1 OVERVIEW OF POOLING AND UNITIZATION AFFECTING APPALACHIAN SHALE DEVELOPMENT Sharon O. Flanery Ryan J. Morgan 1 Steptoe & Johnson PLLC Charleston, WV Synopsis § 01.01. What are Pooling and Unitization? ......................................................................... 2 [1] — Oil and Gas Title and the Rule of Capture ............................................................. 4 [2] — Traditional Concepts of Well Spacing .................................................................... 6 [3] — The Doctrines of Pooling and Unitization .............................................................. 8 § 01.02. History and Development Pooling and Unitization .............................................. 10 [1] — A Brief History of Statutory Pooling .................................................................... 10 [2] — The Development of Spacing and Pooling Law – The Texas Example ............... 13 [3] — A Brief History of Statutory Unitization .............................................................. 15 § 01.03. Current State of the Law – An Overview ............................................................. 17 [1] — Spacing Rules ....................................................................................................... 17 [2] — Pooling and Unitization ........................................................................................ 20 § 01.04. Status of Pooling Statutes in Appalachian Shale States........................................ 27 [1] — Maryland ............................................................................................................... 28 [2] — New York.............................................................................................................. 29 [3] — Ohio ...................................................................................................................... 32 [4] — Pennsylvania ......................................................................................................... 35 [5] — West Virginia ........................................................................................................ 39 § 01.05. Recommendations for Statutory Improvements ................................................... 48 [1] — Spacing Rules Tailored to Horizontal Wells ........................................................ 48 [2] — Notice and Approval Requirements...................................................................... 50 [3] — Allocation of Costs and Election Rights ............................................................... 51 [4] — Surface Use ........................................................................................................... 52 § 01.06. Conclusion ............................................................................................................ 52 1 The authors wish to acknowledge a number of individuals who provided invaluable assistance in the research and preparation of this article. Brian R. Hopkins recently joined our firm after 9 ½ years as in-house counsel at NiSource and provided extensive research on the history of pooling and spacing requirements. Alexandria D. Lay (3L at Washington & Lee University School of Law) and James M. Tartaglia (3L at T.C. Williams School of Law, University of Richmond) provided insightful comments and diligent quality review and revisions.
754
Embed
A National Survey of Statutory Pooling and Unitization
This document is posted to help you gain knowledge. Please leave a comment to let me know what you think about it! Share it to your friends and learn new things together.
Transcript
1
OVERVIEW OF POOLING AND UNITIZATION
AFFECTING APPALACHIAN SHALE DEVELOPMENT Sharon O. Flanery Ryan J. Morgan1
Steptoe & Johnson PLLC
Charleston, WV
Synopsis
§ 01.01. What are Pooling and Unitization? ......................................................................... 2 [1] — Oil and Gas Title and the Rule of Capture ............................................................. 4 [2] — Traditional Concepts of Well Spacing .................................................................... 6 [3] — The Doctrines of Pooling and Unitization .............................................................. 8
§ 01.02. History and Development Pooling and Unitization .............................................. 10 [1] — A Brief History of Statutory Pooling .................................................................... 10 [2] — The Development of Spacing and Pooling Law – The Texas Example ............... 13 [3] — A Brief History of Statutory Unitization .............................................................. 15
§ 01.03. Current State of the Law – An Overview ............................................................. 17 [1] — Spacing Rules ....................................................................................................... 17 [2] — Pooling and Unitization ........................................................................................ 20
§ 01.04. Status of Pooling Statutes in Appalachian Shale States........................................ 27 [1] — Maryland ............................................................................................................... 28 [2] — New York .............................................................................................................. 29 [3] — Ohio ...................................................................................................................... 32 [4] — Pennsylvania ......................................................................................................... 35 [5] — West Virginia ........................................................................................................ 39
§ 01.05. Recommendations for Statutory Improvements ................................................... 48 [1] — Spacing Rules Tailored to Horizontal Wells ........................................................ 48 [2] — Notice and Approval Requirements ...................................................................... 50 [3] — Allocation of Costs and Election Rights ............................................................... 51 [4] — Surface Use ........................................................................................................... 52
1 The authors wish to acknowledge a number of individuals who provided invaluable assistance in the research and preparation of this article. Brian R. Hopkins recently joined our firm after 9 ½ years as in-house counsel at NiSource and provided extensive research on the history of pooling and spacing requirements. Alexandria D. Lay (3L at Washington & Lee University School of Law) and James M. Tartaglia (3L at T.C. Williams School of Law, University of Richmond) provided insightful comments and diligent quality review and revisions.
2
Appendix § 02.01 Analysis of Alabama Regulatory Framework........................................................ 57 § 02.02 Types of Alabama Pooling Statutes. ....................................................................... 69 § 03.01 Analysis of Alaska Regulatory Framework. .......................................................... 76 § 03.02 Types of Alaska Pooling Statutes. ........................................................................... 87 § 04.01 Analysis of Arizona Regulatory Framework. ........................................................ 92 § 04.02 Types of Arizona Pooling Statutes. ......................................................................... 99 § 05.01 Analysis of Arkansas Regulatory Framework. .................................................... 105 § 05.02 Types of Arkansas Pooling Statutes. ..................................................................... 113 § 06.01 Analysis of California Regulatory Framework. ................................................... 118 § 06.02 Types of California Pooling Statutes. ................................................................... 124 § 07.01 Analysis of Colorado Regulatory Framework. .................................................... 129 § 07.02 Types of Colorado Pooling Statutes. ..................................................................... 138 § 08.01 Analysis of Connecticut Regulatory Framework. ............................................... 143 § 09.01 Analysis of Delaware Regulatory Framework. .................................................... 146 § 10.01 Analysis of Florida Regulatory Framework. ....................................................... 147 § 10.02 Types of Florida Pooling Statutes. ........................................................................ 162 § 11.01 Analysis of Georgia Regulatory Framework. ...................................................... 169 § 11.02 Types of Georgia Pooling Statutes. ....................................................................... 178 § 12.01 Analysis of Hawaii Regulatory Framework. ........................................................ 181 § 12.02 Types of Hawaii Pooling Statutes. ......................................................................... 185 § 13.01 Analysis of Idaho Regulatory Framework. .......................................................... 186 § 13.02 Types of Idaho Pooling Statutes. ........................................................................... 191 § 14.01 Analysis of Illinois Regulatory Framework. ........................................................ 199 § 14.02 Types of Illinois Pooling Statutes. ......................................................................... 209 § 15.01 Analysis of Indiana Regulatory Framework. ....................................................... 214 § 15.02 Types of Indiana Pooling Statutes. ........................................................................ 221 § 15.01 Analysis of Iowa Regulatory Framework. ............................................................ 224 § 16.02 Types of Iowa Pooling Statutes. ............................................................................. 231 § 17.01 Analysis of Kansas Regulatory Framework. ........................................................ 234 § 17.02 Types of Kansas Pooling Statutes. ......................................................................... 255 § 18.01 Analysis of Kentucky Regulatory Framework. ................................................... 262 § 18.02 Types of Kentucky Pooling Statutes. .................................................................... 276 § 18.03. Analysis of Kentucky Regulatory Framework—Coalbed Methane. ................. 285 § 18.04 Types of Kentucky Pooling Statutes—Coalbed Methane. .................................. 298 § 19.01 Analysis of Louisiana Regulatory Framework. ................................................... 302 § 19.02 Types of Louisiana Pooling Statutes. .................................................................... 325 § 20.01 Analysis of Maine Regulatory Framework. ......................................................... 337 § 21.01 Analysis of Maryland Regulatory Framework. ................................................... 343 § 22.01 Analysis of Massachusetts Regulatory Framework. ........................................... 350 § 23.01 Analysis of Michigan Framework. ........................................................................ 353 § 23.02 Types of Michigan Pooling Statutes. ..................................................................... 361 § 24.01 Analysis of Minnesota Regulatory Framework. .................................................. 365 § 25.01 Analysis of Mississippi Regulatory Framework. ................................................. 368 § 25.02 Types of Mississippi Pooling Statutes. .................................................................. 385 § 26.01 Analysis of Missouri Regulatory Framework. ..................................................... 392 § 26.02. Types of Missouri Pooling Statutes. ...................................................................... 400 § 27.01 Analysis of Montana Regulatory Framework...................................................... 404 § 27.02 Types of Montana Pooling Statutes. ..................................................................... 416
3
§ 28.01 Analysis of Nebraska Regulatory Framework. .................................................... 421 § 28.02 Types of Nebraska Pooling Statutes...................................................................... 432 § 29.01 Analysis of Nevada Regulatory Framework. ....................................................... 436 § 29.02 Types of Nevada Pooling Statutes. ........................................................................ 447 § 30.01 Analysis of New Hampshire Regulatory Framework. ........................................ 452 § 31.01 Analysis of New Jersey Regulatory Framework. ................................................. 453 § 32.01 Analysis of New Mexico Regulatory Framework. ............................................... 458 § 32.02 Types of New Mexico Pooling Statutes. ................................................................ 467 § 33.01 Analysis of New York Regulatory Framework. ................................................... 473 § 33.02 Types of New York Pooling Statutes..................................................................... 482 § 34.01 Analysis of North Carolina Regulatory Framework. .......................................... 488 § 34.02 Types of North Carolina Pooling Statutes. ........................................................... 493 § 35.01 Analysis of North Dakota Regulatory Framework. ............................................ 496 § 35.02 Types of North Dakota Pooling Statutes. ............................................................. 510 § 36.01 Analysis of Ohio Regulatory Framework. ............................................................ 517 § 36.02 Types of Ohio Pooling Statutes. ............................................................................. 529 § 37.01 Analysis of Oklahoma Regulatory Framework. .................................................. 534 § 37.02 Types of Pooling Statutes in Oklahoma. ............................................................... 545 § 38.01 Analysis of Oregon Regulatory Framework. ....................................................... 551 § 38.02 Types of Oregon Pooling Statutes. ........................................................................ 558 § 39.01 Analysis of Pennsylvania Regulatory Framework. ............................................. 563 § 39.02 Types of Pennsylvania Pooling Statutes. .............................................................. 572 § 40.01 Analysis of Rhode Island Regulatory Framework. ............................................. 580 § 41.01 Analysis of South Carolina Regulatory Framework. .......................................... 581 § 41.02 Types of South Carolina Pooling Statutes. ........................................................... 593 § 42.01 Analysis of South Dakota Regulatory Framework. ............................................. 597 § 42.02 Types of South Dakota Pooling Statutes............................................................... 611 § 43.01 Analysis of Tennessee Regulatory Framework. ................................................... 616 § 43.02 Types of Tennessee Pooling Statutes. .................................................................... 625 § 44.01 Analysis of Texas Regulatory Framework. .......................................................... 630 § 44.02 Types of Texas Pooling Statutes. ........................................................................... 647 § 45.01 Analysis of Utah Regulatory Framework. ............................................................ 652 § 45.02 Types of Utah Pooling Statutes. ............................................................................. 658 § 46.01 Analysis of Vermont Regulatory Framework. ..................................................... 662 § 46.02 Types of Vermont Pooling Statutes. ...................................................................... 672 § 47.01 Analysis of Virginia Regulatory Framework. ...................................................... 675 § 47.02 Types of Virginia Pooling Statutes. ....................................................................... 685 § 48.01 Analysis of Washington Regulatory Framework. ............................................... 694 § 48.02 Types of Washington Pooling Statutes. ................................................................ 703 § 49.01 Analysis of West Virginia Regulatory Framework. ............................................ 711 § 49.02 Types of Pooling Statutes in West Virginia. ......................................................... 739 § 50.01 Analysis of Wisconsin Regulatory Framework.................................................... 746 § 51.01 Analysis of Wyoming Regulatory Framework. ................................................... 748 § 51.02 Types of Wyoming Pooling Statutes. .................................................................... 752
4
§ 01.01. What are Pooling and Unitization?
[1] — Oil and Gas Title and the Rule of Capture. From the initial developments of commercial oil and gas production, legislatures and
courts have faced significant challenges in developing a comprehensive legal framework to
address various questions regarding ownership of oil and gas. Commercial development of oil in
the United States began in 1859 with the first producing well drilled by Colonel E.L. Drake in
Titusville, Pennsylvania.2 By that time, the rules that determined ownership of coal and similar
hard-rock mineral deposits, which formed strata beneath the surface of the land, were relatively
well-evolved.3 However, both oil and gas possess characteristics inconsistent with the traditional
notions of “ownership in place” (or in situ ownership) applied to coal and other hard-rock
minerals.4 Oil and gas are fluid, and migrate from areas of high pressure to areas of lower
pressure within the reservoir, or pool, where they are found.5
The “pure” rule of capture
These natural characteristics led to
near-universal adoption of the “rule of capture” by courts of various producing states as the
standard to determine oil and gas ownership.
6 was elucidated by the Supreme Court of Pennsylvania in its
seminal 1889 decision, Westmoreland & Cambria Natural Gas Co. v. De Witt.7 In De Witt, the
court analogized oil and gas in their natural state to wild animals, or “animae ferae naturae,”
roaming beneath the surface of the earth.8 The court held that title to land does not necessarily
constitute ownership of the oil and gas beneath it.9
2 See Bruce M. Kramer & Owen L. Anderson, “The Rule of Capture - An Oil and Gas Perspective,” 35 Envtl. L. 899, 900 (2005) (citing J.E. Brantley, History of Oil Well Drilling 153 (1971)).
In theory, the oil and gas underlying a tract
3 See Brown v. Spilman, 155 U.S. 665, 669-70 (1895). 4 See Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law, § 203 (LexisNexis Matthew Bender 2010). 5 See id. 6 The rule as stated in this paragraph is described as the “pure rule of capture,” as distinct from the version of the rule that includes a “correlative rights” component, requiring due respect for the rights of others owning an interest in the common pool. This component was, in varying forms, incorporated into the jurisprudence of a number of producing states, including Indiana, Kentucky, and later, West Virginia and Texas. For a discussion of cases involving this component, and its evolution, see Bruce M. Kramer & Owen L. Anderson, “The Rule of Capture - An Oil and Gas Perspective,” 35 Envtl. L. 899, 911-25 (2005). 7 Westmoreland & Cambria Natural Gas Co. v. De Witt, 18 A. 724 (Pa. 1889). 8 See id. at 725. 9 Id.
5
of land belong to the landowner.10 However, when they migrate to other areas and are captured
and reduced to possession by another owner, title vests in the captor and thereby extinguishes
that of the prior owner.11
Petroleum gas and oil are substances of a peculiar character, and decisions in ordinary cases of mining, for coal and other minerals which have a fixed situs, cannot be applied to contracts concerning them without some qualifications. They belong to the owner of the land, and are part of it, so long as they are on it or in it, or subject to his control, but when they escape or go into other land, or come under another’s control, the title of the former owner is gone. If an adjoining owner drills his own land and taps a deposit of oil or gas extending under his neighbor’s field, so that it comes into his well, it becomes his property.
This reasoning was endorsed by the U. S. Supreme Court in Brown v.
Spilman, wherein the Court stated:
12
In essence, the rule of capture provides that “[t]he owner of a tract of land acquires title to the oil
and gas which he produces from wells drilled thereon, though it may be proved that part of such
oil or gas migrated from adjoining lands.”13
Once a producing well had been drilled, the rule of capture motivated landowners in the
area to protect their potential oil and gas assets by rushing to drill on their own land.
Therefore, it is largely a rule of self-help under
which landowners, suffering from potential drainage, were not awarded a share in neighboring
wells because they were deemed to have the ability to prevent drainage and protect their interest
by drilling their own well.
14
10 Id.
Because
oil and gas naturally exist in underground reservoirs or pools that often underlie numerous
separately owned tracts, the rule of capture left a landowner with two options: he could either
drill on his own land to take possession of the oil and gas and thereby perfect ownership; or, he
could sit by while neighbors drilled wells that would likely drain those resources. As a practical
11 Id. 12 Spilman, 155 U.S. at 669-70 (citing Brown v. Vandergrift, 80 Pa. 142 (1875); Westmoreland & Cambria Natural Gas Co. v. De Witt, 18 A. 174 (Pa. 1889)). 13 See Robert E. Hardwicke, “The Rule of Capture and Its Implications as Applied to Oil and Gas,” 13 Tex. L. Rev. 391, 393 (1935) (quoting Eliff v. Texon Drilling Co., 210 S.W.2d 558, 562 (Tex. 1948)). 14 See Rance L. Craft, “Comment: Of Reservoir Hogs and Pelt Fiction: Defending the Ferae Naturae Analogy Between Petroleum and Wildlife,” 44 Emory L.J. 697, 700 (1995).
6
matter, this meant that in order to ensure recovery of his fair share of production from the
“common pool,” each owner needed to drill as many wells on his property as quickly as
possible.15 The resultant race to produce led to excessive well density, substantial over-drilling,
and waste, which included undue surface waste, waste of economic resources, and waste of oil
and gas reserves through premature depletion.16
While the consequences of this frenzied production were manifested in virtually every
producing state, they are perhaps best illustrated by the events surrounding the famed oil well at
Spindletop.
17 Captain Anthony F. Lucas and his drilling team struck oil in the Spindletop salt
dome near Beaumont, Texas, on January 10, 1901.18 The initial “black plume” that shot from
Spindletop soared to twice the height of the drilling derrick, and the well set a world record of
roughly 800,000 barrels of oil within the first nine days of production.19 A wave of speculators
soon followed, and by the end of 1901 there were 440 wells on the 125-acre hill where
Spindletop sat.20 New wells continued to be drilled as “close together as physically possible,”
and 1,000 wells had been drilled around Spindletop by 1904.21 However, only 100 of these
wells produced oil at a rate of more than 10,000 barrels a day.22 Captain Lucas lamented over
the consequences of this rush to produce, stating that “[t]he cow was milked too hard, and
moreover she was not milked intelligently.”23
[2] — Traditional Concepts of Well Spacing.
The rule of capture yielded results during the early days of oil and gas development that
were not contemplated or desired by its authors. In response, various producing states enacted
oil and gas conservation statutes near the turn of the Twentieth Century to curb excessive drilling 15 See Phillip E. Norvell, “Prelude to the Future of Shale Gas Development: Well Spacing and Integration for the Fayetteville Shale in Arkansas,” 49 Washburn L.J. 457, 459 (2010). 16 See id. at 459-60. 17 See Rance L. Craft, “Comment: Of Reservoir Hogs and Pelt Fiction: Defending the Ferae Naturae Analogy Between Petroleum and Wildlife,” 44 Emory L.J. 697, 701 (1995). 18 Id. 19 See id. (citing Walter Rundell, Jr., Early Texas Oil: A Photographic History 1866-1936 36-37 (1977)). 20 Id. 21 Id. (citing Richard O’Connor, The Oil Barons: Men of Greed and Grandeur 81 (1971)). 22 Id. (citing O’Connor, at 85). 23 Id.
7
and protect correlative rights.24 A primary feature of many conservation laws was the imposition
of spacing requirements, which limited the number of wells that could be drilled within a
specified acreage.25 It is against this backdrop that the concept of pooling tracts together for
production first emerged.26
In general, spacing requirements govern the location of wells within a given pool or
common reservoir.
In order to appreciate this relationship, it is important to have a basic
understanding of well spacing. Once one grasps the fundamental concepts of well spacing, it can
readily be seen how pooling emerged as a natural next step in the evolution of this aspect of oil
and gas law.
27 There are two types of spacing rules. First, there are “lineal” rules that
prescribe setback distances between a well and other points.28 Typically, spacing rules will
establish a minimum distance between any two wells and from each well to the boundaries of the
unit or leasehold upon which it sits. In addition, some states impose setback requirements from
dwellings, public roads, or other features.29 The other principal type of spacing dictates the
standard acreage required for a single well and within which no other well may be located.30
This second type of spacing is often referred to as “density” spacing.31
24 See 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization § 2.02 (LexisNexis Matthew Bender 2010).
25 See Bruce M. Kramer, “Compulsory Pooling and Unitization: State Options in Dealing with Uncooperative Owners,” 7 J. Energy L. & Pol’y 255, 258 n.10 (1986) (citing R. Sullivan, Handbook of Oil and Gas Law 285 (1955)). This article identifies other principal methods of oil and gas conservation, including (1) Drilling Operations-The regulation of procedures used in drilling and completing wells; (2) Maximum Efficient Rate-Limiting production to the maximum efficient rate (MER) of the well based on its geological capabilities; and (3) Prorationing-Limiting the amount of oil and gas that can be sold from each well within a common source of supply or reservoir and allocating that amount between the various wells that are producing from that common source. 26 See id. at 258 (“The concepts of well spacing and pooling go hand in hand.”). 27 See 1 Bruce M. Kramer and Patrick H. Martin, The Law of Pooling and Unitization, § 5.02 (LexisNexis Matthew Bender 2010). 28 Id. 29 See text infra § 01.03. [1] for an exemplary spacing regulation; see also Sharon O. Flanery & Ryan J. Morgan, “A National Survey of Statutory Pooling and Unitization,” (Steptoe & Johnson PLLC, Working Paper), available at http://www.steptoe-johnson.com/know-how/docs/A_National_Survey_of_Statutory_Pooling_and_Unitization.pdf [hereinafter “National Survey”] for further discussion of each state’s spacing requirements. 30 These unit areas are commonly set as arbitrary tracts, e.g., 40 acres for oil wells and 640 acres for gas wells. See, e.g., Mo. Code Regs. Ann. tit. 10, § 50-2.070 (2011). Conversely, some statutes do not specify acreage, but allow the conservation agency to set spacing units as that area “that can be efficiently and economically drained by one well.” See, e.g., Neb. Rev. Stat. § 57-908(2) (2010). 31 See 1 Bruce M. Kramer and Patrick H. Martin, The Law of Pooling and Unitization, § 5.02 (LexisNexis Matthew Bender 2010).
8
By limiting the number of wells that may be drilled in a given area, lineal and density
spacing rules seek to protect correlative rights and prevent waste. 32 In accomplishing these
objectives, the spacing rules can also create a situation in which a landowner is prevented from
being able to produce the oil or gas underlying the land. It is this situation that pooling is
intended to address.33
[3] — The Doctrines of Pooling and Unitization.
Most often, the impetus to pool mineral interests is driven by well spacing rules which
would otherwise prevent the owners of small tracts from producing the oil and gas underlying
their land, as each owns insufficient acreage to obtain a well permit.34 In simple terms, pooling
is merely the grouping together of small tracts or interests therein to form a conjoined production
unit in compliance with applicable spacing standards.35
In theory, two basic types of pooling exist. The first is voluntary pooling.
36 As the name
implies, voluntary pooling involves private arrangements to allow for joint development of the
separately owned oil and gas interests within a spacing unit.37 In modern practice, voluntary
pooling is accomplished through several mechanisms, such as (1) community leases that
embrace multiple, separately owned tracts or interests to effectuate joint development; (2) lease
provisions that authorize a lessee to pool the leased area with nearby tracts; and (3) contractual
pooling agreements.38
The second type, referred to as compulsory or statutory pooling, arises when applicable
spacing requirements necessitate the inclusion of adjacent tracts within the spacing unit that are
32 Notably, correlative rights protection and waste prevention are the stated policy goals of every state oil and gas conservation agency. See “National Survey,” for each state’s statutory definition of waste. 33 See Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law, § 901 (LexisNexis Matthew Bender 2010). 34 See 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization § 1.02 (LexisNexis Matthew Bender 2010). 35 See id. 36 See Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law, § 902 (LexisNexis Matthew Bender 2010) (“In some sense, perhaps, virtually all pooling is compulsory rather than voluntary, since it is motivated by the compulsion of economic factors or [by] zoning or spacing regulations.”). 37 See 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization §§ 7.03-7.05 (LexisNexis Matthew Bender 2010). 38 See id.
9
not commonly owned.39 This fragmented ownership may be the result of an existing lease to a
party other than the proposed operator or unleased owners who fail to negotiate satisfactory
terms for voluntary inclusion in the unit. 40 In these circumstances, the vast majority of
producing states provide a statutory process by which, upon consent from a requisite proportion
of the owners or operators in the area to be pooled, an owner or operator may petition the
authorized state agency laws for a pooling order. 41 If granted, the order will mandate the
inclusion of the interests of non-consenting owners or operators in the pooled area and establish
the terms upon which all parties involved will be compensated.42
The rationale behind statutory pooling is that an owner or operator of a small tract who
cannot drill due to spacing requirements should remain entitled to recover the oil and gas
underlying his land. To deny him that right with no opportunity to realize the economic value of
his property amounts to the confiscation of his oil and gas interest without remedy or
compensation.
43
As a general concern, it is important to clarify the distinction between pooling and
unitization. Although the two concepts are doctrinally similar, there is substantial variation in
their treatment among the states.
On the other hand, to permit each owner or operator to drill on his small tract
results in inefficient land use akin to the degradation surrounding Spindletop. A statutory
pooling process provides a prudent and equitable solution to this dilemma.
44
39 See Bruce M. Kramer, “Compulsory Pooling and Unitization: State Options in Dealing with Uncooperative Owners,” 7 J. Energy L. & Pol’y 255, 257-59 (1986).
On many levels, the difference between pooling and
unitization is primarily one of procedure and is best understood by considering the relationship
of each to spacing requirements. As noted above, the term “pooling” most often refers to the
40 See id. at 258. 41 See text infra § 01.03. [2] for a national overview of the variety of pooling and unitization statutes. See also “National Survey,” for a further discussion of each state’s pooling and unitization laws; 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization § 10.01 (LexisNexis Matthew Bender 2010). 42 See 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization § 13.04 (LexisNexis Matthew Bender 2010). 43 See id. at § 10.01 (citing R.R. Comm’n v. Humble Oil & Refining Co., 245 S.W.2d 488 (Tex. 1952)). 44 See “National Survey,” for further discussion of each state’s pooling and unitization laws.
10
integration of smaller tracts and interests therein to obtain a drilling permit in compliance with
spacing rules. Unitization, also commonly labeled “unit operations,” is “the consolidation of
mineral or leasehold interests covering all or part of a common source of supply.”45 The main
objective of unitization is to maximize production efficiency from a given reservoir and may be
sought in the context of drilling permit applications, as well as currently-producing wells and
proposed secondary recovery methods.46 Unitization may also be vital to ensure that correlative
rights of the various owners in the pool are protected.47
Like pooling, unitization is governed by state conservation laws that may address the
ability of private parties to voluntarily unitize their interests in all or part of a reservoir; or, a
statute may prescribe procedural rules under which an owner or operator may petition the agency
for a unitization order.
Thus, while pooling stems directly from
the relevant spacing requirements in an area, unitization exists outside of spacing rules to include
a broader scope of joint operations.
48
§ 01.02. History and Development Pooling and Unitization.
For the purposes of this article, the term “pooling” is used
interchangeably to signify the general concept of integrating separately owned interests that
includes both mechanisms. However, pooling and unitization are distinguished when necessary.
[1] — A Brief History of Statutory Pooling. The practice of statutory pooling dates back to 1920s municipal zoning ordinances
designed to limit drilling within the boundaries of the locality, the first of which was enacted in
Winfield, Kansas in 1927.49
45 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization § 1.02 (LexisNexis Matthew Bender 2010).
Soon after, the validity of a similar ordinance was challenged and
46 See id. 47 See generally Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law, § 901 (LexisNexis Matthew Bender 2010) (discussing the effect and purposes of pooling and unitization); see also, e.g., Colo. Rev. Stat. § 34-60-103(4) (2010) (defining “correlative rights” to mean “that each owner and producer in a common pool or source of supply of oil and gas shall have an equal opportunity to obtain and produce his just and equitable share of the oil and gas underlying such pool or source of supply”). 48 See “National Survey,” for further discussion of each state’s unitization laws. 49 See Patrick H. Martin and Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 905.1 (LexisNexis Matthew Bender 2010) (citing R. M. Williams, “Compulsory Pooling and Unitization (of Oil and Gas Rights),” S.W. Legal Found., 15 Ann. Inst. on Oil and Gas L. & Tax’n 223 (1964)).
11
ultimately upheld in the landmark case of Marrs v. City of Oxford.50 Other municipal ordinances
followed throughout Texas,51 Oklahoma,52 and other states, which were substantially similar to
contemporary statutory pooling laws as they mandated single-well spacing units and the sharing
of production therefrom.53 These local rules were generally affirmed to be valid exercises of
police power under U.S. Supreme Court precedent established in Village of Euclid v. Ambler
Realty Co.54
State-wide statutory pooling statutes were first enacted in New Mexico and Oklahoma in
1935.
55 The Oklahoma Well-Spacing Act, sustained in Patterson v. Stanolind Oil & Gas Co.56
and Croxton v. State,57
In the event a producing well, or wells, is completed upon a unit where there are two or more separately owned tracts, any royalty owner, or group of royalty owners, holding the royalty interest under a separately owned tract, shall share in one-eighth of all of the production from the well or wells drilled within the unit in the proportion that the acreage of their separately owned tract bears to the entire acreage of the unit.
empowered the state’s Corporation Commission to establish drilling or
spacing units of a specified acreage and provided as follows:
58
The statute further required that a lessee holding a majority interest in the unit allow each
minority owner an opportunity to participate as a working interest owner in the development of
50 See generally Marrs v. City of Oxford, 24 F.2d 541 (D. Kan. 1928), aff’d, 32 F.2d 134 (8th. Cir. 1929) (denying that an ordinance requiring well spacing and shared production constituted a violation of local police power and the privileges and immunities clause of the Fourteenth Amendment). 51 See, e.g., Tysco Oil Co. v. R.R. Comm’n, 12 F. Supp. 195 (S.D. Tex. 1935). 52 See Patrick H. Martin and Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 905.1 (LexisNexis Matthew Bender 2010) (citing Am. Bar Ass’n, Conservation of Oil and Gas: A Legal History, 1948 391-397 (Murphy ed. 1949). 53 See id. 54 See id.; see also Vill. of Euclid v. Ambler Realty Co., 272 U.S. 365, 394 (1926)) (“We have nothing to do with the question of the wisdom or good policy of municipal ordinances. If they are not satisfying to a majority of citizens, their recourse is to the ballots – not the courts.”). 55 Id. (citing N.M. Laws 1935, Ch. 72, § 12; 1935 Okla. Sess. Laws art. 1, ch. 59). 56 Patterson v. Stanolind Oil & Gas Co., 77 P.2d 83 (Okla. 1939). 57 Croxton v. State, 97 P.2d 11 (Okla. 1939). 58 See Patterson, 77 P.2d at 87.
12
common acreage to be pooled.59 This mandate, which laid the foundation for modern pooling
statutes, was expressly accepted by the court as within the legislature’s power.60
In reaching this determination, the Oklahoma court relied upon established U.S. Supreme
Court precedent in Ohio Oil Co. v. Indiana.
61 There, the Court considered the constitutional
validity of a state law which prohibited the flow of oil or gas from a well to escape into open air
as a practice constituting physical waste thereof. 62 In upholding the Act, the Court
acknowledged each state’s authority to prevent the waste of oil and gas and to protect correlative
rights of all owners through reasonable legislation. 63
As to gas and oil, the surface proprietors within the gas field all have the right to reduce to possession the gas and oil beneath. They could not be absolutely deprived of this right which belongs to them without a taking of private property. But there is a coequal right in them all to take from a common source of supply, the two substances which in the nature of things are united, though separate. It follows from the essence of their right and from the situation of the things, as to which it can be exerted, that the use by one of his power to seek to convert a part of the common fund to actual possession may result in an undue proportion being attributed to one of the possessors of the right, to the detriment of others, or by waste by one or more to the annihilation of the rights of the remainder. Hence, it is that the legislative power, from the peculiar nature of the right and the objects upon which it is to be exerted, can be manifested for the purpose of protecting all of the collective owners, by securing a just distribution to arise from the enjoyment by them, of their privilege to reduce to possession, and to reach the like end by preventing waste.
Justice White, writing for the Court,
offered the following explanation which supports the mechanisms of statutory pooling and
unitization today:
64
In the wake of cases such as Patterson and Croxton, most producing states enacted statutory
pooling statutes, which consistently have been sustained so that no reasonable debate over their
59 See id. at 87-88. 60 See id. at 88-90. 61 Ohio Oil Co. v. Indiana, 177 U.S. 190 (1899). 62 See id. at 200. 63 See id. at 210-12. 64 Id. at 209-10.
13
constitutionality remains.65
[2] — The Development of Spacing and Pooling Law—The Texas Example.
However, the tension created by spacing and pooling statutes was
not merely a constitutional issue, but often created debate over the equitable principles
underlying state conservation laws. The following brief history of well spacing and pooling as
they developed in Texas illustrates this point and highlights the struggles which led that state to
adopt statutory pooling as a means of leveling the playing field between small and large tract
owners.
The Texas Railroad Commission adopted its first lineal spacing rules in 1919.66 By
1953, the Railroad Commission had adopted density spacing, 67 which effectively prevented
small tract owners from producing the oil and gas under their land unless they were able to
negotiate a pooling arrangement. 68 To account for the plight of these smaller owners, the
Railroad Commission began to treat each oil and gas owner as having the right to locate a well
on his tract regardless of its size and offering certain small tract owners an exception to spacing
rules.69 As no small owner would drill if his production was limited to his acreage, the Railroad
Commission also refused to limit small tract production.70
However, the freedom to produce for small owners unfairly prejudiced adjacent owners
in the pool; thus, the Railroad Commission adopted proration formulas to fairly allocate
production among wells with a common source of supply.
71 By the early 1960s, the Railroad
Commission was commonly using a proration formula for gas wells, known as the one-third to
two-third formula.72
65 See Patrick H. Martin and Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 905.1 (LexisNexis Matthew Bender 2010).
This method meant that “[one-third] of the total field allowable must be
66 See Ronnie Blackwell, “Forced Pooling Within the Barnett Shale: How Should the Texas Mineral Interest Pooling Act Apply to Units for Horizontal Wells?,” 17 Tex. Wesleyan L. Rev. 1, 2 (2010). 67 See id. at 3 (citing Tex. R.R. Comm’n, Oil and Gas Circular No. 11 (Nov. 26, 1919)). 68 See id. 69 See id. Mr. Blackwell notes that the Railroad Commission did not offer this exception to owners whose tract was voluntary subdivided after oil and gas was discovered, either by lease or by deed, to circumvent the spacing rules. 70 See id. 71 See Ernest E. Smith, “The Texas Compulsory Pooling Act,” 43 Tex. L. Rev. 1003, 1004 (1965). 72 See Atlantic Ref. Co. v. R.R. Comm’n, 346 S.W.2d 801, 802 (Tex. 1961). At that time, the Railroad Commission employed a “one-half to one-half” formula for oil wells. See Ronnie Blackwell, “Forced Pooling Within the Barnett
14
divided equally among all the wells in the field and that [two-thirds] of the total field allowable
will be divided among all the wells on a per acreage basis.”73
This practice continued until the methodology was challenged in Atlantic Refining Co. v.
Railroad Commission.
Since a substantial portion of the
allowable production was allocated on a per well basis, this formula inequitably favored the
small tract owner.
74 In that case, the appellee owned a 0.3-acre tract and obtained a drilling
permit in exception from the spacing rules.75 The appellants presented evidence to show that
under the ‘one-third to two-third formula,’ the appellee would be able to produce 200 times more
gas per acre than an owner of a 320-acre tract. 76 Appellants argued that in light of such
evidence, “the proration rule adopted by the Railroad Commission . . . [was] unreasonable,
arbitrary and confiscatory, and [did] not allow appellants to produce their fair share of the gas
from the reservoir.”77 The Texas Supreme Court held that the proration method as applied did
not “afford each producer in the field an opportunity to produce his fair share of the gas from the
reservoir,” as it allowed owners of small tracts excepted from spacing rules to drain well beyond
their equitable share.78 The court refrained from imposing any judicial standard beyond what
was before it, but maintained that the Railroad Commission had a statutory responsibility “to
devise some rule of proration which will conserve the gas in the field…and at the same time be
fair and just to all parties without depriving any of them of his property.”79
In the wake of Atlantic Refining, the Railroad Commission developed various methods to
fairly allocate allowable production and most often employed a formula based solely on
Shale: How Should the Texas Mineral Interest Pooling Act Apply to Units for Horizontal Wells?,” 17 Tex. Wesleyan L. Rev. 1, 4 (2010) (citing Robert E. Hardwicke & M. K. Woodward, “Fair Share and the Small Tract in Texas,” 41 Tex. L. Rev. 75, 81-82 (1962). 73 See Atlantic Ref., at 803. 74 See id. 75 See id. at 803. 76 See id. 77 Id. at 805. 78 Id. at 811. 79 Id. at 812.
15
proportional acreage.80 Although the small tract owners continued to receive spacing exceptions,
drilling on those parcels became unprofitable without an agreement to pool with the owners of
surrounding tracts.81 Thus, the plight of the small tract owner returned, as larger owners could
refuse to pool and drain the oil and gas from the reservoir without compensating the small
owners, who were unable to economically drill alone.82 The legislature responded to this unjust
scenario in enacting the Mineral Interest Pooling Act in 1965 to provide a procedure by which
the Railroad Commission could compulsorily pool interests under certain conditions.83
[3] — A Brief History of Statutory Unitization.
While the concepts of pooling and unitization are similar, the broader scope of unitized
operations is mirrored in its initial development at the federal level. The engineering industry
was accustomed to the idea of unitized operation by the early 1920s; however, many credit the
work of independent oil man Henry L. Doherty as the pre-eminent advocate of its benefits.84
Despite initial opposition from much of the oil industry, Doherty diligently urged producers and
lawmakers to embrace governmental involvement in oil conservation at a national scale.85 The
crux of his arguments targeted the rule of capture as a product of judicial rhetoric that
incentivized inefficiency and devastated the industry and rights of owners. Doherty lamented
that “[p]ractically every evil of the oil business, and everything about which the public complain,
is due to the fact that oil does not follow the usual law of property rights but belongs to the man
who can capture it.”86
In response to such efforts, groups began to investigate the potential for unitization,
which eventually became a well-accepted alternative to the inefficient practices Doherty
80 See Ronnie Blackwell, “Forced Pooling Within the Barnett Shale: How Should the Texas Mineral Interest Pooling Act Apply to Units for Horizontal Wells?,” 17 Tex. Wesleyan L. Rev. 1, 4 (2010); see also Ernest E. Smith, “The Texas Compulsory Pooling Act,” 43 Tex. L. Rev. 1003, 1004 (1965). 81 See id. at 4-5. 82 See id. at 5. 83 See id.; see also 1965 Tex. Gen. Laws 24 (current version at Tex. Nat. Res. Code Ann. §§ 102.001, et seq. (West 2011)). 84 See 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization, § 3.02 (LexisNexis Matthew Bender 2010) (citing R. Hardwicke, Antitrust Laws, et al. v. Unit Operation of Oil and Gas Pools 1-13 (1961)). 85 See id. 86 See id. at n.35 (citing Hardwicke at 179-90).
16
criticized.87 By 1926, the Federal Oil Conservation Board issued a statement, prophesying that
“[t]he unit idea in producing oil is bound to win out because the natural unit is the oil pool…[and
unitization] means both efficiency in development and operation and the determination of
equities among the owners.”88 These remarks, as well as the American Bar Association’s 1929
policy statement, which offered a model unitization statute and the support of the newly-formed
Interstate Oil Compact Commission, prompted broader support of the concept and increased
conservation regulation of the industry. 89 However, much of this state intervention initially
focused on prorated production rather than statutory unitization, until Oklahoma enacted the first
statute of its kind in 1945.90 The Oklahoma Act withstood prompt challenge in the courts, as the
facial constitutionality was upheld in Palmer Oil Corp. v. Phillips Petroleum Corp. 91 Soon
thereafter, many oil-producing states followed suit and passed conservation statutes which
provided for statutory unitization.92
As this brief historical discussion suggests, pooling and unitization, both in their
voluntary and statutory forms, are long-standing doctrines that have been adopted by an
overwhelming majority of oil and gas producing jurisdictions. Today, the constitutional validity
of these regulatory mechanisms is beyond dispute. Further, the public interests of waste
prevention and correlative rights protection are best pursued through a comprehensive regulatory
scheme that incorporates both statutory pooling and unitization.
93
87 See id. (citing Hardwicke at 35-75). Such studies were conducted in 1920s and 1930s by the Federal Oil Conservation Board, the American Petroleum Board, and the ABA’s Mineral Law Section, among others.
As the remainder of this
88 See id. 89 See 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization, § 3.02 (LexisNexis Matthew Bender 2010). 90 See id. The Oklahoma statute originally codified at Okla. Stat. Ann. tit. 52, §§ 286.1, et seq. (1945), authorized the Corporation Commission to unitize all or part of a common reservoir upon petition from lessees owning at least 50 percent of the interests therein. 91 See generally Palmer Oil Corp. v. Phillips Petroleum Corp., 231 P.2d 997, 1003–07 (Okla. 1951), app. denied, 343 U.S. 390 (1952) (upholding the statute’s validity against an array of constitutional challenges). 92 See 1 Bruce M. Kramer & Patrick H. Martin, The Law of Pooling and Unitization, § 3.02 (LexisNexis Matthew Bender 2010); see, e.g., 1951 Ark. Acts § 134 (current version at Ark. Code Ann. § 15-72-310, et seq. (2010)). 93 See Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law, Oil and Gas Terms: “Unitization” (LexisNexis Matthew Bender 2010) (“The best results in conservation can be attained only by unitization.”).
17
article will show, while these goals are common among the states, there is substantial variation in
how each state addresses pooling and unitization and the procedural requirements each employs
to effectuate a pooling or unitization order.
§ 01.03. Current State of the Law—An Overview.
[1] — Spacing Rules.
Spacing rules exist in nearly every state with codified law relating to oil and gas
production. Today, there are 34 states which have default spacing rules of some kind written
into the law.94 Each one of these affords the controlling agency some, if not total, discretion to
reconfigure spacing on a case-by-case basis. This authority is typically exercised through the
creation of special rules applicable to a particular pool or field or by a process by which the
agency may grant exceptions for certain wells upon application. In addition, seven states do not
offer default spacing by statute, but expressly grant full authority to an administrative entity to
set unit size and setback requirements for each pool.95
Whether controlled by statute or agency regulation, most current spacing schemes include
lineal and density spacing requirements. In the modern regulatory framework, the minimum
distance required by lineal spacing rules and the minimum area required by density spacing rules
will often vary depending upon the mineral produced and depth to which the well will be drilled
and completed. Of the 34 states with codified spacing, 30 states specify different lineal or
density spacing rules based on the mineral produced from the pool.
96
94 While application varies significantly, the states which provide some level of general spacing requirements are Alabama, Alaska, Arizona, Arkansas, California, Colorado, Florida, Georgia, Idaho, Illinois, Indiana, Iowa, Kansas, Kentucky, Louisiana, Maryland, Mississippi, Missouri, Nevada, New Mexico, New York, North Dakota, Ohio, Oklahoma, Oregon, Pennsylvania, South Carolina, South Dakota, Tennessee, Texas, Utah, Virginia, Washington, and West Virginia. See “National Survey,” for further discussion of each state’s spacing rules.
In addition to each
imposing separate default rules for oil and gas wells, a number of states have created spacing
95 These seven states are Michigan, Montana, Nebraska, North Carolina, Vermont, Wisconsin, and Wyoming. 96 The four states which do not differentiate general spacing rules based on the mineral produced are Arkansas, California, Ohio, and Utah.
18
laws particular to coalbed methane wells.97
The general spacing rules in Kentucky exemplify an encompassing framework that shows
all levels of distinction:
These rules will often be further differentiated based
on the depth of the producing formation.
Except as provided [by exception or special order], no permits shall be issued for the drilling, deepening, or reopening of any shallow well for the production of oil, unless the proposed location of the well shall be at least [330] feet from the nearest mineral boundary of the premises upon which the well is to be drilled, deepened or reopened; and, the proposed location must be at least [660] feet from the nearest oil producing well. This subsection shall not be construed to regulate the distance between wells which do not produce oil from the same pool. Except as provided [by exception or special order], no permit shall be issued for the drilling, deepening or reopening of any shallow well for the production of gas unless the proposed location of the well shall be at least [500] feet from the nearest mineral boundary of the premises upon which such well is to be drilled, deepened or reopened; and, the proposed location must be at least [1,000] feet from the nearest gas producing well. This subsection shall not be construed to regulate the distance between wells which do not produce gas from the same pool.98
The Kentucky conservation statute sets these differing lineal, shallow well spacing requirements
based on the mineral produced and directs the Oil and Gas Conservation Commission to create
spacing rules applicable to deep wells via its permitting process. These regulations provide for
density spacing of deep wells based on the depth of the target formation. First, a permit
applicant must supply a plat aligned with the Commission’s default density rules:
If a permit is requested for a deep gas well . . . the application shall include a plat showing a proposed unit comprising a square with sides of 3,500 feet if the well is to be drilled to a depth less than 7,000 feet and with sides of 5,000 feet if the well is to be drilled to a depth of 7,000 feet or more.
97 Statutory spacing for coalbed methane wells exists in the following states: Alabama, Colorado, Illinois, Indiana, Kentucky, Maryland, Pennsylvania, Virginia, and West Virginia. 98 See Ky. Rev. Stat. Ann. § 353.610 (LexisNexis 2011) (emphasis added); see also id. § 353.510(15) (defining “shallow well” as “any well drilled and completed at a depth less than [4,000] feet except, in the case of any well drilled and completed east of longitude line 84 degrees 30’, shallow well means any well drilled and completed at a depth less than [4,000] feet or above the base of the lowest member of the Devonian Brown Shale, whichever is the deeper in depth.”).
19
If the permit is for a deep oil well, the proposed unit plat shall comprise a square with sides of 1,750 feet if the well is to be drilled to a depth of less than 7,000 feet and 2,500 feet if the well is to be drilled to a depth of 7,000 feet or more.99
In addition, the regulations provide lineal spacing rules in requiring that “no deep gas well drilled
to a depth less than 7,000 feet shall be located within 1,072 feet of the boundary of the proposed
unit, and no deep gas well drilled to a depth of 7,000 feet or more shall be drilled within 1,532 feet
of the boundary of the proposed unit.”100 Further, “no deep oil well drilled to a depth less than
7,000 feet shall be located within 536 feet of the boundary of the proposed unit, and no deep oil
well drilled to a depth of 7,000 feet or more shall be drilled within 766 feet of the boundary of the
proposed unit.”101
Rather unique to Kentucky law is the caveat that the Commission may grant exceptions to
spacing only to a certain extent. If an exception is necessary due to topographical or geological
conditions, the well location remains subject to the following absolute set-back spacing limitations:
(1) A deep oil well at a depth less than 7,000 feet may be located no closer than 438 feet to the boundary of the proposed unit. (2) A deep oil well at a depth of 7,000 feet or more may be located no closer than 625 feet to the boundary of the proposed unit. (3) A deep gas well at a depth of less than 7,000 feet may be located no closer than 875 feet to the boundary of the proposed unit. (4) A deep gas well at a depth of 7,000 feet or more may be located no closer than 1,250 feet to the boundary of the proposed unit.102
Kentucky does not provide distinct distance requirements for horizontal oil and gas wells.
However, Commission regulations state that if a permit is issued by the Commission to allow
deviated drilling, the “bottom hole location or objective shall comply with all minimum distances
from unit lines as prescribed by all statewide orders or special field rules.”103
Most modern statutory pooling statutes usually have five major elements. First, they
have provisions which lay out the prerequisites that must be met before statutory pooling can be
invoked, such as formation of a spacing or drilling unit that contains two or more separately
owned tracts or interests. Second, statutes often contain provisions identifying or establishing
the parties who are authorized, and who have standing, to apply for a statutory pooling order.
Third, as previously mentioned, they set out a procedure to apply to the state conservation
agency for the desired order. Fourth, they outline the procedure to give notice to the other
interested parties and to hold a hearing on the application for statutory pooling. Finally, such
statutes provide for issuance of an administrative order, which either denies the application or
sets out the terms upon which statutory pooling is granted. In many states, those terms are
established, or at least guided, by statute or rule. In other states, they are left largely to the
discretion of the conservation agency.
Most states have regulatory bodies (herein generically referred
to as the “board” or “boards”) which may compulsorily pool interests in a drilling unit, although
owners or operators may also pool their interest by way of voluntary pooling agreements. The
procedural mechanisms for setting up such group development is generally the same—i.e., in the
absence of a voluntary agreement, the owners or operators must file an application with the
board containing a plan including the information required by statute along with appropriate
bond and often a degree of approval among interest holders.
Pooling orders issued by state boards are generally the result of a petition filed either by
an interested party or upon a board’s own motion.107
106 Among states that have both statutory pooling and unitization are Alabama, Arkansas, Florida, Kentucky, Louisiana, North Dakota, Ohio, Oklahoma, and South Dakota; see “National Survey,” for further discussion of each state’s pooling and unitization laws.
While voluntary agreements have issues of
their own—e.g., must the agreement be ratified by 100 percent of the unit’s ownership?—
107 See, e.g., Ala. Code § 9-17-81 (2010); see also “National Survey,” for further discussion of each state’s procedural requirements for statutory pooling and unitization.
22
statutes allowing for statutory pooling orders contain many provisions, which naturally provide
some variety among states.
Statutory pooling orders generally must be approved by the state board. A few states also
contain minimum operator or owner controls for pooling orders—that is, a provision requiring
the operators or owners of a minimum percentage of interests responsible for costs and of a
minimum percentage of all interests entitled to royalty payments to ratify or approve in writing
the order promulgated by the board. Far more states only contain these minimum operator or
owner controls with regard to unitization orders, discussed below. The relevant percentage, if
any, varies by state.
For states with statutory unitization statutes, the minimum operator control provision
often dictates that unless a requisite percentage of operators or owners authorize or ratify in
writing the unitization order, that order will not become effective.108
Of the 33 states that have statutory unitization, 29 require some form of written
authorization by holders of certain types of interest in the unit to satisfy the minimum control
requirements.
In most cases, this written
authorization must take place within a set number of months from the date the order was issued
or the order will be automatically revoked unless that time allowance is extended.
109
108 See “National Survey,” for further discussion of each state’s minimum control requirements.
The vast majority of these, 25 states, require authorization by both owners of a
percentage of working interest or by those responsible for costs (both groups herein collectively
referred to as the “working interest group”), as well as approval by owners entitled to royalties or
by owners of similar proceeds from production free of costs (both groups herein collectively
referred to as the “royalty group”). The percentage varies between states, but usually it is the
same percentage within a particular state as to both the working interest group and the royalty
109 These states are Alabama, Arizona, Arkansas, California, Colorado, Florida, Georgia, Illinois, Kansas, Kentucky, Louisiana, Michigan, Mississippi, Montana, Missouri, Nebraska, Nevada, New Mexico, New York, North Dakota, Ohio, Oklahoma, Oregon, South Carolina, Tennessee, Utah, Vermont, Washington, and West Virginia. West Virginia’s approval requirements pertain only to unitization of secondary recovery oil wells, see W. Va. Code § 22C-9-8(a)(4) (2011).
23
group; it ranges from as low as 51 percent110 to as high as 80 percent.111 Sixteen states contain
75 percent approval requirements for at least one group,112 while 11 states provide numbers
between 60 percent and 66.67 percent.113
A handful of regulatory unitization structures are unique in that, although they require a
certain percentage of approval, they also dictate that if one interest holder has enough interest to
approve the order, yet holds less than 100 percent of the interest, at least one other interest holder
must vote in favor of the order for it to become effective.
114 The statute may or may not specify
that the other interest holder must be unaffiliated with the majority holder. Similarly, one state,
New Mexico, requires that if one interest holder has enough interest to defeat the order, yet holds
less than 50 percent of the interest, at least one other interest holder must also vote to disapprove
the order.115
Kansas has a noteworthy structure, which allows for “voluntary” unitization so long as all
mineral and royalty owners and not less than 90 percent of the working interest holders approve
the voluntary unitization agreement.
116
110 E.g., Illinois and Kentucky.
In the absence of such approval, the state board may
issue an order for unit operations. The percent of approval required then depends upon the
reason for the order—i.e., it may be due to low production and imminent abandonment of wells
in the unit area (in which case only 63 percent of both groups must authorize), or it may be that
111 E.g., Colorado. 112 These states are Arkansas, California, Florida, Georgia, Kansas, Kentucky, Louisiana, Michigan, Montana, Missouri, Nebraska, New Mexico, Oregon, South Carolina, Washington, and West Virginia. West Virginia’s approval requirement pertains only to unitization of secondary recovery oil wells, see W. Va. Code § 22C-9-8(a)(4) (2011). Kentucky’s approval requirement appears to pertain only to deep wells, see Ky. Rev. Stat. Ann. § 353.652(1)(d) (LexisNexis 2011). 113 Four have 60 percent requirements (Montana, New York, North Dakota, and South Dakota), one has 62.5 percent (Nevada), three have 63 percent (Arizona, Kansas, and Oklahoma), two have 65 percent (Nebraska and Ohio), and one has 66.67 percent (Alabama). 114 Those states are Montana, New Mexico, and North Dakota. 115 N.M. Stat. Ann. § 70-7-8 (2011). 116 Kan. Stat. Ann. § 55-1317(b) (2010).
24
unitization is merely feasible and would increase ultimate recovery of oil and gas (in which case
63 percent of the working interest group and 75 percent of the royalty group must authorize).117
Of the states with minimum operator controls, 21 states specify by statute when the
requisite authorization must be secured.
118 Almost unanimously, states give six months to obtain
approval of the order to satisfy the minimum operator control requirement. Three states,
however, require approval to be shown at the time the application for unitization is submitted to
the board,119 and one state provides 12 months.120
Many states provide statutory options by which unleased, non-consenting interests may
participate in unit development. The options available vary by states—some statutory schemes
provide multiple avenues of participation,
121 while others offer little guidance on how to treat
non-consenting interests.122
117 Id. §§ 55-1304, -1305.
Sometimes, a non-consenting owner is given the statutory right to
lease or otherwise relinquish its interest, opting instead to receive a one-time per-acre bonus and
a fair royalty payment, which is generally a one-eighth percentage of the owner’s share of
production. Another common royalty level is a one-eighth percentage or the lowest royalty
provided by contract in the pool, whichever percentage is greater. The states that provide for
transfer of the non-consenting party’s working interest vary as to whether the surrender of that
interest is permanent or only until the owner’s share of costs, or share of costs plus a penalty fee
as discussed below, have been recovered out of production.
118 These states are Alabama, Arizona, Arkansas, Colorado, Florida, Georgia, Illinois, Kansas, Kentucky, Michigan, Mississippi, Nevada, New York, North Dakota, Ohio, Oklahoma, Oregon, South Carolina, South Dakota, Tennessee, and West Virginia. 119 These states are Kentucky, Tennessee, and West Virginia. For example, West Virginia requires that approval be shown prior to the issuance of any unitization order for secondary recovery oil wells, see W. Va. Code § 22C-9-8(a)(4) (2011). 120 Mississippi provides 12 months to show the requisite approval. 121 States that give the non-consenting owner several statutorily-available participation options include New York, see N.Y. Envtl. Conserv. Law § 23-0901(3)(c) (McKinney 2011), and Pennsylvania, see 58 Pa. Stat. § 408(c) (2011). 122 States that are either silent as to participation or merely state that the board must provide “just and reasonable terms and conditions” for participation include Georgia, Michigan, Oklahoma, Oregon, and Tennessee.
25
Instead of leasing, many states allow the owner to retain their working interests, electing
varying options to finance those interests, while often allowing the owner to continue to receive
their royalty entitlement.123 At one extreme, owners in some states may elect to participate up-
front by paying for their portion of drilling and operating costs at the outset of operations and
sharing in the risk and rewards with other operators. For owners who cannot afford to pay the
cost initially, some states provide the option for the non-consenting party to have its financial
contribution carried, or financed, by the other working interest owners. In those situations, other
operators will pay the carried owners’ costs and in return will be reimbursed from the proceeds
of the carried owners’ portion of production, although the owners’ royalty entitlements may be
exempted from this recapture. Generally, carried participants, who are not vulnerable to the risk
of drilling a dry hole,124 will be charged a “risk penalty,” a fee that can be as much as double or
triple the actual prorated cost of drilling.125 Finally, some states allow “free rides” to non-
consenting owners, allowing owners to be carried without paying a risk penalty.126
The various schemes of working interest participation provide different incentives to non-
consenting owners in deciding whether to join a voluntarily pooling agreement. Owners who are
statutorily entitled to be carried as a free ride have no incentive to participate up front when they
may instead pay over time out of production with no interest charges and no risk penalty. For
owners subject to a substantial risk penalty, the incentive to participate up front increases, but
only so long as the well is likely to produce and provided that the owner has the capital to
participate.
123 This is a majority approach in which the statutes convert the unleased owners’ interest into a one-eighth royalty interest and a seven-eighths working interest and fit those interests into the states’ statutory structure for participation. 124 Operators may not sue these carried non-participating owners for recovery of their proportionate costs of drilling and operating but may only recover said costs from the proportionate share of production; thus if drilling results in a dry hole or marginal producer, the non-consenting owners are not subject to risk. 125 States that allow risk penalty charges include: Colorado, Louisiana, Nebraska, New Mexico, New York, Texas, Utah, and West Virginia. 126 These states are Alabama, Alaska, Arizona, Florida, Indiana, Iowa, Missouri, Montana, Nevada, North Carolina, and North Dakota.
26
Also, some statutes that provide for the option to carry or otherwise finance non-
consenting, unleased owners fail to express that the operator is entitled to retain working interest
revenue from production to recover well costs. In lieu of direct entitlement, those statutes give
the well operator a lien on the non-consenting owner’s share of production until such time as the
non-consenting owner’s share of costs has been recouped, thereby exposing the operator to
increased risk.
Additionally, states differ on whether providing options or offers to the non-consenting
owners is a prerequisite to pooling. Some states require the pooling order to include an offer to
the non-consenting owners of their option to elect, with a stated number of days within which the
operator must respond before he or she will be automatically considered to have chosen the
default election option.127 Other states, however, do not require the pooling order to set out the
options available, but instead incentivize the giving of options by, for example, allowing
operators to charge more in costs if they can show they have provided the non-consenting party
with the option to participate.128
The State of Washington provides a comprehensive example of statutory treatment of
unleased mineral owners. Washington provides non-consenting owners with several options
once a statutory pooling petition has been filed. The first option is a modified seven-eighths to
one-eighth option.
129 The unleased owner can be treated as both royalty owner and working
interest owner, with the possibility of a royalty greater than one-eighth should the leased royalty
owners in the pool have higher royalties, in which case, the remainder is treated as a working
interest.130
127 See, e.g., W. Va. Code § 22-8-11(e) (2011).
For the working interest share, the usual options are available, including the right to
participate and pay pro rata costs and the right to be carried until payout with an appropriate risk
128 See, e.g., Miss. Code Ann. § 53-3-7(2)(a) (2011). 129 Wash. Rev. Code Ann. § 78.52.250(4) (LexisNexis 2011). 130 Id. § 78.52.250(4)(a).
27
penalty.131
The second option authorizes the unleased owner to grant a lease to the operator at the
current market price for comparable leases.
This scheme may present a better option than leasing if an owner knows his or her
tract will be part of a unit which will ultimately be pooled through the statutory process;
however, certainty is unlikely in most instances as the operator may redesign a unit to avoid
having unleased parties gain such economic benefits.
132 This option may be attractive if the lease bonus in
the area is high and the unleased owner will not be able to participate financially as a working
interest owner. Protections against unfair leasehold provisions are written into the statute so that
the operator cannot force the unleased owner to accept unconscionable terms. The final option
allows the unleased owner to treat his or her entire interest as a working interest.133 The owner
would resort to this last option only if the prospects for a very profitable well are high and he or
she can afford to participate in drilling costs. The Washington provision also states that if the
unleased owner does not make an election within 15 days, he or she is to be treated as having
opted for the seven-eighths to one-eighth choice.134
Another difference among the states is that some statutes and regulations provide other
rights to the individuals or entities who own either the surface or the coal seams, or both, within
the pooled acreage. These rights can include requirements that the oil and gas operator notify the
relevant entities of pooling hearings and perform surface reclamation, and also allow objections
by those entities regarding spacing and well location.
§ 01.04. Status of Pooling Statutes in Appalachian Shale States.
The current major horizontal shale development areas in Appalachia are Maryland, New
York, Pennsylvania, and West Virginia for Marcellus Shale development and, in addition to
these states, Ohio for Utica Shale development. Each of these states has adopted conservation
Notwithstanding the adoption of relatively comprehensive statutes by Ohio, New
York, Pennsylvania, and West Virginia, each state has unique problems, whether contained
within the statute itself or in the utilization or application of the statute for horizontal shale
development. These issues are discussed and summarized as follows:
In early June, 2011, an executive order was issued by Maryland’s governor requiring the
Maryland Departments of the Environment (“DOE”) and Natural Resources to conduct a study,
called the Marcellus Shale Safe Drilling Initiative, on the impacts of natural gas drilling in the
Marcellus Shale.136 The final results of that study are not due until August 2014.137 The order is
not a moratorium on permits being issued, but there has been little indication from Maryland that
the issuing of permits is likely before the study is completed. Besides environmental issues, the
Initiative will study spacing and other rules and regulations impacting oil and gas
development.138
In addition to the issues associated with this order and its impacts, a key difficulty that
Maryland oil and gas law presents for shale gas developers is the lack of a statutory pooling
statute. Indeed, the DOE, the state regulatory body, “may not prorate or limit the output of any
gas or oil well.”
139 The DOE is not authorized to order statutory pooling or unitization, even
though voluntary pooling and unitization for mutual benefit are acknowledged by statute.140
135 Each of these states are also members of the Interstate Oil & Gas Compact Commission which serves as a vehicle to assist member states to efficiently maximize oil and natural gas resources through sound regulatory practices while protecting the nation’s health, safety and environment. The IOGCC has drafted a model statute for conservation, i.e., the “2004 Model Oil and Gas Conservation Act.” See http://iogcc.state.ok.us.
For
those reasons, waste prevention and protection of correlative rights are primarily sought through
spacing requirements. Maryland law does contain linear spacing rules, imposing a 1,000-foot
setback between gas or oil wells and boundary lines, unless the owners of adjacent lands have
136 Exec. Order No. 01.01.2011.11 (June 6, 2011) available at http://www.governor.maryland.gov/documents.asp. 137 Id. 138 Id. 139 Md. Code Ann., Envir. § 14-103(LexisNexis 2010). 140 See Md. Code Regs. 26.19.01.09(J) (2010) (defining “pooled unit” as “an area within which permittees of different tracts in the area have voluntarily agreed to participate in a well drilled within the unit”).
29
consented to the spacing in writing.141 The DOE has the authority to prescribe the setbacks
between any wells located on the same property.142 Additionally, the DOE has discretion, after
notice and hearing, to allow drilling within the statutory limits if doing so is necessary due to site
constraints and if the applicant has notified all landowners and royalty owners within 2,000 feet
of the proposed well location by registered mail.143
[2] — New York.
New York law contains spacing rules, as well as both voluntary and statutory pooling and
unitization provisions. All wells in the state must be drilled in conformity with the spacing
requirements, 144 unless the unit otherwise meets the state policy objectives 145 of waste
prevention, increased recovery, and protection of correlative rights.146 The spacing rules differ
for oil and gas wells and are based upon target formation and upon direction; they contain both
lineal and density spacing requirements.147 Any party who applies for an oil or gas drilling
permit must control, either by ownership, voluntary agreement, or departmental integration
order, not less than 60 percent of the acreage in the proposed spacing unit.148
The Department of Environmental Conservation, the governing body, must issue permits
if the proposed spacing unit conforms to spacing rules and if it is approximately uniform in shape
compared to other units covering the same reservoir. The unit must also either adjoin other units
or leave enough space so that additional units may be developed.
149 Prior to issuance of a
permit, the Department must publish notice of intent in the Environmental Notice Bulletin.150
An election form for uncontrolled interests must accompany the integration hearing
notice.163 The options available to such owners include integration as an integrated participating
owner,164 as an integrated non-participating owner,165 or as an integrated royalty owner.166 The
uncontrolled owners have 21 days after receipt of notice within which to indicate to the
Department the type of ownership status they will elect,167 and otherwise the default election
status is that of an integrated royalty owner.168
The Department may also order integration, after notice and hearing, upon its own
motion or after application is filed by an interested person.
169 The same policies regarding waste
prevention and protection of correlative rights are to be considered.170 Unitization orders must
have the written approval of 60 percent of the working interests and 60 percent of the one-eighth
royalty interests in the unit area,171 which approval must be shown within six months of the
issuance of the order or it will become ineffective.172 Orders may be amended in the same way
and are subject to the same conditions as the original orders,173 though only approval of affected
interests will be required.174
The foregoing shows that New York law provides relatively modern procedures that
should promote horizontal shale development. Yet, due to the virtual moratorium in recent
163 Id. § 23-0901(3)(c)(1). 164 An “integrated participating owner” or “participating owner” is a party who chooses to participate in the initial well, pay the costs associated with participating up front, and comply with any and all requirements for participation. Id. § 23-0901(3)(a)(2). 165 An “integrated non-participating owner” or “non-participating owner” is an owner who chooses to reimburse the operator from production proceeds for the owner’s proportionate share of the costs of the well. Id. § 23-0901(3)(a)(1). Once the operator has recouped the portion of the owner’s costs for the well plus a risk penalty, which is equal to 200 percent of the share of the actual well costs allocated to the owner, id. § 23-0901(3)(a)(1), the owner is then entitled to his or her full share of the production attributable to his or her proportionate interest. Id. 166 An “integrated royalty owner” is an owner who chooses to be an integrated royalty owner or who does not choose to operate as either of the previously discussed options; the owner will receive a royalty equaling the lowest royalty of the existing leases in the unit, but not less than one-eighth of the owner’s share of production, but will have no obligation to the well operator for other charges or fees. Id. § 23-0901(3)(a)(3). 167 Id. § 23-0901(3)(c)(2). 168 Id. § 23-0901(3)(c)(1)(i). 169 Id § 23-0901(4). 170 Id. § 23-0901(2). 171 Id. § 23-0901(6). 172 Id. 173 Id. § 23-0901(7). 174 Id. § 23-0901(7)(a).
32
months on hydraulic fracturing in New York which prevents horizontal shale development, the
statute has been rendered moot. In late June of this year, the Department issued
recommendations on mitigating the environmental impacts of high-volume hydraulic fracturing,
which would protect the sensitive watershed areas while allowing for development of
approximately 85 percent of the Marcellus Shale underlying New York lands. 175
(1) High-volume fracturing would be prohibited in the New York City and Syracuse watersheds, including a buffer zone;
Those
recommendations include the following:
(2) Drilling would be prohibited within primary aquifers and within 500 feet of their boundaries; (3) Surface drilling would be prohibited on state-owned land including parks, forest areas and wildlife management areas; (4) High-volume fracturing will be permitted on privately held lands under rigorous and effective controls; and (5) DEC will issue regulations to codify these recommendations into state law.176
Because these recommendations have not been finally adopted and implemented, whether New
York’s statute will be entirely satisfactory in the long term to address the unique challenges
associated with horizontal drilling is still unknown.
[3] — Ohio. While Ohio’s statute can be used for pooling in all active shale plays, such as the Utica,
procedural issues exist. The statute provides exclusive permitting and spacing authority to the
Division of Mineral Resources Management of the Department of Natural Resources.177 The
Chief of the Division administers the rules. The Oil and Gas Commission is strictly an appellate
body, created by statute to allow those adversely affected by an order to appeal to the
Commission.178
175 See Press Release, “New Recommendations Issued in Hydraulic Fracturing Review,” N.Y. Dept. of Envtl. Conservation (June 30, 2011), http://www.dec.ny.gov/press/75403.html.
Applications for drilling permits may be denied by the Chief if he determines
there is substantial risk that the drilling will violate statutory provisions or that the drilling will
put public health and safety or the environment in imminent danger.179 For permits requested in
an urbanized area, longer notice requirements are imposed and more site review is conducted.180
Ohio contains spacing requirements that are set by rule.
181 The Chief is permitted to
issue special orders providing for spacing over a pool or field.182 The rules distinguish between
the depth to which the well is drilled and include both linear and density spacing rules.183 The
rules, rather uniquely, do not distinguish based upon mineral produced; neither do they differ
based upon direction of drilling. In fact, Ohio regulations provide that unless approval is given
by the Chief, wells may not “vary unreasonably from the vertical drawn from the center of the
hole at the surface.”184
Pooling applications may be made to the Division for a mandatory pooling order.
185
Also, in order to accommodate horizontal shale well drilling, special field rules may be
necessary, as the current spacing rules may not be adequate, although to date, several horizontal
wells have been permitted and drilled without any request for special field rules. In the absence
of field rules, units must comply with the boundary set-offs of the general spacing rules, even for
units of larger size. If the information is complete in an application for a pooling order, the Chief
will notify the applicant, the attorneys, and all landowners in the area to be encompassed in the
drilling unit of the date of the hearing in front of the Technical Advisory Council (“TAC”).186
The TAC will recommend approving or denying the application based on the information
presented in the application and at the hearing. The Chief will review the application,
information presented at the hearing and the TAC recommendation and determine whether
179 Id. § 1509.06(F). 180 Id. § 1509.06(H). 181 Id. § 1504. 182 Id. § 1509.25. 183 Ohio Admin. Code 1501:9-1-04 (2011). 184 Id. § 1501:9-1-02(H). 185 Ohio Rev. Code Ann. § 1509.27 (LexisNexis 2011). 186 Id. The Technical Advisory Council on Oil and Gas was created under Section 1509.38 of the Ohio Revised Code and consists of eight members appointed by the Governor and meets at least once a calendar quarter. Additional meetings are at the request of its chair or two of its members, but such requests have not been used in at least 25 years.
34
mandatory pooling is necessary to protect correlative rights and to effectively develop the
mineral resources; then, it will enter an order.187 The order will specify the process whereby any
party to the order may appeal the Chief’s decision to the Oil and Gas Commission.188 For owners
who do not elect to participate in the risk and cost of drilling, those owners will be designated
non-participating owners on a limited or carried basis; applicants who pay for a non-participating
owner’s portion of costs are entitled to the non-participating owner’s share of production,
exclusive of the royalty interest due, until the applicants have been reimbursed the costs
expended plus an added percent of the owner’s share as the Chief may determine, the total
amount of which may not exceed 200 percent of the owner’s share of charges.189
As for unit operation of a pool, the Chief, either by his own motion or by application of
65 percent of the owners of the land overlying the pool, will hold a hearing to decide if a need
exists for the operation of the pool as a unit.
190 This provision was intended for application in
secondary oil recovery operations, involving the use of multiple wells in the unit, and is not
generally applicable to pooled units. Potentially, this could be applied in circumstances
involving the use of multiple horizontal boreholes but is better suited for its primary purpose,
efficient utilization of secondary recovery technology in oil fields. The Chief should enter the
order if it finds that unit operation is reasonably necessary to increase substantially the ultimate
recovery of oil and gas and that the added value likely will exceed the added costs.191 These
orders must also contain provisions providing for costs and potential financing options for
owners unable to meet up-front costs.192
As the foregoing indicates, Ohio’s statute is a relatively generic and comprehensive one.
However, the major issues with this statute and its application are procedural. For example, each
entity is limited to five pooling applications per year, unless further applications are authorized
by the Director, and the TAC generally meets only once per quarter.193
[4] — Pennsylvania.
In addition to these
procedural restrictions, because the Utica is a recent horizontal shale development play, it is
unknown whether Ohio’s statute will be entirely satisfactory in the long term to address the
unique challenges associated with horizontal drilling.
Pennsylvania has three statutes that address oil and gas production: the Oil and Gas
Act, 194 the Oil and Gas Conservation Law (“Conservation Law”), 195 and the Coal and Gas
Resources Coordination Act (“Coal and Gas Coordination Act”),196 which was recently amended
by Pennsylvania Act 2 of 2011 (“Amendment”), effective May 13, 2011.197 The Department of
Environmental Protection (“DEP”) is the regulatory body with authority to carry out the
provisions of each act. The Oil and Gas Act is meant to allow for responsible development of
Pennsylvania’s oil and gas resources and does not restrict its application to any depth.198 The
Coal and Gas Coordination Act requires coordination between gas and coal operators199 and
applies to all gas wells which penetrate a workable coal seam. 200 The Coal and Gas
Coordination Act, however, does not apply to gas wells permitted under the Conservation Law or
to oil wells.201
The Conservation Law is the only act of the three that provides for unitization, and while
none of the three Acts address traditional oil and gas spacing, the Coal and Gas Coordination
Act, as amended, includes spacing designed to protect coal resources. The Conservation Law
provides the DEP with authority to provide for the integration or communitization of interests
193 Id. § 1509.27. 194 58 Pa. Stat. §§ 601.101-.605 (2011). 195 Id. §§ 401-419. 196 Id. §§ 501-518. 197 See S. 265, 2011 Gen. Assemb., Reg. Sess. (Pa. 2011). 198 Id. § 601.102. 199 Id. § 512. 200 Id. § 503(a); see also id. § 502 (defining a “workable coal seam” as “a coal seam identified …as capable of being mined by underground methods.”). 201 Id. § 503(b).
36
within a drilling unit202 to prevent waste. However, it only applies to wells that penetrate the
Onondaga horizon or, in those areas in which the Onondaga horizon is nearer to the surface than
3,800 feet, any wells that exceed a depth of 3,800 feet beneath the surface.203 The Marcellus
shale sits just above the Onondaga limestone formation,204 so it is not covered by any statutory
pooling provisions in Pennsylvania; the Utica, which is deeper,205
For those operators seeking an initial drilling permit in Pennsylvania, they must provide
the DEP with their application, which includes the names of all affected surface owners, surface
owners and water purveyors whose water supplies are within 1,000 feet of the proposed well
location, and the record owner or operator of all known underlying workable coal seams,
is covered by the Conservation
Law.
206 each
of which are entitled to a copy of the plat207 and who have 15 days within which to file an
objection.208 The application must also state whether the well will substantially deviate from the
vertical and which workable coal seams underlie the tract to be drilled.209
No spacing rules exist in Pennsylvania under any of the Acts; however, under the
Conservation Law, spacing or unit orders can be created by the DEP. The location of any wells
drilled subject to the Conservation Law must conform to any applicable spacing or pooling
orders issued under the Conservation Law.
210 The orders must, when created, specify the
minimum distance from the nearest spacing unit boundary.211
202 Id. § 405(c)(1)(iv).
The location of permitted wells
subject to the Conservation Law must be at least 330 feet from the nearest outside lease
203 Id. § 403(b)(1). 204 “Marcellus Shale FAQ,” W. Va. Geological & Economic Survey (Jan. 7, 2011), http://ims.wvgs.wvnet.edu/mar/marfaq.htm. 205“Marcellus and Utica Shales Data,” Ohio Dept. of Nat. Resources Div. of Geological Survey http://www.dnr.state.oh.us/geosurvey/tabid/23014/Deafult.aspx (last visited Jul. 18, 2011) (stating that the Utica Shale was of the Ordovician age, which is older than the Devonian, in which the Marcellus Shale is found). 206 58 Pa. Stat. § 601.201(b) (2011). 207 Id. § 601.201(c). 208 Id. 209 Id. § 601.201(b). 210 Id. § 403(b)(3). 211 Id. § 407.
37
boundary, which requirement may be waived if landowners outside that area have entered into a
voluntary pooling agreement or if the DEP grants an exception to the requirement.212
The Coal and Gas Coordination Act, as amended, which does not apply to wells subject
to the Conservation Law or oil wells, contains spacing rules which were not enacted under
traditional oil and gas concepts. Rather, these were enacted to limit the number of wells drilled
through coal seams and thereby protect coal reserves. Prior to its amendment, the Coal and Gas
Coordination Act set forth that no permits for gas wells subject to the Coal and Gas Coordination
Act may be issued unless the proposed gas well is not less than 1,000 feet from any “other well,”
which is defined as not including oil, gas, or injection wells that do not penetrate a workable coal
seam; oil, gas, or injection wells that have been plugged; nonproducing oil or gas wells drilled
and abandoned prior to 1955; and storage wells.
213 Further, while the applicant and the coal
seam owner may consent to waive the 1,000-foot spacing requirement, they cannot agree to any
distance less than 900 feet.214 However, where the producing formation is a vertical distance of
1,000 feet or more from the producing formation of any other well and if the applicant and coal
owner have consented in writing, the DEP can grant an exception to the 1,000-foot spacing
rule.215
Thus, prior to the Amendment of the Coordination Act, multi-well horizontal well pads
used in Marcellus shale drilling were at risk because a coal seam owner could arguably object to
the drilling of such wells due to the close spacing of the wells on the pad. The Amendment
makes a major change with respect to spacing in that it provides for 2,000-foot spacing between
“well clusters,” which are defined as the area of a well pad intended to host multiple horizontal
wells (and can be no larger than 5,000 square feet).
216
212 Id. § 407(6); 25 Pa. Code § 79.11(b) (2011).
213 58 Pa. Stat. § 507(a) (2011). 214 Id. § 507(b). 215 Id. § 507(c). 216 The 5,000 square feet limitation may or may not be prohibitive, depending on how an operator spaces its wellbores. This change resolves the uncertainty under the prior Coordination Act as to whether the 1,000-foot
38
Also, the Amendment provides that an operator has to obtain the consent as to a well
location from all owners of an operating coal mine that will be penetrated by the well.217 The
Amendment expands the definition of “active coal mine” to include “the area of the workable
coal seam which may reasonably be expected to be mined and permitted for mining by the
operator during the five-year period beyond the projected completion of the mining of the
currently permitted area.”218
For those wells subject to the Conservation Law, parties may obtain spacing orders by
submitting an appropriate application to the DEP after an initial discovery well has been
drilled.
219 Spacing unit orders must cover all lands believed to be underlain by the pool.220 If
the spacing units contain two or more separately owned tracts or interests, the owners of said
interests may decide to integrate for unit development.221 If parties do not voluntarily integrate
their interests, though, the DEP may issue an order, upon application of an operator who holds
interest in the tract, which provides for such integration.222 As part of the order, the DEP must
specify the terms and conditions upon which, in the absence of a voluntary agreement and
without an order explicitly integrating those interests, royalty interests in the units will be
deemed integrated.223
The order should also prescribe the manner and time in which the operators may elect to
participate in unit operations, as well as provisions for payment by those who elect not to
participate in the reasonable actual costs and expense of operations, plus a reasonable
supervision charge and interest on past due accounts.
224
spacing for wells barred having more than one horizontal well on a single well pad overlying workable coal, as well as giving coal producers more space in between well clusters than they are entitled to between vertical wells. These changes should lessen the impact of wells drilled through coal on coal reserve recovery.
and equitable alternatives for non-participating owners to surrender their leasehold interest on a
reasonable basis to participators; the surrender must be in exchange for reasonable consideration.
Otherwise, the order may provide for election to participate on a limited or carried basis.225
Operators who do the work of drilling or pay for such work for the benefit of a non-participator,
are entitled to such non-participating operators’ share of production, exclusive of a one-eighth
royalty interest, until market price of the production equals 200 percent of the share of such costs
payable to the interest.226
The obvious problems with the state of the law in Pennsylvania, then, is that statutory
pooling is limited to deep wells, which does not include wells drilled for Marcellus development.
For those wells that do come under the jurisdiction of the Conservation Law, the DEP has
discretion as to a substantial portion of the regulation—e.g., spacing rules and election rights—
which might result in uncertainty for various operators, at least until the DEP establishes
guidance through its application of this process. Additionally, statutes that regulate deep wells in
Pennsylvania do not address the issue of minimum operator controls. The lack of certainty and
the lack of a detailed framework may prove problematic as various shale plays are explored in
Pennsylvania.
[5] — West Virginia. West Virginia contains three rather complicated processes for dealing with oil and natural
gas development involving different governing entities, each with its own statutory
framework.227
The Department of Environmental Protection (“DEP”), and the Secretary thereof, have
general permitting authority for oil and gas development pursuant to the West Virginia Code.
228
225 Id.
226 Id. 227 This section is not meant to be a comprehensive coverage of the West Virginia statutes; for complete coverage, see “National Survey.” 228 W.Va. Code § 22-6-2 (2010); see generally id. §§ 22-6-1 to -41.
40
The Secretary is vested with statutory authority to perform all the necessary duties relating to
exploration, development, production, storage, and recovery of oil and gas.229
In addition, the Shallow Gas Well Review Board (“Review Board”) is the body that
reviews coal owner objections regarding shallow gas well placement.
230 The Review Board also
has statutory authority to create drilling units and pool interests within those drilling units, albeit
in extremely limited circumstances;231 so limited, in fact, that the Review Board has not issued a
single drilling unit or pooling order.232 As noted, the Review Board’s purview is limited, and it
does not have authority over deep wells, oil wells and enhanced recovery oil wells, or any
shallow well to which no objection is made.233
The Chief of the Office of Oil and Gas (“Chief”) is the state permitting authority for
coalbed methane wells,
234 much like the Secretary is the permitting authority for conventional oil
and gas wells. The Coalbed Methane Review Board (“CBM Review Board”) is the body that
hears coal operator objections to the drilling location of a coalbed methane well.235
Finally, the Oil and Gas Conservation Commission (“Commission”) has authority to
regulate deep well spacing,
236 and, as relates to deep wells, to approve or deny applications for
new well permits, to establish drilling units or special field rules, and to approve or deny
applications for the pooling of interests in a drilling unit.237
229 Id. § 22-6-2(c)(12).
The article that provides authority to
the Commission supplements and expands upon the statutory requirements set out in article six,
chapter 22 of the Code, which includes the Secretary’s permitting authority.
230 Id. § 22C-8-1(b); see also id. §22-6-1(4) (defining “shallow gas wells” as those gas wells drilled and completed above the uppermost member of the Onondaga Group, with an allowance of 20 feet into the Onondaga for logging and completion operations, but in no event may production be had therefrom). 231 Id. §§ 22C-8-7 to -11. 232 Telephone conversation with W. Va. DEP Staff (May 17, 2011). 233 W. Va. Code § 22C-8-3 (2011). 234 Id. § 22-21-4(b)(2). 235 Id. § 22-21-13. 236 Id. § 22C-9-4(f); see also id. § 22-6-1(g) (defining “deep wells” as those drilled and completed in a formation at or below the top of the uppermost member of the Onondaga Group). 237 Id. § 22C-9-4(h).
41
West Virginia’s general permitting statute238 contains significant notice requirements and
opportunities for objections by affected parties. An applicant seeking to drill an oil and gas well
must notify the record owner(s) of the surface tract where the well is to be located and of any
surface tracts to be utilized for roads or other surface purposes.239 Those surface owners have 15
days to submit comments as to the location or construction of the proposed work.240 In addition,
if the proposed well is underlain by a workable coal seam, owners and operators thereof also are
entitled to a 15-day notice and comment period.241 The Secretary may issue the well work
permit after reviewing any comments received or once the 15-day comment period has passed
with no comment submitted.242
Neither article six of chapter 22 nor the applicable state regulations provide spacing rules
that apply to shallow wells; however, any coal owner comments received regarding the location
of the wells, if not resolved, must be forwarded to the Review Board for hearing.
243
The Review Board will make a recommendation to the Secretary to refuse the permit or
to authorize drilling at the proposed or an alternate location.
At the
Review Board hearing stage, article eight of chapter 22C does contain spacing rules to be applied
in response to coal owner objections to shallow well locations. Thus, initial shallow gas well
permits are not subject to any spacing rules unless a coal owner objects to well location,
prompting the Shallow Gas Well Review Board’s jurisdiction.
244
(1) For all shallow wells with a depth less than [3,000] feet, there shall be a minimum distance of [1,000] feet from the drilling location to the nearest existing well . . .; and
In making its determination, the
Review Board must direct the Secretary to refuse to issue a drilling permit unless the following
(2) For all shallow wells with a depth of [3,000] feet or more, there shall be a minimum distance of [1,500] feet from the drilling location to the nearest existing well . . ., except that where the distance from the drilling location to such nearest existing well is less than [2,000] feet but more than [1,500] feet and a coal seam owner has objected, the gas operator shall have the burden of establishing the need for the drilling location less than [2,000] feet from such nearest existing well. Where the distance from the drilling location proposed by the operator or designated by the board to the nearest existing well . . . is greater than [2,000] feet, distance criterion will not be a ground for objection by a coal seam owner.245
Only after this process has been completed may a party apply for the creation of a
shallow drilling unit. Under the Code, the Review Board’s authority to establish a drilling unit is
conditioned upon the Secretary’s prior refusal to permit drilling within the proposed unit acreage
because of an order of the Review Board.
246 The royalty owners and gas operators within the
drilling unit area must consent to the location therein.247 If unable to agree, the Review Board
will hold a hearing and either issue a written order establishing the drilling unit or dismiss the
application.248
(1) The applicant has proved that the drilling location on the drilling unit has been agreed to by all of the owners of the coal seams underlying such drilling location;
The Review Board may not establish a drilling unit unless it finds the following:
(2) The director has previously refused to issue a drilling permit on one of the tracts comprising the drilling unit because of an order of the board; (3) The drilling unit includes all acreage within the minimum distance limitations provided by section eight of this article, unless the gas operators and royalty owners of any excluded acreage have agreed to such exclusion; and (4) The drilling unit includes a portion of the acreage from under which the well operator intended to produce gas under the drilling permit which was refused.249
The complicated structure of such proceedings may help to explain why the Review Board has
not yet entered into a voluntary agreement in order to facilitate a voluntary agreement.266 If
agreement is not reached, the CBM Review Board will then hold a hearing, after which time it
will grant or deny the application for a drilling unit.267
Finally, the West Virginia Conservation Commission is the authority governing the
spacing of deep wells.
268 The Commission has the authority to issue or deny permits, to
establish drilling units or special field rules, and to approve or deny applications for the pooling
of interests within a unit.269 The statute directing the Conservation Commission provides an
important policy, which dictates that a conflict between the duty to prevent waste and the duty to
protect correlative rights should be resolved in favor of waste prevention.270
(b) the locating, [and] drilling . . . of any oil or gas well in a manner that causes, or tends to cause, a reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or that causes or tends to cause unnecessary or excessive surface loss of oil or gas; or
Waste includes:
(c) the drilling of more deep wells than are reasonably required to recover efficiently and economically the maximum amount of oil and gas from a pool.271
An application to establish a drilling unit for a deep well must be preceded by completion
of a discovery well into the formation at issue. Upon application to establish the drilling units,
the Commission provides all interested parties with notice.272 The statute does not require a
hearing; instead, a hearing must be requested within 15 days of receipt of notice. If no request is
submitted, the Commission will proceed to process the application.273 The Commission has 45
days to either grant or deny the order establishing a drilling unit.274
266 Id. § 22-21-17(a).
If a hearing was held, the
order will be final; if no hearing was held, the Commission will issue a proposed order and
state, such as coal interests, severed interests, and shallow well operators, such statutes should be
uniquely tailored to each particular state.
§ 01.05. Recommendations for Statutory Improvements.
Any state conservation statute and implementation thereof needs to address factors that
are unique to horizontal development in Appalachia. Statutory pooling for horizontal Marcellus
and Utica wells will undoubtedly enhance a producer’s ability to efficiently recover oil and gas
from shale deposits. However, a proper regulatory framework should allow this statutory
integration alongside other provisions to ensure that all the various interests, i.e., oil and gas,
coal, and surface owners, are appropriately balanced by the new legal structure. Such
supplemental provisions must consider the unique nature of horizontal methods and should
address the measures discussed below.
[1] — Spacing Rules Tailored to Horizontal Wells. Unlike traditional vertical drilling, common horizontal industry practice—based on
technology and economies of scale—is to drill multiple horizontal wells together from a single
well pad. Further, one horizontal well may possess multiple horizontal side laterals to be drilled
into the same formation. However, increased well density, i.e., multiple wells spaced and drilled
on a well pad, may adversely impact the development of coal reserves because of the potential
inability of a coal operator to mine through the vertical sections of such wells. Thus, any statute
must address the maximum surface acreage to be utilized for the vertical sections of the
horizontal well locations (or “well cluster” as used in Pennsylvania’s recently enacted
Amendment discussed above) on any such multi-well pad; provide adequate minimum spacing
distances between the well cluster on one multi-well pad and the well cluster on any other multi-
well pad; and restrict or limit the drilling of individual conventional vertical wells between such
well clusters in order to both protect coal resources and promote horizontal well drilling.
Horizontal drilling allows significantly less surface disturbance within the encompassed
unit area because of the use of multi-well pads. A typical Marcellus multi-well pad is
49
approximately five acres in disturbed surface size.288
Unlike a conventional vertical well, a horizontal shale well actually drills through the
formation, and its drainage is a limited area beyond the completion locations in the horizontal
bore. Furthermore, because of the irregular size of tracts involved in Appalachia and because
numerous tracts can be penetrated by the horizontal bore in Appalachia, any effective statute for
horizontal shale wells should include not only a combining of drained properties for the sharing
of production but also the right to drill through properties. This right to drill through properties
is somewhat different from the traditional use of conservation statutes that were originally
enacted to address drainage from an off-tract well in addition to addressing over-drilling. Also,
because of the continuing developments in horizontal drilling and completion technology, more
and more properties may be impacted by each horizontal well. Furthermore, an unleased tract in
the middle of a horizontal wellbore design has potentially greater negative impact as it could
affect rational development and deprive not only the oil and gas owner and developer of royalties
and income but also deprive a jurisdiction of significant revenues from taxes and other direct and
Utilizing this limited surface area for well
operations, an operator can produce more natural gas as compared to development by vertical
wells which would require many more conventional vertical well locations and therefore much
more surface disturbance. Thus, promoting development of horizontal multi-well pads and
providing spacing regulations to govern minimum distances between such well clusters better
serves surface owners, as well as environmental and land use interests, because on a macro level
there should be much less surface disturbance. In summary, restrictions on the maximum
acreage area associated with each well cluster, the minimum distance between well clusters, and
the location of conventional vertical wells between well clusters fosters many public policies,
while protecting the interests of surface owners and the coal owners and operators.
288 See, e.g., “Why Multiple Horizontal Wells from Centralized Well Pads Should Be Used for the Marcellus Shale,” W. Va. Surface Owners’ Rights Org., http://www.wvsoro.org/resources/marcellus/horiz_drilling.html (last visited July 10, 2011).
50
indirect economic benefits associated with such well development. Additionally, there is greater
potential for stranded unleased tracts that will never be drilled or developed if pooling and
unitization principles are not adopted. Any statute should therefore address the right to penetrate
or drill through tracts.
[2] — Notice and Approval Requirements. The need for statutory pooling in Maryland, West Virginia, and Pennsylvania is partially
due to the severed land and mineral ownership, as well as the irregularly-shaped tracts in the
region. To ensure that the rights of surface, coal, and oil and gas owners are sufficiently
protected, the statutes should provide specific notice requirements which afford each owner
potentially affected by an application for a pooling order notice and an opportunity to voice
comments and concerns, e.g., surface owners could be impacted by use of their surface; coal
owners could be impacted by increased well density in the unit, and oil and gas owners could be
impacted by being statutorily pooled. In addition, such notice and a clear structure of what
factors should be considered by the reviewing body when addressing such comments are needed
in order to insure that not only are non-oil and gas owners’ rights protected, but that the oil and
gas owners’ rights are protected and that public policy to develop natural resources is fostered.
Additionally, a clear structure setting forth the election rights 289 will offer a currently non-
consenting oil and gas owner a final chance to negotiate with the applicant for consensual
pooling terms. The notice requirements currently in place in West Virginia for well work
applications 290
Further, the statute should subject any horizontal pooling order to minimum operator
control thresholds based on widely accepted standards found in other states. Currently, these
thresholds of required consent across the various jurisdictions range from 50 percent of proposed
offer an example well-suited to transition to applications for pooling and
unitization orders.
289 See text supra §§ 01.03. [2], 01.05. [3] for further discussion of election rights. 290 See W. Va. Code § 22-6-1, et seq. (2010).
51
pooled interests to 75 percent or 80 percent consent by relevant owners thereof on a net acreage
basis.291 Most states require between 63 percent and 75 percent consent from working interest
and/or royalty owners.292 A minimum operator control threshold requiring 75 percent approval
on a net acreage basis also provides substantial protection to owners of unleased tracts and
smaller independent producers who may have acreage within a proposed unit.293
[3] — Allocation of Costs and Election Rights.
Another important aspect of comprehensive pooling statutes is the statutory presence of
clear election rights for non-consenting owners who are subject to a pooling or unitization order.
When issued by the authorized agency, these orders should provide general terms as to how such
non-consenting mineral owners are to be treated. As this article shows, there are many ways to
structure a statutory election scheme. The most comprehensive of these provides legislative
guidance in how these rights should be framed, but also allows agency discretion to set particular
terms based on the facts presented at the public hearing.
Severed ownership in Appalachia, coupled with the substantial initial and continuing
costs of Marcellus well production, suggests that non-consenting owners should be able to
transfer their interests to the operator on reasonable terms or be carried with a marginal risk
compensation fee. For example, as total compensation for the expense and inherent risks in
commencing drilling operations, a non-consenting owner may owe the operator 200 percent of
the unpaid portion of that owner’s share of drilling and operating costs. Notably, this payment
would come solely from such owner’s share of production from the unit and be withheld by the
operator exclusive of a royalty guaranteed by statute. 294
291 See “National Survey,” for further discussion of each state’s minimum control requirements.
This compensation scheme is
292 See text supra § 01.03. [2] for further discussion. 293 In West Virginia, this minimum threshold should also apply to any tracts owned by cotenants and to the extent 75 percent of such leased and unleased cotenants approve, such tract should be counted toward such approval threshold. This will prevent a cotenant with a small undivided interest from exercising a veto over the rights of all other cotenants who freely contract for or approve such pooling and unitization. 294 This proposed risk compensation fee for horizontal shallow wells would mirror those already in place in West Virginia for deep wells. See W. Va. Code § 22C-9-11(b)(6) (2011) (establishing that a deep well operator who obtains a pooling order is entitled to production of a carried non-participating owner “until the market value of such
52
significantly more generous to non-consenting owners than the law in many states, 295
[4] — Surface Use.
while
retaining a nominal fee to fairly protect horizontal well operators and incentivize smaller lessees
and unleased owners to negotiate with operators and feel secure in doing so.
In addition to the protections afforded to an unleased fee simple owner by adequate
notice, approval, and election schemes, a revised statute tailored to horizontal wells must
consider appropriate use of the surface with respect to unleased tracts that will be statutorily
pooled in a unit. For example, the horizontal pooling statute could require consent from the
owner of the surface overlying an unleased mineral owner before the unit operator may conduct
surface operations on said unleased tract. Although the owner of the surface overlying a
statutorily pooled unleased mineral owner holding a minority interest in the pooled acreage
should not able to unilaterally halt the unit operations of the total unit, traditional standards of
equity suggest that he should have some level of control over whether a horizontal well pad is
located on the surface overlying unleased acreage, which was statutorily pooled. Likewise,
public policy interests in some circumstances may require that the unit operator be granted
reasonable access to and from operation locations, and provisions could be set forth granting
access across such unleased tract. When the surface overlying a tract is owned by a number of
cotenants, a statutory requirement could be placed on the operator to secure the voluntary
agreement from a supermajority of the undivided interests before surface operations would be
permitted on the tract.
§ 01.06. Conclusion.
Throughout history, the Appalachian region has supplied the often-overlooked foundation
for America’s global leadership in energy production and technological advancement. The coal
industry in our area has traditionally provided the American public the irreplaceable service of non-participating owner's share of the production, exclusive of such royalty, overriding royalty or one-eighth of production, equals double the share of such costs payable by or charged to the interest of such nonparticipating owner”). 295 See “National Survey,” for further discussion of each state’s treatment of non-consenting owners or operators.
53
affordable and reliable energy. Today, the vast natural reserves of the Marcellus Shale place
Maryland, West Virginia, and Pennsylvania at the precipice of unprecedented economic growth,
with the potential to reshape our nation’s energy portfolio, which is crucial to re-capturing fiscal
stability here and abroad. Further, modern innovation of horizontal drilling methods enables
production from these reserves with efficiency never-before imagined. The wealth of oil and
natural gas underlying our region demands that industrial and independent producers be
supported by a comprehensive regulatory framework to foster safe and efficient development of
these resources.
As this paper shows, there is substantial variety among the states in procedural treatment
of oil and gas production under conservation laws. However, the inclusion of statutory pooling
and unitization is the common trend underlying those regulatory schemes which are well-
developed and most sensitive to the various interests involved. In Appalachia, a cohesive
regulatory framework must protect the rights of surface, coal, and oil and gas owners; address
potential environmental concerns by promoting best industry practices and public education; and
capitalize on the unique natural resources of the region. To accomplish these goals, Maryland,
West Virginia, and Pennsylvania must advance their respective legal structures to incorporate
statutory pooling for all horizontal shale wells. It is inadequate to add a statutory pooling
provision for horizontal shallow wells to existing law; rather a sound, well-developed system for
pooling and unitization of horizontal wells will require a comprehensive approach.
The recommendations above are not intended to provide an exhaustive list of all
important aspects of this horizontal shale well regulation. However, such provisions will afford
benefit to landowners, successfully balance the interests of the coal and natural gas industries so
vital to local economies, and prompt more environmentally-responsible well location and
operation. While the authorized state agency should maintain some level of discretion to
determine proper details for each situation, the legislature must empower these bodies to use
54
statutory integration to pool ownership interests so that production will minimize surface use,
protect coal resources, enhance oil and gas recovery, and provide otherwise unattainable
economic benefit to citizens, owners, and well operators.
This article’s summary of the various pooling strategies found throughout the nation
serves more than an academic exercise or guide for industry actors. It aims to clearly convey
that pooling and unitization are developed, long-standing legal doctrines formed and adopted by
the overwhelming majority of states to encourage the most efficient and cost-effective means of
recovering oil and gas. Further, the constitutional validity of these regulatory mechanisms is
beyond dispute. When done properly, these methods will spur economic growth and be a
catalyst that places Maryland, West Virginia, and Pennsylvania at the forefront of sustainable
energy production through the Twenty-First Century.
55
Appendix
56
Appendix
Notwithstanding the effects of federal environmental legislation, oil and gas production
maintains its traditional place within the purview of state regulation. Many jurisdictions endorse
common goals and procedures in developing conservation mechanisms, yet each state addresses
oil and gas regulation in light of its particular social and economic aims. The logical variety
among states with regard to attainable intrastate resources and other localized interests thus
creates a hodgepodge of regulatory frameworks when considered on a national scale.
This Appendix offers a detailed summary of each state’s oil and gas conservation
regulations, with a focus toward pooling and unitization schemes. While some conservation
programs are significantly more in-depth than others, this Appendix provides a state-by-state
analysis to identify each state’s regulatory framework, procedural requirements imposed for
pooling and unitization, and notable areas of the law that impact their implementation. The
authors hope that the following serves as a reliable tool for industry members, legal
professionals, and anyone seeking to learn more about oil and gas conservation in their home or
other states.
57
§ 02.01 Analysis of Alabama Regulatory Framework.
[1] – Name of the Governing Body.
The State Oil and Gas Board (“Board”) is the regulatory body created by the legislature
with specific authority to regulate pooling in the state.296
[2] – Membership on the Governing Body.
The Board consists of three members with staggered terms. The Governor appoints the
members, and for the initial appointments, one member is elected for a term of two years, one for
a term of four years, and one for a term of six years. At the expiration of the initial terms, each
newly appointed member will thereafter serve six-year terms. In the event of a vacancy, the
Governor must appoint a new member to fill the unexpired term of the previous member. All of
the members of the Commission must be residents of Alabama and must be a qualified voter in
that state. Each member is eligible for reappointment at the Governor’s discretion. Also, each
member must qualify by taking an oath of office and must hold his office until his successor is
appointed and qualified.297 Members who serve nineteen or more years continuously become
nonvoting members emeritus of the Board, which receive no compensation.298 Otherwise, each
member receives an annual compensation of $3,600.00, plus entitlement to a travel and office
expense allowance of $500.00 per month, which allowance is paid by the oil and gas fund.299
The Board is required to elect a chairman from its membership and is required to meet or
hold hearings at times and places found by the Board to be necessary to carry out its duties.
Two members of the Board constitute a quorum, but two affirmative votes are required for the
adoption or promulgation of any rule, regulation, or order of the Board.301
Additionally, the state geologist is, ex officio, the state oil and gas supervisor
(“Supervisor”). The Supervisor is given the duty to enforce this article and all rules, regulations,
and orders promulgated by the Board. Also, the Supervisor is, ex officio, secretary of the Board
and will keep all the Board’s minutes and records.
302 The Supervisor, with the Board’s
concurrence, has the authority and duty to employ all personnel necessary to carry out this
article’s provisions.303
[3] – Scope of Authority.
The Board has jurisdiction and authority “over all persons and property necessary to
administer and enforce effectively the provisions of this article and all other articles relating to
the conservation of oil and gas.”304 The article declares as its public policy the prevention of
waste of oil and gas and protection of correlative rights.305
(a) the inefficient, excessive, or improper use or dissipation of reservoir energy and the locating, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner which results or tends to result in reducing the quantity of oil or gas ultimately to be recovered from any pool in this state;
“Waste” is defined as “‘physical
waste’ as that term is generally understood in the oil and gas industry,” and includes the
following:
(b) the inefficient storing of oil and the locating space, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner causing or tending to cause unnecessary or excessive surface loss or destruction of oil or gas; (c) abuse of the correlative rights and opportunities of each owner of oil and gas in a common reservoir due to nonuniform,
disproportionate and unratable withdrawals causing undue drainage between tracts of land; . . . (g) underground waste however caused and whether or not defined; [and] . . . (l) production of gas in excess of reasonable market demand.306
The Board has the authority and duty to determine whether or not waste exists or is imminent
within its jurisdiction,307 as this article explicitly prohibits waste.308
(1) collect data; (2) make investigation and inspection; (3) examine properties, leases, papers, books, and records, including drilling records, logs, and other geological and geophysical data; (4) examine, check, test, and gauge oil and gas wells, tanks, plants, processing facilities, structures, natural gas pipelines and gathering lines, and storage and transportation equipment and facilities, and other modes of transportation; (5) hold hearings; (6) appoint a hearing officer for the purpose of conducting public hearings on behalf of the board and making recommendations to the board; (7) require the keeping of records and the making of reports; [and] (8) take action as may be reasonably necessary to enforce the article.
In meeting that goal, the
Board has the authority to do the following:
309
The Board has authority to create reasonable rules, regulations, and orders that may be
necessary in the administration and enforcement of this article, after proper hearing and notice.310
(4) to require reports showing the location of wells and to require the filing of logs and drilling records and the lodgment in the office of the State Oil and Gas Supervisor of typical drill cutting or cores, if cores are taken, within six months from the time of any well’s completion; . . .
Such rules, regulations, and orders may be made for the following purposes, among others:
(6) to prevent wells from being drilled, operated, or produced in a way that causes injury to neighboring leases or property; . . . (11) to identify the ownership of all oil and gas wells, producing leases, tanks, plants, processing facilities, structures, natural gas
pipelines and gathering lines and storage and transportation equipment and facilities; . . . (14) to establish drilling units, to determine the spacing of wells, to establish oil and gas fields for each oil and gas pool, to establish the spacing of wells for each pool, and to establish drainage or production units; (15) to limit and prorate the production of oil or gas or both from any pool or field for the prevention of waste as defined herein; [and] . . . (17) to prevent, so far as is practical, reasonably avoidable drainage from each developed unit which is not equalized by counterdrainage.311
The Rules and Regulations Governing the Conservation of Oil and Gas in Alabama can be found
in the Alabama Administrative Code.312
[4] – Process for Pooling.
The Alabama Administrative Code provides rules and regulations governing the
permitting of onshore wells,313 submerged offshore wells,314 coalbed methane gas wells,315 and
other injection and storage wells.316 The Administrative Code also includes rules and regulations
governing forced integration or forced pooling.317
Integration or pooling of interests or tracts of land may be appropriate when any mineral
interest deriving from two or more separately owned tracts of land exist within an established or
a proposed drilling or production unit or when there are separately owned interests in all or a part
of an established unit, or both.
318
311 Id. § 9-17-6(c)(1)–(18).
Pooling may be voluntary, such as when owners of interests
agree to pool and develop their land as a unit. Also, under the Board’s authority to prevent waste
312 Ala. Admin. Code r. 400-1-1-.01 (2010). 313 Id. 314 Id. at r. 400-2-1-.01. 315 Id. r. 400-3-1-.01. 316 Id. rr. 400-4-1-.01, 400-5-1-.01, 400-6-1-.01. 317 Id. r. 400-7-1-.01. 318 Ala. Code § 9-17-13(a) (2010).
61
and to avoid drilling unnecessary wells, the Board may require non-consenting owners to pool
their interests and to develop the land as a unit.319
The Board, of its own volition or upon the petition of any interested person, must hold a
hearing to determine the need for the operation as a unit of an entire field or of any pool or pools
or of any portion of a pool or combination thereof within a field for the production of oil or
gas.
320 A petitioner other than the Board must comply with Rule 400-7-1-.11 relating to
notice,321 which requires the petitioner to file a proposed notice for publication along with a
written request for the Supervisor to approve publication of the notice as submitted or with
modifications.322 After the Supervisor approves the notice for publication, the petitioner will
publish at his or her own expense, and must also obtain proof of publication to be filed with the
Board at least three days before the hearing.323 The notice must have been published in the
appropriate newspaper at least ten days before the hearing.324
(a) Petitions for Exceptional Locations; (b) Petitions to Establish Spacing Units; (c) Petitions to Amend or Reform Established Spacing Units; (d) Petitions to Establish or Amend Allowables; (e) Petitions for Forced Pooling; (f) Petitions for Compulsory Unitization; (g) Petitions to Establish or Amend Special Field Rules; and (h) [when notice is otherwise required by the Supervisor].
Additionally, the petitioner must
give notice by first class mail to particular individuals in the following instances:
325
Such notice must be mailed at least fifteen days before the hearing date after a reasonably
diligent effort to find the correct mailing addresses.326
(a) The name of the petitioner;
The notice should include the following:
319 Id. § 9-17-13(a). 320 Id. § 9-17-81. 321 Ala. Admin. Code r. 400-7-1-.05(2) (2010). 322 Id. r. 400-7-1-.11(1). 323 Id. 324 Id. r. 400-7-1-.11(3). 325 Id. r. 400-7-1-.11(4)(a)–(h). 326 Id. r. 400-7-1-.11(4)(i)(1)–(2).
62
(b) A statement of the time, place, and nature of the hearing; (c) A statement of the legal authority and jurisdiction under which
the hearing is to be held; (d) A reference to the particular sections of the statutes and rules
involved; (e) A short and plain statement of the matters asserted; [and] (f) An accurate description of the lands affected by the petition.327
In addition to the notice requirements, the petitioner must pay the filing fee, to be sent to
the State Treasurer of Alabama, in the amount of $150.00.328 Finally, the petitioner’s written
petition for a hearing must be filed with the Board, together with four copies, at least twenty-five
days before the hearing on the petition.329 Five copies of all exhibits used as evidence by
petitioner in the hearing must be submitted at least twenty days before the hearing, although all
other parties only need to submit their five copies at least two work days before the hearing.330
The Rules contain detailed requirements for the information to be contained in the
petition. Broadly, that information includes the name of petitioner, relief sought, property
involved, wells affected, and signature of the attorney or party attesting to the veracity of the
information contained therein.
331
If the Board finds that: (1) unit operation is reasonably necessary; (2) the proposed plan
for unit operations will increase the ultimate recovery of oil or gas by enhanced recovery
methods; or (3) the estimated additional cost incident to conducting such operation will not
exceed the value of the estimated additional recovery of oil and gas, the Board shall issue an
order requiring the unit operation.
332
327 Id. r. 400-7-1-.11(5).
Factors for the Board to consider when deciding whether
an integration or pooling order is reasonably necessary include the prevention of waste, the
328 Id. r. 400-7-1-.11(2). 329 Id. r. 400-7-1-.05(2). 330 Id. r. 400-7-1-.05(3). 331 Id. rr. 400-7-1-.06(1)–(2), 400-7-1-.07. 332 Ala. Code § 9-17-82 (2010).
63
increase in the ultimate recovery of oil or gas, the avoidance of drilling unnecessary wells, the
allowance of drilling wells at optimum geologic locations, and the protection of correlative
rights.333
The Board will take prompt action as it considers appropriate concerning the subject
matter. Then, it will enter a formal written order, executed by the appropriate number of
members and attested by the Secretary.
334
Orders requiring pooling or integration within a drilling unit are different from orders
requiring pool-wide or field-wide unit operations.
335 A drilling unit is “[a]n administrative unit
established by the Board to provide and allow for the drilling of a well. Prior to the
establishment of a field and drainage or production unit within the field, the Board may establish
a drilling unit to allow for the drilling of a well in search of oil and gas.”336
(1) That the actual and reasonable costs of developing and operating the pooled integrated unit (including a reasonable charge for supervision) and, if applicable, a risk compensation fee . . . shall be charged to the separately owned tracts or interests in the unit in the same proportion that such tracts or interests share in production from the unit.
Those orders must
include the following information:
(2) That such costs and fee (if any) chargeable to a tract or interest shall be paid by the person or persons not entitled to share in production free of development and operating costs and who, in the absence of the pooling or integration order, would be responsible for the expense of developing and operating the tract or interest and that person’s or persons’ interest in the separately owned tract or interest shall be primarily responsible therefor. (3) That, if any non-consenting owner shall fail or refuse to pay the costs and/or fee (if any) chargeable to his or her tract or interest, the cost and/or fee shall be recoverable solely out of the production allocable to the tract or interest, provided, however, that this limitation shall not apply to a non-consenting owner who has
333 Id. §§ 9-17-81, 82. 334 Ala. Admin. Code r. 400-7-1-.23 (2010). 335 Ala. Code § 9-17-13(c) (2010). 336 Id. § 9-17-1(4).
64
furnished the operator with a notarized statement agreeing to pay his or her proportionate share of the drilling and completion costs for a unit well as hereinafter provided. (4) That, when the full amount of any charge made against a separately owned tract or interest is not paid when due by the [responsible party], as provided above, then 13/16ths (or if said tract or interest is leased, the working interest fraction or percent if it is greater) of the oil and gas production allocated to the separately owned tract or interest may be appropriated by the operator and marketed and sold for the payment of the charge, but that a 3/16ths part (or the actual landowner royalty if it is less) of the unit production allocated to each separately owned tract or interest shall in all events be regarded as royalty and shall . . . be distributed to and among, or the proceeds thereof paid to, the person or persons owning royalty or unleased mineral interests . . . free and clear of the development and operating costs and of any risk compensation fee and free and clear of any lien for the payment of the costs and fee. (5) That any person owning any overriding royalty, oil and gas payment, royalty in excess of 3/16ths of production, or other interests, who is not primarily responsible for payment of the development and operating costs or risk compensation fee (if any), shall, to the extent of any payment or deduction therefor from his or her share, be subrogated to all the rights of the operator with respect to the interest or interests primarily responsible for the payment. . . .337
The orders must also contain provision regarding payment by non-consenting owners, allowing
them to agree to pay their share or not based on their signing a notarized statement.338
Unless the order specifies otherwise or the parties otherwise agree, production from any
unit formed by an order will be allocated to each separately-owned tract or interest in the
proportion that the acreage of each tract or unit bears to the total unit acreage. Allocation thus
determined is considered the just and reasonable allocation to give each owner his or her just and
equitable share of production. Also, no order will subject a non-consenting owner who is subject
to a risk compensation fee to personable liability for damages stemming from any related
negligence or tort.339
Orders requiring unit operation for field-wide and pool-wide units are governed by
Section 9-17-83. They must be fair and reasonable under all circumstances, must protect the
rights of interested parties, and must include the following:
(1) A description of the area embraced, termed the unit area, and a description of the pool or pools or portions thereof affected and lying within the unit area, termed the unit pool; (2) A statement of the nature of the operations contemplated; (3) An allocation among the separately owned interested . . . of all the oil or gas, or both, produced from the unit pool within the unit area, and not required in the conduct of such operations or unavoidably lost, such allocation to be based on the relative contribution which each such tract or interest is expected to make during the course of such operation, to the total production of oil or gas, or both, so allocated; (4) A provision for adjustment among the owners of the unit area . . . of their respective investment in wells, . . . equipment, . . . and services of value attributable to the unit operations. . . . The adjustments provided for in this subdivision may be treated separately and handled by agreements separate from the unitization agreement; (5) A provision that the costs and expenses of unit operation, including investment, past and prospective be charged to the separately owned tracts or interests in the same proportions that such tracts or interests share in unit production, as provided in subdivision (3) of this section. . . . .; (6) The designation of, or a provision for the selection of, a unit operator. . . .; (7) A provision that when [a responsible party does not pay its costs and expenses that the owner may appropriate 7/8ths of its oil and gas production allocation to such payment, while the remaining 1/8th is considered to be royalty to be paid to the royalty owners free and clear of unit expenses]; and (8) The time the unit operation shall become effective and the manner in which and the circumstances under which the unit operation will terminate.340
339 Id.
340 Id. § 9-17-83.
66
Orders requiring unit operations become effective only after the above provisions are
signed or ratified in writing by the owners of not less than 66 2/3 percent in interest as costs are
shared and revenue is distributed pursuant to Section 9-17-83(3). If the appropriate percentage
of interest-holders has not ratified an agreement within six months of the order date, the order
will be revoked automatically.341
Additionally, the Board may amend orders to add to unit operations pools or portions
thereof not included and may extend the unit area as required. In such a case, the Board will
reallocate production to include the correct proportion of the new area.
342 Such orders do not
become operative until the requisite 66 2/3 percent of the new ownership interest has ratified the
extension, with a six-month deadline for doing so.343 Costs and expenses will be governed as
provided in Section 9-17-83(5).344
[5] – Matters Covered.
[a] Number of Wells.
The Board has the authority to establish drainage or production units, the maximum area
that may be efficiently and economically drained by one well. The Board may later alter the
number of wells to be drilled and produced within a particular drainage or production unit in the
field after a party has demonstrated the necessity of the amendment based on geologic and
The Board has the authority to establish spacing requirements as part of special field rules
governing each established field.346 A field is “the general area in a pool which may be drained
efficiently and economically by one well.”347 Once the Board has established a field, it will
establish special field rules for that field. Those rules establish drainage or production units, also
called production units, for the specific field. A production unit is “the area in a pool that may
be drained efficiently and economically by one well.”348 Before a field is established and the
drainage or production units within the field are established, an operator may drill a well on a
drilling unit. A drilling unit is “an administrative unit established by the Board to provide and
allow for the drilling of a well.”349
For wells drilled that are not governed by field rules, likely because the field had not yet
been established and so the well was drilled on a drilling unit instead, the Board has set default
spacing provisions.
350 Those provisions have allowable exceptions and maximum limits. 351
After the field is established, the special field rules will apply to govern spacing.352
[c] Authority to Integrate Production.
In the event the owners have not agreed to integrate or pool, and as a means to prevent
waste and the drilling of unnecessary wells, the Board may require the owners to integrate or
pool so to develop their interests as a drilling or production unit.353
[d] Allocation of Production and Costs.
The Alabama Code requires that allocation of production and costs be provided for in
each pooling or unitization order. For unitization of interests within a drilling unit, the Board 346 Ala. Admin. Code r. 400-1-2-.02(1) (2010). 347 Ala. Code § 9-17-1(5) (2010). 348 Ala. Admin. Code r. 400-1-2-.02(1)–(2) (2010). 349 Id. r. 400-1-2-.02(1). 350 Id. r. 400-1-2-.02(2). 351 Ala. Code § 9-17-12(b) (2010). 352 Ala. Admin. Code r. 400-1-2-.02(1) (2010). 353 Ala. Code § 9-17-13(a) (2010).
68
should refer to the guidelines in section 9-17-13(c), which states that actual and reasonable costs
and a risk compensation fee is charged to the separately owned tracts or interests in the unit in
the same proportion that such tracts or interests share in production.354 Each tract’s share of
production is such that it would afford to each interest-owner his or her just and equitable
share,355 equal to the amount recoverable in the developed area of the tract or interest in the tract
that bears to the amount recoverable in the total developed area of the pool. 356 When
determining the allocation for field-wide or pool-wide units, the Board should refer to the
guidelines in § 9-17-83 in promulgating its order, which requires that the order provide a plan of
allocation based on the relative contribution that those tracts or interests expect to make during
the course of the operations to the total production of oil or gas.357 Costs are to be allocated in
the same proportion as production.358
[e] Royalty Distribution.
The Code provides for two different levels of royalty payment.359 As for unitization of
interests within a drilling unit, governed by Section 9-17-13(c)(4), unless the actual landowner
royalty is less, 3/16ths of the unit production allocated to each separately owned tract or interest
will in all events be regarded as royalty.360 As for pool-wide or field-wide units, governed by
Section 9-17-83(4), one-eight of the unit production allocated to each separately owned tract or
interest will in all events be regarded as royalty.361
[f] Agreements Not Restraint of Trade.
Those amounts will be distributed to and
among, or the proceeds thereof paid to, the person or persons owning the respective royalties.
The Rules and Regulations Governing the Conservation of Oil and Gas in Alabama
provide some new and altered definitions. In the “Rules and Regulations of the State Oil and
Gas Board of Alabama Governing Onshore Land Operations,” which govern onshore land
operations but do not apply to coalbed methane gas operations,369 a different definition of gas is
given: “all natural gas, including casinghead gas and occluded natural gas found in coalbeds,
and all other liquid or gaseous hydrocarbons not defined as oil.”370
The “Rules and Regulations of the State Oil and Gas Board of Alabama Governing
Coalbed Methane Gas Operations,”
371 which govern coalbed methane gas operations, contain the
same definition of gas as in the onshore rules, but define additional terms. The Coalbed Methane
rules define coalbed methane gas as “occluded natural gas found in coalbeds” 372 ; coalbed
methane gas field as “the area defined by the operator and approved by the Board which is
underlain or appears to be underlain by at least one coalbed, capable of producing occluded
natural gas”373; and coalbed methane gas well as “a well capable of producing occluded natural
gas from a coalbed or coalbeds.”374
[2] – Split by Depth.
Both the Onshore Land Operation and the Coalbed Methane
Gas Operation rules and regulations state that the Rules and Regulations of the State Oil and Gas
Board of Alabama Governing Practice and Procedure and Forced Integration or Forced Pooling
apply in addition to the rules set forth within their sections.
Alabama law does not appear to distinguish based on drilling depth.
[3] – Spacing Rules and Size.
369 Ala. Admin. Code r. 400-1-1-.01 (2010). 370 Id. r. 400-1-1-.05(30). 371 Id. r. 400-3-1-.01. 372 Id. r. 400-3-1-.05(12). 373 Id. r. 400-3-1-.05(13). 374 Id. r. 400-3-1-.05(14).
71
The Board has the authority to establish special field rules for each pool that set forth,
among other things, the drainage or production units for the field and production allowables for
each drainage or production unit. A drainage or production unit, also referred to as a “production
unit,” is “the maximum area which may be efficiently and economically drained by one well.”375
For those wells drilled that will not be governed by special field rules, pre-determined
spacing provisions are applicable.
376 The Onshore Lands Operations rules and regulations
provide spacing rules,377 as do the Coalbed Methane Gas Operations rules and regulations.378 As
governing onshore land operations, the default regulations require wells to be drilled on drilling
units that consist of a governmental quarter-quarter section, or about 40 acres and at least 330
feet from every exterior boundary of the drilling unit. 379 Also, a well may be drilled on a
governmental quarter section, or 160 acres. However, the larger unit may call for written
justification to be submitted to the Supervisor, and wells drilled thereon should be at least 660
feet from every exterior boundary of the unit.380
The onshore land operations rules also contain specific spacing provisions depending on
the county in which drilling occurs. If drilling is in Fayette, Lamar, Pickens, and Tuscaloosa
Counties, gas wells should be drilled on a drilling unit that consists of 320 acres, a governmental
half section, and located at least 660 feet from every exterior boundary of the unit. Operators
should designate an alternate forty-acre unit, with the well 330 feet from the exterior boundaries,
to revert to if the well is completed as an oil well.
381
375 Ala. Code § 9-17-12(b) (2010).
If the gas well is drilled in Baldwin,
Escambia, Mobile, and Washington Counties, the drilling units should be approximately 640
376 Ala. Admin. Code r. 400-1-2-.02(2) (2010). 377 Id. r. 400-1-2-.02. 378 Id. r. 400-3-2-.02. 379 Id. r. 400-1-2-.02(2)(a). 380 Id. r. 400-1-2-.03(2)(b). 381 Id. r. 400-1-2-.03(2)(c).
72
acres, a governmental section, and wells should be located at least 1,320 feet from every exterior
boundary of the unit. The operators should designate an alternate one hundred sixty-acre drilling
unit in case the well is completed as an oil well, and the well should be at least 660 feet from all
exterior boundaries of that alternate drilling unit.382
The Supervisor may, after receiving written justification from the operator, allow
permitting for a well on a drilling unit that is about approximately 40, 160, 320, or 640
contiguous surface acres other than a governmental section.
383 The Supervisor may require a
well to be drilled on a drilling unit contiguous with an existing field as an extension of that field
and following the spacing provisions provided for by that field’s special field rules. However, an
operator can give written justification that the pool in which the current well is to be completed
is in a pool outside the already-established field, in which case the Supervisor may allow the
operator to follow the default spacing rules in the regulations.384
As provided for in Section 9-17-12(c) of the Code, the Board may allow exceptions if
reasonably necessary where, after notice and hearing, it can be shown that the spacing unit is
partly outside of the pool. Also, if it can be shown that a well located in accordance with the
applicable rules would be unproductive, would not be at the best placement in the unit for the
most efficient and economic drainage of the unit, or where physical conditions make the drilling
as authorized unduly burdensome.
385 No well may be drilled within 200 feet of any permanent
residence, unless the Board provides otherwise.386
As for established fields, parties may prove to the Board, after notice and hearing, using
substantial evidence based on geologic and engineering evidence and production information
382 Id. r. 400-1-2-.03(2)(d). 383 Id. r. 400-1-2-.03(2)(e). 384 Id. r. 400-1-2-.03(2)(f). 385 Id. r. 400-1-2-.03(g). 386 Id. r. 400-1-2-.03(h).
73
that comes from wells in an established field, that one well will not efficiently and economically
drain the entire production unit provided for in the special field rules. In that case, the Board
may amend the rules to allow more than one well to be drilled and produced within that area.
Under no circumstances, however, may the Board establish a spacing unit in a shale natural gas
reservoir larger than 320 acres for a vertical well and 640 acres for a horizontal well. As for
coalbed methane reservoirs, a person may show that one well will not efficiently and
economically drain the entire drainage area, an established field providing for an eighty-acre
drainage and production unit, without a second well. In determining if a second well is needed,
the Board should consider factors including whether the second well: (1) will significantly
increase production from the unit; (2) will extend the duration of production from the unit; and
(3) is an unnecessary well.
The Board does have limits on the size of production units. It does not have the authority
to establish a production unit larger than 160 acres or one governmental quarter section plus 10
percent tolerance for any pool that is determined to be an oil reservoir or larger than 640 acres or
one governmental section plus 10 percent tolerance for any pool determined to be a gas reservoir.
The ten percent tolerance is given to allow for irregularities. However, the Board may establish
production units in excess of the limits when it is affirmatively demonstrated that the larger unit
is justified because of technical, economic, environmental or safety considerations, or other
reasons deemed valid by the Board, after notice and hearing. The Board may, after notice and
hearing, make production units for oil and gas pools not to exceed 50 percent larger than the
above limitations, provided that the action is justified by sufficient technical evidence, indicating
that the acreage or land in excess of the above limits is being drained or is in danger of being
74
drained and that the owners of those excess acreage cannot otherwise receive their just and
equitable share of production from the pool being so drained.387
Finally, if owners voluntarily pool, the law provides that the owners can agree to the
establishment of production units containing as much or more acreage than the Board provided
or has the authority to provide for the same pool. Such unit may not be in excess of the same
limits given to the board, and up to 50 percent greater, as provided in the preceding paragraph.
However, the production unit so created will be valid and binding even if it encompasses more
acreage than the Board included or is authorized to include in a unit for the same pool, subject to
Board approval.
388
[4] – Minimum Operator Control.
Unit operation orders become effective only after the unitization plan prescribed by the
Board is signed or ratified in writing by the owners of not less than 66 2/3 percent in interest as
costs are shared and revenue is distributed pursuant to Section 9-17-83(3). If the appropriate
percentage of interest-holders has not ratified an agreement within six months of the order date,
the order will be revoked automatically.389
Additionally, the Board may amend unitization orders to add to unit operations pools or
portions thereof not included and may extend the unit area as required. In such a case, the Board
will reallocate production to include the correct proportion of the new area.
390 Such orders do
not become operative until the requisite 66 2/3 percent of the new ownership interest has ratified
the extension, with a six-month deadline for doing so.391
All wells must maintain a vertical wellbore unless the operator obtains a permit allowing
otherwise.392 The permit must provide that the bottom of the wellbore remains in compliance
with spacing provisions. Permits must be obtained even if the purpose of deviation is to drill
around an obstruction.393
[6] – Options.
The Statute does not appear to require the operator to extend an option to participate.
However, Section 9-17-13(c)(5) seems to incentivize such offers. That section states that if the
operator, or the operator together with the consenting owners, own a majority in interest of the
unit and the operator has made a good faith effort to negotiate with each non-consenting owner
to have that owner’s interest voluntarily integrated or pooled into the unit, among other things,
including “to offer each non-consenting owner the opportunity to lease or farm out on
reasonable terms or participate in the cost and risk of developing and operating the unit well
involved on reasonable terms,” then the pooling or integration order will, if the operator
requests, also provide that if the non-consenting owner does not pay his or her proportionate
costs within a certain period, or does not agree to do so, then there will be charged to that owner
150 percent of the tract’s or interest’s share of the actual and reasonable costs of drilling,
reworking, testing, plugging back, deepening, and completing that well.394
392 Ala. Admin. Code r. 400-1-2-.01(4)(a) (2010).
393 Id. r. 400-1-2-.01(4)(d). 394 Ala. Code § 9-17-13(c)(5) (2010).
76
§ 03.01 Analysis of Alaska Regulatory Framework.
[1] – Name of the Governing Body. In Alaska, the agency with oversight of pooling is the Alaska Oil and Gas Conservation
Commission (“Commission”).395
[2] – Membership on the Board.
The Commission is composed of three Commissioners appointed by the governor and
confirmed by the legislature in joint session.396 In making appointments to the Commission, the
governor shall consider and give preference to a person who demonstrates experience in oil and
gas operations in the state.397 The governor shall designate one member of the Commission as
chair of the Commission. This member shall serve as chair for a term of four years but may not
be appointed for successive terms as chair of the Commission.398 The term of office of each
member is six years. A Commissioner, upon the expiration of a term, shall continue to hold
office until a successor is appointed and qualified.399
(1) one member shall be a petroleum engineer who:
Members shall be qualified as follows:
(A) holds a certificate of registration as an engineer under AS 08.48 and, under regulations adopted to implement that chapter, has qualified as a petroleum engineer; or (B) has earned a degree from a university in the field of engineering and has at least 10 years of professional subsurface experience in the oil and gas industry in drilling, well operations, production process operations, reservoir engineering, or a combination thereof; for the purposes of this subparagraph, a person meets the requirement of earning a degree in the field of engineering if the person obtains an undergraduate or graduate degree in engineering that meets the requirements for program accreditation by the Engineering Accreditation Commission of the Accreditation Board for Engineering and Technology and
the person completes university or industry training specific to petroleum engineering that illustrates application of engineering principles to the problems encountered and methods used in the petroleum industry, including drilling, production, reservoir engineering, fluid flow through subsurface formations, and hydrocarbon transportation;
(2) one member shall be a geologist who: (A) holds a certification as a professional geologist under
AS 08.02.011 and has professional experience in the field of petroleum geology; or
(B) has earned a degree in the field of geology from a university accredited in the field of geology and has a minimum of 10 years professional experience in the field of petroleum geology; and (3) one member who shall have training or experience that gives the person a fundamental understanding of the oil and gas industry in the state.400
Two members of the Commission constitute a quorum for the transaction of business, for the
performance of a duty, or for the exercise of a power of the Commission.401
[3] – Scope of Authority.
The Commission has jurisdiction and authority over all persons and property, public and
private, necessary to carry out the purposes and intent of Alaska’s Oil and Gas Conservation
Act. 402 The Commission shall investigate to determine whether or not waste exists or is
imminent, or whether or not other facts exist which justify or require action by it,403 and shall
adopt regulations and orders and take other appropriate action to carry out the purposes of the
Act.404
(1) identification of ownership of wells, producing leases, tanks, plants, and drilling structures;
The Commission may require the following:
(2) the making and filing of reports, well logs, drilling logs, electric logs, lithologic logs, directional surveys, and all other subsurface
information on a well for which a permit to drill has been issued by the Commission, subject to the following:
(A) the reports required to be filed by the Commission under this paragraph shall be filed within 30 days after the completion, abandonment, or suspension of the well; and (B) the well logs, drilling logs, electric logs, lithologic logs, directional surveys, and all other information required to be filed by the Commission under this paragraph shall be filed within 90 days after the completion, abandonment, or suspension of the well, unless extended by the Commission on request;
(3) the drilling, casing, and plugging of wells in a manner that will prevent the escape of oil or gas out of one stratum into another, the intrusion of water into an oil or gas stratum, the pollution of fresh water supplies by oil, gas, or salt water, and prevent blowouts, cavings, seepages, and fires; (4) the furnishing of a reasonable bond with sufficient surety conditioned for the performance of the duty to plug each dry or abandoned well or the repair of wells causing waste; (5) the operation of wells with efficient gas-oil and water-oil ratios, and may fix these ratios; (6) the gauging or other measuring of oil and gas to determine the quality and quantity of oil and gas; (7) every person who produces oil or gas in the state to keep and maintain for a period of five years in the state complete and accurate records of the quantities of oil and gas produced, which shall be available for examination by the Commission at all reasonable times; (8) the measuring and monitoring of oil and gas pool pressures; (9) the filing and approval of a plan of development and operation for a field or pool to prevent waste, ensure a greater ultimate recovery of oil and gas, and protect the correlative rights of persons owning interests in the tracts of land affected.405
The Commission may regulate, for conservation purposes and, to the extent not in conflict with
regulation by the Department of Labor and Workforce Development or the Department of
Environmental Conservation, for public health and safety purposes,
(A) the drilling, producing, and plugging of wells; (B) the perforating, fracture stimulation, and chemical treatment
of wells; (C) the spacing of wells; (D) the disposal of salt water, nonpotable water, and oil field wastes;
405 Id. § 31.05.030(d).
79
(E) the contamination or waste of underground water; (F) the quantity and rate of the production of oil and gas from a
well or property; (G) the underground injection of gas for purposes of storage.406
The Commission may also regulate the disposal of drilling mud, cuttings, and
nonhazardous drilling operation wastes in the annular space of a well for which a permit to drill
has been issued by the Commission. As used here, a "nonhazardous drilling operation waste"
means a waste, other than a hazardous waste identified by the Environmental Protection Agency
in Title 40 of the Code of Federal Regulations, part 261, the regulation that identifies and lists
hazardous wastes associated with the act of drilling a well for exploratory or production
purposes.407
For exploration and development operations involving nonconventional gas, the
Commission may not issue a permit to drill if the well would be used to produce gas from an
aquifer that serves as a source of water for human consumption or agricultural purposes unless
the Commission determines that the well will not adversely affect the aquifer as a source of
water for human consumption or agricultural purposes or allow injection of produced water
except at depths below known sources of water for human consumption or agricultural
purposes.408 For exploration and development operations involving nonconventional gas, the
Commission is charged to regulate hydraulic fracturing to ensure protection of drinking water
quality and regulate the disposal of wastes produced from the operations unless the disposal is
otherwise subject to regulation by the Department of Environmental Conservation or the United
States Environmental Protection Agency.409
406 Id. § 31.05.030(e)(1).
As a condition of approval of a permit to drill a
well for regular production of coal bed methane, the Commission shall require the operator to
whether the proposed well is contrary to Alaska oil and gas laws or regulations, or any order,
stipulation, or term of a permit issued by the Commission, whether the applicant is in violation of
any Alaska oil and gas law or regulation or any order, stipulation, or term of a permit issued by
the Commission and the magnitude of such violation.419
The Commission may act upon its own motion, or upon the petition of an interested
person.
420 On the filing of a petition concerning a matter within the jurisdiction of the
Commission, the Commission shall promptly fix a date for a hearing and shall cause notice of
the hearing to be given.421 The hearing shall be held without undue delay after the filing of the
petition.422 The Commission shall enter its order within 30 days after the hearing.423
For an action that involves the exploration for or development of nonconventional gas
and that has application to a single well or a single field, upon the request of a lessee or operator,
the Commission may, where operations might be unduly delayed, approve a variance from the
Commission's regulations that apply to the well or field without providing notice and opportunity
to be heard.
424
(1) the approval provides at least an equally effective means of accomplishing the requirement set out in the Commission's regulation or the Commission determines that the request is more appropriate to the proposed operation than compliance with the requirement of the regulation; and
In the exercise of its authority to issue the variance, the Commission may
approve the variance if:
(2) the terms of the approval of the variance may include exempting the lessee or operator from a requirement of a regulation if the Commission determines that the requirement is not necessary or not suited to the well or field, taking into consideration the nature of the operation involved, the
characteristics of the well or field for which the variance is sought, and the reasonably anticipated risks of the exemption from the requirement to human safety and the environment.425
[a] Establishment of Drilling Units.
The Commission has authority to establish a drilling unit or units for each pool in order to
prevent waste, to protect and enforce the correlative rights of lessees in a pool, and to avoid the
augmenting and accumulation of risks arising from the drilling of an excessive number of wells
or the reduced recovery which might result from too small a number of wells. The establishment
of a unit for gas shall be limited to the production of gas.426
Each permitted well on a drilling unit shall be drilled under the rules and regulations and
in accordance with the spacing pattern as the Commission prescribes for the pool in which the
well is located.427 Exceptions to the rules and spacing pattern may be granted where it is shown,
after notice and hearing, that the unit is partly outside the pool, or for some other reason a well so
located on the unit would be nonproductive, or where topographical conditions make drilling at
such a location unduly burdensome.428 If an exception is granted, the Commission must offset
any advantage the person securing the exception may have over other producers by drilling the
well as an exception and so that drainage from developed units to the tract with respect to which
the exception is granted will be prevented or minimized, and the producer of the well drilled as
an exception will be allowed to produce no more than a just and equitable share of the oil and
gas in the pool.429
When two or more separately owned tracts of land are embraced within an established
drilling unit, persons owning the drilling rights in it and the right to share in the production from
allowable production for the full drilling unit as the area of the separately owned tract bears to
the full drilling unit.443
[b] Unitization and Integration by Agreement.
To prevent waste, to ensure a greater ultimate recovery of oil and gas, and to protect their
correlative rights, persons owning interests in tracts of land may validly integrate their interests
to provide for the unitized management, development, and operation of those tracts as a unit.444
Such voluntary integration agreements must be filed with the Commission not later than 30 days
after the agreement’s execution.445 Prior to beginning production from the oil or gas pool, the
operator must submit to the Commission a plan of development and operation for the pool where
conduct is contemplated, which plan must provide for waste prevention, correlative rights
protection, and greater recovery of oil and gas.446
Where parties have not agreed to integrate their interests, the Commission, upon proper
petition, after notice and hearing, has jurisdiction, power, and authority, and it is its duty, to
make and enforce orders and to do the things necessary or proper to carry out the purposes of
Alaska’s Oil and Gas Conservation Act.
447
(1) the unitized management, operation and further development of a pool or portion of a pool is reasonably necessary in order to effectively carry on pressure control, pressure-maintenance or repressuring operations, cycling operations, water flooding operations, or any combination of these, or any other form of joint effort calculated to substantially increase the ultimate recovery of oil and gas from the pool;
Upon the filing of a petition by or with the
Commission, and after notice and hearing, the Commission will issue an order creating the unit
and providing for the unitized operation of the pool if it finds that:
(2) one or more of the unitized methods of operation as applied to the pool or portion of it is feasible, and will prevent waste and will with reasonable probability result in the increased recovery of substantially more oil and gas from the pool than would otherwise be recovered; (3) the estimated additional cost, if any, of conducting such operations will not exceed the value of the additional oil and gas so recovered; and (4) the unitization and adoption of one or more of the unitized methods of operation is for the common good.448
The petition shall set out a description of the proposed unit area with a map or plat of it attached,
shall allege the existence of the facts required to be found by the Commission and shall have
attached to it a recommended plan of unitization applicable to the proposed unit area and which
the petitioner considers to be fair, reasonable and equitable.449
The order of the Commission shall define the boundary of the area to be included within
the unit area and prescribe with reasonable detail the plan of unitization applicable to it.
450 Each
unit and unit area may be limited to all or a portion of a single pool.451 Only so much of a pool
or pools as has been defined and determined to be productive on the basis of information
available to the Commission may be so included within the unit area.452 A unit may be created
to embrace less than the whole of a pool only where it is shown by the evidence that the area to
be so included within the unit area is of a size and shape as may be reasonably required for the
successful and efficient conduct of the unitized method of operation for which the unit is created,
and that the conduct of it will have no material adverse effect upon the remainder of the pool.453
448 Id. § 31.05.110(b).
The plan of unitization for each unit and unit area shall be suited to the needs and requirements
of the particular unit dependent upon the facts and conditions found to exist with respect to it.454
(1) the efficient unitized management or control of the further development and operation of the unit area for the recovery of oil and gas from the pool affected;
Each plan of unitization shall contain fair, reasonable, and equitable provisions for:
(2) the division of interest or formula for the apportionment and allocation of the unit production, among and to the several separately owned tracts within the unit area such as will reasonably permit persons otherwise entitled to share in or benefit by the production from such separately owned tracts to produce and receive, instead thereof, their fair, equitable and reasonable share of the unit production or other benefits of it; (3) the manner in which the unit and the further development and operation of the unit area shall or may be financed and the basis, terms and conditions on which the cost and expense of it shall be apportioned among and assessed against the tracts and interests made chargeable with it, including a detailed accounting procedure governing all charges and credits incident to such operations; (4) the procedure and basis upon which wells, equipment and other properties of the several lessees within the unit area are to be taken over and used for unit operations, including the method of arriving at the compensation for it, or of otherwise proportionately equalizing or adjusting the investment of the several lessees in the project as of the effective date of unit operation; (5) the creation of an operating committee to have general overall management and control of the unit and the conduct of its business and affairs and the operations carried on by it, together with the creation or designation of other subcommittees, boards or officers to function under the authority of the operating committee as may be necessary, proper or convenient in the efficient management of the unit, defining the powers and duties of all the committees, boards and officers, and prescribing their tenure and time and method for their selection; (6) the time when the plan of unitization becomes effective; (7) the time when and the conditions under which and the method by which the unit shall or may be dissolved and its affairs wound up.455
§ 03.02 Types of Alaska Pooling Statutes.
[1] – Mineral Distinctions.
454 Id. 455 Id.
88
"Gas" includes “all natural gas and all hydrocarbons produced at the wellhead not defined
as oil.”456 “Oil" includes “crude petroleum oil and other hydrocarbons regardless of gravity
which are produced at the wellhead in liquid form and the liquid hydrocarbons known as
distillate or condensate recovered or extracted from gas, other than gas produced in association
with oil and commonly known as casinghead gas.”457
[2] – Split by Depth.
The Alaska Oil and Gas Conservation
Law does not provide a definition for coal bed methane gas.
Alaska law does not differentiate spacing or pooling regulation based on the actual
proposed well depth.
[3] – Size and Spacing Rules.
The Commission will, in its discretion, establish drilling units to govern well spacing and
prescribe a spacing pattern by pool rules adopted in accordance with title 20 of Alaska
Administrative Code section 25.520. In the absence of an order by the Commission establishing
drilling units or prescribing a spacing pattern for a pool, the following statewide spacing
requirements apply:
(1) for a well drilling for oil, a wellbore may be open to test or regular production within 500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line; (2) for a well drilling for gas, a wellbore may be open to test or regular production within 1,500 feet of a property line only if the owner is the same and the landowner is the same on both sides of the line; (3) if oil has been discovered, the drilling unit for the pool is a governmental quarter section; not more than one well may be drilled to and completed in that pool on any governmental quarter section; a well may not be drilled or completed closer than 1,000 feet to any well drilling to or capable of producing from the same pool;
456 Id. § 31.05.170(6). 457 Id. § 31.05.170(9).
89
(4) if gas has been discovered, the drilling unit for the pool is a governmental section; not more than one well may be drilled to and completed in that pool on any governmental section; a well may not be drilled or completed closer than 3,000 feet to any well drilling to or capable of producing from the same pool.458
A well may not begin regular production of oil from a property that is smaller than the
governmental quarter section upon which the well is located or begin regular production of gas
from a property that is smaller than the governmental section upon which the well is located,
unless the interests of the persons owning the drilling rights in and the right to share in the
production from the quarter section or section, respectively, have been pooled. A pooling
agreement must be filed with the Commission before regular production from the affected
property begins.459
The Commission will review an application for an exception to the provisions of this
section in accordance with title 20 of Alaska Administrative Code section 25.540. The applicant
for an exception shall send notice of the application by certified mail to the owners, landowners,
and operators described above and shall furnish the Commission with a copy of the notice, the
date of mailing, and the addresses to which the notice was sent. The application must include:
(1) the names of all owners, landowners, and operators of all properties within 1,000 feet of a well drilling for oil or within 3,000 feet of a well drilling for gas for which an exception is sought; (2) a plat drawn to a scale of one inch equaling 2,640 feet or larger, showing the location of the well for which the exception is sought, all other completed and drilling wells on the property, and all adjoining properties and wells; and (3) an affidavit by a person acquainted with the facts, verifying that all facts are true and that the plat correctly portrays pertinent and required data.460
Each plan of unitization must include a fair provision for carrying or otherwise financing
lessees unable to meet the upfront financial burden of drilling.465
465 Alaska Stat. § 31.05.110(c)(3) (2010).
Alaska law does not provide
statutory standards to dictate options and similar carrying arrangements.
92
§ 04.01 Analysis of Arizona Regulatory Framework.
[1] – Name of Governing Body.
Oil and gas production in Arizona is governed by the state’s Oil and Gas Conservation
Commission (“Commission”).466
[2] – Membership on the Governing Body.
The Commission consists of the State Land Commissioner ex officio, who has no vote,
and five members to be appointed by the governor, no more than three of whom may be of the
same political party. The appointed members must be United States citizens and shall have been
residents of Arizona for not less than the five years immediately preceding their appointment.
Three members of the Commission constitute a quorum for the transaction of business.467 The
Arizona Geological Survey shall provide staff support to the Commission as needed.468
[3] – Scope of Authority.
The Commission administers and enforces the provisions of Arizona law relating to the
conservation of oil and gas.469 The Commission and administrative staff may, at any time, enter
upon property and inspect wells drilled for oil or gas and well records and shall control property,
machinery, and appliances necessary to gauge the wells. 470
(1) Administer oaths to a witness in any hearing, investigation or proceeding held under Arizona law relating to conservation of oil and gas.
The Commission may do the
following:
(2) Issue subpoenas requiring attendance and testimony of witnesses and production of books, papers, and records deemed material or necessary, and direct service of subpoenas by a sheriff or other officer authorized by law to serve process.
(3) Prescribe rules and do all acts necessary or advisable to carry out its duties. (4) Collect fees to cover the costs of services including, but not limited to, reproduction of records and copies of rules. (5) Publish technical maps, cross sections, and reports and sell these materials for a fee to cover the costs incurred in their preparation, reproduction and distribution.471
The Commission must make inquiries deemed proper to determine whether waste exists or is
imminent. In the exercise of such power the Commission may:
(1) collect data; (2) make investigations and inspections; (3) examine property, leases, papers, books, and records, including drilling records and logs; (4) examine, check, test, and gauge oil and gas wells, tanks, refineries, and modes of transportation; (5) hold hearings; (6) require keeping of records and making of reports; (7) take action necessary to enforce and effectuate the provisions of Arizona oil and gas conservation laws.472
The Commission may, in order to prevent waste and avoid drilling unnecessary wells,
permit the cycling of gas in any pool or portion thereof or the introduction of gas or other
substance into an oil or gas reservoir for the purpose of re-pressuring the reservoir, maintaining
pressure, or carrying on secondary recovery operations of any type. The Commission will permit
the pooling or integration of separate tracts when reasonably necessary in connection with the
operations.473
[4] – Process for Pooling and Matters Covered.
In order to prevent waste, to protect and enforce the correlative rights of owners in a pool,
and to avoid augmentation and accumulation of risks arising from drilling an excessive number
of wells, or reduced recovery which might result from too small a number of wells, the
(1) The unitized management, operation, and further development of a pool or portion thereof is reasonably necessary in order to effectively carry on pressure control, pressure-maintenance or repressuring operations, cycling operations, water flooding operations, or any combination thereof, or any other form of joint effort calculated to substantially increase the ultimate recovery of oil and gas from the pool; and
Where there is no voluntary agreement to unitize interests, the Commission,
upon proper petition, after notice and hearing may make an order providing for the unitized
operation of a pool or part thereof if it finds that:
(2) One or more of the unitized methods of operation as applied to such pool or portion thereof are feasible, will prevent waste and will, with reasonable probability, result in the increased recovery of substantially more oil and gas from the pool than would otherwise be recovered; and (3) The estimated additional cost, if any, of conducting such operations will not exceed the value of the additional oil and gas so recovered.496
The order of the Commission shall define the area of the pool or portion thereof to be
included within the unit area and prescribe with reasonable detail the plan of unitization
applicable thereto.497 Each unit and unit area shall be limited to all or a portion of a single
pool.498 Only so much of a pool as has been defined and determined to be productive of oil and
gas by actual drilling operations may be included within the unit area.499 A unit may be created
which contains less than the whole of a pool only if it is shown by the evidence that the area to
be included within the unit area is of a size and shape that is reasonably required for the
successful and efficient conduct of the unitized method of operation will have no material
adverse effect upon the remaining portions of the pool.500
and unit area must be one suited to the needs and requirements of the particular unit dependent
upon the facts and conditions found to exist.501
(1) The efficient unitized management or control of the further development and operation of the unit area for the recovery of oil and gas from the pool affected. Under such a plan the actual operations within the unit area may be carried on in whole or in part by the unit itself, or by one or more of the lessees within the unit area as the unit operator subject to the supervision and direction of the unit, dependent upon what is most beneficial or expedient. The designation of the unit operator shall be by vote of the lessees in the unit in a manner provided in the plan of unitization and not by the Commission.
In addition to the terms, provisions, conditions
and requirements found by the Commission to be reasonably necessary or proper, each plan of
unitization shall contain fair, reasonable and equitable provisions for the following:
(2) The division of interest or formula for the apportionment and allocation of the unit production, among and to the several separately owned tracts within the unit area as will reasonably permit persons otherwise entitled to share in or benefit by the production from the separately owned tracts to produce and receive, in lieu thereof, their fair, equitable, and reasonable share of the unit production or other benefits. (3) The manner in which the unit and the further development and operation of the unit area will be financed and the basis, terms, and conditions on which costs and expenses will be apportioned among the tracts, including a detailed accounting procedure governing all charges and credits incident to those operations. (4) The procedure and basis upon which wells, equipment, and other properties of the lessees within the unit area are to be taken over and used for unit operations, including the method of arriving at compensation or of otherwise proportionately equalizing or adjusting the investment of the several lessees in the project as of the effective date of unit operation. (5) The supervision and conduct of the unit operations, in respect to which each person shall have a vote with a value corresponding to the percentage of the costs of unit operations chargeable against the interest of such person. (6) The time when the plan of unitization becomes effective. (7) The time when, the conditions under which, and the method by which the unit shall or may be dissolved and its affairs wound up.502
501 Id.
502 Id.
99
An order providing for unit operations may be amended by an order made by the
Commission, in the same manner and subject to the same conditions as an original order
providing for unit operations. Provided that,
(1) if an amendment affects only the rights and interests of the owners, the approval of the amendment by the royalty owners shall not be required; and (2) no order of amendment shall change the percentage for allocation of oil and gas as established for any separately owned tract by the original order, except with the consent of all persons owning interests in that tract.503
The Commission, by an order, may provide for the unit operation of a pool or a part
thereof that embraces a unit area established by a previous order of the Commission.504 Such an
order, in providing for the allocation of unit production, shall first treat the unit area previously
established as a single tract, and the portion of the unit production allocated to it shall then be
allocated among the separately owned tracts included in the previously established unit area in
the same proportions as those specified in the previous order.505
§ 04.02 Types of Arizona Pooling Statutes.
[1] – Mineral Distinctions.
"Gas" means “natural gas, casinghead gas, all other hydrocarbons not defined as oil,
carbon dioxide, and helium or other substances of a gaseous nature. Natural gas and casinghead
gas are further defined as follows:
(a) ‘natural gas’ means any combustible gas or vapor composed chiefly of hydrocarbons occurring in gaseous or vapor phase at initial reservoir conditions; (b) ‘casinghead gas’ means any gas or vapor indigenous to an oil stratum and produced from such stratum with oil.”506
503 Id. § 27-533(B).
504 Id. § 27-533(C). 505 Id. 506 Id. § 25-501(9).
100
"Oil" means “crude petroleum oil and all other hydrocarbons, regardless of gravity,
which are produced at a well in liquid form by ordinary production methods and which are not
the result of condensation of gas.”507
[2] – Split by Depth.
Arizona law does not differentiate based upon depth.
[3] – Size and Spacing Rules.
Every well drilled for oil shall be located on a drilling unit consisting of approximately
80 contiguous surface acres within two governmental quarter-quarter sections or lots having one
side in common, upon which there is not located, and of which no part is attributed to, any other
well completed in or drilling to the same pool.508 In areas not covered by United States Public
Land Surveys, the oil drilling unit shall consist of an area bounded by four sides intersecting at
angles of not less than 85 degrees or more than 95 degrees.509 The unit shall contain at least 76
contiguous surface acres, and its maximum dimension shall not exceed 3,000 feet.510 No well
drilled for oil shall be located closer than 330 feet to any boundary of the drilling unit or closer
than 330 feet to the shortest center line of the drilling unit.511 No well drilled for oil shall be
located within a quarter-quarter section or lot having one side in common with another quarter-
quarter section or lot upon which there is located a well completed in or drilling to the same
pool.512
Every well drilled for gas shall be located on a drilling unit consisting of approximately 640
but not less than 600 contiguous surface acres within one governmental section upon which there
An operator drilling a well shall not intentionally deviate from the normal vertical course
of the well unless the operator first files an application and obtains approval from the
Commission after notice and hearing. The normal vertical course of a well is defined by an
average deviation from vertical of not more than five degrees in any 500-foot interval. The
operator shall test any vertical or deviated well that is drilled or deepened at least once each 500
feet or at the first bit change succeeding 500 feet. The operator shall tabulate all deviation tests
run and file the tabulation with the Commission within 30 days after drilling is completed.
Deviation from the vertical for short distances is permitted in the drilling of a well without
special approval only to straighten the hole, sidetrack junk, or correct other mechanical
difficulties.525
(1) The name, address, and telephone number of the operator;
An application for directional drilling shall include the following:
(2) The field name, lease name, well number, state permit number, reservoir name, and county where the proposed well is located; (3) A plat or sketch showing the distance from the surface location to section and lease lines and to the target location within the intended producing interval; (4) The reason for the intentional deviation; and (5) The signature of the operator.526
The operator of any well capable of production and whose producing interval or any
portion of the producing interval is located 330 feet or less in the case of an oil well or 1,660 feet
or less in the case of a gas well from the boundary of any drilling unit shall run a directional
survey before running the production casing.527
In order to ensure compliance with these requirements, the Commission may require the
operator to run a directional survey of any hole at the operator's expense. The Commission may
require an operator to run a directional survey of any hole at the request of an offset operator at
The Act was “enacted for the protection of public and private interests” and to promote
waste prevention and correlative rights protection.540
[a] Matters Governed.
The Commission has jurisdiction over all persons and property necessary to administer
and enforce the Act.541
(A) The inefficient, excessive, or improper use or dissipation of reservoir energy and the locating, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner which results, or tends to result, in reducing the quantity of oil or gas ultimately to be recovered from any pool in this state;
Waste is expressly prohibited and defined to include “physical waste,” as
well as:
(B) The inefficient storing of oil and the locating, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner causing, or tending to cause, unnecessary or excessive surface loss or destruction of oil or gas; [and,] (C) Abuse of the correlative rights and opportunities of each owner of oil and gas in a common reservoir due to nonuniform, disproportionate, and unratable withdrawals causing undue drainage between tracts of land…542
The Commission may: (1) collect data; (2) make investigations and inspections; (3)
examine properties, leases, papers, books, and records; (4) examine, check, test, and gauge oil
and gas wells, tanks, refineries, and means of transportation; (5) hold hearings; (6) provide for
the keeping of records and the making of reports; and (7) take any other action reasonably
necessary to enforce the Act.543 In addition, the Commission may issue permits to authorize
drilling and well operation, establish drilling units, regulate the location and spacing of wells,
and integrate production among various owners within a relevant area.544
The Commission may meet or hold hearings at any time and place necessary to carry out
its duties.545 The Commission is authorized to enact and enforce rules, regulations, and orders
pursuant to the Act. 546 A majority of members constitutes a quorum for voting purposes;
however, in no event, may any rule, regulation, or order be adopted or promulgated without
receiving at least five affirmative votes.547
Excluding emergencies, the Commission must hold a public hearing prior to issuing any
rule, regulation or order.
548
“give notice of the public hearing to be held upon such application by one publication at least ten days prior to the date of the hearing, but not more than 30 days prior thereto, in a legal newspaper having a general circulation in the county, or [if applicable] in each county, in which the lands embraced within the application are situated, except that, as to any public hearing pertaining to a matter of general application throughout the State of Arkansas, the notice shall be published in a legal newspaper having state-wide circulation.”
When an application is filed with the Commission seeking action
authorized under the Act, the Commission must
549
In addition, the Commission may elect to give notice by personal service, which “may be made
by any officer authorized to serve process[,] or by any agent of the Commission in the same
manner as provided by law for the service of summons in civil actions.”550 All rules, regulations
and orders issued by the Commission must in writing and maintained as public record, copies of
which are receivable into evidence in all state courts.551
and internal unit well-location restrictions will allow only six to eight horizontal wells in the
unit.591
The internal well location restriction requires all wells in the unit to be spaced 448 feet
apart with an allowed variance of 20 percent.
592 Externally, each well is required to be located at
least 560 feet from each other well and a minimum of 560 feet from all unit boundaries.593
Applications for exceptions to the well location provisions relative to a drilling unit boundary or
other location in a common source of supply may be brought before the Commission.594
[4] – Minimum Operator Control.
The filing of an application to integrate separately owned tracts within an exploratory
drilling unit is permissible, provided that one or more persons who collectively own at least an
undivided 50 percent interest in the right to drill and produce oil and gas to support the filing of
the application.595 The filing of an application to integrate separately owned tracts within an
established or producing drilling unit is permissible without a minimum acreage requirement,
provided that one or more persons owning an interest in the right to drill, produce oil or gas, or
both from the total acreage assigned to such established drilling unit requests such integration.596
As shown above, a condition to the Commission granting an order for unit operations that
will force all owners within a prescribed area to comply with a proposed unitization agreement
requires consent of certain owners. In particular, when a petition seeking a unitization order is
filed, the applicant must show that “the proposed unit agreement has been executed by persons
591 Id. 592 Id. Rule B-43(i)(3). 593 Id. Rule B-43(i)(1). 594 Id. Rule B-43(i)(5). 595 Ark. Code Ann. § 15-72-302(e) (2010); see also id. Rule B-43(g). This 50% requirement is only applicable to ‘exploratory drilling units,’ as distinct from ‘established drilling units.’ A drilling unit is or becomes ‘established’ if it contains an existing well or completed well, and for which the operator has filed documentation with the Commission establishing such completion. See id. Rule B-43(f). 596 Id. Rule B-43(h).
116
who, at the time of the filing, own legal title to at least an undivided 75 percent interest in the
right to drill into and produce oil or gas from the proposed unit area;” as well as those “persons
who[,] at that time[,] own legal title to 75 percent of royalties and overriding royalties payable
with respect to oil or gas produced from the unit area.”597
[5] – Directional Drilling.
The Commission may grant a drilling permit to allow deviated or horizontal drilling
methods. For the purpose of complying with spacing rules, well location is defined as the actual
physical location of the completed interval in the well, projected to the surface, as follows:
(A) In a vertically drilled well without a directional survey, the well location is the surface location. In a vertically drilled well, the well location is the location of the perforated interval of the well bore, projected vertically to the surface; (B) In a directionally drilled well, the well location is the location of the midpoint of the perforated interval of the producing formation, as calculated from the directional survey, projected vertically to the surface; (C) In a horizontally drilled well, the well location is the entire perforated length of the lateral section of the well bore, as shown on a directional survey, projected vertically to the surface.598
[6] – Options.
The Act acknowledges that an owner subject to compulsory pooling may elect to
participate in the cost of operation. If a pooling order is issued for a well that has not been
commenced within a drilling unit with no currently producible well, the order must provide “that
an owner who does not elect to participate in the risks and costs of operations must transfer his or
her rights to drill and produce from the unit well to those parties who elect to participate
therein.”599
597 Ark. Code Ann. § 15-72-309(b) (2010).
The transfer must be for a reasonable consideration which, absent an agreement
598 Ark. Oil & Gas Commission, Gen. Rules & Regs., Rule B-3(a)(2) (2011). 599 Ark. Code Ann. § 15-72-304(b) (2010).
117
between the parties, will be determined by the Commission.600 Moreover, the transfer “may be
either a permanent transfer or may be for a limited period pending recoupment out of the share of
production attributable to the interest of the nonparticipating owner by the participating parties of
an amount equal to the share of the costs that would have been borne by the nonparticipating
party had he participated in the operations, plus and additional sum to be fixed by the
Commission.”601
The election rights are slightly different if a well capable of production exists on drilling
unit as of the effective date of the pooling order. In that event, the order must stipulate a time
period within which any owner in the drilling unit who did not participate in the drilling of the
well must either:
(A) reimburse the drilling parties in cash for his or her share of the actual cost of drilling, completing, and equipping the well[;] or… (B) transfer his rights in such drilling unit and the production from the well to the drilling parties[,] until those parties have received[,] out of the share of production attributable to the interest so transferred[,] an amount equal to the share of the costs that would have been borne by the transferring party had he participated in drilling, completing, equipping, and operating the well, plus an additional sum to be fixed by the Commission.602
The Act does not provide statutory requirements relating to carrying a non-consenting owner, or
enforcing a risk penalty for such situations. If applicable, the Commission will determine such
matters on a case-by-case basis.
600 Id. 601 Id. 602 Id. § 15-72-304(c).
118
§ 06.01 Analysis of California Regulatory Framework.
[1] – Name of the Governing Body.
The Division of Oil, Gas, and Geothermal Resources (“Division”) in the Department of
Conservation (“Department”) was formed in 1915 to address the needs of the state, local
governments, and industry by regulating statewide oil and gas activities with uniform laws and
regulations. The Division supervises the drilling, operation, maintenance, plugging, and
abandonment of onshore and offshore oil, gas, and geothermal wells, preventing damage to life,
health, property, and natural resources; underground and surface waters suitable for irrigation or
domestic use; and oil, gas, and geothermal reservoirs. Division requirements encourage wise
development of California’s oil, gas, and geothermal resources while protecting the
environment.603
[2] – Membership on the Governing Body.
The state is divided into six districts, the boundaries of which are fixed by the Director of
the Department.604 The State Oil and Gas Supervisor (“Supervisor”) leads the Division of Oil,
Gas and Geothermal Resources 605 and appoints one Chief Deputy and at least one District
Deputy for each of the districts.606 The Chief Deputy appointees must be competent engineers or
geologists, registered in the state, and experienced in the development and production of oil and
gas. 607 Each District Deputy must also be a competent engineer or geologist, preferably
registered in the state, and experienced in the development and production of oil and gas.608
603 State of California Department of Conservation, Oil, Gas, & Geothermal-About Us, http://www.conservation.ca.gov/dog/Pages/aboutUs.aspx (last visited Jun. 6, 2011). 604 Cal. Pub. Res. Code § 3100 (West 2011). 605 Id. § 690. 606 Id. § 3101. 607 Id. § 3103. 608 Id. § 3104.
119
[3] – Scope of Authority.
The Supervisor oversees the drilling, operation, maintenance, and abandonment of wells
to ensure that all suitable methods and practices known to the industry for increasing the ultimate
recovery of underground hydrocarbons are used.609 New wells shall not be drilled without first
obtaining approval from either the Supervisor or the District Deputy.610 If the Supervisor or the
District Deputy fails to give a written response to a notice of intent to drill within 10 working
days from the date of receipt, that failure shall be considered as an approval of the notice.611
The Supervisor is authorized to approve unit agreements proposed by landowners and
consented to by persons who own at least an undivided three-fourths of the total working
interests in the area proposed to be unitized and by persons who own at least an undivided three-
fourths of the total royalty interest in the area.
612 If a valid unit agreement is proposed, the
Supervisor shall issue orders directing unit operations in accordance with the agreement.613 An
order of the Supervisor approving unit operations must require the recordation of the agreement
in the county recorder’s office of each county in which any part of the unit area is situated and
must require that the interests of all persons in the unit area be thereafter subject to the unit
agreement the same as if all such persons had expressly consented to the unit agreement.614
The Supervisor's order shall include fair and reasonable provisions for all of the
following:
(a) The date when all tracts of land not theretofore committed to the unit shall be subject to unit operation (in no event earlier than the first day of the month following the effective date of the Supervisor's order.)
(b) Provision for the carrying or otherwise financing of any persons who request the same and who the Supervisor determines are unable to meet their financial obligations in connection with the unit operation, allowing a reasonable interest charge to those who carry or finance such obligations. (c) Such additional provisions which the Supervisor determines to be appropriate for bringing into the unit area on a fair and reasonable basis tracts of land and interests not theretofore committed to the unit agreement.615
The Supervisor may establish field rules for any oil and gas pool or zone in a field when
sufficient geologic and engineering data is available from previous drilling operations.616
The Supervisor may also establish variances from the statutory well-spacing requirements
if he determines that the development of a pool requires the adoption of a well-spacing pattern
other than that specified by statute in order to prevent waste and to increase the ultimate
economic recovery of oil or gas.
Field
rules supplement more broadly applicable statutory and regulatory requirements. Each field rule
is specific to a field, and in many cases, specific to areas and zones or pools within a field.
617 A well-spacing plan adopted by the Supervisor shall require
that all or certain parcels of land be included in a voluntary or mandatory pooling agreement if
necessary to protect correlative rights. 618 In any order adopting a well-spacing plan, the
Supervisor may provide up to 60 days from the date of the order for affected parties to attempt to
voluntarily pool their respective interests.619
615 Id. § 3646.
That period may be extended at the Supervisor's
discretion upon the written request of the affected parties. Any well-spacing order providing a
period for an attempt at voluntary pooling is not a final order of the Supervisor until either
voluntary pooling has been accomplished and the Supervisor notified of it or the Supervisor has
approval.634 However, until the Supervisor approves the agreement, persons who do not consent
to the agreement will not be bound by it.635
Any proposed agreement for unit operation of tracts of land that has been consented to by
persons who own at least an undivided three-fourths of the total working interests in the area
proposed to be unitized, and by persons who own at least an undivided three-fourths of the total
royalty interest in the area proposed to be unitized, may be filed with the Supervisor by the
owner of any such working interest in conjunction with a petition requesting approval of an
agreement.
636
(a) The unit area of the proposed agreement for unit operation takes in all tracts which, consistent with good oilfield practice, should be considered a part of and related to the field or pool or pools, or portions thereof, proposed for unit operation but does not include tracts which, consistent with good oilfield practice, should not be considered a part of or related to the field or pool or pools, or portions thereof, proposed for unit operation.
The unit agreement shall be approved, if, after a public hearing, the Supervisor
finds all of the following:
(b) As of the date of filing of the petition, the proposed unit agreement was consented to by persons owning at least three-fourths of the working interests and three-fourths of the lessors' royalty interests. (c) The unitized management and operation of the pool or pools, or portions thereof, proposed to be unitized is reasonably necessary to carry on pressure maintenance or pressure replenishment operations, cycling or recycling operations, gas injection operations, water flooding operations, reduction of oil viscosity operations, or any combination thereof, or any other form of joint effort calculated to increase the ultimate recovery of oil and gas from the proposed unit area. (d) The value of the estimated recovery of additional oil or gas, or the increased present worth value due to accelerated recovery of oil or gas, as a result of the unit operations will exceed the estimated additional cost incident to conducting such operations. (e) The proposed unit agreement provides for an allocation of the unit production among and to the separately owned tracts in the
634 Id. § 3641. 635 Id. 636 Id. § 3642.
124
area proposed to be unitized that will reasonably permit persons otherwise entitled to share in or benefit by the production from their separately owned tracts to produce or receive, in lieu thereof, their fair, equitable, and reasonable pro rata share of the unit production or other benefits thereof. (f) The proposed unit agreement provides, to the full extent practical, for the organization and consolidation of surface facilities, including oil production, storage, treatment, and transportation facilities, in a manner that will eliminate wasteful and excessive use of land surface areas, freeing such areas for other productive use and development, and provides a fair procedure for the waiver, from time to time, of the working interest owners’ right of entry on surface areas which in the future become unneeded for the conduct of unit operations. (g) The proposed unit agreement is fair and reasonable under all the circumstances in other material respects. (h) If state-owned lands under the jurisdiction of the State Lands Commission are included in the proposed unit agreement, the agreement has been reviewed and approved by the Commission.637
§ 06.02 Types of California Pooling Statutes.
[1] – Mineral Distinctions.
"Oil" includes petroleum, and "petroleum" includes oil. 638 "Gas" means any natural
hydrocarbon gas coming from the earth.639
[2] – Split by Depth.
California does not differentiate based upon depth.
[3] – Size and Spacing Rules.
Except as otherwise provided by California law, any oil or gas well drilled within 100
feet of an outer boundary of the parcel of land on which the well is situated, or within 100 feet of
a public street or road or highway dedicated prior to the commencement of drilling of the well, or
within 150 feet of a well producing oil or gas or capable of producing oil or gas, is a public
637 Id. § 3643. 638 Id. § 3006. 639 Id. § 3007.
125
nuisance.640 Further, the producing interval of any well drilled into a new pool must not be less
than 75 feet from an outer boundary line.641
Where a parcel of land contains one acre or more, but is less than 250 feet in width, only
one well may be drilled on the parcel of land to each acre of the area if the surface location of
any well or wells is as far from the lateral boundary lines of the parcel of land as the
configuration of the surface and the existing improvements thereon will permit.
642 Where a
parcel of land contains one acre or more and the hydrocarbons to be developed are too heavy or
viscous to produce by normal means, the Supervisor may approve proposals to drill wells at
whatever locations he deems advisable for the purpose of the proper development of such
hydrocarbons by the application of pressure, heat, or other means for the reduction of oil
viscosity, and such wells shall not be classed as public nuisances.643
Where a parcel of land contains one acre or more and where all or substantially all of the
surface of such parcel of land is unavailable for the surface location of oil or gas wells, there may
be drilled or produced not more than one well into each acre of such parcel of land, and the
surface location of such well may be located upon property which may or may not contain one
acre or more of surface area, and the property upon which the surface location of such well may
be located may or may not be contiguous to such parcel of land, provided:
(1) No operator shall construct or maintain any derrick within 150 feet of any other derrick, then standing, of that operator unless approved in advance by the Supervisor who may, in granting approval, attach conditions that are reasonably necessary. (2) The surface location of a well, as measured from the center of the hole, shall be not less than 25 feet from an outer boundary of the surface of the property the well is located upon, and shall be
not less than 25 feet from any dedicated public street, road or highway in public use at the time drilling of the well commences. (3) The producing interval of the well shall be not less than 75 feet from an outer boundary of the parcel of land into which the producing interval is drilled, and the producing interval of the well shall be not less than 150 feet, as measured horizontally in the same zone, from the producing interval of any other well producing or capable of producing oil or gas. If the parcel of land qualified to be drilled is less than 150 feet in width, the producing interval of that well shall be as far from the lateral boundary lines of the property as is practicable.644
The 150-foot restriction shall apply only to wells drilled and producing from the same
zone or pool; provided, however, that the well density shall not exceed one well per acre unless
the Supervisor shall determine that more than one zone or pool underlies the property and that it
is not practical to produce from all zones or pools from a single well per acre and that other
zones or pools are being drained by offset wells. In such cases only, a maximum density of two
wells per acre may be approved.645
[4] – Minimum Operator Control.
Unitization agreements must be authorized by persons owning three-fourths of the total
working interest in the unitized area and by persons owning three-fourths of the total royalty
interest in that area.646
[5] – Directional Drilling.
California does not appear to regulate based upon the direction of operations.
[6] – Options.
The owner of any working interest or royalty interest in a tract that is the subject of a unit
agreement who did not consent to the proposed unit agreement shall, 60 days after the Supervisor
644 Id.§ 3606. 645 Id. § 3606.1. 646 Id. § 3642.
127
issues his order, be entitled to offer his interest for sale.647 All working interest owners who
consented to the proposed unit agreement shall be entitled to purchase that interest in proportion
to their respective shares of unit production.648 Unless one or more working interest owners
purchase that interest, the order of the Supervisor will not become effective.649
If a disagreement arises with respect to the purchase price for such an interest, then
either party may request the Supervisor to authorize the creation of an arbitration committee
consisting of three members, one member appointed by the seller, one member appointed by the
purchaser or purchasers, and a third member selected by the other two members, to make an
independent appraisal of the value of the interest as of the date the Supervisor issued his order.
650
The arbitration committee shall consider all relevant data and information submitted by
interested parties and may seek and consider other information it deems relevant. The arbitration
committee shall determine the fair market value of the interest as of the date the Supervisor
issued his order and fix the price at which the sale shall be consummated.651
The arbitration committee’s determination shall be binding on the parties except that,
within 30 days after the determination of the arbitration committee has been mailed to the parties
concerned, the seller or any one or more of the purchasers may have such price judicially
determined by filing suit for a declaratory judgment as to the fair market value in the superior
court for the county in which the tract involved, or the greater portion of it, lies.
652
647 Id. § 3647.
The
compensation and expenses of the arbitration committee shall be subject to approval by the
Supervisor and, if the unit becomes effective, shall be paid by the working interest owners who
648 Id. 649 Id. 650 Id. 651 Id. 652 Id.
128
elected to participate in purchasing the interest in the proportion they share unit expenses.653 If
the unit does not become effective within the time provided for in the order of the Supervisor, the
working interest owners who have consented to the unit agreement and have requested the
independent appraisal shall pay such compensation and expenses in proportion to what would
have been their shares of unit expenses.654
653 Id. 654 Id.
129
§ 07.01 Analysis of Colorado Regulatory Framework.
[1] – Name of the Governing Body.
The Colorado Oil and Gas Conservation Commission (“Commission”) regulates oil and
gas production and exploration within the state pursuant to the Oil and Gas Conservation Act
(“Act”).655
[2] – Membership on the Governing Body.
The Commission is comprised of nine members, two of which are the executive directors
of the Department of Public Health and the Department of the Environment, respectively.656 The
remaining seven members are appointed by the governor based on the area from which they hail:
at least two must reside west of the continental divide; and, when possible, “other members shall
be appointed taking into account the need for geographical representation of other areas of the
state with high levels of oil and gas activity or employment.”657 No less than three members of
the Commission must have substantial experience in the oil and gas industry, and at least two of
those three must possess a college degree in petroleum geology or petroleum engineering.658
Additionally, at least one member of the Commission must be a local government
official, one member must have formal training or experience in environmental or wildlife
protection, one member must have formal training in soil reclamation, and one member must be
actively engaged in agricultural production, “and also be a royalty owner.”
659 Not including the
two executive directors, no more than four members of the Commission may belong to the same
political party.660 Each person on the Commission serves for a term of four years.661
The Commission’s duty is to promote the public interest and policy goals specified in the
Act, including to:
(I) foster the responsible, balanced development, production, and utilization of the natural resources of oil and gas in the state of Colorado in a manner consistent with protection of public health, safety, and welfare, including protection of the environment and wildlife resources; (II) protect the public and private interests against waste in the production and utilization of oil and gas; (III) safeguard, protect and enforce the coequal and correlative rights of owners and producers in a common source or pool of oil and gas to the end that each such owner and producer…may obtain a just and equitable share of production therefrom; and (IV) plan and manage oil and gas operations in a manner that balances development with wildlife conservation in recognition of the state’s obligation to protect wildlife resources . . . .662
It is neither the intent nor purpose of the Act “to require or permit the proration or distribution of
the production of oil and gas among the fields and pools of Colorado on the basis of market
demand.”
663 Rather, the Act seeks to allow “each oil and gas pool in Colorado to produce up to
its maximum efficient rate of production,” subject to the goals stated above.664
[a] Matters Governed.
As expressed above, the Commission’s authority is grounded in the aim of waste
prevention.665 “Waste” is prohibited under the Act666
(a) Waste, as applied to gas, includes the escape, blowing, or releasing, directly or indirectly into the open air, of gas from wells productive of gas only, or gas in an excessive or unreasonable amount from wells producing oil, or both oil and gas; and the production of gas in quantities or in such manner as unreasonably reduces reservoir pressure or unreasonably diminishes the quantity
of oil or gas that ultimately may be produced; excepting gas that is reasonably necessary in the drilling, completing, testing, and in furnishing power for the production of wells. (b) waste, as applied to oil includes underground waste; inefficient, excessive, or improper use or dissipation of reservoir energy, including gas energy and water drive; surface waste, open-pit storage, and waste incident to the production of oil in excess of the producer's aboveground storage facilities and lease and contractual requirements, but excluding storage, other than open-pit storage, reasonably necessary for building up or maintaining crude stocks and products thereof for consumption, use, and sale; and, (c) waste in addition [to the above] means physical waste, as…generally understood in the oil and gas industry; [t]he locating, spacing, drilling, equipping, operating, or producing of any oil or gas wells in a manner which causes or tends to cause reduction in [the] quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations[,] or which causes or tends to cause unnecessary or excessive surface loss or destruction of oil and gas; [a]buse of the correlative rights of any owner in a pool due to non-uniform, disproportionate, unratable, or excessive withdrawals of oil or gas therefrom, causing reasonably avoidable drainage between tracts of land or resulting in one or more producers or owners in such pool producing more than his equitable share of the oil or gas from such pool.667
The Commission has jurisdiction over “all persons and property, public and private, necessary to
enforce” the Act, and has general authority “to do whatever may reasonably be necessary to
carry out the Act’s provisions.
668
For example, the Commission may require the “[i]dentification of [well] ownership…;
the making and filing of…well logs, directional surveys, and reports on well location…; drilling
[and other operations] in such manner as to prevent the escape of oil or gas,…the intrusion of
water into oil or gas strata, the pollution of fresh water supplies;…[keeping of] complete and
accurate [production] records;” and various other aspects of oil and gas production.
669
667 Id. §§ 34-60-103(11)-(13) (emphasis added).
In
addition, the Commission has authority to dictate the spacing of wells, and “to limit and to
668 Id. § 34-60-105(1). 669 Id. § 34-60-106(1).
132
allocate the production from [any] pool or field among or between tracts of land having separate
ownerships therein.”670
[b] Commission Procedure.
The Commission is authorized to enact and enforce rules, regulations, and orders
pursuant to the Act.671 The Commission is empowered to act upon its own motion or that of any
interested person.672 Any person, or the attorney general on behalf of the state, may apply for a
hearing before the Commission in relation to any issue within its jurisdiction.673 Except in
emergency situations, the Commission may not make any rule, regulation, or order without a
hearing upon no less than 20 days notice.674
Any notice required [under the Act]…shall be given by the election of the Commission either by mailing a copy thereof…to the last known mailing address of the person to be given notice, or by personal service. In addition, the Commission shall cause one publication of such notice, at least 10 days prior to the hearing, in a newspaper of general circulation in the county where the land affected, or some part thereof, is situated. The notice shall issue in the name of the state, shall be signed by the Commission or [its] secretary, and shall specify the style and number of the proceeding and the time and place of the hearing at which the hearing will be held, shall state the time within which protests to the granting of a petition shall be filed if [applicable], and shall briefly state the purpose of the proceeding. Should the Commission elect or be required to give notice by personal service, such service may be made by any officer authorized to serve summons[,] or by any agent of the Commission[,] in the same manner and extent as is provided by law for the service of summons in civil actions in the district courts of this state. Proof of service by such agent shall be by his affidavit, and proof of service by an officer shall be in the form required by law with respect to service of process in civil actions. In all cases
where there is an application for the entry of a pooling order or unitization order, or an application for an exception from an establish well spacing pattern, or a complaint is made by the Commission or any party[,] that any part of any provision of [the Act], or any rule, regulation, or order of the commission is being violated, notice of the hearing to be held on such application or complaint shall be served on the interested parties either by mail or in the same manner as is provided in the Colorado rules of civil procedure for the service of process in civil actions in the district courts of this state.675
Any rule, regulation, or order issued by the Commission must be in writing and maintained as
public record, copies of which are receivable into evidence in all state courts.
676
Any interested person may file a written protest with the Commission that states the
grounds for such protest, which must be filed at least three days prior to the hearing.
677 A timely
protest affords the applicant the right to be heard at the hearing.678 In any case, the Commission
will enter its order within 30 days of the hearing, and “any person affected by any order…shall
have the right at any time to apply to the Commission to repeal, amend, modify, or supplement
the same.”679
[4] – Process for Pooling and Matters Covered.
[a] Drilling Units.
After notice and a hearing, the Commission may establish drilling units “to
prevent…waste, to avoid the drilling of unnecessary wells, or to protect correlative rights.680
Such a hearing may be prompted by the Commission itself, or upon the application of any
interested party.681
675 Id. § 34-60-108(4).
The Commission will set drilling units based on efficient production from an
Each pooling order must provide just and reasonable terms and conditions, and “shall
make provision for the drilling of a well on the drilling unit, if not already drilled, for the
operation thereof, and make provision for the payment of the reasonable actual cost [of
operation], including a reasonable charge for supervision and storage.”689 In addition, a pooling
order must establish how production and costs will be allocated among the various owners within
the pool.690 The Act affords election rights in compulsory pooling situations, yet enforces a risk
penalty for those non-consenting owners who refuse to sell their rights in the pool.691
The Act also allows voluntary and compulsory unitization. Upon application from any
interested person, the Commission will hold a hearing to consider the need for unit operations of
one or more pools.
This will
be discussed in further detail below.
692 After the hearing, the Commission will order unitization if it finds that
such is reasonably necessary to increase ultimate recovery, and that the “value of the estimated
additional recovery of oil or gas exceeds the estimated additional cost incident to conducting
such operations.”693
(a) A description of the pool, or parts thereof, to be so operated, termed the unit area, but only so much of a pool as has reasonably been defined and determined by drilling operations to be productive of oil or gas may be included within the unit area.
A unitization order must contain the following information:
(b) A statement of the nature of the operations contemplated. (c) An allocation to the separately owned tracts in the unit area of all the oil and gas that is produced from the unit area and is saved, being the production that is not used in the conduct of operations on the unit area or not unavoidably lost. (d) A provision for the credits and charges to be made in the adjustment among the owners in the unit area for their respective investments in wells, tanks, pumps, machinery, materials, and equipment contributed to the unit operations.
(e) A provision providing how the costs of unit operations, including capital investments, shall be determined and charged to the separately owned tracts and how said costs shall be paid, including a provision providing when, how, and by whom the unit production allocated to an owner who does not pay the share of the cost of unit operations charged to such owner, or the interest of such owner, may be sold and the proceeds applied to the payment of such costs. (f) A provision, if necessary, for carrying or otherwise financing any person who elects to be carried or otherwise financed, allowing a reasonable interest charge for such service payable out of such person’s share of the production. (g) A provision for the supervision and conduct of the unit operations, in respect to which each person shall have a vote with a value corresponding to the percentage of the costs of unit operations chargeable against the interest of such person; (h) The time when the unit operations shall commence, and the manner in which, and the circumstances under which, the unit operations shall terminate. And, (i) Such additional provisions that are found to be appropriate for carrying on the unit operations, and for the protection of correlative rights.694
[c] Allocation of Production and Costs.
The Commission has express authority to limit and allocate production among various
pools and wells to prevent waste and protect correlative rights.695 Allocation must be made “on
a reasonable basis [to] prevent[] or minimiz[e] reasonably avoidable drainage, so that each
property will have the opportunity to produce or to receive its just and equitable share, subject to
the reasonable necessities for the prevention of waste.”696
The effect of a unitization agreement or order is to treat all tracts within the unit area, and
owners thereof, equitably based on respective interests therein. As a general matter, “[a]ll
operations…of a well upon any portion of the unit area shall be deemed for all purposes the
conduct of such operations upon each separately owned tract in the unit area by the several
the production applicable to his interest in the unit after the consenting owners have recovered
the non-consenting owner’s share out of production.”720
If one or more owners within a pooled drilling unit refuse to pay, each will be subject
to an additional risk penalty respective of each non-consenting owner’s interest until all costs and
other charges are recovered by the consenting owners. This statutory penalty allows respective
consenting owners or operators to recover:
(1) One hundred percent of the non-consenting owner's share of the cost of surface equipment beyond the wellhead connections (including, but not limited to, stock tanks, separators, treaters, pumping equipment, and piping); plus, (2) One hundred percent of the non-consenting owner's share of the cost of operation of the well commencing with first production and continuing until the consenting owners have recovered such costs; and, (3) Two hundred percent of that portion of the costs and expenses of staking, well site preparation, obtaining rights-of-way, rigging up, drilling, reworking, deepening or plugging back, testing, and completing the well, after deducting any cash contributions received by the consenting owners; and, (4) Two hundred percent of that portion of the cost of equipment in the well, including the wellhead connections.721
This penalty applies to non-consenting owners who are oil and gas lessees.
722
A non-consenting owner of a tract in a drilling unit which is not subject to any lease or other contract for the development thereof for oil and gas shall be deemed to have a landowner's proportionate royalty of twelve and one-half percent [i.e. 1/8th] until such time as the consenting owners recover, only out of the non-consenting owner's proportionate seven-eighths share of production, the costs specified [above]. After recovery of such costs, the non-consenting
However, the Act
affords owners of unleased tracts within a unit further protection by allowing a non-consenting
owner to acquire a working interest in the well upon the other consenting owners’ cost recovery.
The Act provides:
720 Id. 721 Id. 722 Id. § 34-60-116 (7)(c).
142
owner shall then own his proportionate eight-eighths share of the well, surface facilities, and production and then be liable for further costs as if he had originally agreed to drilling of the well.723
In addition, the Commission may not enter a pooling order over the protest of an owner of
unleased minerals unless shown that such owner has “been tendered a reasonable offer to lease
upon terms no less favorable that those currently prevailing in the area,” and has “been furnished
in writing such owner’s share of the estimated drilling and completion costs of the well, the
location and objective depth of the well,” and the estimated time of commencing operations.
724
The Act does not provide a risk penalty for owners subject to forced unitization because
such an owner has limited election rights. The cost allocation must be provided in an order for
unit operations to show “how the costs of unit operations, including capital investments, shall be
determined and charged to the separately owned tracts and how said costs shall be paid,
including”
(1) a provision providing when, how, and by whom the unit production allocated to an owner who does not pay the share of the cost of unit operations charged to such owner, or the interest of such owner, may be sold and the proceeds applied to the payment of such costs; and, (2) a provision, if necessary, for carrying or otherwise financing any person who elects to be carried or otherwise financed, allowing a reasonable interest charge for such service payable out of such person's share of the production725
Thus, the non-consenting owner subject to forced unitization may either elect to sell his interest
or portion of production; or in turn, may be carried by other owners who so agree without facing
§ 08.01 Analysis of Connecticut Regulatory Framework.
[1] – Governance.
The body charged with jurisdiction over the preservation of natural resources in
Connecticut is the Department of Environmental Protection (“Department”). 726 The
Commissioner of Environmental Protection (“Commissioner”) directs the Department.727 The
Commissioner’s duties and powers embrace those necessary and convenient to carry out the
state’s environmental policies, including providing for “minimum state-wide standards for the
mining, extraction, excavation or removal of earth materials of all types,”728 and he may employ
such agents and employees as necessary to carry out his duties.729
[2] – Procedure.
Connecticut has not enacted legislation directly related to pooling or spacing. However,
the Department of Environmental Protection has promulgated regulations for oil and gas
exploration and production.730 Those regulations primarily govern permitting for exploration
and production wells.731
(A) The name, . . . mailing and location address and telephone number of the person for whom the exploration is conducted, and, if such person is a business, the name, mailing and location address and telephone number of the individual designated as the contact for the Commissioner.
They require that persons exploring for oil or gas to register with the
Commissioner by submitting information set forth in the regulations:
(B) A United States Geologic Survey topographic map at a scale of one inch equals 25,000 feet which shows the location of the exploration activity. (C) A description of the exploration activity, including but not limited to a description of the methods of exploration to be used and the location, depth and number of borings to be drilled.
(D) A registration fee of $50 payable by certified check or money order to the Commissioner of Environmental Protection. And, (E) Any other information which the Commissioner deems necessary.732
Exploration may not begin until after the Commissioner approves the registration.
733
A separate registration must be submitted for each exploratory well and each production
well.
734 That registration must include the proposed final depth of the proposed well735 and “the
depth of each private well within a 1000 foot radius of the proposed well and the depth of each
public water supply well within a one mile radius of the proposed well.”736 Additionally, the
registration must include a “surety or performance bond payable to the State of Connecticut in
the sum of $25,000 for each proposed well, conditioned on the well being drilled, maintained and
abandoned in accordance with this section and the exploration and production activities not
causing pollution.” 737 If drilling is not commenced within one year of the Commissioner’s
approval of registration, that registration expires.738
The regulations also provide a definition for oil and gas.
739 Oil is defined as “crude
petroleum oil and other hydrocarbons, regardless of gravity, that are produced in liquid form by
ordinary production methods,” while gas is defined as “all natural gas and all other hydrocarbons
that occur in a gaseous phase in the reservoir.”740
§ 09.01 Analysis of Delaware Regulatory Framework.
The state of Delaware has not enacted statutes addressing oil and gas conservation.
147
§ 10.01 Analysis of Florida Regulatory Framework.
[1] – Name of the Governing Body.
The body vested with the authority to enforce Florida’s Oil and Gas Conservation Statute
(“Oil and Gas Statute”)745 is the Division of Water Resource Management (“Division”) of the
Department of Environmental Protection (“Department”).746
[2] – Membership on the Governing Body.
The Department of Environmental Protection is headed by a secretary (“Secretary”), who
is appointed by the Governor with concurrence of three or more members of the Cabinet747 and
confirmation by the Senate.748 The Secretary serves at the pleasure of the Governor749 and may
appoint three deputy secretaries, which serve at the pleasure of the Secretary.750 The Oil and Gas
Statute is administered by the Division of Water Resource Management.751 The departmental
divisions are each headed by a director752
[3] – Scope of Authority.
to be appointed by the Secretary and to serve at his or
her pleasure.
The Division has jurisdiction and authority over “all persons and property necessary to
administer and enforce effectively the provisions of this law and all other laws relating to the
conservation of oil and gas.”753
745 Fla. Stat. § 377.01–.42 (2010).
All production of oil and gas from common supply sources are
746 Id. § 377.07. Although the statute states that the Division of “Resource Management” is the governing body, the more accurate name is the Division of Water Resource Management so to distinguish it from the Division of Air Resource Management. 747 Id. § 20.255(1). 748 Id. § 20.05(2). 749 Id. 750 Id. § 20.255(2)(a). 751 Id. § 377.07. 752 Id. § 20.04(3)(a). 753 Id. § 377.21(1).
148
controlled and regulated under the Oil and Gas Statute,754 which declares that the public policy
of Florida includes the following: “to conserve and control the natural resources of oil and gas in
said state . . .; to prevent waste of said natural resources; to provide for the protection and
adjustment of the correlative rights of the owners of the land wherein said natural resources lie
and the owners and producers of oil and gas resources and the products made therefrom and of
others interested therein.”755
Waste of oil and gas is prohibited.
756
(a) The inefficient, excessive or improper use or dissipation of reservoir energy; and the locating, spacing, drilling, equipping, operating or producing of any oil or gas well or wells in a manner which results, or tends to result, in reducing the quantity of oil or gas ultimately to be recovered . . . .
Waste is defined to mean “physical waste” as
understood in the oil and gas community and also including the following:
(b) The inefficient storing of oil; and the locating, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner causing, or tending to cause, unnecessary or excessive surface loss or destruction of oil or gas. (g) Underground waste however caused and whether or not defined. (k) Abuse of correlative rights and opportunities of each owner of oil and gas in a common reservoir due to nonuniform, disproportionate and unratable withdrawals, causing undue drainage between tracts of land.
The Division has the authority and duty to investigate as is proper to determine if waste exists or
is imminent.757
(a) Collect data.
In the exercise of those duties, the division has the authority to:
(b) Make investigations and inspections. (c) Examine properties, leases, papers, books, and records and to examine, survey, check, test, and gauge oil and gas wells, tanks, storage tanks, treatment plants and facilities, and modes of transportation used to gather and process crude oil or gas and
products derived from wells within the state, prior to delivery to common carrier. (d) Hold hearings. (e) Provide for the keeping of records and making of reports. (f) Take such action as may be reasonably necessary to enforce this law.758
The Department may issue orders and rules in order to implement and enforce this
chapter. Rules and orders may be promulgated under the authority of this chapter for the
following reasons, among others:
(d) To require the drilling, casing, and plugging of wells to be done in such a manner as to prevent the escape of oil or other petroleum products from one stratum to another. (f) To require a reasonable bond, or other form of security acceptable to the department, conditioned upon the performance of the duty to plug properly each dry and abandoned well and the full and complete restoration by the applicant of the area of which geophysical exploration, drilling, or production is conducted to the similar contour and general condition in existence prior to such operation. (i) To prevent wells from being drilled, operated, or produced in such a manner as to cause injury to neighboring leases or property. (r) If necessary for the prevention of waste, as herein defined, to determine, limit, and prorate the production of oil or gas, or both, from any pool or field in the state. (t) To regulate the spacing of wells and to establish drilling units. (u) To prevent, so far as is practicable, reasonably avoidable drainage from each developed unit which is not equalized by counterdrainage. (x) To act in a receivership capacity for fractional mineral interests for which the owners are unknown or unlocated and to administratively designate the operator as the lessee.759
When necessary to prevent waste and to avoid drilling unnecessary wells, the Division
may establish a drilling unit or units for each pool.
760 A drilling unit is defined as “the maximum
area in a pool which may be efficiently and economically drained by one well.”761
758 Id.
Owners of
759 Id. § 377.22(2). 760 Id. § 377.25(2). 761 Id.
150
two or more separately owned tracts may, on their own, agree to integrate their interests and
develop the land as a unit.762 If no agreement has been reached, the Division may require
owners of two or more separately owned tracts within an established drilling unit to integrate
their interests and develop their land as a drilling unit.763 The Department also has the authority
to issue an order requiring the operation as a unit of an entire field or of a pool or pools
therein.764
[4] – Process for Pooling.
Florida requires permits be obtained prior to drilling wells and prior to operating those
wells.765 Before an applicant may apply for a drilling permit, he or she must have “a lawful right
to drill, explore, or develop from a majority of the mineral interests within a drilling unit,”
whether by owning or leasing the minerals.766 Unallocated interests may be unitized.767 Also,
prior to issuing a permit, the Division must find that the applicant has implemented, or will
implement, programs to control oil- and petroleum-related pollution and the abatement
thereof.768
All permits to drill must include the address of the applicant’s residence or the several
applicants’ residences,
769
762 Id. § 377.27(1).
as well as the following: an Organization Report, performance
security, location plat, site construction plans, casing and cementing program, contingency plan
if appropriate, and application fee of $2,000. If the application is one for a nonroutine well, a
well not in conformity with given spacing or location requirements, it should also include a lease
763 Id. 764 Id. § 377.28(1). 765 Fla. Admin. Code Ann. r. 62C-26.003, 008 (2010). 766 Fla. Stat. § 377.2411(2010); see also id. § 377.243(1). 767 Id. § 377.243(1). 768 Id. § 377.243(2). 769 Id. § 377.24(2) (2010).
151
map or document and letter of justification.770 If the Department has any of these items on file,
they may be included by reference.771 The application will be considered incomplete until the
applicant also has requested a “preliminary site inspection” to be made by the Department.772
No permit may be given to allow for the drilling of an oil or gas well on certain coastal locations
or within corporate municipalities. 773 Permits will be valid for one year from the date of
approval and may be extended for up to one year for an additional fee of $1,000.774
After obtaining a permit to drill, the operator must give written notice by certified mail,
return receipt requested, of the proposal to drill to all those mineral owners both who hold a
minority interest and who are either unleased mineral owners or owners of minerals leases who
have not entered farmout agreements or other like agreement to drill with the operator.
775 This
notice must include an offer to participate for a pro rata share of costs or to lease or farm out its
right in the drilling unit.776 However, the bonus and royalty amounts included in the offer may
not be less than a $26-per-acre one-time bonus and a one-eighth royalty.777 This notice must be
given at least 60 days before drilling the well.778
Notified owners have 30 days after receipt of notice to respond in writing. Otherwise,
they will be deemed a “carried owner.”
779 Carried owners do not receive revenue until the
applicant and its partners in the joint venture have been paid from production for an amount
equal to 300 percent of the actual costs of drilling, developing, and producing the well. 780
770 Fla. Admin. Code Ann. r. 62C-26.003(3) (2010).
771 Id. 772 Id. r. 62C-003(4). 773 Fla. Stat. § 377.24(5)–(9) (2010). 774 Fla. Admin. Code Ann. r. 62C-26.003(1) (2010). 775 Fla. Stat. § 377.2411(1)(a) (2010). 776 Id. § 377.2411(1)(b). 777 Id.; see also id. § 377.247(2). 778 Id. § 377.2411(1)(c). 779 Id. § 377.2411(2)(a). 780 Id. § 377.2411(2)(b).
152
Carried owners are entitled to an annual accounting of the amount still owing to the operators.781
If the mineral owner is the State, these provisions do not apply.782
Further, operating permits are necessary for each well not plugged and abandoned to
authorize operators to use them for their intended purpose, i.e., to produce oil or gas; these
permits should be obtained during the testing phase.
783 Every five years, the Department
conducts a field inspection of the well and operating permit to verify compliance.784 Every
application and re-certification for operating permits must include the following: Form 14, the
Application for Permit to Operate Well; application fee of $2,000; continued or revised bond or
security coverage; new or updated Spill Prevention and Clean Up Plan; new or updated Flowline
specifications and installation plan; and Secondary Containment Facility Certification, if not
already on file and current.785 Further, the Department will not issue an operating permit unless
all reporting and data submission requirements have been met, which include the following:
Well Record with driller’s log, Well Completion Report, Monthly Well Production and Test
Report, Monthly Injection Well Report, and copies of all mud logs, well logs, samples, cores,
core analysis reports, and directional surveys.786
The Division may deny any application for just and lawful cause.
787
(1) The nature, character and location of the lands involved; whether rural, such as farms, groves, or ranches, or urban property vacant or presently developed for residential or business purposes or are in such a location or of such a nature as to make such improvements and developments a probability in the near future.
The Division must
base its decision of whether to issue a permit on consideration of the following criteria:
781 Fla. Stat. § 377.2411(2)(c) (2010). 782 Id. § 377.2411(2)(d). 783 Fla. Admin. Code Ann. r. 62C-25.006(2) (2010); see also id. r. 62.26.008(1). 784 Id. r. 62C-25.006(2). 785 Id. r. 62C-26.008(3). 786 Id. r. 62C-26.008(4). 787 Fla. Stat. § 377.24(4) (2010).
153
(2) The nature, type and extent of ownership of the applicant, including such matters as the length of time the applicant has owned the rights claimed without having performed any of the exploratory operations so granted or authorized. (3) The proven or indicated likelihood of the presence of oil or gas or related minerals in such quantities as to warrant the exploration and extraction of such products on a commercially profitable basis.788
The board
789 will establish a drilling unit or units for each pool in order to prevent waste
and to avoid drilling unnecessary wells.790 A drilling unit is the “maximum area in a pool which
may be efficiently and economically drained by one well.”791 The Division, as previously noted,
has the authority to integrate interests “when two or more separately owned tracts are embraced
within an established drilling unit.”792 If the owners agree to pool their interests within the
drilling unit, they may do so voluntarily. 793 If pooling does not take place voluntarily, the
Division will require such integration in the prevention of waste and to avoid the drilling of
unnecessary wells.794 If the Division is found to lack the authority to require integration, the
owners may each drill on their respective tracts subject to a limitation on production allowing
each owner to produce only the proportion of the allowable for the whole drilling unit as the tract
bears to the full drilling unit.795 Also, the Oil and Gas Statute provides that the Department may
determine that an entire field or any pool or pools or portions thereof may need to be operated as
a unit.796
Although the Florida Oil and Gas Statute does not explicitly call for a hearing prior to
integration of interests or orders of unit operation, the Florida Administrative Code’s
788 Id. § 377.241. 789 This is a body not defined by statute; presumably the “Division” is intended. 790 Id. § 377.25(2). 791 Id. 792 Id. § 377.27(1). 793 Id. 794 Id. 795 Id. § 377.27(2). This provision appears to be in place as a safety feature in the statute. 796 Id. § 377.28(1).
154
Administrative Procedure Act provides a procedure for “decisions which affect substantial
interests,” applicable to all proceedings in which substantial interests of a party are determined
by an agency. 797 That section says that, unless otherwise agreed, section 120.57(2) of the
Administrative Code applies to all cases.798 Section 120.57(2) requires that affected persons be
afforded reasonable notice of agency action, whether proposed or already taken, with a summary
of the grounds upon which that action rests; the option to present evidence in opposition to the
action or to otherwise challenge the action; and a written explanation within seven days.799
Parties’ notice must include information that an administrative hearing or judicial review may be
had and should indicate the procedure to obtain such review.800
Petitions or requests for hearings should be filed with the “agency,”
801 which can be
defined as the Department.802 All parties are entitled to reasonable notice of not less than 14
days, which notice requirement may be waived. 803 If not waived, notice must include a
statement of (1) the time, place, and nature of the hearing and (2) a statement of the legal
authority and jurisdiction under which the hearing will be held.804 Besides requirements adopted
specifically by law, the petition or request for hearing must be signed by the party or the party’s
attorney805
(a) The identification of the petitioner.
and must include the following:
(b) A statement of when and how the petitioner received notice of the agency’s action or proposed action. (c) An explanation of how the petitioner’s substantial interests are or will be affected by the action or proposed action.
(d) A statement of all material facts disputed by the petitioner or a statement that there are no disputed facts. (e) A statement of the ultimate facts alleged, including a statement of the specific facts the petitioner contends warrant reversal or modification of the agency’s proposed action. (f) A statement of the specific rules or statutes that the petitioner contends require reversal or modification of the agency’s proposed action, including an explanation of how the alleged facts relate to the specific rules or statutes. (g) A statement of the relief sought by petitioner, stating precisely the action petitioner wishes the agency to take with respect to the proposed action.806
Upon receipt of notice in proper conformity with the above requirements, the agency may
dismiss it as having an incurable defect; promptly give notice to all parties of action taken on the
petition, including particular reasons if not granted; or refer to the Division for the assignment of
an administrative law judge.
807 A final order must be in writing and include finding of facts and
conclusions of law separately; it also should be rendered within 90 days after the hearing, if
conducted by the agency; after a recommended order is submitted to the agency and mailed to all
parties, if conducted by an administrative law judge; or after the agency has received all material
it has authorized to be submitted, if no hearing was conducted.808
Orders requiring integration and pooling must be on just and reasonable terms and must
afford the owners of each tract the opportunity to obtain the tract’s just and equitable share of
production from the pool.
809
(a) A description of the area embraced, termed the “unit area” and a description of the pool or pools, or portions thereof, affected and lying within the unit area.
Orders for unit operation must be fair and reasonable, must protect
the rights of interested parties, and must include the following:
(b) A statement of the nature of the operations contemplated.
(c) A method of allocation among the separately owned tracts in the unit area of all the oil or gas, or both, produced from the unit pool within the unit area and not required in the conduct of such operation or unavoidably lost, such method of allocation to be on a formula that is fair and equitable and that will protect the correlative rights of all interested parties. (d) A provision for adjustment among the owners of the unit area (not including royalty owners) of their respective investments . . . attributable to the unit operations. . . . The adjustment provided for herein may be treated separately and handled by agreements separate from the unitization agreement. (e) A provision that the costs and expenses of unit operation, including investment, past and prospective, be charged to the separately owned tracts in the same proportions that such tracts share in unit production. The expenses chargeable to a tract shall be paid by the person not entitled to share in production free of operating costs and who, in the absence of unit operation, would be responsible for the expenses of developing and operating such tracts, and such person’s interest in the separately owned tract shall be primarily responsible therefor. The obligation or liability of such persons in the several, separately owned tracts for the payment of unit expense shall at all times be several, and not joint or collective. . . . (f) The designation of, or a provision for the selection of, a unit operator. . . . (g) A provision that when the full amount of any charge made against any interest in a separately owned tract is not paid when due by the person or persons primarily responsible therefor, then all of the oil and gas production allocated to the interest in default in such separately owned tract, upon which operator has a lien, may be appropriated by the unit operator and marketed and sold for the payment of such share, together with interest at a rate of six percent (6%) per annum. The remaining portion of the unit production, or the proceeds derived therefrom, allocated to each separately owned tract shall in all events be regarded as royalty to be paid to the owners, free and clear of all unit expense and free and clear of any lien therefor. . . . (h) The time the unit operation shall become effective and the manner in which, and the circumstances under which, the unit operation shall terminate.810
Owners of fractional undivided mineral interests in lands subject to permits are entitled to
their pro rata share of the earnings after costs of exploration and operation have been
810 Id. § 377.28(3).
157
allocated.811 When operators cannot find the owner of the minority mineral interest in a drilling
unit after reasonable attempts to locate that owner, the operator may call for the Department to
act as the receiver for that party. Unlocated owners are entitled to the one-time bonus payment
of $26 per acre and one-eighth production royalty.812
The orders requiring unit operations are not effective until the unitization agreement is
ratified or approved in writing by the owners of at least 75 percent of the cost allocation and by
75 percent of the holders of production allocated to royalty owners.
813 A party potentially could
be responsible for both cost and also be a holder of royalty interest. If that is the case, the party
may cast their vote as one or the other, but not as both. For example, if such party votes its cost
allocation percentage toward the 75 percent required approval, that party’s percentage interest as
a royalty holder will be excluded when calculating the percentage of consenting and non-
consenting royalty holders.814 Additionally, parties responsible for at least 75 percent of the
costs must ratify a contract incorporating the operation arrangements.815 If the required approval
does not take place within six months of the order date, or within a department-granted extension
period, the order is automatically revoked.816
Additionally, the Board may amend or add to orders providing for unit operations by
entering a new order or by amending an order, and production should then be reallocated among
the tracts.
817 No order that changes the percentage of oil and gas allocated to each separately
owned tract is retroactive.818
811 Id. § 377.245.
Orders that extend or add to an existing unit area are only effective
upon whether they are drilled to a depth of greater than or less than 7,000 feet.851 Additionally,
horizontal wells have their own spacing rules. Routine drilling units are based on the U.S.
Government Surveyed Township and Range system, which will be used to space wells. 852
Routine drilling units should be shaped so that the diagonals lie completely within the unit, the
length of the longest diagonal not to exceed 125 percent “of the length of a diagonal of a square
containing the same number of acres as the unit.”853
Each well should be drilled roughly in the center of a drilling unit unless the Division
determines that conditions require otherwise.
854 The surface location is determined by the
surface conditions, and wells should be placed where they cause the least amount of surface
disturbance and where they do not cause other environmental issues.855 For wells with a bottom
hole location that is not in conformity with the spacing requirements in Administrative Code
section 62C-24.004, and if the location was not approved as a condition of the drilling permit, a
well is considered to be in a nonroutine location and the operator must apply for a nonroutine
location as provided in the rules.856 The Department may grant drilling permits that allow for
less distance between unit boundaries when it is necessary.857
To apply for a permit for nonroutine wells or drilling units, the applicant should include
the names and addresses of all “substantially affected parties (offsetting mineral-interest owners,
operators, and lessees).”
858
851 Id. r. 62C-26.004(2)-(6).
The Department should base the determination of whether to grant
the nonroutine well or unit on whether doing so is necessary to prevent waste or to protect
852 Id. r. 62C-26.004(3). 853 Id. r. 62C-26.004(3)(b). 854 Fla. Stat. § 377.25(3) (2010). 855 Fla. Admin. Code Ann. r. 62C-26-004(4) (2010). 856 Id. r. 62C-26-004(4)(c). 857 Id. r. 62C-26.004(6). 858 Id. r. 62C-26.004(6)(a).
164
correlative rights.859
(24) DRILLING UNIT shall mean the block of land surrounding and assigned to a particular well and into which no other like well may be completed.
For purposes of this section, the Florida Administrative Code provides the
following pertinent definitions:
(31) HORIZONTAL WELL shall mean any well within a horizontal or nearly horizontal borehole within the production interval. (38) NONROUTINE DRILLING UNIT shall mean any drilling unit composed of unsurveyed land not divided into townships and sections, composed of irregular townships and sections, or composed of odd sized lots other than 40, 160, or 640 acres. (39) NONROUTINE SPACING shall mean that the required amount of land surrounding an oil or gas well is uncommon in its size, shape, etc., and does not conform to 62C-26.004(1) through (4). (45) ROUTINE DRILLING UNITS are those units based on U.S. Government surveyed township and range lines and, for oil wells, are quarter-quarter or quarter sections (depending on well depth) and for gas wells of any depth, full sections. (46) ROUTINE LOCATION OR WELL shall mean an oil or gas well whose bottom hole position complies with 62C-26.004(4). A routine oil well drilled to a depth of less than 7,000 feet has a bottom hole position no closer than 460 feet to the nearest drilling unit boundary while an oil well drilled to a greater depth has a bhp no closer than 920 feet to the nearest drilling unit boundary. A routine gas well of any depth has a bhp no closer than 1360 feet to the nearest drilling unit boundary. (47) ROUTINE SPACING shall mean well spacing based on the U.S. Government Township and Range System as described in 62C-26-004. Routine spacing for oil wells are quarter-quarter sections for wells less than 7,000 feet deep and quarter sections for wells greater than 7,000 feet deep. Gas wells, regardless of depth, are assigned 650 acres.860
[a] Gas Wells.
859 Id. r. 62C-26.004(6)(b). 860 Id. r. 62C-25.002.
165
Exploratory gas wells, regardless of depth, should be located on 640-acre units. All
routine gas test wells or gas condensate wells should have a bottom hole location not closer than
1,320 feet to the nearest drilling unit boundary.861
[b] Oil Wells Less Than 7,000 Feet Deep.
Exploratory oil wells of less than 7,000 feet should be located on 40-acre units.862 All
routine oil test wells drilled above that depth should have a bottom hole location no closer than
460 feet to the nearest drilling unit boundary.863
[c] Oil Wells Greater Than 7,000 Feet Deep.
Exploratory oil wells drilled to a depth of more than 7,000 feet should be located on 160-
acre units.864 All routine oil test wells drilled below that depth should have a bottom hole
location no closer than 920 feet to the nearest unit boundary.865
[d] Horizontal Wells and Associated Drilling Units.
No producing section of a well may be closer than 1,840 feet to another productive
well.866 All 10-acre blocks whose nearest boundary is within 920 feet of the productive section
of a horizontal well needs to be included in the unit.867 If a horizontal well with productive
sections penetrates within the 400-foot square in the center of a routine drilling unit, that well
should include the entire 160-acre unit. The special requirements for nonroutine drilling units
also apply to horizontal wells.868
[3] – Minimum Operator Control.
861 Id. r. 62C-26.004(4)(b). 862 Id. r. 62C-26.004(2). 863 Id. r. 62C-26.004(4)(a). 864 Id. r. 62C-26.004(2). 865 Id. r. 62C-26.004(4)(a). 866 Id. r. 62C-26.004(5)(a). 867 Id. r. 62C-26.004(5)(b). 868 Id. r. 62C-26.004(5)(f).
166
Unit operations orders do not become effective until the unitization agreement is ratified
or approved in writing by the owners of at least 75 percent of the cost allocation and by 75
percent of the holders of production allocated to royalty owners.869 If a party is responsible for
costs and also a royalty interest holder, the party may cast its vote as one or the other type of
interest holder, but not as both. For example, if the party votes its cost allocation percentage
toward the 75 percent required approval, that party’s percentage interest as a royalty holder will
be excluded when calculating the percentage of consenting and non-consenting royalty
holders.870 Additionally, parties responsible for at least 75 percent of the costs must ratify a
contract incorporating the operation arrangements.871 If the required approval does not take
place within six months of the order date, or within a department-granted extension period, the
order is automatically revoked.872
The Board may amend or add to orders providing for unit operations by entering a new
order or by amending an order, and production should then be reallocated among the tracts.
873
No order that changes the percentage of oil and gas allocated to each separately owned tract will
be retroactive.874 Orders that extend or add to an existing unit area are only effective upon
ratification by the appropriate percentage, given above, of interested parties in the tracts to be
added.875
[4] – Directional Drilling.
The statute provides a definition of horizontal well, which is “a well completed with the
wellbore in a horizontal or nearly horizontal orientation within 10 degrees of horizontal within
the producing formation.”876 The Administrative Code gives a slightly different definition: “any
well within a horizontal or nearly horizontal borehole within the productive interval.”877
The rules provide regulations for the drilling units and spacing of horizontal wells.
Specifically, no producing section of a horizontal well may be within 1,840 feet of another
productive well.
878 All 10-acre blocks within the 160-acre routine drilling unit whose nearest
boundary is within 920 feet of the productive section of a horizontal well is to be included in the
unit. Those wells with productive sections that penetrate the 400-foot square in the center of a
routine drilling unit will include the entire 160-acre unit.879 The rules also request that horizontal
wells should be unitized as soon as possible after testing is finished.880 A Directional survey
should be taken from the surface casing shoe to full depth to be filed with the Oil and Gas
Administrator within 30 days.881 The Oil and Gas Administrator is “the State Geologist and
Chief of the Florida Geological Survey.”882 Finally, the special nonroutine drilling unit and well
requirements apply to horizontal wells.883
[5] – Options.
Any operator who has gotten a permit to drill must give notice to owners holding a
minority interest within the drilling unit and who are: (1) unleased; or (2) owners of mineral
leases which have not entered into a farmout agreement or any other agreement to drill or
produce with the operator.884
876 Id. § 377.19(25).
The notice must include an offer to allow the owner to participate
in its pro rata share of costs of drilling or to lease or farm out its interest. The notice must
877 Fla. Admin. Code Ann. r. 62C-25.002(31) (2010). 878 Id. r. 62C-26.004(5)(a). 879 Id. r. 62C-26.004(5)(b). 880 Id. r. 62C-26.004(5)(c). 881 Id. r. 62C-26.004(5)(e). 882 Id. r. 62C-25.002(1). 883 Id. r. 62C-26.004(5)(f). 884 Fla. Stat. § 377.2411(1)(a) (2010).
168
include the bonus and royalty as previously noted.885 The notified owner has 30 days to make
The Board of Natural Resources (“Board”) is a Constitutional Board that is empowered
by the legislature with specific authority to regulate pooling of oil and gas resources in the
state.887
[2] – Membership on the Governing Body.
The Board, which is appointed by the Governor of Georgia and subject to approval by the
State Senate, consists of a total of eighteen members. There is one member from each
congressional district in Georgia and five members from the state at large, one of whom must be
from one of the following counties: Chatham, Bryan, Liberty, McIntosh, Glynn, or Camden.
The members will each serve a term of seven years and shall represent all areas and functions
encompassed within the Department of Natural Resources (DNR). 888
[3] – Scope of Authority.
The Board shall have authority to make such inquiries as it may deem necessary into any
matter over which it has jurisdiction and to adopt and promulgate rules and regulations.889
(1) protect the health, safety and welfare of the citizens of Georgia by requiring that adequate protection of underground fresh water supplies be assured in any drilling operation which may penetrate through any strata which contains fresh water;
The
purpose of these rules is to establish the administration and enforcement procedures of the
Georgia Oil and Gas and Deep Drilling Act of 1975 (“Act”), as amended, and to carry out the
purposes and requirements of the Act. These rules are promulgated in order to:
(2) protect environmentally sensitive areas; and (3) encourage oil and gas exploration to identify new sources of energy.890
887 Ga. Const. art. IV, § VI.
888 Id. 889 Ga. Code Ann. §§ 12-4-43(1), (4) (2010). 890 Ga. Comp. R. & Regs. 391-1-1-.01 (2010).
170
The Board has jurisdiction and authority over the drilling of and subsequent use of any
exploration, production, or storage well.891
(1) the drilling of and subsequent use of any exploration or production oil or gas well;
This includes, but is not limited to, jurisdiction and
authority for:
(2) any exploration or production well that is drilled to a depth of 1,800 feet for any other mineral; (3) any exploration or production well drilled to a depth sufficient to interfere with the fresh-water aquifer system in an environmentally sensitive area of the coastal zone; (4) any underground storage well that is used for disposal of waste; (5) any fresh water production well drilled deeper than 1,800 feet; and, (6) any salt water or brine exploration or production well.892
The Board has the authority to establish drilling units and operation units, and to allocate
production within a drilling unit.
893 Additionally, the Board has the power to integrate drilling
units to prevent waste.894
(1) the inefficient, excessive or improper use or dissipation of reservoir energy;
Waste, in addition to its ordinary meaning, means “physical waste” as
that term is generally understood in the oil and gas industry. It shall include, but is not limited
to:
(2) the locating, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner which results or tends to result, in a reduction in the quantity of oil or gas ultimately to be recovered from any pool in this State; (3) the inefficient storing of oil; (4) the locating, spacing, drilling, equipping, operating or producing of any oil or gas well or wells in a manner causing, or tending to cause, unnecessary or excessive surface loss or destruction of oil or gas; (5) abuse of the correlative rights and opportunities of each owner of gas or oil in a common reservoir due to nonuniform,
disproportionate and unratable withdrawals causing undue drainage between tracts of land; (6) the production of oil or gas in such a manner as to cause unnecessary water channeling or zoning; (7) the operation of any oil well or wells with an inefficient gas-oil ratio; (8) the drowning with water of any stratum of part thereof capable of producing gas or oil, except where approval of such a project has been granted by the Director; (9) underground waste, however caused and whether or not defined as the same relates to any activity regulated by the provisions of these Rules; (10) the creation of unnecessary fire hazards as the fire relates to any activity regulated by the provisions of these Rules; (11) the escape into the open air, from a well producing both oil and gas, of gas in excess of the amount which is necessary in the efficient drilling or operation of the well; and, (12) permitting gas produced from a gas well to escape into the air, except for testing.
To fulfill the duty of waste prevention, the Board has the authority to: (1) investigate; (2)
hold a hearing; (3) grant reasonable and practicable drilling unit and operation unit orders after
notice and hearing; and (4) grant a new or amended operational unit order.895
The Board has authority to adopt and promulgate rules and regulations dealing with the
control of matters over which it has jurisdiction as above stated. Such rules and regulations shall
include, but are not limited to, rules and regulations for, among others, the following purposes:
(1) to require the making of reports showing the location of all wells regulated under this part, including the filing of drill cutting samples, cores, and copies of all logs, and to further require that the operator submit the name classification used for each of the subsurface formations penetrated and the depth at which each such formation was penetrated; (2) to prevent fires, waste, and spillage as same relates to any activity regulated by the provisions of this part; (3) to identify the ownership of all oil or gas wells, producing leases, refineries, tanks, plants, structures, and all storage and transportation equipment and facilities; (4) to limit and prorate the production of oil or gas, or both, from any pool or field for the prevention of waste;
895 Id. § 12-4-45.
172
(5) to regulate the spacing of wells and to establish drilling units; (6) to prevent, insofar as is practical, avoidable drainage from each developed unit which is not equalized by counter drainage; (7) to require that accurate records be kept on forms to be prescribed by the director, which records shall be reported to the director within the time specified in such rules and regulations. The reports shall include such information as the director may prescribe, including, but not limited to, information concerning cuttings, subsurface samples, and lithologic and geophysical logs; (8) to require that geologic and testing information obtained from a well regulated under this part be held in confidence by the director for a period of at least six months from the time of drilling to total depth, or, if the director approves, a longer period, if the operator makes a written request for the same stating the length of the extension desired and the reasons therefore. This will only be grant if the guarantee of confidentiality provided for in this paragraph shall in no way impair the ability of the board or the director to enforce this part; (9) to regulate the issuance, denial, and revocation of permits and to regulate bonds required under this part, except to persons found to have violated any provision, rule or regulation, or any order or permit; (10) to regulate the issuance of permits to persons who have been found to have violated any provision of this part, any rule or regulation adopted and promulgated pursuant to this part, or any order or permit issued under this part, and to establish the amount of bond for such persons; (11) to regulate the cooperative development or operation of all or part of an oil or gas pool as a unit; (12) to regulate the underground storage or disposal of substances other than those substances covered by The Underground Gas Storage Act.896
Lastly, the Board has authority, subject to the Governor’s approval, to appoint and
remove the Commissioner of Natural Resources (“Commissioner”) and the Director of the
Environmental Protection Division (“Director”).
The Commissioner has the authority to supervise, direct, account for, plan, administer
and execute all the respective statutory functions of the DNR and the Divisions, including the
Environmental Protection Division. The Commissioner has authority, subject to the approval of
896 Id. § 12-4-48.
173
the Board, to appoint the director of the remaining DNR Divisions: Wildlife Resources; Parks,
Recreation and Historic Sites; Coastal Resources; Pollution Prevention Assistance; Historic
Preservation; and Program Support. 897
The Director of the Environmental Protection Division supervises, directs, accounts for,
organizes, plans and enforces the rules and regulations made by the Board under the Act.
898 The
Director may have the power, if delegated to him, to consider and issue permits to drill wells and
to establish drilling and operation units. 899
[4] – Process for Pooling and Matters Covered.
[a] Authority to Integrate Production.
All drilling units and operating units, whether ordered by the Board or created by
voluntary agreement among owners and operators, are established to: (1) conserve gas and/or oil;
(2) prevent waste; (3) ensure the ultimate hydrocarbon recovery; and (4) avoid the drilling of
unnecessary wells. 900 The owners, operators, and royalty owners who have separate holdings in
the same oil or gas pool or in any area that appear from geological or other data to be in the same
reservoir can voluntarily agree to enter into and carry out a cooperative development, and
operation plan, of the pool or area. 901 More specifically, when two or more separately owned
tracts of land are contained within an established drilling unit, the owners may voluntarily agree
to combine or integrate their tracts or interests for the development or operation of that drilling
However, if the owners have not agreed to integrate their interests, the Director may enter
an order that requires the owners to integrate all tracts and interests in the drilling unit.903 All
orders requiring integration of drilling units are subject to the Director’s discretion of what is
reasonable and practicable. 904
The allowable production on the single owner’s tract or tracts is limited in proportion of
those tracts to the full drilling unit.
If the Director does not have the authority to require integration
and there is no owner agreement, then each owner embraced within the drilling unit may drill on
his own tract.
905 Thus, the reservoir will not be fully drained, which
effectively reserves the non-agreeing owners’ rights to drill and produce proportionately on their
respective tracts. The Director will then allocate the production of the unit and, after an
investigation and hearing, must afford the owner and/or producer of each tract or interest in the
drilling unit the opportunity to use its just and equitable share of the reservoir energy.906 As an
alternative to a drilling unit, the Director shall, after discovery of an oil and gas pool and after
due investigation and a hearing, establish operation units.907
The plan for a drilling unit, voluntarily agreed upon by an owner or operator, or both
must be submitted to the Board for approval.
908 The plan may be mailed to the Director. 909
903 Id.
The need of a petition for approval of a drilling unit involuntarily formed or any further
information on a petition for approval of a plan is not provided in the Act, in DNR’s rules and
regulations, or in Georgia’s Administrative Procedure Act.
904 Id. 905 Id. § 12-4-45(a)(1). 906 See Ga. Dep’t of Natural Res. Rules and Regs. § 391-3-13.06. 907 Id. 908 Ga. Code Ann. § 12-4-45(b). 909 See Ga. Dep’t of Natural Res. Rules and Regs. § 391-1-1.04(d).
175
The Board shall have power, after notice and hearing, either to approve or to disapprove
the drilling unit agreement(s) made between owners or operators, or both. 910
After the Director has concluded a hearing, he may grant an order for a drilling unit or
operation unit to the owners or the operators. To grant an operation unit order, the Director must
find that the unit operation is necessary to prevent waste or to increase ultimate recovery of oil or
gas by additional recovery methods and that the estimated additional cost, as a result of the unit
operation, will not be more than the estimated value of the additional recovery of oil or gas.
Additionally, the
Board shall have the power, after due investigation and a hearing, to grant an order to the owners
or operators, or both, for an operation unit. The procedure that the Board must follow when
conducting a hearing is not discussed in the Act, in DNR’s rules and regulations, or in Georgia’s
Administrative Procedure Act.
911
All orders for unit operation must be fair and reasonable and must protect the rights of all
interested parties.912
The order requiring unit operation must include:
1) a description of the unit area; 2) a description of the pool or pools affected and lying within the unit area; 3) a statement of the nature of the operations contemplated; and 4) a fair and equitable formula, which will protect the correlative rights of all interested parties, for the allocation of oil or gas, or both, among the separately owned tracts in the unit area.913
If at any time the contribution of a separately owned tract with respect to any unit pool
has been established, such contribution can not be altered except to correct mathematical errors
or clerical errors.
914
910 Ga. Code Ann. § 12-4-45(b).
The order shall contain a provision requiring the costs and expenses of unit
operations, including investments, past and prospective, to be charged to the separately owned
automatically be revoked. If this six month window passes without a signed agreement, the
Board may extend the time period past six months to fulfill the required provisions.922
[6] – Royalty Distribution.
The Act or DNR’s rules and regulations do not specify the royalty interest to be received
by the mineral interest owner or the producer.
§ 11.02 Types of Georgia Pooling Statutes. [1] – Mineral Distinctions. In Georgia, a mineral means any naturally occurring substance found in the earth, which
has commercial value; mineral includes oil and gas, but not fresh water. Gas is defined as all
natural gas, including casing head gas, and all other hydrocarbons not defined as oil.923 Oil is
defined as crude petroleum oil and other hydrocarbons, regardless of gravity, which are produced
at the well in the liquid form by ordinary production methods and which are not the result of
condensation of gas after it leaves the reservoir.924 Further, a pool is defined as an underground
reservoir containing an accumulation of crude petroleum or natural gas, or both. The term pool
also covers each zone of a general structure which is completely separated from any other zone
in the structure. 925 Moreover, a field is defined as the general area that is underlaid or appears to
be underlaid by at least one pool; a field includes the underground reservoir or reservoirs
containing crude petroleum oil or natural gas, or both. A field may relate to two or more pools;
and field and pool mean the same thing when only one underground reservoir is involved.926
[2] – Split by Depth.
There is no mention of coalbed methane in the Georgia pooling statutes.
over all persons and property necessary for that purpose.973 In the event of a conflict, the duty to
prevent waste is paramount.974 The Commission is authorized to make such investigations as it
deems proper to determine whether action by the Commission is necessary.975
(1) identification of ownership of oil or gas wells, producing leases, tanks, plants, structures, and facilities for the transportation or refining of oil and gas;
Without limiting
its general authority, the Commission has the specific authority to require the following:
(2) the taking and preservation of samples and the making and filing with the Commission of true and correct copies of well logs and directional surveys both in form and content as prescribed by the Commission; provided, however, that logs of exploratory or wildcat wells marked confidential shall be subject to disclosure according to chapter 3, title 9, Idaho Code; (3) the drilling, casing, operation and plugging of wells in such manner as to prevent the escape of oil or gas out of one (1) pool into another; the detrimental intrusion of water into an oil or gas pool that is avoidable by efficient operations; the pollution of fresh water supplies by oil, gas, or salt water; blow-outs, cavings, seepages, and fires; and waste; (4) the taking of tests of oil or gas wells; (5) the furnishing of a reasonable performance bond with good and sufficient surety, conditioned upon the performance of the duty to comply with the requirements of this law and the regulations of the Commission with respect to the drilling, maintaining, operating, and plugging of each well drilled for oil or gas; (6) that the production from wells be separated into gaseous and liquid hydrocarbons, and that each be measured by means and upon standards that may be prescribed by the Commission; (7) that wells not be operated with inefficient gas-oil or water-oil ratios, and to fix these ratios, and to limit production from wells with inefficient gas-oil or water-oil ratios; (8) metering or other measuring of oil, gas, or product; (9) that every person who produces oil or gas in the state keep and maintain for a period of five (5) years complete and accurate records of the quantities thereof, which records, or certified copies thereof, shall be available for examination by the Commission or its agents at all reasonable times within said period, and that every such person file with the Commission such reasonable reports as it may prescribe with respect to such oil or gas production;
973 Id. 974 Id. 975 Id. § 47-319(c).
188
(10) the filing of reports of plats with the Commission that it may prescribe.976
The Commission also has authority to regulate the drilling and plugging of wells and all
other operations for the production of oil or gas; the shooting and treatment of wells; the spacing
or locating of wells; operations to increase ultimate recovery, such as cycling of gas, the
maintenance of pressure, and the introduction of gas, water, or other substances into a producing
formation; and the disposal of salt water and oil-field wastes.
977 The Commission can also
classify and reclassify pools as oil, gas, or condensate pools, or wells as oil, gas, or condensate
wells and has authority to make and enforce rules, regulations, and orders reasonably necessary
to prevent waste, protect correlative rights, to govern the practice and procedure before it.978
[4] – Process for Pooling.
Anyone who wants to drill a well must first notify the Commission and obtain a
permit.979 No permit may be issued by the Commission until it has notified the Director of the
Department of Water Resources, who has 15 days from the date of receipt of such notification to
recommend conditions he believes necessary to protect fresh water supplies.980 Upon issuance
of any permit, a copy thereof, including any limitations, conditions, controls, rules, or regulations
attached thereto for the protection of fresh water supplies, shall be forwarded to the Director of
the Department of Water Resources.981
The Commission may act upon its own motion, or upon the petition of any interested
person.
982
976 Id. § 47-319(d).
On the filing of a petition for a hearing concerning any matter within the jurisdiction
“Oil” means “crude petroleum oil and all other hydrocarbons, regardless of gravity, that
are produced in liquid form by ordinary production methods, but does not include liquid
hydrocarbons that were originally in a gaseous phase in the reservoir.”1002 “Gas” means “all
natural gas and all other fluid hydrocarbons not hereinabove defined as oil, including condensate
because it originally was in the gaseous phase in the reservoir.”1003
[2] – Split by Depth.
Idaho law does not appear to differentiate based upon depth.
[3] – Spacing Rules.
In the absence of an order by the Commission setting spacing units for a pool, the
following default rules apply:
[a] Spacing Units—Oil.
Every well drilled for oil must be located in the center of a 40-acre governmental quarter
section, lot or tract, or combination of lots or tracts substantially equivalent thereto as shown by
the most recent governmental survey, with a tolerance of 200 feet in any direction from the
center location; provided that no oil well shall be drilled less than 920 feet from any other well
drilling to or capable of producing oil from the same pool, or no oil well shall be completed in a
known pool unless it is located more than 920 feet from any other well completed in and capable
of producing oil from the same pool.1004
[b] Spacing Units—Gas.
Every well drilled for gas must be located on a drilling unit consisting of approximately
640 contiguous surface acres, which shall be one governmental section or lot(s) equivalent
thereto, upon which there is not located, and of which no part is attributed to, any other well
1002 Idaho Code Ann. § 47-318(e) (2010). 1003 Id. § 318(f). 1004 Idaho Admin. Code r. 20.07.02.330.01(2010).
193
completed in or drilling to the same pool. In areas not covered by United States Public Land
Surveys, a drilling unit must:
(1) be bounded by four sides intersecting at angles of not less than 85 degrees or more than 95 degrees; (2) be such that the distance between two points farthest apart thereon shall not exceed 8,500 feet; and, (3) contain at least 600 contiguous surface acres.
In areas covered by United States Public Land Surveys, such drilling unit shall consist of one
governmental section containing not less than 600 surface acres. Each well drilled for gas shall
be located within a square, each side of which is one 1,660 feet in length and parallel to a center
line of the section. The center of such square shall coincide with the geometric center of the
section.1005
[c] Well Locations Adjacent to Spaced Areas.
The Commission shall have the discretion to determine the pattern location of wells
adjacent to an area spaced by the Commission, or under application for spacing where there is
sufficient evidence to indicate that the pool or reservoir spaced or about to be spaced may extend
beyond the boundary of the spacing order or application, and the uniformity of spacing patterns
is necessary to insure orderly development of the reservoir pool.1006
[d] Exceptions to Spacing Orders.
Upon proper application, the Director may approve, as an administrative matter, an
exception to the above spacing requirements or any order of the Commission establishing well
spacing for a pool.1007 If for any reason the Commission fails or refuses to approve such an
exception, the Director may, after notice and hearing, grant the exception.1008
1005 Id. r. 20.07.02.330.02.
1006 Id. r. 20.07.02.330.03. 1007 Id. r. 20.07.02.330.04. 1008 Id.
194
The application for an exception shall state fully the reasons why such an exception is
necessary or desirable and shall be accompanied by a plat showing: the location at which an oil
or gas well could be drilled in compliance with the rule, above, or the applicable order; the
location at which the applicant requests permission to drill; and the location at which oil or gas
wells have been drilled or could be drilled, in agreement with the provisions above or the
applicable order, directly or diagonally offsetting the proposed exception.1009 No exception will
prevent any owner from drilling an oil or gas well on adjacent lands, directly or diagonally
offsetting the exception, at locations permitted by applicable Commission rule or order.1010
[4] – Size.
The size of spacing units shall not be smaller than the maximum area that can be
efficiently and economically drained by one well; provided, that if, at the time of a hearing to
establish spacing units, there is not sufficient evidence from which to determine the area that can
be efficiently and economically drained by one well, the Commission may make an order
establishing temporary spacing units for the orderly development of the pool pending the
obtaining of the information required to determine what the ultimate spacing should be.1011
Except where circumstances reasonably require, spacing units shall be of approximately uniform
size and shape for the entire pool.1012 The Commission may establish spacing units of different
sizes or shapes for different parts of a pool or may grant exceptions to the size or shape of any
spacing unit or units or may change the sizes or shape of one or more existing spacing units.1013
[5] – Minimum Operator Control.
1009 Id. 1010 Id. r. 20.07.02.330.04(c). 1011 Idaho Code Ann. § 47-321(b) (2010). 1012 Id. § 47-321(c). 1013 Id.
195
Idaho law appears not to contain a provision requiring approval of operators or royalty
interest holders prior to unitization.
[6] – Directional Drilling.
The maximum point at which a well penetrates the producing formation shall not
unreasonably vary from the vertical drawn from the center of the hole at the surface. 1014
Deviation is permitted without special permission to remedy blowouts and, for short distances, to
straighten the hole, sidetrack junk, or correct other mechanical difficulties.1015
Except for the purposes recited above, no well drilled may be intentionally directionally
deviated from the vertical unless the operator first files an application and obtains a permit from
the Commission.
1016 Such an application shall contain the following information: Name and
address of the operator; lease name, well number, name of field and reservoir and county;
description of surface location and proposed location of the producing interval (footage from
lease and section or block and survey lines); reason for intentional deviation; list of offset
operators and statement that each has been furnished a copy of the application by registered mail;
signature of representative of operator; notification to offset operators that any objection they
may have to the proposed intentional deviation of the well must be filed with the Commission
within fifteen days of receipt of a copy of the application.1017
The application shall be accompanied by a neat, accurate plat or sketch of the lease and
all offset leases showing the names of all offset operators and the surface and proposed
producing interval locations of the well.
1018
1014 Idaho Admin. Code r. 20.07.02.170.01 (2010).
The plat shall be drawn to a scale that permits facile
1015 Id. 1016 Id. r. 20.07.02.170.02. 1017 Id. r. 20.07.02.170.02(a)-(g). 1018 Id. r. 20.07.02.170.02(h).
196
observation of all pertinent data.1019 At the time the application is filed with the Commission, a
copy of the application and the plat shall be forwarded by registered mail to all offset operators
to the lease on which the well is to be drilled.1020 Upon receipt, the Commission will hold the
application for fifteen days.1021
If objection from any offset operator to the proposed intentional deviation is received
within 15 days of receipt of the application, or if the Commission is not in agreement with the
proposed deviation, the application shall be set down for public hearing.
1022 If no objection from
either an offset operator or the Commission is interposed within the fifteen-day period, the
application shall be approved and a permit issued by the Commission.1023 If written consent of
the offset operator(s) is filed concurrently with the application to drill directionally, the
Commission may immediately approve the application without waiting fifteen days.1024
Upon completion, a complete angular deviation and directional survey of the well
obtained by an approved well surveying company shall be filed with the Commission, together
with other regularly required reports.
1025 In the event the proposed, or final, location of the
producing interval of the directionally deviated well is not in agreement with spacing or other
rules of the Commission applicable to the reservoir, proper applications shall be made to obtain
approval of exceptions to such rules. 1026 Such approval shall be granted or denied at the
discretion of the Commission and shall be accorded the same consideration and treatment as if
the well had been drilled vertically to the producing interval.1027
1019 Id.
1020 Id. r. 20.07.02.170.03. 1021 Id. r. 20.07.02.170.04. 1022 Id. 1023 Id. 1024 Id. 1025 Id. r. 20.07.02.170.05. 1026 Id. r. 20.07.02.170.06. 1027 Id.
197
[7] – Options.
Each integration order shall authorize the drilling, equipping, and operation, or operation,
of a well on the spacing unit; shall provide who may drill and operate the well; shall prescribe
the time and manner in which all the owners in the spacing unit may elect to participate therein;
and shall make provision for the payment by all those who elect to participate therein of the
reasonable actual cost thereof, plus a reasonable charge for supervision and interest. 1028 If
requested, each integration order shall provide for one or more just and equitable alternatives
whereby an owner who does not elect to participate in the risk and cost of the drilling and
operation, or operation, of a well may elect to surrender his leasehold interest to the participating
owners on some reasonable basis and for a reasonable consideration which, if not agreed upon,
shall be determined by the Commission, or may elect to participate in the drilling and operation,
or operation, of the well, on a limited or carried basis upon terms and conditions determined by
the Commission to be just and reasonable.1029
If one or more of the owners drill, equip, and operate, or operate, or pay the costs of
drilling, equipping, and operating, or operating, a well for the benefit of another person as
provided for in an order of integration, then those owners or owner shall be entitled to the share
of production from the spacing unit accruing to the interest of that other person, exclusive of a
royalty not to exceed one-eighth of the production, until the market value of the other person’s
share of the production, exclusive of the royalty, equals the sums payable by or chargeable to the
interest of the other person.
1030 If there is a dispute as to the costs of drilling, equipping, or
operating a well, the Commission shall determine such costs.1031
1028 Idaho Code Ann. § 47-322(c) (2010).
In instances where a well is
1029 Id. 1030 Id. 1031 Id.
198
completed prior to the integration of interests in a spacing unit, the sharing of production shall be
from the effective date of the integration, except that, in calculating costs, credit shall be given
for the value of the owner’s share of any prior production from the well.1032
1032 Id.
199
§ 14.01 Analysis of Illinois Regulatory Framework.
[1] – Name of the Governing Body.
The Department of Natural Resources (“Department”) was statutorily created by the
legislature with specific authority to regulate pooling in the state of Illinois.1033 However, the
Director of Natural Resources (“Director”) also appoints the Oil and Gas Board (“Board”) to
advise the Department. The Board acts solely as an advisory body to the Department and its
recommendations have no binding effect on the Department.1034
[2] – Membership on the Governing Body.
The Director, who is appointed by the Governor of Illinois, is charged to appoint a seven-
member Board. Six of the members need to be actively engaged in the oil and gas industry.
When the Director appoints the six members representing the oil and gas industry, he has to give
due consideration to the recommendations of organizations and associations representing the
various interests of the oil and gas industry. With these recommendations in mind, the Director
will appoint individuals in such a manner as to assure the representation of petroleum
engineering, petroleum geology, oil and gas operations and production, and the servicing of oil
and gas operations and production. The final member is appointed by the Director upon
consultation with the Illinois Farm Bureau and must be active in production agriculture.1035
Board members are be appointed to two year terms beginning on the third Monday in
January of odd numbered years, and may be reappointed for additional terms provided that no
member may be reappointed for a term which would cause his continued service to exceed eight
years. Any appointment to fill a vacancy shall be for the unexpired portion of the term. The
1033 225 Ill. Comp. Stat. 725/4 (2010). 1034 Id. at 725/1.2. 1035 Id.
200
Director may remove any member who fails to attend two consecutive meetings of the Board
without sufficient excuse or for any other good cause as determined by the Director.1036
(1) review all federal and State rules and laws affecting the oil and gas industry in Illinois;
The
Board shall meet at least quarterly to:
(2) advise and consult with the Director concerning the adoption of rules pertaining to the conservation of oil and gas; (3) review technical information and operations concerning the improvement of methods, conditions, and equipment for the production of oil and gas; (4) advise and consult with the Director concerning the proper drilling, casing and plugging of oil wells; (5) review the methods and procedures for the issuance of proper permits to drill oil and gas wells; (6) advise and consult with the Director in the administration of the Oil and Gas Well Site Plugging and Restoration Program; and, (7) advise and consult with the Director on any and all other subjects about which the Department should seek information in relation to the oil and gas industry.
The Board, by a majority vote on record, may make specific recommendations to the Department
on any of the above matters.
[3] – Scope of Authority.
The Department has jurisdiction and authority over all persons and property necessary to
enforce effectively the Oil and Gas Act (“Act”).1037 The Department is charged with the duty of
enforcing this Act and all rules, regulations and orders promulgated pursuant of the Act.1038 In
this vein, the Department has the duty to prevent waste.1039
1036 Id.
Waste, in addition to its ordinary
meaning, means "physical waste" as that term is generally understood in the oil and gas industry
and expressly includes:
1037 Id. at 725/4. 1038 Id. at 725/3. 1039 Id. at 725/1.1.
201
(1) the locating, drilling and producing of any oil or gas well or wells drilled contrary to the valid order, rules and regulations adopted by the Department under the provisions of this Act; (2) permitting the migration of oil, gas, or water from the stratum in which it is found, into other strata, thereby ultimately resulting in the loss of recoverable oil, gas or both; (3) the drowning with water of any stratum or part thereof capable of producing oil or gas, except for secondary recovery purposes; (4) the unreasonable damage to underground, fresh or mineral water supply, workable coal seams, or other mineral deposits in the operations for the discovery, development, production, or handling of oil and gas; (5) the unnecessary or excessive surface loss or destruction of oil or gas resulting from evaporation, seepage, leakage or fire…; (6) permitting unnecessary fire hazards; (7) permitting unnecessary damage to or destruction of the surface, soil, animal, fish or aquatic life or property from oil or gas operations.1040
To fulfill the duty of waste prevention and to enforce the Act, the Department has the
authority to make such inquiries as it may think proper to determine whether or not waste, over
which it has jurisdiction, exists or is imminent. In the exercise of such power the Department has
the authority to: (1) collect data; (2) make investigation and inspections; (3) examine properties,
and drilling records; (4) examine, check and test oil and gas wells; (5) hold hearings; and (6) take
any other action reasonably necessary to enforce the Act.
1041
To further the purpose of waste prevention, the Department has the authority to conduct
hearings and make reasonable rules and regulations to ensure proper enforcement of the Act.
This includes the authority to adopt rules and to hold hearings in order to:
(1) require the drilling, casing and plugging of wells to be done in such a manner as to prevent the migration of oil or gas from one stratum to another; to prevent the intrusion of water into oil, gas or coal strata; (2) require the filing with the State Geological Survey of all geophysical logs, a well drilling report and drill cuttings or cores, if cores are required, within 90 days after drilling ceases; and to
1040 Id. at 725/1. 1041 Id. at 725/8.
202
file a completion report with the Department within 30 days after the date of first production following initial drilling or any reworking, or after the plugging of the well, if a dry hole…; (3) prevent "blowouts", "caving" and "seepage" in the same sense that conditions indicated by such terms are generally understood in the oil and gas business; (4) prevent fires; (5) ascertain and identify the ownership of all oil and gas wells, producing leases, refineries, tanks, plants, structures, and all storage and transportation equipment and facilities; (6) regulate the use of any enhanced recovery method in oil pools and oil fields; (7) regulate or prohibit the use of vacuum; (8) regulate the spacing of wells, the issuance of permits, and the establishment of drilling units; (9) regulate directional drilling of oil or gas wells; (10) prohibit waste, as defined in this Act; (11) require the keeping of such records, the furnishing of such relevant information and the performance of such tests as the Department may deem necessary to carry into effect the purposes of this Act; (12) prescribe rules, conduct inspections and require compliance with health and safety standards for the protection of persons working underground in connection with any oil and gas operations.1042
[4] – Process for Pooling.
[a] Drilling Units.
Pool-wide drilling units may be created by voluntary agreement or Department order.
The Department will designate and establish pooled units when reasonably necessary enable,
authorize, and require operations to increase the ultimate recovery of oil and gas; prevent the
waste of oil and gas; and protect correlative rights of the owners of the oil and gas.1043 An
‘owner’ is any person having an interest in the right to drill and produce oil or gas from any pool,
and to appropriate the production for such owner or others.1044
1042 Id. at 725/6.
1043 Id. at 725/23.3. 1044 Id. at 725/22.2(a).
203
Generally, the Department may issue a permit and, upon application of any interested
person, establish a drilling unit or units for the production of oil and gas or either of them for
each pool. As discussed in the next section, the Act provides default size and spacing
characteristics of a standard drilling unit.
[b] Authority to Integrate Production.
More specifically, when two or more separately owned tracts of land are embraced within
an established drilling unit, or when there are separately owned interests in all or a part of such
units, the owners of all oil and gas interests therein may validly agree to integrate their interests
and to develop their lands as a drilling unit.1045 The orders requiring integration will be upon
terms and conditions that are just and reasonable. The terms and conditions have to afford to the
owners of all oil and gas interests ion each tract in the drilling unit the opportunity to recover or
receive their just and equitable share of oil or gas from the drilling unit without unreasonable
expense, will prevent or minimize unreasonable drainage.1046
In making the determination of integrating separately owned interests the Department
may consider:
(1) the reasons requiring the integration of separate interests; (2) the respective interests of the parties in the drilling unit sought to be established, and the pool or pools in the field where the proposed drilling unit is located; (3) any parties' prior or present compliance with the Act and the Department's rules; and, (4) any other information relevant to protect the correlative rights of the parties sought to be affected by the integration order.1047
Where such owners have not agreed to integrate their interests and where at least one of the
owners has drilled or has proposed to drill a well on an established drilling unit, the Department,
1045 Id. at 725/22.2(b). 1046 Id. at 725/22.2(c). 1047 Id. at 725/22.2(e).
204
upon the application of an owner, shall require such owners to do so and to develop their lands as
a drilling unit. The Department, as a part of the order integrating interests, may prescribe the
terms and conditions upon which the royalty interests in the unit or units shall, in the absence of
voluntary agreement, be determined to be integrated without the necessity of a subsequent
separate order integrating the royalty interests. Each such integration order shall be upon terms
and conditions that are just and reasonable.1048
If the Department decides, based on the criteria set forth above, to integrate the owners’
interests in one drilling unit, then each order must:
(1) authorize the drilling, testing, completing, equipping, and operation of a well on the drilling unit; (2) provide who may drill and operate the well; (3) prescribe the time and manner in which all the owners in the drilling unit may elect to participate therein; and, (4) make provision for the payment by all those who elect to participate therein of the reasonable actual cost thereof, plus a reasonable charge for supervision and interest.1049
Should an owner not elect to voluntarily participate in the risk and costs associated with unit
operations, the order must specify options available to such non-consenting owners. These
options are discussed in the following section. In addition, the order must:
(1) specify the size and shape of the unit, which must be sufficient to result in the efficient and economical development of the pool as a whole; (2) cover all lands determined or believed to be underlaid by such pool; and, (3) prohibit the drilling of more than one well on any drilling unit for the production of oil or gas from the particular pool with respect to which the drilling unit is established.1050
For the Department to issue a unitization order, there must be two or more separately
owned tracts of land that are embraced within a pool or a portion of a pool suitable for any
1048 Id. at 725/22.2(b). 1049 Id. at 725/22.2(f). 1050 Id. at 725/21.2(b).
205
enhanced recovery method. When this occurs, the owners may validly agree to unitize to
integrate their interest and to develop their land as a unit.1051
(1) the unitized management and operation is economically feasible and reasonably necessary to increase the ultimate recovery of oil and gas, to prevent waste, and to protect correlative rights;
The Department will issue an order
providing for the unit operation of a pool or pools, or parts thereof, if it is determined, that
(2) the value of the estimated ultimate additional recovery of oil and gas will exceed the estimated additional cost, if any, incident to conducting the unit operation; (3) the areal extent of the pool or pools, or parts thereof, has been reasonably defined and determined by drilling operations, and the unitization and operation of such will have no substantially adverse effect upon the remainder of the pool or pools, or parts thereof; (4) the allocation of unit production to each separately owned tract is fair, reasonable, and equitable to all owners of oil and gas rights in the unit area; (5) the determination and allocation of unit expense is fair, reasonable and equitable to the working interest owners; (6) the compensation or adjustment for wells, equipment and other properties of the working interest owners is fair, reasonable and equitable.1052
An interested person may petition the Department to hold a public hearing to consider the
need for operating a pool, pools, or any portion thereof, as a unit. The petition for an order to
unitize must be filed with the Department office located in Springfield, Illinois. The petition will
be deemed filed when received by the Departments' Division of Oil and Gas.
1053 Each petition
must be signed by the petitioner or a representative and provide relevant contact information. If
after the petition is filed, and prior to setting a hearing date, the Department finds the petition
deficient relative to the requirements, the Department will return the petition to the applicant
with a statement describing the deficiencies.1054
A valid petition must provide the following information:
1051 Id. at 725/23.2(a). 1052 Id. at 725/23.5. 1053 Id. at 725/23.3. 1054 Id.
206
(1) A description of the land and pool, pools, or parts thereof, within the proposed unit area. (2) The names of all persons owning or having an interest in the oil and gas rights in the proposed unit area as of the date of filing the petition, as disclosed by the records in the office of the recorder for the county or counties in which the unit area is situated, and their addresses, if known. If the address of any person is unknown, the petition shall so indicate. (3) A statement of the type of operations contemplated for the unit area. And, (4) A copy of a proposed plan of unitization signed by persons owning not less than 51% of the working interest underlying the surface within the area proposed to be unitized, which the petitioner considers fair, reasonable and equitable.1055
The proposed unitization plan must indicate clearly any details relevant to the Department’s
approval. In particular, it must provide the following:
(1) A plan for allocating to each separately owned tract in the unit area its share of the oil and gas produced from the unit area and not required or consumed in the conduct of the operation of the unit area or unavoidably lost. (2) A provision indicating how unit expense shall be determined and charged to the several owners, including a provision for carrying or otherwise financing any working interest owner who has not executed the proposed plan of unitization and who elects to be carried or otherwise financed, and allowing the unit operator, for the benefit of those working interest owners who have paid the development and operating costs, the recovery of not more than 150% of such person's actual share of development costs of the unit plus operating costs, with interest. Recovery of the money advanced to owners wishing to be financed, for development and operating costs of the unit, together with such other sums provided for herein, shall only be recoverable from such owner's share of unit production from the unit area. (3) A procedure and basis upon which well equipment, and other properties of the several working interest owners within the unit area are to be taken over and used for unit operations, including the method of arriving at the compensation therefor. (4) A plan for maintaining effective supervision and conduct of unit operations, in respect to which each working interest owner
1055 Id. at 725/23.3(1).
207
shall have a vote with a value corresponding to the percentage of unit expense chargeable against the interest of such owner.1056
When the petitioner files the petition with the Department, he may also be asked to file relevant
notice of the petition among the appropriate land records where the affected property lies. Such
notice must convey (1) the type of proceedings before the Department; (2) general statements of
the purpose of such proceedings; and (3) a legal description of the lands, oil and gas lease or
leases, and other oil and gas property interests, which may be affected by the proposed
unitization.
1057
Upon issuing adequate notice, all transfers of title to oil and gas rights will be subject to
the final order of the Department, and the notice shall be constructive notification to every
person subsequently acquiring an interest in the affected property. Any person whose interest or
lien is not shown of record at the time the notice is filed will be deemed a subsequent purchaser
and will be bound by the proceedings before the Department to the same extent and in the same
manner as if he were a party to the hearing.
1058
After Department receives a petition for unitization, it will fix the time and place for a
public hearing. The public hearing will not be less than 30 days nor more than 60 days after the
date of the filing of the petition. The Department, at petitioner's expense, shall give notice of the
hearing at least ten days prior to the hearing in the following manner:
(1) By mailing such notice by United States Mail, postage prepaid, and directed to the persons named in the petition at their last known addresses 10 days prior to the hearing. And, (2) By publication of such notice for service on those persons whose addresses are unknown or whose names are unknown, once each week for 2 consecutive weeks. The first notice must appear at least 10 days prior to the hearing in a newspaper of general
1056 Id. 1057 Id. at 725/23.3(2). 1058 Id.
208
circulation that is published in each county containing some portion of the proposed unit area.1059
All notices for public hearing under this Section shall issue in the name of the State of Illinois
and shall be signed by the Director. Such notices will specify (1) the number and style of the
proceedings; (2) the time and place of the hearing; (3) the purpose of the hearing, (4) the name of
the petitioner; and, (5) a legal description of the lands contained within the proposed unit
area.
1060
[d] Impact on Existing Agreements and Orders.
Adjoining owners within the same pool portions thereof may create a new unit, including
a unit area of another or other units. To do so, the owner must file a petition. Then a notice will
be issued and a hearing will be held following the same procedure that was followed for the
creation of a unit in the first instance.1061 Once the Director issues the order to create a new unit,
the new unit will supersede the existing unit or units. The new order will not alter the
proportionate allocation of unit production among the separately owned tracts included in the
previously established unit area or unit areas. Any new working interest owner whose interest is
added to the new unit area and who becomes liable for his proportionate share of the unit
expense will not be liable for any unit expense incurred prior to that person's entry in the new
unit.1062
Additionally, a drilling unit may be modified after the order has been issued. It may be
modified to include additional lands determined to be underlaid by such pool, to change the size
1059 Id. at 725/23.4(1). 1060 Id. at 725/23.4(2). 1061 Id. at 725/23.12. 1062 Id.
209
of the drilling unit, or to permit the drilling of additional wells.1063 Otherwise, the drilling and
operation of any well in the pool that underlies the ordered drilling unit is prohibited.1064
[e] Royalty interest.
Unless otherwise specified by agreement or Department order, a mineral owner of
unleased interest may elect to participate in risk and expense of operation, thereby securing a
default seven-eighths working interest and a one-eighth royalty from production. 1065
[f] Agreements Not Restraint of Trade.
In the
alternative, such owners may negotiate with proposed operators to enter into a leasehold
relationship and secure a more favorable royalty payment. These option-based rights are
discussed further in the following section.
Once the Department approves an agreement, it will not be held or construed to violate
any Illinois law that relate to trusts, monopolies, contracts, or any combination thereof.1066
§ 14.02 Types of Illinois Pooling Statutes.
[1] – Mineral Distinctions.
In Illinois, gas is defined as all natural gas, including casinghead gas, and all other
hydrocarbons not defined as oil. Oil is defined as natural crude petroleum oil or petroleum and
other hydrocarbons, regardless of gravity, which are produced at the well in liquid form by
ordinary production methods or by the use of an oil and gas operator and which are not the result
of condensation of gas after it leaves the underground reservoir. Further, a pool is defined as a
natural, underground reservoir containing in whole or in part, a natural accumulation of oil or
gas, or both. The term pool also covers each productive zone or stratum in general, which is
1063 Id. at 725/21.2(c). 1064 Id. at 725/21.2(e). 1065 Id. at 725/22.2(g). 1066 Id. at 725/23.2(b).
210
completely separated from any other zone or stratum in the structure. Moreover, a field is
defined as that general area which is underlaid or appears to be underlaid by one or more
pools.1067
[2] – Split by Depth.
Department regulations specify a depth split for gas wells at 5,000 feet or at the top of the
Trenton formation, which ever is greater. As such, any gas well drilled deeper 5,000 feet or the
top of the Trenton formation is considered a “deep well.” Those gas wells not reaching this
depth threshold are defined as “shallow wells.”1068
[3] – Spacing Rules.
There are similar distinctions for oil wells,
with the depth division resting at 4,000 feet.
Drilling units shall be of approximately uniform size and shape for each entire pool,
except that where circumstances reasonably require, the Department may grant exceptions to the
size or shape of any drilling unit or units. However, the size of a drilling unit shall not be smaller
than the maximum area that can be efficiently and economically drained by one well. 1069
Additionally, no oil or gas well shall be drilled nearer than 250 feet to any opening to a working
coal mine used as a means of ingress or egress for the persons employed therein or which is used
as an airshaft. Notwithstanding this setback, wells may be located within such restricted areas
agreed to by relevant and mine and well operators or owners.1070
[a] Unit Size.
Oil and gas wells must comply with standard unit dimensions differentiated by well
depth. All shallow oil wells must be located on: (a) 10 acres of surface area lying within the
1067 Id. at 725/1. 1068 Ill. Admin. Code tit. 62, § 240.410 (2001). 1069 225 Ill. Comp. Stat. 725/21.1(b) (2010). 1070 Id. at 725/20.
211
quarter-quarter-quarter section of land for 4,000 feet beneath the surface; or, (b) [20] acres of
surface area lying within the east-west or north-south one-half of a quarter-quarter section. For
deep oil wells, the applicable unit size is 40 acres.1071
(a) 10 surface acres lying within the quarter-quarter-quarter section for gas wells less than 2,000 feet deep and not producing from a limestone/dolomite reservoir.
Gas wells are subject to similar 10, 20,
and 40-acre limitations as follows:
(b) 20 surface acres lying within the quarter-quarter-quarter section for gas wells less than 2,000 feet deep and producing from a limestone/dolomite reservoir (c) 40 surface acres of lying within a quarter-quarter section for gas wells with a depth between 2,001 and 5,000 or the top of the Trenton formation, which is deeper. (d) 160 surface acres lying within a quarter section of land for all deep gas wells.1072
For a coalbed gas well that is drilled into an unmined coal seam, the well spacing must conform
to the drilling unit requirements of 10 acres of surface area lying within a quarter-quarter-quarter
section of land.
1073
[b] Setback Rules.
Department regulations provide default spacing rules based on unit size and mineral
produced. All oil wells must conform to the following spacing rules:
(a) For an area of [10] or [20] surface acres, the location of the well shall not be less than [330] feet from the nearest external boundary lines of the drilling unit, nor less than [660] feet from the nearest location of a producing well, a well being drilled, or a well for which a permit has previously been issued, but not yet drilled, for a well to the same individual reservoir. Or, (b) For an area of [40] surface acres the location of the well shall be not less than [330] feet from the nearest external boundary lines of the drilling unit, nor less than [900] feet from the nearest location of a producing well, a well being drilled, or a well for
1071 Id. 1072 Id. 1073 Id.
212
which a permit has previously been issued, but not yet drilled, for a well to the same individual reservoir.1074
Similarly, all gas wells must comply with the following:
(a) For an area of [10] or [20] surface acres, the location of the well shall not be less than [330] feet from the nearest external boundary lines of the drilling unit, nor less than [660] feet from the nearest location of a producing well, a well being drilled, or a well for which a permit has previously been issued, but not yet drilled, for a well to the same individual reservoir. Or, (b) For an area of [40] surface acres, the location of the well shall not be less than [330] feet from the nearest external boundary lines of the drilling unit nor less than [900] feet from the nearest location of a producing well or well being drilled or for which a permit has previously been issued but not yet drilled for a well to the same individual reservoir.1075
The standards affect all applicable wells regardless of depth, with one exception: no deep gas
well may be drilled within 660 feet of the nearest external boundary line of the drilling unit.
1076
The only codified spacing rule for coalbed gas wells requires a minimum setback 330 feet from
the nearest external boundary lines of the drilling unit.1077
[4] – Minimum Operator Control.
A unitization order will not become effective until the plan and order from the Director
has been approved in writing by those persons who, under the order, will be required to pay at
least 51 percent of the unit expense, and also by the persons owning at least 51 percent of the
unit production or proceeds. If the requisite number of persons and the requisite percentage of
interests in the unit area do not approve the plan of unitization within a period of 6 months from
the date of the order providing for unitization, then the Department will revoke the order. But if
good cause can be shown to the Department, it may extend the time for an additional period of
time that may not exceed one year. 1078
[5] – Options.
All unitization orders must specify the treatment of non-consenting owners. If any owner
refuses to participate in the risk and costs of the drilling, testing, completing and operation of a
well as determined by the Department, the integration order shall provide either that:
(1) the nonparticipating owner shall surrender a leasehold interest to the participating owners on a basis and for such terms and consideration the Department finds fair and reasonable; or, (2) the nonparticipating owner shall share in a proportionate part of the production of oil and gas from the drilling unit determined by the Department, and pay a proportionate part of operation cost after the participating owners have recovered from the production of oil or gas from a well all actual costs in the drilling, testing, completing and operation of the well plus a penalty to be determined by the Department of not less than 100 percent nor more than 300 percent of such actual costs.1079
1078 225 Ill. Comp. Stat. 725/23.8 (2010). 1079 Id.
214
§ 15.01 Analysis of Indiana Regulatory Framework.
[1] – Name of the Governing Body.
Indiana’s Department of Natural Resources (“Department) is the statutorily created body
empowered to enforce the state’s Oil and Gas Conservation Act (“Act”) 1080 and foster the
conservation and development of the natural resources of Indiana.1081 The Department’s Oil and
Gas Division (“Division”) directly administers the Act; 1082 however, the Indiana Natural
Resources Commission (“Commission”), which is also established by statute, is the ultimate
authority on administrative orders and procedure.1083
[2] – Membership on the Governing Body.
The Department consists of a director appointed by the governor, four deputy directors,
and any other personnel necessary to adequately perform Department functions. 1084 The
Division Director is selected by the Commission to oversee the Division’s enforcement of the
Act.1085 The Commission members include the: (1) commissioner [or designated representative]
from the department of transportation; (2) commissioner [or designated representative] from the
department of environmental management; (3) director [or designated representative] from the
office of tourism development; (4) Department Director; (5) chairperson of the advisory council
under § 14-9-6-1; (6) president [or designated representative] from the non-profit Indiana
Academy of Science; and (7) six citizen members.1086
These positions are filled by governor appointment based on expertise in the relevant areas.1087
Of the six citizen appointees, at least two must have knowledge or experience in environmental
or natural resource conservation, and no more than three may be of the same political party.1088
Unless removed for cause, citizen members serve three-year terms on the Commission.1089
The Commission elects officers annually from its amongst its members, including a
chairman and vice chairman to preside over Commission meetings, and a secretary responsible
for maintaining Commission records.
1090
[3] – Scope of Authority.
The Department has the duty to recommend and secure the enforcement of laws for the
conservation and development of the natural resources of Indiana.1091 In furtherance of this duty,
the Department has the authority to make emergency rules,1092 as well as to investigate, compile
and disseminate information and make recommendations in primary pursuit of waste
prevention.1093 Waste is strictly prohibited,1094
(1) locating, spacing, drilling, equipping, operating, or producing a well for oil and gas…in any manner that reduces…the quantity of oil or gas ultimately to be recovered from any well in this state or violates the spacing provisions;
and includes conduct such as the
(2) storing oil in earthen reservoirs except in an emergency to prevent the total loss of that oil; (3) producing oil or gas in a manner that will cause water channeling or zoning; (4) injecting fluids into a stratum or part of a stratum capable of producing oil or gas, except in accordance with the terms of a permit for an injection well issued under this article; (5) allowing water other than fresh water to flow from any producing horizon located in a producing pool, except in
accordance with the terms of a permit issued under this article; and, (6) allowing gas from a well that produces only gas to escape into the atmosphere, except as is necessary while making or changing connections, completing the well, or reconditioning the well. 1095
The Department Director has the duty, among others, to supervise the work of the
Department and of each of the divisions.
1096 The Department Director may also appoint and
remove deputy directors, and upon the recommendation of the deputy director of a bureau,
appoint and remove all officers and employees of the bureau.1097 The Department Director, with
the approval of the commission, may: (1) cooperate with any other department of state
government in the enforcement of law; (2) assign deputies to aid the other departments in
making inspections and in the prevention or detection of crime; and (3) receive similar assistance
from the deputies of any other state department.1098
As part of the Division’s authority, it must notify a permit applicant if the application is
within the permit boundaries of an underground mine for which a mine plan has been filed or
which contains commercially mineable coal resources.
1099
(1) associated with an underground mine permitted and specifically intended to be mined under the permit;
A commercially minable coal
resource is a seam of coal that can be mined using generally accepted underground practices and
suitable equipment, and consists of coal in sufficient quantities and of sufficient quality to be
commercially saleable. A commercially minable coal resource includes a seam of coal to which
the seam is:
(2) associated with an inactive underground mining operation at which mining operations have temporarily ceased and are
anticipated to be resumed by the person with the right to develop the seam; (3) identified as a commercially minable coal resource by the owner or lessee of the seam by a map accompanied by an affidavit that is filed with the division of oil and gas and states that the coal in the seam is being held for later commercial production; or, (4) at least thirty-six inches thick and located not more than 800 feet below the surface. 1100
The Commission has, among others, the power and duty to establish, in accordance with
criteria established by the United States Secretary of the Interior, a program of matching grants-
in-aid to public agencies for projects having as their purpose the preservation for public benefit
of properties that are significant in American or Indiana history, architecture, archeology, and
culture; and to establish fees.
The Commission oversees the drilling, casing, operating, plugging, and abandoning of
wells and any related fluid storage to prevent waste and minimize environmental impact of the
operations.1101 To further these duties, the Commission may adopt rules to govern any aspect of
oil and gas production within its jurisdiction.1102
The Commission, unless specified elsewhere, is the ultimate authority of the Department
for administrative orders and procedures.
In particular, the Commission has the authority
to regulate spacing through lineal and well density requirements, which are discussed further in
the following section.
1103 Under this power, the Commission is free to
delegate powers and duties to other Department employees or divisions. 1104
The Iowa Oil and Gas Conservation and Unitization Statute (“the Act”) is grounded in
the state’s policy to “foster and promote” oil and gas production in a manner that will prevent
waste and “result in the greatest possible economic recovery of [oil and gas] to the end that the
land owners, the royalty owners, the producers, and the general public realize and enjoy the
greatest possible good from these vital natural resources.”1135
[a] Matters Governed.
To accomplish these goals, the Director has a duty to make proper investigation to
determine the existence or possibility of waste.1136
(1) physical waste, as…generally understood in the oil and gas industry;
Waste, which is explicitly prohibited by
statute, includes:
(2) the inefficient, excessive, or improper use of, or the unnecessary dissipation of reservoir energy; (3) the location, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner which causes, or tends to cause, reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or which causes or tends to cause unnecessary or excessive surface loss or destruction of oil or gas; (4) the inefficient storing of oil; and, (5) the production of oil or gas in excess of transportation or marketing facilities or . . . reasonable market demand.1137
The Director is granted broad authority to combat waste. The Director may enact regulations
and issue orders to effectively enforce the Act and encourage efficient production.
1138
For example, the Director may require “identification of [well] ownership…making and
filing of mechanical well logs and…surveys; operation…of wells in such manner as to prevent
the escape of oil or gas out of one stratum into another; [and maintenance] of complete and
accurate [production] records.”1139 In addition, the Director is authorized to regulate nearly all
aspects of oil and gas production, including but not limited to the “drilling,…chemical
treatment…, [and] spacing of wells.”1140
The Commission may also promulgate rules to preserve surface and subsurface integrity,
and thereby affect the scope of Director authority. A majority of the Commission constitutes a
quorum needed to achieve Commission decisions such as rule making, hearing relevant
challenges to Department action, and restricting waste disposal.
1141
[b] Procedure.
The Department must provide notice and a hearing prior to entering an order.1142 The
Department may act upon its own motion, or upon the petition of “any interested person.”1143
No order may be issued without a least ten days notice and the Department must afford any
interested person the opportunity to be heard at the public hearing. 1144
Any notice required by this chapter shall be given at the election of the Department either by personal service or by letter to the last recorded address [of those persons affected] and one publication in a newspaper of general circulation in the state capital city and in a newspaper of general circulation in the county where the land affected, or some part thereof, is situated. The notice shall issue in the name of the state, shall be signed by the Director, shall specify the style and number of the proceeding, the time and place of the hearing, and shall briefly state the purpose
Upon petition, the
Department will cause notice of the hearing to be given. The Statute specifies notice
requirements particular to Council actions:
1139 Id. 1140 Id. 1141 Id. 1142 Id. § 458A.11. 1143 Id. The Act does not define “interested person.” 1144 Id.
227
of the proceeding. Should the Department elect to give notice by personal service, the service may be any officer authorized to serve process, or by any agent of the Department, in the same manner as is provided by law for the service of original notices in civil actions in the district court of the state. Proof of service by such agent shall be by the affidavit of the person making personal service.1145
A Department order must be written and kept by the state geologist as public record, certified
copies of which are receivable in evidence in all Iowa courts.
1146
[4] – Process for Pooling and Matters Covered.
Neither the Act nor
Department regulations specify appellate procedure for those adversely affected by an order.
Among the Department’s statutory duties is the requirement that it determine market
demand for each “marketing district” and limit production within such areas to avoid waste.1147
“Reasonable market demand” is defined in the Act to mean that “demand for oil or gas for
reasonable current requirements for consumption and use within and without the state,” together
with that amount needed to build and maintain reasonable reserves of those products.1148 When
the Department restricts oil and gas production, it must “allocate or distribute the allowable
production among the pools in the district on a reasonable basis” and prevent “premature
abandonment of…wells in the pool.”1149
If a particular pool is limited to produce less than it otherwise would without restraint, the
Department “shall allocate or distribute the allowable production among the several wells or
producing properties in the pool on a reasonable basis, preventing or minimizing reasonable
avoidable drainage, so that each property will have the opportunity to produce or receive its just
1145 Id. 1146 Id. 1147 Id. § 458A.6. Neither the Act nor Department regulations define or clarify what constitutes a “marketing district.” 1148 Id. § 458A.2 (18). 1149 Id.
228
and equitable share, subject to the…prevention of waste.”1150 The Department defines “just and
equitable share” to mean, respective to each person, “that part of the authorized production from
the pool that is substantially in the proportion that the amount of recoverable oil [and] gas…in
the developed area of the person’s tract or tracts in the pool bears to the recoverable oil [and] gas
in the total developed area in the pool.”1151
[a] Spacing.
The Department must establish spacing units for a pool when necessary to prevent waste,
avoid unnecessary drilling, or protect correlative rights.1152 In general, each spacing unit within
a pool should be uniform in size and shape.1153 However, if necessary to achieve the above-
stated goals, the Department may divide a pool into zones and establish spacing units for each
zone, which “may differ in size and shape from those established in any other zone.” 1154
Whether or not zonal subdivision is needed, spacing units must be set in aims of “the efficient
and economical development of the pool as a whole.”1155
An order to establish spacing units for a pool must specify unit dimensions and proposed
well location(s) to comprise a “reasonably uniform spacing plan.”
1156 In addition, the order must
cover all land “determined or believed to be underlain by such pool.”1157 If the state geologist
finds that a proposed well site will not prove sufficiently productive, or may cause substantial
burden or hazard for drilling, the state geologist may enter its own order to change the
Department’s prescribed location.1158
1150 Id.
In that event, the state geologist’s order must include
The Kansas State Corporation Commission (“Commission”) and its internal divisions
regulate all matters related to oil and gas production throughout the state.1192
[2] – Membership on the Governing Body.
The Commission is comprised of three members who serve four-year staggered
terms. 1193 Each commissioner is appointed by the governor and confirmed by the state
senate.1194 No more than two commissioners serving simultaneously may belong to the same
political party. 1195 The Commission has extensive jurisdiction over resource and economic
development in Kansas, which is carried out through four divisions: Conservation,
Transportation, Energy, and Utilities. 1196 The oil and gas conservation statute (“statute” or
“Act”) is administered by the Commission’s Division of Conservation, which is led by a
Commission-appointed director who oversees daily activity of oil and gas production.1197 The
conservation division acts as the ‘face’ of the Commission’s regulatory authority over oil and gas
production.1198
The Commission may not promulgate any rule or regulation without first obtaining
formal recommendation from the “advisory committee on regulation of oil and gas
activities.”
1199
(1) Kansas Petroleum Council;
This advisory committee contains twelve members appointed by various bodies
throughout the state government and relevant industries as follows:
1192 Kan. Stat. Ann. § 55-150(a) (2010). 1193 Id. § 74-601(a). 1194 Id. 1195 Id. 1196 See Kan. Corp. Commission, http://www.kcc.state.ks.us (last visited June 10, 2011). 1197 Kan. Stat. Ann. § 74-630 (2010). 1198 Kan. Admin. Regs. § 82-3-101(17) (2011). 1199 Kan. Stat. Ann. § 55-152(a) (2010).
235
(2) Kansas Independent Oil and Gas Association; (3) Eastern Kansas Oil and Gas Association; (4) Jointly by the Kansas Farm Bureau and Kansas Livestock Association (appointee must own surface interest within the state); (5) Jointly by the Southwest Kansas Royalty Owners Association and Eastern Kansas Royalty Owners Association (appointee must own mineral interest within the state); (6) Governor of Kansas, (appointee must be a member of the general public); (7) Jointly by presidents of each groundwater management district (to represent the districts collectively); (8) Department of Health and Environment; (9) Kansas Geological Survey; (10) Kansas Water Office; (11) Department of Agriculture, Division of Water Resources; (12) State Corporation Commission.1200
Each appointee serves at the pleasure of the respective represented body.
1201 The person
designated by the Commission (‘number twelve’) serves as the chairperson of the advisory
committee and organizes quarterly meetings. 1202
[3] – Scope of Authority.
For clarity, “Commission” will hereinafter
indicate this collective source of authority under the Act.
The Commission maintains jurisdiction over all matters related to oil and gas production
and unitization throughout Kansas. 1203 The statutory prohibition of waste supplies the
foundation of the Commission’s authority under the Act.1204
1200 Id. § 55-153.
Waste is defined throughout the
Act, and “in addition to its ordinary meaning, . . . include[s] economic waste, underground waste,
surface waste, waste of reservoir energy, . . . the production of [oil or gas] in excess of
transportation or marketing facilities or reasonable market demands; . . . [and] both economic
1201 Id. 1202 Id. 1203 Id. §§ 55-150; 55-603; 55-703; 55-1301. 1204 Id. §§ 55-601, 55-701. The Act does not provide the “ordinary meaning” of waste.
236
and physical waste resulting from the development and operation separately of tracts that can
best be operated as a unit.”1205
[a] Matters Governed.
The Commission may “make and enforce rules, regulations and orders for the prevention
of waste,”1206 and has an affirmative duty to prevent the inefficient and inequitable taking of oil
of gas.1207 In pursuit of these goals, it is authorized to “ascertain[] the several factors entering
into the determination of the productive capacity of each well [and] the total productive capacity
of all wells in [any] common source of supply.”1208 The Commission has broad jurisdiction to
“establish[]…such other standard[s] as [it]…may find proper to determine the productive
capacity of…all wells…and…carry out the spirit and purpose” of the Act.1209
[b] Commission Procedure.
A proceeding to initiate any Commission action under the Act may be instituted by the
Commission itself, the attorney general, or any other person. 1210 Within its authority to
promulgate rules, the Commission has established procedural requirements relevant to certain
situations. If a regulation contains application and notice standards therein, such language
controls for the relevant issue(s) involved.1211
1205 Id. §§ 55-602, 55-702, 55-1302(d).
If applicable, particular procedural rules will be
discussed alongside the substantive law to which they apply. Otherwise, “the notice
requirements [outlined below] apply to each hearing arising under any rule[,] regulation or
If the Commission or the state’s attorney general initiates a hearing, notice of such
hearing must comply with the following:
If the Commission finds that a protest is valid, a hearing will be
held, and the applicant must publish notice of the hearing as specified below.
(1) Notice of the hearing shall be published by the Commission in the Wichita Eagle newspaper and in the Kansas Register. Notice of the hearing shall also be published in the official county newspaper of each county in which the lands affected by the hearing are located. If that county does not have an official county newspaper, notice may be published in any newspaper satisfying the requirements of § 64-101 in a county in which the lands affected by the hearing are located. (2) A copy of the notice of the hearing shall be mailed by the Commission to each person who has filed for the purpose of receiving notice. The notice shall be mailed not less than 10 days prior to the hearing date. (3) Any additional notice required by any rule, regulation or statute which applies to the hearing or which is necessary to provide due process to any person whose property may be affected by the hearing shall be provided by the Commission.1221
If the hearing is initiated by any other person, notice must be given as follows:
(1) Anyone who initiates a hearing shall publish notice of the hearing in the Wichita Eagle newspaper and in the official county newspaper of each county in which the lands affected by the hearing are located. Anyone who initiates a hearing may publish notice in any newspaper satisfying the requirements of K.S.A. 64-101 in a county in which the lands affected by the hearing are located, if that county does not have an official newspaper. (2) A copy of the notice of the hearing shall be mailed by the commission to each person who has filed for the purpose of receiving notice. The copy of the notice shall be mailed not less than 10 days prior to the hearing date. (3) Anyone who initiates a hearing shall provide any additional notice required by any rule, regulation or statute which applies to the hearing or is necessary to provide due process to any person whose property may be affected by the hearing.1222
1220 Id. § 82-3-135b(e).
1221 Id. § 82-3-135(b). 1222 Id. § 82-3-135(c).
239
If the Commission is required to publish notice, it must establish proof that such was properly
given in the form of an affidavit sworn by a staff member that notice is perfected. If another
person must publish notice, the applicant for said hearing must provide a sworn affidavit of
perfection.1223
[4] – Matters Covered.
The disjointed structure of the Act and regulations provides separate rules pertaining to
oil and gas respectively in different articles or sections.1224 Despite this format, the rules often
govern the two products on identical or similar grounds. Further, any provision for unitization
references oil and gas simultaneously. 1225
The regulatory scheme in Kansas is two-fold: the Commission has established general
rules governing allowable production that are “statewide in application” unless otherwise
stated.
For clarity, this discussion will not distinguish
between oil and gas whenever possible, and will signify circumstances where the laws’
distinctions merit attention.
1226 On the other hand, “special orders shall be issued when required, and shall prevail
over general rules” if conflict arises.1227 Further, as will be discussed herein, the Commission
may grant an exception to the requirements of any regulation upon application, notice and
hearing.1228
In Kansas, there is no compulsory pooling per se. Rather, the Commission regulates oil
and gas production through a system of allowable calculations and proration among relevant
1223 Kan. Admin. Regs. § 82-3-135(d) (2010). 1224 See generally Kan. Stat. Ann. §§ 55-601 et seq. (Oil Production & Sale), Kan. Admin. Regs. §§ 82-3-200 et seq. (Oil Conservation Rules); Kan. Stat. Ann. §§ 55-701 et seq. (Production & Conservation of Natural Gas), Kan. Admin. Regs. §§ 82-3-300 et seq (Gas Conservation Rules). 1225 See generally Kan. Stat. Ann. §§ 55-1301 et seq. (Unitization), Kan. Admin. Regs. §§ 82-3-100 et seq. (General Conservation Rules). 1226 Kan. Admin. Regs. § 82-3-100(a) (2011). 1227 Id. For the purposes of this discussion, “order” means “special order,” as compared to general rules. 1228 Id. § 82-3-100(b).
240
areas. The Commission will classify wells “by the common source of supply [or pool] from
which they produce.”1229 The Commission has the authority and responsibility to regulate the
taking of oil and gas from any pool as to prevent: (1) waste; (2) “the inequitable or unfair taking”
of oil and gas; and (3) “unreasonable discrimination” among pools and wells therein.1230
The following discussion should be prefaced by highlighting some key terms used below.
As defined by the Commission, “proration” means the “regulation of the amount of allowed
production to prevent waste[,] or to prevent any of the following[,] in a manner that would favor
any one pool [over another]: undue drainage between developed leases; unratable taking; or
unreasonable discrimination between or among operators, producers, and royalty owners who are
within a common source of supply.”
1231
The phrases “attributable acreage” and “acreage-attribution” are used interchangeably by
the Commission to mean “the acreage assigned to a well in accordance with the well spacing
program for each of the prorated fields.”
In other words, proration refers to the Commission’s
general authority and duty to control oil and gas production on efficient and equitable grounds.
1232
[a] Allowable Production System.
The Commission defines a well’s attributable
acreage as one factor used to determine the allowable production to be granted to a particular
well, as well as to a certain well pool or field under an order.
Pursuant to its statutory duty, the Commission will limit the amount of production within
the state, and among the pools and wells therein, through a system of allowable production
standards. The Act states that “[t]he drilling and completion of a…well shall not itself entitle
1229 Id. § 82-3-102. A “pool” is “any common source of supply” of oil and/or gas. Kan. Stat. Ann. § 55-603 (2010). 1230 Kan. Stat. Ann. § 55-603 (2010). 1231 Kan. Admin. Regs. § 82-3-101(58) (2011). 1232 Id. § 82-3-101(7).
241
said well to an allowable for production.”1233 As such, an “allowable” is “the amount of oil or
gas authorized to be produced by order of the Commission.”1234
[b] Default Allowable—Gas Wells.
The Commission will grant an allowable to each gas well within a prorated pool upon an
operator’s application that provides the following: (1) a written request for an allowable on a
form prescribed by the Commission; (2) an acreage plat displaying well location and a
description of such well’s attributable acreage; and, (3) results of the Commission-supervised
test as required under the applicable pooling order.1235
In determining an allowable for each well, the Commission will consider waste
prevention and correlative rights protection, as well as “market demand” for the product.
1236 The
Commission will base its calculation of market demand upon “the reasonable current
requirements for current consumption and use within and without the state, and such other
factors, conditions, or circumstances that would aid” in this evaluation.1237
This broad statutory guidance will be involved in the Commission’s allowable
determination. However, gas wells are subject to regular testing of production upon which the
Commission will calculate each well’s “actual open flow potential.”
1238 For gas wells, the
“standard daily allowable…shall be limited to 50% of the well’s actual open-flow potential.”1239
So long as a gas well operator complies with regulatory testing requirements, it “shall be entitled
to a minimum allowable of 250 mcf per day.”1240
1233 Kan. Stat. Ann. §55-703a (2010).
1234 Kan. Admin. Regs. § 82-3-101(2) (2011). 1235 Id. § 82-3-300(a). Additional information is required if request is for a replacement well. 1236 Kan. Stat. Ann. § 55-703 (2010). 1237 Id. § 55-703(a). 1238 Kan. Admin. Regs. § 82-3-303 (2011). Equations to calculate open-flow potential are stated in this provision. 1239 Id. § 82-3-312(a). 1240 Id.
242
In addition to applicable exceptions discussed below, the Commission may make
exceptions or modifications to an allowable to prevent waste or protect correlative rights.1241
Regardless of attributable acreage, the Commission may a grant a well “the full allowable if any
of these conditions exist: (1) location exceptions have been granted for man-made structures or
topographic features; (2) no interference with drainage of adjacent wells can be shown by
competent evidence; or (3) actual interference is less than the reduced allowable.”1242
[c] Default Allowable—Oil Wells.
The Commission will hold a monthly hearing to determine the statewide oil allowable for
the coming month, or ‘proration period’.1243 The overall allowable will be that amount which
“can be produced daily throughout the state, during the next succeeding proration period, without
causing waste.” 1244 Once the Commission establishes this amount, it then must allocate
allowable production among the prorated pools and wells within the state1245 in a manner that
“prevent[s] unreasonable discrimination in favor of any one pool as against any other.” 1246
Therefore, generally speaking, an allowable will be the “amount of oil which may be produced
currently…without causing waste or injury to correlative rights, and without discriminating
between pools.”1247
Once the Commission determines allowable production for the various pools, it will
prorate that amount among the several wells within each pool based on the following
considerations: (1) the “productivity of each…well;” (2) “the acreage of each well owner which
is reasonably attributable to each of the owner’s wells;” and (3) the “efficient utilization of the
reservoir energy in the pool.”1248 As the Act expressly prohibits waste, it is unlawful for any
person to produce more “than the allowable specified by the Commission.”1249
For a particular oil well in a prorated pool, the Commission will consider the results of
initial and annual productivity testing, and any applicable overages or underages from the
previous proration periods.
1250 For a well not covered by proration agreement or order,
allowables “shall be assigned on an individual well basis” based on a depth schedule as
follows1251
Producing Interval Found Between
:
(depth in feet) Daily Allowable (barrels/well/day)
0-4000 100 4,001-6,000 200 6,000+ 300 Upon application, the Commission may assign an allowable and attributable acreage to a given
oil well that varies from the applicable default allowable shown above.1252
(1) the exact location of the well and the acreage attributed to the well;
For non-prorated
wells, the application must provide:
(2) the allowable requested; (3) the geological name of the producing formation; (4) the top and bottom depths of the producing formation; (5) an affidavit indicating the date that applicant provided proper notice of the application to, and the names and addresses of, each operator and/or lessee of record and each unleased mineral owner within a one-half mile radius of the proposed well; and, (6) any other information the Commission may require.1253
In addition, any interested party may file an application for an exception to an allowable assigned
by the Commission by initiating a hearing in compliance with the procedures outlined above.
The Commission has discretionary authority to establish “well spacing [requirements] in
any…common source of supply and provide for the orderly development thereof.”1255
Any person having an interest in oil or gas production within a particular area “may file
an application for . . . a well spacing or basic proration order.”
Thus, in
terms of well location and common source production, a person may petition the Commission to
enter a special order defining well-spacing and proration rules for an applicable pool; in the
absence of such order, the law provides default restrictions for all wells within the state, subject
to available individual exceptions in some circumstances.
1256
(1) if the application is for amendment, a description of the nature of the amendment sought;
These applications must
contain the following:
(2) the location, depth, and common source of supply from which a well or wells in the subject acreage are producing; (3) a description of the acreage subject to the application, with an affirmation that all of the acreage is reasonably expected to be productive from the subject common source of supply; (4) the proposed well location restriction and proposed provisions for any exceptions thereto; (5) the proposed configuration of producing units for acreage attribution purposes; (6) the name and address of each operator or lessee of record in the subject acreage, and, a certificate of mailing indicating the date service of a copy of the application was made to each; (7) the name and address of each owner of record of the minerals in unleased acreage within the subject acreage, and a certificate of mailing indicating the date service of a copy of the application was made to each; (8) the name and address, as shown by the applicant's books and records, of each person owning the royalty or leasehold interest in the subject acreage and operated by the applicant, or on which the applicant has a lease or an interest in the lease, and a certificate of
mailing indicating the date service of a copy of the application was made to each; (9) if a proration formula is sought, the specific factors proposed to be utilized in the allocation of production; (10) the applicant's license number; and (11) such other information which may be required by the Commission.1257
The applicant must file the original and four copies of the application with the
Commission, which will set a hearing to consider the action sought.
1258 The applicant must then
publish notice of the hearing under the terms outlined above.1259 Upon adequate notice, no well
may be drilled within the area sought to spaced or prorated by the application until the hearing
concludes, unless that “well location conforms to the most restrictive location provisions sought
in the pending application.”1260
If a special order is entered, “any well drilled or being drilled in violation [thereof] shall
be considered…unlawful [and]…presumed to be in violation of correlative rights[,] and to
constitute waste.”
1261 Upon such violation, the Commission may issue a “show cause order to
determine whether the [unlawful] drilling…was necessary to protect correlative rights or prevent
waste,” and will hold a hearing to consider an exception.1262 If good cause is not sufficiently
established, the Commission may require that “the well…be permanently capped or plugged and
abandoned,” or permit “production at a reduced rate…to ensure the protection of correlative
rights and the prevention of waste.”1263
[e] Exceptions to Special Orders.
1257 Id. 1258 Id. § 82-3-109(c). 1259 Id. 1260 Id. § 82-3-109(d). The Commission may grant exceptions to temporary drilling ban after notice and hearing. Id. 1261 Id. § 82-3-110(a). 1262 Kan. Admin. Regs. § 82-3-110(a) (2011). 1263 Id. § 82-3-110(b).
246
Any gas well located within a prorated pool that requires exceptions to any provision of a
proration order “may be granted an allowable by the Commission only after an application has
been filed.”1264
(1) The exact location of the well and the acreage attributed to the well;
An application seeking such exception must contain the following information:
(2) The common source of supply from which the well is producing; (3) The name and address of the purchaser, if known; (4) A statement of the exception being requested and the reasons the exception should be granted; (5) A plat showing the location and approximate depths of all wells and dry holes that have been drilled within one mile from the acreage to be attributed; (6) The applicant's license number; (7) The names and addresses of each person owning a royalty or working interest in the acreage to be attributed, and a certificate of mailing indicating the date on which service of a copy of the application was made to each person; (8) The names and addresses of all operators of producing acreage abutting or adjoining the acreage to be attributed, and a certificate of mailing indicating the date on which service of a copy of the application was made to each operator; (9) The names and addresses of all lessees of record of nonproducing acreage abutting or adjoining the acreage to be attributed, and a certificate of mailing indicating the date on which service of a copy of the application was made to each lessee; (10) The names and addresses of all owners of record of the minerals in, or royalty of unleased acreage abutting or adjoining, the acreage to be attributed, and a certificate of mailing indicating the date on which service of a copy of the application was made to each owner; (11) The names and addresses of all persons owning the royalty or leasehold interests in acreage abutting or adjoining the acreage to be attributed that is operated by the applicant or on which the applicant has a lease or an interest in the lease, and a certificate of mailing indicating the date on which service of a copy of the application was made to each person; (12) A statement advising each person listed in paragraphs (7) through (11) of this subsection that the person has 15 days in which to file a protest to the application with the conservation division pursuant to the provisions of K.A.R. 82-3-135b; and
1264 Id. § 82-3-300(c).
247
(13) Any other relevant information that the commission may require.1265
In addition to providing notice to each person as outlined above, the applicant must also publish
notice “in at least one issue of the official county newspaper of each county in which lands
affected by the application are located and in the Wichita Eagle newspaper.”
1266
[f] Unitization.
Upon such
notice, the application will be held in abeyance for 15 days to allow potential protests as
discussed above.
In the absence of special order, persons holding oil and gas interests within a shared pool
may establish a terms for unitization by agreement. Under the Act, “if all mineral and royalty
owners[,] and not less than 90% of the working interest owners” approve, in writing, a contract
for unit operation, such agreement “shall become effective without application to or order by the
Commission.”1267 A “working interest owner” is an “owner of tracts or interests who, in the
absence of a unitization order, would have the right to drill and operate a well or wells on the
separately owned tracts comprising the unit.”1268
Prior to such a contract becoming effective, those seeking unitization must file a copy of
the agreement with the Commission and “notify all working interest owners of the intention to
conduct the unit operation” in the same manner required for notice of an application for unit
operation.
1269
1265 Id.
The notice must inform those owners that each has 30 days to institute
proceedings before the Commission challenging the agreement. 1270 If no such proceedings
occur, the contract for unitization becomes effective after that 30-day period.1271
The Act allows any working interest owner to file an application with the Commission
for an order establishing unit operation of a pool, or any portion thereof.
1272
(1) A description of the land and pool or part thereof to be so operated, termed the unit area;
The application
must contain the following:
(2) A statement of the type of operations contemplated for the unit area; (3) A copy of a proposed plan of unitization which the applicant considers fair, reasonable and equitable; (4) A copy of a proposed operating plan covering the manner in which the unit will be supervised and managed and costs allocated and paid; and, (5) An allegation of the facts required to be found by the Commission [provided below].1273
The facts to be alleged in the application must all be found accurate by the Commission.
1274
(a)(1) The primary production from [the applicant pool or part thereof] has reached a low economic level and, without introduction of artificial energy, abandonment of oil or gas wells is imminent; or, (2) the unitized management, operation and further development of [the applicant pool or part thereof] is economically feasible and reasonably necessary to prevent waste within the reservoir and thereby substantially increase the ultimate recovery of oil or gas;
After notice and a hearing, the Commission will grant a unitization order only if the following
conditions exist:
(b) The value of the estimated recovery of oil or gas substantially exceeds the estimated additional cost incident to conducting [unitized] operations; and, (c) The proposed operation is fair and equitable to all interest owners.1275
If the Commission determines that such facts are true, it may grant an order for unit
operation.1276
A unitization order issued by the Commission will not come into effect without formal
approval from a proportion of relevant interest-holders.
1277 The percentage of ownership
approval required will depend on the findings of the Commission in granting the order. If the
Commission grants the order upon finding that “primary production from [the applicant pool or
part thereof] has reached a low economic level and, without introduction of artificial energy,
abandonment of oil or gas wells is imminent,”1278
approved in writing by those persons who, under the…order, will be required to pay at least 63% of the costs of the unit operation, and also by the owners of at least 63% of the production or proceeds thereof that will be credited to royalties, excluding overriding royalties or other like interests which are carved out of the leasehold estate.
then the order must be
1279
If the order is granted because “the unitized management, operation and further development of
[the applicant pool or part thereof] is economically feasible and reasonably necessary to prevent
waste within the reservoir and thereby substantially increase the ultimate recovery of oil or gas,”
the order must be:
approved in writing by those persons who, under the commission's order, will be required to pay at least 63% of the costs of the unit operation, and also by the owners of at least 75% of the production or proceeds thereof that will be credited to royalties, excluding overriding royalties or other like interests which are carved out of the leasehold estate.1280
In either case, the Commission must make a formal finding that the plan for unitization
has been so approved, and may hold supplemental hearings to obtain such approval.1281 If the
proposed order has not been approved within six months of entry, it “shall cease to be of further
force and effect and shall be revoked” unless the Commission finds good cause for extending the
approval period.1282
A unitization order must be “upon terms and conditions that are just and reasonable” and
provide a unit operation plan that includes the following:
(a) A legal description in terms of surface area of the pool or a part thereof to be so operated, termed "the unit area"; (b) A statement of the nature of the operations contemplated; (c) An allocation to the separately owned tracts in the unit area of all the oil and gas that is produced from the unit area and is saved; (d) A provision for the credits and charges to be made in the adjustment among the working interest owners in the unit area for their respective investments in wells, tanks, pumps, machinery, materials and equipment contributed to the unit operations; (e) A provision providing how the costs of unit operations, including capital investments, shall be determined and charged to the separately owned tracts and how such costs shall be paid, including a provision providing when, how and by whom the unit production allocated to a working interest owner who does not pay the share of the cost of unit operations charged to such owner, or to the interest of such owner, may be sold and the proceeds applied to the payment of such costs; (f) A provision whereby a non-operating working interest owner shall be furnished, but not more often than once a month, reasonably detailed information regarding the nature and amount of the various items of costs and expenses, including capital investments, chargeable against the interest of the non-operating working interest owners; (g) A provision for carrying any non-operating working interest owner on a limited, carried or net-profits basis, payable out of production, upon terms and conditions determined by the Commission to be just and reasonable, or otherwise financing any non-operating working interest owner who elects to be carried or otherwise financed or who does not meet the owner's financial obligations with the unit and a provision for establishing a
1281 Id. 1282 Id. This ‘good cause’ extension period may be no more than 60 days.
251
reasonable rate of interest and a penalty on all unpaid expenses, in amounts established by rules and regulations adopted by the Commission; (h) A provision for the supervision and conduct of the unit operations, including the selection, removal or substitution of an operator from among the working interest owners to conduct the unit operations; (i) A provision for a voting procedure for the decision of matters to be decided by the working interest owners in respect to which each working interest owner shall have a vote with a value corresponding to the percentage of the costs of unit operations chargeable against the interest of such owner; (j) The time when the unit operations shall commence and the manner in which, and the circumstances under which, the unit operations shall terminate and for the settlement of accounts upon such termination; (k) A provision specifying the particular records the unit operator shall keep and the detailed accounting procedure that the unit operator shall follow; and (l) Such additional provisions that are found to be appropriate for carrying on the unit operations and for the protection of correlative rights.1283
[g] Allocation of Production and Costs.
As expressed above, the terms upon which production and costs are distributed among
interest-holders in the unit area must be stated in the applicable unitization order. The Act
provides that “[t]he portion of the unit production allocated to any tract, and the proceeds from
the sale thereof, shall be the property and income of the several persons to whom, or to whose
credit, the same are allocated or payable under the order providing for unit operations.”1284
Further, all real and personal property “acquired in the conduct of unit operations…shall be
acquired for the account of the working interest owners within the unit area, and shall be the
property of such owners in the proportion that the expenses of unit operations are charged.”1285
1283 Id.
1284 Id. § 55-1306. 1285 Id.
252
The obligation of each working interest owner within the unit, whether operator or non-
operator, “at all times shall be several and not joint or collective, and a working interest owner of
the oil or gas rights in [each] separately owned tract shall not be . . . obligated or liable . . . for
more than the amount apportioned . . . or charged to his or her interest in the separately owned
tract pursuant to the order.”1286
The Act stipulates a one-eighth minimum production right for any owner subject to a
unitization order. As such, “a [one-eighth] part of the production allocated to each tract under an
order . . . shall in all events be and remain free and clear of any cost or expense of developing or
operating the unit.”
1287 Further, if a lease pertaining to a tract or interest stipulates a royalty or
other payment or obligation in excess of one-eighth of production, then “the working interest
owner subject to such excess payment or other obligation shall bear and pay the same.”1288
Production that is saved (not used in operation or unavoidably lost) will be allocated in
accordance with any controlling agreement among all interest owners. If no agreement exists,
the Commission will “determine the relative value of the separately owned tracts in the unit area,
exclusive of physical equipment, for development of oil and gas by unit operations, and the
[saved] production allocated to each tract shall be the proportion that the value of each tract so
determined bears to the total value of all tracts in the unit area.”
1289
In general terms, “[a] plan of unitization shall not be considered fair and reasonable if it
contains a provision for operating charges which include any part of district or central office
acres.” 1317 This is the default attributable acreage for each well that satisfies the 330-foot
setback requirement. Unless otherwise excepted (and apart from those counties in eastern
Kansas noted above), “each [oil or] gas well located nearer than 330 feet to any lease or unit
boundary line shall have acreage attributed to it by the establishment of an acreage attribution
unit.”1318 The acreage attribution unit will have an identical length and width, each defined “as
being twice the distance from the well to the nearest lease or unit boundary.”1319 In order to
properly allocate production, a well with attributable acreage of less than 10 acres will be granted
an allowable that is “reduced in the same proportion that the acreage attributable to the well
bears to 10 acres.”1320
While equitable factors must be considered in determining allowable production, the Act
and Commission regulations impose minimum amounts that each well must be allowed to
produce.
1321 For a well located on a spacing unit or attributable acreage of 10 acres or more, the
minimum allowable that the Commission may set is 25 barrels of oil per day.1322 However, if
the “acreage attributable” to a well is less than 10 acres, “the 25 barrels per day minimum…may
be reduced in the proportion that the acreage attributable to the well bears to 10 acres.”1323
[b] Exceptions.
If necessary to prevent waste or protect correlative rights, the Commission may grant a
well location exception to setback rules, as well as to an excepted well’s attributable acreage and
1317 Id. §§ 82-3-207(a), 82-3-312(c). 1318 Id. § 82-3-312(d); see also id. § 82-3-207(b). 1319 Id. §§ 82-3-207(b), 82-3-312(d). 1320 Id. §§ 82-3-207(c), 82-3-312(e). 1321 Kan. Stat. Ann. § 55-604(b) (2010). 1322 Id. § 55-604(b)(3). “Attributable acreage” generally refers to the surface area from under which a single well may produce, or the “acreage assigned to a well in accordance with [a] well spacing program” for a prorated pool or field. Kan. Admin. Regs. § 82-3-101(7) (2011). 1323 Kan. Stat. Ann. § 55-604(b)(3) (2010).
258
allowable production.1324
(1) A brief explanation of the exception or exceptions requested;
An exception will only be granted upon proper application containing
the following:
(2) The proposed location of the well, including the distance to the nearest lease or unit boundary line; (3) A list of the following:
(A) Each offset operator whose lease line is located less than the required distance from the proposed location; (B) Each unleased offset mineral owner whose property boundary is located less than the minimum distance required by subsection (a) or (b) from the proposed locations; and (C) The applicant’s lessor or lessors, if the applicant operates any lease that will be situated less than the minimum distance required by subsection (a) or (b) from the proposed well location;
(4) The acreage attributable to the well; and, (5) The allowable requested.1325
In addition, the application must be accompanied by a notice of intent to drill and a plat
displaying: “(1) the property on which the well is sought to drilled; (2) all other completed,
partially drilled or permitted wells on the property; and (3) all adjacent properties and wells.”
1326
[4] – Minimum Operator Control.
A voluntary agreement to unitize operations will be valid and effective without a
Commission order “if all mineral and royalty owners[,] and not less than 90% of the working
interest owners” approve, in writing, a contract expressing such intent.1327
A unitization order issued by the Commission requires approval of a certain percentage
of relevant owners, depending on the grounds for granting the order.
1328
1324 Kan. Admin. Regs. § 82-3-108(c) (2011).
If the Commission
grants the order upon finding that “primary production from [the applicant pool or part thereof]
has reached a low economic level and, without introduction of artificial energy, abandonment of
oil or gas wells is imminent,”1329
approved in writing by those persons who, under the…order, will be required to pay at least 63% of the costs of the unit operation, and also by the owners of at least 63% of the production or proceeds thereof that will be credited to royalties, excluding overriding royalties or other like interests which are carved out of the leasehold estate.
then the order must be
1330
If the order is granted because “the unitized management, operation and further development of
[the applicant pool or part thereof] is economically feasible and reasonably necessary to prevent
waste within the reservoir and thereby substantially increase the ultimate recovery of oil or gas,”
the order must be
approved in writing by those persons who, under the commission's order, will be required to pay at least 63% of the costs of the unit operation, and also by the owners of at least 75% of the production or proceeds thereof that will be credited to royalties, excluding overriding royalties or other like interests which are carved out of the leasehold estate.1331
If the applicable percentage of owners have not approved the order within six months of
issuance, it will not go into effect unless the Commission finds good cause to extend the
approval period for an extra 60 days.
1332
[5] – Directional Drilling.
An operator or other person responsible for operation must submit a written application
to the Commission prior to drilling “any hole where [the] intended deviation from the surface to
the top of the producing formation exceeds seven degrees.” 1333 The Commission may only
approve such deviated drilling after sufficient notice and a hearing.1334
[6] – Options.
The Act acknowledges rights of election and optional carrying for those owners who
refuse or are unable to pay drilling and operating costs. 1335
a provision providing when, how and by whom the unit production allocated to a working interest owner who does not pay the share of the cost of unit operations charged to such owner, or to the interest of such owner, may be sold and the proceeds applied to the payment of such costs…;
The options available for non-
consenting owners and any other terms of election must be stated in the unitization agreement or
order that, if applicable, must include:
If parties involved choose to establish a system to carry non-contributing working interest owner,
they may do so and provide for the terms of such in the applicable agreement or order. The Act
requires that an order or agreement include:
A provision for carrying any non-operating working interest owner on a limited, carried or net-profits basis, payable out of production, upon terms and conditions determined by the Commission to be just and reasonable, or otherwise financing any non-operating working interest owner who elects to be carried or otherwise financed or who does not meet the owner's financial obligations with the unit and a provision for establishing a reasonable rate of interest and a penalty on all unpaid expenses, in amounts established by rules and regulations adopted by the Commission.1336
In situations where an operator or owner carries a non-contributing owner, the agreement
or order may also specify a ‘risk-penalty.’
1337
1333 Kan. Admin. Regs. § 82-3-103a(a) (2011).
The terms must remain just and reasonable to all
1334 Id. § 82-3-103a(b). 1335 See Kan. Stat. Ann. § 55-1305 (2010). 1336 Id. 1337 Id.
261
parties affected and reimbursement will be taken from the non-contributing owner’s share of
production.1338
(1) One hundred percent of the unpaid portion of the owner's share of the cost of aboveground surface equipment beyond the wellhead connection, including, but not limited to, stock tanks, separators, treaters, pumping equipment and piping, plus 100% of the unpaid portion of the owner's share of the cost of operation of the unit, all subject to the rate of interest established;
Under the Act, such penalties may not exceed:
(2) Three hundred percent of the unpaid portion of the owner's share of the costs and expenses of drilling wells in the unitized area, including staking, well site preparation, rigging up, or drilling, and reworking, deepening or plugging back, testing and completing wells; and (3) Three hundred percent of the unpaid portion of the owner's share of the costs and expenses of underground pipeline systems, expenses for injected substances and any other non-recoupable expenses incurred.1339
1338 Id.
1339 Id.
262
§ 18.01 Analysis of Kentucky Regulatory Framework.
[1] – Name of the Governing Body.
In Kentucky, the Department of Natural Resources’ Division of Oil and Gas (“Division”)
oversees the majority of oil and gas production in the state. 1340 However, the Department also
includes the Oil and Gas Conservation Commission (“Commission”), which has express
authority to administer those sections under the state’s oil and gas conservation statute (“Act”)
particular to deep-well pooling and unitization.1341
While the Act discusses issues relevant to the protection of coal rights, the significance of
coal production to Kentucky’s economy prompted the legislature to codify statutes particular to
the coalbed methane regulation in 2004.
1342
[2] – Membership on the Governing Body.
The Kentucky coalbed methane laws will be
discussed separately in §§ 18.01. and 18.02.
The Division and Commission work in tandem to implement the Act. The Division is led
by a director, who is appointed by the secretary of the Energy and Environment Cabinet.1343 The
director must have at least five years field experience oil and gas production or exploration when
appointed.1344 While in office, the director may not acquire a financial interest in any activity
related to oil and gas production within the state.1345 The director may employ staff to carry out
daily Division activities.1346
1340 Ky. Rev. Stat. Ann. § 353.530(2) (LexisNexis 2010) (The Division director shall “administer the provisions of §§ 353.500 to 353.720…”).
1341Id. § 353.565(7) (“The Commission shall execute and carry out, administer and enforce the provisions of §§ 353.651 and 353.652.”). 1342 See Ky. Rev. Stat. Ann. §§ 349.005 et seq (2010). 1343 Id. § 355.530. 1344 Id. § 355.530. 1345 Id. 1346 See Dep’t. Nat. Resources, Div. Oil & Gas, http://oilanggas.ky.gov/Pages/AboutUs/aspx (last visited June 15, 2011) (“The Division of Oil and Gas currently employs 14 field inspectors, 3 field supervisors, and 9 administrative staff personnel.”).
263
The Commission is comprised of five members, four of which are appointed by the
governor.1347 The fifth member is the director of the Division, who serves as the Commission’s
non-voting chairman.1348 The four gubernatorial appointees serve staggered four-year terms.1349
Each must be a state resident, with two hailing from eastern Kentucky and two from western
Kentucky.1350 No more than one of these four may be “directly employed in the exploration for
or the production of oil and gas, or derive more than 50% of [his or her] income” from such
activity.1351 If applicable, a member may not participate in deliberation or vote on any matter in
which such financial interests exist; however, all members may be involved in general matters,
“such as the fixing of statewide spacing patterns,” regardless of an interest therein.1352
For clarity, the Division and Commission will hereafter be referred to collectively as the
Department of Natural Resources (“the Department”), with which all authority rests under the
Act.
1353
[3] – Scope of Authority.
The Department maintains “jurisdiction over all persons and property necessary” to
enforce the Act.1354 The Department may promulgate rules and regulations and “take all actions
necessary to assure efficient oil and gas operations.”1355
…to foster conservation of all mineral resources, to encourage exploration for such resources, to protect correlative rights of land and mineral owners, to prohibit waste and unnecessary surface loss and damage and to encourage the maximum recovery of oil and
The Department acts pursuant to the
public interests stated in the Act, which are
1347 Ky. Rev. Stat. Ann. § 353.565(1) (LexisNexis 2010). 1348 Id. The director may cast a deciding vote in the event of deadlock among the four voting Commission members. 1349 Id. 1350 Id. 1351 Id. 1352 Id. 1353 Ky. Rev. Stat. Ann. § 353.540 (LexisNexis 2010). 1354 Id. 1355 Id. § 353.500(2).
264
gas from all deposits thereof now known and which may hereafter be discovered; and to promote safety in the operation thereof. 1356
[a] Matters Governed.
The Act expressly prohibits waste.1357
(a) The locating, drilling, equipping, operating or producing of any oil or gas well, or wells drilled, deepened, or reopened in a manner that causes, or tends to cause, a reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or contrary to any provision of, or any order, rule or regulation promulgated [under the Act];
“Waste” means “physical waste as that term is
generally understood in the oil and gas industry,” and in particular includes:
(b) Permitting the migration of oil, gas or water from the stratum in which it is found into other strata, thereby ultimately resulting in the loss of recoverable oil or gas; (c) The drowning with water of any stratum or part thereof capable of producing oil or gas in paying quantities, except for secondary recovery purposes, or in hydraulic fracturing or other completion practices; (d) The unreasonable damage to underground, fresh or mineral water supply, workable coal seams, or other mineral deposits in the operations for the discovery, development, production or handling of oil and gas; (e) The unnecessary or excessive loss of oil and gas by spillage or venting or destruction of oil or gas or their constituents; and (f) The drilling of more wells than are reasonably required to recover efficiently the maximum amount of oil and gas from a pool.1358
The Act explicitly states that it “shall not be construed to authorize any limitation of production
of oil or gas…to prevent or control [solely] economic waste[,] or to limit production to market
demand.”
1359
In discharging its duties, the Department may require: identification of mineral
ownership; the making and filing of logs and surveys; drilling and operation [as to] prevent the
(a) State that an application for a pooling order is being filed …; (b) Describe any tract, or portion thereof, proposed to be pooled; (c) In the case of an unknown owner, identify the name of the last known owner; (d) In the case of an non-locatable owner, identify the owner and owner’s last known address; and, (e) State that any party claiming an interest in any tract, or portion thereof, proposed to be pooled should contact the operator at the published address and provide a copy of the notification [to the Department] within 20 days of the date of publication.1392
A pooling order must provide certain information to govern the development and operation of
the pooled area. In particular, the order must:
(1) Authorize the drilling, deepening, or reopening, and the operation of a well for the production of oil or gas on the tracts or portions thereof pooled; (2) Designate the operator to drill and operate the well; (3) Prescribe the time and manner in which all owners of operating interests in the pooled tracts or portions thereof may elect to participate therein; (4) Provide that all reasonable costs and expenses of drilling, deepening, or reopening, and the completing, operating, plugging, and abandoning the well shall be borne, and all production from the well shall be shared, by all owners of operating interests in proportion to the net mineral acres in the pooled tracts owned or under lease to each owner; and, (5) Make provision for the payment of the reasonable actual cost thereof, including a reasonable charge for supervision, by all those who elect to participate therein.1393
Any person who has transferred his or her to oil and gas rights under a lease or other
contract is not considered an owner requiring notice.
1394 A certified copy of a pooling order may
be recorded in the clerk’s office of any county or counties in which all or a portion of the pooled
The Act also provides specific procedure for pooling particular to deep wells.1396 In this
case, multiple owners may voluntarily “pool their tracts or interests for the development and
operation of the drilling unit.”1397 In the alternative, any operator having an interest in the
drilling unit may file an application to request a pooling order.1398
After notice is given “to all persons reasonably known to own an interest in the oil or gas
in the drilling unit,” and a hearing is held, the Department may “enter an order pooling all tracts
or interests in the drilling unit for the development and operation thereof and for the sharing [of]
production therefrom.”
1399
(1) Authorize the drilling and operation of a deep well for the production of oil or gas from the pooled acreage;
A pooling order must establish “just and reasonable” terms to govern
the operation, and in particular must:
(2) Designate the operator to drill and operate such deep well; (3) Prescribe the time and manner in which all owners of operating interests in the pooled tracts or portions of tracts may elect to participate therein; (4) Provide that all reasonable costs and expenses of drilling, completing, equipping, operating, plugging, and abandoning the deep well shall be borne, and all production therefrom shared, by all owners of operating interests in proportion to the acreage in the pooled tracts owned or under lease to each owner; and, (5) Make provision for payment of all reasonable costs thereof, including reasonable charge for supervision and for interest on past due accounts, by all those who elect to participate therein.1400
By its own motion, or upon the application of a lessee or owner within a proposed unit,
the Department may hold a hearing to consider the necessity for unit operations of all or part of a
pool, “for the production of oil and associated gas in order to increase their ultimate recovery . . .
so that each owner in the [unit area] shall have the opportunity to recover his fair and equitable
(a) A description of the area to be included in the unit, with a map attached, and a description of the pool or pools, or portions thereof, to be included within the unit;
An application for proposed unit operations must provide
the following:
(b) A statement of the nature of the unit operations contemplated; (c) A proposed allocation of production and reserves among the separately owned tracts and interests contributed to the unit; (d) The procedure upon which wells and equipment of the separately-owned tracts and interests are to be used and compensated for in unit operations; and, (e) Documentation that the application is approved by at least [51%] ownership in the interests proposed for inclusion in the unit.1402
A unitization hearing will be conducted under the terms of state administrative
procedure.
1403 The Department will provide notice “to all persons reasonably known…to be a
lessee or owner of an oil and gas interest in a pool or pools within a proposed unit.”1404 After
notice and a hearing, the Department will enter an order “establishing a unit and requiring unit
operation and development” thereof if: (1) unitization is reasonably necessary to increase
ultimate recovery and the estimated value of additional recovery exceeds to additional cost of
unit operations; or, (2) unitization is needed to prevent waste and protect correlative rights of
owners in the unit area.1405
(a) Authorize the unit operation of a pool or pools, including drilling, deepening, reopening, conversion to injection wells, and operation of all wells within the unit for the production of oil and gas from the unit:
If granted, a unitization order must:
(b) Designate the unit operator of the operation; (c) Approve a unit operating agreement; (d) Provide for the allocation of production and reserves among all separately owned tracts and interests in the unit;
1401 Ky. Rev. Stat. Ann. § 353.645(1) (LexisNexis 2010). 1402 Id. § 353.645(2). 1403 Id.; see also id. § 13B.008 et seq. 1404 Id. The Department may require an application fee from the applicant for the cost of notice. 1405 Id. § 353.645(3).
272
(e) Provide for the proportionate allocation of all reasonable costs and expenses of unit operations as these costs and expenses are set out in the approved operating agreement; and (f) Establish the spacing approved for the unit.1406
Any pooling or unitization order must offer information outlining the rights and obligations of
any owner who does not desire to participate in the joint operation.
1407
The Act also provides specific provisions governing unitization of interests within a
drilling unit. Upon the application of “any operator in a deep well pool” productive of oil and/or
gas, the Department will provide notice “to all persons reasonably known to own an interest in
the oil or gas in the pool,” and conduct a hearing to determine whether a compulsory unitization
order should be issued.
1408
A unitization order will only be granted if the Department finds that: (1) unitization is
reasonably necessary to prevent waste; (2) the proposed unit operating plan will increase oil and
gas recovery from the pool, and is economically feasible; and, (3) the production of oil and gas
“from the unitized pool can be allocated in a manner to insure the recovery by all owners of their
just and equitable share of the production.”
1409 Prior to entering the order, the Department must
also receive written consent to the unitization agreement by the owners of at least “75% in
interest as production is to be allocated of the royalty in the unit area.”1410 Further, both the
unitization agreement and “a contract incorporating the required arrangements for operations”
must be approved by owners of “at least 75% in interest as costs are shared under the terms of
drilling at such a location unduly burdensome.”1458 If an exception is sought due to potentially
burdensome topographical conditions, the operator seeking such must establish that the
Department is able to effectively offset any advantage that may accrue by virtue of the exception
being granted. 1459 In turn, upon granting such exception, the Department must offset any
resulting advantage in order to properly protect the correlative rights of other owners or units
within the pool.1460
The Act acknowledges that default spacing regulations to not apply to lands within an
incorporated municipality which, by ordinance, has minimum requirements that are “not less
than [those] prescribed [herein].”
1461
(1) A deep oil well at a depth less than 7,000 feet may be located no closer than 438 feet to the boundary of the proposed unit.
Notwithstanding an exception to default spacing rules
being granted, an approved location must comply with the following limitations for deep wells:
(2) A deep oil well at a depth of 7,000 feet or more may be located no closer than 625 feet to the boundary of the proposed unit. (3) A deep gas well at a depth less than 7,000 feet may be located no closer than 875 feet to the boundary of the proposed unit. (4) A deep oil well at a depth of 7,000 feet or more may be located no closer than 1,250 feet to the boundary of the proposed unit.1462
A “wildcat well” refers to either (1) “a deep well drilled with the intent of discovering
and producing hydrocarbons from a formation or formations not previously productive of oil or
gas[,] from a well within 25,000 feet of its location;” or, (2) “a well drilled under such proven
geological conditions that, even though located less than 25,000 feet from the nearest deep well
previously productive of oil or gas, will not, if completed successfully, produce from a
rights of coalbed methane operators…and owners in a pool…so that each operator and owner
obtain his or her just and equitable share of production.”1490
The CBM Board is authorized to rule on objections to proposed location or operation of
coalbed methane wells and appeals of coalbed methane well permit denials made by the
Department. In addition, the CBM Board conducts hearings under the CBM Act, including those
for drilling unit applications, requests for pooling or unitization orders, and the adoption of
special field rules.
1491
[a] Matters Governed.
Committing or inducing waste of coalbed methane is statutorily prohibited.1492
(a) The locating, drilling, equipping, operating or producing of any coalbed methane well or wells drilled, deepened, or reopened in a manner that causes, or tends to cause, a reduction in the quantity of coalbed methane ultimately recoverable from a pool under prudent and proper operations, or contrary to any provision of, or any order, rule or regulation promulgated [under the CBM Act];
“Waste”
includes “physical waste as that term is generally understood in the oil, gas, and coalbed methane
industry,” as well as:
(b) Permitting the migration of coalbed methane from the stratum in which it is found into other strata, thereby ultimately resulting in the loss of recoverable coalbed methane; (c) The drowning with water of any stratum or part thereof capable of producing coalbed methane in paying quantities, except for secondary recovery purposes, or in hydraulic fracturing or other completion practices; (d) The unlawful damage to underground, fresh or mineral water supply, coalbeds, or other mineral deposits in the operations for the discovery, development, production or handling of coalbed methane; (e) The unnecessary or excessive loss of coalbed methane by spillage or venting or destruction of coalbed methane or its constituents; and,
(f) The drilling of more wells than are reasonably required to recover efficiently the maximum amount of coalbed methane from a pool.1493
Similar to Kentucky’s Oil and Gas Conservation Act, the CBM Act does not “authorize any
limitation of production of coalbed methane from any coalbed methane well, lease, drilling unit,
pool, field or property to prevent or control economic waste[,] or to limit production to market
demand.”
1494
[b] Department Procedure.
No person may conduct operations to extract or produce coalbed methane in the state
without first obtaining the applicable permits.1495
(a) The county in which the coalbed methane well drill site is located;
A drilling permit application must include an
attached plat displaying:
(b) The name of the surface owner of the drill site tract, the acreage of the drill site tract, the names of the surface owners of adjacent tracts, the names of all coal interest holders from the surface to [50] feet below the deepest penetration of the coalbed methane well on the tract on which the well is proposed to be located, and the names of all oil and gas owners from the surface to [100] feet below the deepest penetration of the coalbed methane well on the tract on which the well is proposed to be located; (c) The proposed or actual location of the coalbed methane well determined by bearing and distance, relative to [2] permanent points or monuments that appear on the applicable United States Geological Survey [7½] minute topographic quadrangle map; (d) The location of any other existing or permitted coalbed methane well or any oil or gas well located within [1,500] feet of the well; (e) The outside boundary of the mineral tract from which the coalbed methane is to be produced if within [750] feet of the well; and, (f) The number to be given the coalbed methane well, the earliest date for commencement of drilling, the earliest date for
1493 Id. 1494 Id. § 349.160(5). To avoid confusion, the legislature clarified coalbed methane regulation is subject only to the provisions of the CBM Act, unless otherwise stated therein. See id. § 349.160(7). 1495 Id. § 349.035(5).
288
commencement of any stimulation of the coalbed methane well, and if horizontal drilling of a coalbed methane well is proposed, the vertical and horizontal alignment and extent of the coalbed methane well.1496
The applicant must also provide notice of the application and a copy of the plat to all relevant
surface owners, coal owners, and permitted operators noted therein.
1497 Such notice must inform
the relevant parties that each has twenty days from receiving notice to file an objection to the
proposed well, which will be heard and considered by the CBM Board.1498
Provided that relevant conditions stated in the CBM Act are met, and no objection is filed
within twenty days, the Department will “immediately issue a drilling permit to the well
operator[,] approving the location of the well and authorizing the well operator to proceed to drill
at that location.”
1499 If a coal interest holder objects to a well permit for proposed stimulation,
the Department will not issue a permit allowing such practices “unless the applicant has
obtained…an agreement between the coal interest holders of any workable coalbed within 500
horizontal feet of the proposed coalbed methane well to be stimulated and within the 500 foot
horizontal radius and 50 vertical feet above or below the workable coalbed…to be
stimulated.”1500
However, such proof is not required if the operator has a contractual right to develop and
stimulate by virtue of an existing lease, deed, or other agreement.
1501
1496 Ky. Rev. Stat. Ann. § 349.015(1) (LexisNexis 2010).
In addition, if the operator
fails to supply the Department with an agreement to stimulate, he or she may request a hearing
before the Board by filing an affidavit that provides: (1) a statement that the coal interest holder
1497 Id. § 349.015. 1498 Id. 1499 Id. § 349.020(4). 1500 Id. § 349.050(1). The CBM Act defines “stimulat[ion]” as “any action taken to increase the flow of coalbed methane, or the inherent productivity of a coalbed methane well, including but not limited to fracturing, shooting, acidizing, or waterflooding, but excluding cleaning out, bailing, or workover operations.” Id. § 349.010(28). 1501 Id. § 349.050(2).
289
has refused to sign a written agreement to stimulate the workable coalbed; (2) a statement
detailing the efforts undertaken by the operator to obtain such consent; and, (3) a statement that
the proposed method of stimulation does not involve the use of explosives, pose a significant
adverse affect on the mineability of the workable coalbed, or impair mine safety.1502
The CBM Board conducts proceedings under the administrative rules codified in Ky.
Rev. Stat. §§13B.008 et seq.
1503 Upon an objection to a permit application, the CBM Board will
determine whether the Department should issue the permit, and may include any conditions
needed to ensure safe and equitable production from the well.1504
(a) The declaration of public policy and legislative findings as set forth in this chapter;
In deciding whether to grant
the permit, the CBM Board will consider the following factors applicable each proceeding:
(b) Whether the proposed coalbed methane well can be drilled safely, taking into consideration the dangers from creeps, squeezes, or other disturbances due to the extraction of coal; (c) The feasibility of moving the proposed drilling location to another location; (d) Whether any stimulation of the workable coalbed will have a significant adverse affect on the mineability of that workable coalbed or any other workable coalbeds within [500] feet of the proposed coalbed methane well to be stimulated or within the [500] foot horizontal radius and [50] vertical feet above or below the workable coalbed proposed to be stimulated or impair mine safety; (e) Whether the drilling location is above or in close proximity to any mine opening, shaft, entry, travelway, airway, haulageway, drainageway or passageway, or to any proposed extension thereof, any abandoned, operating coal mine or any coal mine already surveyed and platted but not yet being operated; (f) Whether the proposed drilling can reasonably be done through an existing or planned pillar of coal, or in close proximity to an existing or planned pillar of coal, taking into consideration the surface topography; (g) The extent to which the proposed drilling location interferes with the safe recovery of coal or coalbed methane;
(h) The extent to which the proposed drilling location will unreasonably interfere with present or future coal mining operations; (i) The technology and methods proposed for the safe and efficient recovery of coal and coalbed methane; (j) The practicality of locating the coalbed methane well out of a uniform pattern with other wells; (k) The surface topography and use; and, (l) Any other factor the review board determines would be considered consistent with [the CBM Act].1505
The CBM Board will “enter a written order containing findings of fact and conclusions which
address any [of these] considerations,” and file it with the Department. The order also provides
the CBM Board’s recommended action, which may include issuing permits, enforcing general
orders, and granting modifications or exceptions thereto.
1506
[4] – Process for Pooling and Matters Covered.
The CBM Act authorizes the CBM Board to establish and modify drilling units, assist in
the enforcement of voluntary pooling agreements of separately-owned interests therein, and
compulsorily pool such interests for the joint development of coalbed methane wells.1507
[a] Drilling Units.
The CBM Act defines a “drilling unit” as “the maximum area in a pool which may be
drained efficiently by one well so as to produce the reasonable maximum recoverable coalbed
methane in the area.”1508 Upon its own motion, or upon the application of an operator or owner
of coalbed methane, the Board may “establish or modify drilling units, establish or modify field
rules, or unitize coalbed methane wells, pools or fields” in order to prevent waste or protect
correlative rights.1509
1505 Id. § 349.065(4).
If possible, drilling units will be uniform in size and shape for an entire
(a) The area which may be drained efficiently and economically by the proposed coalbed methane well or wells and the spacing requirements of Section 349.075;
Upon request for the creation or modification of a drilling unit or applicable
field rules, the Board will consider the following factors in making its determination:
(b) The plan of development for the coal, that drilling units conform to mine development plans, and the need for proper ventilation of any mines or degasification of any affected coal seams; (c) The nature and character of any coal seam or seams which will be affected by the coalbed methane well or wells; (d) The surface topography and mineral boundaries of the lands underlaid by the coal seams to be included in the unit; (e) Evidence relevant to the proper boundary of the drilling unit; (f) The nature and extent of ownership of each coalbed methane owner or claimant and whether conflicting claims exist; (g) Whether the applicant for the drilling unit proposes to be the operator of the coalbed methane well within the drilling unit; and if so, whether the applicant has a lease or other agreement from the owners or claimants of a majority interest in the proposed drilling unit; (h) Whether a disagreement exists among the coalbed methane owners or claimants over the designation of the operator for any coalbed methane well within the drilling unit; and if so, relevant evidence to determine which operator can properly and efficiently develop the coalbed methane within the drilling unit for the benefit of the majority of the coalbed methane owners; (i) If more than one person is interested in operating a coalbed methane well within the drilling unit, the estimated cost of submitting by each such person for drilling, completing, operating and marketing the coalbed methane from any proposed coalbed methane well or wells; (j) Any other available geological or scientific data pertaining to the pool which is proposed to be developed; (k) The correlative rights of the operators and owners of coalbed methane, so that each operator and owner may obtain his or her just and equitable share of production from the coalbed methane; and, (l) Any other factor the review board determines should be considered consistent with KRS Chapters 350 and 352, and this chapter. 1511
1510 Id.
1511 Id. § 353.070(2).
292
Like drilling permits, the CBM Board will “enter a written order containing findings of fact and
conclusions which address any relevant considerations” and file an order with the Department
which: (1) establishes or modifies a drilling unit, field rules or unitizing coalbed methane wells,
pools or fields; (2) refuses to establish or modify a drilling unit, field rules or unitization of
coalbed methane wells, pools or fields; or (3) attaches certain conditions to the establishment or
modification of a drilling unit, field rules, or unitization of coalbed methane wells, pools or
fields.1512
[b] Spacing Rules.
The Board will not issue a permit for coalbed methane well operations unless the
proposed location complies with statutory spacing requirements.1513 Certain exceptions may be
granted to default spacing rules due to necessary modifications to drilling units if the
considerations above dictate such changes.1514 Further, spacing rules may be varied under a
voluntary pooling agreement.1515 Pursuant to legislative direction under the CBM Act, the Board
is charged with enacting regulations particular to horizontal coalbed methane wells.1516
[c] Authority to Integrate Production.
Owners or operators holding separately owned interests in a tract or tracts that are
embraced within a single drilling unit “may pool their interests for the development and
operation of the drilling unit by voluntary agreement.”1517 These agreements may be exercised
based on the right to pool or unitize as “granted in any gas or oil lease, coal lease, coalbed
(b) Describe any tract, or portion thereof, proposed to be pooled; (c) In the case of an unknown owner, identify the name of the last known owner; (d) In the case of a non-locatable owner, identify the owner and owner’s last known address; and, (e) State that any party claiming an interest in any tract, or portion thereof, proposed to be pooled should contact the permit applicant at the published address and provide a copy of the notification to the CBM Board within 20 days of the date of publication.1525
Whenever a permit applicant proposes to drill or conduct operations, and the ownership of the
right to produce coalbed methane is in dispute, the Department will refer the application to the
CBM Board to consider the issuance of a pooling order for the well.
1526 If the CBM Board finds
pooling reasonable, the Department will issue a permit and require the development and
operation of all pooled tracts and interests as a single leasehold estate in accordance with the
pooling order.1527
In making its determination, the CBM Board weighs the following factors that it
considers applicable to the proceeding:
(a) The area which may be drained efficiently and economically by the proposed coalbed methane well or wells and the spacing requirements of Ky. Rev. Stat. § 349.075; (b) The plan of development of the coal and the need for proper ventilation of any mines or degasification of any affected coal seams; (c) The nature and character of any coal seam or seams [that] will be affected by the proposed coalbed methane well or wells; (d) The surface topography and mineral boundaries of the lands underlaid by the coal seams to be included in the unit; (e) Evidence relevant to the proper boundary of the drilling unit; (f) The nature and extent of ownership of each coalbed methane owner or claimant and whether conflicting claims exist; (g) Whether the applicant for the drilling unit proposes to be the operator of the coalbed methane well or wells within the drilling unit; and if so, whether the applicant has a lease or other agreement
from the owners or claimants of a majority interest in the proposed drilling unit; (h) Whether a disagreement exists among the coalbed methane owners or claimants over the designation of the operator for any coalbed methane wells within the unit, and if so, relevant evidence to determine which operator can properly and efficiently develop the coalbed methane within the unit for the benefit of the majority of the coalbed methane owners; (i) If more than one person is interested in operating a coalbed methane well within the unit, the estimated cost submitted by each such person for drilling, completing, operating, and marketing the coalbed methane from any proposed coalbed methane well or wells; (j) Any other available geological or scientific data pertaining to the [proposed] pool … to be developed; (k) The correlative rights of the operators and owners of the coalbed methane, so that each operator and owner may obtain his or her just and equitable share of production from the coalbed methane; and, (l) Any other factor the CBM Board determines should be considered consistent with Ky. Rev. Stat. §§ 349, 350 and 352.1528
The CBM Board will render a decision to grant or deny a pooling order, and enter a written
statement of factual findings to support its ruling.
1529 The CBM Board will then file this written
order with the Department to grant or deny the pooling order, which may be conditioned upon
any issues the CBM Board proposes.1530
If granted, a coalbed methane pooling order must provide information to govern the
development and operation of the pooled area. Each pooling order will:
(1) Authorize the drilling, deepening, or reopening, and the operation of a well for the production of coalbed methane on the tracts or portions thereof pooled; (2) Designate the operator to drill and operate the well; (3) Prescribe the time and manner in which all owners of working interests in the pooled tracts or portions thereof may elect to participate therein; (4) Provide that all reasonable costs and expenses of drilling, deepening, or reopening, and the completing, operating, plugging,
and abandoning the well shall be borne, and all production from the well shall be shared, by all owners of working interests in proportion to the net mineral acres in the pooled tracts owned or under lease to each owner; and, (5) Make provision for the payment of the reasonable actual cost thereof, including a reasonable charge for supervision, by all those who elect to participate therein.1531
A pooling order must also establish a procedure for election rights for owners who do not wish to
participate in the operation, which are discussed in the following section.
1532
Any person who has transferred his or her to rights to coalbed methane under a lease or
other contract is not considered a working interest owner for notice purposes.
1533 A certified
copy of a pooling order may be recorded in the clerk’s office of any county or counties in which
all or a portion of the pooled area rests.1534
[d] Allocation of Production and Costs.
In general, the coalbed methane produced from any pooled well is “deemed for all
purposes to have been so produced from each tract or portion thereof included in the pool in
proportion to the amounts established in the pooling order.”1535 If pooling is ordered despite
ownership disputes, the order must also establish “an interest-bearing escrow account to be
maintained by the Department.” 1536
(a) Each participating working interest owner, except for the unit operator, shall deposit in the escrow account the owner’s proportionate share of the costs allocable to the ownership interest claimed by each participating working interest owner as set forth in the pooling order; and,
The escrow account will “receive deposits and hold
payments for costs and proceeds attributable to the conflicting interests” in the following
(b) The unit operator shall collect all proceeds from the sale or use of coalbed methane and deposit in the escrow account all proceeds attributable to the conflicting interests of lessors, lessees, or royalty owners and all proceeds in excess of the recovery of all capital costs and expenses and all ongoing operational expenses including reasonable overhead costs and operating fees attributable to conflicting working interests.1537
The Department will order payment of principal and any accrued interest from the escrow
account to all parties entitled thereto within 30 days an agreement among all claiming an
ownership interest, or a final determination of entitlement made by the Department.
1538
(a) Each legally entitled participating working interest owner shall receive a proportionate share of the proceeds attributable to the conflicting ownership interest;
Unless
otherwise consented to by such voluntary agreement among actual or potential owners, the
Department’s final determination will provide the allocation of production and costs as follows:
(b) Each legally entitled nonparticipating working interest owner shall receive a proportionate share of the proceeds attributable to the conflicting ownership interest, less the cost of being carried as a nonparticipating working interest owner as determined by the election of the person under the applicable pooling order; (c) Each person leasing or deemed to have leased its coalbed methane ownership interest to the unit operator shall receive a share of the royalty proceeds as set out in the applicable pooling order attributable to the conflicting interests of the lessees; (d) The unit operator shall receive the costs contributed to the escrow account by each legally entitled participating working interest owner, but only to the extent that the costs and expenses described in subsection (10)(b) of this section have not been recouped from production proceeds; (e) Each participating working interest owner who is determined not to hold an ownership interest shall receive a refund of all amounts placed in escrow pursuant to subsection (10)(a) of this section plus interest earned thereon; and, (f) All amounts remaining in escrow, after distribution of amounts described in paragraphs (a), (b), (c), (d), and (e) of this subsection,
requirements to all oil, gas, and coal owners of proposed pooled tracts, as well as the Board’s
consideration of ownership disputes at a pooling hearing.1550
[5] – Directional Drilling.
The Department has established more extensive plat requirements to be submitted with an
application for a permit of a horizontal well.1551 The CBM Act defines “horizontal drilling” to
include any “intentional act of drilling a borehole, shaft, or hole, which deviates from the vertical
for the purpose of penetrating a coal seam to produce coalbed methane.”1552 As noted above,
horizontal wells must comply with spacing requirements as measured by “the actual drilled
course of the well, its end point, the intersection of the well bore and the producing
formations.”1553
[6] – Options.
A pooling order must establish a procedure for an owner who claims a “working interest”
in pooled acreage but “does not decide to become a participating working interest owner.”1554
(a) Surrender, by means of sale or lease, the interest to a participating operator on a reasonable basis and for a reasonable consideration, which if not agreed upon will be one-eighth of the production attributable to the well; or,
This owner has two options under the CBM Act, and may either:
(b) Share in the operation of the well as a non-participating working interest owner on a carried basis after the proceeds allocable to his or her share equal 200% of the share of costs allocable to his or her interest.1555
1550 Ky. Rev. Stat. Ann. §§ 349.085(1)-(2) (LexisNexis 2010).
1551 Id. § 349.010(15). 1552 Id. 1553 805 Ky. Admin. Regs. 9:070 (2010). 1554 Ky. Rev. Stat. Ann. § 349.085(5) (LexisNexis 2010). The CBM Act defines “participating working interest owner” as “a coalbed methane owner or lessee who elects to bear a share of the risks and costs of drilling,…and operating…a well equal to the proportion which the acreage in the drilling unit he or she owns or holds under lease bears to the total acreage of the drilling unit.” Id. § 349.010(22). 1555 Id.
301
A coalbed methane owner or claimant who remains unable to be identified or located at the close
of the hearing, such an owner “shall be deemed to have elected to lease the interest to the
coalbed methane operator, exclusive of [one-eighth] of the production attributable to the
unleased interest, and shall not be entitled to make the election” as provided above.1556 Further,
an owner who does not make an election within 30 days of the order’s entry “shall be deemed to
have leased the coalbed methane interest to the…operator” in the same manner. 1557 These
presumptions and election rights only apply to those parties holding coalbed methane interests
not subject to a lease or other agreement that grants the right to operate and produce to another
§ 19.01 Analysis of Louisiana Regulatory Framework.
[1] – Name of the Governing Body.
The Louisiana Office of Conservation (“OC”) has primary responsibility for the
regulation and conservation of oil, gas, and other natural resources.1559 The OC was made a part
of the Louisiana Department of Natural Resources (“DNR”) in 1983.1560 The jurisdiction of the
OC consists of all natural resources of the state that are not within the jurisdiction of other state
departments or agencies,1561 including oil and gas. The Commissioner of Conservation is the
principal state official dealing specifically with pooling and unitization issues, in addition to the
generalities of oil and gas conservation.1562
[2] – Membership on the Governing Body.
The OC is directed and controlled by a Commissioner of Conservation
(“Commissioner”).1563 The Commissioner is appointed by the Governor, with the consent of the
Senate, for a term of four years.1564 In the event of a vacancy, the Governor shall, with the
consent of the Senate, fill the office by appointment for the unexpired term.1565 The Assistant
Secretary of the Office of Conservation (“Assistant Secretary”) also has authority similar to that
of the Commissioner.1566
[3] – Scope of Authority.
1559 See Office of Conservation, Department of Natural Resources State of Louisiana, http://dnr.louisiana.gov/ (last visited May 27, 2011). 1560 La. Rev. Stat. Ann. § 30:359(D) (2011) (“The State Department of Conservation…is transferred to and hereafter shall be within the Department of Natural Resources as provided in Rev. Stat. Ann. 36:806.”); see Bruce M. Kramer , The Law of Pooling and Unitization § 30.18A (3d ed. 2007). 1561 La. Rev. Stat. Ann. § 30:1(C). 1562 See Bruce M. Kramer , The Law of Pooling and Unitization § 30.18A (3d ed. 2007). 1563 La. Rev. Stat. Ann. § 30:1(A). 1564 Id. 1565 Id. 1566 See La. Rev. Stat. Ann. §§ 30:4(D), 30:5(C) (2011). It appears that, on some occasions, the terms “Commissioner” and “Assistant Secretary” are used interchangeably, but other times there is a distinction between the two designations.
303
The Commissioner has broad authority under the OC. His authority and jurisdiction
extend to “all persons and property necessary to enforce effectively the provisions of this
Chapter and all other laws relating to the conservation of oil or gas.”1567 Additionally, after
appropriate notice and a hearing, the Commissioner has the authority to make “any reasonable
rules, regulations, and orders that are necessary for the proper administration of this Chapter.”1568
The Commissioner specifically has jurisdiction over waste,
Rules and regulations promulgated pursuant to La. Rev. Stat. Ann. § 30:1 et seq. may be found in
Title 43 of the Louisiana Administrative Code.
1569 which is strictly
prohibited by Louisiana law.1570 “Waste,” in addition to its ordinary meaning, is defined to be
“physical waste” as it is generally understood in the oil and gas industry. 1571 This general
understanding includes: (1) the inefficient, excessive, or improper use or dissipation of reservoir
energy, and the location, spacing, drilling, equipping, operating, or producing of an oil or gas
well in a manner that results, or tends to result, in reducing the quantity of oil or gas ultimately
recovered from a pool; (2) the inefficient storing of oil, the producing of oil or gas from a pool in
excess of transportation or marketing facilities or of reasonable market demand, and the location,
spacing, drilling, equipping, operating, or producing of an oil or gas well in a manner causing, or
tending to cause, unnecessary or excessive surface loss or destruction of oil or gas; and (3) the
disposal, storage or injection of any waste product in the subsurface by means of a disposal
The Commissioner is required to make inquiries to determine whether or not waste exists
or is imminent.1573
to collect data; to make investigations and inspections; to examine properties, leases, papers, books, and records; to examine, survey, check, test, and gauge oil and gas wells, tanks, refineries, and modes of transportation; to hold hearings; to provide for the keeping of records and the making of reports; to require the submission of an emergency phone number by which the operator may be contacted in case of an emergency, and to take any action as appears reasonably necessary to enforce this chapter.
In doing so, the Commissioner has the authority:
1574
For the purpose of preventing waste, the Commissioner may regulate the pooling,
unitization and consolidation of oil and gas tracts and/or leases.
1575 Included within his
jurisdiction is the authority to establish drilling units, 1576 to compulsorily pool owner’s oil
and/gas interests, 1577 to limit and prorate the production of oil and/or gas from any pool or
field,1578 and to regulate the spacing of wells.1579 The Commissioner may even designate a new
well operator where a well is not being operated in order to prevent waste.1580
[4] – Process for Pooling.
[a] Establishing Drilling Units by the Assistant Secretary.
Upon the application of any interested party, the Assistant Secretary is authorized to enter
an order requiring unit operation of any pool or combination of two pools in the same field,
productive of oil or gas, or both, in connection with the institution and operation of systems of
pressure maintenance by the injection of gas, water, or any other extraneous substance, or in
connection with any program of secondary or tertiary recovery.1581 The Assistant Secretary is
also empowered to require the unit operation of a single pool in any situation where the ultimate
recovery can be increased and waste and the drilling of unnecessary wells can be prevented by
such unit operation.1582 This process impliedly applies to shallow wells, as deep oil and gas
pools are addressed in a separate action.1583
[b] Establishing Drilling Units by the Commissioner.
In order to prevent waste and to avoid the drilling of unnecessary wells, the
Commissioner is required to establish a drilling unit or units for each pool.1584 This process
impliedly applies to shallow wells, as deep oil and gas pools are addressed in a separate
section. 1585 A “drilling unit” is defined as the maximum area that may be efficiently and
economically drained by one well.1586 A “pool” refers to an underground reservoir containing a
common accumulation of crude petroleum oil or natural gas or both.1587 Due to this definition of
a “pool,” the Commissioner has traditionally taken the position that it does not have jurisdiction
to form a unit unless there is evidence that the interval is productive.1588
1581 La. Rev. Stat. Ann. § 30:5(C)(1)(a).
1582 Id. § 30:5(C)(1)(b). 1583 See La. Rev. Stat. Ann. § 30:5.1. 1584 La. Rev. Stat. Ann. § 30:9(B) (2011). “[E]xcept for those pools which, prior to July 31, 1940, had been developed to an extent and where conditions exist making it impracticable or unreasonable to use a drilling unit at the present stage of development.” Id. The provisions of this Section are intended to and shall affect presently existing units. Id. § 30:9.1(E). Note that La. Rev. Stat. Ann. § 30:5 also provides the Assistant Secretary certain powers regarding establishing and regulating units. That section states that it does not in any way modify the authority granted to the Assistant Secretary in La. Rev. Stat. Ann. § 30:9(B); however, as stated above, that cited section provides authority to the Commissioner rather than the Assistant Secretary. 1585 See La. Rev. Stat. Ann. § 30:5.1. 1586 Id. § 30:9(B). 1587 Id. § 30:3(6). 1588 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010. Note that the tests providing such evidence do not have to be in the same reservoir, or even an adjacent one, but can be from any well within the field, or a correlative sand outside the field but in the general area of the proposed unit. Id.
306
The Commissioner also has the authority to establish the location at which a well may be
drilled upon a drilling unit.1589 In determining the location, the Commissioner shall consider all
available geological and engineering evidence, and shall provide for the unit well to be located at
the optimum position for the most efficient and economic drainage of the unit.1590 However, the
Commissioner must also fix the well at a location so that the producer thereof shall be allowed to
produce no more than his just and equitable share of the oil and gas in the pool.1591
…that part of the authorized production of the pool, whether it be the total which could be produced without any restriction on the amount of production, or whether it be an amount less than that which the pool could produce if no restrictions on amount were imposed, which is substantially in the proportion that the quantity of recoverable oil and gas in the developed area of his tract or tracts in the pool bears to the recoverable oil and gas in the total developed area of the pool, in so far as these amounts can be practically ascertained.
A producer’s
“just and equitable share” is defined as
1592
Mineral owners are also entitled to their equitable share of production, and the Commissioner
may issue orders to ensure that each owner is able to so recover.
1593
Unless sooner terminated, extended or otherwise modified, any unit established by the
Commissioner shall remain in full force and effect so long as: (1) a well is producing from the
pool for which the unit(s) was established; (2) a well is completed in the pool for which the
unit(s) was established, and, although not producing, has been proved capable of producing; or
(3) drilling, reworking, recompletion, plugging back or deepening operations are being
conducted on a well to secure or restore production from the pool for which the unit(s) was
1589 La. Rev. Stat. Ann. § 30:9(C) (2011). 1590 Id. 1591 Id. 1592 Id. § 30:9(D). 1593 See Amoco Production Co. v. Thompson, 86-0190 (La. App. 1 Cir. 9/17/87); 516 So. 2d 376 ( holding that the Commissioner of Conservation has authority to issue any order necessary to ensure that the owner of each tract be given the opportunity to recover his equitable share of the gas in a compulsory unit).
307
developed.1594 If none of the above conditions have occurred within a time period of one year
and ninety days, the Commissioner may, by order issued after 10 days legal notice, terminate all
units within the pool. 1595 Absent any objection to such an order, no public hearing is
required.1596
Units may also be terminated by request. The Commissioner may, upon application and
by order issued after ten days notice, terminate any unit or units when he finds that, as of the date
of the application for termination, each of the following items are true: (1) a period of five years
has elapsed without any production from the unit; (2) there is no well located on the unit which is
capable of producing from the pool for which the unit was established; (3) a period of one year
and ninety days has elapsed without any drilling, reworking, recompletion, plugging back, or
deepening operations having been conducted on a well located on the unit in an attempt to obtain
or restore production from the pool for which the unit was established; and (4) there is no
unexpired drilling permit for the drilling of a new well on the unit to a depth which could
penetrate the pool for which the unit was established.
1597
The Commissioner has the authority to prescribe, issue, amend and rescind such orders,
rules and regulations as he finds necessary or appropriate to carry out the provisions of the
Act.
1598 This includes the power to amend the acreage of a previously established drilling unit.
That issue was addressed in Monsanto Chemical Co. v. Hussey, where the Louisiana Supreme
Court held that the Commissioner has the authority to issue an amendatory order increasing the
acreage of previously established units to govern the production of gas and condensate.1599
1594 La. Rev. Stat. Ann. § 30:9.1(A)(1)–( 3) (2011).
Once a producing well is located on a unit, the unit is considered a “developed area.”1600
The effect of a unit being a “developed area” is that no other well can be drilled on the unit into
the same pool.1601 This limitation to one well has been held to be a valid exercise of the State’s
police power.1602
(1) make it necessary for the producer from, or the owner of, a tract of land in the pool, in order that he may obtain the tract’s just and equitable share of the production of the pool…to drill and operate any well or wells on the tract in addition to the well or wells that can without waste produce this share; or,
Although the Commissioner has broad authority, his authority is expressly
subject to the prohibition that any action taken by the Commissioner may not:
(2) occasion net drainage from a tract unless there be drilled and operated upon the tract a well or wells in addition to the well or wells thereon that can without waste produce the tract’s just and equitable share of the production of the pool.1603
An example of the Commissioner exceeding his authority can be found in Alexander v.
Holt.
1604 In that case, defendant Holt sold to plaintiff Alexander a tract of land, reserving to
himself a mineral servitude. Plaintiff contended that the mineral reservation had not been used
for over ten years, and thus had expired and prescribed. Defendant countered that, by virtue of a
voluntary unitization agreement, which was approved by the Commissioner of Conservation, his
mineral servitude had been tolled. The issue at bar was whether the effect of the
Commissioner’s Order was to integrate or force pool the entire area, so as to toll the ten-year
liberative prescription limitation, or whether it simply approved of the voluntary unitization
agreement. 1605
1600 La. Rev. Stat. Ann. § 30:9(B) (2011).
Ultimately, the Court held that the Commissioner’s Order was merely an
approval of the voluntary agreement and could not function to institute a compulsory unit.
1601 See Alexander v. Holt, 116 So. 2d 532, 534 (La. Ct. App. 1959) (“[E]ach well is ordinarily limited to one well for developmental purposes.”); see also Sohio Petroleum Co. v. V.S. & P.R.R., 62 So. 2d. 615 (La. 1952). 1602 See Robinson v. Horton, 2 So. 2d 647 (La. 1941); see also Childs v. Wash., 87 So. 2d 111 (La. 1956). 1603 La. Rev. Stat. Ann. § 30:9(A)(1),(2) (2011). 1604 Alexander, 116 So. 2d at 532. 1605 Id. at 532–534.
309
Where forced pooling is directed by an Order of the Commissioner, the owners of an
established drilling unit must pool their interests.1606 When a well is drilled within such a unit, it
has the effect of interrupting the running, or tolling, the liberative prescription as to each
individual tract of minerals located in the unit because each unit is ordinarily limited to one well
in the interest of preventing waste.1607 In Alexander, a voluntary unitization agreement was
entered into by most, but not all, of the mineral holders in the area of interest, including
defendant Holt. This voluntary agreement was then approved by an Order of the Commissioner
of Conservation, known as Order 96—G. The Court previously considered Order 96—G in
Hunter v. Hussey, finding that in the said Order, the Commissioner “specifically disclaimed
authority to institute a compulsory water injection secondary recovery program” and further
provided that no person not a party to the Unit Operating or Unitization Agreements would
become subject to such agreements providing for a field-wide water injection secondary recovery
program.”1608
The present Court was in “full accord” with this finding, and held that “there was no
integration or forced pooling of the area involved or contemplated by the voluntary
agreements.”
1609 In other words, ordering the integration or forced pooling of the area was not a
proper exercise of the Commissioner’s power under La. Rev. Stat. Ann. § 30:9(A) because the
signing of the voluntary unitization agreement, even with the Commissioner’s approval, was no
more than a voluntary act. 1610 Therefore, Holt’s voluntary action in signing the unitization
agreement was merely voluntary, and thus he was powerless to extend his mineral servitude.1611
1606 Id. at 534.
1607 Id. 1608 Id. at 535–36 (citing Hunter v. Hussey, 90 So. 2d 429, 432 (La. Ct. App. 1956). 1609 Alexander v. Holt, 116 So. 2d 532, 536 (La. Ct. App. 1959). 1610 Id. at 536–37. 1611 Id. at 537.
310
Another example may be found in Monsanto Chemical Co. v. Southern Natural Gas
Co.,1612 where it was held that although the Commissioner’s pooling order could allocate to each
tract its pro rata share of production, it was beyond the Commissioner’s authority to determine
who was entitled to that production under the terms of voluntary agreements.1613 Monsanto was
followed by Southwest Gas Producing Co. v. Creslenn Oil Co.,1614 which held that an operating
agreement executed by working interest owners that provided for the allocation of their interests
on the basis of surface acreage did not conflict with was not superseded by a Commissioner’s
order that created field-wide units and allocated production on by a ‘60/40 formula’ (60% based
on productive acre feet and 40% on productive surface area).1615 This was true because the
action of the Commissioner recognized the distribution of production in accordance with any
agreement in effect prior to the effective date of the field-wide unit agreement.1616 “Private
contractual rights are only superseded when they are in conflict with the valid orders of the
Commissioner of Conservation.”1617
[c] Compulsory Pooling by the Commissioner.
When two or more separately owned tracts of land are embraced within a drilling unit
established by the Commissioner pursuant to La. Rev. Stat. Ann. § 30:9(B), landowners may
voluntarily agree to pool their interests.1618
1612 Monsanto Chem. Co. v. S. Natural Gas Co., 102 So. 2d 223 (La. 1958).
However, even if there is no voluntary pooling
1613 See 6 Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 941.3 (MB 2008). 1614 Sw. Gas Producing Co. v. Creslenn Oil Co., 181 So. 2d 63 (La. App. 1965), appeal denied, 182 So. 2d 74 (La. 1966). 1615 See 6 Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 941.2 n.2 (MB 2008); see also Sw. Gas Producing Co., 181 So. 2d at 67. 1616 Sw. Gas Producing Co., 181 So. 2d at 67. 1617 Id. (citing Ark. La. Gas Co. v. Sw. Natural Gas Producing Co., 60 So. 2d 9 (La. 1952)). 1618 La. Rev. Stat. Ann. § 30:10(A) (2011).
311
agreement, Louisiana law provides the Commissioner the authority to compulsorily pool their
interests “if he finds it necessary to prevent waste or to avoid drilling unnecessary wells.1619
The language of the statute provides “little direction [to] the Commissioner in issuing
compulsory pooling orders except that they must be just and reasonable.”
1620 All orders
requiring pooling shall be made after notice and hearing.1621 These must also be made upon just
and reasonable terms and conditions that afford the owner of each tract the opportunity to
recover his just and equitable share of the oil and gas in the pool without unnecessary
expense.1622 Additionally, the order must prevent or minimize reasonable avoidable drainage
from each developed tract that is not equalized by counter drainage.1623 The portion of the
production allocated to each owner shall, when produced, be considered as if it had been
produced from his tract by a well drilled thereon.1624
In the event that owners of separate tracts embraced within a drilling unit fail to agree
upon the pooling of the tracts and the drilling of a well on the unit, and should it be established
by final and irreversible judgment of the court that the Commissioner is without authority to
require pooling, then the owner of each tract so embraced may drill thereon.
1625 The allowable
production therefrom shall be the proportion allowable for the full unit as the area of the
separately owned tract bears to the full drilling unit.1626
[d] Pooling by the Assistant Secretary.
1619 Id. § 30:10(A) (1). 1620 6 Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 10.02[3] (MB 2008). 1621 La. Rev. Stat. Ann. § 30:10(A)(1)(a). 1622 Id. 1623 La. Rev. Stat. Ann. § 30:10(A)(1)(a). 1624 La. Rev. Stat. Ann. § 30:10(A)(1)(b) (2011). The Court has held that this subsection is also applicable to field-wide units created by the Commissioner.; see Ark. La. Gas Co. v. Sw. Gas Producing Co., 181 So. 2d 9, 68 (La. 1952) (“Although the statute relates to drilling units, we can find no ground for distinction in its application to a field-wide unit such as that created by the Commissioner in this case.”). 1625 La. Rev. Stat. Ann. § 30:10(B). 1626 Id.
312
Where a reservoir is of sufficient size and characteristics that more than one well is
necessary to efficiently and economically drain it, or where gas injection pressure maintenance
or enhanced recovery projects are appropriate, the Commissioner has the authority to create a
single, “reservoir-wide” unit.1627 Although not necessary for primary recovery operations, this
type of unit is also available in those cases if the requisite statutory requirements can be met.1628
In connection with a unit operation under La. Rev. Stat. Ann. § 30:5(C), the Assistant Secretary
has the right to unitize, pool and consolidate all separately owned tracts and other property
ownerships.1629 Any such order may be issued only after notice and hearing.1630 Reservoir units
authorize the operator to complete as many unit wells as necessary, without needing to obtain
subsequent orders for substitute or alternate well approval.1631
In making an order, the Assistant Secretary should consider all available geological and
engineering evidence.
1632 The proposed unit operation must be economically feasible, and the
order shall be based on the fact that it is reasonably necessary to prevent waste or drilling of
unnecessary wells, and will appreciably increase the ultimate recovery of oil or gas from the
affected pool or combination of two pools.1633 The order must also provide for the allocation to
each separate tract within the unit of a proportionate share of the unit production to insure the
recovery by the owners of that tract of their just and equitable share of the recoverable oil or gas
in the unitized pool or combination of two pools.1634
1627 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010.
1628 Id. at 29. 1629 La. Rev. Stat. Ann. § 30:5(C)(2) (2011). 1630 Id. 1631 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010. 1632 La. Rev. Stat. Ann. § 30:5(C)(4). 1633 Id. § 30:5 (C)(2)(a)–(b). 1634 Id. § 30:5(C)(2)(c).
313
Additionally, the plan and terms of unit operation must be approved by at least three-
fourths of the owners and three-fourths of the royalty owners as to a particular interest.1635 The
first category of owners here is thought to refer to working interest owners.1636 Such approval
must be evidenced by a written contract covering the terms and operation of the unitization,
signed and executed by the required three-fourths owners and three-fourths royalty owners, and
filed with the Assistant Secretary on or before the day set for hearing.1637
For the purpose of calculating the required three-fourths approval, “royalty owner” means
any interested party other than the owner of an unleased interest or a mineral lessee or the owner
of any interest created out of the interest of a mineral lessee, such as a net operating interest,
overriding royalty or production payment.
1638 Without the necessary percentage of approvals of
both royalty owners and working interest owners, a unit cannot effectively be created, even if all
of the other requirements are met, and even if the evidence is “clear and undisputed” that such a
unit is necessary to prevent waste or to avoid the drilling of unnecessary wells.1639
Any order hereby entered requiring unit operation must designate a unit operator, and
must also make provision for the proportionate allocation to the owners of the costs and expenses
of the unit operation.
1640 Said allocation shall be in the same proportion that the separately
owned tracts share in unit production.1641
1635 La. Rev. Stat. Ann. § 30:5 (C)(2)(d) (2011).
In the absence of a voluntary agreement among the
owners, the cost of capital investment in wells, physical equipment and intangible drilling costs
1636 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010 (“[A]t least 3/4ths of royalty owners and 3/4ths of the working interest owners. . . . ”). 1637 La. Rev. Stat. Ann. § 30:5(C)(2)(d). 1638 Id. § 30:5(C)(5). 1639 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010. 1640 La. Rev. Stat. Ann. § 30:5(C)(3) (2011). 1641 Id.
314
shall be shared in like proportion. 1642 However, any owner who has not consented to the
unitization shall not be required to contribute to the proceeds of production accruing to the
interest of such owner out of production from such unit operation.1643 The order requiring unit
operation shall not vary or alter any terms of the above referenced contract, nor impose any term
or operation upon non-signers of the contract more onerous than the terms and operations set out
in the contract(s). 1644 Upon application, and after notice and public hearing, to the extent
required by the evidence so established, the Assistant Secretary may revise any reservoir-wide
unit(s) so created.1645
[e] Limitation and Allocation of Production.
The Commissioner has the authority to limit the production of a pool to an amount less
than that which the pool could produce if no restriction were imposed.1646 Pursuant to his charge
in preventing waste, the Commissioner may even prohibit the production of minerals.1647 When
the Commissioner limits production, he must prorate the allowable production among the
producers in the pool on a reasonable basis so as to prevent or minimize avoidable drainage from
each developed area that is not equalized by counter drainage.1648 He must also ensure that each
producer will have the opportunity to produce or receive his just and equitable share, subject to
the reasonable necessities for the prevention of waste.1649
1642 Id.
After the effective date of a rule,
regulation or order of the Commissioner fixing the allowable production of oil or gas or both for
a pool, no person shall produce from a well, lease or property more than the allowable
1643 Id. 1644 Id. 1645 Id. § 30:5(C)(4). 1646 La. Rev. Stat. Ann. § 30:11(B) (2011). 1647 See Delatte v. Woods, 94 So. 2d 281 (La. 1957) (finding the Commissioner has the authority to regulate and control, or to prohibit the production of minerals); see also La. Rev. Stat. Ann. § 30:2. 1648 La. Rev. Stat. Ann. § 30:11(B). 1649 Id.
315
production which is applicable, nor shall any person produce be in a manner different than the
manner of production which was authorized.1650
Whenever the Commissioner limits the total amount of oil or gas that may be produced,
he shall allocate the allowable production among the fields.
1651 A “field” is the general area
underlaid by at least one pool, and includes the underground reservoir(s) containing crude
petroleum oil or natural gas or both.1652 Distinguished from the definition of a “pool,” a “field”
may relate to two or more pools.1653 This allocation must be made on a reasonable basis, giving
to each field with small wells of settled production an amount which will prevent a general
premature abandonment of the wells in the field.1654
An order fixing allowable production of oil or gas, or making changes therein, shall be
issued by the Commissioner on or before the 23rd day of the month preceding the month for
which the order is to be effective.
1655 The order shall be promulgated by immediate publication
in the official journal of the state.1656 In the case of old fields or pools for which schedules had
already been issued, no hearing is required before the issuance of a subsequent order unless there
is a written request for a hearing made by an interested person.1657 In the event that a schedule is
promulgated without prior notice and hearing, an aggrieved producer may, within 72 hours, file
with the Commissioner a sworn written statement, detailing the grounds of his complaint.1658
The Commissioner shall then hold a hearing within 48 hours. 1659
1650 Id. § 30:11 (C).
At this hearing, oral or
1651 Id. § 30:11 (A). 1652 Id. § 30:3(7). 1653 La. Rev. Stat. Ann. § 30:3(7) (2011). However, if only one underground reservoir is involved, “field” and “pool” mean the same thing. Id. 1654 Id. § 30:11(A). 1655 Id. § 30:7(A). 1656 Id. 1657 Id. § 30:7 (B)(1). 1658 La. Rev. Stat. Ann. § 30:3(7) (B)(2) (2011). 1659 Id.
316
documentary evidence may be received in favor of and against the complaint.1660 After the
hearing, the Commissioner shall summarily render a decision.1661 If his decision is not made on
or before the effective date of the order complained of, that order shall be suspended until a
decision is rendered. During such suspension, the former order remains in force.1662
[f] Application Process.
There are three categories of individuals that an applicant must keep in mind in filing any
application: interested owners, represented parties, and interested parties. An “interested owner”
is defined as any owner who presently owns an interest within the area of, or proximate to, the
tracts directly affected by the application.1663 A “represented party” is any person who is known
to the applicant after reasonable search to presently own an interest within the area of, or
proximate to, the tracts directly affected by the application, and who is also known to the
applicant to have either a consultant or attorney representing him in conservation matters.1664 An
“interested party” is any person other than an interested owner or a represented party who owns
an interest within the area of, or proximate to, the tracts directly affected by the application.1665
Unless pre-application notice is waived,
1666 any person intending to apply for a hearing,
prior to filing an application, must send a notice outlining the proposal to the Commissioner in
duplicate, with a copy to the District Manager and to each interested owner and represented
parties.1667
1660 Id.
The following list of items must be furnished to the Commissioner, interested owners
and represented parties, but the first item need not be furnished to represented parties or
interested owners unless so requested:
1661 Id. 1662 Id. 1663 La. Admin. Code tit. 43, § 3903 (2011). 1664 Id. 1665 Id. 1666 For procedures on waiver, see id. § 3917. 1667 Id. § 3907(A).
317
(1) The names and addresses of all interested owners and represented parties to whom it is being sent; (2) A statement that a reasonable effort has been made to determine to whom the notices as required by this rule must be sent; (3) An explanation of the nature of the proposal and a copy of a unit plat for each sand, if units are involved, prepared in accordance with La. Admin. Code tit. 43:XIX.103; (4) A day, time and place for a conference which need by held only if notice of a desire to confer with respect to the application is given as herein provided; and, (5) A definition of the sand proposed for unitization with such sand defined in each reservoir thereof by reference to well log measurements.1668
If the applicant has proof that there is no indication of opposition from any person to whom pre-
application notice must be sent, and the Commissioner finds such proof acceptable, the applicant
may immediately proceed to file his application and need not schedule a conference.
1669
Unless otherwise agreed, any requested conference must be held within the state of
Louisiana in a city reasonably convenient to the persons involved and shall be scheduled for not
less than 20 days after the date of pre-application notice.
1670 Pertinent data must be made
available to interested owners and represented parties sufficiently in advance of any conference
so as to allow them reasonable time for review and interpretation.1671 Reference to the source of
data may be obtained at the cost of the requesting party.1672 Within ten days of receiving pre-
application notice, any interested owner or represented party may advise the applicant of his
desire to confer about his proposal.1673
1668 Id. § 3907(A)–(B)(5).
The applicant, within 15 days after the date of pre-
application notice, shall inform the Commissioner, the District Manager, and all other persons to
the first two items need not be furnished to represented parties or interested owners unless so
requested:
(1) The names and addresses of interested owners and represented parties notified; (2) The names and addresses of all interested parties who are known to the applicant after reasonable search; (3) A statement that a reasonable effort has been made to obtain a complete list of interested parties, interested owners and represented parties; (4) A statement that a conference has or has not been held, including a brief report on the conference, if held, and a list of the parties in attendance; (5) A unit plat, if units are involved, prepared in accordance with La. Admin. Code tit. 43 XIX.103; and, (6) A definition of the sand proposed for unitization with such sand defined in each reservoir thereof by reference to well log measurements.1683
Requests for separate sands are considered a separate application for each sand; the
Commissioner should be furnished an extra copy of the application for each additional sand.
1684
If, as a result of a conference, an applicant’s proposal is revised, the revised proposal
should be explained in the application, and if units are involved, the revised unit plats should be
filed with the application.
1685 If differences are not resolved, or if any interested owner or
represented party wishes to oppose or support a proposal by the introduction of evidence at the
hearing, then not less than 15 days before the hearing such a person must file with the
Commissioner and the District Manager, as well as the applicant and all persons who attended
the pre-application conference, his counter plan or supporting plan.1686
1683 Id. § 3915(1)–(6).
If units are involved, his
plan must include a plat of his proposed units, with any geological bases for any unit
boundary.1687 Finally, he must provide a letter explaining any points of difference between his
plan and the applicant’s plan.1688 The Commissioner has reserved the right to call a pre-hearing
conference at any time prior to the hearing if he believes that it would resolve or narrow the
issues in controversy, or would assist in the conduct of the hearing.1689
After the application is filed, if the applicant’s proposal is revised, the applicant must
promptly notify the Commissioner, the District Manager, and all parties to whom the application
was sent of the revision.
1690 Additionally, the applicant must furnish to them a copy of any
revised plan and unit plat, if units are involved, and shall, if requested, hold a conference to
discuss the revised proposal prior to the hearing.1691 No revised proposal shall be considered at
the hearing unless notice of the revision has been provided as required above at least five days
prior to the hearing.1692 If appropriate notice has been provided, the applicant must present both
the original application proposal and the revised proposal at the time of hearing, with evidence to
support the revision.1693
Statewide Order 29-R-10/11, effective November 19, 2010, sets forth the application fees
associated with various activities for the fiscal year 2010-2011.
1694 Several relevant fees are as
follows: the fee for an Application for Public Hearing is $755 and the fee for an Application for
Unit Termination is $252. 1695
1687 La. Admin. Code tit. 43, § 3915(E) (2011).
Fees for applications to Permit to Drill, as well as to Amend
1688 Id. For additional procedures regarding opposition to or support of an application, see id. § 3921. 1689 Id. § 3923(A). 1690 Id. § 3919(A). 1691 Id. 1692 Id. 1693 La. Admin. Code tit. 43, § 3919(A) (2011). 1694 Id. § 701. 1695 Id. § 703.
321
Permits to Drill or to Drill Minerals Deeper vary based upon substance and depth.1696 There are
also regulatory fees and production fees applicable to certain oil and gas production activities.1697
Whenever any application is made for “creation, revision, or modification of any unit or
units for production of oil or gas, or for adoption of any plan for spacing of wells or for cycling
of gas, pressure maintenance, or restoration, or other plan of secondary recovery…at least thirty
days notice shall be given of the hearings to be held.”
1698 Other hearing matters require only ten
days notice.1699 Procedures for conducting hearings before the Commissioner can be found in
Title 43, Part XIX, Subpart 17 and Chapter 39 of the La. Admin. Code. These procedures are
applicable to all hearing applications requiring 30 days notice, with certain narrow
exceptions,1700 and, to the extent practical, also apply to hearing applications which require ten
days notice.1701
The applicant is required to publish legal notice by the Commissioner in the official state
journal, and must provide for the posting of a copy of the legal notice of hearing, as well as unit
plats, in a prominent place in the area affected.
1702 A copy must also be published in a
newspaper in the vicinity or general area of the affected field at least 15 days before the
hearing. 1703
1696 See id.
The applicant must mail copies of the legal notice to all interested owners,
represented parties and interested parties, and a copy of the unit plat or plats shall be included if
1697 See id. 1698 Id. § 30:6(B). 16996 Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 11.04[4] (MB 2008). 1700 La. Admin. Code tit. 43, § 3905(A) (2011) (“[T]hese rules of procedure shall not apply to applications relating to the initial creation of poolwide units under Section 5C. . . of Title 30. . . .”). If the application relates to the creation of a poolwide units under Section 5C, a copy of the application must be given to each interested owner and represented party. Id. § 3905 (B). If the required 75% of owners have not joined the agreement by the 15th day prior to the date of hearing, the application shall secure cancellation of the hearing and shall notify all owners, represented parties, and interested parties of the cancellation. Id. 1701 Id. § 3905 (C). 1702 Id. § 3915(A)(2). 1703 Id.
322
they have not already been provided to the same. 1704 Evidence to establish the posting,
publication, and mailing of notice shall be submitted at the hearing.1705
Although notice by mailing should be provided as required, actual notice obtained by an
interested party may cure a defect in procedure in giving notice.
1706 “As a general proposition, it
is reasonable to expect one with knowledge of notice of an administrative proceeding affecting
his rights not to stand by until the day of the hearing and then for the first time assert lack of
notice.”1707 Kaiser Aluminum Exploration Co. v. Thompson upheld a similar concept, holding
that, even though the applicant had made no effort to give notice by mail to certain owners in a
non-producing unit, such failure to give notice does not mean that a resultant order is invalid.1708
Furthermore, it has been found that failure to provide notice will not invalidate an order of
unitization where the unitization was advantageous to the one who was not notified based upon a
presumption that such a person would not have opposed the application had he been notified.1709
At the hearing, the applicant presents his case first. In doing so, he shall present the
entire geological, engineering or other bases in support of his proposal.
1710 Next, any interested
owner or represented party who supports the applicant and has complied with §§ 3915, 3917 and
3921 shall present his entire geological, engineering or other bases in support of the applicant’s
proposal. 1711
1704 Id.
Any interested party wishing to present evidence supporting the applicant’s
proposal shall do so immediately after the applicant and supporting parties have completed their
1705 Id. 1706 See Brown v. Sutton, 356 So. 2d 965 (La. 1978) (holding that an order approving a petroleum company’s application for a unitized operation and secondary recovery project under LA. REV. STAT. ANN. § 30:5(C) (2011) was valid because the lack of formal notice to a purported assignee was cured by actual notice and the order was referred to in this case as an order of the Commissioner, not an order of the Assistant Secretary); see also 6 6 Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 11.04[4] (MB 2008). 1707 Brown, 356 So. 2d at 972. 1708Kaiser Aluminum Exploration Co. v. Thompson, 525 So. 2d 1050 (La. 1988); see also 6 6 Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 11.04[4] (MB 2008). 1709 Placid v. N. Cent. Tex. Oil Co., 19 So. 2d 616, 622 (La. 1944). 1710 La. Admin. Code tit. 43, § 3292(A) (2011). 1711 Id.
323
presentations.1712 Opponents who have complied with §§ 3915, 3917 and 3921 will then present
their entire geological, engineering or other bases for their opposition.1713 After all opponents
have completed their presentations, the applicant may present rebuttal geological, engineering or
other testimony, but is strictly limited to a refutation of the matters covered by the opponents.1714
Rebuttal evidence should not be used to prove matters that should have been proven on direct
examination.1715
In making their presentations, parties are permitted to call witnesses. Any witness shall
be subject to cross-examination by the Commissioner or any member of his staff, and by no
more than two representatives of a party.
1716 Cross-examination should be limited to questions
concerning the testimony and exhibits presented by the witness.1717 The witness should not be
required to make measurements or calculations or comparisons between his exhibits and those
presented by other witnesses. 1718 There should be no attempt to establish matters that are
peculiarly within the knowledge of the witness as such should been presented on direct
examination.1719
After the applicant and any opponents have made their presentations, any party shall be
afforded an opportunity to make a statement.
1720 If the statement involves technical data, the
party must be sworn in and cross-examined.1721
1712 Id. § 3292 (B).
The applicant, any opponent and any supporting
party may make opening or closing statements, but they should not include technical matters
establish the limits of the producing area.1747 The order must designate a unit operator and make
provision for the proportionate allocation of costs and expenses, as well as the cost of capital
investment, similar to the provisions for oil and gas wells contained in § 30:5(C)(3), discussed
hereinabove.1748
Upon application, and after notice and hearing and consideration of all new available
geological and engineering evidence, the Commissioner, to the extent required, may create,
revise, or dissolve any unit, or modify any provision of an order.
1749 Any such order shall
provide for the allocation of unit production on a just and equitable basis to each separately
owned tract within the unit.1750 Furthermore, the Commissioner shall prescribe, issue, amend
and rescind orders, rules and regulations as he finds necessary and appropriate to enforce this
Chapter.1751
[2] – Split by Depth.
Section 30:5, discussed hereinabove, impliedly relates to shallow oil and gas wells,
whereas § 30:5.1 makes separate provision for deep wells, which are at least 15,000 feet in
depth. 1752 For similar reasons of preventing waste, avoiding unnecessary drilling, and
encouraging production of deep oil and gas pools, the Commissioner is authorized to establish a
single unit to be served by one or more wells for a deep pool.1753 The Commissioner is further
authorized to adopt a development plan for a deep unit.1754
1747 La. Rev. Stat. Ann. § 30:5.2(E) (2011).
While this authorization is for the
1748 See id. § 30:5.2(F). 1749 Id. § 30:5.2(G). 1750 Id. 1751 Id. § 30:5.2(H). 1752 See id. § 30:5.1(C)(3). 1753 La. Rev. Stat. Ann. § 30:5.1(A) (2011). 1754 Id.
328
creation of a single unit, there is no limitation on the Commissioner’s authority to approve the
drilling of alternate wells on drilling units established pursuant to § 30:9(B).1755
Upon the application of any interested party, the Commissioner may order the unit
operation of any deep pool when such operation will promote the development of deep pools,
prevent waste, and avoid drilling unnecessary of wells.
1756 In connection with such an order, the
Commissioner has the right to unitize, force pool and consolidate all separately owned tracts and
other property ownerships within the unit.1757
(1) the order is reasonably necessary to promote the development of a deep pool and for the prevention of waste and the drilling of unnecessary wells;
Any order creating a unit shall be issued only after
notice and public hearing, and shall be based on findings that:
(2) the proposed unit operation is economically feasible; (3) the geologic top of the deep pool was encountered in the initial well for the pool at a depth in excess of 15,000 feet true vertical depth; (4) sufficient evidence exists to reasonably establish the limits of the deep pool; and, (5) the plan of development for the unit is reasonable.1758
The plan should be revised only if approved by the Commissioner after notice and public
hearing.
1759
The order shall provide for the initial allocation of unit production on a surface acreage
basis to each separately owned tract within the unit.
1760 No order may be issued unless interested
parties have been given a reasonable opportunity to review and evaluate all data submitted by the
applicant to the Commissioner to establish the limits of the producing area.1761
The order must designate a unit operator and make provision for the proportionate
allocation of costs and expenses of the unit operation, as well as the cost of capital investment,
similar to the provisions for oil and gas wells contained in § 30:5(C)(3), discussed
hereinabove.1762 The Louisiana statute and regulations do not specifically define what costs and
expenses must be considered. However, an example of a definition of “unit expense” as
contained within a Reservoir-wide Unit Agreement is “all cost, expense or indebtedness incurred
by Working Interest Owners or Unit Operator pursuant to this Agreement and the Unit Operating
Agreement for or on account of Unit Operations.”1763 “Unit Operations” are broadly defined to
include “all operations conducted pursuant to this Agreement and the Unit Operating
Agreement.”1764
Upon application, and after notice and hearing and consideration of all new available
geological and engineering evidence, the Commissioner, to the extent required, may create,
revise, or dissolve any unit, or modify any provision of an order.
1765 Any such order shall
provide for the allocation of unit production on a just and equitable basis to each separately
owned tract within the unit.1766 Furthermore, the Commissioner shall prescribe, issue, amend
and rescind orders, rules and regulations as he finds necessary and appropriate to enforce the
law.1767
[3] – Spacing Rules.
Spacing regulations in Louisiana make a distinctions based upon the depth of the well to
be drilled, as well as between whether the well to be drilled is for the production of oil or the
1762 See id. § 30:5.1(F). 1763 6 Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 29.17[5] (MB 2008). 1764 Id. 1765 La. Rev. Stat. Ann. § 30:5.1(G) (2011). 1766 Id. 1767 Id. § 30:5.1(H).
330
production of gas. In the absence of spacing set by a unit order, well spacing is governed by
Statewide Order 29-E.1768
(1) No spacing shall be required for wells drilled in search of oil to depths less than 3,000 feet subsea, except as provided for in the last Paragraph of this order.
Louisiana Office of Conservation Statewide Order 29-E provides, in
relevant part:
1769
(2) Wells drilled in search of oil to depths below 3,000 feet subsea shall not be located closer than 330 feet from any property line nor closer than 900 feet from any other well completed in, drilling to, or for which a permit shall have been granted to drill to, the same pool.
(3) Wells drilled in search of gas shall not be located closer than 330 feet to any property line nor closer than 2,000 feet to any other well completed in, drilling to, or for which a permit shall have been granted to drill to, the same pool.1770
Note that there are several instances in which the Commissioner may grant an exception to the
above requirements, such as when the Commissioner believes that the wells drilled in a certain
area will be affected by piercement type salt domes, or where a pool has already been partially
developed with a greater density than prescribed by these orders.
1771 Furthermore, in addition to
such prescribed exceptions, the Commissioner may, without additional public hearing, grant an
exception in any case where it appears to be necessary to prevent waste, to prevent inequity or
loss of property rights.1772
1768 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010.
However, such an exception may only be granted when the applicant
has furnished the proper data and evidence, defined in § 1907(5)(a)-(d) through the district
manager.
1769 The last paragraph of Statewide Order 29-E provides: “This order also is not intended to eliminate pools shallower than 3,000 feet from appropriate rules and regulations, including spacing regulations after notice and public hearing. After sufficient geological and engineering evidence is available with respect to these pools found at depths of 3,000 feet or less subsea then the operator or operators owning wells therein are required to petition the Commissioner of Conservation for a public hearing for the purpose of establishing rules and regulations and the creation of drilling units for each such pool.” La. Admin. Code tit. 43, § 1909(C) (2011). 1770 Id. § 1905(A)(1)–(3). 1771 See id. § 1907. 1772 Id. § 1907 (5).
331
When forming units, the Commissioner sets field rules and spacing requirements as part
of the unit order. 1773 Usually, the Commissioner will incorporate Statewide Order 29-E in
defining spacing requirements within the unit order. 1774 However, the Commissioner has
approved special field spacing rules that require greater distances from unit boundaries. 1775
Additionally, special field spacing rules are normally issued for horizontal wells.1776
There has been virtually no litigation on the subjects of well spacing and exceptional well
locations for several reasons.
1777 First, the OC has been consistent in not granting exception well
locations until a well has been drilled at a regular location.1778 Second, the OC encourages
parties to resolve their difference outside of litigation. 1779 Third, “it is well understood in
Louisiana that the courts will defer to the Commissioner of Conservation on technical
matters.”1780
[4] – Size.
A “drilling unit” is defined as “the maximum area which may be efficiently and
economically drained by one well.” 1781 Generally, the Commissioner favors geological
boundaries in South Louisiana when there is enough data to reasonably delineate the reservoir
limits.1782 When such data is not available, drilling units are formed in geographical shapes.1783
1773 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010.
Alternatively, in North Louisiana, due to the lower permeability and lateral sands, almost all
drilling units are formed on a geographic basis, “rectangular or square in shape with a standard
1774 Id. 1775 Id. 1776 Id. 1777 See 6 Patrick H. Martin & Bruce M. Kramer, Williams & Meyers, Oil and Gas Law § 5.02 (MB 2008). 1778 Id. 1779 Id. 1780 Id. 1781 La. Rev. Stat. Ann. § 30:9(B) (2011). 1782 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010. 1783 Id.
332
number of acres sufficient for one well to drain the unit.”1784 Louisiana does not have any
defined size or acreage limits, and the Commissioner exercises broad discretion in setting unit
sizes on a case-by-case basis. Typically, however, units are 640 acres, or about one square
mile,1785 though smaller units do exist.1786
In the case of a single-well reservoir, drilling units are determined by the geological
boundaries of the reservoir.
1787 If those boundaries cannot be determined, geographic units will
be formed, the size determined by estimating the drainage for the well, its depth, the reservoir
pressure and other characteristics of that particular location.1788 In the case of multiple drilling
and production units per reservoir, the Commissioner will consider various economic factors
which drive operators to determine how many wells should be drilled to adequately develop the
reservoir in determining the size and shape of the units.1789 Finally, reservoir-wide units are
always governed by the size and shape of the reservoir as defined by its geological boundaries;
these units are formed when there is enough development to ensure the productive field limits
and reservoir fluid contacts have been adequately determined.1790
[5] – Minimum Operator Control.
In general, a lessee is not in a fiduciary relationship with his lessor, but he is bound to act
in good faith and to develop and operate the property leased as a reasonably prudent operator for
1784 Id. 1785 See Office of Conservation, Department of Natural Resources State of Louisiana, http://dnr.louisiana.gov/index.cfm?md=pagebuilder&tmp=home&pid=46&ngid=4 (last visited May 27, 2011). 1786 See Ark. v. Sw. Gas Producing Co., 181 So. 2d 9, 65 (“[T]he Commissioner of Conservation had developed a program establishing spacing and drilling units in the area involved upon the basis of 320 acre tracts delineated as the North and South Halves of each Section of land.”); Alexander v. Holt, 116 So. 2d 532, 533 (“By virtue of the Commissioner’s Order 96, 40-acre spacing or drilling units were established for the field.”). 1787 Brent G. Sonnier, Oil & Gas Development and Unitization Laws in Various States 27 (March 2010), available at http://www.hadoa.org/publications/2010. 1788 Id. 1789 Id. 1790 Id.
333
the benefit of himself and his lessor.1791 Parties are permitted to stipulate what shall constitute
reasonably prudent conduct on behalf of the operator.1792
[6] – Directional Drilling.
Statewide Order 45-I-A defines a “horizontal well” as a well with the wellbore drilled
laterally at an angle of at least 80 degrees to the vertical and with a horizontal well displacement
of at least 50 feet in the pool in which the well is completed for production, measured from the
initial point of penetration into such pool.1793 Similarly, Statewide Order 151-A-2 defines a
“horizontal oil well” as a well with the wellbore drilled laterally at an angle of at least 80 degrees
to the vertical and with a horizontal displacement of at least 50 feet in the pool in which the well
is completed for production, measured from the initial point of penetration into such pool.1794
This Order establishes allowable schedules for oil wells that are both horizontal, and other than
horizontal. For oil wells other than horizontal wells, the statewide allowable is a power of ten
less than the measured depth of the deepest perforation in the pool.1795
For horizontal oil wells, the amount of production allowable for each horizontal well is
its maximum efficient rate.
For example, a well
depth of 2,000 feet has an allowable of 200 BDP, a well depth of 12,000 feet has an allowable of
1,200 BDP, and so on. No mention is made of horizontal gas wells.
1796 “Maximum efficient rate” is defined to be the maximum
sustainable daily oil withdrawal rate from a reservoir which will permit economic development
and depletion without causing waste.1797
1791 La. Rev. Stat. Ann. § 30:122 (2011).
Allowables assigned to units in competitive reservoirs
shall be subject to adjustment if needed to prevent adverse drainage or to protect correlative
If a notified owner elects not to participate in the risk and expense of the unit well, or
should the owner elect to participate and then fail to pay his share of such expenses within 60
days of receipt of detailed invoices, the drilling owner shall be entitled to own and recover out of
production from such unit well the nonparticipating owner’s allocated share,1806 in addition to
any other available legal remedies to enforce collection of such expenses.1807 Furthermore, in
addition to recovering the nonparticipating owner’s share of actual reasonable expenditures
incurred in drilling, testing, completing, equipping or operating the unit well, a risk charge may
also be recovered by the operator; said risk charge shall be 200 percent of the tract’s allocated
share of the cost of drilling, testing and completing the well.1808 Any owner not notified will
bear only his tract’s allocated share of the actual reasonable expenditures incurred, including a
charge for supervision.1809 In order for [this Subsection] to have any valid effect outside of a
Commissioner’s compulsory drilling unit, however, some conservation measure must thereby be
served.1810
If a drilling unit is created by order of the Commissioner around a well already drilled or
drilling, and includes one or more tracts as to which the owner(s) thereof has not participated in
the risk and expenses of drilling, the above provisions regarding notice, election and
participation will be applicable as if a unit well were being proposed by the owner who drilled or
was drilling such well.
1811
1806 La. Rev. Stat. Ann. § 30:10(A)(2)(b)(i) (2011).
If a drilling unit is revised by order of the Commissioner so as to
1807 See Superior Oil Co. v. Humble Oil & Refining Co., 165 So. 2d 905 (La. Ct. App. 1964), cert. denied , 167 So. 2d 668 (La. 1964) (holding reimbursement from well proceeds was not the exclusive method for the operator to recover the drilling expenses from the co-owners). Similarly, La. Rev. Stat. Ann. § 30:10 is not the sole remedy for unleased land owners. See Lamson Petroleum Co. v. Hallwood Petroleum, Inc., 99-1444 (La. App. 3 Cir. 5/24/00); 770 So. 2d 786, cert. denied , 775 So. 2d 448 (La. Nov. 27, 2000). 1808 Id. 1809 La. Rev. Stat. Ann. § 30:10(A)(2)(b)(ii). 1810 See Exchange Oil & Gas Co. v. Foster, 237 So. 2d 904 (La. Ct. App. 1970), cert. denied, 37 So. 2d 709 (La. 1970). 1811 La. Rev. Stat. Ann. § 30:10(A)(2)(c) (2011).
336
include additional tracts, the above provisions shall be applicable to such added tracts and the
owners thereof as if a unit well were being proposed by the owner who had drilled on the
unit.1812 However, to determine that share of cost allocable to the subsequently included tracts,
the cost of drilling, testing, completing, equipping, and operating the unit well shall be reduced
in the same proportion as the recoverable reserves in the unitized pool have been recovered by
prior production, if any, in which said tracts did not participate.1813
If a drilling unit is revised to exclude a tract, to determine the share of cost allocable to
the subsequently excluded tracts, the cost of drilling, testing, completing, equipping and
operating shall be reduced in the same proportion as the recoverable reserves in the unitized pool
have been recovered by prior production.
1814
In the event of a dispute regarding the calculation of unit well costs or depreciated unit
well costs, the Commissioner shall determine the proper costs after notice to all interested
owners and public hearing.
1815 However, such a determination amounts merely to a finding of
fact, and is reviewable by the District Court of East Baton Rouge Parish.1816
Notwithstanding these provisions, a royalty and overriding royalty owner shall receive
that portion of production due to them under the terms of the contract creating the royalty.
1817
Royalty owners are entitled to payment on the basis of the amounts realized by their own lessees
from the sale of production allocated to the tracts in which they had an interest, rather than from
the sale of all gas and distillate from the unit.1818
1812 Id. § 30:10(A)(2)(d)(i).
1813 Id. 1814 Id. § 30:10(A)(2)(d)(ii). 1815 Id. § 30:10(A)(2)(f). 1816 See Superior Oil Co. v. Humble Oil & Refining Co., 226 So. 2d 565 (La. Ct. App. 1969), annulled by, 241 So. 2d 911 (La. 1970). 1817 La. Rev. Stat. Ann. §30:10(A)(2)(e) (2011). 1818 See Ark. La. Gas Co. v. Sw. Natural Gas Producing Co., 60 So. 2d 9 (La. 1952).
337
§ 20.01 Analysis of Maine Regulatory Framework.
[1] – Governing Body and Structure.
Maine law provides little discussion of oil and gas production, none of which references
pooling or unitization. The following is an analysis of existing substantive law and procedures
related to oil and gas in Maine. The Maine Mining Statute (“the statute”), grants to the State
Bureau of Geology and Natural Areas (“the Bureau”) jurisdiction over all state-owned lands for
the purpose of mineral development and mining on that land. 1819 Under the statute, those
“minerals” concerned include all naturally occurring mineral deposits, including hydrocarbons
and peat, but excluding sand, gravel and water.”1820
The Bureau is “established within the Maine Department of Conservation and is
administered by the commissioner. The bureau consists of the Maine Geological Survey, and the
Natural Areas Program. The executive director of the bureau is the director of the survey.”
1821
Under the statute the director of the survey is granted power to issue exploration permits,
regulate the issue of mining leases, and promulgate rules governing the exploration and mining
of hydrocarbons in the state.1822
[2] – Scope of Authority.
The director of the survey and the director of the Bureau of Parks and Lands are
permitted to “promulgate rules governing exploration and mining of hydrocarbons on all lands
within the jurisdiction of the State, public and private, in order to prevent the waste of
hydrocarbons and to protect correlative rights and natural resources.”1823
1819 Me. Rev. Stat. Ann. tit. 12, § 549 (2010).
The directors are also
permitted to, “promulgate rules on all lands in the State to specify the size of the area of
exploration, the amount charged for exploration permits and exploration claims, the duration of
those permits and claims and other matters related to the exploration and mining of hydrocarbons
on State lands.”1824
[3] – Regulatory Process.
The Bureau regulates the surveying of minerals on state lands through the use of
exploration permits.1825 The Bureau may grant any individual over 18 years of age the authority
to explore state lands.1826 “Exploration” is defined as, “an examination of an area for the purpose
of discovering the presence of minerals with techniques which include all of the manual,
mechanical, electronic or chemical methods of determining the presence, size and quality of a
mineral deposit.”1827
An individual is authorized to enter upon state lands for exploration upon “receipt of an
exploration permit from the director of the survey for the purpose of exploration.”
1828
“An exploration permit shall bear a number and be dated on the date of issue of the permit and shall expire at midnight on the next June 30th.
Exploration permits must meet the following guidelines:
1829 The holder of an exploration permit is entitled to a renewal of his permit upon expiration of the permit, upon making application to the director of the survey on or before June 30th, including payment of the prescribed fee, which renewal shall take effect on July 1st and bear the same number as the expired permit.”1830
The statute differentiates between standard exploration and exploration involving machinery or
“If machinery or explosives are to be used for exploration on state lands, the methods to be employed and the amount of explosives to be allowed shall first be approved by the director of the survey and the director of the agency having jurisdiction over the state land. The use of machinery or explosives shall be approved only where it will be done in harmony with the activities of the agency having jurisdiction over the state land and will not result in environmental harm.” 1831
Upon securing an exploration permit, any person or corporation is permitted to locate
their exploration claim, by establishing the boundary lines of the claim or claims. The
exploration claim cannot be smaller than 20 acres, unless the only available area on a parcel of
state land is smaller than 20 acres.
1832 The exploration claim is “construed to include all surface
found within the surface boundary lines, and all ledges throughout their entire vertical depth, but
shall not include any portion of the ledges beyond the end and sidelines of the exploration claim
or timber or growth on the exploration claim.”1833
The director of the agency with jurisdiction over the relevant state lands may issue
mining leases with the consent of the director of the survey.
1834 Once a corporation or individual
acquires a valid and recorded exploration permit they are permitted to apply for a mining lease
with the director of the agency.1835 The director of the agency will grant the petitioner a hearing
within 90 days of the application.1836
“… a report from a certified geologist or mining engineer containing all information of a geologic, engineering and operational nature which is required by the director of the survey or the director of the agency having jurisdiction over the state lands on which the mining lease is sought to properly evaluate the application and an accurate survey of the property boundaries
certified by a registered surveyor and evidence of ability to finance the proposed mining operations”1837
Upon receipt of a completed application the director of the agency will hold a hearing to
determine whether the mining leases should or should not be granted.
1838
“The hearing shall be held within 90 days of receipt of the application and notice of the date, time and place shall be given to the applicant and public notice shall be made by causing publication of the notice twice in a newspaper of general circulation in the proposed locality or, if none, in the state paper. The date of first publication shall be at least 10 days and the last publication shall be at least 3 days before the date of the hearing… A decision…shall be issued within 120 days of the date of the hearing.”
The proceedings must
meet the following standards:
1839
Once in receipt of a lease, the lessee must provide a bond in an amount to be determined
by the director of the agency.
1840 The bond may be used to “reclaim the area mined and to protect
against damage that may be caused to any property located outside the leased area by the lessee's
mining operations.” In lieu of a bond, the lessee is permitted to provide other security to be
determined by the director of the agency.1841
The lessee shall also be required to pay royalties annually or more frequently if specified
in the lease. The director of the survey and the director of the agency will determine the
“amount of royalty payments, including minimum royalties and preproduction payments,
together with the other terms and conditions of the lease.”
1842 The royalty rate should be
reasonably related to the prevailing royalty rates.1843
The statute provides the director of the survey or the director of the agency the power to
terminate the rights of alleged violators of the statute. 1844
…the director of the survey or the director of the agency having jurisdiction over the state-owned lands shall notify the explorer, claimant or lessee, as the case may be, of the alleged violation and of the nature of the alleged violation, by sending the notice by registered or certified mail to him at his last known address. If the violation is not remedied within 30 days after the date of mailing the notice, the permit, claim or lease of the violator in existence at the time of the violation may be terminated by the State through the director of the survey or the director of the agency having jurisdiction over the state-owned lands by giving written notice of termination in the same manner specified for notice of violation.
If an explorer or lessee is alleged to
have violated the statute:
1845
If it appears that any person is violating or threatening to violate the statute the state is
permitted to seek injunction against the person in Superior Court.
1846 The Superior court has
jurisdiction to grant to the state without bond, an injunction as warranted by the facts, “including
temporary restraining orders and preliminary injunctions.”1847
[e] Common and Undivided Interests.
The director of the survey and the director of the Bureau of Parks and Lands may
together promulgate procedures for the filing of exploration claims and issuance of exploration
permits and leases addressing, “state-owned public lands, including public reserved lands, which
are comprised of state-owned common and undivided interests.”1848
1844 Id. § 549-B(14).
The regulations promulgated
by the directors may, “condition the issuance of an exploration permit or mining lease and the
filing of an exploration claim upon the consent of a majority of the private common and
rules, regulations, and orders must be written and maintained as public records, copies of which
are receivable in all state courts.1858
Any person adversely affected by any Department rule, regulation or order may file a
written application for a rehearing within 15 days after the effective date thereof.
1859 The
Department will act upon the application within 15 days of filing, and promptly hold a hearing if
it so chooses.1860 If the rehearing is not granted, “any person aggrieved by any action of the
Department may apply to the circuit court of the county in which the person resides[,] or the well
is located[,] for review of [the Department’s] decision.”1861 The Department may become a
party to such appeal.1862 The court will review the agency’s decision de novo and determine all
matters of law and fact without a jury.1863 Any party aggrieved by a final decision of the circuit
court may then appeal to the Maryland Court of Special Appeals.1864
[3] – Drilling and Operating Permits.
No person may drill a well without first obtaining a permit from the Department.1865
(1) The names and contact information of the applicant, operator, and resident agent;
An
application for a drilling and operating permit must include, among other information:
(2) An environmental assessment; (3) A copy of the oil and gas lease that gives the applicant the right to enter and drill at the proposed location, and if the mineral rights have been severed, a copy of the right of entry agreement with the surface owner; (4) If a pooled unit, copies of all leases in the unit which shall accompany the application showing the right to pool interests; and,
(5) Certification that the applicant has provided written notice of intent to drill to each landowner and leaseholder of property that borders the proposed drillable lease area.1866
Upon proper application, the Department will notify the public via weekly publication for two
consecutive weeks “in a newspaper of general circulation in the county where the proposed
permit activity would occur” that a complete application has been received.
1867 The notice must
provide an opportunity for any interested person to request a public hearing, which will be held
within 45 days the Department’s receipt of such request.1868 The Department will then publish
notice of the hearing in the same fashion, hold a public hearing, and decide whether to approve
or deny the permit within 30 days thereafter.1869
Maryland imposes a statutory ban against drilling for oil or gas in the coastal waters and
tributaries of the Chesapeake Bay.
1870 Further, the Department may deny a permit application if
the proposed operation poses a substantial threat to public safety, or a risk of environmental
damage to: the Chesapeake Bay Critical Area; any wetlands; endangered or threatened species or
habitats thereof; designated historic properties; or populated areas.1871 No permit will be granted
if the operation “will constitute a significant physical hazard to” any dwelling, school, church,
hospital, commercial or industrial building, public road, or other public or private property.1872
Further, a permit will be denied if proposed operations will adversely affect the use of any public
park, forest, or recreation area.1873
[4] – Spacing Rules.
1866 Md. Code Regs. 26.19.01.06(C) (2010). 1867 Id. 21.19.01.07(B). 1868 Id. 1869 Id. 21.19.01.07(C). 1870 Md. Code Ann., Envir. § 14-107 (LexisNexis 2010). 1871 Md. Code Regs. 26.19.01.09(H) (2010). Lands included in the Chesapeake Bay Critical Area are defined and regulated under Md. Code. Ann., Nat. Res. § 8-1807 (LexisNexis 2010). 1872 Md. Code Ann., Envir. § 14-107 (LexisNexis 2010). 1873 Id.
346
No oil or gas well may be drilled on any tract nearer than 1,000 feet from any boundary
of said tract without the written consent of all owners of oil and gas underlying adjacent
lands. 1874 For coalbed methane wells, the required distance is 500 feet from any property
boundary.1875
The Department is authorized to prescribe the distance required between any two wells
located on the same property.
1876 The Department may also allow drilling within general
setbacks if necessary due to site constraints, provided that the applicant has notified all
landowners and royalty owners within 2,000 feet of the proposed well location. 1877 If the
Department grants an exception, it will “notify every landowner, royalty owner, [and]
leaseholder within the required minimum of the proposed well, giving them a reasonable
opportunity to file objections to the issuance of the permit.”1878
After notice, the Department will hold a hearing to determine whether an exception is
necessary.
1879 Any landowner, royalty owner, or leaseholder within the relevant distance may
file for a rehearing or appeal to a court of competent jurisdiction, which stays any authorization
granted under the permit until a final determination is made.1880
The Department may not issue a drilling permit for a gas well nearer than 2,000 feet to
any existing gas well in the same reservoir.
1881 Similarly, the Department may not issue a permit
to drill an oil well closer than 1,320 feet to any existing oil well within the same reservoir.1882
1874 Id. § 14-112(a)(1).
For both oil and gas wells, the Department may allow an exception to these distance
lands originally included with [said] agreement.”1889 Then, six months after initial production,
“the lands within the unit agreement not included as ‘in pool’ acreage[,] and on which no
royalties are payable[,] shall be released,” unless the owners of such lands have provided written
consent otherwise.1890
[6] – Directional Drilling
Notwithstanding these indirect references, Maryland law does not directly
address pooling or unitization or specify operator control requirements, restraints of trade, or
similar matters contemplated by other states.
Upon application, the Department may grant a permit for directional, or horizontal,
drilling operations.1891 The application must state (1) the reason(s) for proposed directional
drilling; (2) the depth at which deviation from the vertical is planned; and, (3) the horizontal
distance and direction of the proposed objective in reference to surface location.1892 Horizontal
operations also require extensive surveys to be taken prior to and during drilling and
production.1893
Absent a permit to authorize directional drilling, “a well may not vary more than 3
degrees from the vertical.”
1894 The Department may grant a permit for greater deviation “in
order to straighten the hole, sidetrack impenetrables, or to correct other mechanical difficulties,”
so long as correlative rights are not in dispute. 1895 Also, the Department may require the
deviation of a particular well to be less than three degrees if necessary to protect correlative
rights.1896
1889 Md. Code. Ann., Envir. § 14-113 (2010).
The Department may require a well to be re-drilled, or plugged and abandoned, “[i]f
1890 Id. 1891 Md. Code. Regs. 26.19.01.06(D) (2010). 1892 Id. 1893 Id. at 26.19.01.10(T)-(U). 1894 Id. at 26.19.01.11(A). 1895 Id. at 26.19.01.11(B). 1896 Id. at 26.19.01.11(C).
349
an angular deviation and directional survey verifies violations of the approved well location or
spacing requirements.”1897
1897 Id. at 26.19.01.11(E).
350
§ 22.01 Analysis of Massachusetts Regulatory Framework.
[1] – Governing Body and Structure.
Massachusetts law provides little discussion of oil and gas production, none of which
references pooling or unitization. The state Oil and Gas Act (“Act”), which comprises only three
statutory sections,1898 grants authority to the Department of Environmental Protection’s Division
of Mineral Resources (“Department”) to oversee mineral extraction within the
commonwealth.1899 Under the Act, those “mineral resources” concerned include “oil, gas, fossil
fuels, sulphur, metal, ores, minerals, rock, soil, sand and gravel.”1900
(a) license orderly exploration for mineral resources;
The Division of Mineral
Resources is led by a Director who, with Department approval, may:
(b) lease exclusive rights for extraction of such mineral resources as have been discovered; (c) establish…fees for such licenses; and, (d) adopt, after a public hearing, such rules and regulations relating to such exploration and extraction of mineral resources…as will insure the proper utilization of such resources consistent with the harvesting and propagation of other valuable natural resources and the general safety, welfare and convenience of the commonwealth.1901
[2] – Procedure.
The Department may not grant any license or adopt any rule under the Act without
holding “a public hearing, notice of which, including a statement of intent, shall be sent, at least
thirty days prior to said public hearing, to each city and town bordering on the coastal waters of
the commonwealth.”1902
1898 Mass. Gen. Laws ch. 21, §§ 54-56 (2010).
1899 Id. § 54. 1900 Id. 1901 Id. 1902 Id.
351
Under the Act, “[n]o lease shall be issued for the extraction of any mineral resource until
such time as the Department has obtained reliable information as to the quantities, quality and
location of the resource available…and as to the extent of and risk of harm to marine and other
natural resources.”1903 The Department makes this information public prior to the hearing to
afford citizens the ability to comment at the proceeding.1904
Prior to commencing extraction operations, a licensee or lessee must post a bond
“guaranteeing faithful performance of the contract with the commonwealth, …observance of any
applicable rules, regulations and statutes, and timely payment as provided in said contract for any
materials removed.”
1905 The Act does not specify a required bond amount, but only that it shall
serve to indemnify the commonwealth against any and all matters “in relation to or in connection
with [the applicable] license or lease.”1906
[3] – Extraction Operations.
The Act prohibits a licensee or lessee from operating under its contract “in such a manner
as to interfere unreasonably with navigation or fishing, or with the conservation of natural
resources.”1907 The Department may revoke or suspend any active license or lease “upon any
breach…by the licensee of any of the terms and conditions of the [contract], or upon any attempt
to assign the rights of the licensee to any third party, …or any evidence of [the licensee’s]
insolvency or…inability to perform under the contract.”1908
[4] – Other Matters.
1903 Id. 1904 Id. 1905 Id. 1906 Id. 1907 Id. Note that ‘conservation’ herein is not mineral waste prevention per se. In Massachusetts, “natural resources” includes mineral resources, but also all “wild birds,…wild mammals and game; sea and fresh water fish…; forests and all uncultivated flora;… land, soil and soil resources, lakes, ponds, streams, coastal, [and] underground and surface waters.” Id. ch. 21, § 1. 1908 Id.
352
The remainder of the Act authorizes and requires the Department to cooperate with other
states and political entities regarding off-shore mineral extraction, 1909 and establishes civil
penalties for mineral exploration or extraction without a license or lease from the
Department.1910
1909 Id. § 55. 1910 Id. § 56.
353
§ 23.01 Analysis of Michigan Framework.
[1] – Name of the Governing Body.
The Michigan Department of Environmental Quality (“Department”) has the power to
regulate unitization and pooling.1911 The Office of Geologic Survey, which is a division in the
Department, oversees the locating, drilling, operating, and plugging of oil and gas wells.1912
[2] – Membership on the Governing Body.
The Michigan Department of Environmental Quality (“Department”) was created by
executive order in 1995. The authority to govern unitization, plus many other actions, was then
transferred from the Michigan Department of Natural Resources to the Department by the
Governor.1913
[3] – Scope of Authority.
The Director of the Department (“Director”) is appointed by the Governor, and
may delegate his authority as necessary to adequately perform his duties.
Michigan’s stated policy to foster natural resource conservation frames the Department’s
goals to prevent waste and promote industry development and ultimate recovery of the maximum
production of these oil and gas.1914 Under direction of a designated supervisor, the Department
has jurisdiction over all persons and things necessary for effective enforcement of conservation
rules.1915 Waste is strictly prohibited under the Act1916
(1) underground waste, as those words are generally understood in the oil business;
and defined to include:
(2) the inefficient, excessive, or improper use or dissipation of the reservoir energy, including gas energy and water drive, of any pool;
(3) the locating, spacing, drilling, equipping, operating, or producing of a well or wells in a manner to reduce or tend to reduce the total quantity of oil or gas ultimately recoverable from any pool; (4) unreasonable damage to underground fresh or mineral waters, natural brines, or other mineral deposits from operations for the discovery, development, and production and handling of oil or gas; (5) surface waste, as those words are generally understood in the oil business; (6) the unnecessary or excessive surface loss or destruction without beneficial use, however caused, of gas, oil, or other product, but including the loss or destruction, without beneficial use, resulting from evaporation, seepage, leakage, or fire, especially a loss or destruction incident to or resulting from the manner of spacing, equipping, operating, or producing a well or wells, or incident to or resulting from inefficient storage or handling of oil; (7) the unnecessary damage to or destruction of the surface, soils, animal, fish, aquatic life, property, or other environmental values from or by oil and gas operations; (8) the unnecessary endangerment of public health, safety, or welfare from or by oil and gas operations; (9) the drilling of unnecessary wells; and, (10) market waste, which includes the production of oil or gas in any field or pool in excess of the market demand.1917
In order to prevent waste, the supervisor has broad authority and may promulgate and
enforce rules, issue orders of specific or general application, hold hearings, and “do whatever
may be necessary [to administer the Act]…whether or not indicated, specified, or enumerated
[therein].”
1918
[4] – Process for Pooling.
[a] Authority to Integrate Production.
To prevent the drilling of unnecessary wells, which is considered waste, the supervisor
may establish a drilling unit for each pool. A drilling unit is the maximum area that may be
efficiently and economically drained by one well.1919
1917 Id. § 324.61501(q).
All operations on any portion of the unit
1918 Id. § 324.61506. 1919 Id. § 324.61513(2).
355
area shall be considered the conduct of those operations upon each separately owned tract. As
such, the portion of the unit production allocated to a single tract is deemed to have been actually
produced from a well drilled on that tract.1920
The voluntary pooling of interests is permitted under the Act. If an agreement cannot be
made among owners, the supervisor may require pooling in any case when and to the extent that
the smallness or shape of a separately owned tract or tracts would, under the enforcement of a
uniform spacing plan or proration or drilling unit, otherwise deprive owners of the opportunity to
recover or receive a just and equitable share of oil or gas in the pool.
1921
The owner of any tract that is smaller than the drilling unit established for the field will
not be deprived of the right to drill on and produce from that tract, if the drilling and production
can be done without waste. If these conditions are met, the allowable production from that tract,
as compared with the allowable production if that tract were a full unit, will be in the ratio of the
area of the tract to the area of a full unit. A smaller ratio may be required to maintain average
bottom hole pressures in the pool, to reduce the production of salt water, or to reduce an
excessive gas-oil ratio. The portion of the production allocated to the owner of each tract
included in a drilling unit formed by voluntary agreement or by a pooling order will be
considered as if it had been produced from the tract by a well drilled on the tract.
1922
Michigan law provides for the orderly development of state-owned resources through an
oil and gas leasing program. The pooling of state-owned lands is not required if the supervisor
determines the owner of each tract is afforded the opportunity to recover and receive his or her
just and equitable share of the hydrocarbon resources in the pool.
Any interested lessee may file a verified petition with the supervisor requesting an order
for the unit operation of a pool, pools, or parts of one or more pools. The petition needs to
contain:
(1) a description of the pool, pools, or parts of one or more pools to be so operated, termed the unit area; (2) the names of all persons owning or having an interest in oil and gas in the proposed unit area; (3) the names of all surface owners in the proposed unit area, as disclosed by the records in the office of the register of deeds for the county in which the unit area is situated, and their addresses, if known. If the address of any person is unknown, the petition shall so indicate; (4) a statement of the type of the operations contemplated; (5) a recommended plan of unitization applicable to the proposed unit area which the petitioner considers fair, reasonable, and equitable; (6) a verified statement indicating in detail what action the petitioner has taken to contact and obtain the approval of all persons of record owning or having an interest in oil and gas in the proposed unit area who have not approved the proposed plan of unitization. This verified statement need not be part of the petition and may be filed separately prior to the supplemental hearing if the question of whether the plan for unit operations has been approved and is to be considered at a supplemental hearing.1924
Once the petition is filed, the petitioner will give notice to all interested persons.
1925
(1) once each week for [two] weeks consecutively in a newspaper of general circulation in the county in which the unit area or any portion of the unit area is located if the date of last publication is at least [twenty] days prior to the date set for the hearing; and,
Notice of time, place, and issues involved must be published:
(2) at least [twenty] days prior to the date set for the hearing in a trade journal, periodical, or newsletter or paper, or commercially available scout report, in general circulation in exploratory and developmental branches of the oil and gas industry in this state.1926
1924 Id. § 324.61703.
1925 Id. § 324.61704 (1). 1926 Id. § 324.61726.
357
The petitioner’s notice to interested persons needs to provide the procedure required to
file a protest and the name, address, and phone number of a representative of the petitioner who
is available to discuss the petition.1927 A person protesting the petition has fifteen days after the
completion of the publication of notice to provide the supervisor with written notice of protest
and the reason or reasons for the protest.1928 Other than this requirement, the Act does not set
forth any other procedure to protest the petition. The notice also needs to state that the
supervisor may issue an order approving the petition without a hearing if no protests are received
within the proscribed period of time. The notice to all mineral owners who have not approved
the plan of unitization shall include a copy of the petition.1929
Additionally, the notice needs to be provided to the last known address of the following
interested persons:
(1) the last owner of record of the oil and gas mineral interests underlying the lands or areas directly affected by the proposed action, and of the surface owners; (2) the last owner of record of the oil and gas mineral interests underlying the lands or areas immediately adjacent to, and contiguous to, the lands or areas directly affected by the proposed action, and of the surface owners; and (3) the last owner of record of oil and gas leases from one or more owners described above.1930
If the delivery of the notice is by certified mail, then receipts need to be filed with the
supervisor on or before the date of the hearing, or before the supervisor's order is issued if there
is no hearing. Undelivered notices that are returned to the petitioner will be filed with the
supervisor on or before the date of the hearing, or before the supervisor's order is issued if there
is no hearing. If notice is given by personal service, an affidavit of service will be filed with the
(2) the type of operations contemplated by the plan are feasible, will prevent waste, and will protect correlative rights; and, (3) the estimated additional cost of conducting such operations will not exceed the value of the additional oil and gas so recovered.1939
The order needs to be upon terms and conditions that are fair, reasonable, and equitable.
The order for the unit operation plan will provide:
(1) a description of the unit area; (2) a statement in reasonable detail of the operations contemplated; (3) an allocation to the separately owned tracts in the unit area of all the oil and gas that is produced from the unit area and is saved, excepting that production that is used in the conduct of operations on the unit area or unavoidably lost. A separately owned tract's fair, reasonable, and equitable share of production shall be measured by the value of the tract for oil and gas purposes and its contributing value to the unit in relation to like values of all tracts in the unit; (4) the manner in which the unit and the further development and operation of the unit area shall or may be financed and the basis, terms, and conditions on which the cost and expense will be apportioned among and assessed against the tracts and interests made chargeable therewith, including a detailed accounting procedure governing all charges and credits incident to the operations; (5) provisions for carrying or otherwise financing a person who elects to be carried or otherwise financed, allowing a reasonable interest and service charge payable out of the person's share of production; (6) the procedure and basis upon which wells, equipment, and other properties of the several lessees within the unit area are to be taken over and used for unit operations, including the method of arriving at the compensation therefore; (7) provisions for supervision and conduct of the unit operations, in respect to which each person will have a vote with a value corresponding to the percentage of the costs of unit operations chargeable against the interest of the person; (8) the time when the plan of unitization becomes effective and when unit operations commence; (9) the time when, conditions under which, and method by which the unit shall be dissolved and its affairs wound up; and, (10) additional provisions that are found to be appropriate for carrying on the unit operations and for the protection and adjustment of correlative rights.1940
1939 Id. § 324.61704(4).
360
An order of the supervisor providing for unit operations cannot be declared or become
effective until the supervisor makes a finding, either in the order providing for unit operations or
in a supplemental order, that the plan for unit operations has been approved in writing by the
appropriate persons. If a finding of approval by the appropriate person is not made at the time of
the order for unit operations, the supervisor, after notice and on the supervisor's motion or the
motion of any interested person, will hold supplemental hearings to determine if the plan for unit
operations has been approved. If the written approval is found, then the supervisor will make a
supplemental order declaring the plan effective and setting forth the date for the commencement
of unit operations. If the written approval is not found within a period of six months from the
date on which the order providing for unit operations is made, the order will be ineffective and
must be revoked by the supervisor unless, for good cause shown, the supervisor extends the time
for an additional period not to exceed one year.
Additionally, an order providing for unit operations may be amended by an order made
by the supervisor in the same manner and subject to the same conditions as an original order for
unit operations after approval by the appropriate persons. An amendment will not change the
percentage for the allocation of oil and gas as established for any separately owned tract without
the consent of all persons entitled to receive the allocation.1941
Operations conducted pursuant to an order of the supervisor for unit operations constitute
a fulfillment of all the express and implied obligations of each lease or contract covering lands in
the unit area to the extent that compliance with the obligations cannot be had because of the
Neither the Act nor any other promulgated rules discuss the royalty interest rate.
[e] Modifications and Exceptions.
The supervisor, by order, may provide for the unit operation of a unit area that embraces
a unit area established by a previous order. The order in providing for the allocation of unit
production first will treat the unit area previously established as a single tract, and the portion of
the unit production so allocated thereto will then be allocated among the separately owned tracts
included in the previously established unit area in the same proportions as those specified in the
previous order.1943
An order may provide for a unit area less than the whole of a pool if the unit area is of
such size or shape as may be reasonably adaptable to unit operation and if the conduct of that
unit area will not have a substantially adverse effect upon other portions of the pool, whether
unitized or not.
1944
§ 23.02 Types of Michigan Pooling Statutes.
[1] – Mineral Distinctions.
For general application to waste prevention and the creation of drilling units, the Act
defines oil and gas as follows:
(1) “Gas” means a mixture of hydrocarbons and varying quantities of non-hydrocarbons in a gaseous state which may or may not be associated with oil, and includes those liquids resulting from condensation. (2) “Oil” means natural crude oil or petroleum and other hydrocarbons, regardless of gravity, that are produced at the well in liquid form by ordinary production methods and that are not the result of condensation of gas after it leaves the underground reservoir.1945
The Act also provides a collective definition particular to unitization concerns:
(1) “Oil and gas” means oil and gas as such in combination one with the other and also means oil, gas, casinghead gas, casinghead gasoline, gas distillate, or other hydrocarbons, or any combination or combinations of these substances, which may be found in or produced from a common source of supply of oil, gas, oil and gas, or gas distillate.1946
[2] – Split by Depth.
The Act does not differentiate its default provisions based on well depth.
[3] – Spacing Rules.
Each well permitted to be drilled upon any drilling unit shall be located in the
approximate center of the drilling unit, or at such other location on the drilling unit as may be
necessary to conform to a uniform well spacing pattern as adopted and promulgated by the
supervisor.1947
(1) the unit is partly outside the pool or that, for some other reason, a well at the location would be unproductive;
The well may be located so it does not conform with the uniform well spacing
pattern if the supervisor finds that:
(2) the owner or owners of a tract or tracts covering that part of the drilling unit or tract on which the well would be located if it conformed to the uniform well spacing pattern refuses to permit drilling at the regular location; (3) topographical or other conditions are such as to make drilling at the regular location unduly burdensome or imminently threatening to water or other natural resources, to property, or to life.1948
Also, the drilling and permitting of an oil and gas well is prohibited if located within 450 feet of
a residence lying in a city or township with a population of 70,000 or more. However, a waiver
may be granted by the supervisor if:
(1) the clerk of the city, village, or township in which the well is located has been notified of the application for the well permit; (2) the owner or owners of all residential buildings located within 450 feet of the proposed well give written consent;
(3) the supervisor determines that there is no reasonable alternate location for the well that will allow the oil and gas rights holder to develop the oil and gas; and, (4) the well will not cause waste.1949
[4] – Size.
The Act does not specify the size of a drilling unit.
[5] – Minimum Operator Control.
For an order of the supervisor providing for unit operations to be declared or to become
effective, the plan for unit operations needs to have been approved in writing by:
(1) those persons who under the supervisor's order will be required to pay at least 75% of the costs of unit operation, and also by those persons who under the supervisor's order will be entitled to at least 75% of the production from the unit area or the proceeds of that production that will be credited to interests that are free of cost, including, but not limited to, royalties, overriding royalties, and production payments; (2) those persons who under the supervisor's order will be entitled to at least 75% of all production from the unit area or the proceeds of that production, provided that among those persons there must be persons who under the supervisor's order will be entitled to at least 50% of the production from the unit area or the proceeds of that production that will be credited to interests that are free of cost, including, but not limited to, royalties, overriding royalties, and production payments; or (3) those persons who under the supervisor's order will be entitled to at least 90% of all production from the unit area or the proceeds of that production.1950
Additionally, when an order providing for unit operations has been amended, and the
amendment affects only the rights and interests of those persons responsible for the payment of
the costs of unit operations, only 75 percent of these persons are required to effectuate the
amendment. If an amendment in whole or in part changes the percentage of allocation of cost,
then the consent of all these persons is required. If the consent is granted by all person entitled to
1949 Id. § 324.61506(b). 1950 Id. § 324.61706.
364
receive the allocation of oil and gas as established for any separately owned tract, then the
amendment may change the percentage of allocation.1951
1951 Id. § 324.61708.
365
§ 24.01 Analysis of Minnesota Regulatory Framework.
[1] – Governance.
In Minnesota, the Commissioner of the Department of Natural Resources (“Department”)
is given the authority to adopt rules relating to spacing, pooling, and unitization of oil and
gas.1952 The Commissioner is the head of the Department1953 and is appointed by the Appointing
Authority with consent of the Senate.1954 The Appointing Authority is defined as “a person or
group of persons empowered by the Constitution, statute, or executive order to employ persons
in or to make appointments to positions in the civil service,”1955 here, the governor.1956 The
Commissioner’s term expires along with the term of governor, whether the governor’s term ends
due to natural expiration or is vacated for other reasons.1957 No former commissioner or deputy
commissioner may participate in a proceeding of the Department representing private interests
within one year of leaving the position.1958
If a vacancy occurs in the Commissioner’s office or the incumbent is not designated at
the term’s end, the Deputy Commissioner fills in until further notice. If more than one deputy
commissioner exists, the governor determines which takes charge; if no deputy commissioner
exists, the governor will appoint a temporary commissioner.
1959 The governor also has the
power to appoint someone other than the Deputy Commissioner as the temporary
therefrom; and to obtain the full development of all producing pools or those which may later be
brought into production.1988
Further, it is not the State’s intent to prorate oil and gas production on the basis of market
demand, but rather to allow each pool in the State to be produced to its maximum efficient rate
of production, subject to the prohibition of waste and subject to protection of correlative
rights.
1989
(1) The inefficient storing of oil; and the locating, spacing, drilling, equipping, operating or producing of any oil or gas well or wells in a manner causing or tending to cause unnecessary or excessive surface loss or destruction of oil or gas.
Waste is explicitly made unlawful in section 53-3-3 of the Statute. The Statute
defines “waste” as follows:
(2) Abuse of the correlative rights and opportunities of each owner of oil or gas in a pool due to non-uniform, disproportionate, or unratable withdrawals causing undue drainage between tracts of land or resulting in one or more owners in such pool producing more than his just and equitable share of the production from such pool. (3) Producing oil or gas in such manner as to cause unnecessary channeling of water or gas or both or coning of water. (4) The operation of any oil well or wells with an inefficient gas-oil ratio. (5) The drowning with water of any stratum or part thereof capable of producing oil or gas. (6) The creation of unnecessary fire hazards. (7) The escape into the open air, from a well producing both oil and gas, of gas in excess of the amount which is necessary in the efficient drilling or operation of the well. (8) Permitting gas produced from a gas well to escape into open air. (9) The use of gas from gas wells, except sour gas, for the manufacture of carbon black, except and unless the board shall find that there are no adequate pipeline connections to otherwise market the gas.1990
1988 Id. § 53-1-1.
1989 Id. 1990 Id. § 53-1-3(l).
371
The Board has the authority and duty to discover whether or not waste exists or is
imminent. In exercising that authority, the Board may do the following: collect data; make
investigations and inspections; examine properties, leases, papers, books and records, including
drilling records and logs; examine, check, test and gauge oil and gas wells, tanks, refineries, and
modes of transportation; hold hearings; require recordkeeping and report-making; and do all
other things reasonably necessary to enforce sections 53-1-1 through 53-1-47 and 53-3-1 through
53-3-21 of the Statute.1991
The Board also has the authority and duty to make reasonable rules and orders for the
following purposes, among others:
(c) To require adequate proof of financial responsibility in a form acceptable to the board and conditioned for the performance of the duties [of drilling in an environmentally responsible manner] as outlined in paragraphs (a) and (b) of this subsection . . . . (k) To regulate the spacing of wells and to establish drilling units. (l) To allocate and apportion the production of oil or gas, or both, from any pool or field for the prevention of waste as herein defined, and to allocate such production among or between tracts of land under separate ownership in such pool on a fair and equitable basis to the end that each such tract will be permitted to produce not more than its just and equitable share from the pool. (m) To prevent, so far as is practicable, reasonably avoidable drainage from each developed unit [that] is not equalized by counter-drainage.1992
The Board has the authority to regulate the drilling and location of wells in pools and to
regulate the production from those wells so “to prevent reasonably avoidable net drainage from
each developed unit (that is, drainage which is not equalized by counterdrainage)” so that all
1991 Id. § 53-1-17(2). 1992 Id. § 53-1-17(3).
372
owners might be able to receive their fair and equitable share of production from the pool.1993 In
carrying out all of its duties to prevent waste and protect correlative rights, the Board should
establish a drilling unit or units for each pool.1994 The Board has the authority to require owners
of separate tracts and/or separate interests within those drilling units to integrate or pool their
interests for development.1995 Additionally, the Board, upon application of an interested person,
may hold a hearing to determine whether an entire field, or an entire pool or pools, or any portion
or portions or combinations thereof, within a field, should be operated as a unit for production of
oil or gas, or both, to increase the ultimate recovery of oil and gas and to prevent waste.1996
[4] – Process for Pooling.
Integration of interests and development of lands as a drilling unit may be appropriate
when an established drilling unit covers two or more separately owned tracts or embraces
separately owned interests. The persons owning such tracts or interests may agree to integrate
their interests. However, in the event such owners have not so agreed, the Board may require
integration in order to prevent waste or to avoid drilling unnecessary wells. Such an order must
be made after notice and hearing and should be upon terms that are just and reasonable and that
will give owners the ability to recover their just and equitable share of oil and gas in the pool
without unnecessary cost.1997 The Board, upon the application of an interested person, may also
determine whether or not an entire field, or a pool or pools, or a portion or combination thereof,
should be operated as a unit in the interest of preventing waste and of preventing the drilling of
reasonably necessary in order to effectively carry on secondary recovery, pressure maintenance, repressuring operations, cycling operations, water flooding operations, or any combination thereof, or any other form of joint effort calculated to substantially increase the ultimate recovery of oil or gas or both, from the unit so formed, or to prevent waste as defined [herein]; (b) One or more method of unitized operation as applied to such common source of supply or portion thereof is feasible and will prevent waste or will with reasonable probability result in the recovery of substantially more oil or gas, or both, from the unit so formed than would otherwise be recovered; (c) The plan of unitization and the agreements effectuating same are fair and reasonable under all of the circumstances and protect the rights of all interested parties; (d) The correlative rights of interested parties will be protected; (e) The estimated additional cost incident to conducting such operation will not exceed the value of the estimated additional recovery of oil and gas and such cost of oil operation shall not be borne by the royalty owners.2015
Unit operators must have drilled enough wells to a sufficient depth and at such locations “as may
be necessary for the board to approve the boundaries of the unit and determine that the field, pool
or pools have been reasonably developed according to a spacing pattern approved by the
board.”
2016 Field unitization may not be approved until each of the field’s drilling units have
been drilled, unless the Board waives this requirement after finding that it is not economically
feasible for a certain drilling unit to be drilled.2017
The prevailing party must draft a proposed order for the Board to review and approve,
which order must specify the findings of fact and conclusions of law.
2018 The signed order must
then be filed with the Board not more than 30 days after the final decision.2019
2015 Id. § 53-3-103.
Unitization orders
should be fair and reasonable under all circumstances and must include the following:
(a) A description of the unit area. (b) A statement of the nature of the operations contemplated. (c) A formula for allocating production from the unit, which allocation should provide each person with his or her just and equitable share of unit production, being the proportionate part of the unit production value contributed by his or her tract as said tract bears to the total of all like values of all tracts in the unit. (d) A provision for the adjustment among the owners (not including royalty owners) of their respective investment in drilling materials and services for unit operations. The owners of the unit area will determine the amount to be charged; if those owners cannot agree to the amount, the Board must determine appropriate charges after notice and hearing. The cost of dry holes drilled within the unit area before the effective date of an order of the Board is not chargeable as investment unless used in the unit operation, in which event its value to the unit shall be charged as investment. (e) A provision that the costs and expenses of unit operation, including investment past and prospective, will be borne by the owner or owners (not entitled to share in production free of operating costs and who in the absence of unit operation would be responsible for the expenses of developing and operating) of each tract in the same proportion that such tract shares in unit production. The unit operator has a lien thereon to secure payment of such share. If any owner fails to pay his part when due, then all of that owner’s interest in the unit production and equipment may be foreclosed in the same manner and under the same procedures provided for the foreclosure of mortgages in chancery court. A transfer or conversion of any owner’s interest or any portion thereof, however accomplished after the effective date of the order creating the unit, shall not relieve the transferred interest of said operator’s lien on said interest for the cost and expense of unit operations, past or prospective. (f) The designation of, or a provision for the selection of a successor to the unit operator, the conduct of whom is governed by the terms of the unitization agreement. (g) The time the unit operation shall become effective and the manner in which, and the circumstances under which, the unit operation shall terminate. (h) A requirement that all oil and/or gas contained in a unit area shall be produced and sold as rapidly as possible without decreasing the ultimate recovery of such oil and/or gas causing damage to the reservoir.2020
2020 Miss. Code Ann. § 53-3-105 (2011).
377
Orders requiring unitization do not become effective until the plan and agreement have
been signed or ratified in writing by the owners or lessees of at least 75 percent in interest in
proportion to the surface acreage content of the unit area and by at least 75 percent (exclusive of
royalty interests owned by lessees or by subsidiaries or successors in title of any lessee) in
interest of the royalty owners on the basis of the surface acreage content. Also, the Board must
have found that the requisite approval has been given in the initial order or in a supplemental
order. If the required percentage of interest holders does not give such approval within 12 month
of the order, it will be automatically revoked.2021 The Board may extend or add new portions of
pools to an existing unit area to be approved by the same percentage of interest holders of the
area to be added.2022
Board orders may be appealed to the chancery court of the county where the land
involved is located. Appeals must be made within 30 days from the date the order is filed with
the Board.
2023
[5] – Matters Covered.
[a] Number of Wells.
As noted above, a petition may be filed to obtain permission to drill multiple wells within
a single unit. Unless such an exception is granted, not more than one well may be producing
from or drilled to the same pool in a unit.2024
[b] Depth and Spacing Rules.
The Statewide Rules and Regulations (“Statewide Rules”) provide detailed spacing and
depth requirements. Spacing rules differ based upon which pool is drained, as well as based
the sale of such share, . . . or the market value thereof if such share is not sold, after deducting
production and excise taxes, . . . and the payment required herein” is equal to the sum of the
following:
(a) [100%] of the non-consenting owner’s non-consenting share of the cost of any newly acquired surface equipment beyond the wellhead connections including, but not limited to, stock tanks, separators, treaters, pumping equipment and piping; (b) [250%] of that portion of the costs and expenses of operations provided for in the pooling order, and [250%] of that portion of the cost of newly acquired equipment in the well, including wellhead connections, which would have been chargeable to the non-consenting owner’s non-consenting share thereof, provided, however, when a mineral interest that is severed from the surface estate is owned by a non-consenting owner or when a mineral interest is subject to an oil and gas lease that is owned by a non-consenting owner, the payment under this subparagraph shall be [300%]; and (c) [100%] of the non-consenting owner’s non-consenting share of the cost of operation of the well commencing with the first production and continuing to such point in time.2037
Within 60 days after completion of operations on which alternate charges were ordered,
the operator must furnish to non-consenting owners who make a request an itemized statement of
the costs of production; or the operator may submit detailed monthly statements of its costs
instead of an itemized statement. Amounts realized from the sale or disposition of equipment
obtained in connection with operations which would have been owned by a non-consenting
owner had that owner participated will be credited against the total unreturned costs of the work
done and equipment purchased in determining when the interest of that non-consenting owner
will be owned by that non-consenting owner. If there is a credit balance, it must be paid to the
non-consenting owner.
2038
2037 Id. § 53-3-7(2)(g).
2038 Id. § 53-3-7(2)(h).
382
After the costs due in section 53-3-7(2)(g) have been paid by said non-consenting owner,
that owner will then own the same interest in the well, material, and equipment, and the
production therefrom, as that owner would have owned had it participated in the drilling.
Thereafter, the operator will be entitled to charge the non-consenting owner’s proportionate part
of all reasonable costs of operation, including a reasonable charge for supervision. The operator
may take such charges from that owner’s portion of production.2039
[d] Royalty Distribution.
If a leased interest is subject to a pooling and integration order, and the operator and/or
consenting owners are entitled to alternate charges, the lessor of the lease will be paid royalties,
not to exceed an amount of three/sixteenths of the proceeds attributable to the non-consenting
owner’s share of production.2040
When a disbursing agent, defined as “that person who, pursuant to an oil and gas lease,
operating agreement, purchase contract, or otherwise, assumes the responsibility of paying
royalty proceeds derived from a well’s oil and gas production to the royalty owner or owners
legally entitled thereto,”
No other specifics are provided regarding the amount of royalty
to be paid.
2041 has not disbursed royalty proceeds to the royalty owner within 120
days after the date of the first sale if the disbursing agent is a first purchaser, or within 120 days
following the date the disbursing agent receives the proceeds from such production if the
disbursing agent is not the first purchaser, the royalty owner will have a lien to secure payment
of royalty.2042
2039 Id.
The first purchaser, that is, “the first person who purchases oil or gas production
from the interest owners after the production is severed and may include the operator if the
on a drilling unit that consists of 80 contiguous surface acres or two contiguous governmental
quarter-quarter sections containing not less than 72 acres nor more than 88 acres on which no
drilling or producible well is located. “Contiguous” as used in this section means “bordering
each other at more than one point.” 2056 Any drilling unit that is not composed of two
governmental quarter-quarter section must be wholly encompassed by the “perimeter of a
rectangle 1600 feet by 2725 feet.” However, no such unit may create island acreage.2057 Wells
must be at least 1,000 feet from other drilling wells or wells producing from or completed in the
same pool.2058 The wells must be at least 500 feet from every exterior boundary of the drilling
unit.2059
For each pool “occurring in the discovery well, the top of which is encountered below a
measured depth of 12,000 feet below the surface,” the Supervisor may allow 160-acre units for
those pools if the unit size will foster the orderly development of the pool.
2060
(a) on a drilling unit of four contiguous quarter-quarter sections of not less than 144 nor more than 176 acres upon which no other well producing from or drilling to the same pool is located;
All wells drilled
in such pools must be
(b) if not made of four contiguous quarter-quarter sections, 160 surface acres, which must be completely encompassed by the perimeter of a rectangle 2,640 feet by 3,500 feet, so long as no island acreage is thereby created; and, (c) each well must be at least 1,500 feet from other wells drilling or producing from the same pool and not less than 750 feet from all exterior boundaries of the drilling unit.2061
For all other pools, all oil wells must be on a drilling unit of 40 contiguous surface acres
or a governmental quarter-quarter section of not less than 36 acres nor more than 44 acres, upon
(a) To foster, to encourage and to promote the orderly and economic development, production and utilization of natural resources of oil and gas. (b) To authorize and to provide for the operation and development of oil and gas properties in a manner that a greater ultimate recovery of oil and gas be had and that the correlative rights of all owners be fully protected. (c) To encourage and to authorize the development and use of physical processes to obtain the greatest possible economic recovery of oil and gas. (d) To provide for complete protection of…fresh water…; and, (e) To provide for the elimination of surface or subsurface pollution or waste during and after drilling, producing and abandonment procedures in all wells.2098
Under the state geologist’s supervision, the Council has broad statutory authority to foster
oil and gas development in Missouri and prevent waste, which is explicitly prohibited.
2099
(a) Physical waste, as…generally understood in the oil and gas industry, but not including unavoidable or accidental waste;
“Waste” is defined to include:
(b) The inefficient, excessive, or improper use of, or the unnecessary dissipation of, reservoir energy; (c) The location, spacing, drilling, equipping, operating, or production of any oil or gas well or wells in a manner which causes, or tends to cause, reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or which causes or tends to cause unnecessary or excessive surface loss or destruction of oil and gas; (d) The inefficient storing of oil; (e) The production of oil or gas in excess of transportation or marketing facilities or in excess of reasonable market demand; and, (f) Through negligence, the unnecessary or excessive surface loss or destruction of oil or gas resulting from evaporation, seepage, leakage or deliberate combustion.2100
The Council must engage in reasonable investigation to determine existing or potential
waste, and in doing so may require the “identification of [well] ownership, . . . making and filing
of all mechanical well logs; . . . operation . . . of wells in such manner as to prevent the escape of
oil or gas out of one stratum into another,” and other related practices pursuant of waste
prevention.2101 In addition, the Council may regulate “[t]he drilling, producing, and plugging of
wells, and all other operations for the production of oil and gas; . . . the spacing of wells; [and]
operations to increase ultimate recovery . . . .”2102 This encompassing authority includes, among
other things, the ability “to limit and [] allocate the production of oil and gas from any field,
pool, or area” within the state.2103
In general terms, the Council is authorized and required to “promulgate and enforce rules,
regulations, and orders to effectuate the purposes and intent” of the Act.
2104 Except in
emergency situations, the Council must provide notice and a hearing prior to entering an
order.2105 The Council may act upon its own motion, or upon a petition of “any interested
person.”2106
Any notice required by this chapter shall be given at the election of the Council either by personal service or by letter to the last recorded address of the person to whom the order is directed and one publication in a newspaper of general circulation in the county where the land affected, or some part thereof, is situated. If the notice is applicable throughout the state, then it shall be published in a newspaper of general circulation which is published in Jefferson City. The notice shall issue in the name of the state, shall be signed by the state geologist, shall specify the style and number of the proceeding, the time and place of the hearing, and shall briefly state the purpose of the proceeding. Should the Council elect to give notice by personal service, such service may be made by any officer authorized to serve process, or by any agent of the Council, in the same manner as is provided by law for the service of
If a petition is filed, the Council will promptly cause notice of the hearing to be
given. The Act specifies notice requirements particular to Council actions:
2101 Id. § 259.070. 2102 Id. 2103 Id. 2104 Id. §§ 259.070, 259.140. 2105 Id. § 250.140. 2106 Id. Neither Missouri statute nor regulation related to oil and gas define “interested person.”
395
original notices in civil actions in . . . the state. Proof of the service by such agent shall be by the affidavit of the person making personal service.2107
A Council order must be in writing and entered within 30 days following the hearing.
2108
Once entered, all orders are kept by the state geologist as public record, copies of which are
receivable into evidence in all Missouri courts.2109 Any person adversely affected by an order
may, within 30 days of its effective date, move the Council for a rehearing.2110 The Council may
deny such application, in which case the applicant may appeal to the Circuit Court of Cole
County or any locality in which a portion of the affected property rests.2111
[4] – Process for Pooling and Matters Covered.
To avoid waste, the Council consistently assesses market demand for oil and gas. As
defined in the Act, “reasonable market demand” is “the demand for oil or gas for reasonable
current requirements for consumption and use,” both within and outside Missouri, together with
the quantity needed to maintain reliable reserves of each product.2112 The Council must limit
production to that amount which can be produced without waste and without exceeding market
demand.2113
If restrictions are needed, the Council shall allocate allowable production reasonably
among pools within the state. Further, if the Council limits production within a particular pool, it
must distribute allowable production among the various wells or producing properties on a
reasonable basis.
2114
2107 Id.
Subject to aims of waste prevention, allocation within a pool should
minimize avoidable drainage to ensure that “each property will have the opportunity to produce
description of the proposed unit area; (2) a statement of the nature of the proposed unit operation;
and (3) conformed copies of the applicable unit agreements.”2132
The Council will require the refusing owner’s incorporation into the proposed pooling
agreement if, after notice and hearing, the Council determines that: (1) at least 75 percent of
interests in the right to drill and produce from the proposed unit agree to pool; (2) pooling is
reasonably necessary to avoid waste, increase recovery, and protect correlative rights; and, (3)
the value of additional oil and gas recoverable under the proposed plan outweighs the costs
needed to effectuate the proposal.
2133 Once so ordered, the proposed agreements bind all parties
owning interest in the unit area or any oil or gas produced therefrom.2134
A compulsory pooling order must be fair and reasonable under all circumstances.
2135
Each pooling order shall account for the drilling and operation of a well on the spacing unit, and
payment of costs required for operation, plus a reasonable charge for supervision. 2136
(1) A description of the unit area;
In
particular, each order must include the following:
(2) An allocation, upon the basis agreed upon by the provisions of the unit applicable agreements, and found by the council to be fair and equitable to each separately owned tract in the unit area, in that under the allocation each separately owned tract receives its fair share of all of the oil and gas produced from the unit area and not required or consumed in the conduct of the operation of the unit area or unavoidably lost; (3) A provision for the credits and charges to be made in the adjustment among the owners of the unit area for their respective investments in wells, tanks, pumps, machinery, materials and equipment contributed to the unit operation; (4) A provision that a part of the expenses of unit operation, including capital investments, be charged to each separately owned
tract in the same proportion that the tract shares in the unit production; (5) Designation of the unit operator and the time at which the unit operation shall commence; and, (6) Those additional provisions, not in conflict with, or inconsistent with, the applicable unit agreements, which the Council determines to be appropriate for the prevention of waste and the protection of all interested parties.”2137
[c] Allocation of Production and Costs.
All operation related to oil and gas development that occurs on any portion of a pooled
area is deemed to have occurred on all portions.2138 In turn, “that portion of the production
allocated to each tract included in a spacing unit covered by a pooling order shall, when
produced, be deemed for all purposes to have been produced from such tract by a well drilled
thereon.” 2139
Expenses incurred by owners within a pool are similarly apportioned amongst the group.
In compulsory pooling situations, “the net amount charged against the owner or owners of a
separately owned tract shall be considered expenses of unit operation chargeable against such
tract.”
In other words, each owner within a pooled unit is entitled to production
proportional to his or her respective ownership interest of the entire pool.
2140 Further, “expenses chargeable to a tract shall be paid by the person or persons who, in
the absence of unit operation, would be responsible for the expense of developing and operating
such tract.”2141
Liability for expenses is allocated to each owner based on that party’s respective
interest.
2142
2137 Id. § 259.120.
The obligation of each interest-holder within a pool “shall at all times be several and
protect against offset drainage in the event offset wells were drilled prior to the enactment of” the
Act.2161
[4] – Minimum Operator Control.
As noted above, the Council will not grant a compulsory unitization order unless it
receives approval from the owner(s) of at least 75 percent of the interests in the drilling and
production rights from the total proposed unit area, as well as the owner(s) of at least 75 percent
of production payments, royalty, and overriding royalty that is payable with respect to oil and
gas produced from the area to be covered by the order.2162
[5] – Directional Drilling.
Neither the Act nor Council regulations distinguish or reference vertical or horizontal
drilling.
[6] – Options.
Missouri statutes and regulations do not address the issue of election rights related to oil
and gas production.
2161 Id. The Act, codified at Section 259 of the Missouri Revised Statutes, was enacted in 1965. 2162 Mo. Rev. Stat. § 259.120 (2010).
404
§ 27.01 Analysis of Montana Regulatory Framework. [1] – Name of Governing Body. In the state of Montana, the Oil and Gas Conservation Act of 1953 (“Act”) created the
Board of Oil and Gas Conservation (“Board”) as a quasi-judicial agency to oversee the use of the
state’s natural resources.
[2] – Membership on the Governing Body. The Board is made up of seven members.2163 The Governor of Montana, upon his or her
election, appoints four of the Board members when he or she takes office. Two years later, the
Governor appoints the three remaining Board members.2164 The members must meet certain
qualifications prior to serving on the Board. Three members must be from the oil and gas
industry and have at least three years of experience in the production of oil and gas.2165 Two
members must be landowners residing in oil- or gas-producing counties of the state but not
actively associated with the oil and gas industry.2166 Of these two members, one must be a
landowner who owns the mineral rights with the surface, and the other shall be a landowner who
does not own the mineral rights.2167 The final member of the Board must be an attorney.2168
Each Board member serves four-year terms.2169
[3] – Scope of Authority.
The statute at issue is Montana Code Annotated section 82-11-101, et seq. According to
a case that has interpreted this statute, U.V. Industries v. Danielson, the primary purpose of the
Act is to prevent the waste of oil and gas by vesting power in the Board of Oil and Gas
Conservation to regulate the drilling, producing, and spacing of wells and the pooling and
utilization of oil and gas interests.2170 Generally, the Montana Legislature has empowered the
Board to “make investigations that it considers proper to determine whether waste exists or is
imminent . . . .”2171 Further, the Board has exclusive jurisdiction over all Class II injections
wells2172 and all pits and ponds in relation to those wells such that it may issue, suspend, revoke,
modify, or deny permits to operate such wells; may clearly specific limits as to volume and
characteristics of the fluids to be injected and the operation of the well; and may authorize staff
to enter upon any public or private property to inspect and investigate conditions relating to
violations of permit conditions.2173
Specifically, “the Board of Oil and Gas Conservation has broad powers to (1) conduct
evidentiary hearings; (2) establish well spacing units; (3) order involuntary pooling of interests
within such units; (4) grant or deny permission to drill wells; and (5) issue rules, regulations, and
orders to prevent waste.”
2174 Waste of oil and gas or either of them is prohibited. 2175
“‘Waste’2176
(i) physical waste, as that term is generally understood in the oil and gas industry; (ii) the inefficient, excessive, or improper use of or the unnecessary dissipation of reservoir energy; (iii) the location, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner which causes or tends to cause reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations or which causes
is defined as the following:
2170 See U.V. Indus., Inc. v. Danielson, 184 Mont. 203, 602 P.2d 571 (1979). 2171 Mont. Code Ann. § 82-11-111(1) (2010). 2172 Id. § 82-11-101(3). "Class II injection well" means a well, as defined by the federal Environmental Protection Agency or any successor agency, that injects fluids: (a) that have been brought to the surface in connection with oil or natural gas production; (b) for purposes of enhancing the ultimate recovery of oil or natural gas; or (c) for purposes of storing liquid hydrocarbons. 2173Id. § 82-11-111(5)(a)–(d). 2174 U.V. Indus., Inc., 184 Mont. at 212, 602 P.2d at 578. 2175 Mont. Code Ann. § 82-11-121 (2010). 2176 The loss of gas to the atmosphere during coal mining operations is not waste within the meaning of this definition.
406
or tends to cause unnecessary or excessive surface loss or destruction of oil or gas; and (iv) the inefficient storing of oil or gas. (The production of oil or gas from any pool or by any well to the full extent that the well or pool can be produced in accordance with methods designed to result in maximum ultimate recovery, as determined by the [B]oard, is not waste within the meaning of this definition.) 2177
Furthermore, the Code allows the Board, in the interest of preventing waste, to establish
well spacing units (through the size and shape
2178) for a pool of oil or gas and to grant exceptions
in appropriate cases to allow for a well to be drilled outside the location generally authorized by
the Board’s spacing orders.2179 “The size and shape of spacing units shall be such as will result
in efficient and economic development of the pool as a whole, and the size shall be the area that
can be efficiently drained by one well.”2180
[4] – Process for Pooling.
[a] Spacing units.
The Board, upon its own motion or upon application of an interested person, after
hearing, may order and establish (a) temporary spacing units on a statewide basis or for defined
areas within the state . . . oil, gas, or oil and gas wells drilled to varying depths; and (b)
permanent spacing units for a discovered pool . . . .” A temporary spacing unit must remain in
effect until the Board issues another order or until a permanent spacing unit is established. The
Board, upon application, notice, and hearing, may increase or decrease the size of a temporary or
permanent spacing unit or permit the drilling of additional wells in a spacing unit to (1) prevent
2177 Mont. Code Ann. § 82-11-101 (16) (a), (b) (2010). 2178 Mont. Admin. R. § 36-3-18(10)-S18040 (2010). 2179 Mont. Code Ann. § 82-11-201 (2010). 2180 Id. § 82-11-201(2).
407
or assist in preventing waste of oil or gas prohibited by this chapter, (2) avoid the drilling of
unnecessary wells, or (3) protect correlative rights.2181
[b] Pooling.
When two or more separately owned tracts are embraced within a temporary or
permanent spacing unit or when there are separately owned interests in all or a part of the
spacing unit, then the persons owning those interests may pool their interests for the
development and operation of the spacing unit.
The Board, upon the application of an interested person, may enter an order pooling all
interests in the permanent spacing unit for the development and operation of the permanent
spacing unit and the allocation of production if the applicant has made an unsuccessful, good
faith attempt to voluntarily pool the interests within the permanent spacing unit. The applicant
must be a person who owns an interest in the oil or gas underlying the permanent spacing unit or
who has drilled a well, proposes to drill a well, or proposes to conduct other operations on a well,
including recompleting, deepening, or stimulation.2182
Operations incident to the drilling of a well upon any portion of a permanent spacing unit
covered by a pooling order are considered, for all intents and purposes, the conduct of the several
owners of the tracts as if they were operating on each separately owned tract.
2183 However, an
order providing for unit operations or pooling of resources does not result in a transfer of all or
any part of the title of any person to the oil and gas rights in any tract of the unit area.2184
2181 Id. § 82-11-20 (2010).
Furthermore, the formation of such a unit shall not create a relationship between the parties
thereto which would be deemed to be a joint endeavor, adventure, undertaking, association, or
mining or other partnership.2185
[c] Applications and Hearings.
The Board holds approximately six pre-scheduled hearings a year to hear drilling
applications from interested persons.2186 In order to be heard at such a hearing, an interested
individual must submit his or her application by noon on the date of the hearing.2187 However,
the applicant must notify all known persons owning an interest in the oil and gas within the
proposed unit area at least 60 days prior to application of the applicant’s intent to apply for the
order.2188 Applications are available to be downloaded from the Board’s website.2189 According
to the rules promulgated by the Board, a notice of intention and application for permit to drill
must include a survey plat certified by a registered surveyor that shows the location of the
proposed well with reference to the nearest lines of an established public survey.2190 The permit
should be accompanied with payment of the applicable fee which is calculated pursuant to the
proposed well’s depth.2191
For the Board to hold a hearing to consider the need for the operation of one or more
pools or parts of the pools in a field as a unit, the persons owning leasehold interests underlying
60 percent of the surface within the unit must apply for a hearing. The applicant, at least 60 days
prior to application, shall, by registered or certified mail, notify all known persons owning an
2185 Id. § 82-11-216. 2186 See Montana Board of Oil and Gas, http://bogc.dnrc.mt.gov/ (last updated Jan. 1, 2011). 2187 Id. 2188 Mont. Code Ann. § 82-11-204(2) (2010). Upon written request of an operator of a lease which is in whole or in part within the confines of the proposed area, the applicant shall furnish the operator with copies of any exhibits to be submitted to the Board at the time of the hearing. 2189 See Montana Board of Oil and Gas, http://bogc.dnrc.mt.gov/ (last updated Jan. 1, 2011). 2190 Mont. Admin. R. § 36.22.602 9 (2010). 2191 Id. § 36.22.603. “(1)(a) for each well whose estimated depth is 3,500 feet or less, $25.00; (b) from 3,501 feet to 7,000 feet, $75.00; (c) 7,001 feet and deeper, $150.00. (2) Permits for deepening wells shall require the payment of fees for the estimated new total depth; where fees have been paid for the previous depth, credit shall be given therefor.”
409
interest in the oil and gas within the proposed unit area of the applicant's intention to make the
application. These known persons are those on record in the county or counties where the
proposed unit area is situated. The notice will be sent to these persons' last known addresses.
At the same time as notification, producers must be furnished with a plan of unit
operations. Upon written request of an operator for a lease that is in whole or in part within the
confines of the proposed delineated area, the applicant shall furnish the operator with copies of
any exhibits to be submitted to the Board at the time of hearing.2192
[d] Orders.
[i] Shaping Unit Orders.
The Board has the authority to regulate the size and shape of the pool of resources to be
developed on both a statewide scale and on a smaller scale. The Board may first establish well
spacing units by a statewide spacing order.2193 This type of order is done on the Board’s own
motion and without the necessity of notice or a hearing.2194 Or, the Board may make an order
on a smaller scale by specific order upon application of an interested party. Such a specific
order, which is issued after notice and a hearing before the Board, covers a specific area
overlying a pool or reservoir of oil or gas.2195
2192 Mont. Code Ann. § 82-11-204 (2010).
Such an order can essentially alter the obligations
of performance under a previously-executed lease: “[o]perations conducted pursuant to an order
of the [B]oard providing for unit operations shall constitute a fulfillment of all the express or
implied obligations of each lease or contract covering lands in the unit area to the extent that the
2193 Mont. Admin. R. § 36-3-18(10)-S18040 (2010). 2194 The size—in terms of acreage—and number of wells can vary depending on the Board’s current order in place. For example, in the U.V. Industries case, the Court discussed the order of the Board in 1972 which dictated that one well could be drilled and operated on each quarter section (160 acres) and the subsequent order of the Board which provided that one well could be drilled and operated on each half section (320 acres). See U.V. Indus., Inc., 184 Mont. at 212, 602 P.2d at 578. 2195 See id. at 212, 602 P.2d at 578.
410
obligations cannot be performed because of the order of the [B]oard.”2196 Furthermore, orders
of the Board of Oil and Gas Conservation are incorporated into oil and gas leases as a matter of
law.2197
The order must be upon terms and conditions that are just and reasonable, and it must
prescribe a plan for unit operations. That plan must include the following:
(1) a description of the pool or pools or parts of a pool or pools to be operated, termed the unit area, but only so much of a pool as has reasonably been defined and determined by drilling operations to be productive of oil or gas may be included within the unit area;2198
(2) a statement of the nature and purpose of the plan and operations contemplated, together with a copy of the proposed unit agreement and unit operating agreement;
(3) a plan for allocating to each tract in the unit area its fair share of the oil and gas produced from the unit area and not required or consumed in the conduct of the operation of the unit area or unavoidably lost; (4) a provision for the credits and charges to be made in the adjustment among the owners in the unit area for their respective investments in wells, tanks, pumps, machinery, materials, and equipment contributed to the unit operations; (5) a provision providing how the costs of unit operations, including overhead and capital investments, must be determined and charged to the separately owned tracts; (6) a provision for the supervision and conduct of the unit operations, in respect to which each owner has a vote with a value corresponding to the percentage of the costs of unit operations chargeable against the interest of the owner; (7) a provision by which the unit operator, after having operated for a minimum period of 2 years, may be challenged by any other owner in the unit; (8) the time when the unit operations must commence and the manner in which and the circumstances under which the unit operations must terminate; and
2196 Mont. Code Ann. § 82-11-211(2) (2010). 2197 See U.V. Indus., Inc. v. Danielson, 184 Mont. 203, 212, 602 P.2d 571, 578 (1979). 2198 If the unit is formed solely for production of gas, a spacing unit on which is located a well producing or capable of producing gas on March 1, 1971, may not be included in the unit area without the written consent of the majority in interest of the working interest owners of the spacing unit and well. Mont. Code Ann. § 82-11-206 (2010).
411
(9) additional provisions that are found to be appropriate for carrying on unit operations and for the protection and adjustment of correlative rights.2199
An order establishing temporary or permanent spacing units may permit only one well to
be drilled and produced from the common source of supply on any spacing unit. The well must
be drilled at a location authorized by the order, with an exception as may be reasonably
necessary. The well location exception may be included in the request to establish permanent or
temporary spacing units if, upon application, notice, and hearing, the Board finds that the spacing
unit is located on the edge of a pool or field and adjacent to a producing unit or, for some other
reason, the requirement to drill the well at the authorized location on the spacing unit would be
inequitable or unreasonable. The Board shall take action to offset any advantage that the person
securing the exception may have over other producers by reason of drilling the well as an
exception. The order must include provisions to prevent production from the spacing unit from
being more than its just and equitable share of the producible oil and gas in the pool.
2200
Additionally, an order establishing temporary or permanent spacing units for a pool must
cover all lands determined or believed to be underlaid by the pool and may be modified after
notice and hearing by the Board to include additional areas subsequently determined to be
underlaid by the pool.
2201
However, the Board may provide by an order for the unit operation of a pool or pools or
parts of a pool or pools that embrace a previously established unit. The order, in providing for
the allocation of unit production, must first treat the unit area previously established as a single
tract, and the portion of the unit production allocated to that tract must then be allocated among
the tracts included in the previously established unit area in the same proportions as those
oil or gas less royalties or, as to gas pools only, the value of the economies to be affected,
exceeds the estimated additional cost incident to conducting such operations; and (3) the full
areal extent of the pool or pools or part thereof has been reasonably defined and determined by
drilling operations.2206 It must provide for the drilling and operating of a well on the permanent
spacing unit and for the payment of the cost of the well, if a well has not been drilled prior to the
hearing on the application.2207
The pooling order must be upon terms and conditions that are just and reasonable and
that afford to the owner of each tract or interest in the permanent spacing unit the opportunity to
recover or receive without unnecessary expense a just and equitable share of the oil or gas
produced and saved from the spacing unit. Operations incident to the drilling of a well upon any
portion of a permanent spacing unit covered by a pooling order are considered, for all purposes,
the conduct of the operations upon each separately owned tract in the spacing unit by the several
owners of the tracts. That portion of the production allocated to each tract included in a
permanent spacing unit covered by a pooling order must, when produced, be considered for all
purposes to have been produced from the tract by a well drilled on the tract.
If an owner refuses to pay that owner's share of the costs of development or other
operations, the order must provide for payment of the owner's share of the cost out of and only
out of production from the well allocable to the owner's interest in the permanent spacing unit,
excluding royalty or other interest.
If a well has not been drilled prior to the hearing on the application, the pooling order
must provide for the drilling and operating of a well on the permanent spacing unit and for the
payment of the cost of the well, which may include a reasonable charge for supervision,
2206 Id. § 82-11-205. 2207 Id. § 82-11-202(2)(a).
414
handling, and storage. If a dispute arises as to the cost, the Board by subsequent order, after
notice and hearing, shall determine the proper cost. The order may provide in substance that the
owners who agree to share in the cost of drilling and operating the well are, unless they agree
otherwise, entitled to receive, subject to royalty or similar obligations, all of the production of the
well until they have recovered all of the costs out of the production. After all costs of drilling and
operation are recovered, all of the owners in the permanent spacing unit are entitled to receive
their respective shares of the production of the well as their interest may appear after deducting
their respective shares of current operating costs.2208
If a well has been drilled prior to the hearing on the application and an owner, after
written demand, has failed or refused to pay the owner's share of the costs of development or
other operations or if a well has not been drilled prior to the hearing on the application and an
owner refuses to agree to pay the owner's share of drilling and completion costs, the order must
also include the following as costs:
(i) 100% of the refusing owner's share of the cost of newly acquired surface equipment beyond the wellhead connections, including but not limited to stock tanks, separators, treaters, pumping equipment, and piping, plus 100% of the refusing owner's share of the cost of operation of the well commencing with first production and continuing until the agreeing owners have recovered the costs; and (ii) 200% of the refusing owner's share of the costs and expenses of staking, well site preparation, obtaining rights-of-way, rigging up, drilling, reworking, deepening or plugging back, testing, and completing the well, after deducting any cash contributions received from the refusing owners by the agreeing owners, and 200% of that portion of the cost of equipment in the well, including the wellhead connections. 2209
[iii] Amendments.
2208 Id. § 82-11-202. 2209 Id.
415
An order providing for unit operations may be amended by an order made by the Board
in the same manner and subject to the same conditions and notice as an original order providing
for unit operations; however, if such an amendment affects only the rights and interests of the
owners, the approval of the amendment by the persons owning interests which are free of costs,
such as royalties, overriding royalties, and production payments, is not required, and an order of
amendment may not change the percentage for the allocation of oil and gas as established for any
tract by the original order, except with the consent of all persons owning oil and gas rights in the
tract, or change the percentage for the allocation of cost as established for any tract by the
original order, except with the consent of all owners in the tract.2210
[5] – Matters Covered.
[a] Royalty Interest and Election Rights.
An owner who refuses to lease his or her oil and gas interest in a spacing unit or contract
for the development oil and gas is considered to own a landowner royalty equal to one-eighth of
the owner’s proportionate share of production from the well until such time as the consenting
owners recover costs.2211 After costs have been recovered by the agreeing owners, the refusing
owner owns the refusing owner's proportionate share of the well, surface facilities, and
production and is liable for further costs as if the refusing owner had originally agreed to drill the
well. 2212
[b] Coalbed Methane.
2210 Id. § 82-11-208. 2211 Id. § 82-11-202. Any interest in production from the spacing unit to which the interest of the refusing owner may be subject must be deducted from the royalty considered to be owned by the refusing owner. 2212 Id. § 82-11-202(2)(d). The operator of a well under a pooling order which is subject to a refusing owner shall, upon demand, furnish the refusing owner with a monthly statement of all costs incurred, together with the quantity of oil or gas produced and the amount of proceeds realized from the sale of production during the preceding month.
416
Coalbed methane production wells that involve the production of ground water must
comply with Code section 82-11-175. That section specifies that if ground water is produced in
association with a coalbed methane well, it must be managed in any of the following ways:
(a) used as irrigation or stock water or for other beneficial uses in compliance with Title 85, chapter 2, part 3; (b) reinjected to an acceptable subsurface strata or aquifer pursuant to applicable law; (c) discharged to the surface or surface waters subject to the permit requirements of Title 75, chapter 5; or (d) managed through other methods allowed by law.
Prior to the development of a coalbed methane well that involves the production of
ground water from an aquifer that is a source of supply for appropriation rights or permits to
appropriate under Title 85, chapter 2, the developer of the coalbed methane well shall notify and
offer a reasonable mitigation agreement to each appropriator of water who holds an
appropriation right or a permit to appropriate under Title 85, chapter 2, that is for ground water
and for which the point of diversion is within (i) one mile of the coalbed methane well or (ii)
one-half mile of a well that is adversely affected by the coalbed methane well. The mitigation
agreement must address the reduction or loss of water resources and must provide for prompt
supplementation or replacement of water from any natural spring or water well adversely
affected by the coalbed methane well. The mitigation agreement is not required to address a loss
of water well productivity that does not result from a reduction in the amount of available water
because of production of ground water from the coalbed methane well.2213
§ 27.02 Types of Montana Pooling Statutes.
[1] – Mineral Distinctions. Prior to 1993, there was no specific reference in the Montana statutes to coal seam
methane gas; however, “gas” was defined at Montana Code Annotated section 82-11-101(9)
2213 Id. § 82-11-175.
417
(1991) as “all natural gases and all other fluid hydrocarbons as produced at the wellhead and not
defined as oil . . . .”2214
(1) “Coal” means a combustible carbonaceaous rock formed from the compaction and induration of variously altered plant remains. Coal does not include:
In 1993, the Montana Legislature deleted the definition of gas from the
Code and added a new section that defines coal, gas, and oil. Section 82-1-111 provides as
follows:
(a) methane gas or any other natural gas that may be found in any coal formation, (b) oil shale, or (c) gilsonite.
(2) “Gas” means all natural gases and all other fluid hydrocarbons, including methane gas or any other natural gas found in any coal formation, as produced at the wellhead and not defined as oil in subsection (3).2215
(3) “Oil” means crude petroleum oil and other hydrocarbons, regardless of gravity, that are produced at the wellhead in liquid form by ordinary production methods and that are not the result of condensation of gas before or after it leaves the reservoir.
2216
In addition, the legislature inserted a new section into the Montana Code to insure that all
instruments regarding coal, oil, and gas are interpreted according to this section of the Code.
Section 1-4-110 of the Code, provides that “[w]hen used in any instrument, unless the clear and
express terms of the instrument provide otherwise, the terms “coal,” “gas,” and “oil” must be
construed as defined in 82-1-111.”2217
Within Code section 82-11-101, “‘[f]ield’ means the general area underlaid by one or
more pools.” “‘Pool’ means an underground reservoir containing a common accumulation of oil
or gas or both; each zone of a structure which is completely separated from any other zone in the
same structure is a pool . . . .”
2218
2214 Mont. Code Ann. § 82-11-101(9) (1991). 2215 Thus, coalbed methane is included in the definition of “gas.” 2216 Mont. Code Ann. § 82-1-111 (1993). 2217 Id. § 1-4-110 (1993). 2218 Mont. Code Ann. § 82-11-101 (2010).
418
[2] – Split by Depth. The Board distinguishes between well depths by requiring differing permit fees based on
the depth of the well to be drilled. These different depths are (a) 3,500 feet or less; (b) from
3,501 feet to 7,000 feet; and (c) 7,001 feet and deeper. 2219
[3] – Spacing Rules.
The Board does not otherwise
distinguish between well depths except that the depths of a well must be designed to promote the
orderly development of unproven areas.
The size and shape of temporary spacing units must be established to promote the orderly
development of unproven areas and must be uniform throughout the surface area including
depths covered by the unit.2220
Conversely, a permanent spacing unit need not be uniform in size or shape, but must
result in the efficient and economic development of the pool as a whole.
2221 The Board may
divide a pool into zones and establish spacing units for each zone if necessary to prevent waste
and promote efficiency or to facilitate production through the use of innovative drilling and
completion methods.2222
The spacing units within the zone may differ in size and shape from spacing units in any
other zone but may not be smaller than the maximum area that can be efficiently and
economically drained by one well.
In establishing permanent spacing units, the acreage to be embraced
within a unit and the shape of the unit must be determined by the Board based upon evidence
“secretary” of the Commission and maintains minutes and records, for which he or she must hire
necessary assistants to support the Director and members.2236
[3] – Scope of Authority
The Commission’s statutory jurisdiction stems from the Act’s declared public interests.
In particular, these goals are as follows:
to foster, to encourage and to promote the development, production and utilization of natural resources of oil and gas in the state in such a manner as will prevent waste; to authorize and to provide for the operation and development of oil and gas properties in such a manner that the greatest ultimate recovery of oil and gas be had; and that the correlative rights of all owners be fully protected; and to encourage and to authorize . . . recovery operations in order that the greatest possible economic recovery of oil and gas be obtained within the state to the end that the landowners, the royalty owners, the producers and the general public realize and enjoy the greatest possible good from these vital irreplaceable natural resources.2237
The Act further states that its “intent and purpose [is] . . . to permit each and every oil and gas
pool in Nebraska to be produced up to its maximum efficient rate of production, subject to the
prohibition of waste, . . . [and] the enforcement and protection of [owners’] correlative rights, . . .
so that each common owner may obtain his just and equitable share of . . . production” from a
pool.2238
[a] Matters Governed.
As expressed above, the Commission’s authority stems from its primary aim of waste
prevention.2239
(a) Waste, as applied to oil, shall include underground waste, inefficient, excessive, or improper use, or dissipation of reservoir energy, including gas energy and water drive, surface waste, open pit storage, and waste incident to the production of oil in excess of
“Waste” is prohibited under the Act and defined to include the following:
2236 Id. 2237 Id. § 57-901. 2238 Id. 2239 Id.
423
the producer's aboveground storage facilities and lease and contractual requirements, but excluding storage, other than open pit storage, reasonably necessary for building up or maintaining crude stocks and products thereof for consumption, use, and sale; (b) waste, as applied to gas shall include (i) the escape, blowing, or releasing, directly or indirectly, into the open air of gas from wells productive of gas only, or gas from wells producing oil or both oil and gas and (ii) the production of gas in quantities or in such manner as will unreasonably reduce reservoir pressure or unreasonably diminish the quantity of oil or gas that might ultimately be produced, but excluding gas that is reasonably necessary in the drilling, completing, testing, and producing of wells and gas unavoidably produced with oil if it is not economically feasible for the producer to save or use such gas; and (c) waste shall also mean the abuse of the correlative rights of any owner in a pool due to nonuniform, disproportionate, unratable, or excessive withdrawals of oil or gas therefrom causing reasonably avoidable drainage between tracts of land or resulting in one or more owners in such pool producing more than his or her just and equitable share of the oil or gas from such pool.2240
The Commission has an affirmative duty to investigate “to determine whether waste exists or is
imminent or whether other facts exist which justify action” within its authority.
2241 Pursuant to
that duty, the Commission maintains jurisdiction over all persons subject to service and property,
public and private, within the state.2242
Among its powers, the Commission may require the “[i]dentification of [well]
ownership . . .; the making and filing of directional surveys[] and reports on well location . . .;
[all matters of well operation] in such manner as to prevent the escape of oil or gas, . . . the
intrusion of water into oil or gas strata, the pollution of fresh water supplies; . . . the furnishing of
a reasonable bond . . .”; and various other aspects of oil and gas development.
2243
2240 Id. § 57-903(1) (emphasis added).
Moreover, the
Commission has direct authority, for the sake of waste prevention, to regulate the “drilling,
producing and plugging of wells . . . and all other operations for the production of oil or gas; . . .
[the] chemical treatment of wells; . . . the spacing of wells; . . . [and all] operations to increase
ultimate recovery” of oil and gas.2244 The Commission may only limit production of oil and gas
in a pool or field if necessary to prevent waste therein.2245
[b] Commission Procedure.
The Commission may “promulgate and enforce rules, regulations, and orders to
effectuate the purposes and intent” of the Act. 2246 The Commission may act upon its own
motion, or upon a petition of “any interested person.”2247 A petition for public hearing must
include a $250.00 filing fee.2248 Unless deemed an emergency, the Commission must hold a
public hearing prior to any order or rule entered. 2249
Any notice required [hereunder] . . . shall be given at the election of the Commission either by personal service, registered or certified mail, or one publication in a newspaper of general circulation in the county where the land affected, or some part thereof, is situated. The notice shall be issued in the name of the state, shall be signed by a member of the Commission or its secretary, and shall specify the style and number of the proceedings, the time and place of the hearing, and the purpose of the proceeding. Should the commission notice be by personal service, such service may be made by any officer authorized to serve summons, or by any agent of the Commission, in the same manner and extent as is provided by law for the service of summons in civil actions in the district courts of this state. Proof of the service by such agent shall be by his or her affidavit and proof of service by an officer shall be in the form required by law with respect to service of process in civil actions. In all cases where a complaint is made by the Commission or the Director of the Nebraska Oil and Gas Conservation Commission that any part of any provision of sections 57-901 to 57-921, or any rule, regulation, or order of the commission is being violated, notice of
All hearings must be preceded by at least
15 days notice in accordance with the following:
2244 Id. § 57-905(4). 2245 Id. § 57-905(5) (“Commission shall not have authority to limit . . . production . . . except to prevent waste.”) (emphasis added). 2246 Id. § 57-905(7). 2247 Id. § 57-911(6). The Act does not define “interested person.” 2248 Id. § 57-911(7). 2249 Id. § 57-911(2)–(3).
425
the hearing to be held on such complaint shall be served on the interested parties in the same manner as is provided in the code of civil procedure for the service of process in civil actions in the district courts of this state. In addition to notices required by this section, the Commission may provide for further notice of hearing in such proceedings as it may deem necessary in order to notify all interested persons of the pendency of such proceedings and the time and place of hearing and to afford such persons an opportunity to appear and be heard.2250
The Commission will enter a written order within 30 days after a hearing.2251 Any rule or order
issued is maintained by the Commission as public record, copies of which are deemed original
and receivable into evidence in all Nebraska courts.2252
Any person holding an interest in property affected by a Commission rule or order may
appeal under the process established in the Nebraska Administrative Procedure Act.
2253
[4] – Process for Pooling & Matters Covered.
The Commission has a statutory duty to “limit the production of oil and gas from each
pool to that amount which can be produced without waste in such pool.”2254 The Act defines
“pool” to mean “an underground reservoir containing a common accumulation” of oil and/or gas
and includes that “each zone of the structure which is completely separated from any other zone
in the same structure is a pool.”2255 If waste prevention so requires, the Commission “shall
allocate or distribute the allowable production among the several wells or producing properties in
the pool on a reasonable basis . . . [to ensure] that each property will have the opportunity to
produce or . . . receive its just and equitable share.”2256
plan.2263 The Commission is further authorized to amend spacing orders whenever required to
prevent waste, avoid the drilling of unneeded wells, or protect correlative rights.2264
[b] Authority to Integrate Production.
One or more persons owning interest in production within the same spacing unit may
voluntarily agree to integrate such interests “for the development and operation of the spacing
unit.” 2265 If no such agreement exists, the Commission may require owners to do so through
compulsory pooling order.2266 Upon the application of any interested person, and after notice
and hearing, the Commission may “order pooling [of] all interests in the spacing unit.”2267
(1) A description of the land and pool, pools, or parts thereof to be so operated . . .; (2) The names of all persons owning or having an interest in the oil and gas in the proposed unit area or the production therefrom, including mortgagees and the owners of other liens or encumbrances, as disclosed by the public records . . . and their addresses, if known. If . . . unknown, the application shall so indicate; (3) A statement of the type of the operations contemplated in order to effectuate the purposes of [the Act]; (4) A proposed plan of unitization applicable to the proposed unit area which the petitioner considers fair, reasonable, and equitable; and (5) A proposed operating plan covering the manner in which the unit will be supervised and managed and costs allocated and paid, unless . . . [already expressed in an applicable operating agreement].
An
application must contain the following information:
2268
The Commission will consider an application and other information provided at the hearing, and
will accept proposed unit agreements upon satisfaction of certain factors. The Act specifies
conditions which must be present for the Commission to issue a compulsory pooling order:
(1) The material averments of the application are true; (2) Such unit operation is feasible, will prevent waste, and can reasonably be expected to increase substantially the ultimate recovery of oil or gas, or both; (3) The value of the estimated additional recovery of oil or gas will exceed the estimated additional costs incident to conducting unit operations; and (4) The oil and gas allocated to each separately owned tract within the unit area under the proposed plan of unitization represents, so far as can be practicably determined, each such tract's just and equitable share of the oil and gas, or both, in the unit area.2269
In addition, the Commission must receive written notice to establish that a proposal has been
agreed upon by “those persons who own at least seventy-five percent of the unit production or
proceeds thereof.” 2270 If the application includes a proposed operating plan, that plan must be
similarly approved “by those persons who will be required to pay at least sixty-five percent of
the costs of unit operation.”2271
If there is any person with oil and gas interests in an area covered by the proposed plan
who has not agreed thereto at the time of hearing, the Commission may nonetheless issue the
order and thereby bind all such persons to its terms.
2272
(a) Makes a fair and equitable adjustment among the owners within the unit area for their respective investments in [all] equipment . . . contributed to the unit operation;
However, the Commission will only do
so if the proposed plan does the following:
(b) Provides for a fair and equitable determination of the cost of unit operations, including capital investment, and establishes a fair and equitable method for allocating such costs to the separately owned tracts and for payment of such costs by the owners of such tracts, either directly or out of such owner's respective shares of unit production; (c) Establishes, if necessary, a fair and equitable method for carrying or otherwise financing any owner who elects to be carried, or otherwise financed, allowing a reasonable interest
2269 Id. § 57-910.03. 2270 Id. § 57-910.03(5)(d). 2271 Id. 2272 Id. § 57-909; see also id. § 57-910.
429
charge for such service payable out of such owner's share of the unit production; and, (d) Provides that each owner shall have a vote in the supervision and conduct of unit operations corresponding to the percentage of the costs of unit operations chargeable against the interest of such owner.2273
If the percentage requirements are not met, the Commission may hold “supplemental hearings
. . . as may be required to determine if there has been such consent so that a supplemental order
authorizing the commencement of unit operations can be entered.” 2274 Notice of any
supplemental hearing will be delivered by mail at least ten days prior to such hearing. 2275 If the
consent needed has still not been obtained within six months of Commission approval, the order
is “ineffective and shall be revoked by the Commission unless, for good cause shown, the
Commission extends that time.” 2276
A certified copy of any active pooling order may be filed with the appropriate clerk or
register for recording among the real property records in the county or counties where the
affected property lies. Like other applicable documents, satisfactory recordation of a pooling
order constitutes constructive notice thereof.
2277
[c] Contents of Pooling Order.
Each pooling order must account “for the drilling and operation of the authorized well on
the spacing unit, and for the payment of the reasonable actual cost thereof, including a
reasonable charge for supervision.2278
2273 Id. § 57-910.03.
The Act provides that a pooling order must “determine
the interest of each owner in the unit” and contain specific measures to dictate allocation of
The Commission has authority to regulate the spacing of wells through rule or order.2295
[4] – Minimum Operator Control.
Outside of the general guidelines discussed in Section 27.01[4][a], the Act does not otherwise
specify any default spacing requirements.
Prior to an order for unitization becoming effective, the Commission must receive written
notice to establish that a proposal has been agreed upon by “those persons who own at least
seventy-five percent of the unit production or proceeds thereof.” 2296 If the application includes a
proposed operating plan, that plan must be similarly approved “by those persons who will be
required to pay at least sixty-five percent of the costs of unit operation.”2297
[5] – Directional Drilling.
The Act does not reference or distinguish between vertical and horizontal drilling
practices.
[6] – Election.
The Act acknowledges the right of election in forced pooling situations, which generally
allows those subject to a pooling order to agree or refuse to contribute up-front operating costs
and remain entitled to shared production. In supplying the required contents of a Commission
order to establish pooling, the Act states, in relevant part, the following:
[A]s to each owner who agrees with the person or persons drilling and operating the well for the payment by the owner of his share of the costs, such owner, unless he has agreed otherwise, shall be entitled to receive, subject to royalty or similar obligations, the share of the production of the well applicable to the tract of the consenting owner.2298
A non-consenting owner will likewise remain entitled to recover production proportionate to his
share; however, he will only receive such benefit once the operator and contributing owners are
adequately “reimbursed” for up-front costs:
As to each owner who refuses to agree upon the terms for drilling and operating the well, the order shall provide for reimbursement for his share of the costs out of, and only out of, production from the unit representing his interest, excluding royalty or other interest not obligated to pay any part of the cost thereof.2299
Nebraska incentivizes voluntary pooling arrangements by offering unattractive terms to owners
who refuse to contribute operating costs. The Act provides that “reimbursement” is not limited
to the actual expense put forth for operation, but includes a “risk penalty” owed to the operator
and carrying owners. As such, upon production the contributing owners or operators may recoup
over and above the monetary value of their initial investment from non-contributing owners. For
example,
[A]s to each owner who does not agree, he shall be entitled to receive from the person or persons drilling and operating said well on the unit his share of the production applicable to his interest, after the person or persons drilling and operating said well have recovered two hundred percent of that portion of the costs and expenses of [any aspect of well construction or operation] and other intangible expenses approved by the Commission chargeable to each owner who does not agree, and one hundred percent of all [drilling and operating] equipment . . . plus one hundred percent of the nonconsenting owner's share of the cost of operation and a reasonable rate of interest on the unpaid balance.2300
Any dispute over the existence or amount of drilling costs may be resolved by the
Commission.
2301
2299 Id.
For the purpose of formulating cost allocation under this method, the Act
presumes that an owner of unleased oil and gas rights within a pool “shall be regarded as a lessee
2300 Id. (emphasis added). 2301 Id.
435
to the extent of a seven-eighths interest in and to such rights[,] and [as] a lessor to the extent of
the remaining one-eighth interest therein.”2302
2302 Id.
436
§ 29.01 Analysis of Nevada Regulatory Framework.
[1] – Name of Governing Body.
In Nevada, pooling is regulated by the Division of Minerals (“the Division”) of the
Commission on Mineral Resources, pursuant to the state’s oil and gas conservation statute (“the
Act”).2303
[2] – Membership on the Board.
The Chief Administrative Officer of the Division is the Administrator, who must be
appointed by the Commission. The Administrator of the Division must be a graduate of an
accredited college or university and have substantial administrative or industry experience; be in
the unclassified service of the state; must devote his or her entire time and attention to the
Administrator’s duties as a public officer; and may not pursue any other business or occupation
or hold any other office for profit.2304
[3] – Scope of Authority.
The Division has jurisdiction over all persons and property, public and private, necessary
to effectuate the purpose and intent of the Act.2305 Pursuant to the Act’s prevention of waste, the
Division may investigate or take other action as required to determine whether waste exists or is
imminent.2306
(1) The inefficient, excessive or improper use of or unnecessary dissipation of reservoir energy;
“Waste” is defined to include the following:
(2) The locating, spacing, drilling, equipping, operating, or producing of any oil or gas well in a manner which results or tends to result in reducing the quantity of oil or gas to be recovered from any pool in this state under operations conducted in accordance with good engineering practices in an oil field; (3) The inefficient aboveground storage of oil;
(4) The locating, spacing, drilling, equipping, operating or producing of any oil or gas well in a manner causing or tending to cause unnecessary or excessive surface loss or destruction of oil or gas; (5) Producing oil or gas in such manner as to cause unnecessary water channeling or coning; (6) The operation of an oil well with an inefficient ratio of gas to oil; (7) The drowning with water of any pool or part thereof capable of producing oil or gas, except insofar as and to the extent authorized by the Commission under this chapter; (8) Underground waste; (9) The creation of unnecessary fire hazards; (10) The escape into the open air, from a well producing oil or gas, of gas in excess of the amount which is reasonably necessary in the efficient production of the well; and (11) The use of gas for the manufacture of carbon black, except as provided for in this chapter.2307
The Division is authorized to promulgate rules and regulations and issue orders to
conserve Nevada’s oil and gas resources.2308
(1) Identification or ownership of wells, producing leases, tanks, plants and drilling structures;
Among its powers, the Division may require the
following:
(2) The making and filing of reports, well logs and directional surveys. Logs of exploratory or “wildcat” wells marked “confidential” must be kept confidential for 6 months after the filing thereof, unless the owner gives written permission to release those logs at an earlier date; (3) The drilling, casing and plugging of wells in such a manner as to prevent the escape of oil or gas out of one stratum into another, the intrusion of water into an oil or gas stratum, the pollution of fresh water supplies by oil, gas or salt water, and to prevent blowouts, cavings, seepages and fires; (4) The furnishing of a reasonable bond with good and sufficient surety conditioned for the performance of the duty to plug each dry or abandoned well or the repair of wells causing waste; (5) The operation of wells with efficient gas-oil and water-oil ratios and to fix these ratios; (6) The gauging or other measuring of oil and gas to determine the quality and quantity thereof;
2307 Id. § 522.039. 2308 Id. § 522.040(3).
438
(7) That every person who produces oil or gas in Nevada keep and maintain for a period of 5 years complete and accurate record of the quantities thereof, which must be available for examination by the Division or its agents at all reasonable times.2309
The Division regulates the drilling, producing and plugging of wells; the shooting and
chemical treatment of wells; the spacing of wells; and the contamination or waste of
underground water.
2310 The Division issues permits to drill in search of oil or gas and collects a
fee for each permit application.2311 The drilling of a well without a permit is prohibited.2312
[4] – Process for Pooling & Matters Covered.
[a] Drilling Units.
If necessary to prevent waste, protect correlative rights, or avoid the drilling of an
excessive or insufficient number of wells, the Division will hold a hearing to establish one or
more drilling units for each pool within the state.2313 Each well permitted on a drilling unit is
subject to the regulations and spacing patterns that the Division prescribes for the relevant
pool.2314 The Department may grant exceptions to such rules after notice and a hearing, if a
party shows that “the unit is partly outside the pool, or for some other reason a well so located on
the unit would be non-productive, or topographical conditions are such as to make drilling at
such a location unduly burdensome.”2315
2309 Id. § 522.040(4)(a).
If an exception is granted, the Division must offset any
advantage accruing to the excepted well, and minimize drainage from developed units to the tract
Upon a valid petition, the Division will provide notice and hold a hearing to determine
whether a unitization order should be granted.2324
(1) The unitized management, operation and further development of a pool or portion thereof is reasonably necessary in order effectively to carry on pressure control, pressure-maintenance or repressuring operations, cycling operations, waterflooding operations, or any combination thereof, or any other form of joint effort calculated to substantially increase the ultimate recovery of oil and gas from the pool;
The Act specifies the grounds required to
issuing such an order, and the Division must make the following findings:
(2) One or more of the unitized methods of operation as applied to the pool or portion thereof are feasible, will prevent waste and will, with reasonable probability, result in the increased recovery of substantially more oil and gas from the pool than would otherwise be recovered; (3) The estimated additional cost, if any, of conducting those operations will not exceed the value of the additional oil and gas so recovered; and (4) The unitization and adoption of one or more of the unitized methods of operation is for the common good and will result in the general advantage of the owners of the oil and gas rights within the pool or the portion thereof directly affected.2325
If such conditions exist, the Division will order unitization and establish any terms and
conditions thereon “which are necessary or proper to protect, safeguard and adjust the respective
rights and obligations of the several persons affected, including royalty owner, owners of
overriding royalties, oil and gas payments, carried interests, mortgages, lien claimants and
others, as well as the lessees.”
2326
A unitization order must define the pool or portion thereof to be included in the unit area
and outline the accepted plan for unit operations.
2327
2324 Id. § 522.0828.
The scope of the unit area will only include
those lands which have been determined to be productive by actual drilling operations and will
2325 Id. 2326 Id. 2327 Id. § 522.083(1).
441
cover portions of a single pool only where the Division finds that such limitation “is reasonably
required for the successful and efficient conduct of the unitized operation, and that unitized
operation will have no material adverse effect upon the remainder of the pool.”2328
Each unitization plan will be tailored to the specific needs of the particular unit area
covered thereby.
2329
(1) The efficient unitized management or control of the further development and operation of the unit area for the recovery of oil and gas from the pool affected. Under such a plan the actual operations within the unit area may be carried on in whole or in part by the unit itself, or by one or more of the lessees within the unit area as the unit operator subject to the supervision and direction of the unit, dependent upon what is most beneficial or expedient. The designation of the unit operator must be by vote of the lessees in the unit in a manner provided in the plan of unitization and not by the Division;
In addition to such other terms and conditions that the Division finds
necessary or proper, each plan of unitization must contain fair, reasonable, and equitable
provisions for the following:
(3) The division of interest or formula for the apportionment and allocation of the unit production among and to the several separately owned tracts within the unit area as will reasonably permit persons otherwise entitled to share in or benefit by the production from such separately owned tracts to produce and receive, in lieu thereof, their fair, equitable and reasonable share of the unit production or other benefits thereof. A separately owned tract’s fair, equitable and reasonable share of the unit production must be measured by the value of each tract for oil and gas purposes and its contributing value to the unit in relation to like values of other tracts in the unit, taking into account acreage, the quantity of oil and gas recoverable, location on the structure, its probable productivity of oil and gas in the absence of unit operations, the burden of operation to which the tract will or is likely to be subjected, or such other factors as may be reasonably susceptible of determination; (3) The manner in which the unit and the further development and operation of the unit area will be financed and the basis, terms and conditions on which the cost and expense thereof will be apportioned among and assessed against the tracts and interests
2328 Id. 2329 Id. § 522.083(2).
442
made chargeable therewith, including a detailed accounting procedure governing all charges and credits incident to the operations. Upon and subject to such terms and conditions as to time and rate of interest as is fair to all concerned, reasonable provisions must be made in the plan of unitization for carrying or otherwise financing lessees who are unable promptly to meet their financial obligations in connection with the unit; (4) The procedure and basis upon which wells, equipment and other properties of the several lessees within the unit area are to be taken over and used for unit operations, including the method of arriving at the compensation therefor, or of otherwise proportionately equalizing or adjusting the investment of the several lessees in the project as of the effective date of unit operation; (5) The creation of an operating committee to have general overall management and control of the unit and the conduct of its business and affairs and the operations carried on by it, together with the creation or designation of such other subcommittees, boards or officers to function under the authority of the operating committee as may be necessary, proper or convenient in the efficient management of the unit, defining the powers and duties of all those committees, boards and officers, and prescribing their tenure and time and method for their selection; (6) The time when the plan of unitization becomes effective; (7) The time when and the conditions under which and the method by which the unit may be dissolved and its affairs wound up.2330
The unit area of a unit may be enlarged to include adjoining portions of the same pool,
including the area of an existing unit. A new unit created for the unitized management,
operation, and further development of the enlarged unit area or the plan of unitization may be
amended, all in the same manner, upon the same conditions and subject to the same limitations
applicable to the creation of a unit in the first instance. However, where the amendment to the
plan affects only the rights and obligations as between lessees, the requirement that it be
approved by royalty owners therein does not apply.
2331
[c] Allocation of Production and Costs.
2330 Id. § 522.0838. 2331 Id. § 522.084.
443
Operations incident to the drilling of a well upon any portion of a pooled drilling unit
covered by an order shall be deemed to be the conduct of the operation upon each separately
owned tract in the unit by the several lessees thereof.2332 The portion of the production allocated
to the lessee of each tract therein, when produced, is considered as if it had been produced from
the tract by a well drilled thereon.2333
The cost of development and operation of a pooled unit chargeable by the operator to the
other interested lessees is limited to the actual and reasonable expenditures required for that
purpose, including a reasonable charge for supervision.
2334 In the event of a dispute over those
costs, the Division shall determine the proper amount.2335 Appeals may be taken from this
determination as from any other order of the Division.2336
If the persons owning the production rights in separate tracts embraced within a drilling
unit fail to agree upon pooling, and the Division is without authority to require pooling as
provided in the Act, the lessee of each tract may drill upon his acreage, but the allowable
production from each well will be proportionate to the allowable production for the entire
drilling unit as the area of such tract bears to the acreage of the whole unit.
However, the Act also provides a risk
penalty for lessees who refuse to share in the upfront costs and risks of drilling operations, which
is further discussed below.
2337
If one or more of the lessees drill and operate, or pay the expense of drilling and
operating, the well for the benefit of others, in addition to any other right conferred by the
pooling order, the lessee or lessees have a lien on the share of production from the unit accruing
Subject to such reasonable limitations as may be set out in the plan of unitization, the unit
has a first and prior lien upon the leasehold estate and all other oil and gas rights (exclusive of a
one-eighth landowners’ royalty interest) in each separately owned tract, the interest of the
owners thereof in the unit production and all equipment in the possession of the unit, to secure
the payment of the amount of the unit expense charged to the separately owned tract.2344
The interest of the lessee or other persons who by lease, contract or otherwise are
responsible for the cost and expense of developing and operating a separately owned tract for oil
and gas in the absence of unitization, is primarily responsible for any assessment for unit expense
made against the tract and resort may be had to overriding royalties, oil and gas payments,
royalty interests in excess of one-eighth of the production, or other interests not otherwise
chargeable with that cost, only if the owner of interest primarily responsible fails to pay the
assessment of the production to the credit thereof, or production is insufficient for that
purpose.
2345
If the owner of any royalty interest, overriding royalty, oil or gas payment, or any other
interest which under the plan of unitization is not primarily responsible therefor pays in whole or
in part the amount of an assessment for unit expense for the purpose of protecting that interest, or
the amount of the assessment in whole or in part is deducted from the unit production to the
credit of that interest, the owner thereof is to the extent of the payment or deduction subrogated
to all the rights of the unit with respect to the interest or interests primarily responsible for the
assessment.
2346
2344 Id. § 522.0858(1).
2345 Id. § 522.0858(2). 2346 Id. § 522.0858(3).
446
A one-eighth part of the unit production allocated to each separately owned tract must in
all events be regarded as royalty to be distributed to and among, or the proceeds thereof paid to,
the royalty owners free and clear of all unit expense and free of any lien therefor.2347
[d] Royalty Distribution
For purposes of determining the respective rights of the lessor and lessee and the owners
of a royalty interest, overriding royalty interest, and any other nonworking interest in the money
earned from any oil and gas lease or other agreement concerning the sale of the production from
an oil or gas well located in Nevada:
(a) The lessee is liable for all of the costs of production, which must be deducted from the working interest. (b) The lessor’s interest, the mineral owner’s royalty interest and the overriding royalty interest must not be decreased by the costs of production. (c) The following information must be reported with each remittance, unless otherwise reported each month, to the owner of an interest:
(1) The name or number used to identify the lease, property or well; (2) The month and year during which any sale occurred for which payment is being made; (3) The total number of barrels of oil or thousands of cubic feet of gas sold; (4) The price per barrel of oil or the price per thousand cubic feet of gas; (5) The total amount of state taxes on the net proceeds of minerals, taxes ad valorem and other taxes on the production from an oil or gas well, if the payment of those taxes reduces the amount paid to the owner of an interest; (6) An itemized list of any other deductions or adjustments that reduce the amount paid to the owner of an interest; (7) The net value of total sales after deductions or adjustments that reduce the amount paid to the owner of an interest; (8) The percentage share of the owner of an interest in the sales of the production from the oil or gas well, lease or property as expressed by a decimal number; (9) The share of the total value attributed to the owner of an interest in the sales of the production from the oil or gas well,
2347 Id.
447
lease or property before any deductions or adjustments and after any deductions or adjustments; and (10) A name and an address where the owner of an interest may receive clarification of the information reported pursuant to this paragraph and additional information concerning the owner’s interest. If information is requested by certified mail, an answer must be mailed by certified mail within 30 days after receipt of the request.2348
The term “costs of production” means all costs incurred for the exploration and
development of, primary or enhanced recovery of oil or gas from, and operations associated with
the abandonment of, an oil or gas well, including costs associated with the acquisition of an oil
and gas lease; drilling and completion of the well; pumping or lifting, recycling, gathering,
compressing, pressurizing, heater treating, dehydrating, separating and storing of oil or gas; and
transporting of oil to storage tanks, or gas into the pipeline for delivery. Such costs do not
include the reasonable and actual direct costs associated with transporting oil from storage tanks
to the market, gas from the point of entry into the pipeline to the market or the processing of gas
in a processing plant.
2349 However, a Division order may not alter or amend the terms of a
previously-executed oil or gas lease or other written agreement.2350
[e] Restraint of Trade.
The Act specifies that “[n]o agreement or plan for the development and operation of a
field or pool of oil or gas as a unit, if approved by the Division for the purpose of conserving oil
or gas, violates any [Nevada] statutes . . . prohibiting monopolies or acts . . . in restraint of trade
Nevada defines “gas” to include “all natural gas and all hydrocarbons produced at the
wellhead except oil.” 2352 “Oil” is defined to include the crude petroleum oil and other
hydrocarbons regardless of gravity which are produced at the wellhead in liquid form; and the
liquid hydrocarbon known as distillate or condensate recovered or extracted from gas, other than
gas produced in association with oil and commonly known as casinghead gas.2353
[2] – Split by Depth.
As discussed
below, the general statewide spacing rules are different for oil and gas wells. Other than the
spacing rules stated below, there is little language in the Act or Division rules to distinguish
between the two.
As noted below, the Division regulations provide default spacing rules which vary based
upon the depth of a given well.
[3] – Size & Spacing Rules.
In a proven oil and gas field, the spacing of wells is governed by special rules for each
particular field, to be adopted by the Division after notice and hearing. 2354
(1) Each well drilled for oil with a projected depth of 5,000 feet or less must be located not less than 330 feet from the outside boundary of a government quarter-quarter section, or of a lot, tract or combination of lots or tracts substantially equivalent to a quarter-quarter section as shown by the most recent government survey. Unless the administrator, in his discretion, determines otherwise, only one well may be issued a permit to produce oil from the same reservoir within the same quarter-quarter section.
In the absence of a
special order of the Division establishing drilling units or authorizing different densities of wells
or patterns of location for particular pools or parts of pools, the following requirements apply:
(2) Each well drilled for oil with a projected depth of greater than 5,000 feet must be located not less than 330 feet from the outside boundary of a government quarter section, or of a lot, tract or
combination of lots or tracts substantially equivalent to a quarter section as shown by the most recent government survey. Unless the administrator, in his discretion, determines otherwise, only one well may be issued a permit to produce oil from the same reservoir within the same quarter section. (3) Each well drilled for gas with a projected depth of 5,000 feet or less must be located not less than 660 feet from the outside boundary of a government quarter section, or of a lot, tract or combination of lots or tracts substantially equivalent to a quarter section as shown by the most recent government survey. Unless the administrator, in his discretion, determines otherwise, only one well may be issued a permit to produce gas from the same reservoir within the same quarter section. (4) Each well drilled for gas with a projected depth of greater than 5,000 feet must be located not less than 990 feet from the outside boundary of a government section, or of a lot, tract or combination of lots or tracts substantially equivalent to a section as shown by the most recent government survey. Unless the administrator, in his discretion, determines otherwise, only one well may be issued a permit to produce gas from the same reservoir within the same section. (5) These requirements for the location of a well do not apply to federal units, wells drilled pursuant to a working interest agreement, and areas subject to existing orders for drilling and spacing. (6) The administrator will determine the pattern for the location of wells adjacent to an area in which the spacing of wells is prescribed by the Division or under application for spacing, where there is sufficient evidence to indicate that the pool or reservoir for which the spacing of wells is or will be prescribed by the Division may extend beyond the boundary of the spacing order or application, and the uniformity of the pattern of spacing is necessary to ensure an orderly development of the pool.2355
Upon proper application, the administrator may approve an exception to general spacing
laws or to any order of the Division dictating the spacing of wells for a pool.
2356
(a) The locations at which an oil or gas well could be drilled in compliance with law or an applicable order;
An application
for an exception must state the reasons the exception is sought and be accompanied by a plat
showing the following:
2355 Id. 2356 Id. § 522.240.
450
(b) The location at which the applicant requests permission to drill; and (c) The locations at which oil or gas wells have been or could be drilled in accordance with law or an applicable order:
(1) In a quarter section, for any oil well, regardless of depth, or any gas well of 5,000 feet or less; or (2) In a section, for any gas well greater than 5,000 feet, directly or diagonally adjoining the quarter section or section for which the proposed exception is sought.
An exception approved by the administrator does not affect the rights of owners of directly or
diagonally adjoining tracts to drill for oil or gas.2357 If, before drilling a well, the person to
whom the permit was originally issued desires to change the location, he must submit a letter so
stating and another application showing the new location.2358
[4] – Minimum Operator Control.
The Act states that a Division order for unitization will not become effective without the
written approval “by the lessees of record of not less than 62.5 percent of the unit area affected
thereby[,] and by the owners of record of not less than 62.5 percent (exclusive of royalty interests
owned by lessees or subsidiaries of any lessee) of the normal one-eighth landowners’ royalty
interest in and to the unit area.”2359 The Division must make a formal finding that such consent
has been granted, and may hold supplemental hearings as necessary to obtain the requisite
percentage.2360 If sufficient approval has not be established within six months of the order’s
issuance, the Division will revoke the order.2361
[5] – Directional Drilling.
Except for wells that are intentionally deviated, all wells must be drilled as nearly
vertically as possible by normal, prudent, and practical drilling operations. No interval in an oil
well may be opened to the wellbore closer than 330 feet from the outer boundary of the lease on
which the well is located, and no interval in a gas well may be opened to the well bore closer
than 660 feet from the outer boundary of the lease on which the well is located. Plans for
directional drilling must be approved by the Division before the drilling is begun. Upon
completion of the well, a complete directional survey of the well, including a plat obtained by
methods used for surveying wells must be filed with the Division. Deviation from the plan is
permitted without the approval for short distances to straighten the hole, sidetrack junk, or
correct other mechanical difficulties.2362
[6] – Election.
As to lessees who refuse to agree upon pooling, the order must provide for reimbursement
for 300 percent of the costs chargeable to each lessee out of, and only out of, production from the
unit belonging to the lessee.2363
2362 Id. § 522.275.
2363 Id. § 522.060(4).
452
§ 30.01 Analysis of New Hampshire Regulatory Framework. The state of New Hampshire has not enacted any statute addressing oil and gas
conservation.
453
§ 31.01 Analysis of New Jersey Regulatory Framework.
[1] – Name of Governing Body.
New Jersey law does not provide an express statutory provision relating to pooling or
unitization and only includes a discussion of oil and gas production. Chapter 1M, Title 13 of the
New Jersey statute (“Act”) discusses the drilling requirements for an oil and natural gas well.2364
Natural gas does not include methane or other hydrocarbon gases resulting from the
decomposition of organic matter in solid waste at any landfill facility. 2365
The Act provides that no person may begin operations incident to the exploration and
drilling of oil or natural gas wells without having received a permit from the Department of
Environmental Protection (“Department”).
2366
Within the Department, there is the Commissioner of the Department (“Commissioner”),
who is the Department administrator and head. The Commissioner has the Deputy
Commissioner, the Chief of Staff, two Counselors to the Commissioner, and eight Assistant
Commissioners, report directly him or her.
2367
(1) administer the work of the Department;
The Commissioner, as the head of the
Department, has the authority to do the following:
(2) appoint and remove officers and other personnel employed within the Department, subject to the provisions of Title 11 of the Revised Statutes, Civil Service, and other applicable statutes, except as herein otherwise specifically provided; (3) perform, exercise, and discharge the functions, powers, and duties of the Department through such divisions as may be established by this act or otherwise by law; (4) organize the work of the Department in such divisions, not inconsistent with the provisions of this act and in such bureaus and other organizational units as he may determine to be necessary for efficient and effective operation;
2364 N.J. Stat. Ann. §13:1M-2 (West 2011). 2365 Id. 2366 Id. 2367 N.J. Admin. Code §7:1-1.2 (a) (2011).
454
(5) adopt, issue, and promulgate, in the name of the Department, such rules and regulations as may be authorized by law; (6) formulate and adopt rules and regulations for the efficient conduct of the work and general administration of the Department, its officers and employees; (7) institute or cause to be instituted such legal proceedings or processes as may be necessary properly to enforce and give effect to any of his powers or duties; (8) make an annual report to the Governor and to the Legislature of the Department's operations, and render such other reports as the Governor shall from time to time request or as may be required by law; (9) co-ordinate the activities of the Department, and the several divisions and other agencies therein, in a manner designed to eliminate overlapping and duplicating functions; (10) integrate within the Department, so far as practicable, all staff services of the Department and of the several divisions and other agencies therein; and (11) perform such other functions as may be prescribed in this act or by any other law. 2368
The Deputy Commissioner provides policy recommendations to the Commissioner and
serves as Acting Commissioner in the Commissioner's absence or disability.
2369 The Chief of
Staff coordinates staff functions in the Commissioner's office. He or she is also responsible for
the day-to-day administration of Department activities. 2370
Two Counselors to the Commissioner serve as the Commissioner's legal liaisons with the
Department of Law and Public Safety and advise the Commissioner regarding policy
implications of legal issues that arise in connection with the Department's work. In addition, the
lead Counselor to the Commissioner serves as the Department's Ethics Liaison Officer and the
Department's liaison to all of the agencies allocated to the Department in accordance with the
New Jersey Constitution and commonly known as "in but not of agencies." The lead Counselor
to the Commissioner oversees the Office of Legal Affairs and the Office of Dispute
Resolution. 2371
Additionally, each of the eight Assistant Commissioners oversees a number of programs
and organizational units. However, none of these programs or organizational units is granted
specific authority over the drilling of oil and natural gas wells. The Act only grants general
authority to the Department to oversee and regulate drilling for oil and gas.
2372
[2] – Procedure.
In order to drill for oil and gas, a person needs to file with the Department, upon forms
proscribed and supplied by the Department, for a permit to drill. A permit will be issued only
upon a written finding by the Department that the authorized actions will not result in any (1)
adverse consequences to groundwater and surface water; (2) significant degradation of
landscape; (3) threat to public health and safety; and (4) substantial air and noise pollution. 2373
(1) the name and address of the owner, and if a corporation, the name and address of the statutory agent;
The permit or application to drill an oil and gas well needs to include the following information:
(2) the signature of the owner or his authorized agent. When an authorized agent signs an application it shall be accompanied by a certified copy of his appointment as such agent; (3) the names and addresses of all persons holding the royalty interest in the tract upon which the well is located or is to be drilled or within a proposed drilling unit; (4) the location of the tract or drilling unit on which the well is located or is to be drilled, as identified by municipal tax map by lot and block; (5) designation of the well by name and number; (6) the geological formation to be tested or used and the proposed total depth of the well; (7) the type of drilling equipment to be used; (8) the name of the New Jersey-licensed well driller or driller who supervises the drilling operations;
2371 Id. § 7:1-1.2 (d). 2372 See generally id. § 7:1 (2010); N.J. Stat. Ann. § 13:1M-2 (West 2011). 2373 N.J. Stat. Ann. § 13:1M-3.
456
(9) the name and address of the corporate surety and the identifying number of the bond required; (10) a plan for ground and surface water protection, which shall include a method for disposal of water and other waste substances—including brine—resulting, obtained, or produced in connection with the exploration and drilling for oil or natural gas; (11) a plan for casing; (12) a plan for handling muds; (13) a plan for safety; (14) a plan for restoration of the land surface disturbed by operations incident to the exploration, drilling, and plugging and abandonment of wells for oil or natural gas; (15) if the well is for the injection of a liquid, identity of the geological formation to be used as the injection medium and the composition of the liquid to be injected; (16) a sworn statement that the owner has in force and will maintain until abandonment of any oil or gas well in this State liability insurance coverage in an amount not less than $10,000,000.00 for bodily injury and $10,000,000.00 for property damage, to pay claims arising out of the drilling, operation, or plugging and abandonment of the wells; (17) a sworn statement that all requirements of any municipality having jurisdiction over any activity related to the exploration, drilling, and plugging and abandonment of any oil or gas well that have been filed with the Department and are in effect at the time the application is filed, including but not limited to zoning ordinances and resolutions, will be complied with; (18) a description, by name or number, of the county, State, and municipal roads, streets, and highways that the applicant anticipates will be used for access to and egress from the well site; and (19) a map, on a scale not smaller than four hundred feet to the inch, prepared by a surveyor licensed in New Jersey, showing the location of the well and containing such other data as may be required by the Department.2374
The permit must be accompanied by a permit fee and a surety bond.
2375
Prior to the approval of a permit or an amended permit, the Department must provide
timely and informative notice of permit application to the public of the affected area. The public
will then be afforded an opportunity to review and comment on the permit application. Any
2374Id. § 13:1M-2. 2375Id. §§13:1M-4, 5.
457
public comment that is made and submitted to the Department will be made part of the record.
The Department will consider these comments when deciding whether to approve the permit.
Additionally, the Department will hold a public hearing if any person requests that such be
done.2376
The permit holder may change the well site with the approval of the Department.
Requests for change must be accompanied by an amended application. The Act prohibits the
commencement of drilling on the new drilling site until the new location has been approved by
the Department. The Department will show its approval by posting the amended permit at the
well site.
2377
Once the well is drilled and it is determined that it will produce marketable quantities of
oil or natural gas, the permit holder must file a written report within seven days of the
determination of marketable quantities to the Department that provides (1) the location and depth
of the well; (2) the estimated quantity of oil or natural gas producible from the well; (3) the
plans, if any, for extraction of the oil or natural gas; and (4) any additional information that may
be required by the Department.
2378
An oil and gas well must be plugged if it is incapable of producing oil or gas in
commercial quantities, unless the Department grants written permission to do otherwise. If the
Department finds that the well needs to be plugged and abandoned, then it will notify and order
in writing the permittee to plug the well. The order will contain a reasonable time for
§ 32.01 Analysis of New Mexico Regulatory Framework.
[1] – Governing Body.
New Mexico (along with Oklahoma) enacted the first compulsory pooling statute in the
United States.2380 New Mexico currently has both compulsory pooling and unitization.2381 The
Oil Conservation Division of the Energy, Minerals, and Natural Resources Department
(“Division”) carries out compulsory pooling under the Oil and Gas Act and unitization under the
Statutory Unitization Act in New Mexico.2382
[2] – Membership on the Governing Body.
The New Mexico Oil Conservation Commission (“Commission”) is the policymaker for
the Division. The Commission is composed of a designee of the Commissioner of Public Lands,
a designee of the Secretary of Energy, Minerals, and Natural Resources, and the director of the
Oil Conservation Division. 2383 The designees of the Commissioner of Public Lands and the
Secretary of Energy, Minerals, and Natural Resources must be persons who have expertise in the
regulation of petroleum production by virtue of education or training.2384 The Oil and Gas Act
states that the term of office of each member of the Commission is concurrent with the other
office held by him (in the case of a designee, although the statute is not clear, this presumably
means that their tenure is based on the tenure of the official that designated them, whether the
Commissioner of Public Lands or the Secretary of Energy, Minerals, and Natural Resources).2385
The director of the Division is appointed by the Secretary of Energy, Minerals, and
Natural Resources and must (1) be a resident of the state and (2) be registered by the state board
2380 See Patrick Martin & Bruce Kramer, The Law of Pooling and Unitization § 3.02 (MB 2010). 2381 N.M. Stat. Ann. §§ 70-2-17, -2-1 to -2-38, -7-1 to -7-21 (2011). 2382 Id. § 70-2-17. 2383 Id. § 70-2-4. 2384 Id. 2385 Id.
459
of registration for professional engineers and land surveyors as a petroleum engineer or (3) by
virtue of education and experience have expertise in the field of petroleum engineering.2386 His
official title is the “State Petroleum Engineer.”2387
[3] – Scope of Authority.
The Commission and the Division have jurisdiction over all matters relating to oil and
gas conservation.2388 The statutory sections generally refer to the authority of the Division rather
than the Commission, but the Commission has concurrent jurisdiction and authority with the
Division.2389 The Division has the authority to determine and change the limits of pools and
units.2390 Regulatory decisions must be based on substantial evidence.2391 Courts generally
defer to administrative technical authority.2392
The Division has the power and duty under the Oil and Gas Act to prevent waste and
protect correlative rights.
2393 The Division has the power to prescribe “proration units” in a pool
(these appear to be similar to the “drilling units” in other states), being the area that can be
efficiently drained by one well in the pool. The Division may vary the standard spacing rules if
the deviation is necessitated by a variation in public land surveys upon application. 2394 In
regards to compulsory pooling, the Division has the power to pool two or more separately owned
tracts of land within a spacing or proration unit to avoid waste and protect correlative rights, but
only when the owners have not agreed to pool their interest voluntarily.2395
2386 Id. § 70-2-5.
2387 Id. 2388 Id. § 70-2-6. 2389 Id. 2390 Id. § 70-2-12. 2391 See Santa Fe Exploration Co. v. Oil Conservation Comm'n of N.M., 114 N.M. 103, 114, 835 P.2d 819, 830 (1992). 2392 See, e.g., id. at 114, 835 P.2d at 819. 2393 N.M. Stat. Ann. § 70-2-11 (2011). 2394 N.M. Code R. § 19.15.15.11 (2011). 2395 N.M. Stat. Ann. § 70-2-17 (2011).
460
The Division also has the express authority to carry out the purposes of the Statutory
Unitization Act.2396 The Act seeks to “authorize and provide for the unitized management,
operation and further development of the oil and gas properties to which the Statutory
Unitization Act is applicable, to the end that greater ultimate recovery may be had therefrom,
waste prevented, and correlative rights protected of all owners of mineral interests in each
unitized area.”2397 The Act applies to “any type of operation that will substantially increase the
recovery of oil above the amount that would be recovered by primary recovery alone and not to
what the industry understands as exploratory units.”2398
The Division has the expressly enumerated power to collect data; make investigations
and inspections; examine properties, leases, papers, books, and records; examine, check, test, and
gauge oil and gas wells, tanks, plants, refineries, and all means and modes of transportation and
equipment; hold hearings; provide for the keeping of records and the making of reports and for
the checking of the accuracy of the records and reports; limit and prorate production of crude
petroleum oil or natural gas; and require certificates of clearance or tenders in connection with
the transportation of oil or gas or any products of either.
2399 It also has the authority to regulate
well plugging, well production records, the encroachment of water in productive strata, the
prevention of fires, blow-ups, and caving, well spacing, classification of wells and pools as gas
or oil pools or wells, oil or gas storage (including subsurface storage), secondary recovery
activities, including natural gas injection, water use and disposal, and oil treatment plants.2400
the area of drainage, although of course proration unit boundaries are supposed to be defined by
the area that can be drained efficiently).2419 Unleased landowners must be treated as one-eighth
royalty owners and seven-eighths working interest owners (thus entitling them to a share of net
profits, potentially diminished by the risk penalty if they do not pay for their share of drilling
costs). 2420 The default risk penalty is 200 percent, although it may be altered upon
application.2421
[b] Statutory Requirements for Unitization Orders.
Unitization orders are entered after notice and hearing.2422 Any working interest owner
may file an application with the Division requesting an order for the unit operation of a pool or
any part thereof. An application must contain (1) a description of the proposed unit area and the
vertical limits to be included therein with a map or plat thereof attached; (2) a statement that the
reservoir or portion thereof involved in the application has been reasonably defined by
development; (3) a statement of the type of operations contemplated for the unit area; (4) a copy
of a proposed plan of unitization which the applicant considers fair, reasonable, and equitable;
(5) a copy of a proposed operating plan covering the manner in which the unit will be supervised
and managed and costs allocated and paid; and (6) an allegation of the facts required to be found
by the Division under section 70-7-6 of the New Mexico statutes.2423
Section 70-7-6 requires the following facts be found for the issuance of a unitization
order:
(1) that the unitized management, operation, and further development of the oil or gas pool or a portion thereof is reasonably necessary in order to effectively carry on pressure
maintenance or secondary or tertiary recovery operations, to substantially increase the ultimate recovery of oil and gas from the pool or the unitized portion thereof; (2) that one or more of the said unitized methods of operations as applied to such pool or portion thereof is feasible, will prevent waste and will result with reasonable probability in the increased recovery of substantially more oil and gas from the pool or unitized portion thereof than would otherwise be recovered; (3) that the estimated additional costs, if any, of conducting such operations will not exceed the estimated value of the additional oil and gas so recovered plus a reasonable profit; (4) that such unitization and adoption of one or more of such unitized methods of operation will benefit the working interest owners and royalty owners of the oil and gas rights within the pool or portion thereof directly affected; (5) that the operator has made a good faith effort to secure voluntary unitization within the pool or portion thereof directly affected; and (6) that the participation formula contained in the unitization agreement allocates the produced and saved unitized hydrocarbons to the separately owned tracts in the unit area on a fair, reasonable, and equitable basis.2424
Unitization orders must be ratified by 75 percent of the production owners and the cost
providers.
2425 If one owner controls more than 75 percent of the minerals, there must
nonetheless be at least one other owner who consents to the order. Unleased landowners owners
receive a one-eighth royalty.2426
[5] – Matters Covered.
Spacing rules fall under New Mexico Administrative Code section 19.15.15 and are more
fully described in Section 31.02, infra. As mentioned above, in addition to regulating pooling
and unitization, the Division also regulates well plugging, well production records, the
encroachment of water in productive strata, the prevention of fires, blow-ups, and caving,
classification of wells and pools as gas or oil pools or wells, oil or gas storage (including
subsurface storage), secondary recovery activities including natural gas injection, water use and
disposal, and oil treating plants.2427
§ 32.02 Types of New Mexico Pooling Statutes.
[1] – Mineral and Depth Distinctions.
In New Mexico pooling applies to oil and gas pools. 2428 Coalbed methane is not
expressly included or excluded from the definition of oil and gas under the Oil and Gas Act, New
Mexico oil and gas regulations, or state case law. The pooling statute is not expressly limited to
any strata or depth. Unitization expressly applies to oil and gas.2429 “Oil and gas” are defined
under the Act as “crude oil, natural gas, casinghead gas, condensate or any combination
thereof.”2430
[2] – Spacing and Size Rules.
Thus, the Unitization Act does not expressly include or exclude coalbed methane.
The Act also does not expressly limit its application to any depth or strata. Wells are treated
differently by strata, to the extent that spacing is different based on the strata that a well drains,
as described in more detail, infra.
The spacing rules in New Mexico are different according to the type of well, the county
in which the well is located, and the pool from which it produces.2431 The spacing rules first
distinguish between wildcat wells and development wells.2432
(1) In San Juan, Rio Arriba, Sandoval, and McKinley counties, a wildcat well is a well to be drilled the spacing unit of which is a distance of two miles or more from:
A wildcat is defined as follows:
(a) the outer boundary of a defined pool that has produced oil or gas from the formation to which the well is projected to be drilled; and
(b) a well that has produced oil or gas from the formation to which the proposed well is projected to be drilled. (2) In all counties except San Juan, Rio Arriba, Sandoval, and McKinley, a wildcat well is a well to be drilled the spacing unit of which is a distance of one mile or more from: (a) the outer boundary of a defined pool that has produced oil or gas from the formation to which the well is projected to be drilled; and (b) a well that has produced oil or gas from the formation to which the proposed well is projected.2433
[3] – Spacing for Oil Wells.
A well that is not a wildcat well is classified as a development well for the nearest pool
that has produced oil or gas from the formation to which the well is projected to be drilled. The
operator must space, drill, operate, and produce a development well in accordance with the rule
or order in effect for that pool, provided the well is completed in that pool.2434
A wildcat well that the operator projects to drill as an oil well to a formation and in an
area that in the Division's opinion may reasonably be presumed to produce oil rather than gas,
and each development well for a defined oil pool unless otherwise provided in special pool
orders, must be located on a spacing unit consisting of approximately 40 contiguous surface
acres, substantially in the form of a square that is a legal subdivision of the United States public
land surveys and is a governmental quarter-quarter section or lot, and shall be located no closer
than 330 feet to a boundary of the unit.
2435 Only 40-acre spacing units committed to active
secondary recovery projects may be permitted more than four wells.2436 If a proposed oil well is
completed as a gas well, the operator must seek Division approval for the nonstandard location
of the well before it may produce.2437
2433 Id. § 19.15.15.8.
2434 Id. 2435 Id. § 19.15.15.9. 2436 Id. 2437 Id.
469
[4] – Spacing for Gas Wells.
A wildcat well that the operator projects to drill as a gas well to a formation and in an
area that in the Division's opinion may reasonably be presumed to produce gas rather than oil
and each development well for a defined gas pool, unless otherwise provided in special pool
orders, shall be spaced and located as follows:
(1) 640-acre spacing applies to a deep gas well2438
(2) 320-acre spacing applies to a deep gas well in Lea, Chaves, Eddy, or Roosevelt Counties that is projected to be drilled to a gas-producing formation, or is within a defined gas pool, that is in the Wolfcamp or an older formation. The well must be located on a spacing unit consisting of 320 surface contiguous acres, more or less, comprising any two contiguous quarter sections of a single section that is a legal subdivision of the United States public land surveys provided that (1) the initial well on a 320-acre unit is located no closer than 660 feet to the outer boundary of the quarter section on which the well is located and no closer than 10 feet to a quarter-quarter section line or subdivision inner boundary and (2) only one infill well on a 320-acre unit shall be allowed provided that the well is located in the quarter section of the 320-acre unit not containing the initial well and is no closer than 660 feet to the outer boundary of the quarter section and no closer than 10 feet to a quarter-quarter section line or subdivision inner boundary;
in Rio Arriba, San Juan, Sandoval, or McKinley Counties that is projected to be drilled to a gas producing formation older than the Dakota formation or is a development well within a gas pool created and defined by the Division after June 1, 1997 in a formation older than the Dakota formation, which formation or pool is located within the surface outcrop of the pictured cliffs formation (i.e., the San Juan basin). The well must be located on a spacing unit consisting of 640 contiguous surface acres, more or less, substantially in the form of a square that is a section and legal subdivision of the United States public land surveys and must be located no closer than (1) 1,200 feet to an outer boundary of the spacing unit; (2) 130 feet to a quarter section line; and (3) 10 feet to a quarter-quarter section line or subdivision inner boundary;
(3) 160-acre spacing applies to a gas well not covered above. The well must be located in a spacing unit consisting of 160 surface contiguous acres, more or less, substantially in the form of a square
2438 “Deep gas well” is not defined in the regulations; however “deep pool” is defined as “a common source of supply that is situated 5,000 feet or more below the surface”; presumably a “deep well” is one that produces from a “deep pool.” See id. § 19.15.2.7(D)(1).
470
that is a quarter section and a legal subdivision of the United States public land surveys and must be located no closer than 660 feet to an outer boundary of the unit and no closer than 10 feet to a quarter-quarter section or subdivision inner boundary.2439
[5] – Non-Standard Spacing Units.
Division district offices may approve non-standard spacing units without notice when the
unorthodox size or shape is necessitated by a variation in the legal subdivision of the United
States public land surveys or consists of an entire governmental section, and the non-standard
spacing unit is not less than 70 percent or more than 130 pecent of a standard spacing unit.2440
The director may approve administratively an application for non-standard spacing units after
notice and opportunity for hearing when the unorthodox size or shape is necessitated by a
variation in the legal subdivision of the United States public land surveys or the following facts
exist: (a) the non-standard spacing unit consists of a single quarter-quarter section or lot or
quarter-quarter sections or lots joined by a common side and (b) the non-standard spacing unit
lies wholly within a single quarter section if the well is completed in a pool or formation for
which 40, 80, or 160 acres is the standard spacing unit size; a single half section if the well is
completed in a pool or formation for which 320 acres is the standard spacing unit size; or a single
section if the well is completed in a pool or formation for which 640 acres is the standard spacing
unit size.2441
[6] – Directional Drilling.
No New Mexico oil and gas statutes or regulations contain any provisions specifically
on the Board in an ex-officio capacity.2455 The Bureau of Mineral Resources is directed by a
chief, 2456 aided by and assistant chief, who acts in the chief’s absence. 2457 The Bureau is
organized into regions, each with a regional supervisor acting as the chief’s deputy.2458
[3] – Scope of Authority.
The Department is granted its authority and given the framework for regulating the oil
and gas industry by the Act, 2459 as amended by Chapter 386 of the Laws of 2005. The
Department may, with regard to oil and gas pools and fields, investigate as necessary to
determine if waste exists or is imminent. 2460 The Department has the authority to regulate
pooling and spacing, as well as to review drilling proposals, conduct hearings, investigate the
environmental impact of drilling, and conduct site inspections, among other things.2461
[4] – Process for Pooling.
The Department may not promulgate any orders without first holding a public hearing
upon at least 10 days’ notice.2462 Hearings must be conducted by the director2463 or his staff as
designated. 2464 Notice of Department hearings must be given, either by personal service,
newspaper publication, or by mail and must address the purpose, style, number, time, and place
of the hearing.2465
Any party who applies for a permit to drill an oil or gas well must control, either through
fee ownership, voluntary agreement, or integration order of the Department, not less than 60
2455 Id. § 23-0311(2). 2456 N.Y. Comp. Codes R. & Regs. tit. 6, § 550.2(c) (2011). 2457 Id. § 550.2(d). 2458 Id. § 550.2(e). 2459 N.Y. Envtl. Conserv. Law § 23-0303(1) (McKinney 2011). 2460 Id. § 23-0305(7)(a). 2461 Id. § 23-0305. 2462 N.Y. Comp. Codes R. & Regs. tit. 6, § 550.4(a) (2011). 2463 The regulations state that the “director” conducts hearings, although the director is an undefined term; likely, either the commissioner of the Department or the chief of the Bureau were intended. 2464 N.Y. Comp. Codes R. & Regs. tit. 6, § 550.4(b) (2011). 2465 Id. § 550.4(c).
475
percent of the acreage in the proposed spacing unit for that well.2466 Those parties must also
submit to the Department a map of the proposed spacing unit in conformity with statewide
spacing rules, discussed in detail below, and a showing that the applicant controls the appropriate
percentage of oil or gas rights.2467 If the proposed spacing unit conforms to said spacing rules
and is approximately the same shape as other units in the same pool or field, and if it either
adjoins other units or leaves enough space for additional units to be developed, then the
Department will issue the permit. 2468 However, before it may issue such permits, the
Department must publish notice of intent to do so in the Environmental Notice Bulletin.2469
If the proposed unit does not fit the statewide spacing provisions, the Department may
still issue a permit if the unit meets the state’s policy objectives
2470—i.e., to prevent waste, to
increase ultimate recovery, and to protect correlative rights.2471 If approved, the Department
must make adjustments to production allowables so that each owner in the unit receives his or
her equitable share of production from the underlying pool.2472
The Department must receive all comments and challenges regarding the notice of intent
to issue a permit within 30 days of sending the notice, which challenges must include a
description and map of a proposed alternative spacing unit, technical justification for such
alternative spacing unit, and the name, address, and experience of any expert witnesses
supporting the alternative unit.
2473
2466 N.Y. Envtl. Conserv. Law § 23-0501(2) (McKinney 2011).
If the Department determines that the challenge raises no
substantive issues, or if no challenge is submitted, the Department will issue the permit and final
(c) The locating, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner which causes or tends to cause reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or which causes or tends to cause unnecessary or excessive surface loss or destruction of oil or gas; (d) The inefficient storing of oil or gas; and (e) The flaring of gas produced from an oil or condensate well after the department has found that the use of the gas, on terms that are just and reasonable, is, or will be economically feasible within a reasonable time.2490
Where an integration hearing is scheduled, the operator must give at least 30 days’ notice
to the uncontrolled owners.
2491 The operator must also provide an estimate of well costs to be
paid by the participating owners based on their proportionate interests, a list of the controlled
tracts, and a list of the names and addresses of the uncontrolled owners.2492 The operator must
indicate if the identities of the uncontrolled owners are unknown. Where the owners are
unknown and a spacing unit is ordered, the operator must hold the royalties payable to the
unknown owner in an interest-bearing account until the owner is located or the property is
deemed abandoned.2493
The notice of the hearing for uncontrolled owners must be in a form prescribed by the
Department and include several provisions.
2494 It must contain an election form allowing
uncontrolled owners to elect to be integrated into the spacing unit as an integrated participating
owner, an integrated non-participating owner, or an integrated royalty owner, along with
estimated costs of participation; if uncontrolled owners do not make a timely election, the default
election status is that of an integrated royalty owner, 2495
Notice must also include the proposed integration order. 2496
(A) The owner is liable for its proportionate share of all costs and expenses and third-party claims related to the well;
The proposed order has
several required terms, including the following:
(B) The well operator should hold risk penalty funds in an interest-bearing account until those funds are used for plugging and abandonment; (C) The owner is liable for and shall indemnify all other participants in the development of the well from and against all claims arising from the owner’s non-payment of rentals, royalties, and other required payments and from and against all claims associated with the loss or failure of title to the mineral rights; (D) The well operator has a lien on the production of owners to pay outstanding costs and may retain revenue or production to pay such costs owed under the integration order; (E) The well operator must submit to all owners written authority for expenditures of the costs associated with construction of the facilities that are not included in well costs beyond surface equipment at the wellhead to the first point of interconnection with other facilities that commingle production from a group of wells that include the well. If the owner does not elect to participate and pay its proportionate share within 30 days, the owner is deemed not to have elected, and the operator is entitled to retain all of the owner’s share of production until he has recouped from the net proceeds the actual costs plus a risk penalty of 100 percent of the costs; (F) If the owner is not subject to a risk penalty, the owner has the right to take its share of production and be responsible for marketing and transportation. The owner’s election to take in kind must be communicated to the operator not later than 14 days before first production or upon 75 days’ notice to the operator at any time thereafter subject to the expiration of an existing contract; (G) If the owner is not subject to a risk penalty and does not take its production share in kind, the operator will market such share with its own share for the owner’s account and pay the owner based on the price received in the general area minus (I) the owner’s proportionate share of costs and (II) a marketing fee not to exceed five percent of the sales price; (H) The operator is entitled to propose and conduct subsequent operations on a well; owners will be provided with written authorization for expenditure of the estimated costs of subsequent operations. Owners in a risk penalty phase may not participate in such subsequent operations but will be charged the owner’s
2496 Id. § 23-0901(3)(c)(1)(ii).
480
proportionate share of actual costs plus 200 percent risk penalty. Owners not in a risk penalty phase have 30 days to elect to participate unless the rig is already on location, in which case telephone notification is allowed, and the owner has 48 hours, exclusive of weekends and holidays, to accept. If no election is made, the operator may retain the owner’s proportionate share plus 200 percent of actual costs; (I) The operator, on behalf of the owner, is entitled to conduct all acts relating to the well; and (J) Other terms are allowed to be included in the order if the Department determines those terms are reasonably required to further the section 23-0301 policy objectives.2497
Within 21 days of receipt of the notice, the uncontrolled owners must indicate to the
Department and the operator the type of ownership status (discussed in detail in below) that they
elect.
2498 If the owner fails to make an election, the owner will be integrated as an integrated
royalty owner.2499
If substantive and significant issues are raised during the initial hearing, then the Division
will schedule an adjudicatory hearing regarding the issues.
2500 If there are no such issues,
however, the Division will issue a final order of integration confirming the status of all
uncontrolled owners. The order will be recorded in the office of the county clerk in the county or
counties where the property is located, and the order will be final and binding on the well
operator as well as the owners and their heirs, successors, and assigns.2501 All operations on a
spacing unit that is covered by an integration order are deemed to be conducted upon each
separately owned tract in the spacing unit by the owner or owners thereof, and production
allocated to each tract under an integration order is deemed to have been produced by a well
The Department’s authority to order compulsory integration also pertains to integration
resulting in the unit operation of an entire pool.2503 The Department may elect to hold a hearing
to consider the need for unit operation upon its own motion and it must hold such a hearing when
an application is filed by an interested person.2504 Once an application is filed, a hearing should
be held without “undue delay,” and the Department must issue an order within 60 days of the
conclusion of the hearing.2505 In making its determinations, the same policies regarding waste
prevention and correlative right protection must be considered.2506 Prior to issuing an order, the
Department has broad powers of investigation and may subpoena parties to testify.2507 Once a
permit is issued, the operator must notify by certified mail any local government affected by the
location of the drilling site prior to commencing operations.2508
If the Department decides that unit operations are reasonably necessary to increase
substantially the ultimate recovery of oil and gas and that the estimated additional recovery value
is greater than the estimated additional cost of running such operations, the Department will
issue an order providing for unit operations.
2509
(a) A description of the unit area; (b) A statement of the nature of the operations contemplated; (c) An allocation of production that is not used in conducting operations and that is not unavoidably lost. If the parties have not agreed as to the allocation, the Department will determine the production allocation, which must be the proportion that the value of each tract bears to the value of all tracts in the unit area; (d) A provisions for charges to be made in adjusting among owners for their investments in operations; (e) A provision providing how expenses, including capital investment, will be charged and paid; (f) A provision, if needed, for carrying or
financing those unable to pay for their portion of unit operations; (g) A provision for the supervision and conduct of the operations; (h) The time when operations begin and the manner in which they end; (i) Additional provisions as appropriate.2510
Unitization orders are not effective until the plan issued by the Department is approved in
writing by the owners of 60 percent or more in interest as the costs are shared under the order
and by owners of a like percentage of a one-eighth royalty interest in the unit area.
2511 The
Department must make a finding that the plan has been adequately approved, and such approval
must be had within six months from the order date or it will become ineffective.2512
Orders may be amended in the same way and subject to the same conditions as the
original order.
2513 However, if the amendment only affects rights of owners, royalty owners
need not give their approval. 2514 Amendments may not change the percentage allocation
provided for in the original order without the consent of all persons owning interest in the tract at
issue.2515 Also, the Department may provide for unit operation in an area that is covered by a
previous order so long as allocation is had for the new portion of the tract.2516
§ 33.02 Types of New York Pooling Statutes.
[1] – Mineral Distinctions.
New York law provides the following definitions. “Gas” is defined as “all natural,
manufactured, mixed, and byproduct gas, and all other hydrocarbons not defined as oil in this
section.”2517
2510 Id.
“Oil” means “crude petroleum oil and all other hydrocarbons, regardless of gravity,
that are produced at the wellhead in liquid form by ordinary production methods and that are not
the result of condensation of gas.”2518
[2] – Spacing Rules.
Spacing orders are not required for wells that were drilled, operated, plugged, or
converted prior to January 1, 1981. 2519
For gas pools drilled to any depth in the Medina Formation, the spacing unit must be within 10 percent of 40 acres, with the wellbore within the target formation no less than 460 feet from any unit boundary, plus, if applicable, the number of additional acres necessary and sufficient to ensure that any horizontal wellbore within the target formation is not less than 460 feet from any unit boundary;
The following spacing requirements are listed in
subsection (b)(1) of section 23-0501(1) for wells drilled after that date unless another percentage
is specifically stated:
For gas pools drilled to any depth in the Onondaga reef or Oriskany formation, the spacing unit must be within 10 percent of 160 acres, with the wellbore within the target formation no less than 660 feet from any unit boundary, plus, if applicable, the number of additional acres necessary and sufficient to ensure that any horizontal wellbore within the target formation is not less than 660 feet from any unit boundary; For hydrothermal dolomite gas pools drilled from 4,000 to 8,000 feet in the fault-bounded Trenton and/or Black River formation, the spacing unit must be within 10 percent of 320 acres, with the proposed productive section of the wellbore within the target formation no less than one-half mile from any other well in another unit in the same pool and no less than 1,000 feet from any unit boundary that is not defined by a field-bounding fault, but in no event less than 660 feet from any unit boundary; For hydrothermal dolomite gas pools drilled below 8,000 feet in the fault-bounded Trenton and/or Black River formation, the spacing unit must be within five percent of 640 acres, with the proposed productive section of the wellbore within the target formation no less than one mile from any other well in another unit in the same pool and no less than 1,500 feet from any unit boundary that is not defined by a field-bounding fault, but in no event less than 660 feet from any unit boundary;
2518 Id. § 23-0101(10). 2519 Id. § 23-0503(1).
484
For shale gas pools at any depth, for a vertical well outside any existing spacing unit for the same formation, the spacing unit must be within 10 percent of 40 acres, with the wellbore within the target formation no less than 460 feet from any unit boundary; For shale gas pools at any depth, for a horizontal well outside any existing spacing unit for the same formation and with a written commitment from the well operator to drill infill wells pursuant to subdivision 4 of section 23-0503 of this title, with all horizontal infill wells in the unit to be drilled from a common well pad within three years of the date the first well in the unit commences drilling, notwithstanding the 10 percent tolerance specified in this subparagraph, the spacing unit may be up to 640 acres, with the initial horizontal wellbore or wellbores within the target formation approximately centered in the spacing unit, and no wellbore in the target formation less than 330 feet from any unit boundary; For shale gas pools at any depth, for a horizontal well outside any existing spacing unit from the same formation and in the absence of a written commitment from the well operator to drill infill wells pursuant to subdivision 4 of section 23-0503, the spacing unit must be within 10 percent of 40 acres, with the wellbore within the target formation no less than 330 feet from any unit boundary plus the number of additional acres necessary and sufficient to ensure that the wellbore within the target formation is not less than 330 feet from any unit boundary; For all other gas pools where the majority of the pool is above 4,000 feet, the spacing unit must be within 10 percent of 80 acres, with the wellbore within the target formation no less than 460 feet from any unit boundary, plus, if applicable, the number of additional acres necessary and sufficient to ensure that any horizontal wellbore within the target formation is not less than 460 feet from any unit boundary; For all other gas pools where the majority of the pool is 4,000 to 6,000 feet deep, the spacing unit must be within 10 percent of 160 acres, with the wellbore within the target formation no less than 660 feet from any unit boundary, plus, if applicable, the number of additional acres necessary and sufficient to ensure that any horizontal wellbore within the target formation is not less than 660 feet from any unit boundary; For all other gas pools where the majority of the pool is 6,000 to 8,000 feet deep, the spacing unit must be within 10 percent of 320 acres, with the wellbore within the target formation no less than 1,000 feet from any unit boundary, plus, if applicable, the number of additional acres necessary and sufficient to ensure that any horizontal wellbore within the target formation is not less than 1,000 feet from any unit boundary;
485
For all other gas pools where the majority of the pool is below 8,000 feet, the spacing unit must be within five percent of 640 acres, with the wellbore within the target formation no less than 1,500 feet from any unit boundary, plus, if applicable, the number of additional acres necessary and sufficient to ensure that any horizontal wellbore within the target formation is not less than 1,500 feet from any unit boundary; For oil pools in the Bass Island, Trenton, Black River, Onondaga reef or other oil-bearing reefs at any depth, the spacing unit must be within 10 percent of 40 acres, with the wellbore within the target formation no less than 460 feet from any unit boundary, plus, if applicable, the number of additional acres necessary and sufficient to ensure that any horizontal wellbore within the target formation is not less than 460 feet from any unit boundary; and For all other oil pools at any depth, the wellbore within the target formation must be at least 165 feet from any lease boundary.2520
Wells drilled as oil wells may not produce natural gas before the spacing unit is modified
pursuant to gas spacing provisions.
2521
[3] – Minimum Operator Control.
An order issued by the Department compelling operations will not be effective unless and
until the unit operations plan is approved in writing by owners of 60 percent or more of the
interests, and by a like percentage of the owners of one-eighth royalty interests, and the
Department has found that the plan has been approved by the requisite number of owners. If the
plan has not been approved by the requisite percentage within six months of the order, the order
will then be revoked by the Department.2522
[4] – Review of Election Rights/Options.
Non-participating owners have 30 days after receipt of the proposed order for integration
to elect to participate.2523 The election form they will receive as part of their notice2524
include the operator’s good faith estimate of costs. Uncontrolled owners who do not make a
timely election to participate or who do not make the requisite payments will be integrated as an
integrated royalty owner, described further below.2525
[a] Non-Participating Owners.
An “integrated non-participating owner” or “non-participating owner” is an owner who
chooses to reimburse the operator from production proceeds for the owner’s proportionate share
of the costs of the well.2526 Once the operator has recouped the portion of the owner’s costs for
the well plus a risk penalty,2527 the owner is then entitled to his or her full share of the production
attributable to his or her proportionate interest.2528
Where the tract is under lease, a royalty is deducted from the non-participating owner’s
share of production, without being subject to charges and costs.
2529
(i) During the recovery of the actual well costs, 1/16 or 6.25%; (ii) During the recovery of the first 100% of the risk penalty, 3/32 or 9.38%; (iii) During the recovery of the second 100% of the risk penalty, the lowest royalty fraction set forth in an existing lease in the unit, but no less than 1/8 or 12.5%.
The royalty is calculated
separately and paid to the non-participating owner on the royalty owner’s behalf under the
following allocations:
2530
The lessee is not relieved of any obligations to pay any remaining royalty and/or overriding
royalty owed under the terms of its lease.
2531
[b] Integrated Participating Owner.
2525 Id. 2526 Id. § 23-0901(3)(a)(1). 2527 Id. “Risk penalty” is defined as the percentage applied to well costs to reimburse the operator for the risk associated with exploration and development. Id. § 23-0901(3)(a)(4). The risk penalty is equal to two hundred percent of the share of the actual well costs allocated to the owner. Id. § 23-0901(3)(a)(1). 2528 Id. § 23-0901(3)(a)(1). 2529 Id. 2530 Id. 2531 Id.
487
An “integrated participating owner” or “participating owner” is a party who chooses to
participate in the initial well, pay the costs associated with participating up front, and comply
with any and all requirements for participation.2532
[c] Integrated Royalty Owner.
An integrated royalty owner is an owner who chooses to be an integrated royalty owner
or who does not choose to operate as either of the previously-discussed options (the state-
mandated default participation interest).2533 This type of owner receives a royalty equaling the
lowest royalty of the existing leases in the unit, but not to an amount less than one-eighth.2534 An
integrated royalty owner has no obligation to the well operator or other owners for charges,
taxes, or fees associated with operating the well and is also insulated from claims for personal
injury or property damage related to the drilling and operation of the well.2535
§ 34.01 Analysis of North Carolina Regulatory Framework. [1] – Name of Governing Body.
The North Carolina Department of Environment and Natural Resources (“the
Department”) has the authority to regulate oil and gas production under the state’s Oil and Gas
Conservation Act (“the Act”).2536
[2] – Membership on the Governing Body.
There is little detail available about the membership of the Department relevant to oil and
gas regulation. 2537 In general, the Secretary leads the Department. 2538 The Secretary is
appointed by the Governor and has the power to appoint Deputy Secretaries. 2539 The
Department is organized as the “Secretary's office and staff, administration, divisions, programs,
regional offices, boards, councils and commissions.”2540
[3] – Scope of Authority.
The Act grants the Department jurisdiction and authority “over all persons and property
necessary to administer and enforce” its provisions.2541 The Act specifies its public policy goals
of “prohibiting waste and compelling ratable production[,] and authorizing regulations for the
protection of the environment. 2542 Waste, which is expressly prohibited, 2543 is defined as
“‘physical waste,’ as that term is generally understood in the oil and gas industry.” 2544
2536 N.C. Gen. Stat. § 113-378 (2011).
In
addition, waste includes the following:
2537 Id. § 143B-279.4. 2538 Id. 2539See NCDENR, North Carolina Department of Environment and Natural Resources, http://www.enr.state.nc.us/html/Sec_Freeman.html (last visited June 10, 2011) (discussing the appointment of the current Secretary of the Department). 2540 Id. 2541 N.C. Gen. Stat. § 113-391 (2011). 2542 Id. § 113-382. 2543 Id. § 113-390. 2544 Id. § 113-389(14).
489
(a) The inefficient, excessive or improper use or dissipation of reservoir energy; and the locating, spacing, drilling, equipping, operating or producing of any oil or gas well or wells in a manner which results, or tends to result, in reducing inefficiently the quantity of oil or gas ultimately to be recovered from any pool in this State; (b) The inefficient storing of oil, and the locating, spacing, drilling, equipping, operating or producing of any oil or gas well or wells in a manner causing, or tending to cause, unnecessary or excessive surface loss or destruction of oil or gas; (c) Abuse of the correlative rights and opportunities of each owner of oil and gas in a common reservoir due to non-uniform, disproportionate, and unratable withdrawals causing undue drainage between tracts of land; (d) Producing oil or gas in such manner as to cause unnecessary water channeling or coning; (e) The operation of any oil well or wells with an inefficient gas-oil ratio; (f) The drowning with water of any stratum or part thereof capable of producing oil or gas; (g) Underground waste however caused and whether or not defined; (h) The creation of unnecessary fire hazards; (i) The escape into the open air, from a well producing both oil and gas, of gas in excess of the amount which is necessary in the efficient drilling or operation of the well; or (j) Permitting gas produced from a gas well to escape into the air. 2545
The Department has the authority and the duty to determine whether or not waste exists or is
imminent within its jurisdiction.
2546 Pursuant to waste prevention, the Department may collect
data; investigate, inspect, and examine properties and records; test oil and gas wells; hold
hearings; require the maintenance of records and reports; and any take other action as may be
reasonably necessary to enforce Act.2547
2545 Id.
In particular, the Department may enact and enforce
regulations to govern proper drilling and operating methods, limitation and proration of oil and
gas production, spacing of wells, establishment of drilling units, and the pooling and unitization
2546 Id. §§ 113-391(b). 2547 Id.
490
of oil and gas interests.2548 Although the Act does not specify detailed requirements to obtain a
drilling permit, no well may be drilled for oil or gas without providing notice to the Department
by formal registration in a manner required by the Department.2549
[4] – Process for Pooling & Matters Covered.
[a] – Drilling Units.
In order to prevent waste and avoid the drilling of excessive wells, the Department may,
after notice and a hearing, establish a drilling unit or units for each pool.2550 A “drilling unit” is
that “area which can be efficiently and economically drained by one well.”2551 The Department
has discretion as to the size and shape of each drilling unit and may set such dimensions as
necessary to prevent any producer within the pool from procuring “more than his just and
equitable share of oil and gas.”2552 The Act defines a producer’s “just and equitable share” as
“that part of authorized production from the pool . . . which is substantially in the proportion that
the quantity of recoverable oil and gas in the developed area of his tract . . . bears to the
recoverable oil and gas in the total developed area in the pool.”2553
[b] – Authority to Integrate Production.
When multiple, separately-owned tracts are embraced within an existing drilling unit,
“the owners thereof may agree validly to integrate their interests and to develop their lands as a
drilling unit.”2554
2548 Id. § 113-391(c).
In the absence of such agreement, the Department may “require such owners
to do so and to develop their lands as a drilling unit” in order to prevent waste or avoid
2549 See id. § 113-395; see also 15A N.C. Admin. Code 05D.0104-05 (2011). 2550 N.C. Gen. Stat. § 113-392(c) (2011). 2551 15A N.C. Admin. Code 05D.0103(2) (2011). 2552 N.C. Gen. Stat. § 113-392(c) (2011). 2553 Id. § 113-392(d). 2554 Id. § 113-393(a).
491
unnecessary drilling.2555 A pooling order may only be issued after notice and a hearing and must
provide just and reasonable terms to “afford . . . the owner of each tract the opportunity to
recover or receive his just and equitable share of the oil and gas in the pool without unnecessary
surface.”2576 However, the Department may prescribe rules or issue an order governing the
reasonableness of horizontal variation as it sees fit.2577
[6] – Election.
The Act does not discuss election rights or other requirements for the treatment of non-
consenting working interest owners subject to a pooling order.
2576 N.C. Gen. Stat. § 113-393(d) (2011). 2577 Id.
496
§ 35.01 Analysis of North Dakota Regulatory Framework. [1] – Name of Governing Body. The Industrial Commission (hereinafter the “Commission”) is vested with jurisdiction
over oil and gas resources in North Dakota.2578
[2] – Membership on the Governing Body.
The members of the Commission are the Governor, the Attorney General, and the
Agriculture Commissioner of the State.2579 The Governor is the Chairman, and a quorum for the
transaction of business consists of the Governor and one additional member.2580 The Attorney
General serves as general counsel.2581 The Industrial Commission has the authority to appoint a
Director of Mineral Resources who serves at the pleasure of the Commission.2582
[3] – Scope of Authority.
“The Industrial Commission has very broad, general jurisdiction and authority to regulate
production of oil and gas and oil and gas industry in North Dakota.”2583 The Act for the Control
of Gas and Oil Resources (hereinafter the “Act”)2584 vests the Commission with its various duties
and powers.2585
[It is] in the public interest to foster, to encourage, and to promote the development, production, and utilization of natural resources of oil and gas in the state in such a manner as will prevent waste; to authorize and to provide for the operation and development of oil and gas properties in such a manner that a greater ultimate recovery of oil and gas be had and that the correlative rights of all owners be fully protected; and to encourage . . . the greatest possible economic recovery of oil and gas be obtained within the
The Act states that its public policy is as follows:
2578 N.D. Cent. Code § 38-08-01 (2010). 2579 See N.D. Indus. Comm’n, Department of Mineral Resources Oil & Gas Division Home Page, https://www.dmr.nd.gov/oilgas/ (last visited May 28, 2011). 2580 Id. 2581 Id. 2582 N.D. Cent. Code § 38-08-4.2 (2010). 2583 Amerada Hess Corp. v. Furlong Oil & Minerals Co., 348 N.W.2d 913 (1984). 2584 N.D. Cent. Code § 38-08-01 to -23 (2010). 2585 Id. § 38-08-04.
497
state to the end that the landowners, the royalty owners, the producers, and the general public realize and enjoy the greatest possible good from these vital natural resources.2586
North Dakota law also states that the Commission has jurisdiction over “all persons and
property, public and private, necessary to enforce effectively the provisions of [the Act].”
2587
Specifically, it must investigate appropriately to determine whether waste exists or is imminent
or if other facts exist that justify Commission action. 2588
(a) Physical waste, as that term is generally understood in the oil and gas industry.
“Waste” is defined by statute as
follows:
(b) The inefficient, excessive, or improper use of or the unnecessary dissipation of reservoir energy. (c) The locating, spacing, drilling, equipping, operating or producing of any oil or gas well or wells in a manner which causes, or tends to cause, reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or which causes or tends to cause unnecessary or excessive surface loss or destruction of oil or gas. (d) The inefficient storing of oil. (e) The production of oil or gas in excess of transportation or marketing facilities or in excess of reasonable market demand.2589
The Commission has authority, among other things, to require payment of bonds and fees
conditioned upon compliance with this Act;
2590 to regulate drilling, production, plugging, and
spacing of wells;2591 to limit and allocate production from any pool or field;2592 and to adopt and
enforce rules and orders to effectuate the purposes and intent of this Act. 2593
2586 Id. § 38-08-01.
Finally, the
Commission has the authority to determine market demand and regulate the amount of allowable
then the owners who pay for that nonparticipating owner’s share of drilling may recover the
nonparticipating owner’s costs plus a risk penalty.2622
(a) If the nonparticipating interest is derived from a lease or other development contract, the penalty is 200 percent of the nonparticipating owner’s share of reasonable actual costs of drilling and completing the well and may be recovered out of production, exclusive of any royalty or overriding royalty.
The risk penalty is as follows:
(b) If the nonparticipating interest is not subject to a lease or other development contract, the risk penalty is 50 percent of the nonparticipating owner’s share of reasonable actual drilling and completion costs and may be recovered out of production, exclusive of any royalty. (c) The owner paying for the nonparticipating owner’s share of costs may recover from that nonparticipating owner a risk penalty only if the owner has made an unsuccessful, good-faith attempt to have said nonparticipating owner execute a lease or to have that owner participate in the risk.2623
A person to whom such drilling expenses are owed may obtain a lien on the debtor’s interest in
the production by filing with the register of deeds in the county in which the property is located
an affidavit denoting the amount due and the debtor’s interest in production.
2624
[c] – Unitization of Interests within a Pool or Pools.
The Commission is vested with the jurisdiction and authority to order plans of
unitization, “which are fair, reasonable, and equitable and which are necessary or proper to
protect, safeguard, and adjust the respective rights and obligations of the several persons
affected.”2625 A unitization plan containing operating charges which include “any part of district
or central office expense other than reasonable overhead charges” will not be considered fair and
reasonable.2626
2622 Id. § 38-08-08(3).
The Commission must also make and enforce the orders that are necessary and
for the common good, resulting in the general advantage of owners within the common source of
supply or portion thereof.2632
If the Commission makes the required findings, it will issue an order that must be
equitable and reasonable and that is “necessary or proper to protect, safeguard, and adjust the
respective rights and obligations of the several persons affected, including royalty owners,
owners of overriding royalties, oil and gas payments, carried interests, mortgagees, lien
claimants, and others, as well as the lessees.”
2633 The order must define the area of the pool or
portion of the pool and must prescribe a detailed unitization plan.2634
(1) A provision providing for the efficient unitized management of the unit area for the recovery of oil and gas from the common source of supply, including a provision allowing the working interest owners to vote to determine the unit operator.
The unitization plan should
be suited to the needs of the particular unit based on the facts, but must include the following:
(2) A provision determining production allocation among the several tracts so to allow all to receive each party’s fair and equitable share of unit production or proceeds therefrom. The fair portion is the value of each tract for oil and gas purposes and its contributing value to the unit in relation to like values of other tracts in the unit, taking into account acreage, oil and gas quantity recoverable therefrom, probable productivity in the absence of unit operations, and other relevant factors. (3) The manner in which operations will be financed and the basis, terms, and conditions on which the costs will be apportioned among tracts and interests, including a reasonable provision for carrying or financing owners who are unable to meet the upfront financial obligations of unit operations and a risk penalty. The risk penalty is the same as that for pooled spacing units, supra. (4) The basis upon which wells and properties of the lessees in the unit area are to be used for unit operations, including the method of determining compensation or equalizing the investment of the lessees. (5) The creation of an operating committee to have overall management and control of the unit and its business and such other
subcommittees, boards, or officers as may be necessary to manage the unit. (6) The time when the unitization becomes effective. (7) The time when the unit must be or may be dissolved and its affairs wound up.2635
Units created under section 38-08-09.1 through 38-08-09.16 of the Act must be limited to
a single pool.
2636 Section 38-08-09.17 also gives the Commission the authority to promulgate
orders unitizing two or more pools or parts thereof that are separated vertically in one field,
termed a “unit source of supply.”2637 The process for unitizing a unit source of supply is to be
the same as the process to unitize a common source of supply.2638
Orders of the Commission do not become effective until the unitization plan has been
signed or ratified in writing by the persons who will be responsible for at least 60 percent of the
costs of unit operations and by the owners of at least 60 percent of the royalty interests, not
including overriding royalties, production payments, and other interests taken from the working
interest.
2639 In addition, if more than one person is obligated to pay unit costs, at least two
unaffiliated such persons and at least two royalty holders are required to be voluntary parties.
The Commission must then make a finding either in the unit order or in a later order that the
required approval has been given.2640 If the required approval has not been given within six
months from the date the order, it becomes void.2641
Operations conducted on and production obtained from a unit is deemed to be conducted
on and produced from each separately owned tract. Such operations are considered fulfillment
of all oil and gas mining leases on lands included in the unit area. However, if the lease also
The N.D.R.C.P. asserts that service may be given by hand delivering notice to the person
in need of notification or by leaving it conspicuously at that person’s office or with a person of
suitable age at that person’s home.2648 Additionally, service is complete upon mailing to the
person’s last known address or by sending it via a third-party commercial carrier to the last
known address.2649 For parties with no known addresses, the court may allow the sender to leave
the notice with the clerk of court.2650 Parties may also agree to other forms of notice, e.g.,
electronic notice, if consented to in writing.2651 If the Commission decides to give notice by
personal service, it should be in the manner provided for in the law for service of summons in the
civil action in state court. If the proceeding does not involve a complaint and a specific
respondent, the notice must be given at least 15 days before the hearing.2652
Any party adversely affected by a Commission order may file a written petition for
reconsideration
2653 or may appeal to district court for the county in which the well or the
property or any portion thereof is located.2654 Additionally, a right of appeal was established by
the Legislature providing that any person adversely affected by a unitization order of the
Commission may appeal from such order to the district court of the county in which the land or a
part thereof involved in the unit lies.2655 At the time of filing of the notice of appeal, if an
application for the suspension of the order is filed, the Commission may enter an order
suspending the order complained of and fixing the amount of a supersedeas bond.2656
2648 N.D. R. Civ. P. § II, Rule 5(b)(2)(A)–(B).
Within 10
2649 Id. at § II, Rule 5(b)(2)(C)–(D). 2650 Id. at § II, Rule 5(b)(2)(E). 2651 Id. at § II, Rule 5(b)(2)(F)–(G). 2652 N.D. Cent Code § 38-08-11(3) (2010). 2653 Id. § 38-08-13. 2654 Id. § 38-08-14(1). 2655 Id. § 38-08-09.16. 2656 Id. § 38-08-14(2). Such a bond must run in favor of the Commission for the use and benefit of any person who may suffer damage by reason of the suspension of the order in the event the same is affirmed by the district court. Id.
507
days after the entry of an order by the Commission which suspends the order complained of and
fixes the amount of the bond, the appellant shall file with the Commission a supersedeas bond in
the required amount and with property surety.2657 Upon approval of the bond, the order of the
Commission suspending the order complained of is effective until its final disposition upon
appeal.2658 If the order of the Commission is not superseded, it must continue in force as if no
appeal was pending, unless a stay is ordered by the district court to which the appeal is taken.2659
[5] – Matters Covered.
[a] Number of Wells.
The North Dakota rules and regulations state that no more than one well will be drilled to
the same pool on any drilling unit, except by order of the Commission.2660
[b] Spacing of Wells/Depth.
As previously mentioned, the Industrial Commission has authority to regulate well
spacing. 2661 Spacing units’ size and shape should result in efficient and economical pool
development.2662 The Commission may establish spacing units for a pool, which must be of
uniform size and shape for the entire pool. 2663 In the absence of a Commission order
determining the unit spacing for pools, the N.D. regulations contain default spacing
waive the deviation test for shallow gas wells if the Director is satisfied that waiver is necessary.
Otherwise, if the deviation from the vertical is greater than five degrees, the Director may require
the hole be straightened.2703
Waiver may also be given by the Director when deviation is needed in order “to sidetrack
junk in the hole, straighten a crooked hole, control a blowout, or if the necessity therefor can be
demonstrated to the director’s satisfaction.”
2704 The Director may also grant permits to allow for
directional drilling. If the Director denies the permit request for deviation from the vertical, he
must give reasons therefor, which decision may be appealed to the Commission.2705
[5] – Options.
North Dakota law provides that operators may not receive a risk penalty from
nonparticipating owners unless they first provide such owners the opportunity to participate in
the risk and costs.2706
[a] Pooled Interests.
Owners of interest may not recover the risk penalty allowed under section 38-08-08 of
the code unless the owners give a written invitation to participate in the risk and costs of drilling
to the owners from whom the penalty is sought.2707
(1) The location of the proposed or existing well and its proposed depth and objective zone; (2) An itemization of the estimated costs of drilling and completion; (3) The approximate date upon which the well was or will be spudded or reentered; (4) A statement indicating the invitation must be accepted within thirty days of receiving it; (5) Notice that the participating owners plan to impose a risk penalty and that the nonparticipating owner may object to
the risk penalty by either responding in opposition to the petition for a risk penalty, or if no such petition has been filed, by filing an application or request for hearing with the commission.2708
Also, if the nonparticipating owner’s interest is not covered by a lease or other development
contract, the owner seeking a risk penalty must make a good-faith attempt to have the unleased
owner execute a lease.
2709
Both the invitation to participate and the election must be served personally, by mail
requiring signed receipt or by overnight service requiring signed receipt. Failure to accept such
mail constitutes service.
2710 Elections must be in writing and received by the offering owner
within 30 days of the participating party’s receipt of the invitation. 2711 Elections are only
binding upon the electing party if the well is spudded or reentry operations are commenced on or
prior to 90 days after the date the inviting owner set as the date upon which a response must be
received or prior to the drilling permit expires. If the election lapses, the risk penalty may only
be obtained if the owner again complies with these requirements.2712
[b] Unit Operations.
Owners of interest may not recover the risk penalty allowed under section 38-08-09.4 of
the code unless the owners give a written invitation to participate in the unit expense to the
owners from whom the penalty is sought. 2713
(1) A description of the proposed unit expense, including the location, objectives, and plan of operation; (2) An itemization of the estimated costs; (3) The approximate date upon which the proposal was or will be commenced; (4) A statement indicating the invitation must be accepted within thirty days of receiving it; (5)
Notice that the participating owners plan to impose a risk penalty and that the nonparticipating owner may object to the risk penalty by either responding in opposition to the petition for a risk penalty, or if no such petition has been filed, by filing an application or request for hearing with the commission.2714
Both the invitation to participate and the election must be served personally, by mail
requiring signed receipt or by overnight service requiring signed receipt. Failure to accept such
mail constitutes service.
2715 Elections must be in writing and received by the offering owner
within 30 days of the participating party’s receipt of the invitation. 2716 Elections are only
binding upon the electing party if the unit expense is commenced within 90 days after the date
the inviting owner set as the date upon which a response must be received or prior to the drilling
permit expires. If the election lapses, the risk penalty may only be obtained if the owner again
complies with these requirements.2717
An invitation to participate in unit expenses that cover monthly operating expenses will
be effective for all of those monthly operating expenses for five years if the expense identified in
the invitation is commenced within 90 days after the date set as the date upon which a response
must be received.
2718
Finally, the Commission may include in its pooling order requirements that relate to the
invitation and the election to participate. If the Commission does so, the pooling order controls
to the extent it is inconsistent with the rules in Administrative Code section 43-02-03-16.3.
develop resources and to protect correlative rights.2732 Further, the Chief, upon its own motion
or upon application by 65 percent of the owners of land overlying a pool, must hold a hearing to
determine whether unit operation of the pool is necessary. The Chief may issue an order for unit
operations if it finds that unit operation is “reasonably necessary to increase substantially the
ultimate recovery of oil and gas, and the value of the estimated additional recovery of oil or gas
exceeds the estimated additional cost incident to conducting such operation.”2733
[4] – Process for Pooling and Matters Covered.
[a] Permitting Process.
Ohio Revised Code section 1509.05 lists the requirements to obtain a permit to drill,
reopen, convert, or plug back a well. No person is permitted to drill a new well, deepen an
existing well, reopen a well, convert a well to any use other than its original purpose, or plug
back a well to a source of supply different from the existing pool, without a permit. This permit
is issued by the Chief of the Division of Mineral Resources Management. Until the original
permit, or a photocopy, is posted in a conspicuous and easily-accessible place at the well site, the
activities cannot occur. This permit shall be displayed at all times.
Ohio Revised Code section 1509.06 states all of the requirements for filing a permit. The
permit must state the following:
(1) The name and address of the owner and, if a corporation, the name and address of the statutory agent; (2) The signature of the owner or the owner's authorized agent. When an authorized agent signs an application, it shall be accompanied by a certified copy of the appointment as such agent; (3) The names and addresses of all persons holding the royalty interest in the tract upon which the well is located or is to be drilled or within a proposed drilling unit;
2732 Id. § 1509.27. 2733 Id. § 1509.28(A).
520
(4) The location of the tract or drilling unit on which the well is located or is to be drilled identified by section or lot number, city, village, township, and county; (5) Designation of the well by name and number; (6) The geological formation to be tested or used and the proposed total depth of the well; (7) The type of drilling equipment to be used; (8) If the well is for the injection of a liquid, the identity of the geological formation to be used as the injection zone and the composition of the liquid to be injected; (9) For an application for a permit to drill a new well within an urbanized area, a sworn statement that the applicant has provided notice by regular mail of the application to the owner of each parcel of real property that is located within five hundred feet of the surface location of the well and to the executive authority of the municipal corporation or the board of township trustees of the township, as applicable, in which the well is to be located. In addition, the notice shall contain a statement that informs an owner of real property who is required to receive the notice under division (A)(9) of this section that within five days of receipt of the notice, the owner is required to provide notice under section 1509.60 of the Revised Code to each residence in an occupied dwelling that is located on the owner's parcel of real property. The notice shall contain a statement that an application has been filed with the Division of Mineral Resources Management, identify the name of the applicant and the proposed well location, include the name and address of the Division, and contain a statement that comments regarding the application may be sent to the Division. The notice may be provided by hand delivery or regular mail. The identity of the owners of parcels of real property shall be determined using the tax records of the municipal corporation or county in which a parcel of real property is located as of the date of the notice; (10) A plan for restoration of the land surface disturbed by drilling operations. The plan shall provide for compliance with the restoration requirements of division (A) of section [1509.07.2] of the Revised Code and any rules adopted by the chief pertaining to that restoration; (11) A description by name or number of the county, township, and municipal corporation roads, streets, and highways that the applicant anticipates will be used for access to and egress from the well site; and (l2) Such other relevant information as the chief prescribes by rule.2734
2734 Id. § 1509.06 (A)(1)–(12).
521
Every application must also be accompanied by a map, on a scale not smaller than 400
feet to the inch, prepared by an Ohio registered surveyor.2735
The Chief may not issue a permit less than ten days after the filing of the application, but
should issue a permit within 21 days of the filing of the application, unless the Chief waives that
timeline for expedited review.
The Chief will also prepare a
weekly circular for each county to show each drilling site.
2736 If the well is in an urbanized area, the Chief shall not issue a
permit for at least 18 days after the filing of the application.2737 An applicant is permitted to file
a request with the Chief for expedited review if the well is not to be located in a gas storage
reservoir. A request for expedited review will also cost an additional $250.00. If the Chief does
not deny this request, a permit shall be issued within seven days of the expedited application.2738
The Chief is permitted to deny a permit if he believes that there is a substantial risk that
the activities will violate a provision of this chapter or will present an imminent danger to public
health or safety or damage to the environment.
2739 The fees associated with a permit, except a
permit to plug back an existing well, are as follows: (a) $500.00 to conduct activity in a township
with a population of 10,000 or less; (b) $750.00 if the township has a population greater than
10,000, but less than 15,000; (c) $1,000.00 if the township has a population of 15,000 or more, a
municipal organization regardless of population. 2740 If the application requires mandatory
pooling, then an additional $5,000 will be added to the fee.2741
§ 37.01 Analysis of Oklahoma Regulatory Framework.
[1] – Name of Governing Body.
By statute, the Oklahoma Corporation Commission (“Commission”) maintains legal
authority to propose and implement rules regarding the pooling of oil and gas interest in
Oklahoma. 2802 However, the Conservation Division (“Division”) is the Division of the
Commission charged with the administration and enforcement of the rules and regulations
established by the Commission.2803
[2] – Membership of Governing Body.
The Commission consists of three members, who are elected for staggered six-year terms.
If a vacancy occurs in the Commission, the Governor of Oklahoma appoints a new member to
fill the vacancy. The appointee serves until the next general election, at which time the seat is
placed on the ballot and an election is held. The newly-elected member will sit as a member for
the remainder of the unexpired portion of the term. The qualifications to stand for election to the
Commission are fairly minimal, with one important exception. To be qualified to stand for
election, an individual must be at least 30 years old, must have been a resident of Oklahoma for
at least two years, and, most importantly, must not have any direct or indirect interest in any
entity regulated by the Oklahoma Corporation Commission. This final requirement is a
substantial impediment to many potential candidates as the Commission’s jurisdiction extends
well beyond the regulation of oil and gas issues and includes other entities identified as public
utilities in Oklahoma. 2804
2802 Okla. Stat. tit. 52, § 87.1(a) (2010).
With regard to its oversight of the oil and gas industry, the
2803 26 Okla. Reg. 5 (July 1, 2009). 2804 The Oklahoma Corporation Commission is essentially the public utilities commission of Oklahoma and regulates not only oil and gas, but also trucking and railroad companies, telecommunications, water, heat, light, and power companies, and, interestingly, cotton gins. See Okla. Stat. tit. 17, § 1 (2010).
535
Commission has established the Oil and Gas Department to help administer the Commission’s
rules and regulations.2805
The Conservation Division consists of
[a] Director of Conservation, who, in addition to the [foregoing] duties and functions . . ., shall have overall responsibility, supervision and direction of the activities of the Conservation Division and the administration and enforcement of the rules, regulations and orders of the Commission relating to oil and gas conservation and the prevention of pollution. The statutes require that the Director of Conservation be a college graduate with a Bachelor's Degree and needs to have five years of experience in a supervisory capacity in an administrative or personnel management position to get the job.
Additionally, the Division consists of the following members: (1) a manager of pollution
abatement, (2) a manager of field operations, (3) a deputy director of conservation, (4) a manager
of technical services, (5) a district managers, (6) assistant district managers, (7) oil and gas field
inspectors, (8) an assistant manager of field operations, (9) an oil and gas safety specialist, and
(10) an oil and gas inspector supervisor.2806
[3] – Scope of Authority.
The Commission has general authority with regard to the regulation of oil and gas under
Oklahoma Statutes title 52, section 86.1, et seq. Specifically, the Commission has, “[i]n all
matters pertaining to the making, issuing and enforcement of its orders, rules and regulations”
under this Act, the power and authority as follows:
(1) [o]f visitation and of a court of record; (2) [t]o administer oaths; (3) [t]o compel attendance of witnesses; (4) [t]o compel the production of books and records; . . . (6) [t]o punish as for contempt any disobedience or violation of the provisions of this act and of any of its orders, rules, regulations, and judgments made or rendered by it under and in pursuance of the provisions of this act; (7) [t]o enforce the provisions of this act, and compliance with any
of its orders, rules, regulations or judgments by appropriate process, and by shut down orders, ordering and directing the shutting down or discontinuance of production of oil from any well or wells of or operated by the offender with respect to which complaint has been made; and by orders or writs remedial or otherwise necessary or proper, to carry into effect its orders, rules and regulations; [and] (8) [t]o appoint or designate one of its agents or employees or one of the deputies to the Proration Umpire to act as Marshal of the Commission . . . .2807
Waste, within the Act, is prohibited. The Commission has the duty to reduce waste. To
do so, it has the authority to make rules, regulations, and orders for the prevention of such waste.
In addition to its ordinary meaning, waste, “when applied to gas, shall include” the following:
(1) the inefficient or wasteful utilization of gas in the operation of oil wells drilled to and producing from a common source of supply; (2) the inefficient or wasteful utilization of gas from gas wells drilled to and producing from a common source of supply; (3) the production of gas in such quantities or in such manner as unreasonably to reduce reservoir pressure or unreasonably to diminish the quantity of oil or gas that might be recovered from a common source of supply; (4) the escape, directly or indirectly, of gas from oil wells producing from a common source of supply into the open air in excess of the amount necessary in the efficient drilling, completion or operation thereof . . .; (5) the escape, blowing or releasing, directly or indirectly, into the open air, of gas from wells productive of gas only . . .; and (6) the unnecessary depletion or inefficient utilization of gas energy contained in a common source of supply.
In order to prevent waste, the Commission shall “limit the production of gas from wells
producing gas only to a percentage of the capacity of such wells to produce.”2808
upon a proper application and notice . . . and after a hearing as provided in said notice, shall have the power to establish well spacing and drilling units of specified and approximately uniform
To assist in
such, the Commission has the specific authority to regulate and approve pooling and unitization
under Oklahoma Statutes tit. 52, § 87.1, which provides that the Commission,
2807 Id. § 98. 2808 Id. § 86.3.
537
size and shape covering any common source of supply, or prospective common sources of supply of oil and gas within the state of Oklahoma.2809
However, the Commission
may authorize the drilling of an additional well or wells on any spacing and drilling unit or units or any portion or portions thereof or may establish, reestablish, or reform well spacing and drilling units of different sizes and shapes when the Commission determines that a common source of supply contains predominantly oil underlying an area or areas and contains predominantly gas underlying a different area or areas;
and “shall adjust allowable production within [a] common source of supply, or any part thereof,
and take such actions as may be necessary to protect the rights of interested parties.”2810 The
ability of the Commission to grant exceptions to general rules in specific instances has been
upheld by courts on several occasions.2811
The Division has the duty to administer and enforce (1) the statutes of this State; (2) the
rules, regulations, and orders of the Commission relating to (a) the conservation of oil and gas
and (b) the prevention of pollution in connection with, among others, the exploration, drilling,
and production of oil and gas; and (3) enforce the applicable provisions of the Natural Gas Policy
Act of 1978.
2812
The Division, among other rights, duties, and authorities, has the right at all times to go
upon and inspect any “oil and gas properties [or] pipelines . . . for the purpose of making any
2809 Id. § 87.1(a). “It shall not be necessary to publish such order, rule or regulation, after its adoption or promulgation by the Commission, before it shall go into effect, nor shall it be necessary to publish any such order, rule or regulation in each subsequent annual report of the Commission. Provided, that the Corporation Commission shall not under the provisions of this act make any order establishing a well spacing or drilling unit.” 2810 Id. 2811 See, e.g., S. Okla. Owners Ass’n v. Stanolind Oil & Gas Co., 266 P.2d 633 (Okla. 1954). 2812 26 Okla. Reg. 17 (July 1, 2009).
538
investigations or tests to ascertain whether the rules, regulations, and orders of the Commission
are being complied with, and shall report to the Commission any violation thereof.”2813
Additionally, the Division has access to all well records, regardless of where the records
are kept. All companies, operators, drilling contractors, drillers, service companies, or other
persons shall permit any authorized employee of the Commission to come upon any lease or
property operated or controlled by them and to inspect the records of wells.
2814
[4] – Pooling Process.
[a] Drilling and Spacing Units.
All rules of general application are promulgated to prevent waste, assure the greatest
ultimate recovery from the reservoirs of this state, protect the correlative rights of all interests,
and to prevent pollution. The rules shall be effective throughout the State of Oklahoma and be in
force in all pools except as amended, modified, altered, or enlarged in specific individual pools
by orders now in effect or hereafter issued by the Commission.2815
Drilling and spacing units are set by statute. Oklahoma set the condition that for any
person who has the right to drill into and produce from a common source of oil or natural gas
when production from such source can only be obtained under conditions constituting waste or
drainage not compensated by counterdrainage, then such person can produce only as much oil or
natural gas from a well as would be non-wasteful or not cause drainage in relation to the acreage
After a spacing order has been entered, each working interest owner2817 within the unit
has the right to drill; however, generally only one well may be drilled within the unit.2818
If a working interest owner proposes to drill within a unit and all parties are not either
(1) leased by the operator proposing to drill or (2) agreeable to the proposed drilling, the
Commission may compulsorily pool the owners’ interests. Thus, the Commission, after
application from an owner and a hearing, shall require such owners to pool and develop their
lands in the spacing unit as a unit to avoid the drilling of unnecessary wells or to protect
correlative rights.
In
Oklahoma, the mineral owners or the Commission may pool the interests or tracts within a unit.
Thus, when there are separately owned tracts of land, undivided interests, or both, embraced
within the unit, the owners of such interests or tracts may validly pool their interests or tracts,
and develop their lands as a unit.
2819
However, should the owners of separate tracts or interests embraced within a
spacing unit fail to agree upon a pooling of their interests and the drilling of a well on the unit,
and should it be established by final, unappealable judgment of a court of competent jurisdiction
that the Commission is without authority to require pooling, then the owner of each tract or
interest embraced within a spacing unit may drill on his separately owned tract. The allowable
production from each tract or interest shall be that portion of the allowable for the full spacing
unit as the area of such separately owned tract bears to the full spacing unit.
2820
[c] Application Process and Hearings.
2817 26 Okla. Reg. 223 (July 1, 2009). “Working interest” means the interest in a well entitling the owner thereof to drill for and produce oil and gas, including but not limited to the interest of a participating mineral owner to the extent set forth in Section 87.1 of Title 52 of the Oklahoma Statutes. 2818 Okla. Stat. tit. 52, § 87.1(a)–(e) (2010). The working interest holder is either a lessee or unleased owner of oil or gas within the unit. 2819 Id. § 87.1(e). 2820 Id.
540
In order to obtain approval for the establishment of a unit and to establish spacing
requirements from the Commission, the Conservation Officer of the State of Oklahoma or a
person or entity must file an application in the form of a petition with the Commission. An
applicant must establish that it (1) “owns an interest in the minerals in lands embraced within
[the] common source of supply” or (2) has “the right to drill a well for oil or gas on the lands
embraced within [the] common source of supply.”2821 An application for spacing in Oklahoma
must include a survey plat showing the intended spacing unit and any adjoining spacing units
that either (1) are proposed or (2) have already been created by order of the Commission.2822
(1) [a]n identification of the applicants and all respondents (i.e. any person or entity having an interest in the property comprising the proposed spacing unit); (2) [a]n allegation of the facts (i.e. a showing of the property ownership and the proposed spacing unit); (3) [t]he legal authority upon which the application for spacing is based; (4) [t]he relief sought (i.e. the desired creation or modification of the spacing unit); and (5) [c]ertification of service upon the respondents.
Additionally, every application must provide the following information:
2823
When an application for a unit and spacing requirements is filed, the Commission shall
give at least fifteen (15) days' notice of the hearing to be held upon such petition by one publication . . . in some newspaper of general circulation published in Oklahoma County, and by one publication . . . in some newspaper published in the county, or in each county, if there be more than one, in which the lands embraced within the application are situated.2824
In order to pool interests, an owner needs to file an application for a hearing with the
Commission. Fifteen days’ notice, by mail, shall be given by the applicant to all the owners
2821 Id. § 87.1(a). 2822 Okla. Admin. Code § 165:5-7-6 (2009). 2823 Id. § 165:5-7-1. 2824 Okla. Stat. tit. 52, § 87.1(a) (2010). “Except as to the notice of hearing on such a petition, the procedural requirements of Sections 86.1 et seq. of this title, shall govern all proceedings and hearings provided for by this section.” Id.
541
whose addresses are known or could be known through the exercise of due diligence, and shall
have a return receipt request. The applicant shall also give notice by one publication, at least
fifteen days prior to the hearing in some newspaper of general circulation published in
Oklahoma County, and in some newspaper published in the county, or in each county, if there be
more than one, in which the lands embraced within the spacing unit are situated.
The applicant shall file proof of publication and an affidavit of mailing with the
Commission prior to the hearing. 2825 An application for pooling must conform to the same
general requirements as an application for spacing.2826 As with an application for a spacing unit,
a pooling application must be served upon all respondents by regular mail.2827 If the proper
notice is made and proof thereof is filed with the Commission, a hearing will be held and the
Corporation Commission may grant a statutory pooling order.2828
Additionally, the Commission may hear such a petition if made by the Conservation
Officer of the State of Oklahoma. Upon filing a petition, the Commission must give at least
fifteen days notice by publication of a hearing on that petition.
2829 An applicant must serve a
copy of the application upon all respondents by regular mail.2830
[d ] Orders and Order Content.
2825 Id. § 87.1(e). 2826 Okla. Admin. Code § 165:5-7-1(2009). 2827 Id. 2828 According to the Commission, the administrative law judge hearing an application for a pooling order will “inquire whether the applicant has made a good faith effort to bargain with the respondents prior to filing the pooling application.” Thus, a spacing unit must be established and an attempt made to lease or otherwise acquire the interests of the owners therein before a forced pooling application can be filed. See Okla. Corp. Comm’n, Pooling, Admin. Proceedings Div., http://www.occeweb.com/ap/pooling.html (last visited April 8, 2011). 2829 Okla. Stat. tit. 52, § 87.1(a) (2010). This notice is to be published in a newspaper of general circulation in both Oklahoma County and the county or counties where the lands subject to the petition are situated. 2830 Okla. Admin. Code § 165:5-7-1 (2009).
542
After a full evidentiary hearing, the Commission can issue a spacing order creating a unit.
If no protest is made at the docket calling for a hearing, the Commission may issue a spacing
order creating a unit without a full evidentiary hearing.2831
All orders requiring such pooling shall be upon such terms and conditions as are just and
reasonable and will afford to the owner of such tract in the unit the opportunity to recover or
receive without unnecessary expense his just and fair share of the oil and gas.
2832
When the pooling order allocates the portion of the production, when produced, to the
owner of each tract or interests included in a well spacing unit, such portion shall be considered
as if produced by such owner from the separately owned tract or interest by a well drilled
thereon. Such pooling order of the Commission shall make definite provisions for the payment
of cost of the development and operation, which will be limited to the actual expenditures
required for such purpose not in excess of what are reasonable, including a reasonable charge for
supervision.
2833 The Commission is specifically authorized to provide that the owner or owners
drilling, or paying for the drilling, or for the operation of a well for the benefit of all, will be
entitled to production from such well which would be received by the owner or owners for
whose benefit the well was drilled or operated, after payment of royalty, until the owner or
owners drilling or operating the well have been paid the amount due under the terms of the
pooling order or order settling such dispute. No part of the production or proceeds accruing to
any owner of a separate interest in such unit shall be applied toward payment of any cost
properly chargeable to any other interest in said unit. 2834
2831 Id. § 165:5-13-3.1.
2832 Okla. Stat. tit. 52, § 87.1(e) (2010). 2833 In the event of any dispute relative to such costs, the Commission shall determine the proper costs after due notice to interested parties and a hearing thereon. 2834 Okla. Stat. tit. 52, § 87.1(e) (2010).
543
In order for the Commission’s unitization and unitization plan order to become effective, it
needs to be signed, or in writing ratified or approved, by lessees of record of not less than 63
percent of the unit area affected by the unitization and by owners of record of not less than 63
percent (exclusive of royalty interests owned by lessees or by subsidiaries of any lessee) of the
normal one-eighth royalty interest in and to the unit area. Additionally the Commission needs to
have made a finding either in the order creating the unit or in a supplemental order that the plan
of unitization has been so signed, ratified, or approved by lessees and royalty owners owning the
required percentage interest in and to the unit area.
Where the plan of unitization has not been so signed, ratified or approved by lessees and royalty owners owning the required percentage interest in and to the unit area at the time the order creating the unit is made, the Commission shall, upon petition and notice, hold . . . additional and supplemental hearings as may be requested or required to determine if and when the plan of unitization has been so signed, ratified or approved by lessees and royalty owners owning the required percentage interest in and to the unit area and shall, in respect to such hearings, make and enter a finding of its determination in such regard. [If the] lessees and royalty owners, or either, owning the required percentage interest in and to the unit area have not so signed, ratified or approved the plan of unitization within a period of six (6) months from and after the date on which the order creating the unit is made, the order creating the unit shall cease to be of further force and effect and shall be revoked by the Commission.2835
[e] Appeals.
A motion for a rehearing may be made by any person within ten days of the entry of an
order by the Commission. Any such motion must show the (1) the part(s) of the order sought to
be set aside or modified or from which relief is sought; (2) the specific modifications or other
relief sought; and (3) the specific grounds relied upon for relief.2836
2835 Id. § 287.5.
After the expiration of this
ten day period, any person may file an application to vacate or modify an order of the
2836 Okla. Admin. Code § 165:5-17-1 (2009).
544
Commission.2837 This application must provide the same information as the motion made within
ten days; however, this application will be treated by the Commission as a new case.2838
If an application to vacate or modify an order of the Commission is denied, the order may
be appealed to the Oklahoma Supreme Court.
2839 Such an appeal will be assigned by the
Oklahoma Supreme Court to a panel of the Oklahoma Civil Court of Appeals, which will then
hear the appeal. All appellate petitions and filings are required to be served on all parties and
upon the general counsel of the Commission.2840
[f] Royalty Interests.
The owner or owners of oil and gas rights in and under an unleased tract of land shall be
regarded as a lessee to the extent of a seven-eighths working interest and a lessor to the extent of
the remaining one-eighth interest therein.
In the event a producing well or wells are completed upon a unit where there are, or may
thereafter be, two or more separately owned tracts, each royalty interest2841
2837 Id. § 165:5-17-2.
owner shall share in
all production from the well or wells drilled within the unit, or in the gas well rental provided for
in the lease covering such separately owned tract or interest in lieu of the customary fixed
royalty, to the extent of such royalty interest owner's interest in the unit. Each royalty interest
owner's interest in the unit shall be defined as the percentage of royalty owned in each separate
tract by the royalty owner, multiplied by the proportion that the acreage in each separately owned
tract or interest bears to the entire acreage of the unit.
2838 Id. 2839 Id. § 165:5-17-5. 2840 Id. 2841 26 Okla. Reg. 13 (July 1, 2009). “Royalty interest” means the entirety of the percentage interest in production or proceeds therefrom:
(A) reserved or granted by a mineral interest owner exclusive of any interest defined as a working interest or a subsequently created interest, or (B) otherwise provided or ascribed to a mineral interest owner by statute, rule, order or operation of law.
545
§ 37.02 Types of Pooling Statutes in Oklahoma.
[1] – Mineral Distinctions.
The statutory framework governing pooling in Oklahoma is the same for oil and gas.
Within the statute and regulations, “‘[o]il’ means crude petroleum oil, and any other
hydrocarbons, regardless of gravity, which are produced at the well in liquid form by ordinary
production methods.” The statute defines “gas” as “all natural gas, including casinghead gas,
and all other hydrocarbons not defined as oil.”2842 The regulations break this meaning down
even further. Within the regulations, gas means “any petroleum hydrocarbon existing in the
gaseous phase.” Further, casinghead gas means “any gas or vapor, or both, indigenous to an oil
stratum and produced from such stratum with oil.” “Dry gas or dry natural gas means any gas
produced in which there are no appreciable hydrocarbon liquids recoverable by separation at the
wellhead.” “Condensate gas means any gas which is produced with condensate as defined as
‘condensate’”. “‘Condensate’ means a liquid hydrocarbon which: (A) [w]as produced as a
liquid at the surface, (B) [e]xisted as gas in the reservoir, and (C) [h]as an API gravity greater
than or equal to fifty degrees, unless otherwise proven.”2843
The regulations define "[c]ommon source of supply" or "pool" as follows:
that area which is underlaid or which, from geological or other scientific data, or from drilling operations, or other evidence, appears to be underlaid by a common accumulation of oil and/or gas; provided that, if any such area is underlaid, or appears from geological or other scientific data or from drilling operations, or other evidence, to be underlaid by more than one common accumulation of oil or gas or both, separated from each other by strata of earth and not connected with each other, then such area
shall, as to each said common accumulation of oil or gas or both, shall be deemed a separate common source of supply. 2844
[2] – Depth.
The Oklahoma statute differentiates between the depth of oil and gas wells. Each
different depth will have a maximum unit size (discussed in further detail below). For vertical
oil wells, the depth is split between two different criteria: a total depth of less than 4,000 feet
below the surface or a total depth of more than 4,000 feet but less than 9,000 feet below the
surface. The statute does not set specific depths for horizontal oil wells2845
[3] – Unit Size.
or horizontal and
vertical gas wells.
Within the acreage bounds set forth by the statute, the Commission has discretion in
determining unit size and shape; however, the following factors are to be taken into account in
making such a determination:
(1) [t]he lands embraced in the actual or prospective common source of supply; (2) the plan of well spacing then being employed or contemplated in said source of supply; (3) the depth at which production from said source of supply has been or is expected to be found; (4) the nature and character of the producing or prospective producing formation or formations; (5) any other available geological or scientific data pertaining to said actual or prospective source of supply which may be of probative value to [the Corporation] Commission in determining the proper spacing and well drilling unit therefor [sic], with due and relative allowance for the correlative rights and obligations of the producers and royalty owners interested therein.2846
2844 Id. Reg. 6–7.
2845 In order to qualify as a “horizontally drilled oil well,” an oil well must be drilled in a manner “in which the horizontal component of the completion interval in the geological formation exceeds the vertical component thereof,” and in which the horizontal component extends at least 150 feet in the formation. Okla. Stat. tit. 52, § 87.1(f) (2010). 2846 Id. § 87.1(c).
547
The Commission may also decrease the size of existing units or permit additional wells to be
drilled thereon “upon proper proof [at a hearing] that such modification . . . will prevent or assist
in preventing the various types of waste prohibited by statute . . . .”2847
The regulations further provide that “the drilling and spacing units within any common
source of supply of oil or gas shall be of approximately uniform size and shape.”
2848 In a
combination reservoir, the drilling and spacing units within the oil portion of the reservoir shall
be of approximately uniform size and shape, and the drilling and spacing units within the gas
portion of the reservoir shall be of approximately uniform size and shape; provided, however, the
drilling and spacing units within the gas portion of a combination reservoir along the gas-oil
contact line or transition zone may be of nonuniform size and shape.2849
The Commission has provided that standard drilling units should be either square or
rectangular, with square units containing about 10, 40, 160, or 640 acres apiece, and rectangular
units containing 20, 80, or 320 acres apiece (essentially two adjacent square units).
2850
For horizontal drilling, the appropriate unit
2851 size (see above discussion on unit size) is
determined by the length of the horizontal bore.2852
For a vertical oil well
Additionally, Oklahoma has different unit
requirements depending on the depth, mineral, and type of drilling (i.e. vertical vs. horizontal).
2853
2847 Id. § 87.1(d).
that has a total depth of less than 4,000 feet, the maximum unit area is
40 acres. For a vertical oil well that has a total depth of more than 4,000 feet but less than 9,000
2848 Id. 2849 26 Okla. Reg. 31–32 (July 1, 2009). 2850 Okla. Admin. Code § 165:10-1-22 (2009). 2851 26 Okla. Reg. 57 (July 1, 2009). “Horizontal well unit” shall mean a drilling and spacing unit established by the Commission, after application, notice, and hearing, for a common source of supply into which a horizontal well has been or will be drilled. 2852 Okla. Admin. Code § 165:10-1-37 (2009). 2853 If reservoir dewatering is used to extract oil from “reservoirs having initial water saturations at or above fifty percent (50%),” the maximum unit size is 640 acres. Okla. Stat. tit. 52, § 87.1(d) (2010).
548
feet, the maximum unit area is 80 acres. All horizontal oil wells, as well as all gas wells, can
have a maximum unit area of 640 acres. 2854
Additionally, a horizontal well unit may be established for a common source of supply
for which there are already established non-horizontal drilling and spacing units. The horizontal
well unit may include within its boundaries more than one existing non-horizontal drilling and
spacing unit for the common source of supply. Horizontal well units may also exist concurrently
with producing non-horizontal drilling and spacing units. Horizontal well units shall supersede
existing non-developed non-horizontal drilling and spacing units for the duration of the
horizontal well unit.
2855
Further, the regulatory framework in Oklahoma provides that, if a unit consists of 160
acres or more, no oil or gas leasehold outside of the unit may be considered held by production
from the unit for more than 90 days after the expiration of the primary term of the lease
thereon.
2856
[4] – Spacing.
Thus, although a pooling unit of 640 acres may be approved for natural gas, if a
leasehold is only partially within the unit, all acreage outside the unit must be held by separate
production or will be lost 90 days after the expiration of that lease’s primary term.
The statutory framework for spacing regulations differ between oil and gas; however, the
permitted location for all types of wells will be at or near the center of square spacing units and
at the center of alternate squares of rectangular spacing units.2857
2854 Plus a 10% tolerance. Additionally, if a governmental section contains more than 640 acres, the unit may “comprise the entire section.” Id. § 87.1(c).
The regulations established by
the Commission provide that a well will be deemed to be drilled within a permitted location if it
(1) Not less than 165 feet from the boundary of any standard 10-acre drilling and spacing unit or the proper square 10-acre tract within any standard 20-acre [rectangular] spacing unit. (2) Not less than 330 feet from the boundary of any standard 40-acre drilling and spacing unit or the proper square 40-acre tract within any standard 80-acre [rectangular] spacing unit. (3) Not less than 660 feet from the boundary of any standard 160-acre drilling and spacing unit or the proper square 160-acre tract within any standard 320-acre [rectangular] spacing unit. (4) Not less than 1320 feet from the boundary of any standard 640-acre drilling and spacing unit.2858
The regulations further provide that the well spacing requirements generally are as follows:
Any well drilled for oil or gas to an unspaced common source of supply 2,500 feet or more in depth shall be located not less than 330 feet from any property line or lease line, and shall be located not less than 600 feet from any other producible or drilling oil or gas well when drilling to the same common source of supply; provided and except that in drilling to an unspaced common source of supply that is less than 2,500 feet in depth, the well shall be located not less than 165 feet from any property line or lease line and not less than 300 feet from any other producible or drilling oil or gas well in the same common source of supply; provided, however, that the completed depth of the discovery well shall be recognized as the depth of the common source of supply for the purpose of this Section; provided further, when an exception to this Section is granted, the Commission may adjust the allowable or take such other action as it deems necessary for the prevention of waste and protection of correlative rights.2859
The Commission’s regulations provide that a horizontal wellbore,
from its point of entry and along any part of the lateral[,] shall be located not less than the minimum tolerance distance from the boundary of the horizontal well unit as follows: (A) Not less than 165 feet from the boundary of any 10, 20, or 40 acre horizontal well unit; (B) [n]ot less than 330 feet from the boundary of any 80 or 160 acre horizontal well unit; (C) [n]ot less than 660 feet from the boundary of any 320 acre or 640 acre horizontal drilling and spacing unit.2860
Any horizontal wellbore drilled into an unspaced common source of supply may not be
located closer to the lease line or voluntary unit or to another wellbore completed in the same
common source of supply than the tolerance distance prescribed for a well drilled in a standard
horizontal well unit as determined by the length of the horizontal component of the unspaced
horizontal wellbore.2861
The Commission may grant an exception to the standard well placement upon an
applicant showing need for such non-standard placement and after taking into consideration “the
correlative rights of all persons entitled to share in the common source of supply.”
2862
[5] – Operator Control and Participation by Owners.
There is no statutory minimum level of operator control for the acreage within a unit.
The statute provides that an unleased owner will be treated as lessee to the extent of a seven-
eighths working interest and lessor to the extent of a one-eighth royalty interest.2863 As with
most states, owner (i.e., non-operator) participation in Oklahoma appears relatively rare. 2864
Upon development of a unit, the owner of a working interest (either as an actual lessor or as an
unleased owner) may participate in one of two ways. First, the working interest owner may
contract privately with the operator developing the unit to participate by sharing in the
development, operating, and production costs. Second, in a forced pooling situation, the
Corporation Commission may provide in the forced pooling order that the unleased owner shall
be responsible for the owner’s proportional share of the costs of development and operation.2865
2861 26 Okla. Reg. 58-59 (July 1, 2009).
2862 Okla. Admin. Code § 165:10-1-24 (2009). 2863 Okla. Stat. tit. 52, § 87.1(e) (2010). 2864 Okla. Corp. Comm’n, Pooling, Admin. Proceedings Div., http://www.occeweb.com/ap/pooling.html (last visited April 8, 2011). 2865 Okla. Stat. tit. 52, § 87.1(e). The operator of a unit is granted a lien on the minerals of such an owner until the costs of development and operation are paid. Additionally, if there is any dispute over the costs, the Corporation Commission is to resolve such dispute after notice and a hearing.
551
§ 38.01 Analysis of Oregon Regulatory Framework.
[1] – Name of Governing Body.
The Department of Geology and Mineral Industries (the “Department”) oversees oil and
gas law in the State of Oregon.2866
[2] – Membership on the Governing Body.
A five-member Governing Board of citizens (“the Board”), appointed by the Governor
and confirmed by the Senate, oversees the Department. The Board sets policy and oversees
general operations. Every six years it develops a strategic plan to help guide the Department’s
mission and objectives.2867 The State Geologist acts as secretary to the Board.2868
[3] – Scope of Authority.
The Board has jurisdiction and authority over all persons and property, including tidal
submerged and submersible lands of the state necessary to enforce effectively all laws relating to
the conservation of oil and gas.2869 The Department may determine whether waste of oil or gas
exists or is imminent.2870
(a) The inefficient, excessive or improper use or dissipation of reservoir energy of any pool, or the locating, spacing, drilling, equipping, operating or producing of any oil well or gas well in a manner that results or may result in reducing the quantity of oil or gas ultimately recoverable from any pool; or,
Waste, which is prohibited under the Act, is defined as follows:
(b) The inefficient storing of oil and the locating, spacing, drilling, equipping, operating or producing of any oil wells or gas wells in a manner that causes or may cause unnecessary or excessive surface loss or destruction of oil or gas.2871
2866 Or. Rev. Stat. § 520.055 (2010).
2867 Department of Geology and Mineral Industries, Governing Board-Voice of the Public, http://www.oregon.gov/DOGAMI/portoff/GovBrd.shtmlb (last visited Jun. 6, 2011). 2868 Or. Admin. R. 632-010-0006 (2011). 2869 Or. Rev. Stat. § 520.055 (2010). 2870 Id. § 520.045. 2871 Id. § 520.005(15).
552
The Department may collect data; make investigations and inspections; examine properties,
leases, papers, books and records, including drilling records and logs; examine, check, test and
gauge oil and gas wells and tanks; hold hearings; provide for recordkeeping and reporting; and
take such action as may be reasonably necessary to enforce the applicable laws. 2872 The
Department also has the authority to issue drilling permits, which are required prior to
commencing any drilling operations within the state.2873
[4] – Process for Pooling & Matters Covered.
[a] Spacing Units.
If necessary to prevent waste, protect correlative rights, or avoid unnecessary drilling of
excessive wells, the Board will establish spacing units for a pool or field.2874 Under the Act,
“spacing units . . . shall be of uniform shape and size for the entire pool or field, except that when
found necessary . . . the board is authorized to divide any pool or field into zones and establish
spacing units for each zone.”2875 In that event, spacing units may differ in size and shape from
those established in other zones.2876 Regardless of whether zonal subdivision is needed, spacing
units must be set in a manner that will result in “efficient and economical development of the
pool or field as a whole and . . . [each unit] may not be smaller than the maximum area that can
be efficiently drained by one well.”2877
An order to establish spacing units must “specify the size and shape of each unit and the
location of each permitted well thereon in accordance with a reasonably uniform spacing
plan.”
2878
2872 Id. § 520.045.
Any owner may file a petition with the Board for an exception to a spacing order,
which may be granted upon a showing that the prescribed location will not allow production in
paying quantities, or that surface conditions pose a significant burden to drilling operations at the
proposed site.2879 The Board must provide notice to adjacent mineral owners, who may move
the Board to hold a hearing prior to granting any exception.2880 Whether or not an exception is
granted, a spacing order must provide any additional provisions necessary to ensure that
production from any unit does not exceed that amount which is “its just and equitable share of
the oil and gas in the pool.”2881
Oregon regulations include specific notice requirements for a hearing to establish spacing
units. Immediately upon the discovery of any pool or at any time after the effective date of the
applicable rule, the Board may prescribe spacing units for each pool and establish special field
rules applicable to that new pool.
2882 Prior to establishing spacing units or field rules, the Board
must provide notice to certain owners and hold a hearing.2883
(a) In areas of the state with surveyed sections, and where the top of the productive interval in the well is at a depth of less than 7,000 feet below the surface, the Department shall notify mineral owners in the 160 acre quarter section in which the well is located. If the top of the productive interval is located within 250 feet from any 160 acre quarter section line, the Department shall notify mineral owners in the affected adjacent quarter sections;
Notification for such a hearing
must be provided to mineral owners in the area surrounding the discovery well according to the
following:
(b) In the areas of the state with surveyed sections, and where the top of the productive interval in the well is at a depth of 7,000 feet or greater below the surface, the Department shall notify mineral owners in the 160 acre quarter section in which the well is located and in the eight surrounding quarter sections;
2879 Id. 2880 Id. 2881 Id. 2882 Or. Admin. R. 632-010-0156(1) (2011). 2883 Id. R. 632-010-0156(2).
554
(c) In those parts of the state that are without surveyed sections, the Department shall notify mineral owners located within the boundary of a superimposed 640 acre section with the well being centered in the section. Such superimposed section shall be oriented north-south.2884
After a hearing, the Board may grant exceptions to spacing or special rules when
necessary due to geological or topographical conditions, deficient productivity, or environmental
protection.
2885 The Board will notify all mineral owners within the spacing unit or affected by
the proposed exception prior to the hearing, and any mineral owner notified may contest the
proposed exception within 20 days of such notice.2886 Whenever a uniform spacing plan has
been prescribed for any pool, exceptions may be permitted if, after notice and a hearing, the
Board finds that conditions within the pool are such that the special rules would be
impracticable.2887
[b] Authority to Integrate Production.
When two or more separately owned tracts are embraced within a spacing unit or when
there are separately owned interests in all or a part of such spacing unit, then the interested
persons may integrate their tracts or interests for the development and operation of the spacing
unit.2888 In the absence of voluntary pooling, the Board, upon the application of any interested
person, may order the integration of all tracts or interests in the spacing unit for pooled
development, operation, and production from the unit.2889 A pooling order must establish just
and reasonable terms and conditions to provide for the integrated development and operation of
In the absence of a voluntary integration agreement for the entire spacing unit, the Board
shall enter an order integrating all mineral rights ownership interests in a spacing unit at any time
following the entry of an order establishing the spacing unit for a pool. 2891 A compulsory
integration order shall determine the interest of each mineral rights owner in the spacing unit by
dividing the number of surface acres subject to such owner's mineral rights located in the spacing
unit by the total number of surface acres in the spacing unit.2892
The compulsory integration order shall provide for the drilling, if necessary, and
operation of the well on the spacing unit, for the sharing of production, and for the payment of
costs. It shall also provide that the operator and participating owners shall be treated as an entity.
The operator-participating owners' entity shall be entitled to share production and pay costs, both
in proportion to the total interest of the operator-participating owners' entity in the spacing unit.
The express and constructive agreements between the operator and participating owner(s) shall
control the allocations of production and costs attributable to the operator-participating owners'
entity.
The compulsory integration order shall also provide that each non-participating owner
shall be entitled to a full share in production in proportion to his interest in the spacing unit
subject to his royalty obligations, if any. In addition to the above, the compulsory integration
order shall provide that the operator-participating owners' entity first shall receive from each
non-participating owner's share of production an entitlement in the amount of 300 percent as a
maximum of the amount of drilling costs attributable (pro rata on the basis of interests) to the
non-participating owner's interest; and 300 percent as a maximum of production costs
attributable to the non-participating owner's interest on the same basis. Each such entitlement
2891 Or. Admin. R. 632-010-0161 (2011). 2892 Id.
556
shall be allocated between the members of the operator-participating owners' entity according to
their actual and constructive agreements.2893
In addition to pooling of interests within a spacing unit, owners may execute an
agreement “for the unit or cooperative development and operation of a field, pool or part
thereof.”
2894 If all owners to be included in a unitized area do not agree by contract, the Board,
upon its own motion or the application of any interested person, will hold a hearing to consider
the need for the operation as a unit of any proposed unit area.2895
(a) Unit operation is reasonably necessary to effectively carry on pressure control, pressure maintenance or repressuring operations, cycling operations, water flooding operations, injection operations, or any combination thereof, or any other method of recovery designed to substantially increase the ultimate recovery of oil from the pool or pools; and
Upon such hearing, the Board
will issue a unitization order if it finds that:
(b) The value of the estimated additional recovery of oil or gas exceeds the estimated additional cost incident to conducting unit operations.2896
As these conditions suggest, Oregon provides for compulsory unitization only for those wells
employing secondary recovery or injection methods to enhance ultimate recovery from the pool
produced therefrom.
If the Board determines that unitization is proper, it may issue an order that will prescribe
a plan for unit operations.2897
(1) A description of the pool or pools or parts thereof to be so operated.
The order must include the following:
(2) A statement of the nature of the operations contemplated. (3) An allocation to the separately owned tracts in the unit area of all the oil and gas that is produced from the unit area and is saved,
2893 Id. 2894 Or. Rev. Stat. § 520.230(2). The Act also provides distinct rules for voluntary unitization by lessees of tidal or submersible lands, which are governed by the Department of State Lands. See id. § 520.240. 2895 Id. § 520.260(1). A unit area may include “one or more pools or parts thereof in a field.” 2896 Id. § 520.260. 2897 Id. § 520.270.
557
being the production that is not used in the conduct of operations on the unit area or not unavoidably lost. (4) A provision for the credits and charges to be made in the adjustment among the owners in the unit area for their respective investments in wells, tanks, pumps, machinery, materials and equipment contributed to the unit operations. (5) A provision stating how the costs of unit operations, including capital investments, shall be determined and charged to the separately owned tracts and how these costs shall be paid, including a provision stating when, how and by whom the unit production allocated to an owner who does not pay the share of the cost of unit operations charged to such owner, or the interest of such owner, may be sold and the proceeds applied to the payment of such costs. (6) A provision, if necessary, for carrying or otherwise financing any person who elects to be carried or otherwise financed, allowing a reasonable interest charge for such service payable out of that person’s share of the production. (7) A provision for the supervision and conduct of the unit operations, in respect to which each person shall have a vote with a value corresponding to the percentage of the costs of unit operations chargeable against the interest of that person. (8) The time when the unit operations shall commence, and the manner in which, and the circumstances under which, the unit operations shall terminate. (9) Additional provisions that are found appropriate for carrying on the unit operations, and for the protection of correlative rights.2898
As discussed below, a unitization order and plan issued by the Board will not become effective
until it is approved by owners of a required percentage of relevant interests in the area covered
by the proposed unit area.
2899
[c] Allocation of Production & Costs.
If there is no agreement between the interested parties regarding allocation of production,
the Board shall determine the relative value, from evidence introduced at the hearing, of the
separately owned tracts in the unit area, exclusive of physical equipment, for development of oil
2898 Id. 2899 Id. § 520.290(1). For a discussion of the ownership consent required, see subsection titled “Minimum Operator Control” below.
558
and gas by unit operations.2900 The production allocated to each tract shall be the proportion that
the relative value of each tract bears to the relative value of all tracts in the unit area.2901 That
portion of the unit production allocated to any tract, and the proceeds from the sale thereof, are
the property and income of the persons to whom, or to whose credit, they are allocated or
payable under the order providing for unit operations.2902
All operations, including but not limited to the commencement, drilling, or operation of a
well, upon any portion of the unit area, are considered for all purposes the conduct of operations
upon each separately owned tract in the unit area by the several owners thereof.
2903 The portion
of the unit production allocated to a separately owned tract in a unit area, when produced, is
considered for all purposes to have been actually produced from that tract by a well drilled
thereon. 2904 Operations conducted pursuant to an order of the Board providing for unit
operations constitute a fulfillment of all the express or implied obligations of each lease or
contract covering lands in the unit area to the extent that compliance with obligations cannot be
had because of the order of the Board.2905
[d] Allocation of Gas Pursuant to Special Pool Rules.
Whenever the full production from any pool producing natural gas is in excess of the
market demand for gas from that pool, any operator or interest owner may petition the Board for
a hearing and an order establishing a method of determining the market demand from the pool
and of distributing that demand among the wells producing therefrom.2906
“Gas” means “all natural gas and all other fluid hydrocarbons not defined as oil . . .,
including condensate originally in the gaseous phase in the reservoir.”2907 “Oil” means “crude
petroleum oil and all other hydrocarbons, regardless of gravity, that are produced in liquid form
by ordinary production methods, but does not include liquid hydrocarbons that were originally in
a gaseous phase in the reservoir.”2908
[2] – Split by Depth.
As shown below, Oregon law provides distinct spacing
requirements for oil and gas wells.
As discussed below, the default spacing regulations for Oregon’s Mist Gas Field vary
based on the depth of a given well.
[3] – Spacing Rules.
The Department has enacted general spacing requirements for gas wells only. In the
absence of special field rules, no gas well may be located within 250 feet from the unit boundary
and 500 feet from the nearest well producing gas from the same pool.2909
The minimum spacing for gas wells in the Mist Field shall be 160 acres when the top of
the producing zone is less than 7,000 feet in vertical depth.
2910 The minimum spacing for gas
wells in the Mist Field shall be 640 acres when the top of the producing zone is 7,000 feet or
more in vertical depth.2911 The spacing units are based upon the federal land grid of sections and
quarter sections or projected extensions of the grid if the affected lands are not surveyed.2912
2907 Or. Rev. Stat. § 520.005(3) (2010).
The
completion location of each well permitted to be drilled on any spacing unit in the Mist Gas
2908 Id. § 520.005 (5). 2909 Or. Admin. R. 632-010-0230 (2011). 2910 Id. R. 632-010-0225(2). 2911 Id. R. 632-010-0225(3). 2912 Id. R. 632-010-0225(4).
560
Field shall be the location of the well at the top of the producing horizon.2913 The Board may
grant exceptions to the above field rules after holding a hearing when necessary on the basis of
geology, productivity, topography, enhancement requirements, or environmental protection.2914
[4] – Minimum Operator Control.
The Act requires that a certain proportion of ownership interests is accounted for in the
approval of any unitization order issued by the Board. No unitization order will become
effective until the plan for unit operations has been approved in writing by the following
percentages:
(A) Those owners who, under the board’s order, will be required to pay at least 75 percent of the costs of the unit operation, and (B) Those persons who, at the time of the order of the Board, owned of record legal title to 75 percent of royalty and overriding royalty payable with respect to oil and gas produced from the pool or part thereof over the entire unit area.2915
This required approval must be presented to and accepted by the Board within six months of the
order’s issuance.
2916 If not consented to upon the initial hearing for unit operations, the Board
may hold supplemental hearings as necessary to obtain such approval within that time period.2917
[5] – Directional Drilling.
The Department regulations require specific rules governing horizontal drilling in the
state. A well that is intentionally deviated from the vertical must be surveyed at intervals of no
less than 250 feet to determine the location of the borehole at such intervals.2918
2913 Id.
Horizontal
deviation is permitted without special permission for short distances if done to straighten the
hole, sidetrack junk, or correct mechanical difficulties.2919 Unless variation is pursuant to such
conditions, no well may be intentionally deviated from the vertical without a permit from the
state geologist.2920
If drilling has not commenced, an application to deviate a wellbore may be approved as
part of the initial drilling permit.
2921 If drilling is in progress, the operator must notify the state
geologist as soon as practicable of his intent to deviate the hole direction, and file an application
for a permit to proceed with such plans. 2922
(A) Surface location in terms of distances from lease and section boundaries. Plan coordinates of top of producing interval and bottom of hole from surface location;
The application must include the following
information:
(B) Reason for deviation; (C) If the proposed or final location of the producing interval of the directionally deviated well is not in compliance with the spacing or other rules applicable to the reservoir:
(i) List of affected mineral rights owners or evidence that the applicant is the only affected mineral rights owner. For the purposes of this rule, affected mineral rights owners are the mineral rights owners in adjoining or cornering drilling or spacing units toward which the well is to be deviated; (ii) Neat and accurate plat of the lease and of all affected leases showing the names of all affected mineral rights owners and the surface and proposed producing interval locations of the well. The plat shall be drawn to a scale which will allow easy observation of all pertinent data.2923
Prior to approving any proposed deviation, the state geologist will notify all affected
mineral owners in drilling or spacing units toward which the well is being directionally
drilled.
2924
2919 Id.
Any such affected mineral owner may request a hearing to contest the application
2920 Id. R. 632-010-0142(2). 2921 Id. 2922 Id. 2923 Id. 2924 Id. R. 632-010-0142(3).
562
within 20 days of receipt of notice; however, the application to deviate shall be granted or denied
at the sole discretion of the state geologist whether or not a hearing is required.2925
If the applicant is the only affected mineral owner or has obtained the right to drill by
lease or waiver, the State Geologist may approve the permit without a 20-day pendency
period.
2926 Further, the state geologist may permit deviation without notice and a hearing if the
deviation is part of an existing and continuous drilling operation.2927
[6] – Election.
Neither the Act nor Department regulations specify terms for carrying or for the
institution of a risk penalty for non-consenting owners subject to pooling or unitization orders.
2925 Id. 2926 Id. 2927 Id.
563
§ 39.01 Analysis of Pennsylvania Regulatory Framework.
[1] – Governing Body.
Oil and gas activities in Pennsylvania are governed by the Oil and Gas Act,2928 codified
in chapter 11 of title 58 of the Pennsylvania Statutes; the Oil and Gas Conservation Law,2929
codified at chapter 7 of title 58; and the Coal and Gas Resource Coordination Act (hereinafter the
“Coal and Gas Act”),2930 codified at chapter 10 of title 58. Both the Oil and Gas Act and the
Coal and Gas Act were enacted in 1984. The Oil and Gas Act gave authority to the Department
of Environmental Services, which has now transferred its duties to the Department of
Environmental Protection (hereinafter, the “DEP”). The Coal and Gas Act also authorizes the
Department of Environmental Protection to carry out its provisions.2931
The Oil and Gas Conservation Law was enacted in 1961 and created the Oil and Gas
Conservation Commission. The purpose of the Commission was to advise and enforce the
provisions of the statute. The Conservation Law was also enforced by the Oil and Gas Division
of the Department of Mines and Mineral Industries. Both the Commission’s and the Division’s
powers and duties were later transferred to the Department of Environmental Resources in
1971,
2932 and then to the Department of Environmental Protection by the Conservation and
Natural Resources Act in 1995.2933 The DEP now has the authority and duty to execute and
carry out the provisions of the Oil and Gas Conservation Law.2934
The DEP appoints and fixes the compensation of additional experts, engineers,
geologists, inspectors, investigators, hearing officers, attorneys, clerks, reporters, and other
2928 58 Pa. Stat. Ann. §§ 601.101–601.605 (West 2011). 2929 Id. §§ 401–419. 2930 Id. §§ 501–518. 2931 Id. §§ 504, 502. 2932 Act of 1970, No. 275, Pub. L. No. 834, § 30 (codified at 71 Pa. Cons. Stat. § 510-103(a) (2011)). 2933 Act of 1995, No. 18, Pub. L. No. 89, § 1 (codified at 71 Pa. Cons. Stat. 1340.503(a) (2011)). 2934 58 Pa. Stat. Ann. § 405(a) (West 2011).
564
employees as may be necessary for the proper conduct of the work of the DEP.2935 The DEP and
its employees are subject to all the provisions of “The Administrative Code of 1929,”2936
[2] – Scope of Authority.
which
apply generally to administrative departments and offices.
The Oil and Gas Act brings the development of oil and gas and coal under the jurisdiction
of the DEP and requires a permit prior to commencement of drilling operations.2937 The Oil and
Gas Act is intended to do the following: to allow for the optimal development of Pennsylvania’s
oil and gas resources consistent with health, safety, and environmental concerns; to protect the
safety of those employed in the industries of natural gas or oil or coal mining; to protect those
persons living in areas where those industries operate; and to protect the natural resources and
environmental rights secured by the Pennsylvania Constitution.2938 It sets out the process by
which the Department grants drilling permits, along with various other provisions.2939
The Coal and Gas Act, which the DEP has primary responsibility for enforcing, requires
coordination of gas well operators and coal mine operators.
The Oil
and Gas Act does not restrict its applicability to any depth.
2940 The act applies to all gas wells
that penetrate a workable coal seam, 2941
2935 Id. § 415(a).
which is defined as “a coal seam identified . . . as
2936 71 Pa. Stat. Ann. § 510-1, states that the “Department of Environmental Resources (now known as the Department of Environmental Protection) shall, subject to any inconsistent provision in this act contained, continue to exercise the powers and perform the duties by law heretofore vested in and imposed upon (2) The Department of Mines and Mineral Industries, the Secretary of Mines and Mineral Industries, the Oil and Gas Conservation Commission. . . .” 2937 58 Pa. Stat. Ann. § 601.101–102 (West 2011). 2938 Id. § 601.102. 2939 See, e.g., id. § 601.201. 2940 Id. § 512. 2941 Id. § 503(a).
565
capable of being mined by underground methods.”2942 The Coal and Gas Act does not apply to
gas wells permitted under the Oil and Gas Conservation Law or to oil wells.2943
The Oil and Gas Conservation Act defines the term “pool” as “an underground reservoir
containing a common accumulation of oil and gas, or both, not in communication laterally or
vertically with any other accumulation of oil or gas.”
2944 To protect any oil or gas pool, and to
prevent blowouts, cavings, seepages, and fires or the detrimental intrusion of water into any pool,
the DEP is authorized to make investigations and inspections of records and facilities, 2945
including the authority to enter the premises of an oil or gas well for the purposes of inspecting
the drilling, casing, operations, and plugging of the wells. 2946 Along with the authority to
inspect wells, the DEP is permitted to provide for the integration or communitization of interests
within a drilling unit2947 in order to prevent waste. Accordingly, the DEP is also empowered to
promulgate and to enforce rules, regulations, and orders to effectuate the purposes and the intent
of the Act.2948
The Oil and Gas Conservation Law applies to wells that penetrate the Onondaga horizon,
or in those areas in which the Onondaga horizon is nearer to the surface than 3,800 feet, any
wells that exceed a depth of 3,800 feet beneath the surface.
2949
2942 Id. § 502.
The Onondaga horizon is defined
as “the top of the Onondaga formation, except in those areas in which the Onondaga formation is
not present, and in such areas, the term shall be understood to mean either the top of the
stratigraphic horizon first appearing in the interval of the missing Onondaga formation, or where
strata older than the top of the Onondaga are exposed at the surface, then the term ‘Onondaga
Horizon’ shall mean the surface.”2950 After a well has been drilled into a pool of oil or gas, the
statute can be invoked by the well operator, an owner of mineral interests “directly and
immediately affected by the well,” or any other person who owns mineral interests in the
pool.2951
any owner of the right to develop, operate, and produce oil and gas from the pool. In the event that there is no oil and gas lease in existence the owner of the oil and gas rights shall be considered as “operator” to the extent of seven-eighths of the oil and gas in that portion of the pool underlying the tract owned by such owner, and a royalty owner as to a one-eighth interest in such oil and gas. In the event that the oil is owned separately from the gas, the owner of the substance being produced or sought to be produced from the pool shall be considered as “operator” as to such pool.
The Oil and Gas Conservation Law defines “operator” as,
2952
[3] – Process for Pooling.
As an initial matter, an operator must obtain a permit from the DEP to drill a well.2953
All applications must include a plat, approvable bond, a fee, and proof of notification, among
other things.2954 The plat, among other requirements, must state the name of affected surface
owners, surface owners and water purveyors whose water supplies are within 1,000 feet of the
suggested location, and the record owner or operator of all known underlying workable coal
seams; the proposed angle of the well; if the well is to be deviated substantially from the vertical;
and the workable coal seams underlying the tract to be drilled.2955 The permit fee is set by a
table in the regulations.2956
The applicant must forward a copy of the plat to the previously mentioned landowners,
water purveyors, and coal owners or operators by a form of notice deemed appropriate in the
temperature of 60 degrees Fahrenheit and pressure 14.7 PSIA, any manufactured gas, any
byproduct gas or any mixture of gases” and defining “oil” or “petroleum” as “[h]ydrocarbons in
liquid form at standard temperature of 60 degrees Fahrenheit and pressure 14.7 PSIA.” The
statutes do not expressly define coalbed methane.2989
[2] – Split by Depth.
The Oil and Gas Conservation Law, the only of the above statutes that deals with pooling
and unitization, affects lands in the Commonwealth of Pennsylvania,2990 but applies only to a
well or wells which penetrate the Onondaga horizon or, in those areas in which the Onondaga
horizon is nearer to the surface than 3,800 feet, any well or wells which exceed a depth of 3,800
feet beneath the surface. 2991 The Onondaga formation underlies the Marcellus Shale; 2992
Which statute a well is governed by is determined by the depth of the producing interval
of the discovery well in the pool. If such producing interval is covered by the Conservation Law,
then all wells drilled to such pool are covered by that Law, even though some of the wells in the
pool, if considered alone, would not be covered by it.
therefore the Conservation Law is presumed not to apply to wells drilled into the Marcellus
Shale. (See below for a discussion of the proposed pooling statue that applies to Marcellus
wells.) Presumably, though, the Oil and Gas Act and the Coal and Gas Act do apply to
Marcellus wells.
2993
2989 In Pennsylvania, the Court, in the case of U.S. Steel Corp. v. Hoge, 503 Pa. 140, 468 A.2d 1380 (Pa. 1983), determined that ownership, control and the right to produce coalbed methane was vested in the owner of the coal seam in which in the coalbed methane is situate so long as it remains in the seam.
Gas wells not covered by the
Conservation Law, if drilled through a workable coal seam, come under Coal and Gas Act
2990 58 Pa. Stat. Ann. § 403(a) (West 2011). 2991 Id. § 403(b)(1). 2992 John A. Harper, Devonian, The Geology Of Pennsylvania 111 (Charles H. Schultz ed. 1999). 2993 58 Pa. Stat. Ann. § 403(b)(1) (West 2011).
574
jurisdiction.2994 The Conservation Law does not apply to wells commenced prior to its effective
date, except such wells previously completed in strata above the Onondaga horizon, but
subsequent to the effective date of the law, drilled deeper than the Onondaga horizon, or 3,800
feet, whichever is deeper. Also these existing wells may be considered in spacing and pooling
orders entered by the DEP.2995 The Oil and Gas Conservation Law also does not apply to wells
drilled to inject gas into or withdraw gas from gas storage reservoir.2996
[3] – Spacing Rules & Minimum Operator Control.
The Oil and Gas Conservation Law provides for the integration of interests in spacing
units. As part of the order establishing a spacing unit or units, the DEP prescribes the terms and
conditions upon which the royalty interests in the unit or units shall, in the absence of voluntary
agreement, be deemed to be integrated without the necessity of a subsequent separate order
integrating the royalty interests.2997
The DEP enters orders establishing well spacing and drilling units, the size and shape of
which should be specified in the order and should be approximately uniform for each pool; the
statute does not give a specified size or space for these wells or units, and it is assumed that they
are conducted on a case-by-case basis.
The Conservation Law contains no provision requiring the
proposed operator of the unit to have any minimum level of control of the tracts within the unit.
2998 The orders establishing spacing units will specify the
minimum distance from the nearest boundary of the spacing unit, where a well maybe be
payable by or charged to the nonparticipating interests. If parties dispute costs, the DEP may
determine proper costs. If a well is completed before the spacing unit is integrated, production
sharing is only effective from the date of integration, except that nonparticipating parties will
receive credit for the value of their share of prior production from the well.3009
[6] – Proposed New Legislation for Marcellus Operations.
As previously stated, the Oil and Gas Conservation Law does not apply to Marcellus
Shale drilling because it sits above the Onondaga horizon. With the development of the
Marcellus Shale, the gas drilling industry has proposed a new pooling law for Pennsylvania
called the Pennsylvania Unconventional Oil and Gas Fair Pooling Act (the “Fair Pooling
Act”).3010 The Fair Pooling Act would create an “Oil and Gas Fair Pooling Office” within the
Department of Conservation and Natural Resources’s Bureau of Topographic and Geologic
Services. 3011 The Office would “administer the provisions of the act and promote the
development of unconventional oil and gas resources of the Commonwealth in accord with the
best principles and practices of oil and gas conservation, while reasonably protecting the
correlative rights” of affected persons. 3012 A director, who is a civil service employee of
Pennsylvania, would administer the Office and would be required to have experience in the
administration of oil and gas conservation laws, rules, and regulations.3013
The Fair Pooling Act would apply only to wells drilled into and producing from oil and
natural gas reservoirs below the base of the Elk Sandstone or its stratigraphic equivalent. The act
would apply both to vertical and horizontal wells; however, the only portion applying to vertical
3009 Id. 3010 Pa. Unconventional Oil & Gas Fair Pooling Act, available at http://www.marcellus-shale.us/pdf/Forced-Pooling-Act_6-15-10.pdf. 3011 Id. § 5(a). 3012 Id. § 5(b). 3013 Id. § 5(c).
578
wells is a 250-foot setback requirement from lease or unit lines and from other wells seeking
production from the same stratigraphic interval.3014 The Fair Pooling Act would not apply to
“coalbed methane or oil or gas found in tight sandstone reservoirs.”3015
Any person who “owns or controls at least 75 percent of the oil or gas working interest in
a proposed unit” could apply to the Office for an order establishing a drilling unit and integrating
all interests in the unit “for the development and production from unconventional oil or gas
reservoirs.” If a person does not own 75 percent of the proposed unit, but has written evidence
of an agreement with other owners who, in the aggregate, control at least 75 percent of the unit,
then that person can apply for the integration of interests for that unit.
3016 The application must
include a certification that the applicant made a good faith effort to lease or otherwise reach an
agreement with all interest owners in the unit, proof of actual and constructive notice to all
interest owners, and a proposed “joint operating agreement and lease for the unit.” 3017 The
application may be for a “standard unit” or a “special unit.”3018
[A]ny unit that is not more than 640 acres in area plus ten percent (10%) tolerance for possible survey error or other acreage discrepancies and that (absent interference by adjacent pre-existing voluntary unit(s) or unit(s) created under this Act) is configured generally in a regular square or other rectangular form oriented generally with the orientation of one or more horizontal well bores in the vicinity that the Applicant reasonably believes can be developed from a single pad (which may be located on or off the unit); and that includes all interests in and to the oil and gas within the boundaries of the proposed unit. Acreage in excess of the stated 640 acre maximum and 10% supplemental tolerance may be
§ 40.01 Analysis of Rhode Island Regulatory Framework. The state of Rhode Island has not enacted any statute addressing oil and gas conservation.
581
§ 41.01 Analysis of South Carolina Regulatory Framework.
[1] – Name of Governing Body.
The South Carolina Department of Health and Environmental Control (“the Department”)
regulates oil and gas production under the state’s conservation and unitization statute (“the
Act”).3024
[2] – Membership on the Governing Body.
The Department is a non-Cabinet agency supervised by the Board of Health and
Environmental Control (“the Board”).3025 The Board contains seven members: one gubernatorial
appointee named as Commissioner, and one representative from each of the state’s six
congressional districts. 3026 Board members serve four-year terms. 3027
As established by the Board, the Department is comprised of five deputy divisions:
Administration, Health Regulation, Health Services, Ocean and Coastal Resource Management,
and Environmental Quality Control, the last of which administers the Act under authority granted
to the Department.
3028 The Board elects a director every four years to lead the Department, who
has “such authority and perform[s] such duties as may be directed by the Board.”3029
[3] – Scope of Authority.
The Department has statutory authority to enforce the Act and maintains “jurisdiction
over all persons and property necessary for that purpose.”3030
3024 S.C. Code Ann. §§ 48-43-10(B), 48-43-30 (2010).
Its primary goals are to “prevent
3025 Id. § 44-1-20. 3026 Id. 3027 Id. 3028 See S.C. Dep’t. of Health and Envtl. Control, http://www.scdhec.gov/administration/organization.htm (last visited June 6, 2011). 3029 S.C. Code Ann. § 44-1-40 (2010). 3030 Id. § 48-43-30(A)(1).
582
waste of oil and gas, to protect correlative rights[,] and to prevent pollution of the water, air and
land by oil or gas.”3031
[a] Matters Governed.
Although waste and pollution are both expressly prohibited,3032 the Act clarifies that if
Department goals conflict, “the duty to prevent waste is paramount.”3033
Physical waste, as . . . generally understood in the oil and gas industry; . . . inefficient, excessive, or improper use, or the unnecessary dissipation of, reservoir energy; . . . locating, drilling, equipping, operating, or producing of any oil or gas well in a manner that causes, or tends to cause, reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or . . . unnecessary or excessive surface loss or destruction of oil or gas; . . . production of oil or gas in excess of (a) transportation or marketing facilities; (b) the amount reasonably required to be produced in the proper drilling, completing or testing of the well from which it is produced; . . . and, . . . underground or above ground waste in the production or storage of oil, gas or condensate, however caused . . . .
“Waste” includes, but
is not limited to, the following:
3034
The Department may initiate investigation and establish rules and regulations to
discharge its duties under the Act.
3035 In particular, the Department may require “identification
of [well] ownership; . . . preparing and filing of well logs; . . . furnishing [of] . . . a reasonable
performance bond,” and any other action necessary to prevent waste.3036
3031 Id.
Department authority
includes the power to regulate “the spacing [and] locating of wells; . . . to limit [and allocate] the
production of oil, gas or condensate from any field, pool, area, lease, or well; . . . [and] to
classify and reclassify pools [and wells]” based on the respective hydrocarbon(s) produced
therefrom.3037
[b] Council Procedure.
The Department may not issue any rule, regulation or order “without a public hearing
upon at least twenty days’ notice, exclusive of the date of service.”3038 A public hearing is held
at a time and place chosen by the Department at which “any interested person shall be entitled to
be heard.”3039 The Department may act upon its own motion or any interested person may
petition for a public hearing.3040
Any notice required by this chapter shall be given by the Department. Any such notice, at the election of the Department, may be given by any one or more of the following methods: (a) personal service, (b) publication in one or more issues of a newspaper in general circulation in the state capital or of a newspaper of general circulation in the county where the land affected or some part thereof is situated, or (c) by United States mail addressed, postage prepaid, to the last known mailing address of the person or persons affected. The date of service shall be the date on which service was made in the case of personal service, the date of first publication in the case of notice by publication, and the date of mailing in the case of notice by mail. The notice shall be issued in the name of the State, shall be signed by the chairman, secretary or executive director of the Department, shall specify the style and number of the proceedings, the time and place of the hearing, and shall briefly state the purpose of the proceeding. Should the Department elect to give notice by personal service, such service may be made by an officer authorized to serve process, or by any agent of the Department, in the same manner as is provided by law for the service of process in civil action in the courts of the State. Proof of the service by such agent shall be by the affidavit of the agent making personal service.
The Department must provide notice of a hearing as follows:
3041
3037 Id.
3038 Id. § 48-43-40(A). 3039 Id. Neither the Act nor Department regulations define “interested person.” 3040 Id. § 48-43-40(E). 3041 Id.
584
Any rule, regulation or order must be in writing and entered within 30 days of the
hearing.3042 All entries are maintained by the Department as public record, copies of which are
receivable into evidence in all state courts.3043 Department rules and regulations must also be
filed with the Secretary of State.3044 Notably, the Act requires that “all rules and regulations
adopted by the Department . . . be approved by the General Assembly before they [become]
effective.”3045
Any person who “has a direct interest in the subject matter of any final order” may appeal
to a circuit court within the state.
3046
[4] – Process for Pooling & Matters Covered.
The Act does not prescribe an appropriate venue for such
appeal.
No person may begin drilling without first obtaining a valid permit from the
Department.3047 Drilling permits will only be granted upon application from the proposed well
operator(s).3048 Unless otherwise approved by a municipality, “no well drilling permit shall be
issued within the corporate limits of any municipality.”3049 Further, no permit will be granted to
drill on any beach within the state.3050
The Department may limit and allocate oil and gas production among and within pools as
necessary to prevent waste.
3051
3042 Id. § 48-43-40(D).
A “pool” is “an underground reservoir containing a common
3043 Id. 3044 Id. 3045 Id. § 48-43-100. 3046 Id. § 48-43-60. In most cases, an appeal may be filed in the applicable judicial district in which affected property rests. 3047 S.C. Code Ann. Regs. 121-8.5(A) (2010). 3048 Id. 3049 Id. 121-8.5(D). 3050 Id. 3051 S.C. Code Ann. § 48-43-30 (2010).
585
accumulation” of oil and/or gas; in addition, “each zone of a structure that is completely
separated from any other zone in the same structure is a pool.”3052
Discussion of the Act’s pooling provisions requires attention to its distinction between
ownership interests. An “owner” is that person “who has the right to drill into and produce from
a pool and to appropriate the oil or gas that he produces therefrom, either for himself or for
himself and others.”
3053 This owner is different from the person who qualifies as a “royalty
owner,” which references “the person who[,] pursuant to a lease agreement with another[,] has
the right to receive, free of costs, an allocation of production or payments based upon the value
of production.”3054
[a] Spacing of Wells.
The Department may establish spacing units for a pool after notice and a hearing.3055
Upon such notice, “no additional well shall be commenced for production from the pool [in
question] until the order establishing units has been made.”3056 A spacing order must contain the
size and shape of each unit and the proposed well(s) to be located thereon.3057 In addition, the
order should cover all land “determined or believed to be underlain” by a relevant pool.3058
The Department will establish spacing units of like shape and size within a pool;
however, the Act authorizes sacrifice of spatial uniformity for production efficiency.
3059 For
example, the Department may set “spacing units of different sizes or shapes for different parts of
a pool” and grant exceptions to uniformity “where circumstances reasonably require.”3060
compulsory unitization order if “[integrated] operation is reasonably necessary to increase the
ultimate recovery of oil or gas; and, the value of the estimated additional recovery of oil and gas
exceeds the estimated additional cost incident to conducting such operations.” 3070
No order of the department providing for unit operations shall become effective unless and until the plan for unit operations prescribed by the Department has been approved in writing by those persons who . . . will be required to pay at least seventy-five percent of the costs of the unit operation, and also by the owners of at least seventy-five percent of the production or proceeds thereof that will be credited to interests which are free of cost, such as royalties, overriding royalties and production payments, and the department has made a finding, either in the order providing for unit operations or in a supplemental order, that the plan for unit operations has been so approved.
To be
effective, the Department must obtain formal consent from a proportion of relevant interests in
the unit area. The Act states,
3071
To determine whether the requisite 75 percent thresholds are met, the Act presumes that
the owner of an unleased tract is considered to hold a seven-eighths interest as “owner” and a
one-eighth royalty interest.
3072 The Department may hold supplemental hearings to determine
approval if necessary.3073 Unless owners agree within six months of entry, the proposed order is
“ineffective[] and shall be revoked,” absent good cause to offer an extension.3074
[c] Contents of Pooling & Unitization Orders.
A pooling order must be “upon terms and conditions that are just and reasonable.”3075
authorize the drilling, equipping, and operation of a well on the spacing unit; . . . provide who may drill and operate the well; . . . prescribe the time and manner in which all owners in the spacing
Each pooling order shall do the following:
3070 Id. 3071 Id. § 48-43-350(D) (emphasis added). 3072 Id. If unleased acreage is state-owned, statutory presumption is five-sixths owner and one-sixth royalty owner. 3073 Id. 3074 Id. 3075 Id. § 48-43-350(C).
588
unit may elect to participate therein; and . . . make provision for the payment by all those who elect to participate therein of the reasonable cost thereof, plus a reasonable charge for supervision and interest.3076
Each unitization order must prescribe a plan for pooled operation which includes the
following information:
(1) A description of the pool or pools or parts thereof to be so operated, termed the unit area; (2) A statement of the nature of the operations contemplated; (3) An allocation to the separately owned tracts in the unit area of all the oil and gas that is produced from the unit area and is saved, being the production that is not used in the conduct of operations on the unit area or not unavoidably lost; (4) A provision for the credits and charges to be made in the adjustment among the owners in the unit area for their respective investments in wells, tanks, pumps, machinery, materials, and equipment contributed to the unit operations; (5) A provision providing how the costs of unit operations, including capital investments, shall be determined and charged to the separately owned tracts and how such costs shall be paid, including a provision providing when, how, and by whom the unit production allocated to an owner who does not pay the share of the cost of unit operations charged to such owner, or the interests of such owner, may be sold and the proceeds applied to the payment of such costs; (6) A provision, if necessary, for carrying or otherwise financing any person who elects to be carried or otherwise financed, allowing a reasonable interest charged for such service payable out of such person's share of the production; (7) A provision for the supervision and conduct of the unit operations, in respect to which each person shall have a vote with a value corresponding to the percentage of the costs of unit operations chargeable against the interest of such person; (8) The time when the unit operations shall commence, and the manner in which, and the circumstances under which, the unit operations shall terminate; and, (9) Such additional provisions that are found to be appropriate for carrying on the unit operations, and for the protection of a correlative rights.3077
3076 Id. § 48-43-340(C).
3077 Id. § 48-43-350(C).
589
As shown in these provisions, the Act recognizes election rights in compulsory pooling
situations, the terms of which must appear in the order. Election is further discussed below.
[d] Allocation of Production and Costs.
If the Department limits production throughout the state, it must “allocate the allowable
production among the pools on a reasonable basis.” 3078 In doing so, the Department “may
consider, but not be bound by, nominations of purchasers to purchase from particular pools or
groups of pools.” 3079 However, the Department will allocate production to “prevent undue
discrimination among pools” resulting from selective purchasing.3080
Subject to needs of waste prevention, the Department must “allocate the allowable
production among the several wells or producing properties in the pool so that each entitled
thereto will have a reasonable opportunity to produce or to receive a just and equitable share of
the production.”
3081 The Department defines “just and equitable share” to mean, “as to each
person, that part of the authorized production from the pool that is substantially in the proportion
that the amount of recoverable oil or gas . . . in the developed area of his tract[s] . . . in the pool
bears to the recoverable oil or gas . . . in the total developed areas in the pool.”3082
All operations incident to oil and gas production which occur upon any portion of pooled
land “shall be deemed for all purposes the conduct of such operations upon each separately
owned tract in the unit area by the several owners thereof.”
3083 As such, the portion of the unit
production allocated to a separately owned tract in a unit area is considered “to have been
actually produced from such tract by a well drilled thereon.”3084
Department for approval shall not for that reason imply or constitute evidence” that anti-trust
laws are violated.3104
§ 41.02 Types of South Carolina Pooling Statutes.
[1] – Mineral Distinctions.
Under South Carolina law, “gas” encompasses “all natural gas and all other fluid
hydrocarbons not [otherwise] defined as oil, including condensate . . . .” 3105 In turn, “oil”
includes “crude petroleum oil and all other hydrocarbons, regardless of gravity, that are produced
in liquid form by ordinary production methods, but does not include [condensate].”3106
The Department has authority under the Act “[t]o classify and reclassify pools . . . [and]
wells” based on the hydrocarbon to be produced therefrom.
3107 Upon the discovery of any new
oil pool in the State, the Department will classify such in one of the following categories: (1)
Pools on Temporary Allowable; (2) Prorated Pools; or (3) Pools Under Pressure Maintenance or
Secondary Recovery.3108 Gas pools will be classified as either (1) Dry Gas Pools; (2) Gas
Condensate Pools; or (3) Gas Condensate Pools Under Cycling.3109
[2] – Split by Depth.
These classifications will
foster Department action in establishing field rules to dictate applicable spacing and allowable
production standards.
Except in terms of performance bond amount noted below, neither the Act nor state
regulations distinguish amongst various wells by depth. However, nothing in the Act suggests
that the Department is limited in its ability to set depth restrictions by rule or order.
3104 Id. 3105 Id. § 48-43-10(E). “Condensate” includes “liquid hydrocarbons that were originally in the gaseous phase in the reservoir.” Id. § 48-43-10(F). 3106 Id. § 48-43-10(D). 3107 Id. § 48-43-30(B)(4). 3108 S.C. Code Ann. Regs. 121-8.20(A) (2010). 3109 Id. 121-8.20(B).
594
[3] – Spacing Rules.
The Department has authority to regulate the spacing of wells by order or through
establishing field rules, which are spacing and production standards covering one or more
pools.3110 Field rules shall provide for “the establishment of the allowable, the production unit
[if applicable] . . ., well spacing requirements [for the pool(s) covered], and other matters
incidental to hydrocarbon production.”3111 After notice and a hearing, the Department may grant
exceptions to existing or temporary field rules if necessary to prevent waste or to protect
correlative rights. 3112 Such notice and hearing must comply with the requirements outlined
above.3113
The Department has established default spacing requirements for wells not covered by
field rules. No well may be located nearer than 330 feet from any lease boundary.
3114 An oil
well shall not be drilled within 900 feet of “any other well completed in, drilling to, or for which
a permit has been granted to drill to, the same pool.”3115 Similarly, no gas well may be located
within 2,000 feet of any other existing or permitted well within the same pool.3116
In addition to its authority to establish general or “special” field rules, the Department
may grant exceptions to these default spacing requirements upon application.
3117 Any well
excepted from spacing requirements is afforded the opportunity to produce on test basis until the
Department determines appropriate unit dimensions.3118
[4] – Minimum Operator Control.
3110 Id. 121-8.9(A) (2010). A “field” is “the general area underlain by one or more pools.” S.C. Code Ann. § 48-43-10(H) (2010). 3111 S.C. Code Ann. Regs. 121-8.9(B) (2010). 3112 Id. 121-8.9(C). 3113 Id.; see also S.C. Code Ann. § 48-43-40 (2010). 3114 S.C. Code Ann. Regs. 121-8.9(A) (2010). 3115 Id. 3116 Id. 3117 Id. 121-8.9(A)-(B). 3118 Id. 121-8.9(A).
595
To be effective, the Department must obtain formal consent from a proportion of relevant
interests in the unit area. The Act requires that a unitization order is ineffective unless, within
six months of entry, the Department receives written consent of its terms from at least 75 percent
of the working interest ownership, as well as 75 percent of the non-paying royalty interests.3119
To determine whether the sufficient approval exists, the owner of an unleased tract is presumed
to hold a seven-eighths working interest and a one-eighth royalty interest.3120
[5] – Directional Drilling.
As a general rule, “[a]ll wells must be drilled with due diligence to maintain a reasonably
vertical well bore.”3121 However, “upon application by an operator to drill a well that is to be
intentionally deviated and directionally controlled,” the Department may issue a permit for such
variant operation.3122 An application must comply with the terms specified for new drilling
permits and also include adequate survey(s) displaying both surface and proposed bottom home
locations.3123 An operator may likewise apply to receive Department permission to deviate an
existing permitted well, upon which the Department will require maintenance of certain records
concerning direction and production.3124
The Department will not grant a permit for deviated drilling unless “the location of the
deviated well at the depth of the proposed producing zone is in compliance with the applicable
spacing rules.”
3125
3119 S.C. Code Ann. § 48-43-350(D) (2010) (emphasis added).
Again, “proper applications shall be made to obtain approval or exceptions to
3120 Id. § 48-43-350(D). If unleased acreage is state-owned, statutory presumption is five-sixths owner and one-sixth royalty owner. 3121 S.C. Code Ann. Regs. 121-8.17(A) (2010). 3122 Id. 3123 Id. 3124 Id. 121-8.17(B)–(E). 3125 Id. 121-8.17(A).
596
such rules.” 3126 The Department has discretion to grant exceptions, and must afford such
application “the same consideration and treatment as if the well had been drilled vertically.”3127
[6] – Election.
The Act acknowledges election rights for those subject to compulsory pooling. If
applicable, the options available for non-consenting owners and any other terms of election must
be stated in the order itself, which shall provide the following:
one or more just and equitable alternatives whereby an owner who does not elect to participate in the risk and cost of the drilling and operation . . . of a well may elect to surrender his leasehold interest to the participating owners on some reasonable basis and for a reasonable consideration which, if not agreed upon, shall be determined by the Department, or may elect to participate in the drilling and operation, or operation, of the well, on a limited or carried basis upon terms and conditions determined by the Department to be just and reasonable.3128
The Act does not enforce a default “risk penalty” against those owners who refuse to
cover upfront drilling expenses. If an operator or owner(s) pay the costs of operation for the
benefit of others within the pool, those who cover such costs will “be entitled to the share of
production from the . . . unit accruing to the interest of such other [owners], exclusive of a
royalty not to exceed one-eighth of the production.”
3129 However, the right of covering owners
to recoup investment is limited to a non-payer’s production at the market value of respective
drawing a significant portion of their income from individuals subject to those permits. 3136
Potential conflicts must be adequately disclosed. 3137 A quorum of the Board consists of a
majority of members, and the Board should hold meetings either upon request of the chairman or
upon request of a majority of the members, but at least once every three months.3138
The Secretary of the Department of Environment and Natural Resources must be
qualified by training and experience to administer the Department’s programs.
3139 The Secretary
may appoint the Geologist, who must have an advanced degree in geology. No information is
given as to what degree will satisfy this requirement. He or she will act as an advisor to the
Secretary in all matters relating to geology, hydrology, and natural history.3140
[3] – Scope of Authority.
The Board has jurisdiction and authority over “all persons and property, public and
private, necessary to enforce effectively the provisions of this chapter.”3141 The chapter declares
its purpose to be as follows: to prevent waste, to promote “a greater ultimate recovery of oil and
gas,” to fully protect the correlative rights of all owners, and to support the greatest possible
economic recovery of oil and gas within the state so that “the landowners, the royalty owners, the
producers, and the general public realize and enjoy the greatest possible good from these vital
natural resources.”3142
Waste of oil and gas is prohibited.
3143
Physical waste, as that term is generally understood in the oil and gas industry; the inefficient, excessive or improper use of, or the unnecessary dissipation of reservoir energy; the inefficient storing
of oil or gas; the drilling of unnecessary wells; the locating, spacing, drilling, equipping, operating, or producing of any oil or gas well or wells in a manner that causes, or tends to cause, reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or that causes or tends to cause unnecessary or excessive surface loss or destruction of oil or gas; and the underground or above ground waste in the production or storage of oil and gas, however caused, and whether or not defined in other subdivisions of this section.3144
The Board has the authority and duty to investigate as is proper to determine if waste exists or is
imminent or if such facts exist to justify the Board action.
3145 Moreover, authority exists to
promulgate rules and issue orders “reasonably necessary to prevent waste, to protect correlative
rights, to govern the practice or procedure before the board, and otherwise to administer this
chapter.” 3146 The Board may delegate to the Secretary the authority to monitor and enforce
compliance with rules thus promulgated.3147 It may also otherwise regulate the production of oil
and gas from any field, pool, or area where physical waste is created, which authority it may
delegate to the Geologist.3148
The Board also has the authority to promulgate rules to regulate and allow for the
following:
(a) The drilling, producing, and plugging of wells, and all other operations for the production of oil or gas; (b) the shooting and chemical or physical treatment of wells; (c) the spacing or locating of wells; (d) operations to increase ultimate recovery such as cycling of gas, the maintenance of pressure, and the introduction of gas, water or other substances into producing formations; and (e) disposal of salt water and oil field wastes.3149
determined by an agency after an opportunity for hearing . . . .”3165
(1) A statement of the time, place, and nature of the hearing;
Such notice should include
the following:
(2) A statement of the legal authority and jurisdiction under which the hearing is to be held; (3) A reference to the particular sections of the statutes and rules involved; (4) A short and plain statement of the matters asserted. If the agency or other party is unable to state the matters in detail at the time the notice is served, the initial notice may be limited to a statement of the issues involved. Thereafter upon application a more definite and detailed statement shall be furnished; (5) A statement of any action authorized by law, which may affect the parties, as a result of any decision made at the hearing, whether it be the revocation of a license, the assessment of a fine or other effect; (6) A statement that the hearing is an adversary proceeding and that a party has the right at the hearing, to be present, to be represented by a lawyer, and that these and other due process rights will be forfeited if they are not exercised at the hearing; (7) Except in contested cases before the Public Utilities Commission, a statement that if the amount in controversy exceeds two thousand five hundred dollars or if a property right may be terminated, any party to the contested case may require the agency to use the Office of Hearing Examiners by giving notice of the request to the agency no later than ten days after service of a notice of hearing issued pursuant to § 1-26-17; [and] (8) A statement that the decision based on the hearing may be appealed to the circuit court and the State Supreme Court as provided by law.3166
The Rules also contain detailed requirements for the information to be included in the
petition. In order for a person to request a contested case hearing, the petition filed with the
Secretary of the Department must include the following:
(1) A statement of the petitioner’s interest in the involved matter; (2) A statement of the departmental recommendation contested, if any, and the relief and decision requested from the board; (3) A statement alleging the relevant facts and issues known to the petitioner upon which the contest or request of the board is based;
3165 Id. § 1-26-1(2). 3166 Id. § 1-26-17.
603
(4) A statement of the legal authority and jurisdiction under which the hearing would be held, if known; (5) A reference to the particular statutes and rules involved, if known; and (6) The signature of the petitioner or the petitioner’s attorney.3167
The petitioner must serve a copy of this petition to all persons known who are affected by the
request and who will be considered parties in the proceeding.
3168
Additionally, pursuant to the established contested case procedure, operators may file
applications to conduct unit operations in a common pool. The applications, submitted to the
Secretary, must contain the following:
(1) The name and address of the operator; (2) The location and type of all existing and proposed wells and the legal description of all land proposed to be operated as a unit; (3) A description of the pool proposed to be unitized; (4) A description of the proposed secondary or tertiary recovery method, including its costs. Information on costs will be held confidential by the secretary and the board if requested by the operator; (5) A list of all operators affected by the application; (6) A plan for unit operations which, at a minimum, addresses the requirements of SDCL § 45-9-39; (7) A statement of how the proposed operation will increase the recovery of oil or gas and the value of the additional recovery. The value will be held confidential if requested by the operator; and (8) A plan of operation of injection wells being proposed in the unit operation.3169
The Board must enter the order within 30 days of holding a hearing.
3170 The final
decision in a contested case will be had by majority vote of a quorum of the Board. The final
decision and resulting order must be signed by the hearing chairman.3171
3167 S.D. Admin. R. 74:09:01:01 (2010).
The hearing chairman
is a member of the Board appointed by the Board’s chairman to be responsible for the conduct of
3168 Id. 3169 Id. R 74:10:07:28. 3170 S.D. Codified Laws § 45-9-57 (2010). 3171 S.D. Admin. R. 74:09:01:18 (2010)
604
the prehearing conference and the hearing. He or she will also rule on all motions regarding the
hearing process. Those decisions are final unless overruled by the Board.3172
For pooling orders covering existing spacing units, the law provides that each order must
“authorize the drilling, equipping, and operations of a well on the spacing unit; shall provide who
may drill and operate the well; shall prescribe the time and manner in which all the owners in the
spacing unit may elect to participate therein; and shall make provisions for the payment by all
those who elect to participate therein of the reasonable actual cost thereof, plus a reasonable
charge for the supervision and interest.”
3173 Finally, each order, if requested, must provide
equitable alternatives for owners who do not elect to participate in the risk and cost of drilling to
surrender his or her leasehold interest to the participating owner for reasonable consideration or
to elect to participate on a limited or carried basis. If terms and conditions are not agreed upon
by the parties, the Board should determine what terms are just and reasonable.3174
Operations on any part of a spacing unit that is covered by a pooling order is deemed to
be the conduct of operations on each separately owned tract in the drilling unit by the several
owners thereof. The portion of production so allocated to each tract is, when produced, deemed
to have been produced from that tract by a well drilled thereon.
3175
As for unitization hearings, if the Board finds that unit operation is “reasonably necessary
to increase substantially the ultimate recovery of oil or gas” and that the value of that estimated
additional recovery is greater than the estimated additional costs corresponding to the unit
operation, it will make an order providing for the unit operation of a pool or part thereof.
Orders for unit operation must be on just and reasonable terms and must prescribe a plan for such
operations including the following:
(1) A description of the pool or pools or parts thereof to be so operated, termed the unit area; (2) A statement of the nature of the operations contemplated; (3) An allocation to the separately owned tracts in the unit area of the oil and gas that is produced from the unit area and is saved, being the production that is not used in the conduct of operations on the unit area or not unavoidably lost. The allocation shall be in accord with the agreement, if any, of the interested parties. If there is no such agreement, the board shall determine the relative values, from evidence introduced at the hearing, of the separately owned tracts in the unit area, exclusive of physical equipment, for the development of oil and gas by unit operations, and the production allocated to each tract shall be the proportion that the relative values of each tract so determined bears to the relative value of all tracts in the unit area; (4) A provision for the credits and charges to be made in the adjustment among the owners in the unit area for their respective investments in wells, tanks, pumps, machinery, materials, and equipment contributions to the unit operations; (5) A provision providing how the costs of unit operations, including capital investments, shall be determined and charged to the separately owned tracts and how said costs shall be paid, including a provision when, how, and by whom the unit production allocated to an owner who does not pay the share of the cost of unit operations charged to such owner, or the interest of such owner, may be sold and the proceeds applied to the payment of such costs; (6) A provision, if necessary, for carrying or otherwise financing any person who elects to be carried or otherwise financed, allowing a reasonable interest charge for such service payable out of such person’s share of the production; (7) A provision for the supervision and conduct of the unit operations in respect to which each person shall have a vote with a value corresponding to the percentage of the costs of unit operations chargeable against the interest of such person; (8) The time when the unit operations shall commence, and the manner in which, and the circumstances under which, the unit operations shall terminate; and (9) Such additional provisions that are found to be appropriate for carrying on the unit operations, and for the protection of correlative rights.3177
3177 Id. § 45-9-39.
606
The orders by the Board requiring unit operations are not effective until the plan
approved by the Board is also approved in writing by the parties who, according to the order, are
required to pay at least 60 percent “of the production or proceeds thereof that will be credited to
interests which are free of cost, such as royalties, and production payments,” and the Board has
determined that the order has been thus approved.3178 The Board, upon application and notice,
will hold supplemental hearings as may be required to make that determination.3179 If the proper
approval of the order for unit operation does not occur within six months from the date of the
order, the order will be ineffective and revoked unless the Board extends the deadline for good
cause shown.3180
Additionally, the Board may amend orders providing for unit operations by an order
made “in the same manner and subject to the same conditions as an original order providing for
unit operations.”
3181 However, if the amendment only affects rights or interests of the owners,
the royalty owners’ approval is not needed.3182 No order may change the percentage of oil and
gas allocated to each separately owned tract without consent of all persons who own oil and gas
rights in that tract, nor may it change the percentage of costs allocated to tracts except with
consent of all owners in that tract.3183
All operations on any portion of the unit area are deemed for all purposes the conduct of
such operations upon each separately owned tract by the several owners thereof. All production
allocated to each tract shall be deemed to have been actually produced from that tract by a well
drilled thereon.
3184
3178 Id. § 45-9-40.
If the Board later provides for unit operation of a pool or pools or parts
In order to drill a horizontal well, the drilling party must submit the information required
under section 74:10:03:01 of the South Dakota Administrative Code. Additionally, that party
must submit an application for a permit to drill a horizontal well, which includes the following
information:
(1) Size, weight, and amount of all casing strings; (2) Top of cement behind each casing string; (3) Mud program; (4) Coordinates of the casing shoe; (5) Coordinates of the terminus; (6) Depth of kick-off point; (7) Azimuth of the horizontal segment; (8) Down-hole survey frequency; (9) Name and address of surveying contractor; and (10) Location of cementing tool.3238
Relatedly, operators who desire to conduct directional drilling operations, other than
directional drilling to circumvent debris, to straighten, or to control blowouts, must file a petition
for a contested case with the secretary.
3239 This requirement does not apply to drilling horizontal
holes covered by section 74:10:03:01.01.3240
[6] – Options.
All pooling orders must set forth “the time and manner in which all the owners in the
spacing unit may elect to participate therein and shall make provision for the payment by all
those who elect to participate therein of the reasonable actual cost thereof, plus a reasonable
charge for supervision and interest.”3241
3238 S.D. Admin. R. 74:10:03:01.01 (2010).
If requested, pooling orders should provide for one or
more “just and equitable alternatives” by which an owner electing not to participate in the cost
and risk of drilling may elect “to surrender his leasehold interest to the participating owners on
some reasonable basis and for a reasonable consideration which if not agreed upon, shall be
3239 Id. R. 74:10:03:21. 3240 Id. 3241 S.D. Codified Law § 45-9-32 (2010).
615
determined by the [Board],” or may elect to participate, on a limited or carried basis, on terms
and conditions the Board determined to be just and reasonable.3242
Orders for unit operation must include provisions setting forth how costs, including
capital investments, are to be determined, charged, and paid. The order must also include when,
how, and by whom the costs allocated to a non-participating owner should be paid from
proceeds.
3243 If needed, the order must include a provision for financing any owner who elects
to be carried or financed in the unit operation. 3244 The production allocated to a tract and
proceeds thereof are property of the persons to whose credit the proceeds are payable under the
§ 43.01 Analysis of Tennessee Regulatory Framework.
[1] – Name of Governing Body.
The Tennessee Oil and Gas Board (“Board”) is the body charged with regulating the oil
and gas industry in Tennessee.3246
[2] – Membership on the Board.
The Board is composed of the Commissioner of Environment and Conservation who acts
as chair (“Supervisor”), a designee of the Commissioner of Economical and Community
Development, the chair of the Conservation Commission, a member from the oil and gas
industry appointed by the governor, an owner of oil or gas property appointed by the governor,
and a member from the mineral industry3247 appointed by the governor.3248
The member from the oil and gas industry, the oil or gas property owner, and the member
from the mineral industry each serve a four year term.
3249
Any three members of the Board shall constitute a quorum, but three affirmative votes
are necessary for the adoption of any rule or order of the Board.
3250
[3] – Scope of Authority.
The Board has the jurisdiction and authority (1) over all persons and property necessary
to enforce this chapter, (2) to enforce the provisions and rules regulating oil and gas production,
(3) to collect data, (4) to investigate potential violations of the rules regulating oil and gas
production, and (5) to make inquiries to determine whether waste is imminent.3251
3246 Tenn. Code Ann. § 60-1-201 (2010).
Waste, which
3247 “Mineral Industry” is not a defined term in the statute. 3248 Tenn. Code Ann. § 60-1-201 (2010). 3249 Id. 3250 Id. § 60-1-203. 3251 Id. § 60-1-202 (a).
617
is prohibited,3252
(1) underground waste and inefficient, excessive, or improper use or dissipation of reservoir energy of any pool; (2) the locating, spacing, drilling, equipping, operating, or producing of any oil well or gas ultimately recoverable from any pool; (3) surface waste; and (4) the inefficient storing of oil or gas wells.
carries, in addition to its ordinary meaning, the meaning of “physical waste” as
that term is generally understood in the oil and gas industry. It includes the following:
3253
Thus, the Board has rulemaking authority and a statutory duty to (1) prevent the escape of
oil and gas, (2) prevent pollution of fresh water by oil and gas, (3) protect minable coal, and (4)
require bond for the plugging of dry or abandoned wells.
3254
Additionally, the Board has authority to,
(1) require that the Supervisor be notified of someone’s intention to drill any well; (2) require the filing of logs within 30 days following the cessation of drilling operations; (3) prevent wells from being drilled or operated, to prevent drowning by water of any oil and gas stratum in paying quantities; (4) require operation of wells with efficient gas-oil ratios; (5) prevent blow-outs, caving and seepage; (6) prevent fires; (7) identify ownership of oil and gas leases; (8) regulate the shooting and chemical treatment of wells; (9) regulate secondary recovery methods; (10) regulate spacing; and (11) provide for forced integrations of separately owned tracts.3255
[4] – Process for Pooling.
[a] Unitization.
A pooled unit is defined as “two or more tracts of land, of which their ownership may be
different, that are consolidated and operated as a single tract for production of oil and/or gas,
either by voluntary agreement between the owners thereof, or by exercising of the authority of
surface poolwide unit in the absence of a voluntary agreement, the Board must give a 60-day
notice to the owners, and the pool producers who own more than 50 percent of the pool acreage
must request such unitization of the pool. 3257 When such tracts are consolidated by Board
authority, the size of the consolidation tract will not exceed the size, with permitted tolerance, of
a “Drilling Unit” (see below). 3258 If there is not an acceptable plan of unitization by the
operators, the Board must shut in the pool to prevent waste.3259
Additionally, an owner with an interest in a tract of land offsetting production who
cannot comply with spacing rules may make an application for a hearing before the Board to
have the tract, or portion of the tract, included in the production unit.
3260
All drilling and production unit wells shall comply with the rules on spacing between
wells and distance from property lines, see below. The shape and pattern shall be designed to
permit the attendant unit well to economically, efficiently, and equitably drain the unit’s pro-rata
share of the pool’s oil and/or gas and shall be based on available geologic and engineering
parameters. Length of any drilling unit shall not exceed twice its width.
When part of a leased tract is included within a pool or unitized area, drilling or
production anywhere within the unitized area during the primary term of the lease continues the
lease as to the portions of the lease both inside and outside the unit.3261
[b] Permit Application.
3257Tenn. Code Ann. § 60-1-202 (a)(4)(N) (2010). 3258 Tenn. Oil & Gas Board, Definition of terms: Rule 1040-1-1-.01 (2010). 3259 Tenn. Code Ann. § 60-1-202 (a)(4)(O). 3260 Tenn. Oil & Gas Board, Unit Operations: Rule 1040-5-1.02 (2010). 3261 Asberry v. Saint Joseph Petroleum, 653 S.W.2d 412 (Tenn. Ct. App. 1983). The Court determined that the shut-in royalty for an off-lease unit well formed by the lessee under the pooling clause maintained the entire lease even though only a portion of the lease was in the unit.
619
No person is permitted to drill, or conduct any surface disturbances, in preparation for
drilling, unless a permit application has been submitted to the Supervisor. This application must
include the following information:
(1) the exact location of the well; (2) the name and address of the person responsible for drilling; (3) the proposed depth of the well; (4) the locations of all existing roads providing access to the well site; and (5) the location of all blue-line streams within one half mile of the well site or access roads.3262
The application must also contain a provision for erosion control, the prevention of pollution of
surface waters, and reclamation of all areas. No drilling may begin until the application has been
approved. Failure to comply with any plan shall be reason for revocation of the permit and
forfeiture of the bond.
3263
Requests for permits for a voluntary pooled drilling unit, or for two or more leases or
tracts that have been force pooled for exploration or development, shall follow the prescribed
procedure where applicable and shall be accompanied by a notarized affidavit signed by the
operator that has the right to pool these leases to form a drilling unit.
3264
Additionally, after filing an application with the Board for a permit, and prior to any site
preparation, the applicant must give notice, by certified mail to property owner or owners of the
surface of the land to be drilled, or to be affected by the surface disturbances, of the applicant’s
intent to drill on the property.
3265
The notice shall include the following information:
The property owners to be notified under this section shall be
the property owners of record in the property tax assessor’s office in the county where the
(1) a well location plat which shows the proposed location of the oil and gas well site; (2) the proposed location of all new ingress and egress; (3) the location of all diversions, drilling pits, dikes, and related structures and facilities; and (4) the location of proposed storage tanks and all other surface disturbances.
The notice shall state that the property owner and applicant have 15 working days from
the date of mailing to discuss the location of surface disturbances in connection with the drilling
operation. It shall also state that if the property owner and applicant are unable to resolve
differences regarding the location of surface disturbances, either or both may request in writing a
hearing before the Supervisor or his designee. The notice shall provide the name and address of
the Supervisor.3266
Notwithstanding any other requirement for a permit to drill, such a permit may only be
issued,
(1) [i]f the applicant submits to the Supervisor statements of no objection signed by all property owners entitled to notice; (2) [i]f a hearing is not requested; or (3) [u]pon the issuing of a final order.
In order to satisfy these requirements of permit issuance, the Supervisor may treat the persons
named in the applicant’s certification of property owners as being all of the property owners
entitled to notice unless the Supervisor has actual notice to the contrary. Additionally, inspection
and approval of all access roads, surface disturbances, and pollution control structures at a
proposed well site by the designated gas and oil field inspector is required prior to the issuance
of any permit.
In the event of litigation over a particular tract of land, or in the event a tract of land is
contested as to the ownership of oil and gas rights, the policy of the Board will be to issue
operation. If those differences cannot be resolved, then a hearing and order may be obtained as
follows:
(1) Any property owners entitled to notice (or the applicant) may request, within fifteen (15) working days3270
(2) The hearing shall be conducted as a contested case under Title 4, Chapter 5, Part 3 and shall be held before a hearing officer sitting alone. For purposes of the hearing, the Supervisor or his designee shall be the hearing officer. The hearing shall be held within ten (10) working days of receipt of a request for hearing by the Supervisor or his designee, and shall be held in the county of the proposed oil and gas well. Notice of the hearing shall be given to all persons entitled to notice under subparagraph (a) and the applicant.
of the mailing of the notice required in subparagraph (a), that the Supervisor or his designee conduct a hearing. A request for hearing under this paragraph shall be in writing to the Supervisor, and shall be mailed by certified mail, return receipt requested, within fifteen (15) working days of the mailing of the notice required in subparagraph (a) above. The purpose of the hearing will be to minimize the impact of the proposed drilling operation on the surface of the land.
3. The hearing officer shall render a decision within ten (10) calendar days of the hearing. The decision shall be considered a final order not subject to further agency review pursuant to T.C.A. 4-5-315(a)(1).3271
If a request for hearing is not delivered to the office of the Supervisor within 15 working
days plus three additional days after the date notice-of-intent to drill was mailed to each property
owner, as stated in the applicant’s certification of notice, the Supervisor may assume that no
hearing was requested, unless he has actual notice to the contrary.
3272
[ii] Public Hearings.
Public hearings, after legal notice, shall be held by the Board as needed by the Board to
implement its responsibility and upon applications made for such hearings. A notice of public
3270 For purposes of subparagraph (f) above, “working day” means all calendar days excluding Saturdays, Sundays, and legal holidays as designated in T.C.A. 15-1-101, see Tenn. Oil & Gas Board, Permit Required: Rule 1040-02-02-.01(5) (2010). 3271 Id. 3272 Id.
623
hearing as provided by T.C.A. §60-107 shall be given by publishing one notice of the time and
place thereof in at least three newspapers of general circulation in at least three major cities in
Tennessee, and such notice shall be published at least ten days prior to the date of such hearing.
The applicant must pay the cost incurred in publishing legal notices. The time and place for each
public hearing shall be fixed by the Board as soon as reasonably possible and each public hearing
will be conducted by the Board. If more than one hearing is to be held on a particular date, the
Board conducting the hearings shall determine the order in which they will be held.
The Board has the power to subpoena witnesses and to require their attendance to give
testimony.3273 If someone does not comply with a subpoena issued by the Board, the Board may
petition the Circuit Court in the county where the Board is sitting for a motion to compel
compliance with the subpoena.3274
After a public hearing, rule may be made on behalf of the Board. If an emergency arises,
the Board may act without a public hearing, given that the rule enacted by the Board will not
remain in force longer than 15 days after its effective date. All rules and regulations shall be
made in writing and shall be made open to public inspection.
3275
The Board has the ability to assess monetary penalties for any violation of this chapter or
its rules. If a violation is issued to any operator, and that violation is not corrected within the
period of correction, the penalty could be up to $1,000 for each day the violation exists.
3276
3273 Tenn. Code Ann. § 60-1-205 (a) (2010).
Anyone who willfully or repeatedly violates the rules or requirements may be fined up to
the base of the Chattanooga Shale, 3287 whichever is deeper. Oil well requirements are then
further split for wells drills at a depth greater than 2,000 feet. Gas wells have two further depth
requirements: one for wells that have been drilled between 2,000 and 5,000 feet and another for
those that have been drilled deeper than 5,000 feet. 3288
The Board further requires that horizontal wells have split depth requirements. As such,
there are separate requirements for oil wells drilled to the top of the Conasauga Group
3289 and for
gas wells drilled either to the top of the Conasauga Group or below the top of the Conasauga
Group. 3290
[3] – Spacing Rules.
The spacing of wells is controlled by and through specific rules. General spacing
requirements have been set for wells drilled in counties that have a designated population. If a
county has a population between 17,550 and 17,650, then oil and gas wells drilled within that
county to a depth of less than 2,500 feet shall not be located closer than 400 feet from any other
well or 200 feet from any property line. 3291
3287 “Chattanooga Shale” is not a defined term in the statute. However, it is located in Eastern Tennessee, Northern Alabama, Southern Kentucky, and Northeast Georgia. The Chattanooga Shale Field is an extension of the Appalachian Basin Devonian Shale, which is known to most as the Marcellus Shale. The productive zone is at a depth between 3,000 and 4,000 feet, and the shale thickness ranges from 80 to 200 feet in Tennessee. It is the stratigraphic equivalent of the Lower Huron found in Eastern Kentucky and West Virginia. Chattanooga Shale Natural Gas Field – Tennessee Shale Formation, http://www.oilshalegas.com/chattanoogashale.html (last visited June 24, 2011).
For any county that has a population between 4,300
and 4,400, or between 7,650 and 7,700, then any oil or gas well drilled within that county shall
3288 Tenn. Oil & Gas Board, Well Spacing: Rule 1040-2-4.01 (2010). 3289 “Conasauga Group” is not defined in the statute. However, in Tennessee it includes the: Maynardville Limestone, Nolichucky
Shale, the Maryville, Rogersville, and Rutledge Formations, Pumpkin Valley Shale, Rome Formation, and Shady Dolomite. The Conasauga Group is about 2,000 feet thick, and is mostly shale, with the secondary rock being dolomite. U.S. Geological Survey, Mineral Resources On-Line Spatial Data, http://tin.er.usgs.gov/geology/state/sgmc-unit.php?unit=TNCAc%3B11 (last visited June 24, 2011). 3290 Tenn. Oil & Gas Board, Directional Drilling: Rule 1040-2-8.01 (2010). 3291 Tenn. Code Ann. § 60-1-106(a) (2010).
627
not be located closer than 400 feet from any other well for which a permit shall have been
granted to drill to the same pool and not closer than 200 feet from any property line. 3292
Thus, if an oil and/or gas well is not drilled within a county with a population of 17,550
to 17,650 and drill to a depth of 2,500 feet or within a county with a population of 4,300 to
4,400, or 7,650 to 7,700, then the well is regulated by Rule 1040-2-4.01, which was established
by the Tennessee Oil and Gas Board. The rules are as follows:
Oil and gas wells drilled to a depth less than 1,000 feet shall not be located closer than
660 feet from any other well and not closer than 330 feet from the property line.3293 Oil and gas
wells drilled from 1,000 feet to 2,000 feet, or at the base of the Chattanooga Shale, shall not be
closer than 660 feet from any other well and not closer than 330 feet from any property line. Oil
wells drilled to a depth greater than 2,000 feet shall not be located closer than 660 feet from
another well and not closer than 330 feet from any property line. Gas wells drilled between
2,000 and 5,000 feet shall not be located closer than 660 feet from another well and not closer
than 330 feet from any property line. Gas wells drilled more than 5,000 feet shall not be located
closer than 1,320 feet from any other well and not closer than 660 feet from any property line.
Additionally, a wildcat well will have its spacing assigned by the Supervisor.3294
For horizontal oil wells and horizontal gas wells drilled to the top of the Conasauga
Group, the surface tract of that portion of the wellbore or any portion of the horizontal drainhole
shall not be located closer than 330 feet from any property line.
3295
3292 Id. § 60-1-106 (b).
For horizontal gas wells
drilled below the top of the Conasauga Group, the surface tract of that portion of the wellbore or
3293 Tenn. Oil & Gas Board, Well Spacing: Rule 1040-2-4.01 (2010). 3294 Id. 3295 Tenn. Oil & Gas Board, Well Abandonment: Rule 1040-2-8.04 (2010).
628
any portion of the horizontal drainhole that penetrates the producing formation, including the
horizontal drainhole end point, shall not be located closer than 660 feet from any property line.
A poolwide unit is exempt from well spacing rules as to the particular unitized pool, but
all wells must be located interior of the unit outline in compliance with the rules for distance
from property lines for this to apply.3296
Additionally, no well shall be drilled closer than 200 feet from a dwelling or closer than
100 feet from a public road.
3297 Further, no well may be drilled within 200 feet of any water well
that is in active use.3298
[4] – Size.
No well may be drilled within 100 feet of any stream, lake or other body
of water.
3299
Oil and gas wells drilled to a depth less than 1,000 feet shall be drilled one per ten-acre
unit.
3300 Oil and gas wells drilled from 1,000 feet to 2,000 feet, or at the base of the Chattanooga
Shale, shall be drilled on 20-acre units. Oil wells drilled to a depth greater than 2,000 feet shall
be drilled on 40-acre units. Gas wells drilled to a depth between 2,000 and 5,000 feet shall be
drilled on 40-acre. Gas wells drilled deeper than 5,000 feet shall be drilled on 160-acre units.3301
[5] – Minimum Operator Control.
3296 Id. 3297 Tenn. Oil & Gas Board, Prevention of Hazards and Pollution: Rule 1040-3-3.01 (2010). 3298 Id. 3299 Upon the completion of a confirmation well to a discovery well (neither of which are defined) the operator of the discovery well must apply for a public hearing before the State Oil and Gas Board for the purpose of establishing temporary drilling and production units. When a pool has had five wells drilled to and completed therein or after one year has elapsed from the completion of the confirmation well in the field, whichever occurs first, the operator or operators of well(s) in the field shall petition the Board for a public hearing for the purposes of establishing field rules and regulations and the creation of drilling and production units for the pools in the field. The right is reserved, however, to any interested party to apply for a public hearing at an earlier date and if the Board finds from an examination of the information furnished that temporary or permanent drilling and production units should be formed, it shall be so ordered. 3300 Tenn. Oil & Gas Board, Well Spacing: Rule 1040-2-4.01 (2010). 3301 Id.
629
The pool producers owning more than 50 percent of the pool acreage must request
unitization of the pool in order for the Board, in the absence of a voluntary agreement, and after a
60-day notice to the owners, to force a volumetric or surface poolwide unit.3302
3302 Tenn. Code Ann. § 60-1-202 (a)(4)(N) (2010).
630
§ 44.01 Analysis of Texas Regulatory Framework. [1] – Name of Governing Body. Pooling of oil and gas is regulated by the state of Texas and, more specifically, by the
Railroad Commission of Texas (“Commission”).3303
[2] – Membership on the Governing Body.
There are three Commissioners on the Railroad Commission of Texas. Railroad
Commissioners are elected to six-year terms with one Commissioner seeking election every two
years. When a Commissioner is appointed by the Governor of Texas to fill an unexpired term,
the appointee serves until the next General Election at which time the appointee may run for the
remainder of the unexpired term.3304
[3] – Scope of Authority.
The Railroad Commission, through its Oil and Gas Division, regulates the exploration,
production, and transportation of oil and natural gas in Texas. Its statutory role is to protect the
correlative rights of different interest owners, prevent pollution, provide safety, and prevent
waste of the state’s natural resources.3305 Waste, which is prohibited,3306
(1) operation of any oil well or wells with an inefficient gas-oil ratio . . .; (2) drowning with water a stratum or part of a stratum that is capable of producing oil or gas or both in paying quantities; (3) underground waste or loss, however caused . . .; (4) permitting any natural gas well to burn wastefully; (5) creation of unnecessary fire hazards; (6) physical waste or loss incident to or resulting from drilling, equipping, locating, spacing, or operating a well or wells in a manner that reduces or tends to reduce the total ultimate recovery of oil or gas from any pool; (7) the unnecessary, inefficient, excessive, or improper use of the reservoir energy . . .; (8) surface waste or surface loss, including the temporary or permanent storage of oil or the placing of any product of oil in
includes the following:
3303 Tex. Nat. Res. Code Ann. § 85.001 (West 2010). 3304 Railroad Commission of Texas, Home Page, http://www.rrc.state.tx.us (last visited May 31, 2011). 3305 Id. 3306 Tex. Nat. Res. Code Ann. § 85.045 (West 2010).
631
open pits or earthen storage, and other forms of surface waste or surface loss including unnecessary or excessive surface losses, or destruction without beneficial use, either of oil or gas; (9) escape of gas into the open air in excess of the amount necessary in the efficient drilling or operation of the well from a well producing both oil and gas; (10) production of oil in excess of transportation or market facilities or reasonable market demand . . .; and (11) surface or subsurface waste of hydrocarbons, including the physical or economic waste or loss of hydrocarbons in the creation, operation, maintenance, or abandonment of an underground hydrocarbon storage facility.3307
In addition, each month the Commission assigns production allowables on oil wells and
gas wells; receives operators’ production reports on oil leases (an oil lease may contain multiple
oil wells) and gas wells; and audits the oil disposition path to ensure production did not exceed
allowables. Allowables are assigned according to factors such as tested well capability, reservoir
mechanics, market demand for production, and past production.
3308
The Commission also regulates oil field injection and disposal wells which include
permitting, annual reports, and tests. Through these program, fluids are injected into either
productive reservoirs under enhanced recovery projects to increase production or into non-
productive reservoirs for disposal. In other pollution prevention activities, waste management is
carried out by permitting pits and landfarming, discharges, waste haulers, waste minimization,
and hazardous waste management.
3309
To prevent pollution of the state’s surface and ground water resources, the Commission
has an abandoned well plugging and abandoned site remediation program that uses funds
provided by industry through fees and taxes. Many wells and sites are remediated with these
The Oil and Gas Division of the Railroad Commission does have the authority to grant
exceptions to many of its regulations. Exceptions are usually granted when the exception would
further the Railroad Commission’s obligation to prevent waste.3311
[4] – Process for Pooling.
The Commission may, under specific circumstances, establish a unit and pool all of the
interest in the unit to avoid the drilling of unnecessary wells, protect correlative rights, or prevent
waste. The unit shall in no event exceed 160 acres for an oil well or 640 acres for a gas well,
plus 10 percent tolerance.3312
The Commission shall establish a unit and pool all of the interests in the unit within an
area containing the approximate acreage of the proration unit (1) when two or more separately
owned tracts of land are embraced in a common reservoir of oil or gas for which the Commission
has established the size and shape of proration units, whether by temporary or permanent field
rules; (2) where there are separately owned interests in oil and gas within an existing or proposed
proration unit in the common reservoir and the owners have not agreed to pool their interests;
and (3) where at least one of the owners of the right to drill has drilled or has proposed to drill a
well on the existing or proposed proration unit to the common reservoir. However, the
Commission may only do this upon the application of a mineral interest owner.
3313 An owner
can be (1) the owner of any interest in oil and gas in an existing proration unit or with respect to
a proposed unit; (2) the owner of any working interest; or (3) any owner of an unleased tract
other than a royalty owner.3314
3311 Id.
3312 Tex. Nat. Res. Code Ann. § 102.011 (West 2010). 3313 Id. 3314 Id. §102.012.
633
An operator may pool acreage, in accordance with appropriate contractual authority and
applicable field rules, for the purpose of creating a drilling unit or proration unit by filing an
original certified plat delineating the pooled unit and a Certificate of Pooling Authority, Form P-
12 (revised 5/2001), according to the following requirements:
(1) Each tract in the certified plat shall be identified with an outline and a tract identifier that corresponds to the tract identifier listed on the Form P-12. (2) The operator shall provide information on the Certificate of Pooling Authority, Form P-12, accurately and according to the instructions on the form.
(A) The operator shall separately list each tract committed to the pooled unit by authority granted to the operator. (B) For each tract listed on Form P-12, the operator shall state the number of acres contained within the tract. The operator shall indicate by checking the appropriate box on Form P-12 if, within an individual tract, there exists a non-pooled and/or unleased interest. (C) The operator shall state on Form P-12 the total number of acres in the pooled unit. The total number of acres in the pooled unit shall equal the sum of all acres in each individual tract listed. (D) If a pooled unit contains more tracts than can be listed on a single Form P-12, the operator shall file as many additional Forms P-12 as necessary to list each pooled tract individually. The additional Forms P-12 shall be numbered in sequence. (E) The operator shall provide the requested identification and contact information on the Form P-12. (F) The operator shall certify the information on the Form P-12 by signing and dating the form.
Failure to timely file the required information on the certified plat or the Form P-12 may
result in the dismissal of the W-1 application. “Timely” means within three months of the
634
Commission notifying the operator of the need for additional information on the certified plat
and/or the Form P-12.3315
The operator must file the original certified plat and Form P-12 at the Commission’s
Austin office. The operator must also file a copy of the certified plat and Form P-12 with the
appropriate Commission district office or offices. If the operator files electronically through the
Commission’s Electronic Compliance and Approval Process (ECAP) system, the operator is not
required to file additional paper copies in the appropriate Commission district office, because all
Commission offices will have electronic access to the Form P-12 and certified plat.
3316
The operator shall file the Form P-12 and certified plat as follows:
(1) with the drilling permit application when two or more tracts are joined to form a pooled unit for Commission purposes to obtain a drilling permit, (2) with completion paperwork when the pooled unit's acreage is being used or assigned for allowable purposes, (3) to designate a pooled unit formed after completion paperwork has been filed when the pooled unit's acreage is being used or assigned for allowable purposes, or (4) to designate a change in a pooled unit previously recognized by the Commission.
The operator shall file any changes to a pooled unit in accordance with the requirements of 16
Tex. Admin. Code §3.38(d)(3) relating to Well Densities.3317
If a tract to be pooled has an outstanding interest, for which pooling authority does not
exist, the tract may be assigned to a unit where authority exists in the remaining undivided
interest, provided that total gross acreage in the tract is included for allocation purposes, and the
certificate filed with the Commission shows that a certain undivided interest is outstanding in the
tract. The Commission will not allow an operator to assign only his undivided interest out of a
basic tract where a nonpooled interest exists.3318
The nonpooled undivided interest holder retains his development rights in his basic tract
and, should such rights be exercised, authority to develop the basic tract is to be approved by the
Commission. If a well is completed as a producer thereon, then the entire interest in the basic
tract must be allocated to said well, and any interest insofar as it is pooled with another tract
must be assigned to the well on the basic tract for allocation purposes. Splitting of undivided
interest in a basic tract between two or more wells on two or more tracts is not acceptable.
3319
Acreage assigned to a well for drilling and development, or for allocation of allowable,
shall not be assigned to any other well or wells projected to or completed in the same reservoir.
While such duplicate assignment of acreage is not acceptable, this limitation shall not prevent the
reformation of development or proration units so long as no duplicate assignment of acreage
occurs, and so long as such reformation does not violate other conservation regulations.
3320
[5] – Process for Drilling Unit.
[a] General Permitting Provisions.
An application for a permit to drill, deepen, plug back, or reenter any oil well, gas well,
or geothermal resource well shall be made under the provisions of sections 3.37, 3.38, 3.39,
and/or 3.40, Title 16 of the Texas Administrative Code, or as an exception thereto, or under
special rules governing any particular oil, gas, or geothermal resource field or as an exception
thereto and filed with the Commission on a form approved by the Commission. An application
must be accompanied by any relevant information, form, or certification required by the Railroad
Commission or a Commission representative necessary to determine compliance with this rule
3318 Id. 3319 Id. 3320 Id.
636
and state law.3321
An application for a permit to drill shall include the fees required in Section 3.78, Title 16
of the Texas Administrative Code (relating to Fees and Financial Security Requirements) and
shall be certified by a person acquainted with the facts, stating that all information in the
application is true and complete to the best of that person's knowledge.
An application may be made by a form prescribed by the Commission or
through electronic filing.
3322 Any permit to drill,
deepen, plug back, or reenter granted by the commission expires no later than two years after the
date of original approval. 3323
An application to drill, deepen, plug back, or reenter shall be accompanied by a neat,
accurate plat, with a scale where one inch equals 1,000 feet. The plat for the initial well on the
lease, pooled unit, or unitized tract shall show the entire lease, pooled unit, or tract, including all
tracts being pooled. If necessary to show the entire lease, the scale may be one inch equals 2,000
feet. Plats for subsequent wells on a lease or pooled unit shall show at least the lease or pooled
unit line nearest the proposed location and the nearest survey/section lines. The Division Director
or the director's delegate may approve plats with other scales upon request. The plat needs to
include the following information:
(1) the surface location of the proposed drilling site; (2) perpendicular lines providing the distance in feet from two nearest non-parallel survey/section lines to the surface location; (3) perpendicular lines providing the distance in feet from two nearest non-parallel lease lines to the surface location; (4) a line providing the distance in feet from the surface location to the nearest point on the lease line, pooled unit line, or unitized tract line. If there is an unleased interest in a tract of the pooled unit that is nearer than the pooled unit line, the nearest point on that unleased tract boundary shall be used; (5) a line providing the distance in feet from the surface location to the nearest oil,
3321 Id. §3.5. 3322 Id. 3323 Id.
637
gas, or oil and gas well identified by number either applied for, permitted, or completed in the same lease, pooled unit, or unitized tract and in the same field and reservoir; (6) the geographic location information; (7) a labeled scale bar; and (8) northerly direction. 3324
Requirements for plats as provided for in sections 3.11, 3.37, 3.38, and 3.86 of this title
(relating to Inclination and Directional Surveys Required, Statewide Spacing Rule, Well
Densities, and Horizontal Drainhole Wells) may supplement or replace the plat requirements set
out above.
3325
A Commission designee may grant administrative approval if he or she determines that
granting the application will not result in the circumvention of the density restrictions of this
section or other Commission rules and if either written waivers are filed by all affected persons
or no protest is filed within the time set forth in the notice of application.
3326
The well densities per acre requirements are outlined below in the next section under
subsection “Size.” The Commission, or Commission designee, in order to prevent waste or,
except as provided in subsection section 3.38(d)(2), Title 16 of the Texas Administrative Code,
to prevent the confiscation of property, may grant exceptions to the density provisions set forth
in this section. Such an exception may be granted only after notice and an opportunity for
hearing.
3327
A permit issued as an exception to the applicable density provision shall expire two years
from the effective date of the permit unless drilling operations are commenced in good faith
within the two year period.
3328
3324 Id.
3325 Id. 3326 Id. § 3.38. 3327 Id. 3328 Id.
638
Upon receipt of a complete application, the Commission will give notice of the
application by mail to all affected persons for whom signed waivers have not been submitted. If
the Commission designee determines, based on the data submitted, that a permit requiring an
exception to the applicable density provision is justified, then the Commission designee may
issue the exception permit administratively so long as one of the following requirements is
satisfied:
(A) signed waivers from all affected persons were submitted with the application; (B) notice of application was given in accordance with rule requirements and no protest was filed within 21 days of the notice; or (C) no person appeared to protest the application at a hearing scheduled pursuant to rule.3329
If a written protest is filed within 21 days after the notice of application is given, the
application will be set for hearing. If the application is not protested and the Commission
designee determines that a permit requiring an exception to the applicable density provision is
not justified, the operator may request a hearing to consider the application.
3330
When filing an application for an exception to the density requirements, in addition to the
plat requirements in section 3.5, Title 16 of the Texas Administrative Code (relating to
Application to Drill, Deepen, Reenter, or Plug Back) (Statewide Rule 5), the applicant shall
attach to each copy of the application a plat that,
(A) depicts the lease, pooled unit, or unitized tract, showing thereon the acreage assigned to the drilling unit for the proposed well and the acreage assigned to all current applied for, permitted, or completed oil, gas, or oil and gas wells in the same field or reservoir which are located within the lease, pooled unit, or unitized tract; (B) on large leases, pooled units, or unitized tracts, if the established density is not exceeded as shown on the face of the
3329 Id. 3330 Id.
639
application, outlines the acreage assigned to the well for which the permit is sought and the immediately adjacent wells on the lease, pooled unit, or unitized tract; (C) on leases, pooled units, or unitized tracts from which production is secured from more than one field, outlines the acreage assigned to the wells in each field that is the subject of the current application; (D) corresponds to the listing required under subsection (g)(1)(A) of 16 Tex. Admin. Code 3.38; (E) is certified by a person acquainted with the facts pertinent to the application that the plat is accurately drawn to scale and correctly reflects all pertinent and required data.3331
If a permit to drill requires an exception to the applicable density provision, the operator
must also provide the following information:
(A) a list of the names and addresses of all affected persons. For the purpose of giving notice of application, the Commission presumes that affected persons include the operators and unleased mineral interest owners of all adjacent offset tracts, and the operators and unleased mineral interest owners of all tracts nearer to the proposed well than the prescribed minimum lease-line spacing distance. The Commission designee may determine that such a person is not affected only upon written request and a showing by the applicant that:
(i) competent, convincing geological or engineering data indicate that drainage of hydrocarbons from the particular tracts subject to the request will not occur due to production from the proposed well; and (ii) notice to the particular operators and unleased mineral interest owners would be unduly burdensome or expensive;
(B) engineering and/or geological data, including a written explanation of each exhibit, showing that the drilling of a well on substandard acreage is necessary to prevent waste or to prevent the confiscation of property; (C) additional data requested by the Commission designee.3332
An exception to the density provision may be granted only to prevent waste for a well on
a lease, pooled unit, or unitized tract that is composed of substandard acreage and that:
3331 Id. 3332 Id.
640
(A) took its present size and shape after the date of attachment of the voluntary subdivision rule (16 Tex. Admin. Code § 3.37(g) (relating to the Statewide Spacing Rule)); and B) was composed of substandard acreage in the field according to the density rules in effect at the time it took its present size and shape.3333
An exception to the minimum density provision is not required for a well in a unitized
area for which the Commission has granted an entity for density order, if the sum of all applied
for, permitted, or completed producing wells in the field within the unitized area, multiplied by
the applicable density provision, does not exceed the total number of acres in the unitized area.
The operator must indicate the docket number of the entity for density order on the application
form.
3334
[b] Substandard Acreage Permitting.
An application for a permit to drill on a lease, pooled unit, or unitized tract composed of
substandard acreage must include a certification in a prescribed form indicating the date the lease
or the drillsite tract of a pooled unit or unitized tract took its present size and shape.3335 Similar
certification is required for any application for a permit to drill on surplus acreage. 3336
(A) [t]he operator shall file the Form W-1A with the drilling permit application and shall indicate the purpose of filing. The operator shall accurately complete all information required on the form in accordance with instructions on the form;
Certifications required under this subsection shall be filed on Form W-1A, Substandard Acreage
Certification. When filing a W-1A form,
(B) [t]he operator shall list the field or fields for which the substandard acreage certification applies in the designated area on the form. If there are more than three fields for which the certification applies, the operator shall attach additional Forms W-1A and shall number the additional pages in sequence;
3333 Id. 3334 Id. 3335 Id. 3336 Id.
641
(C) [t]he operator shall file the original Form W-1A with the Commission's Austin office and a copy with the appropriate district office, unless the operator files electronically through the Commission's Electronic Compliance and Approval Process (ECAP) system; (D) [t]he operator or the operator's agent shall certify the information provided on the Form W-1A is true, complete, and correct by signing and dating the form, and listing the requested identification and contact information; and (E) [f]ailure to timely file the required information on the appropriate form may result in the dismissal of the application.3337
An exception to the minimum density provision is not required for the first well in a field
on a lease, pooled unit, or unitized tract composed of substandard acreage, when the leases, or
the drillsite tract of a pooled unit or unitized tract either:
(A) took its present size and shape prior to the date of attachment of the voluntary subdivision rule (16 Tex. Admin. Code § 3.37(g) (relating to Statewide Spacing Rule)); or (B) took its present size and shape after the date of attachment of the voluntary subdivision rule (16 Tex. Admin. Code § 3.37(g) (relating to Statewide Spacing Rule)) and was not composed of substandard acreage in the field according to the density rules in effect at the time it took its present size and shape.3338
[c] Surplus Acreage Permitting.
An application to drill a well for oil, gas, or geothermal resource on a drilling unit
composed of surplus acreage, commonly referred to as the “tolerance well,” may be granted as
regular when the operator seeking such permit certifies to the Commission in a prescribed form
the necessary data to show that such permit is needed to develop a lease, pooled unit, or unitized
tract to final density, and only in the following circumstances:
(1) when the amount of surplus acreage equals or exceeds the maximum amount provided for tolerance acreage by special or county regular rules for the field, provided that this paragraph does not apply for a lease, pooled unit, or unitized tract that is completely developed with optional units and the special or county
3337 Id. 3338 Id.
642
regular rules for the field do not have a tolerance provisions expressly made applicable to optional proration units; (2) if the special or county regular rules for the field do not have a tolerance provision expressly made applicable to optional proration units, when the amount of surplus acreage equals or exceeds one-half of the smallest amount established for an optional drilling unit; or (3) if the applicable rules for the field do not have a tolerance provision for the standard drilling or proration unit, when the amount of surplus acreage equals or exceeds one-half the amount prescribed for the standard unit.3339
[d] Drilling Unit Dissolution.
If two or more separate tracts are joined to form a unit for oil or gas development, the
unit is accepted by the Commission, and the unit has produced hydrocarbons in the preceding
twenty years, the unit may not thereafter be dissolved into the separate tracts with the rules of the
Commission applicable to each separate tract if the dissolution results in any tract composed of
substandard acreage for the field from which the unit produced, unless the Commission approves
such dissolution.3340
The Commission shall grant approval only after application, notice, and an opportunity
for hearing. The applicant seeking the unit dissolution shall provide a list of the names and
addresses of all current lessees and unleased mineral interest owners of each tract within the
joined or unitized tract at the time the application is filed. The Commission shall give notice of
the application to all current lessees and unleased mineral interest owners of each tract within the
joined or unitized tract. Additionally, if one or more wells on the unitized tract has produced
from the field within the twelve-month period prior to the application, the applicant shall include
on the list all affected persons (e.g., the operators and unleased mineral interest owners of all
adjacent offset tracts, and the operators and unleased mineral interest owners of all tracts nearer
3339 Id. 3340 Id.
643
to the proposed well than the prescribed minimum lease-line spacing distance), and the
Commission shall give notice of the application to these affected persons.3341
[6] – Horizontal Drilling.
[a] Horizontal Drilling Units.
The maximum diagonal for each proration unit containing a horizontal drainhole well
shall be the horizontal drainhole displacement of the longest horizontal drainhole for the well
plus (A) 2,100 feet for fields that are regulated under statewide rules or (B) the maximum
diagonal allowed for fields where the special field rules specify a maximum diagonal.3342
A single well may be developed with more than one horizontal drainhole originating
from a single vertical wellbore. A horizontal drainhole well developed with more than one
horizontal drainhole shall be treated as a single well. The horizontal drainhole displacement used
for calculating additional acreage assignment for a well completed with multiple horizontal
drainholes shall be the horizontal drainhole displacement of the longest horizontal drainhole plus
the projection of any other horizontal drainhole on a line that extends in a 180 degree direction
from the longest horizontal drainhole.
3343
Acreage may be assigned to each horizontal drainhole well for the purpose of allocating
allowable oil or gas production up to the amount specified by applicable rules for a proration unit
for a vertical well plus the additional acreage assignment as provided in this paragraph.
3344
3341 Id.
Assignment of acreage to proration and drilling units for horizontal drainhole wells must be done
3342 Id. § 3.86. 3343 Id. 3344 Id.
644
in accordance with Statewide Rule 40, section 3.40, Title 16 of the Texas Administrative Code
(relating to Assignment of Acreage to Pooled Development and Proration Units).3345
The maximum daily allowable for a horizontal drainhole well shall be determined by
multiplying the applicable allowable for a vertical well in the field with a proration unit
containing the maximum acreage authorized by the applicable rules for the field, exclusive of
tolerance acreage, by a fraction,
(A) the numerator of which is the acreage assigned to the horizontal drainhole well for proration purposes; and (B) the denominator of which is the maximum acreage authorized by the applicable field rules for proration purposes, exclusive of tolerance acreage. The daily oil allowable shall be adjusted in accordance with Statewide Rule 49(a), 16 Tex. Admin. Code § 3.49(a) (relating to Gas-Oil Ratio), when applicable.3346
All proration and drilling units shall consist of continuous and contiguous acreage and
proration units shall consist of acreage that can be reasonably considered to be productive of oil
or gas. All points on the horizontal drainhole must be within the proration and drilling unit.
3347
[b] Horizontal Drilling Permits.
According to section 3.11, Title 16 of the Texas Administrative Code, “[a]ll wells shall
be drilled as nearly vertical as possible by normal, prudent, practical drilling operations. Nothing
in this section shall be construed to permit the drilling of any well in such a manner that the
wellbore crosses lease and/or property lines (or unit lines in cases of pooling) without special
permission.” Horizontal drilling is permissible upon approval of the proper application.
Any intent to develop a new or existing well with horizontal drainholes must be indicated
on the application to drill. An application for a permit to drill a horizontal drainhole shall include
the fees required by Statewide Rule 78, section 3.78, Title 16 of the Texas Administrative Code
3345 Id. 3346 Id. 3347 Id.
645
(relating to Fees and Financial Security Requirements), and shall be certified by a person
acquainted with the facts, stating that all information in the application is true and complete to
the best of that person's knowledge.3348
In addition to the plat requirements provided for in section 3.5, Title 16 of the Texas
Administrative Code (relating to Application to Drill, Deepen, Reenter, or Plug Back) (Statewide
Rule 5), the plat shall include the following information:
The application to drill a horizontal drainhole shall be
accompanied by a plat.
(i) the lease, pooled unit, or unitized tract, showing the acreage assigned to the drilling unit for the proposed well and the acreage assigned to the drilling units for all current applied for, permitted, or completed oil, gas, or oil and gas wells on the lease, pooled unit, or unitized tract; (ii) the surface location of the proposed horizontal drainhole well, and the proposed path, penetration points, and terminus locations of all drainholes; (iii) two perpendicular lines from the nearest point on the lease line, pooled unit line, or any unleased interest in a tract of the pooled unit, depicting the distance(s) to:
(I) the penetration points; and (II) the terminus location;
(iv) perpendicular lines providing the distance in feet from the two nearest non-parallel survey lines to the terminus location(s); (v) a line providing the distance in feet from the closest point along the horizontal course(s) of the drainhole(s) to the nearest point on the lease line, pooled unit line, or unitized tract line. If there is an unleased interest in a tract of the pooled unit that is nearer than the pooled unit line, the nearest point on that unleased tract boundary shall be used; and (vi) lines from the nearest oil, gas, or oil and gas well, applied for, permitted or completed in the same lease or pooled unit and in the same field and reservoir depicting the distance to:
(I) the penetration point(s); (II) the closest point along the horizontal course(s) of the drainhole(s); and (III) the terminus location(s).3349
3348 Id.
3349 Id.
646
A directional survey from the surface to the farthest point drilled on the horizontal
drainhole shall be required for all horizontal drainholes. The directional survey and
accompanying reports shall be conducted and filed in accordance with Statewide Rules 11 and
12, sections 3.11 and 3.12, Title 16 of the Texas Administrative Code (relating to Inclination and
Directional Surveys Required and Directional Survey Company Report). No allowable shall be
assigned to any horizontal drainhole well until a directional survey and survey plat has been filed
with and accepted by the Commission.3350
The required proration unit plat must depict the lease, pooled unit, or unitized tract,
showing the acreage assigned to the proration unit for the horizontal drainhole well, the acreage
assigned to the proration units for all wells on the lease, pooled unit, or unitized tract, and the
path, penetration point, and terminus of all drainholes. No allowable shall be assigned to any
horizontal drainhole well until the proration unit plat has been filed with and accepted by the
Commission.
3351
If after completion of the horizontal drainhole well, the Commission determines that the
drainhole as drilled is not reasonable with respect to the drainhole represented on the plat filed
with the drilling permit application, an amended drilling permit application and plat shall be
filed.
3352
The Commission may grant exceptions to this section in order to prevent waste, prevent
confiscation, or to protect correlative rights. If a permit to drill a horizontal drainhole requires an
exception to this section, the notice and opportunity for hearing procedures for obtaining
exceptions to the density provisions prescribed in Statewide Rule 38, section 3.38, Title 16 of the
Texas Administrative Code (relating to Well Densities), shall be followed as set forth in
3350 Id. 3351 Id. 3352 Id.
647
Statewide Rule 38(h), section 3.38(h), Title 16 of the Texas Administrative Code (relating to
Well Densities). The Commission presumes that for each adjacent tract and each tract nearer to
any point along the proposed or existing horizontal drainhole than the prescribed minimum
lease-line spacing distance, affected persons that will have to be notified include the designated
operator, all lessees of record for tracts that have no designated operator, and all owners of
record of unleased mineral interests.3353
[7] – Matters Covered.
The Commission has jurisdiction over all common carrier pipelines in Texas, oil and gas
wells in Texas, persons owning or operating pipelines in Texas, and persons owning or engaged
in drilling or operating oil or gas wells in Texas.3354 In addition, the Commission may adopt all
necessary rules for governing and regulating persons and their operations under the jurisdiction
of the Commission, including such rules as the Commission may consider necessary and
appropriate to implement state responsibility under any federal law or rules governing such
persons and their operations.3355
§ 44.02 Types of Texas Pooling Statutes.
The Commission also oversees well spacing, well density, and
royalties, most of which are discussed below.
[1] – Mineral distinctions.
According to the Texas Natural Resources Code, section 85.001, “‘[o]il’ means crude
petroleum oil, crude petroleum, and crude oil, and ‘gas’ means natural gas. These terms shall not
be construed as referring to substances different from those referred to in this chapter and other
3353 Id. 3354 Tex. Nat. Res. Code Ann. § 81.051 (West 2010). 3355 Id. § 81.052.
648
laws as ‘oil and gas’ and these terms mean the same whether used in this chapter or in other laws
relating to the conservation of oil and gas.”3356
[2] – Split by Depth.
Texas law does not appear to regulate wells based on depth.
[3] – Spacing Rules.
The Statewide Spacing Rule states that “[n]o well for oil, gas, or geothermal resource
shall hereafter be drilled nearer than 1,200 feet to any well completed in or drilling to the same
horizon on the same tract or farm, and no well shall be drilled nearer than 467 feet to any
property line, lease line, or subdivision line; provided the Commission, in order to prevent waste
or to prevent the confiscation of property, may grant exceptions to permit drilling within shorter
distances than prescribed in this paragraph when the Commission shall determine that such
exceptions are necessary either to prevent waste or to prevent the confiscation of property.” This
provision also sets forth the procedure for requesting an exception to the spacing rule.3357 It is
important to note that many, if not most, fields in Texas have their own special field rules and
will not be regulated by the standard set forth above.3358
Horizontal drilling regulations can be found in section 3.86, Title 16 of the Texas
Administrative Code. Under this regulation, no point on a horizontal drainhole shall be drilled
nearer than 1,200 feet (horizontal displacement), or other between-well spacing requirement
under applicable rules for the field, to any point along any other horizontal drainhole in another
well, or to any other well completed or drilling in the same field on the same lease, pooled unit,
3356 Id. § 81.051. 3357 16 Tex. Admin. Code § 3.37 (2011). 3358 Jack M. Wilhelm, What Every Landman Should Know About the Railroad Commission of Texas, Tex. Land Inst., 6 (2005), http://blumtexas.tripod.com/sitebuildercontent/sitebuilderfiles/wilhelm.pdf.
649
or unitized tract.3359 No point on a horizontal drainhole shall be drilled nearer than 467 feet, or
other lease-line spacing requirement under applicable rules for the field, from any property line,
lease line, or subdivision line.3360 All wells developed with horizontal drainholes shall comply
with applicable spacing and well density rules.3361
[4] – Size.
Section 3.38, Title 16 of the Texas Administrative Code (relating to Well Densities), sets
forth the standard well densities. This section provides the means for analyzing well density
based on available acreage. The standard drilling unit for all oil, gas, and geothermal resource
fields, absent special field rules, are as follows:
Spacing Rule Acreage Requirement
(1) 150–300 2
(2) 200–400 4
(3) 330–660 10
(4) 330–933 20
(5) 467–933 20
(6) 467–1,200 40
(7) 660–1,320 40
Thus, the minimum requirement for a drilling unit is forty acres per well. The spacing
rules listed in this section are not exclusive. If any spacing rule not listed in this section is
brought to the attention of the Commission, it will be given an appropriate acreage
assignment.3362
[5] – Minimum Operator Control.
The Texas Natural Resources Code does not specify the minimum operator controls.
[6] – Review of Election Rights/Options.
Chapter 102 of the Texas Natural Resources Code is referred to as the Mineral Interest
Pooling Act (“MIPA”). Section 102.051 sets forth the rights in a pooled unit. For the purpose of
determining the portions of production owned by the persons owning interests in the pooled unit,
the production shall be allocated to the respective tracts within the unit in the proportion that the
number of surface acres included within each tract bears to the number of surface acres included
in the entire unit. However, if the Commission finds that allocation on a surface-acreage basis
does not allocate to each tract its fair share, the Commission shall allocate the production so that
each tract will receive its fair share, which for any nonconsenting owner shall be no less than he
would receive under a surface-acreage allocation.3363
As to an owner who elects not to pay his proportionate share of the drilling and
completion costs in advance, the Commission shall make provision in the pooling order for
reimbursement solely out of production, to the parties advancing the costs, of all actual and
reasonable drilling, completion, and operating costs plus a charge for risk not to exceed 100
percent of the drilling and completion costs. If there is a dispute relative to the costs, the
Commission shall determine the proper costs and their allocation among working interest owners
after due notice to interested parties and a hearing on the costs.
3364
3362 Id.
3363 Tex. Nat. Res. Code Ann. § 102.051 (West 2010). 3364 Id. § 102.052.
651
There is no forced pooling in Texas. However, MIPA contains a provision where the
owner of a tract of land can force the tract’s inclusion in a pool. Recently, larger pool operations
have attempted to use MIPA to require smaller units to submit to the pool.
652
§ 45.01 Analysis of Utah Regulatory Framework.
[1] – Name of Governing Body.
In Utah, the oil and gas industry general pooling and unitization and compulsory pooling
and unitization are regulated under Chapter Six of Title Forty of the Utah Code Ann. by the
Division of Oil, Gas, and Mining within the Department of Natural Resources.3365
[2] – Membership on the Governing Board.
Under the statute, the Board of Oil, Gas, and Mining (“Board”) is the “policy making
body” for the Division.3366
(1) two members knowledgeable in mining matters; (2) two members knowledgeable in oil and gas matters; (3) one member knowledgeable in ecological and environmental matters; (4) one member who is a private land owner, owns a mineral or royalty interest, and is knowledgeable in those interests; and (5) one member who is knowledgeable in geological matters.
The Board consists of seven members appointed by the governor
with the consent of the Senate. No more than four members may be from the same political
party. The members must include the following:
3367
The terms are staggered so that approximately half of the Board is appointed every two
years. As terms of current Board members expire, the governor appoints each new member or
reappointed member to a four-year term. When a vacancy occurs in the membership for any
reason, the replacement is appointed for the unexpired term by the governor with the consent of
the Senate.
3368
[3] – Scope of Authority.
3365 Utah Code Ann. § 40-6-6.5 (Lexis 2011); see also id. § 40-6-8. 3366 Id. § 40-6-4. 3367 Id. 3368 Id.
653
The Board has the authority to regulate all operations for and related to the production of
oil or gas.3369 This includes regulation of oil and gas operations on federal lands to the extent that
such regulation does not conflict with Federal law.3370 The Division also has the right to name oil
and gas fields.3371
The director of the Division is appointed by the director of the Department of Natural
Resources with the “concurrence” (presumably meaning the approval) of the Board.
3372 The
director is the executive and administrative head of the Division of Oil, Gas, and Mining and
must be a person “experienced in administration” and “knowledgeable in the extraction of oil,
gas, and minerals.”3373 The director or an authorized agent has the right at reasonable times to
enter and inspect any oil or gas properties and wells to investigate or conduct tests necessary to
determine compliance with the statutes, general rules, special rules, and orders.3374
Prohibition of waste is a chief purpose of the Conservation Act.
3375
[t]he locating, drilling, equipping, operating, or producing of any oil or gas well in a manner that causes reduction in the quantity of oil or gas ultimately recoverable . . . [causing] unnecessary wells to be drilled, or [causing] the loss or destruction of oil or gas either at the surface or subsurface . . . [or] [t]he production of oil or gas in excess of . . . [t]ransportation or storage facilities.”
“Waste” is defined
under the regulations to include, inter alia,
3376
Special rules and orders may be granted by the Board and prevail over general rules.
3377
3369 Id. § 40-6-5.
Exceptions to the general rules may be granted by the director or authorized agent for good cause
3370 Utah Admin. Code r. 649-2-1 (2011). 3371 Id. r. 649-2-7. 3372 Utah Code Ann. § 40-6-15 (Lexis 2011). 3373 Id. 3374 Utah Admin. Code r. 649-2-5. 3375 See Utah Code Ann. § 40-6-3 (Lexis 2011). 3376 Utah Admin. Code r. 649-2-1; see also Utah Code Ann. § 40-6-2 (Lexis 2011). 3377 Utah Admin. Code r. 649-2-1 (2011).
654
shown.3378 General rules may also be suspended by unit orders.3379 Drilling unit orders must be
“just and reasonable.”3380 In addition, all Division orders must be supported by “substantial
evidence.”3381 The Division has the authority to grant exceptions to well location requirements
after receipt of a proper written application for the exception well location and either written
consent from all owners within a 460 foot radius of the proposed well location when the
exception is to the requirements of general siting requirements3382 or written consent from all
owners of directly or diagonally offsetting drilling units when the exception is to an order of the
Board establishing oil or gas well drilling units.3383
[4] – Process for Pooling.
[a] Request for Hearings and Hearings.
Procedures for pooling before the Division are generally conducted by informal
adjudicative proceeding.3384 The procedures and proceedings must comply with the provisions
of the more broadly applicable state Administrative Procedures Act.3385 Presiding officers may
convert an informal proceeding to a formal one if the presiding officer determines it is in the
public interest and there is no prejudice to any party.3386 Pooling proceedings brought by owners
are initiated by a Request for Agency Action (proceedings may also be initiated by the Division
itself) (“Request”).3387
3378 Id.
A Request must be in writing and signed by the person seeking action by
the agency or by his representative and must include the names and addresses of all persons to
whom a copy of the request for agency action is being sent, the agency's file number or other
3379 Id. 3380 Utah Code Ann. § 40-6-6 (Lexis 2011). 3381 See Cowling v. Bd. of Oil, Gas & Min., Dept. of Natural Res. for Utah, 830 P.2d 220, 224 (Utah 1991). 3382 See Utah Admin. Code r. 649-3-2 (2011). 3383 Id. r. 649-3-3. 3384 See id. r. 649-10-1. 3385 Utah Code Ann. § 63-G-4 (Lexis 2011). 3386 Utah Admin. Code r. 649-10-1 (2011). 3387 Id. r. 649-10-3.
655
reference number, if known, the date that the request for agency action was mailed, the legal
authority and jurisdiction under which the agency action is requested, the relief or action sought
from the Division, and the facts and reasons forming the basis for relief or action.3388 The person
requesting agency action must file the request with the Division and send a copy by mail to each
person known to have a direct interest in the requested agency action unless previously waived in
writing by each person entitled to receive notice of the requested agency action.3389
The presiding officer must “promptly” review a Request for Agency Action and must
either notify the requesting party in writing that the request is granted and when the adjudicative
proceeding is to be completed, notify the requesting party in writing that the request is denied, or
notify the requesting party that further proceedings are required to determine the agency's
response to the request.
3390
The Division must mail any required notice to all parties. The notice must state the
division's file number or other reference number, the name of the proceeding, and designate that
the proceeding is to be conducted informally. The notice must also state the time and place of
any scheduled hearing, the purpose for which the hearing is to be held, and give notice that a
party who fails to attend or participate in a scheduled and noticed hearing may be held in default.
If a hearing is required by statute or rule, or if a hearing is permitted by rule and may be
requested by a party with the time prescribed by rule, the notice must also state the parties' right
to request a hearing and the time within which a hearing may be requested under the agency's
rules. If a hearing is scheduled, the notice must give the name, title, mailing address, and
telephone number of the presiding officer.
3391
3388 Id. r. 649-10-2.3.
3389 Id. r. 649-10-2.4. 3390 Id. r. 649-10-2.6. 3391 Id. r. 649-10-2.7.
656
Within a reasonable time after the close of an informal adjudicative proceeding, the
presiding officer shall issue a signed order in writing that states the decisions and reasons for the
decision.3392 An appeal or review must be filed with the secretary of the Board within 30 days of
the issuance of the order.3393 It must state the grounds for review and the relief requested.3394
The Board must review appeals within a reasonable time, and they may require briefing or
hearings.3395 After review the Board must issue within a reasonable time an order stating the
statute or rule permitting or requiring review, a statement of issues, findings of fact, conclusions
of law, and whether the decision of the officer is affirmed, reversed, modified, and whether the
case is remanded for further proceedings.3396
[b] Unitization.
The Board’s authority to issue drilling unit orders in a pool (drilling units being a
subsection of a pool with one well) is provided for under Section 40-6-6. Within each drilling
unit, only one well may be drilled for production from the common source of supply, except as
noted below.3397 Although there is no mandated unit acreage, a drilling unit may not be smaller
than the maximum area that can be efficiently and economically drained by one well and it shall
be of uniform size and shape, except when it must differ for geologic or geographic reasons.3398
Drilling unit orders must specify the unit borders and well location and may be modified to
change well location, unit boundaries, or provide for additional wells.3399
The Board’s authority to issue pool or field unit orders is provided for under Code
Section 40-6-8. An order prescribing a plan for unit operations must include the following
information:
(1) a description of the unit; (2) a description of the planned operations; (3) an allocation of the production to the separate tracts within the unit, consistent with any voluntary agreements between owners; (4) a provision for allocation and adjustments to production rights of non-royalty owners based upon their cost contribution, including investment in physical assets and service of the unit operations; (5) a designation of a unit operator; (6) a timeline for unit operations; and (7) any necessary financing arrangements if an owner elects to be carried.3400
An application for an exception to general rules or a Board drilling unit order must state
the reasons why such an exception is necessary or desirable and be accompanied by a plat
showing:
(1) the location at which an oil or gas well could be drilled in compliance with general siting requirements or a Board drilling unit order; (2) the location at which the applicant requests permission to drill; (3) the location at which oil or gas wells have been drilled or could be drilled in accordance with general siting requirements or a Board drilling unit order directly or diagonally offsetting the proposed exception; and (4) either the names of owners of all lands within a 460 foot radius of the proposed well location when the exception is to the requirements of general siting requirements, or the names of owners of all directly or diagonally offsetting drilling units when the exception is to an order of the Board establishing oil or gas drilling units.3401
No exception may prevent any owner of adjacent land from drilling a well at locations permitted
by general siting requirements; and the Board or Division may take action to offset the advantage
3400 Id. § 40-6-8(3). 3401 Id.
658
obtained by the party seeking the exception over other producers by reason of the exception
location.3402
[c] Compulsory Pooling.
Compulsory pooling within a drilling unit is provided for under Section 40-6-6.5.
Compulsory pooling is unnecessary if there is a written agreement between all owners.3403 Under
compulsory pooling, non-consenting operators are paid their share of profits, minus their share of
drilling costs, plus a penalty of 150 percent to 300 percent of drilling costs (as determined by the
Board).3404 Unleased landowners receive the average landowner's royalty attributable to each
tract within the drilling unit.3405
§ 45.02 Types of Utah Pooling Statutes.
[1] – Mineral and Depth Distinctions.
In Utah, the pooling and unitization statutes (including the compulsory pooling section)
do not make any distinction between oil and gas, and coalbed methane is defined as natural gas
under the Conservation Act. 3406
[2] – Spacing Rules.
Pooling and unitization are not expressly restricted to any
particular strata or depth.
The Board has the authority to regulate the spacing of wells.3407
3402 Id.
The Board’s default well
spacing rules are provided for at Utah Administrative Code rule 649-3-2. Thus, in the absence of
special orders of the Board establishing drilling units or pool-wide rules, each oil and gas well
shall be located in the center of a 40-acre quarter-quarter section, or a substantially equivalent lot
3403 Id. § 40-6-6.5(2). 3404 Id. § 40-6-6.5(4)(d). 3405 Id. § 40-6-6.5. 3406 Id. § 40-6-6 (providing for the creation of drilling units); id. § 40-6-6.5 (providing for compulsory pooling); id. § 40-6-8 (providing for pool and field wide unitization); see id. § 40-6-2 (defining “natural gas” to include coal bed methane); see also Utah Admin. Code r. 649-1 (2011). 3407 Utah Code Ann. § 40-6-5 (Lexis 2011).
659
or tract or combination of lots or tracts as shown by the most recent governmental survey, with a
tolerance of 200 feet in any direction from the center location, a “window” 400-foot square.3408
Wells cannot be drilled or completed within 920 feet of another well in the same pool.3409 The
Division may restrict well locations adjacent to existing drilling units to ensure orderly
development.3410 Default horizontal well spacing units are 640 acres.3411 Horizontal wells must
be no closer than 660 feet from a drilling unit or spacing unit boundary,3412 and must be no
closer than 1,320 feet from any vertical well completed in the same formation.3413
The Division has the authority to grant exceptions to well location requirements after
receipt of the following from the proposed operator:
(1) proper written application for the exception well location; (2) written consent from all owners within a 460 foot radius of the proposed well location when such exception is to the requirements of general siting requirements;3414 or (3) written consent from all owners of directly or diagonally offsetting drilling units when such exception is to an order of the Board establishing oil or gas well drilling units.3415
An application for an exception to general rules or a Board drilling unit order must state
the reasons why such an exception is necessary or desirable and be accompanied by a plat
showing the following information:
(1) the location at which an oil or gas well could be drilled in compliance with general siting requirements or a Board drilling unit order; (2) the location at which the applicant requests permission to drill; (3) the location at which oil or gas wells have been drilled or could be drilled, in accordance with general siting requirements or Board drilling unit order, directly or diagonally
3408 Utah Admin. Code r. 649-3-2. 3409 Id. 3410 Id. 3411 Id. 3412 Id. 3413 Utah Admin. Code r. 649-3-2 (2011). 3414 See id. 3415 Id. r. 649-3-3.
660
offsetting the proposed exception; (4) the names of owners of all lands within a 460 foot radius of the proposed well location when such exception is to the requirements of general siting requirements; or (5) the names of owners of all directly or diagonally offsetting drilling units when such exception is to an order of the Board establishing oil or gas drilling units.3416
No exception may prevent any owner of adjacent land from drilling a well at locations permitted
by general siting requirements; and the Board or Division may take action to offset the advantage
obtained by the party seeking the exception over other producers by reason of the exception
location.
3417
[3] – Size.
There is no statutorily-mandated field unit size.3418 Utah expressly rejects the Texas
cross-conveyance theory of pooling. 3419 Yet a drilling unit may not be smaller than the
maximum area that can be efficiently and economically drained by one well and it shall be of
uniform size and shape, except when it must differ for geologic or geographic reasons. 3420
Neither is there any statutorily-mandated field unit size, although of course any determination
(like all Division orders) must be supported by “substantial evidence.”3421 No express pooling
provisions are applicable to horizontal wells except for the spacing rules stated above.3422
[4] – Minimum Operator Control.
In Utah, there is no mandated ownership percentage for an operator to request a
compulsory pooling order on a drilling unit. However for pool-wide unitization orders, 70
3416 Id. 3417 Id. 3418 See id. 3419 See Utah Code Ann. § 40-6-8(11) (Lexis 2011). 3420 Id. § 40-6-6. 3421 See id. § 40-6-8; see also Cowling v. Bd. of Oil, Gas & Min., Dept. of Natural Res. for State of Utah, 830 P.2d 220, 224 (Utah 1991). 3422 There are some non-pooling regulatory provisions applicable to horizontal wells, such as the permit diagramming requirement under Utah Admin. Code r. 649-3-4 and the well log filing requirement under Utah Admin. Code r. 649-3-21.
661
percent of production owners and cost providers must approve any order before it can take
effect.3423
[5] – Review of Election Rights/Options.
Under compulsory pooling, nonconsenting operators are paid their share of profits, minus
their allocated share of drilling costs, plus a penalty of 150 percent to 300 percent of drilling
costs (as determined by the Board).3424 Unleased landowners receive the average landowner's
royalty attributable to each tract within the drilling unit.3425
The Vermont Natural Gas and Oil Conservation Act (“Act”) gives the Natural Gas and
Oil Resources Board (“Board”) jurisdiction over pooling and unitization issues. 3426
[2] – Membership on the Governing Body.
The Board consists of five members who are appointed by the Vermont governor
(“Governor”) with the advice and consent of the state senate. Appointments are for a term of
three years and, in the event of death or resignation, the successor will serve out the term of the
deceased or resigned member. The terms of members initially appointed are set so that not more
than two terms will expire in the same year. Annually, in February after new appointments, the
Governor will designate a chairman of the Board. 3427
In order for the Board to function in the best interests of the people of the state,
Board members should have knowledge of (1) geology; (2) engineering; (3) law; (4) state and
local government; (5) economic development; (6) environmental protection; (7) regional
planning; (8) agriculture; or (9) related fields of knowledge.
3428
A person may not be a member of the Board if that person is one of the following:
(1) employed or holds any official relation to any company that is subject to the supervision of the Board; (2) engaged in the management of such company; (3) owns stock, bonds or other securities in the company; or (4) in any manner, connected with the operation of such company in Vermont. 3429
3426 Vt. Stat. Ann. tit. 14, § 505 (2011).
3427 Id. § 504. 3428 Id. 3429 Id.
663
A member cannot participate in any action of the Board that involves himself or any
person engaged in oil and gas development in which he has a financial interest. 3430 And each
prospective appointee or member of the board shall have the affirmative duty to disclose any
actual or potential conflicts of interest to the other members of the Board. 3431
[3] – Scope of Authority.
The Board has the authority over all lands and over all oil and gas resources to fulfill the
purposes of the Act. The purposes of the Act are to do the following:
(1) encourage oil and gas exploration and production; (2) protect property rights and interests of all citizens; (3) prevent long-term harm to the environment and other resources that might occur through oil and gas activities; (4) protect correlative rights; (5) prevent undue waste of oil and gas; and (6) promote the greatest ultimate recovery of oil and gas, consistent with technology and economic conditions. 3432
The Board has the authority to prevent the waste of oil and gas, promote conservation,
protect correlative rights, and otherwise administer and enforce the Act. In the event of a
conflict, the Board’s duty to prevent waste is paramount.
3433
(1) inefficient, excessive, or improper use or the unnecessary dissipation of reservoir energy; (2) inefficient storing of oil or gas; (3) locating, drilling, equipping, operating, or producing of an oil and gas well in a manner that causes or tends to cause reduction in the quantity of oil or gas which would be ultimately recoverable from a reservoir under prudent and proper operations, or that causes or tends to cause unnecessary wells to be drilled, or that causes or tends to cause surface or subsurface loss or destruction of oil or gas; and (4) unauthorized flaring of gas produced from an oil and condensate well after the Board has found that the use of gas is, or will be, economically feasible within a reasonable time on terms that are just and reasonable.
Waste includes the following:
3434
The Board, without limiting its general authority, may, among other rights:
(1) require identification of ownership of oil and gas wells, producing leases, tanks, processing plants, structures, and facilities for the transportation or refining of oil and gas; (2) require the making and filing of well logs, directional surveys, and reports on well location, drilling and production; (3) provide that all such records marked “confidential” shall be kept confidential for two years after their filing, unless the owner gives written permission to release them at an earlier date; (4) require the drilling, casing, and installation of proper equipment and facilities, operating, and plugging of wells . . .; (5) require the testing of wells used in connection with the production of oil and gas . . .; (7) require that production from wells be separated into gaseous and liquid hydrocarbons; (8) require that wells be operated at efficient gas-oil or water-oil ratios or that production be limited from wells with inefficient gas-oil or water-oil ratios; . . . (12) require the filing of reports, plats, and other data related to matters within the Board's jurisdiction; (13) regulate the drilling, testing, equipping, completing, operating, producing, and plugging of wells, and all other operations for the production of oil or gas; . . . (15) regulate the spacing or locating of wells; . . . (18) determine the amount of oil or gas that may be produced without waste from any unit, reservoir, or field, and allocate the allowed production to and among the wells in such fields or reservoirs; . . . (20) identify reservoirs and classify or reclassify them as oil or gas reservoirs, and classify or reclassify wells as oil or gas wells; and (21) adopt rules and make and enforce orders reasonably necessary to prevent waste, to protect correlative rights, to govern the practice and procedure before the Board and otherwise administer this chapter.3435
[4] – Process for Pooling.
[a] Establishment of Drilling and Pooling Units.
The Board will regulate the spacing and location of oil and gas wells by the establishment
of drilling units whenever reasonably necessary to prevent waste and to protect correlative
rights.3436
3435 Id. § 505(b).
The drilling units that the Board can establish are known as development drilling
units. “Development drilling unit” means the area attributed by the Board to a well drilled or to
3436 Id. § 522(a).
665
be drilled in a known reservoir, for the purpose of allocating production so as to prevent waste
and protect correlative rights. 3437
An order establishing development drilling units for a reservoir will cover all lands
believed to be underlain by that reservoir, and may be modified by the Board from time to time
based on additional geological and engineering information. The Board may grant exceptions to
the size and shape of any development unit or units, or may change the size or shape of any
development unit or units. Additionally, the Board may permit the drilling of additional wells if
such actions are reasonably necessary to prevent waste or to protect correlative rights. No well
shall be commenced into that reservoir after the date of the notice of hearing called to establish
development units in a reservoir, unless expressly authorized by the Board, until an order
establishing development drilling units has been adopted.
3438
The Board may also establish an exploratory drilling unit whenever a well is to be drilled
to test for the existence of a reservoir.
3439 “Exploratory drilling unit” means the area attributed
by the Board to the first well drilled or to be drilled to test for a reservoir, for the purpose of
allocating production so as to prevent waste and to protect correlative rights.3440
The order establishing the exploratory drilling unit will specify the size and shape of the
exploratory unit. If insufficient geological and engineering information is available to establish
the proper unit size, the Board may establish a temporary unit to ensure orderly development of
the reservoir pending the availability of additional information.
3441
In addition to the authority for the establishment of drilling units for individual wells, the
Board may establish field-wide drilling units comprised of one or more reservoirs or parts
properly coming before the Board and may make reports and recommendations to the Board.3451
To enable this, the Board needs to, but has yet to, adopt rules with regard to hearings to be
conducted before examiners. After the examiner hears an issue, the Board may enter orders
based upon the reports and recommendations it receives from its examiners.3452
Although the Board has not done so, it also needs to promulgate rules to provide
procedures for rehearing before the Board and times within which requests for a rehearing must
be made. Upon request of an interested party, the Board will hold a rehearing.
3453 At any
rehearing, the parties shall have the right to present additional testimony and documentary
evidence. 3454
The Board has the ultimate authority to hear any matter or proceeding if the following
occurs:
(1) it desires to hear the matter; (2) the matter is initiated on the motion of the Board and is for the purpose of enforcing, amending, establishing, or revoking a statewide rule, regulation, or order; or (3) any person who may be affected by the matter or proceeding files with the board, more than ten days prior to the date set for the hearing, a written objection to the hearing before an examiner.3455
In any matter properly before it, the Board may compel the attendance of witnesses and
the production of documentary evidence. A party shall be entitled to the issuance of subpoenas
by making a written request. In all other respects, the Vermont Rules of Civil Procedure are to
cost incident to conducting such operations; and (3) the development or operation is reasonably
necessary to prevent waste.3461
The order will be upon terms and conditions that are just and reasonable and shall include
a prescribed plan for unit operation, which must contain the following information:
(1) a description of the reservoir, reservoirs, or parts thereof to be operated as a unit, termed the unitized area; (2) a statement of the nature of the operations contemplated; (3) an allocation of production and costs to the separately owned tracts in the unitized area. The allocation will be in accord with the agreement, if any, of the interested parties. If there is no such agreement, production shall be allocated in a manner calculated to ensure that each owner within the unitized area receives his or her just and equitable share of production. Costs shall be allocated on a just and reasonable basis; (4) a provision, if necessary, permitting any owner who has involuntarily unitized to pay his or her share of costs out of his or her share of production, plus a supervision, risk, and interest assessment not to exceed 300 percent of that owner's share of the costs; (5) a provision for the supervision and conduct of the unit operations, in respect to which each owner will have a vote with a value corresponding to the percentage of the costs of unit operations chargeable against its interest; (6) the time when the unit operations will commence and the manner in which, and the circumstances under which, the unit operations will terminate; and (7) such additional provisions as are found to be appropriate for carrying out the unit operations.3462
An order of the Board providing for unit operations will not become effective until the
plan for unit operations has been approved by the appropriate persons, and the Board has made a
finding, either in the order providing for unit operations or in a supplemental order, that the plan
for unit operations has been approved.
3463
If the plan for unit operations has not been approved at the time the order providing for
unit operations is made, the Board, upon application and notice, will hold supplemental hearings
to determine if and when the plan for unit operations has been approved. If the required persons
establish a temporary development unit pending the availability of the necessary information. In
order that all owners are accorded substantially equal treatment, development units shall be of
approximately uniform size if consistent with available geological and engineering
information.3474
[5] – Minimum Operator Control.
The Act does not provide any additional information on size.
If an order of the Board that provides for unit operations is to become effective, then the
unit operation plan needs to have been approved in writing by the owners who, under the Board's
order, will be required to pay at least 60 percent of the costs of the unit operation, and also by
those persons who own at least 60 percent of the royalties.3475
(1) if the amendment affects only the rights and interests of the owners, the approval of the amendment by the owners of interests free of cost will not be required; (2) the order of amendment will not change the percentage established in the original order for the allocation of oil and gas as established for any separately owned tract, except with the consent of all persons owning oil and gas rights in the tract; and (3) the order of amendment will not change the percentage established in the original order for the allocation of cost as established for any separately owned tract, except with the consent of all owners in the tract.
Additionally, an amended order
that provides for unit operations, under particular circumstances, needs to be approved by the
required persons. These circumstances and persons are as follows:
§ 47.01 Analysis of Virginia Regulatory Framework.
[1] – Name of Governing Body.
The Virginia Gas and Oil Act (the “Act”) was enacted by the 1990 Session of the General
Assembly. The 1990 Act regulates the exploration for and development, production, utilization
and conservation of the Commonwealth’s gas and oil resources. 3477 The 1990 Act and the
regulations promulgated thereunder significantly revised the predecessor Oil and Gas Act
adopted in 1982 and consolidated the Virginia Well Review Board and the Virginia Oil and Gas
Conservation Board into the Virginia Gas and Oil Board (the “Board”).3478
The Board was established with statewide jurisdiction as the governing body within the
Department of Mines, Minerals and Energy, Division of Gas and Oil (the “Division”) for the
purpose of administering and interpreting the statutory provisions of the Act directed toward
regulating the Commonwealth’s gas and oil resources.
3479
[2] – Membership of the Governing Body.
As such, the Board is an
administrative agency of the Commonwealth.
The Board is composed of seven members, the Chairman and six additional members
appointed by the Governor and confirmed by the General Assembly as follows: (1) two
members for an initial term of two years; (2) two for an initial term of four years; and (3) three
for initial terms of six years.3480 At all times, the Board shall consist of the following qualified
members: (1) the Director3481
3477 Va. Code Ann. § 45.1-361.3 (2010).
or his designee; (2) one but not more than one individual who is a
representative of the gas and oil industry; (3) one but not more than one individual who is a
3478 See Va. Att’y Gen. Op. No. 09-023 (June 10, 2009). 3479 Va. Code Ann. § 45.1-361.13(A) (2010) (establishing Virginia Gas and Oil Board). 3480 Id. § 45.1-361.13(B). 3481 4 Va. Admin. Code § 25-160-10 (2010). (defining “Director” as the Director of the Department of Mines, Minerals, and Energy or his authorized agent).
676
representative of the coal industry; and (4) four other individuals who are not representatives of
the gas, oil, or coal industry. 3482 In the event of a vacancy, the Governor, subject to the
confirmation of the General Assembly, must fill the seat for the unexpired term within 60 days of
the occurrence of said vacancy.3483 Further, as the member terms expire, the Governor must
appoint qualified persons whose terms are for six years from the day on which their immediate
predecessor expired.3484 The Governor must endeavor to appoint persons who reside in localities
with significant oil or gas production or storage.3485
[3] – Scope of Authority.
Pursuant to section 2.2-2813 of the Virginia
Code Ann., each Board member is entitled to receive compensation and expenses for their
services.
The 1990 Act delegated broad statutory authority to the Board. “The Board shall have
the power necessary to execute and carry out all of it duties specified in [Chapter 22.1—The
Act].”3486
B. Without limiting its general authority, the Board shall have the specific authority to issue rules, regulations or orders pursuant to the provisions of the Administrative Process Act (§ 2.2-4000 et seq.) in order to:
Furthermore, the Act provides that:
… 12. Take such actions as are reasonably necessary to carry out the provisions of [Chapter 22.1 – The Act].3487
In executing its broad authority, the Board has a duty to (1) foster, encourage and
promote the safe and efficient exploration for and development, production and conservation of
the gas and oil resources located in the Commonwealth; (2) administer a method of gas and oil
conservation for the purpose of maximizing exploration, development, production and utilization
compulsory pooling3491 orders pursuant to the Act.3492 The issue presented a situation in which a
gas owner failed to make an election under a compulsory pooling order of the Board. 3493
Pursuant to § 45.1-361.21(E) of the Act, “[a]ny person who does not make an election under the
pooling order shall be deemed to have leased his gas or interest to the gas or oil well operator as
the pooling order may provide.” Furthermore, section 45.1-361.22(6) provides that “[a]ny
person who does not make an election under the pooling order shall be deemed to have leased his
gas or interest to the coalbed methane gas well operator as the pooling order may provide.” The
question presented whether the Board’s authority to deem that the gas owner has leased his
interest in the gas to the unit operator arises out of the Commonwealth’s police power and
whether the Board’s action is a valid exercise of such police power.3494
The advisory opinion recognizes that the “deemed lease” language recited in sections
45.1-361.21(E) and 45.1-361.22(6) is mandated by the General Assembly and is not within the
Board’s general discretionary authority to alter.
3495 Therefore, the Board must include such
language in its pooling orders. Reciting the extensive list of duties and responsibilities outlined
in section 45.1-361.15, the advisory opinion concluded that the “Board is authorized and, in fact,
is mandated to issue compulsory pooling orders to deem that unleased interests are leased when
gas owners fail to elect to participate in the operation of the well . . . and that such action by the
Board is a valid exercise of the Commonwealth’s police power.”3496
[4] – Administrative Process.
3491 4 Va. Admin. Code § 25-160-10 (2010) (defining “Pooling” as the combining of all interests or estates in gas, oil, or coalbed methane drilling unit for the development and operations thereof. Pooling may be accomplished either through voluntary agreement or through a compulsory order of the Board). 3492 See Va. Att’y. Gen. Op. No. 09-018 (2009) (noting that the term “compulsory pooling” is not defined in the Code; however, the opinion defined the term as the pooling of interests within a drilling unit pursuant to § 45.1-361.21 or § 45.1-361.22). 3493 Id. at 2. 3494 Id. 3495 Id. at 3. 3496 Id. at 10.
679
The Board is scheduled to meet on the third Tuesday of the month at a time and place
designated by the Chairman. However, if no petition for action has been filed prior to the
scheduled meeting, the meeting may be cancelled by written notification by the Chairman at
least five days in advance.3497 In order to transact any business before the Board, a quorum must
be present. Four members constitute a quorum and all determinations of the Board are made by
a majority vote of the quorum present.3498
A. Any person who applies for a hearing in front of the Board pursuant to the provisions of § 45.1 – 361.20, § 45.1 – 361.21, or § 45.1 – 361.22, [discussed hereinbelow], shall simultaneously with the filing of such application, provide notice by certified mail, return receipt requested, to each gas or oil owner, coal owner, or mineral owner having an interest underlying the tract which is the subject of the hearing, and to the operator of any gas storage field certificated by the State Corporation Commission as a public utility facility whose certificated area includes the tract which is the subject of the hearing. Whenever a hearing applicant is unable to provide such written notice because the identity or location of a person to whom notice is required to be given is unknown, the hearing applicant shall promptly notify the Board of such inability.
All hearings scheduled before the Board are required
to comply with the notice provisions for publication pursuant to section 45.1 – 361.19 of the
Virginia Code Ann. which provides as follows:
B. At least 10 days prior to a hearing, the Board shall publish its agenda in newspapers of general circulation that are widely circulated in the localities where the lands that are subject of the hearing are located. The agenda shall include the name of each applicant, the localities where the lands that are the subject of the hearing are located, the purpose of the hearing, and the date, time and location thereof. C. The Board shall conduct all hearings on applications made to it pursuant to the formal litigated issues hearing provisions of the Administrative Process Act (§ 2.2-4000 et seq.). The applicant and any person to whom notice is required to be given pursuant to the provisions of subsection A of this section shall have standing to be heard at the hearing. The Board shall render its decision on such applications within thirty days of the hearing’s closing date and
3497 Va. Code Ann. § 45.1-361.14(A) (2010). 3498 Id.
680
shall provide notification of its decision to all parties to the hearing pursuant to the provisions of the Administrative Process Act.3499
The Board can establish deadlines for filing materials for meetings or hearings scheduled
on other than the third Tuesday of each month.
3500 All applications, petitions, appeals, or other
requests for Board action must be received by the Division at least 30 calendar days prior to the
regularly scheduled meeting of the Board.3501 If a completed application is not filed by the
aforementioned deadline, then it will be carried over to the next scheduled meeting of the Board.
Incomplete applications received by the Division will not be considered or scheduled until the
application is complete.3502 When required, two copies of (1) an affidavit demonstrating that due
diligence was used to locate and serve persons in accordance with section 45.1 – 361.19 of the
Virginia Code Ann. and section 25-160-40 of the Virginia Administrative Code and (2) proof of
notice by publication in accordance with section 25-160-40(D) of the Virginia Administrative
Code must be filed with the Division at least seven calendar days prior to the regularly scheduled
meeting with the Board for the application to be considered complete.3503 Once a completed
application is filed, the Division then assigns a docket number to the application and notifies the
applicant of the docket number. 3504
In addition to the above requirements, each application for a hearing before the Board
must contain the following caption headings: (1) “Before the Virginia Gas and Oil Board”; (2)
the name of the applicant; (3) the relief sought; and (4) the docket number assigned by the
Any materials submitted regarding the application or
Division. 3505 The application must be signed by the applicant, an authorized agent of the
applicant, or an attorney for the applicant, certifying that “[t]he foregoing application to the best
of my knowledge, information and belief is true and correct.”3506 Any Exhibits attached thereto
are identified by the docket number and an exhibit number.3507 Ten sets of each application and
exhibits submitted and each person offering exhibits into evidence must also have available a
sufficient number of exhibits for other persons who are subject to the provisions of sections 45.1
– 361.19 and 45.1 – 361.23 of the Virginia Code Ann. and are expected to be in attendance at
the hearing. 3508 A nonrefundable fee of $130, payable to the Treasurer of Virginia, must
accompany applications submitted for the establishment of units, spacing or pooling.3509
[5] – Applications for Field Rules.
In an effort to preserve the Commonwealth’s natural resources, Virginia has created field
rules and drilling units for wells. Field rules are rules established by order of the Board that
define a pool, drilling units, production allowable, or other requirements for gas or oil operations
within an identifiable area.3510 A drilling unit is defined as the acreage on which one gas or oil
well may be drilled.3511
(1) The name and address of the applicant and the applicant’s counsel, if any;
An application filed pursuant to section 45.1 – 361.20 of the Virginia
Code Ann. to establish or modify a field rule, a drilling unit, or drilling units requires the
following information:
(2) In the case of an application to vacate or amend an order, identification of the order to be vacated or amended; (3) A statement of the relief sought and the proposed provisions of the order or a proposed order;
(4) Citations of statutes, rules, orders and decided cases supporting the relief sought; (5) In the case where a field rule is proposed to be established or modified:
(a) A statement of the type of field (gas, oil or coalbed methane gas); (b) A description of the proposed formation or formations subject to the petition; and (c) A description of the pool or pools included in the field, based on geological and technical data, including the boundaries of the pool or pools and field, shown in accordance with the Virginia Coordinate System of 1927, as defined in Chapter 17 (§ 55-287 et seq.) of Title 55 of the Code of Virginia, also known as the State Plane Coordinate System. The boundaries of the pool or pools and field shall also be located by taking the measured distance in feet from the unit to the nearest 2.5 minute longitude line to the east and the nearest 2.5 minute latitude line to the north on the 7.5 minute (1:24,000) topographic map, with a notation of the 7.5 minute topographic map name and series;
(6) In the case where a drilling unit or units are proposed to be established or modified:
(a) A statement of the acreage to be embraced within each drilling unit; (b) A description of the formation or formations to be produced by the well or wells in the unit or units; and (c) The boundaries of the drilling unit or units shown in accordance with subdivision (5)(c) of this section;
(7) A statement of the amount of acreage to be included in the order; (8) A statement of the proposed allowable production rate or rates and supporting documentation, if applicable; (9) Evidence that any proposal to establish or modify a unit or units for coalbed methane gas will meet the requirements of § 45.1-361.20(C) of the Code of Virginia; (10) An affidavit demonstrating that due diligence was used to locate and serve persons in accordance with § 45.1-361.19 of the Code of Virginia and § 25-160-40 of the Virginia Administrative Code; and (11) When required, proof of notice by publication in accordance with § 25-160-40(D) of the Virginia Administrative Code.3512
[6] – Applications for Exceptions to Minimum Well Spacing Requirements.
3512 4 Va. Admin. Code § 25-160-50 (2010).
683
Virginia requires certain statewide spacing of wells depending on the type of well (i.e.,
oil, gas, or coalbed methane) drilled. The details regarding the spacing requirements are
discussed hereinbelow. However, in order to file an application for an exception to the statewide
spacing requirements the following information must be provided:
(1) The name and address of the applicant and the applicant’s counsel, if any; (2) In the case of an application for an exception to spacing established in a field rule, identification of the order governing spacing in the field; (3) A statement of the proposed location of the well in relation to wells permitted or for which a permit application is pending before the Division at the time of filing within the distances prescribed in § 45.1-361.17 of the Code of Virginia; (4) A description of the formation or formations to be produced by the well proposed for alternative spacing and the wells identified in subdivision 3 of this section; (5) A description of the conditions justifying the alternative spacing; (6) An affidavit demonstrating that due diligence was used to locate and serve persons in accordance with § 25-160-40 of the Virginia Administrative Code; and (7) When required, proof of notice by publication in accordance with § 25-160-40(D) of the Virginia Administrative Code.3513
[7] – Applications to Pool Interests in a Drilling Unit: Conventional Gas or Oil or
No Conflicting Claims to Coalbed Methane Gas Ownership.
An application filed pursuant to section 45.1 – 361.21 of the Virginia Code Ann. to pool
interests in a drilling unit for conventional gas or oil or for coalbed methane gas where there are
no conflicting claims to ownership of the coalbed methane gas requires the following
information:
(1) The name and address of the applicant and the applicant’s counsel, if any; (2) In the case of an application to vacate or amend an order, identification of the order to be vacated or amended;
3513 Id. § 25-160-60.
684
(3) A statement of the relief sought and the proposed provisions of the order or a proposed order; (4) Citations of statutes, rules, orders and decided cases supporting the relief sought; (5) A statement of the type of well or wells (gas, oil or coalbed methane gas); (6) The permit number or numbers, if any have been issued; (7) A plat showing the size and shape of the proposed unit and boundaries of tracts within the unit, shown in accordance with the Virginia Coordinate System of 1927, as defined in Chapter 17 (§ 55-287 et seq.) of Title 55 of the Code of Virginia, also known as the State Plane Coordinate System. The proposed unit shall also be located by taking the measured distance in feet from the unit to the nearest 2.5 minute longitude line to the east and the nearest 2.5 minute latitude line to the north on the 7.5 minute (1:24,000) topographic map, with a notation of the 7.5 minute topographic map name and series. Also included shall be the names of owners of record of the tracts, and the percentage of acreage in each tract, certified by a licensed land surveyor or a licensed professional engineer and attested by the applicant as to its conformity to existing orders issued by the Board; (8) A description of the status of interests to be pooled in the unit at the time the application is filed; (9) For an application to pool a coalbed methane gas unit, a statement of the percentage of the total interest held by the applicant in the proposed unit at the time the application for the hearing is filed; (10) A statement of the names of owners and the percentage of interests to be escrowed under § 45.1-361.21(D) of the Code of Virginia for each owner whose location is unknown at the time the application for the hearing is filed; (11) A description of the formation or formations to be produced; (12) An estimate of production over the life of the well or wells, and, if different, an estimate of the recoverable reserves of the unit; (13) An estimate of the allowable costs in accordance with § 25-160-100 of the Virginia Administrative Code. (14) An affidavit demonstrating that due diligence was used to locate and serve persons in accordance with § 45.1-361.19 of the Code of Virginia and § 25-160-40 of the Virginia Administrative Code; and (15) When required, proof of notice by publication in accordance with § 25-160-40(D) of the Virginia Administrative Code.3514
3514 Id. § 25-160-70(A).
685
Amendments may be filed after the order pooling interests in a drilling unit by written
stipulation of the affected persons. In such case, the application is not required to contain the
above specified information, but must contain the proposed amendment.3515 The unit operator is
required to file an affidavit with the Board after the time for election provided in any pooling
order has expired stating whether any elections were made. If any elections were made, the
affidavit must name each respondent making an election and describe such election. If no
election was made or if any response was untimely, the affidavit shall state this information.3516
[8] – Applications to Pool Interests in a Drilling Unit: Conflicting Claims to
Coalbed Methane Gas Ownership.
In addition to the information required for applications for pooling interests when there
are no conflicting claims of ownership to the coalbed methane gas, applications filed pursuant to
section 45.1-361.22 of the Virginia Code Ann. to pool interests in a drilling unit for coalbed
methane gas where there are conflicting claims to ownership require a description of the
conflicting ownership claims and the percentage of interests to be escrowed for the conflicting
claims of ownership.3517 Also, a plan for escrowing the costs of drilling and operating the well
or wells and the proceeds from the well or wells attributable to the conflicting interests must be
contained within the application.3518
§ 47.02 Types of Virginia Pooling Statutes.
[1] – Mineral Distinctions.
The Va. Code Ann. defines “oil” as natural crude oil or petroleum and other
hydrocarbons, regardless of gravity which are produced at the well in liquid form by ordinary
accordance with the provisions of section 45.-361.11 and 45.-361.12 of the Virginia Code
Ann.3530
Temporary orders establishing provisional drilling units and field boundaries may be
entered by the Board subject to further investigation and the gathering and taking of additional
data and evidence.
3531 Once the application for a hearing to establish or modify drilling units or
pool boundaries has been filed, no additional wells are permitted in the pool until the Board’s
order establishing or modifying the pool or units has been entered.3532 After the field or pool
spacing order has been entered by the Board, should a gas or oil owner apply for a permit or
indicate his/her desire to drill a well outside of such drilling units or pattern of drilling units, the
Board may, on its own motion or the motion of any interested person, require that the well be
located and drilled pursuant to the provisions of the order affecting the pool.3533
[4] – Pooling of Interests in Drilling Units.
Prior to 1990, the Oil and Gas Act did not define coalbed methane or include provisions
regarding coalbed methane in the drilling unit or compulsory pooling statutes. The current Act
significantly revised the 1982 Oil and Gas Act to encourage the production of coalbed methane
gas.
Upon application from any gas or oil owner, the Board shall enter an order pooling all
interests in the drilling unit for the development and operation thereof when (1) two or more
separately owned tracts are embraced in a drilling unit; (2) there are separately owned interests in
all or part of such drilling unit and those having interests have not agreed to pool their interests;
3530 See generally id. § 45.1-361.11 (“Objections by Coal Owner’). 3531 Id. § 45.1-361.20(E). 3532 Id. § 45.1-361.20(F). 3533 Id. § 45.1-361.20(G).
689
or (3) there are separately owned tracts embraced within the minimum statewide spacing
requirements.
All pooling orders entered by the Board pursuant to section 45.-361.21 shall do the
following:
(1) Authorize the drilling and operation of a well, including the stimulation of all coal seams in the case of a coalbed methane well when authorized; (2) Include the time and date when such order expires; (3) Designate the gas or oil owner who is authorized to drill and operate the well; provided, however, that except in the case of coalbed methane gas wells, the designated operator must have the right to conduct operations or have the written consent of owners with the right to conduct operations on at least 25% of the acreage included in the unit; (4) Prescribe the conditions under which gas or oil owners may become participating operators or exercise their rights of election under subdivision 7 hereinbelow; (5) Establish the sharing of all reasonable costs, including a reasonable supervision fee, between participating operators so that each participating operator pays the same percentage of such costs as his acreage bears to the total unit acreage; (6) Require that nonleasing gas or oil owners be provided with reasonable access to unit records submitted to the Director or Inspector; (7) Establish a procedure for a gas or oil owner who received notice of the hearing and who does not decide to become a participating operator may elect either to (i) sell or lease his gas or oil ownership to a participating operator, (ii) enter into a voluntary agreement to share in the operation of the well at a rate of payment mutually agreed to by the gas or oil owner and the gas or oil operator authorized to drill the well, or (iii) share in the operation of the well as a nonparticipating operator on a carried basis after the proceeds allocable to his share equal the following:
(a) in the case of a leased tract, 300% of the share of such costs allocable to his interest; or (b) in the case of an unleased tract, 200% of the share of such costs allocable to his interest.3534
A gas and oil owner is deemed to have elected to lease his/her interest to the gas or oil
operator at a rate to be established by the Board if he/she remains unknown or unidentified after
3534 Id. § 45.1-361.21(C).
690
the establishment of the pooling order.3535 An escrow account will be established by the Board
and the unknown lessor’s share of the proceeds shall be paid to the account and held for his/her
benefit. If the identity and location of any unknown owner subject to escrow is determined, the
designated operator shall, within 30 days, file with the Board a petition for disbursement of funds
to be considered at the next available hearing.3536 Otherwise, the unclaimed escrow proceeds
shall be disposed of under the Uniform Disposition of Unclaimed Property Act.3537
Any person who does not make an election under the pooling order shall be deemed to
have leased his gas or oil interest to the gas or oil well operator as the pooling order may
provide.
3538
Any royalty or overriding royalty reserved in any lease which is deducted from a
nonparticipating operator’s share of production shall not be subject to charges for operating costs
but shall be separately calculated and paid to the royalty owner.
3539
[5] – Pooling of Interests for Coalbed Methane Gas Wells: Conflicting Claims to
Ownership.
The 1990 revisions added specific provisions to the compulsory pooling statute dealing
with problems concerning coalbed methane gas wells.3540
3535 Id. § 45.1-361.21(D).
When there are conflicting claims to
the coalbed methane gas ownership, the Board, upon application from any claimant, must enter
an order pooling all interests or estates in the unit for the development and operation thereof. In
addition to the provisions of section 45.1 – 361.21, hereinabove, the following provisions are
required:
3536 Id. 3537 Id. 3538 Id. § 45.1-361.21(E). 3539 Id. § 45.1-361.21(G). 3540 27 Energy & Min. L. Inst. ch. 7 (2007).
691
(1) Simultaneously with the filing of such application, the gas or oil owner applying for the order shall provide notice pursuant to the provisions of § 45.1 – 361.19 to each person identified by the applicant as a potential owner of an interest in the coalbed methane gas underlying the tract which is subject of the hearing. (2) The Board shall cause to be established an escrow account into which the payment for costs or proceeds attributable to the conflicting interests shall be deposited and held for the interest of the claimants. (3) The coalbed methane gas well operator shall deposit into the escrow account any money paid by a person claiming a contested ownership interest as a participating operator’s share of costs pursuant to the provisions of § 45.1-361.21 and the order of the Board. (4) The coalbed methane gas well operator shall deposit into the escrow account one-eighth of all proceeds attributable to the conflicting interests plus all proceeds in excess of ongoing operational expenses as provided for under § 45.1-361.21 and the order of the Board. (5) The Board shall order payment of principal and accrued interest, less escrow account fees, from the escrow account to conflicting claimants only after (i) a final decision of a court of competent jurisdiction adjudicating the ownership of coalbed methane gas as between them; (ii) a determination reached by an arbitrator pursuant to § 45.1-361.22:1; or (iii) an agreement among all claimants owning conflicting estates in the tract in question or any undivided interest therein. Upon receipt of an affidavit from conflicting claimants affirming such decision, determination, or agreement, the designated operator shall, within 30 days, file with the Board a petition for disbursement of funds on behalf of the conflicting claimants. The petition shall include a detailed accounting of all funds deposited in escrow that are subject to the proposed disbursement. The amount to be paid to the conflicting claimants shall be determined based on the percentage of ownership interest of the conflicting claimants as shown in the operator’s supplemental filing made part of the pooling order that established the escrow account, the operator’s records of deposits attributable to those tracts for which funds are being requested, and the records of the escrow account for the coalbed methane gas drilling unit. The petition for disbursement shall be placed on the first available Board docket. Funds shall be disbursed within 30 days after the Board decision and receipt by the Department of all documentation required by the Board. The interests of any cotenants that have not been resolved by the agreement or by judicial decision shall remain in the escrow account.
692
(6) Any person who does not make an election under the pooling order shall be deemed, subject to a final legal determination of ownership, to have leased his gas or oil interest to the coalbed methane gas well operator as the pooling order may provide.3541
An additional provision added to the 1990 Act allows claimants to arbitrate conflicting
claims of ownership if certain statutory requirements are met.
3542
[6] – Statewide Spacing of Wells.
With respect to well spacing, the Act differentiates between the type of well being drilled
(i.e., gas, oil, or coalbed methane gas). Unless prior approval has been received from the Board
or a provision of the field or pool rules so allows, the oil and gas well spacing requirements are
as follows: (1) wells drilled in search of oil shall not be located closer than 1,250 feet to any well
completed in the same pool; (2) wells drilled in search of gas shall not be located closer than
2,500 feet to any other well completed in the same pool, or closer than 2,500 feet to any storage
well within the boundary of a gas storage field certificated by the State Corporation Commission
prior to January 1, 1997, if the well to be drilled is to be completed within the same horizon as
the certificated gas storage field; (3) a well shall not be drilled closer to the boundary of the
acreage supporting the well, whether such acreage is a single leasehold or other tract or a
contractual or statutory drilling unit, than one-half of the minimum well spacing distances.3543
Coalbed methane gas wells shall not be located closer than 1,000 feet to any other
coalbed methane gas well, or in the case of coalbed methane gas wells located in the gob, such
wells shall not be located closer than 500 feet to any other coalbed methane gas wells located in
the gob.
3544
3541 Va. Code Ann. § 45.1-361.22 (2010).
A well shall not be drilled closer than 500 feet, or in the case of such well located in
3542 See generally id. § 45.1-361.22:1. 3543 Id. § 45.1-361.17(A). 3544 Id. § 45.1-361.17(B)(1).
693
the gob, not closer than 250 feet, from the boundary of the acreage supporting the well, whether
such acreage is a single leasehold or other tract or a contractual or statutory drilling unit.3545
Wells drilled in search of oil and coalbed methane gas are subject to the provisions of
section 45.1-361.12 of the Virginia Code Ann., which provides as follows:
A. If the well operator and the objecting coal owners present or represented at the hearing to consider objections to the proposed drilling unit or location are unable to agree upon a drilling unit or location for a new well within 2,500 linear feet of the location of an existing well or a well for which a permit application is on file, then the permit or drilling unit shall be refused. B. The minimum distance limitations established by this section shall not apply if the proposed well will be drilled through an existing or planned pillar of coal required for protection of a preexisting well drilled to any depth, and the proposed well will neither require enlargement of the pillar nor otherwise have an adverse effect on existing or planned coal mining operations.
3545 Id. § 45.1-361.17(B)(2).
694
§ 48.01 Analysis of Washington Regulatory Framework.
[1] – Name of Governing Body.
The Department of Natural Resources (“Department”), through the Division of Geology
and Earth Resources (“Division”), regulates drilling and related activities under the Oil and Gas
Conservation Act (“the Act”) and the rules of the Department of Natural Resources. The
Department designates a State Oil and Gas Supervisor (“Supervisor”). Previously, there had
been an Oil and Gas Conservation Committee (which is still referenced in the statutes); however,
it was dissolved by the legislature in 1994, and its regulatory responsibilities were assigned to the
Department.3546
[2] – Membership of the Governing Body.
The head of the Department is an elected official, referred to as the Commissioner of
Public Lands. Under the Act, the Department is given the authority to employ all personnel
necessary to carry out its provisions.3547
[3] – Scope of Authority.
However, further information on how the Department is
structured and the membership is not available.
The Department has authority to adopt rules and regulations and to issue orders, and has
jurisdiction, power, and authority over all persons and property, public and private, necessary to
enforce its duties under the Act.3548 The Department also issues drilling permits.3549
3546 Wash. Rev. Code Ann. § 78.52.030 (Lexis 2011); Wash. Admin. Code § 3440-12-035 (2011); see also Wash. State Dep’t of Natural Res., Oil & Gas Geothermal Regulation, http://www.dnr.wa.gov/BusinessPermits/Topics/MiningEnergyResourceRegulation/Pages/energy_regulation.aspx (last visited Jun. 22, 2011).
Any person
desiring or proposing to drill any well in search of oil or gas must first apply to the Department
upon such form as the Department may prescribe. The Department shall require sufficient
3547 Wash. State Dep’t of Natural Res., Peter Goldmark: Washington State Commissioner of Public Lands, http://www.dnr.wa.gov/AboutDNR/Pages/commissioner.aspx (last visited Jun. 3, 2011). 3548 Wash. Rev. Code Ann. § 78.52.040 (Lexis 2011). 3549 Id. § 78.52.120.
695
safeguards to minimize the hazards of pollution of all surface and ground waters of the state. If
safeguards acceptable to the Department cannot be provided, the drilling permit shall be
denied. 3550 The Department is also authorized to make such investigations as it may deem
proper to determine whether waste exists or is imminent or whether other facts exist which
justify action by the Department.3551
[4] – Process.
[a] Drilling Permit Applications.
A permit applicant must notify the surface landowner, the landowner's tenant, and other
surface users in the manner provided by regulations of the Department that a drilling permit has
been applied for by furnishing each such surface landowner, tenant, and other users with a copy
of the application concurrent with the filing of the application. Within 15 days of receipt of the
application, each surface landowner, the landowner's tenant, and other surface users have the
right to inform the Department of objections or comments as to the proposed use of the surface
by the applicant, and the Department shall consider the objections or comments.3552
The Department shall issue a permit if it finds that the proposed drilling will be consistent
with Washington’s oil and gas laws and is not detrimental to the public interest. The Department
shall impose conditions and restrictions as necessary to protect the public interest and to ensure
compliance with the law. A person shall not apply to drill a well in search of oil or gas unless
that person holds an ownership or contractual right to locate and operate the drilling operations
upon the proposed drilling site. A person shall not be issued a permit unless that person prima
3550 Id. 3551 Id. § 78.52.150. 3552 Id.
696
facie holds an ownership or contractual right to drill to the proposed depth, or proposed horizon.
Proof of prima facie ownership shall be presented to the Department.3553
If drilling will be conducted through or under any surface waters of the state, the
applicant shall prepare and submit an environmental impact statement upon such form as the
Department of Ecology (which oversees environmental matters) shall prescribe at least 120 days
prior to commencing drilling. Within 90 days after receipt of an environmental statement the
Department of Ecology shall prepare and submit to the Department of Natural Resources a report
examining the potential environmental impact of the proposed well and recommendations for
Department action thereon. If after consideration of the report the Department determines that
the proposed well is likely to have a substantial environmental impact the drilling permit for such
well may be denied.
3554
[b] Pooling of Interests.
When two or more separately owned tracts are embraced within a development unit, or
when there are separately owned interests in all or a part of the development unit, then the
owners and lessees thereof may pool their interests for the development and operation of the
development unit. In the absence of this voluntary pooling, the Department, upon the application
of any interested person, may enter an order pooling all interests, including royalty interests, in
the development unit for the development and operation thereof. Each such pooling order shall
be made after notice and hearing. The applicant or applicants shall have the burden of proving
that all reasonable efforts have been made to obtain the consent of, or to reach agreement with,
A pooling order shall be upon terms and conditions that are fair and reasonable and that
afford to each owner and royalty owner his or her fair and reasonable share of production.
Production shall be allocated as follows:
(1) For the purpose of determining the portions of production owned by the persons owning interests in the pooled unit, the production shall be allocated to the respective tracts within the unit in the proportion that the surface acres in each tract bear to the number of surface acres included in the entire unit. (2) Notwithstanding the above, if the Department finds that allocation on a surface acreage basis does not allocate to each tract its fair share, the Department shall allocate the production so that each tract will receive its fair share.
[d] Development Units Authorized for Known Pools.
When necessary to prevent waste, to avoid the drilling of unnecessary wells, or to protect
correlative rights including those of royalty owners, the Department, upon its own motion or
upon application of interested persons, shall establish development units covering any known
pool. Development units shall be of uniform size and shape for the entire pool unless the
Department finds that it must make an exception due to geologic, geographic, or other factors.
When necessary, the Department may divide any pool into zones and establish development
units for each zone, which units may differ in size and shape from those established in any other
zone.3556
[e] Development Units to be Prescribed for Pooling after Discovery—Temporary
Development Units.
A hearing shall be held within 60 days after the discovery of oil or gas in a pool not then
covered by an order of the Department, and the Department shall issue an order prescribing
development units for the pool. If sufficient geological or other scientific data from drilling
operations or other evidence is not available to determine the maximum area that can be 3556 Id. § 78.52.200.
698
efficiently and economically drained by one well, the Department may establish temporary
development units to ensure the orderly development of the pool pending availability of the
necessary data. A temporary order shall continue in force for a period of not more than 24
months at the expiration of which time, or upon the petition of an affected person, the
Department shall require the presentation of such geological, scientific, drilling, or other
evidence as will enable it to determine the proper development units in the pool. During the
interim period between the discovery and the issuance of the temporary order, permits shall not
be issued for the drilling of direct offsets to a discovery well.3557
[5] – Matters Covered.
[a] Limitation of Production to “Gas Allowable”—Proration.
Whenever the total amount of gas that all of the pools in the state can currently produce
in accordance with good operating practice exceeds the amount reasonably required to meet the
market demand, the Department shall limit the gas that may be produced to an amount,
designated as the “gas allowable,” which will not exceed the reasonable market demand for gas.
The Department shall then prorate the “gas allowable” among the pools on a reasonable basis,
avoiding undue discrimination among the pools, and so that waste will be prevented, giving due
consideration to location of pipe lines, cost of interconnecting such pipe lines, and other pertinent
factors. In determining the reasonable market demand for gas as between pools, the Department
must give due regard to the fact that gas produced from oil pools is to be regulated in a manner
that will protect the reasonable use of gas energy for oil production and promote the most or
maximum efficient recovery of oil from such pools.3558
[b] Limitation of Gas Production from One Pool.
3557 Id. § 78.52.205. 3558 Id. § 78.52.290.
699
Whenever the total amount of gas that may be produced from all of the pools in the state
has not been limited to “gas allowable,” and the available production from any one pool
containing gas only is in excess of the reasonable market demand or available transportation
facilities for gas from such pool, the Department shall limit the production of gas from that pool
to an amount that does not exceed the reasonable market demand or transportation facilities for
gas from that pool.3559 Whenever the Department limits the total amount of oil or gas that may
be produced from any pool to an amount less than that which the pool could produce if no
restrictions were imposed (whether incidental to, or without, a limitation of the total amount of
oil which may be produced in the state) the Department shall prorate the allowable production
for the pool among the producers in the pool on a reasonable basis, so that each producer will
have opportunity to produce or receive his or her just and equitable share, subject to the
reasonable necessities for the prevention of waste, giving, where reasonable under the
circumstances, to each pool with small wells of settled production allowable production which
prevents the premature abandonment of wells in the pool.3560
All orders establishing the “oil allowable” and “gas allowable” for the state, and all
orders prorating such allowables, and any changes thereof, for any month or period shall be
issued by the Department on or before the 15th day of the month preceding the month for which
such orders are to be effective, and such orders shall be immediately published in some
newspaper of general circulation printed in Olympia, Washington. No orders establishing such
allowables, or prorating such allowables, or any changes thereof, shall be issued without first
having a hearing, after notice. However, when in the judgment of the Department, an emergency
requiring immediate action is found to exist, the Department may issue an emergency order that
3559 Id. § 78.52.300. 3560 Id. § 78.52.310.
700
has the same effect and validity as if a hearing had been held after due notice. The emergency
order permitted by this section shall remain in force no longer than 30 days, and in any event it
shall expire when the order made after due notice and hearing with respect to the subject matter
of the emergency order becomes effective.3561
[c] Unit Operations of Separately Owned Tracts.
To assist in the development of oil and gas in Washington, persons owning interests in
separate tracts of land may validly agree to integrate their interests and manage, operate, and
develop their land as a unit, subject to the approval of the Department.3562
[d] Unit Operation of Pools.
The Department shall, upon the application of any interested person or upon its own
motion, hold a hearing to consider the need for the operation as a unit of one or more pools or
parts of them in a field. The Department may enter an order providing for the unit operations if
it makes the following findings:
(1) the unit operations are necessary for secondary recovery or enhanced recovery purposes, where enhanced recovery means that oil or gas or both are recovered by any method, artificial flowing or pumping, that may be employed to produce oil or gas, or both, through the joint use of two or more wells with an application of energy extrinsic to the pool or pools. This includes pressuring, cycling, pressure maintenance, or injections into the pool or pools of a substance or form of energy. This does not include the injection in a well of a substance or form of energy for the sole purpose of (i) aiding in the lifting of fluids in the well, or (ii) stimulation of the reservoir at or near the well by mechanical, chemical, thermal, or explosive means; (2) the unit operations will protect correlative rights; (3) the operations will increase the ultimate recovery of oil or gas, or will prevent waste, or will prevent the drilling of unnecessary wells; and (4) the value of the estimated additional recovery of oil and/or gas exceeds the estimated additional cost incident to conducting these operations.
3561 Id. 3562 Id. § 78.52.330.
701
The Department may also enter an order providing for unit operations, after notice and
hearing, only if the Department finds that there is clear and convincing evidence that all of the
following conditions are met:
(1) in the absence of unitization, the ultimate recovery of oil or gas, or both, will be substantially decreased because normal production techniques and methods are not feasible and will not result in the maximum efficient and economic recovery of oil or gas, or both; (2) the unit operations will protect correlative rights; (3) the unit operations will prevent waste, or will prevent the drilling of unnecessary wells; (4) there has been a discovery of a commercial oil or gas field; and (5) there has been sufficient exploration, drilling activity, and development to properly define the one or more pools or parts of them in a field proposed to be unitized.
Notwithstanding any of the above, nothing shall be construed to prevent the voluntary
agreement of all interested persons to any plan of unit operations. The Department shall approve
operations upon making a finding consistent with the statute. The order shall be upon terms and
conditions that are fair and reasonable and shall prescribe a plan for unit operations that includes
the following information:
(1) a description of the pool or pools or parts thereof to be so operated, termed the unitized area; (2) a statement of the nature of the operations contemplated; (3) an allocation of production and costs to the separately-owned tracts in the unitized area. The allocation shall be in accord with the agreement, if any, of the interested parties. If there is no agreement, production shall be allocated in a manner calculated to ensure that each owner's correlative rights are protected, and each separately-owned tract or combination of tracts receives its fair and reasonable share of production. Costs shall be allocated on a fair and reasonable basis; (4) a provision, if necessary, prescribing fair, reasonable, and equitable terms and conditions as to time and rate of interest for carrying or otherwise financing any person who is unable to promptly meet his or her financial obligations in connection with the unit, such carrying and interest charges to be paid as provided by the Department from the person's prorated share of production; (5) a provision for the supervision and conduct of the unit operations, in respect to which each owner shall have a vote with a value corresponding to the percentage of the costs of unit operations chargeable
702
against the owner's interest; (6) the time when the unit operations shall commence, the timetable for development, and the manner and circumstances under which the unit operations shall terminate; and (7) additional provisions which are found to be appropriate for carrying out the unit operations and for the protection of correlative rights.
No order of the Department providing for unit operations may become effective until the
plan for unit operations approved by the Department has been approved in writing by the
appropriate persons.
Finally, the Department must find either in the order providing for unit operations or in a
supplemental order that the plan for unit operations has been approved. If the plan for unit
operations has not been approved at the time the order providing for unit operations is made, the
Department shall, upon application and notice, hold supplemental hearings as may be required to
determine if and when the plan for unit operations has been so approved. If the persons owning
required percentages of interest in the unitized area do not approve the plan for unit operations
within a period of six months from the date on which the order providing for unit operations is
made, or within such additional period or periods of time as the Department prescribes, the order
will become unenforceable and shall be vacated by the Department.
An order providing for unit operations may be amended by an order made by the
Department in the same manner and subject to the same conditions as an original order.
However, if such an amendment affects only the rights and interests of the owners, the approval
of the amendment by those persons who own interests that are free of costs is not required. Also,
no such amending order may change the percentage for the allocation of oil and gas as
established for any separately-owned tract or combination of tracts by the original order, except
with the consent of all persons owning oil and gas rights in the tract, and no such order may
change the percentage for the allocation of cost as established for any separately-owned tract or
703
combination of tracts by the original order, except with the consent of all persons owning an
interest in the tract or combination of tracts. An amendment that provides for the expansion of
the unit area shall comply with the statute described below.
The Department, by order, may provide for the unit operation of a reservoir or reservoirs
or parts thereof that include a unitized area established by a previous order of the Department.
The order, in providing for the allocation of unit production, shall first treat the unitized area
previously established as a single tract and the portion of the new unit production allocated
thereto shall then be allocated among the separately owned tracts included in the previously-
established unit area in the same proportions as those specified in the previous order.3563
§ 48.02 Types of Washington Pooling Statutes.
[1] – Mineral Distinctions.
"Gas" means “all natural gas, all gaseous substances, and all other fluid or gaseous
hydrocarbons not defined as oil [by the Washington Revised Code], including but not limited to
wet gas, dry gas, residue gas, condensate, and distillate, as those terms are generally understood
in the petroleum industry.” 3564 "Oil" means “crude petroleum, oil, and all hydrocarbons,
regardless of gravity, that are in the liquid phase in the original reservoir conditions and are
produced and recovered at the wellhead in liquid form.”3565
[2] – Split by Depth.
The statutes do not provide any depth requirements.
No exploratory well, or any part of the bore, casing, or drill site, shall be located closer
than 500 feet (152 meters) to the external boundary of those lands on which the operator and/or
their partners hold a contiguous mineral interest. Upon written request to the Supervisor, the
Department may grant exceptions to the exploratory well setback requirements for good cause
shown, provided that all owners of oil and gas and surface rights within a 500-foot radius of the
well consent in writing to the proposed location.3566
[b] Development Units.
As determined by competent geological, geophysical, engineering, or other scientific
testimony, data, and evidence, the Department shall fix development units for a pool. No
development unit in a pool deemed by the Department to be an oil reservoir shall be larger than
160 acres (65 hectares) nor shall the well be located closer than 500 feet (152 meters) to the lease
line, nor closer than 1,000 feet (305 meters) to the nearest well drilling to or capable of
producing from the same pool. The Department shall have the right to waive these limits.
No development unit in a pool deemed by the Department to be a gas reservoir shall be
larger than 640 acres (261 hectares) nor shall the well be located closer than 1,000 feet (305
meters) to the lease line nor closer than 2,000 feet (610 meters) to the nearest well drilling to or
capable of producing from the same pool. The Department shall have the right to waive these
limits.
If upon application, and after notice and hearing, the Department finds that a well drilled
at the location prescribed by any applicable rule of the Department would not produce in paying
quantities or that surface conditions would substantially add to the burden or hazard of the well,
3566 Wash. Admin. Code § 344-12-043(2011). The regulation says “Committee,” yet, the Oil and Gas Conservation Committee was abolished in 1994. The statutes and regulations have not been thoroughly cleaned up. A telephone conversation with staff in the Department of Natural Resources confirms to substitute the words “Supervisor” and/or “Department of Natural Resources” for “Committee” anywhere it still appears.
705
the Department may enter an order permitting the well to be drilled at a location on which the
applicant prima facie owns an ownership or contractual right to drill other than that prescribed
and shall include in the order suitable provisions to prevent the production from that well of
more than its just and equitable share of the oil and gas in the pool.
Applications for exceptions shall set forth the names of the lessees or owners of
contiguous or cornering properties and shall be accompanied by a plat or sketch map drawn to
the scale of not smaller than one inch equaling 2,000 feet (610 meters) or as otherwise required,
accurately showing to scale the property for which the exception is sought and accurately
showing to scale all other completed and drilling wells on this property and accurately showing
to scale all contiguous or cornering surrounding properties and wells. The application shall be
verified by some person acquainted with the facts, stating that all facts are within the knowledge
of the affiant are true and that the accompanying plat is accurately drawn to scale and correctly
reflects pertinent and required data. Upon the filing of an application, the Department shall give
notice by certified mail to all lessees and owners of lands towards whom the well is being
moved, if closer to the proposed well than offset distances set forth above.
In filing an application to drill, redrill, or deepen, the surface distance must be shown
between the proposed location and other wells within a radius of 1,000 feet (305 meters) for oil
tests and 3,000 feet (914 meters) for gas tests.
An order establishing development units for a pool shall specify the size and shape of
each area and the location of the permitted well thereon in accordance with a reasonable uniform
spacing plan. Upon application and after notice and a hearing, if the Department finds that a well
drilled at the prescribed location would not produce in paying quantities, or that surface
conditions would substantially add to the burden or hazard of drilling the well, the Department
706
may enter an order permitting the well to be drilled pursuant to a permit at a location other than
that prescribed by such development order; however, the Department shall include in the order
suitable provisions to prevent the production from the development unit of more than its just and
equitable share of the oil and gas in the pool.3567
[4] – Size.
The size and the shape of any development units shall be such as will result in the
efficient and economical development of the pool as a whole, and the size shall not be smaller
than the maximum area that can be efficiently and economically drained by one well as
determined by competent geological, geophysical, engineering, drilling, or other scientific
testimony, data, and evidence. The Department shall fix a development unit of not more than 160
acres for any pool deemed by the Department to be an oil reservoir or of 640 acres for any pool
deemed by the Department to be a gas reservoir, plus a ten percent tolerance in either case to
allow for irregular sections. The Department may, at its discretion, after notice and hearing,
establish development units for oil and gas in variance of these limitations when competent
geological, geophysical, engineering, drilling, or other scientific testimony, data, and evidence is
presented and upon a finding that one well can efficiently and economically drain a larger or
smaller area and is justified because of technical, economic, environmental, or safety
considerations.3568
The Department may establish development units of different sizes or shapes for different
parts of a pool or may grant exceptions to the size or shapes of any development unit or units.
Where development units of different sizes or shapes exist in a pool, the Department shall, if
necessary, make adjustments to the allowable production from the well or wells drilled thereon
so that each operator in each development unit will have a reasonable opportunity to produce or
receive his or her just and equitable share of the production.3569
[5] – Minimum Operator Control.
No order of the Department providing for unit operations may become effective until the
plan for unit operations approved by the Department has been approved in writing by those
persons who, under the Department's order, will be required to pay at least 75 percent of the
costs of unit operations and the plan has been approved in writing by those persons such as
royalty owners, overriding royalty owners, and production payment owners, who own at least 75
percent of the production or proceeds thereof that will be credited to interests that are free of
costs. 3570
[6] – Vertical vs. Horizontal Drilling.
Before beginning directional drilling, other than sidetracking due to hole conditions, the
operator shall file a request and obtain approval from the Supervisor. Such request shall state the
following information:
(1) name and address of operator, (2) well name and number, (3) drilling permit number, (4) exact surface location of well bore, (5) the proposed direction of deviation, (6) the proposed horizontal distance between bottom of the hole and the surface location, (7) the reason for directional drilling, and (8) a list of direct offset operators towards whom the well is being drilled, if any.
Within sixty days after completion of the work, an accurate and complete copy of the directional
Each pooling order shall make provision for the drilling and operation of a well on the
development unit and for the payment of the reasonable actual cost thereof by the owners of
interests required to pay such costs in the development unit, plus a reasonable charge for
supervision and storage facilities. Costs associated with production from the pooled unit shall be
allocated in the same manner as is production in Washington Revised Code Ann. section
78.52.245. In the event of any dispute as to costs, the Department shall determine costs.
As to each owner who fails or refuses to agree to bear his or her proportionate share of
the costs of the drilling and operation of the well, the order shall provide for reimbursement of
those persons paying for the drilling and operation of the well of the nonconsenting owner's
share of the costs from, and only from, production from the unit representing that person's
interest, excluding royalty or other interests not obligated to pay any part of the cost thereof. The
Department may provide that the consenting owners shall own and be entitled to receive all
production from the well after payment of the royalty as provided in the lease, if any, applicable
to each tract or interest, and obligations payable from production, until the consenting owners
have been paid the amount due under the terms of the pooling order or order settling any dispute.
The order shall determine the interest of each owner in the unit and shall provide that
each consenting owner is entitled to receive, subject to royalty or similar obligations, the share of
the production of the well applicable to the owner's interest in the unit, and, unless the owner has
agreed otherwise, his or her proportionate part of the nonconsenting owner's share of the
production until costs are recovered as provided in this subsection. Each nonconsenting owner is
entitled to receive, subject to royalty or similar obligations, the share of production from the well
applicable to the owner's interest in the unit after the consenting owners have recovered from the
nonconsenting owner's share of production the following:
709
(1) in respect to every such well, one hundred percent of the nonconsenting owner's share of the cost of surface equipment beyond the wellhead connections, including but not limited to, stock tanks, separators, treaters, pumping equipment, and piping, plus one hundred percent of the nonconsenting owner's share of the cost of operation of the well, commencing with first production and continuing until the consenting owners have recovered these costs, with the intent that the nonconsenting owner's share of these costs and equipment will be that interest which would have been chargeable to the nonconsenting owner had he or she initially agreed to pay his or her share of the costs of the well from the beginning of the operation; (2) one hundred and fifty percent of that portion of the costs and expenses of staking the location, well site preparation, rights-of-way, rigging-up, drilling, reworking, deepening or plugging back, testing, and completing, after deducting any cash contributions received by the consenting owners, and also 150 percent of that portion of the cost of equipment in the well, up to and including the wellhead connections; and (3) if there is a dispute regarding the costs, the Department shall determine the proper costs and their allocation among working interest owners after due notice to interested parties and a hearing on the costs.
The operator of a well under a pooling order in which there are nonconsenting owners
shall furnish the nonconsenting owners with monthly statements of all costs incurred, together
with the quantity of oil or gas produced and the amount of proceeds realized from the sale of this
production during the preceding month. If and when the consenting owners recover from a
nonconsenting owner's relinquished interest the amounts provided for in subsection (2) of this
section, the relinquished interest of the nonconsenting owner shall automatically revert to him or
her, and the nonconsenting owner shall own the same interest in the well, the production from it,
and be liable for the further costs of the operation as if he or she had participated in the initial
drilling and operation.
A nonconsenting owner of a tract in a development unit which is not subject to any lease
or other contract for the development thereof for oil and gas shall elect within 15 days of the
issuance of the pooling order or such further time as the Department shall, in the order, allow:
710
(1) to be treated as a nonconsenting owner as provided above and is deemed to have a basic landowners' royalty of one-eighth, or twelve and one-half percent, of the production allocated to the tract, unless a higher basic royalty has been established in the development unit. If a higher royalty has been established, then the nonconsenting owner of a nonleased tract shall receive the higher basic royalty. This presumed royalty shall exist only during the time that costs and expenses are being recovered, and is intended to assure that the owner of a nonleased tract receive a basic royalty free of all costs at all times. Notwithstanding anything herein to the contrary, the owner shall at all times retain his or her entire ownership of the property, including the right to execute an oil and gas lease on any terms negotiated, and be entitled to all production as set forth above; (2) to grant a lease to the operator at the current fair market value for that interest for comparable leases or interests at the time of the commencement of drilling; or (3) to pay his or her pro rata share of the costs of the well or wells in the development unit and receive his or her pro rata share of production, if any.
A nonconsenting owner who does not make an election as provided in this subsection is
deemed to have elected to be treated under (a) of this subsection.3572
3572 Wash. Rev. Code Ann. § 78.52.250 (Lexis 2011).
711
§ 49.01 Analysis of West Virginia Regulatory Framework. In West Virginia, multiple statutes govern the oil and gas industry. The Office of Oil and
Gas is established in West Virginia Code sections 22-6-1 to 22-6-41, which provides that the
Secretary of the Department of Environmental Protection (“Secretary”) has the powers and
duties to permit well work, drilling, and fracturing, among other things.3573 The Shallow Gas
Well Review Board (“Review Board”) was formed by statute to hear objections by coal owners
regarding placement of shallow well location. 3574 Shallow gas wells are those drilled and
completed above the uppermost member of the Onondaga Group, with an allowance of 20 feet
into the Onondaga for logging and completion operations, but in no event may they produce
therefrom.3575 Deep wells are those drilled and completed in a formation at or below the top of
the uppermost member of the Onondaga Group.3576 The Review Board may also create drilling
units and pool the interests within those drilling units in limited circumstances,3577
The West Virginia Oil and Gas Conservation Commission (“Commission”) is a body
created by statute with the authority to regulate deep well spacing to make and enforce
reasonable rules and orders that are necessary to prevent waste and to protect correlative
rights.
although the
Board has yet to use this authority.
3578 The Commission holds the authority to approve or deny applications for new well
permits, to establish drilling units or special field rules, and to approve or deny applications for
West Virginia Code section 22C-8-1 provides that it is the public policy of West Virginia and in
the best interest to “[s]afeguard, protect and enforce the correlative rights of gas operators and
royalty owners in a pool of gas to the end that each such gas operator and royalty owner may
obtain a just and equitable share of production from such pool of gas.”3588
The Legislature declared further in section 1 that,
it is in the public interest to enact new statutory provisions establishing a shallow gas well review board which shall have the authority to regulate and determine the appropriate placing of shallow wells when gas well operators and owners of coal seams fail to agree on the placing of such wells, and establishing specific considerations, including minimum distances to be allowed between certain shallow gas wells, to be utilized by the shallow gas well review board in regulating the placing of shallow wells; that in order to encourage and ensure the fullest practical recovery of coal and gas in this state and to protect and enforce the correlative rights of gas operators and royalty owners of gas resources, it is in the public interest to enact new statutory provisions establishing a shallow gas well review board which shall also have authority to establish drilling units and order the pooling of interests therein to provide all gas operators and royalty owners with an opportunity to recover their just and equitable share of production.3589
[b] Membership of Governing Body.
The Secretary is the chief executive officer of the Department and may appoint a deputy
secretary, assistants, and employees, among other persons, who are necessary for the
Department’s operation.3590 The WVDEP is broken into a number of offices, one of which is the
Office of Oil and Gas.3591
The Review Board is composed of three members: (1) the Commissioner of the West
Virginia Department of Environmental Protection (WVDEP) Office of Oil and Gas; (2) the Chief
of the WVDEP Office of Oil and Gas and; (3) a “registered professional who has been
successfully tested in mining engineering, with at least ten years practical experience in the coal
mining industry and shall be appointed by the governor, by and with the advice and consent of
the Senate.”3592 If there is a vacancy in the appointed seat on the Board, the West Virginia
Governor must select a new appointee within 60 days after the seat becomes vacant.3593
[c] Scope of Authority.
The Secretary has the duty of supervision the execution and enforcement of all matters
related to oil and gas set out in the Environmental Resources statute.3594 Among a host of duties
that deal with the organization of the WVDEP, the Secretary is charged with performing “all
duties as the permit issuing authority for the state in all matters pertaining to the exploration,
development, production, storage and recovery of the state’s oil and gas.”3595
As for the Shallow Gas statute, the provisions of that law apply to “all lands located in
this state under which a coal seam . . . is located.”
3596 The Shallow Gas Well Review Board has
no authority or jurisdiction over (1) deep wells; (2) oil wells and enhanced oil recovery wells
associated with oil wells; (3) any shallow well as to which no objection is made under section
22-6-17;3597 (4) wells defined in section 22-9-1(4)3598; or (5) free gas rights.3599
3592 Id. § 22C-8-4(a).
The Review
Board is predominately an appellate body that decides whether to issue drilling or fracturing
permits when the locations or conditions of such permits have been challenged by the coal seam
owner.
3593 Id. § 22C-8-4(b). 3594 Id. § 22-6-2(a). 3595 Id. § 22-6-2(c)(12). 3596 Id. § 22C-8-3(a). 3597 West Virginia Code section 22-6-17 is titled, “Objections to proposed drilling of shallow gas wells; notice to chair of review Board; indication of changes on plats; issuance of permits.” 3598 The term “well” means a borehole drilled or proposed to be drilled within the storage reservoir boundary or reservoir protective area for the purpose of or to be used for producing, extracting or injecting any gas, petroleum, or other liquid but excluding boreholes drilled to produce potable water to be used as such. 3599 W. Va. Code § 22C-8-3 (2011).
715
The Board does not have the authority or power to limit production or output from any
well, prorate production from any gas well, or to fix prices of gas.3600
(1) take evidence and issue orders concerning applications for drilling permits and drilling units; (2) promulgate reasonable rules of practice and procedure before the Board;
The Board’s authority, in
furtherance of its review of an objection filed by the coal owner or the Director is limited to the
following actions:
3601 (3) make investigations of records and facilities; and (4) issue subpoenas for the attendance of and sworn testimony by witnesses and subpoenas duces tecum for the production of any books, records, maps, charts, diagrams and other pertinent documents, and administer oaths and affirmations to such witnesses.3602
[d] Pooling Process and Matters Covered.
All persons who wish to commence well work3603 must obtain a well work permit from
the Secretary.3604 Every well work application must contain, among other things, the names and
addresses of the well operator, all persons that the applicant must notify by statute, and every
coal operator operating coal seams under the tract of land on which the well is or may be located,
and the coal seam owner and lessee entitled to notice, if any, if the owner or lessee is not yet
operating the coal seam.3605
3600 Id. § 22C-8-5(d).
No later than the date the application was filed, the applicant must
deliver copies of the application, a well plat, and an erosion and sediment control plan by
personal service or certified mail, return receipt requested, to the record owners both of the
surface tracts where the well is to be located and of the surface tracts overlying the oil and gas
3601 The rules of procedure before the Board must be implemented in accordance with and pursuant to the West Virginia Administrative Procedures Act. See id. § 29A-1-1. 3602 Id. § 22C-8-5(e). 3603 “Well work” is defined as the “drilling, redrilling, deepening, stimulating, pressuring by injection of any fluid, converting from one type of well to another, combining or physically changing to allow the migration of fluid from one formation to another or plugging or replugging any well.” Id. § 22-6-1(v). 3604 Id. § 22-6-6(a). 3605 Id. § 22-6-6(c)(1)–(2).
716
leasehold proposed to be used for roads or other disturbances.3606 The plat accompanying the
application must be sufficient to show all wells within 1,200 feet of the subject well.3607 In the
case of a shallow gas well application with a depth of 3,000 feet or more and that penetrates a
coal seam, the plat must be sufficient to show all wells within 2,400 feet of the subject well.
Each shown well must be distinguished as oil, gas, liquid injection, or underground storage well
and as having an active, abandoned, or drilling status.3608 The plat must also show water wells
within 200 feet of the well being sought, except for liquid or waste disposal wells, in which case
the plat must show water wells within 1,000 feet of the well.3609 Finally, the plat must also show
dwellings within 200 feet of the well, in addition to streams, roads, and railroads.3610
The applicant must certify to the Secretary that the required notice has been given prior to
issuance of the well work permit.
3611 Those persons may file comments as to the location or
construction of the proposed well work within 15 days of the filing of the application with the
Secretary, 3612 who must review the applications and determine whether or not to grant a
permit.3613 A permit will not be issued less than 15 days after filing unless the applicant both
certifies that all persons entitled to notice have received notice and files written statements of no
objection by all such persons.3614
3606 Id. § 22-6-9(a).
The permit will not be issued if the Secretary determines that
the proposed work will be a human safety hazard, the plan for soil erosion and sediment control
are inadequate, that publicly owned lands or resources would be damaged, or the work does not
protect fresh water resources.3615
Upon review of application and comments, the Secretary may issue a well work permit.
If no objection is made, the permit will be issued.
3616 Any such permit will expire automatically
unless the permitted well work is commenced within 24 months of the permit date.3617 Permits
may not be extended to authorize work after the expiration date, nor may they be transferred to
other parties.3618
Before drilling a well, or before fracturing or stimulating a well, the operator must
prepare a plat detailing the location and work to be done. If the location is underlain by one or
more coal seams, copies of the plat must be forwarded by registered or certified mail to each coal
operator who operates those coal seams and is filed at the Office of Miners’ Health, Safety, and
Training, and to coal seam owners and lessees, if they are not yet operating the coal seams. The
same plat and information should be sent to the Secretary, also.
3619 If no objections are made by
the coal interests or by the Secretary within 15 days of the Secretary’s receipt of the materials,
the Secretary must file the information to become permanent record of the operations.3620
The coal seam owner may, however, within 15 days of the director’s receipt of the plat
and notice, file written objections to the drilling location or fracturing conditions with the
Secretary, setting out the grounds for those objections. If the proposal affects a shallow gas
drilling site above a coal seam or seams, the Secretary must immediately mail, by registered or
certified mail, the Review Board Chair, a notice that the objection to the proposed operations has
3615 Id. 3616 Id. 3617 W. Va. Code R. § 35-4-5.2(g) (2011). 3618 Id. § 35-4-5.2(g)–(h). 3619 W. Va. Code § 22-6-12(a) (2011). 3620 Id. § 22-6-12(b).
718
been filed, along with a copy of the objections, the application, and the plat.3621 No further
action will be taken on the drilling permit application until the Board issues an Order.3622
If the parties are unable to reconcile as to location or conditions, the Review Board must
hold a hearing to consider the application for drilling permit. At the hearing for an objection
filed by the coal owner or the Director, the Board must consider the following:
(1) whether the drilling location is above or in close proximity to any mine opening or shaft, entry, travelway, airway, haulageway, drainageway or passageway, or to any proposed extension thereof, in any operated or abandoned or operating coal mine, or any coal mine already surveyed and platted but not yet being operated; (2) whether the proposed drilling can reasonably be done through an existing or planned pillar of coal, or in close proximity to an existing well or such pillar of coal, taking into consideration the surface topography; (3) whether the proposed well can be drilled safely, taking into consideration the dangers from creeps, squeezes or other disturbances due to the extraction of coal; and (4) the extent to which the proposed drilling location unreasonably interferes with the safe recovery of coal and gas.3623
The objecting party has the burden of proving its case by a preponderance of the
evidence.
3624 However, if the Department is the objecting party or if the proposed well is
to be drilled to a depth of 3,000 feet or more and the drilling location is less than 2,000
feet from the nearest existing well, the burden of proof is on the gas operator.3625
The written order of the Board shall contain findings of fact and conclusions
based thereon concerning the following:
(1) the extent to which the proposed drilling location will unreasonably interfere with present or future coal mining operations on the surface including, but not limited to, operations subject to the provisions of article three, chapter twenty-two of this code; (2) the feasibility of moving the proposed drilling location to
3621 Id. § 22-6-17. 3622 Id. 3623 Id. § 22C-8-7(c). 3624 W. Va. Code R. § 51-1-5.8(a) (2011). 3625 Id.
719
a mined-out area, below the coal outcrop, or to some other location; (3) the feasibility of a drilling moratorium for not more than one year in order to permit the completion of imminent coal mining operations; (4) the methods proposed for the recovery of coal and gas; (5) the distance limitations established in section eight of this article; (6) the practicality of locating the well on a uniform pattern with other wells; (7) the surface topography and use; and (8) whether the order of the Board will substantially affect the right of the gas operator to explore for and produce gas.3626
The Board’s order will instruct the Director of WVDEP to,
(1) refuse a drilling permit; (2) issue a drilling permit for the proposed drilling location; (3) issue a drilling permit for an alternate drilling location different from that requested by the well operator; or (4) issue a drilling permit either for the proposed drilling location or for an alternate drilling location different from that requested by the well operator, but not allow the drilling of the well for a period of not more than one year from the date of issuance of such permit.3627
Pooling under the Shallow Gas provisions of West Virginia law is extremely limited. In
order to submit an application for pooling, there must first be an objection filed by an affected
coal owner or by the Director of WVDEP.
3628
An application for a shallow drilling unit in West Virginia is submitted to the West
Virginia Shallow Gas Well Review Board and must include the following:
Outside of these two limited circumstances,
pooling is unavailable. The Shallow Gas Well Review Board has never actually issued a single
pooling order.
(1) the name and address of the applicant; (2) a plat prepared by a licensed land surveyor or registered professional engineer showing the boundary of the proposed drilling unit, the district and county in which such unit is located, the acreage of the proposed drilling unit, the boundary of the tracts which comprise the proposed drilling unit, the names of the owners of record of each such tract, the proposed well location on the proposed drilling unit, and the proposed well location for which the division refused to issue a
drilling permit; (3) the names and addresses of the royalty owners of the gas underlying the tracts which comprise the proposed drilling unit; (4) the names and addresses of the gas operators of the tracts which comprise the proposed drilling unit; (5) the approximate depth and target formation to which the well for the proposed drilling unit is to be drilled; (6) a statement indicating whether a voluntary pooling agreement has been reached among any or all of the royalty owners of the gas underlying the tracts which comprise the proposed drilling unit and the gas operators of such tracts; (7) an affidavit of publication of the notice of intent to file an application to establish a drilling unit as required in subsection (c) of this section; and (8) such other pertinent and relevant information as the Board may prescribe by reasonable rules promulgated in accordance with the provisions of section six of this article.3629
Prior to filing the application, the applicant must publish a Class II legal advertisement
providing notice of its intent to file an application to establish a drilling unit. This notice must
provide information identifying the proposed location of the unit and state that written protests
and objections can be filed with the Board until ten days after the application submission date.
This notice must be published in the county or counties in which the proposed drilling unit is to
be located.
3630
At the time an application is filed, the applicant must mail a copy of the completed
application by registered or certified mail to each and every person identified on the application
as a royalty owner
3631 or gas operator.3632 This mailing must include a notice of hearing to all
those parties within the proposed unit who have not previously agreed to voluntary pooling.3633
3629 Id. § 22C-8-9(b).
3630 Id. § 22C-8-9(c). 3631 “Royalty owner means any owner of gas in place, or gas rights, to the extent that such owner is not a gas operator as defined in subdivision (13) of this section.” Id. § 22C-8-2(20) (internal citation omitted). 3632 “Gas operator means any person who owns or has the right to develop, operate and produce gas from a pool and to appropriate the gas produced therefrom either for such person or for such person and others. In the event that there is no gas lease in existence with respect to the tract in question, the person who owns or has the gas rights therein shall be considered a ‘gas operator’ to the extent of seven eighths of the gas in that portion of the pool underlying the tract owned by such person, and a ‘royalty owner’ to the extent of one eighth of such gas.” Id. § 22C-8-2(13) (internal citation omitted). 3633 Id. § 22C-8-9(d).
721
If all of the royalty owners and operators within the proposed unit agree to voluntarily
participate in the proposed unit, the applicant must appear on the date provided for in the notices
described above. 3634 At that time, the applicant must present proof that the drilling unit
boundaries have been agreed upon by all affected parties and the coal seam owners have agreed
upon and consented to the well location(s). If all of the foregoing is demonstrated to the Board,
the Board will issue a written Order establishing the unit.3635
If all of the parties cannot agree upon the boundary of the proposed unit, the Board will
hold a hearing
3636
(1) the surface topography and property lines of the lands comprising the drilling unit; (2) the correlative rights of all gas operators and royalty owners therein; (3) the just and equitable share of production of each gas operator and royalty owner therein; (4) whether a gas operator or royalty owner objecting to the drilling unit has proved by clear and convincing evidence that the drilling unit is substantially smaller than the area that will be produced by the proposed well; and (5) other evidence relevant to the establishment of the boundary of a drilling unit.
to consider the application to establish a drilling unit. Within 20 days of the
hearing, the Board shall issue a written order establishing the unit or dismissing the application.
When considering whether or not to establish a drilling unit during a hearing where all of the
parties could not agree upon the boundary of the proposed unit, the Board must consider:
3637
In order for the Board to grant an application to establish a drilling unit or approve a
drilling unit, they must find that:
(1) the applicant has proved that the drilling location on the drilling unit has been agreed to by all of the owners of the coal seams underlying such drilling location; (2) the director has previously refused to issue a drilling permit on one of the tracts comprising the drilling unit because of an order of the Board; (3) the drilling
3634 Id. § 22C-9-10(a). 3635 Id. 3636 All hearings conducted by the Board are to be conducted in accordance with and pursuant to the West Virginia Administrative Procedures Act. See id. § 29A-1-1. 3637 Id. § 22C-8-10(b).
722
unit includes all acreage within the minimum distance limitations provided by section eight of this article, unless the gas operators and royalty owners of any excluded acreage have agreed to such exclusion; and (4) the drilling unit includes a portion of the acreage from under which the well operator intended to produce gas under the drilling permit which was refused.3638
The burden of proof in a proceeding to establish drilling units is on the party initiating the
proceeding, which burden must be met by a preponderance of the evidence.
3639
Once the Board establishes a drilling unit, the order establishing such drilling unit shall
include an order pooling the separately owned interests in the gas to be produced from such
drilling unit.
3640 If a voluntary pooling agreement has been reached between all persons owning
separate operating interests in the tracts comprising the drilling unit, the order of the Board shall
approve such agreement.3641 If no voluntary pooling agreement is reached prior to or during the
hearing, then at such hearing the Board shall also determine the pooling of interests in the
drilling unit.3642
Any order of the Board pooling the separately owned interests in the gas to be produced
from the drilling must be upon terms and conditions which are just and equitable and shall
authorize the production of gas from the drilling unit.
3643
3638 Id. § 22C-8-10(c).
The order shall (1) designate the
applicant as the operator to drill and operate such gas well; (2) prescribe the procedure by which
all owners of operating interests in the pooled tracts or portions of tracts may elect to participate
therein; and (3) provide that all reasonable costs and expenses of drilling, completing, equipping,
operating, plugging, abandoning and reclaiming such well shall be borne, and all production
therefrom shared, by all owners of operating interests in proportion to the net gas acreage in the
3639 W. Va. Code R. § 51-1-5.8(b) (2011). 3640 W. Va. Code § 22C-8-11(a) (2011). 3641 Id. § 22C-8-11(b). 3642 Id. § 22C-8-11(c). 3643 Id. § 22C-8-11(d).
723
pooled tracts owned or under lease to each owner. The order must also make provisions for
payment of all reasonable costs thereof, including all reasonable charges for supervision and for
interest on past-due accounts, by all those who elect to participate therein.3644
Upon request, any such pooling order shall provide an owner of an operating interest an
election to be made within ten days from the date of the pooling order to participate in the risks
and costs of the drilling of the well or to participate in the drilling of the well on a limited or
carried basis on terms and conditions which, if not agreed upon, shall be determined by the
Board.
3645 If the election is not made within the ten-day period, such owner shall be
conclusively presumed to have elected the limited or carried basis. Thereafter, if an owner of
any operating interest in any portion of the pooled tract shall drill and operate, or pay the costs of
drilling and operating, a well for the benefit of such nonparticipating owner as provided in the
order of the Board, then such operating owner shall be entitled to the share of production from
the tracts or portions thereof pooled accruing to the interest of such nonparticipating owner,
exclusive of any royalty or overriding royalty reserved with respect to such tracts or portions
thereof, or exclusive of one-eighth of the production attributable to all unleased tracts or portions
thereof, until the market value of such nonparticipating owner’s share of the production,
exclusive of such royalty, overriding royalty of one-eighth of production, equals double the share
of such costs payable by or charged to the interest of such nonparticipating owner.3646
[2] – Analysis of Regulatory Framework: Oil and Deep Gas Development.
[a] Governing Body.
West Virginia Code sections 22C-9-1 to 22C-9-16 details the laws governing the
development of oil and deep gas resources in West Virginia. This Code chapter establishes the
3644 Id. 3645 Id. § 22C-8-11(e). 3646 Id.
724
Oil and Gas Conservation Commission (“Commission”), describes its power, authority, and
jurisdiction, and details the process and requirements for pooling and unitizing oil and deep gas
interests for development in West Virginia. West Virginia Code section 22C-9-1 provides that it
is the public policy of West Virginia and in the best interest to:
(1) foster, encourage and promote exploration for and development, production, utilization and conservation of oil and gas resources; (2) prohibit waste of oil and gas resources and unnecessary surface loss of oil and gas and their constituents; (3) encourage the maximum recovery of oil and gas; and (4) safeguard, protect and enforce the correlative rights of operators and royalty owners in a pool of oil or gas to the end that each such operator and royalty owner may obtain his just and equitable share of production from such pool of oil or gas.3647
[b] Membership of Governing Body.
The West Virginia Oil and Gas Conservation Commission is composed of five members.
The Secretary of the WVDEP and the Chief of the WVDEP Office of Oil and Gas are permanent
members of the Commission. The remaining three members are appointed by the Governor with
the advice and consent of the Senate. 3648
(1) an independent producer; (2) a member of the public that is not engaged in any activity under the jurisdiction of the West Virginia Public Service Commission or the Federal Energy Regulatory Commission; and (3) an individual who has a degree from an accredited college or university in petroleum engineering or geology and is a registered professional engineer with particular knowledge and experience in the oil and gas industry, which individual shall serve as chair of the Commission.
None of the three appointed members can be
employees of the WVDEP and must represent respectively:
3649
Commission members appointed by the Governor sit on the Commission for overlapping
six-year terms. There is no limit to the number of terms a Commission member can serve, and a
new appointee must be named by the Governor in 60 days in the case of a vacancy on the
Commission. Commission members can be removed for (1) incompetency, (2) neglect of duty,
(3) gross immorality, or (4) malfeasance. A provision also exists which requires dismissal of an
appointed Commission member who fails to attend three consecutive meetings.3650
[c] Scope of Authority.
The Commission has authority over all persons and property necessary for the
implementation of West Virginia Code sections 22C-9-1 to 22C-9-16, subject to a number of
exceptions.3651 The Commission has the authority to regulate spacing of deep wells.3652 The
Commission is also authorized to issue or deny permits, establish drilling units or special field
rules, and approve or deny applications for the pooling of interests within a unit. 3653 Any
exception to field rules or spacing rules and any application for pooling the interests in a drilling
unit must be brought before the Commission for a hearing.3654 In furtherance of all of these
powers the Commission can make investigations of records and facilities; issue subpoenas; and
make and enforce reasonable rules to prevent waste, protect correlative rights and govern the
practice and procedure before the Commission.3655
3650 Id. § 22C-9-4(b).
3651 Id. § 22C-9-3(b). “This article shall not apply to or affect: (1) Shallow wells other than those utilized in secondary recovery programs; (2) Any well commenced or completed prior to March 9, 1972, unless such well is, after completion, deepened subsequent to that date to a formation at or below the top of the uppermost member of the “Onondaga Group”; or involved in secondary recovery operations for oil under an order of the Commission entered pursuant to section eight of this article; (3) Gas storage operations; (4) Free gas rights. The Commission does not have power to: Limit production or output, prorate production or fix prices of oil or gas.” Id. 3652 Id. § 22C-9-4(f). 3653 Id. § 22C-9-4(h). 3654 Id. § 22C-9-4(i). 3655 Id. § 22C-9-4(e)–(f).
726
An important policy note is that the statute specifically provides that “[i]n the event of a
conflict between the duty to prevent waste3656 and the duty to protect correlative rights, the
Commission’s duty to prevent waste shall be paramount.”3657
(1) physical waste, as the term is generally understood in the oil and gas industry; (2) the locating, drilling, equipping, operating or producing of any oil or gas well in a manner that causes, or tends to cause a substantial reduction in the quantity of oil or gas ultimately recoverable from a pool under prudent and proper operations, or that causes or tends to cause a substantial or unnecessary or excessive surface loss of oil or gas; (3) the drilling of more deep wells than are reasonably required to recover efficiently and economically the maximum amount of oil and gas from a pool; (4) substantially inefficient, excessive or improper use, or the substantially unnecessary dissipation of, reservoir energy; (5) inefficient storing of oil or gas; and (6) other underground or surface waste in the production or storage of oil, gas or condensate.
Waste means:
3658
[d] Pooling Process and Matters Covered.
Procedural rules before the Commission are codified in the Code of State Regulations
Title 39 Series 2. These rules are quite general and simply provide that a majority of the
Commission is necessary for any decision to be rendered and also generally describe attorney
conduct before the Commission. Otherwise, the rules of practice and procedure before the
Commission are governed by the West Virginia Administrative Procedures Act.3659
Before an operator can file an application to establish a pool, it must drill a discovery
well into the formation or formations where it seeks to establish the pool or pools. Upon the
While the
rules and regulations do not specifically state what must be included in an application for the
establishment of a drilling unit or the pooling of interests within a unit, the statute does
specifically provide the factors that the Commission must consider before issuing a final order.
3656 Id. § 22C-9-6 specifically states that, “Waste of oil or gas is hereby prohibited.” 3657 Id. § 22C-9-4(e)–(f). 3658 Id. §22-6-1(t). 3659 Id. § 29A-1-1.
727
filing of an application to establish drilling units, the Commission must provide notice to all
interested parties.3660 Each notice must include a description of the affected area, the time, date
and place of a hearing, and must include a statement that any party has a right to a hearing before
the Commission upon request. Any request for hearing must be filed with the Commission
within 15 days of receipt of notice. If no request for hearing has been received within the 15 days
following receipt of the notice, the Commission may proceed to process the application.3661
Before issuing an order establishing a drilling unit or units, the Commission must
determine the acreage to be included in each unit, the spacing of the unit(s), and the distance
from the outside boundary of a unit at which a deep well may be drilled.
3662
(1) the surface topography and property lines of the lands underlaid by the pool to be included in such order; (2) the plan of deep well spacing then being employed or proposed in such pool for such lands; (3) the depth at which production from said pool has been found; (4) the nature and character of the producing formation or formations, and whether the substance produced or sought to be produced is gas or oil or both; (5) the maximum area which may be drained efficiently and economically by one deep well; and (6) any other available geological or scientific data pertaining to said pool which may be of probative value to the Commission in determining the proper deep well drilling units therefore.
In making these
determinations, the Commission must consider the following factors:
3663
The Commission shall, within 45 days after the filing of an application to establish
drilling units for a pool, enter an order establishing such drilling units, dismiss the application, or
for good cause, continue the application process.
3664
3660 Id. § 22C-9-7(1)–(2).
As part of the order establishing a drilling
unit, the Commission shall prescribe just and reasonable terms and conditions upon which the
royalty interests in the unit shall, in the absence of a voluntary agreement, be deemed to be
integrated without the necessity of a subsequent order integrating the royalty interests.3665
If a hearing has been held on an application, the order shall be a final order. If no hearing
has been held, the Commission shall issue a proposed order and shall provide a copy of the
proposed order, together with notice of the right to appeal and request a hearing, to all interested
parties. Any party aggrieved by the proposed order may appeal the proposed order to the full
Commission and request a hearing. Notice of appeal and request for hearing shall be made in
accordance with section 10 of this article within 15 days of entry of the order. If no appeal and
request for hearing has been received within 15 days, the proposed order shall become final.
3666
When two or more separately owned tracts are included within a drilling unit, or when
there are separately owned interests in all or a part of a drilling unit, the interested persons may
pool their tracts or interests for the development and operation of the drilling unit.
3667 In the
absence of voluntary pooling and upon application of any operator having an interest in the
drilling unit, the Commission shall set a hearing and provide notice to all interested parties.3668
After the hearing, the Commission shall enter an order pooling all tracts or interests in the
drilling unit for the development and operation thereof and for sharing production therefrom.3669
Each such pooling order must include terms and conditions which are just and reasonable; and
under no circumstances can drilling be initiated on the tract of an unleased owner without the
owner's written consent.3670
3665 Id. § 22C-9-7(a)(10).
3666 Id. § 22C-9-7(a)(11). 3667 Id. § 22C-9-7(b)(1). 3668 Id. 3669 Id. 3670 Id. Requirement are reiterated in West Virginia Code section 22C-9-7(b)(4), which also states that valuable consideration must be given in exchange for the consent and an easement therefore.
729
Any pooling order issued by the Commission shall authorize the drilling and operation of
a deep well for the production of oil or gas from the pooled acreage.3671 The order must also
designate the operator to drill and operate such deep well, prescribe the time and manner in
which all owners of operating interests in the pooled tracts or portions of tracts may elect to
participate therein; and provide that all reasonable costs and expenses of drilling, completing,
equipping, operating, plugging and abandoning such deep well shall be borne, and all production
therefrom shared, by all owners of operating interests in proportion to the net oil or gas acreage
in the pooled tracts owned or under lease to each owner. 3672 The order must also include
provisions for payment of all reasonable costs of operating and drilling the well(s), including a
reasonable charge for supervision and for interest on past-due accounts, by all those who elect to
participate therein.3673
The Conservation Commission also has authority over secondary recovery of oil. The
Commission must set a hearing and provide notice to all interested parties upon application of an
operator in a pool that is productive of oil.
3674
(1) The order is reasonably necessary for the prevention of waste and the drilling of unnecessary wells;
After hearing, the Commission may enter an order
requiring unit operation of the pool in connection with secondary recovery of oil and unitizing
the separately owned tracts and interests within such pool. Such an order may only be made if
the Commission makes the following findings:
(2) The proposed plan of secondary recovery will increase the ultimate recovery of oil from the pool to such an extent that the proposed secondary recovery operation will be economically feasible;
(3) The production of oil from the unitized pool can be allocated in such a manner as to ensure the recovery by all operators of their just and equitable share of such production; and (4) The operators of at least three-fourths of the acreage . . . and the royalty owners of at least three fourths of the acreage . . . in such pool have approved the plan and terms of unit operation to be specified by the commission in its order, such approval to be evidenced by a written contract setting forth the terms of the unit operation and executed by said operators and said royalty owners, and filed with the Commission.3675
The order providing for unit operation will designate one operator in the pool as unit
operator and will include provisions for the proportionate allocation to all operators of costs and
expenses of unit operation, including reasonable charges for supervision and interest on past-due
accounts, which allocation shall be in the same proportion that the separately owned tracts share
in production from the unit.
3676 If no agreement can be reached regarding costs, the Commission
will provide for the sharing of costs, so long as any operator who has not consented to unitization
is not required to contribute to the costs and expenses of unit operation or to the cost of capital
investment, except out of the proceeds from the sale of that owner’s proportionate share of
production.3677
[3] – Analysis of the Regulatory Framework: Coalbed Methane Development.
[a] Governing Body.
West Virginia Code sections 22-21-1 to 22-21-41 details the laws governing the
development of coalbed methane (CBM) resources in West Virginia. The Chief of the Office of
Oil and Gas is primarily responsible for carrying out the chapter.3678
3675 Id.
This Code chapter also
establishes the West Virginia Coalbed Methane Review Board (“CBM Review Board”),
describes its power, authority, and jurisdiction, and details the process and requirements for
pooling and unitizing CBM interests for development in West Virginia. West Virginia Code
section 22-21-1 provides that it is the public policy of West Virginia and in the best interest to:
(1) preserve coal seams for future safe mining; facilitate the expeditious, safe evacuation of coalbed methane from the coalbeds of this state, and maintain the ability and absolute right of coal operators at all times to vent coalbed methane from mine areas; (2) foster, encourage and promote the commercial development of this state's coalbed methane by establishing procedures for issuing permits and forming drilling units for coalbed methane wells without adversely affecting the safety of mining or the mineability of coal seams; (3) safeguard, protect and enforce the correlative rights of coalbed methane well operators and coalbed methane owners in a pool of coalbed methane to the end that each such operator and owner may obtain his or her just and equitable share of production from coalbed methane recovered and marketed under this article; (4) safeguard and protect the mineability of coal during the removal of coalbed methane, as permitted under this article; (5) create a state permitting procedure and authority to provide for and facilitate coalbed methane development as encouraged by the Energy Policy Act of 1992; and (6) seek the deletion of the state of West Virginia from the list of affected states by the secretary of the United States department of the interior as provided for in the Energy Policy Act of 1992.3679
[b] Membership on the Governing Board.
The Coalbed Methane Review Board is comprised of seven members. All three members
of the West Virginia Shallow Gas Well Review Board are also on the Coalbed Methane Review
Board. The chair of the Shallow Gas Well Review Board also serves as the chair of the CBM
Review Board. The other members include (1) the West Virginia state geologist; (2) a
representative of the United Mine Workers of America; (3) an employee of the gas industry; and
(4) the Director of the Office of Miners' Health, Safety, and Training.3680
3679 Id. § 22-21-1(b).
A majority of the
3680 Id.
732
CBM Review Board constitutes a quorum and a quorum is required in order for the Board to
decide any issue before it.3681
[c] Scope of Authority.
The Chief of the Office of Oil and Gas has the duty “of issuing permits and otherwise
supervising the execution and enforcement of the provisions of this article.”3682 The Chief is
further authorized to enact rules necessary to carry out the purpose of the article and to perform
“all duties as the permit issuing authority for the state in all matters pertaining to the exploration,
development, production and recovery of coalbed methane.”3683
The CBM Review Board is an appellate body much like the Shallow Gas Well Review
Board and has jurisdiction and authority over all persons and property necessary for the
implementation of Article 21. The Board does not, however, have the authority to fix the price
of coalbed methane gas.
3684
(1) take evidence, conduct hearings and issue orders concerning applications for drilling permits and coalbed methane gas drilling units and the pooling of the interests therein; (2) promulgate, pursuant to the West Virginia Administrative Procedures Act,
The Board is specifically granted the power to do the following:
3685 and enforce reasonable rules necessary to govern the practice and procedure before the Board; (3) propose legislative rules pursuant to the West Virginia Administrative Procedures Act necessary to implement the powers and duties of the Board; (4) make relevant investigations of records and facilities it considers proper; and (5) issue subpoenas for the attendance of and sworn testimony by witnesses and subpoenas duces tecum for the production of any books, records, maps, charts, diagrams and other pertinent documents in its own name or at the request of any party.3686
The Chief of the Office of Oil and Gas acts in the same capacity regarding CBM wells as
the Secretary of the WVDEP does regarding conventional oil and gas wells. Namely, any entity
wishing to commence, operate, deepen, or stimulate any CBM well, to drill a horizontal CBM
well, or to convert any existing well to a CBM well must first obtain a permit from the Chief.3687
Permits must contain the names and addresses of the well operator, every person entitled to
notification, and each coal operator of record of any coal seam that is to be penetrated, that is
within 750 horizontal feet of any part of the proposed well bore or that is within 100 vertical feet
of the coal seam to be stimulated, unless the permit is for conversion of a ventilation hole to a
gob well.3688 In addition to other requirements, permits must specify the depth to which the well
should be drilled, the coal seams to be penetrated and to be completed by the well, and the means
proposed for stimulation of the well.3689
All CBM well permit applications must be accompanied by sufficient bond, an
application fee, an erosion and sediment control plan, consent and agreement of certain coal
seam owners, a plat with certain specifications, and certification that the notice requirements
have been satisfied.
3690 Also, before filing the application, the applicant must deliver by
personal service or by certified mail, return receipt requested, copies of the application, well plat,
and erosion and sediment control plan to owners of the surface of the tracts both on which the
well is to be located and on which the surface is to be used for roads or other land
disturbance.3691
3687 Id. § 22-21-6(a).
Owners and lessees and each operator of natural gas surrounding the well bore
3688 Id. § 22-21-6(b)(1)–(2). A “gob well” is defined as a “well drilled or vent hole converted to a well pursuant to this article which produces or is capable of producing coalbed methane or other natural gas from a distressed zone created above and below a mined-out coal seam by any prior full seam extraction of the coal.” Id. § 22-21-1(l). 3689 Id. § 22-21-6(b)(2)–(3). 3690 Id. § 22-21-6(c). 3691 Id. § 22-21-9(a)(1)–(2).
734
and existing formations above the top of the uppermost member of the Onondaga Group or less
than 6,000 feet deep, whichever is shallower, are also entitled to notice.3692
The coal owner consent requirement in section 7 of article 21 states that the CBM well
applicant must receive consent by each coal owner and operator of any workable seam in the
state that is 28 inches or more thick that is within 750 horizontal feet of the proposed well bore
and (1) which coal seam the applicant plans to stimulate or (2) which coal seam is within 100
vertical feet above or below a coal seams the applicant plans to stimulate.
3693 If the applicant
already has a contract or lease with the coal owner or operator for the development of CBM, that
contract constitutes a waiver of the consent requirements.3694
(1) A statement that a coal owner or operator as described in subsection (a) of this section has refused to provide written authorization to stimulate the well; (2) A statement detailing the efforts undertaken to obtain such authorization; (3) A statement setting out any known reasons for the authorization not being provided; and (4) A statement or other information in addition to that provided pursuant to subdivision (5), subsection (b), section six of this article necessary to provide prima facie evidence that the proposed method of stimulation will not render the coal seam unworkable, or considering all factors, impair mine safety.
If the required consent is not
given, the applicant may submit a hearing requires to the Coalbed Methane Review Board along
with an affidavit including the following:
3695
Besides merely not providing consent, a coal owner may also file a written objection of the
proposed drilling with the Chief within 15 days of receipt of notice and must explain the reasons
The Chief will review permit applications. No permit may be issued within 15 days of
the filing date, in order to provide time for comments or objections, unless the applicant certifies
that all persons entitled to notice have been properly served and have written statements of no
objection to the well and access road locations. 3697 Permits that are issued will expire
automatically unless well work is commenced within 24 months of the permit date; no permit
may be extended to authorize the well work after the permit expires.3698
If comments or objections are filed, the Chief will provide to the Chairman of the CBM
Review Board a copy of the objection or comment, along with the permit application in question,
the corresponding plat, and other related information.
3699 The CBM Review Board will
promptly schedule a hearing, for which it will provide 15 days’ notice to any person that
submitted comments or objections, to any person entitled to notice of the application, and to any
applicant. In making its decision, the Review Board must consider the issues raised, including
surface topography and use and, among other aspects, must consider the ability to mine any
affected coal seam safely and to protect the future mining of such seams.3700 The applicant has
the burden of proving by clear and convincing evidence that stimulation of the workable coal
seam of 28 inches thick or more will not render that seam or any other seam of that or greater
thickness unmineable or unsafe for mining.3701
3697 Id. § 22-21-12.
The CBM Review Board must then make a
decision and file an order with the Chief, directing him to either refuse a permit, issue a permit
for the same or an alternate drilling location, issue a permit for the same or an alternate location
3698 W. Va. Code R. § 53-3-4.7.e (2011). 3699 W. Va. Code § 22-21-13(a) (2011). 3700 Id. § 22-21-13(b). 3701 Id. § 22-21-13(c).
736
but not allow drilling for a period of not more than one year from date of issuance of permit, or
to issue a permit without consent, while requiring evidence of sufficient financial security.3702
In the absence of a voluntary agreement, an operator, owner or other party claiming an
ownership interest in the coalbed methane may file an application with the Chief to pool (1)
separately owned interests in a single tract; (2) separately owned tracts; (3) separately owned
interests in any tract; and (4) any combination of (1), (2) and (3) to form a drilling unit for the
production of coalbed methane from one or more coalbed methane wells.
3703
(1) the identity of each well and operator as set out in the well permit application; (2) each well number, if one has been assigned; (3) the acreage of the proposed unit, the identity and acreage of each separate tract to be included in the proposed unit and, where parts of tracts are included, the acreage of such parts; (4) the district and county in which the unit is located; (5) the names and addresses of all persons to whom notice must be provided.
An application for
the creation of a drilling unit and pooling of the interest therein can be filed concurrently with a
permit application or filed later as a supplement to the permit. An application for the creation of
a drilling permit must contain the following:
3704
3702 Id. § 22-21-13(d).
When any coal seam is separately owned, the list of names shall identify such separate ownership giving the names of the separately owned seams; (6) statement describing the actions taken by the applicant to obtain a voluntary agreement from each interest owner or claimant named in the application to whom notice must be provided or any other owner or claimant who has notified the applicant of a claim from which agreement has not been obtained;
3703 Id. § 22-21-15(a). 3704 West Virginia Code section 22-21-16(a) provides that, “At least thirty days prior to the date set for hearing, the applicant shall deliver by personal service or by certified mail, return receipt requested, notice to the following:
(1) Each coal owner of record and coal operator of record of any coal seam underlying any tract or portion thereof which is proposed to be included in the unit;
(2) Each owner and lessee of record and each operator of natural gas surrounding the well bore and existing in formations above the top of the uppermost member of the “Onondaga Group” or at a depth less than six thousand feet, whichever is shallower. Notices to gas operators shall be sufficient if served upon the agent of record with the Office of Oil and Gas; and
(3) Any coalbed methane owner to the extent not otherwise named which interest arises from a deed, lease, contract, will, inheritance or other instrument of record wherein a person or entity identified in subdivision (1) or (2) of this section or the predecessor in title to such person or entity, expressly granted, leased, reserved or conveyed coalbed methane.
737
and (7) other pertinent and relevant information as the chief may prescribe by rules.3705
In addition to the information detailed above, the applicant must also provide the
following for the Board:
(1) A plat prepared by a licensed land surveyor or registered professional engineer showing the location of the coalbed methane well or wells, or proposed well or wells, the boundary and acreage of the proposed drilling unit, the boundary and acreage of each tract contained in the unit and, where parts of tracts are included, the boundary and acreage of such parts, a name identification of each tract and the district and county in which the unit is located. All boundaries must be shown with courses and distances; (2) A permit application fee of $250; (3) A certificate by the applicant that the notice requirements of section sixteen of this article were satisfied by the applicant. Such certification may be by affidavit of personal service, or the return receipt card, or other postal receipt, for certified mailing; (4) An estimate of the cost, or the actual cost if known, of drilling, completing and equipping, operating, plugging and abandoning any well or wells in the proposed unit.3706
After submitting the application, the Board sets a hearing date and issues notice to all
required parties. Prior to the time set for hearing, the Board must also set a time and place for
the applicant and all person to whom notice is required and who have not yet entered into a
voluntary agreement to hold a conference, at which time those parties may enter into a voluntary
agreement.
3707
(1) the area which may be drained efficiently and economically by the proposed coalbed methane well or wells; (2) the plan of development of the coal and the need for proper ventilation of any mines or degasification of any affected coal seams; (3) the nature and character of any coal seam or seams which will be affected by
If such agreement was not reached, the hearing will take place, at which time the
Board must take evidence and make a record thereof. Prior to issuing an order on the
the coalbed methane well or wells; (4) the surface topography and property lines of the lands underlaid by the coal seams to be included in the unit; (5) evidence relevant to the proper boundary of the drilling unit; (6) the nature and extent of ownership of each coalbed methane owner or claimant and whether conflicting claims exist; (7) whether the applicant for the drilling unit proposes to be the operator of the coalbed methane well or wells within the unit; and if so, whether such applicant has a lease or other agreement from the owners or claimants of a majority interest in the proposed drilling unit; (8) whether a disagreement exists among the coalbed methane owners or claimants over the designation of the operator for any coalbed methane wells within the unit and, if so, relevant evidence to determine which operator can properly and efficiently develop the coalbed methane within the unit for the benefit of the majority of the coalbed methane owners; (9) if more than one person is interested in operating a well within the unit, the estimated cost submitted by each such person for drilling, completing, operating and marketing the coalbed methane from any proposed well or wells; and (10) any other available geological or scientific data pertaining to the pool which is proposed to be developed.3708
The Board shall take into account the evidence introduced, comments received and any
objections at the hearing, and if satisfied that a drilling unit should not be established, it shall
enter an order denying the application.
3709
(1) establish the boundary of the proposed unit, making such adjustment in the boundary as is just; (2) authorize the drilling and operation of a coalbed methane well or wells for production of coalbed methane from the pooled acreage; (3) establish minimum distances for any wells in the unit and for other wells which would drain the pooled acreage; (4) designate the operator who will be authorized to drill, complete and operate any well or wells in the unit; (5) establish a reasonable fee for the operator for operating costs, which shall include routine maintenance of the well and all accounting necessary to pay all expenses, royalties and amounts
If the Board is satisfied that a drilling unit should be
established, it shall enter a pooling order establishing a drilling unit. Such pooling order shall do
the following:
3708 Id. § 22-21-17(b). 3709 Id. § 22-21-17(c).
739
due working interest owners; (6) and such other findings and provisions as are appropriate for each order.3710
The operator designated in the final pooling order shall be responsible for drilling,
completing, equipping, operating, plugging and abandoning the well, shall market all production
from the well, shall collect all proceeds, and shall distribute such proceeds in accordance with
the division order issued by the review Board.
3711 All operations on a drilling unit for which a
pooling order has been entered are deemed operations on each separately owned tract in the unit
by the several owners thereof. The production allocated to each separately owned tract is
likewise deemed to be produced from those tracts.3712
§ 49.02 Types of Pooling Statutes in West Virginia.
[1] – Mineral Distinctions.
In West Virginia, oil, gas, and coalbed methane (“CBM”) are defined and regulated
according to several separate statutes. The coverage of the respective statutes for traditional
natural gas is determined by depth. Production from shallow natural gas formations is regulated
by the Secretary of the WVDEP and the West Virginia Shallow Gas Well Review Board and
must be developed and produced in accordance with West Virginia Code sections 22C-8-1 to
22C-8-19. The West Virginia Code defines a shallow well as:
any well drilled and completed in a formation above the top of the uppermost member of the “Onondaga Group”: [p]rovided that in drilling a shallow well the operator may penetrate into the “Onondaga Group” to a reasonable depth, not in excess of twenty feet, in order to allow for logging and completion operations, but in no event may the “Onondaga Group” formation be otherwise produced, perforated, or stimulated in any manner.3713
The Code defines a deep well as “any well, other than a shallow well, drilled and completed in a
formation at or below the top of the uppermost member of the ‘Onondaga Group.’” 3714
Coalbed methane production and development is administered by the Chief of the Office
of Oil and Gas and by the West Virginia Coalbed Methane Review Board and must be developed
and produced in accordance with West Virginia Code sections 22-21-1 to 22-21-29. “Coalbed
methane” is gas which can be produced from a coal seam, the rock or other strata in
communication with a coal, a mined-out area, or a gob well. A “coalbed methane well” is any
hole or well sunk, drilled, bored, or dug into the earth for the production of coalbed methane.
Production of oil and from deep natural gas formations is regulated by the Secretary and by the
West Virginia Oil and Gas Conservation Commission and must be developed and produced in
accordance with West Virginia Code sections 22C-9-1 to 22C-9-16.
3715
[2] – Depth/Size and Spacing.
By statute, the Secretary of the WVDEP does not explicitly have authority to set spacing
for oil and gas wells. However, the Secretary does hold the authority to perform all duties as the
state permitting authority.3716 While no spacing laws or regulations have been promulgated for
initial well permits, the plat that a well work permit applicant must submit must show all wells
within 1,200 feet of the subject well, unless the application is for a shallow gas well with a depth
of 3,000 feet or more which penetrates a coal seam, in which case the plat must show all wells
within 2,400 feet of the subject well. 3717
[a] Shallow Gas Wells.
Presumably this information is considered by the
Secretary in determining whether to grant a permit.
3714 Id. § 22-9-2-(a)(12). 3715 Id. § 22-21-2. 3716 Id. § 22-6-2. 3717 W. Va. Code R. § 35-4-9.2(j) (2011).
741
For shallow gas wells, the Shallow Gas Review Board oversees the spacing requirements.
By statute, there are no minimum spacing requirements if the coal seam owner(s) underlying the
well or unit do not file an objection to the proposed well location. If the gas operator and coal
seam owner cannot agree on a location, then statute provides that the Board must direct the
Secretary to refuse to issue a drilling permit unless the following spacing provisions apply.3718
For all shallow wells with a depth less than 3,000 feet, there shall be a minimum distance
of 1,000 feet from the drilling location to the nearest existing well.
3719 For shallow wells drilled
to a depth of 3,000 feet or more, there must be at least 1,500 feet from the drilling location to the
nearest existing well.3720 If a coal owner objects to a well location that is between 1,500 and
2,000 feet from the nearest existing well, the gas operator has the burden of establishing the need
for the drilling location less than 2,000 feet from such nearest existing well. When the distance
between a proposed well location and the nearest existing well is greater than 2,000 feet, a coal
owner cannot file an objection based on spacing.3721
These minimum distance limitations do not apply if the proposed shallow well will be
drilled through an existing or planned pillar of coal required for protection of a preexisting oil or
gas well and the proposed well will neither require enlargement of such pillar nor otherwise have
an adverse effect on existing or planned coal mining operations.
3722
[b] Oil and Deep Natural Gas Wells; Coalbed Methane Wells.
3718 W. Va. Code § 22C-8-8(a) (2011). 3719 Id. § 22C-8-8(a)(1). "Existing well" means (i) any well not plugged within nine months after being drilled to its total depth and either completed in the same target formation or drilled for the purpose of producing from the same target formation, and (ii) any unexpired, permitted drilling location for a well to the same target formation. Id. § 22C-8-8(b). 3720 Id. § 22C-8-8(a)(2). 3721 Id. § 22C-8-8(a). 3722 Id. § 22C-8-8(c).
742
For oil and deep natural gas wells, the Oil and Gas Conservation Commission has
authority to regulate spacing.3723 There are no statutorily defined spacing requirements like
those for shallow wells. However, the Commission has promulgated rules that apply to location
of wells.3724 With an eye toward preventing waste, and “in the absence of an application for
special field rules or special field rules ordered by the Commission establishing drilling units or
authorizing different deep well spacing or location patterns for a particular field or pool or parts
thereof,” deep wells should not be less than 3,000 feet from any permitted deep well location or
any deep well drilling to or capable of producing hydrocarbons from the objective pool of the
deep well.3725 No such well should have less than a 400-foot setback from any unit or lease
boundary.3726 The Commission has the authority to determine deep well pattern locations for
deep wells located adjacent to any area governed by special field rules where enough evidence
exists to show that the pool spaced by such special field rules may extend beyond the spacing
order boundary and where uniformity in the spacing pattern is necessary for orderly development
of the field.3727 The rules also provide the Commission with the authority grant exceptions to
well locations, which exceptions may not prevent any operator from drilling a deep oil or gas
well on adjacent lands, directly or diagonally offsetting the exception, at locations allowed by the
applicable special field rules that the Commission has ordered.3728
The spacing of CBM wells is specifically provided for in West Virginia Code section 22-
21-20. No CBM well may be drilled closer than 100 feet from the outermost boundary of the
CBM tract, leased premises, or unit from which CBM will be produced, unless all owners and
operators of “any affected workable coal seams3729 agree in writing.”3730 Spacing will otherwise
be that provided by pooling order issued by the Chief, an order establishing special field rules, or
an order issued by the CBM Review Board.3731
Neither the shallow gas well nor the CBM statutes discussed above provide for a stated
maximum or minimum acreage for any pooled unit. West Virginia Code section 22C-9-7(a)(5)
and (7) establish a minimum and maximum size for oil and deep gas units. No drilling unit
established by the Commission may be smaller than the maximum area that can be drained
efficiently or economically by one deep well.
3732 However, if there is not enough evidence to
determine the area that can be drained efficiently and economically by one deep well, the
Commission may enter a temporary order until the requisite information is obtained to make
such a determination.3733
An order that establishes drilling units must specify setback requirements from the
nearest outside boundary of the drilling unit in which a deep well may be drilled.
3734 The
minimum distance should be the same in all drilling units with exception for deep wells drilled at
the time the application was filed.3735
3729 “Affected workable coal seams” for purposes of this section shall be those which will be penetrated or those seams more than twenty-eight inches in thickness from which production is targeted. W. Va. Code § 22-21-20 (2011).
The Commission may make an order allowing deep wells
to be drilled at locations within the minimum prescribed distance when a well drilled in
conformity with those provisions would not be likely to produce in paying quantities, would
encounter burdensome or hazardous surface or drilling conditions, or the location is prohibited
to participate in the risks and costs of the well must be given two options. The first option is for
the owner to surrender his or her interest or a portion thereof to the participating owners for
reasonable consideration, which, if not agreed upon, shall be determined by the Board.3742 The
second option is to participate in the costs and risks associated with drilling the deep well on a
limited or carried basis upon terms and conditions, which, if not agreed upon, shall be
determined by the Commission.3743
Pooling orders for CBM units provide three options for a coalbed methane owner
regarding participation in the unit:
(1) an election to sell or lease its interest to the operator on such terms as the parties may agree, or if unable to agree, upon such terms as are set forth by the Board in its Order; (2) an election to become a working interest owner by participating in the risk and cost of the well; or (3) an election to participate in the operation of the well as a carried interest owner.
A party that fails to make an election within 30 days of the issuance of the pooling order shall be
deemed to have elected to sell or lease their interest pursuant to the first option.3744
[4] – Minimum Operator Control
The West Virginia Code only provides for minimum operator controls in one instance, in
the unit operation of secondary oil recovery under the authority of the West Virginia
Conservation Commission.3745 In that case, the Commission must find that operators of at least
three-fourths of acreage and that the royalty owners of at least three-fourths of the acreage in the
pool have approved the plan and terms of unit operations to be specified in the Commission’s
order prior to the Commission’s issuance of said order.3746
The Act provides that no person, meaning “an individual, owner, operator, corporation,
limited liability company, partnership, association, municipality, interstate agency, state agency
or federal agency,”3757 may engage in oil and gas exploration or production without a license
issued from the Department.3758
(a) Submit any information that the department considers necessary to determine whether the applicant is competent to conduct oil and gas exploration, production and site reclamation and to determine whether the requirements of sub. (5) are satisfied;
The licensure procedure to be established by the Department for
oil and gas exploration and production must require that the applicant do the following:
(b) Submit any information necessary for the department to determine whether the proposed exploration, production and site reclamation comply with this subchapter and rules promulgated under this subchapter; (c) Pay fees to cover the costs of plan review and licensing; [and] (d) File with the department a bond conditioned on the faithful performance of all of the requirements of this subchapter and rules promulgated under this subchapter.3759
Additionally, no person may commit waste in the exploration or production of oil and
gas.
3760 The rules promulgated by the Department for the prevention of waste in the exploration
for or the production of oil and gas must include rules related to, among other things, the spacing
of wells and the regulation of well production, including the allocation of allowable production
in any field or pool.3761
Although the Department has the authority to promulgate the aforementioned rules, no
rules regarding production of oil and gas have been so promulgated. To date, the only rules
private, necessary to effectuate the purposes and intent of this act . . . .”3772 Pursuant to that
authority, the Commission implements regulations for the permitting of oil and gas wells.3773
[3] – Pooling Process.
[a] Permitting Process; Matters Covered by Permit.
No person may commence drilling a well without first applying for and obtaining a
permit. 3774
(1) detailed information regarding the proposed well site, (2) an accurate plat showing the location of the proposed well together with the proposed depth to which it will be drilled, (3) the type of drilling tools used in its drilling, (4) the identification of all water supply wells permitted by the Wyoming Office of the State Engineer which are located within one-quarter mile of the drilling and spacing unit together with the depth of the water to be appropriated, (5) the depth of the formation, and (6) any information known regarding useable groundwater underlying the drilling or spacing unit.
That application, submitted to the Commission, must contain the following
information:
3775
In addition, the person applying for the permit must attempt to secure the permission of
the surface owner for its drilling activities and provide compensation to that owner for damage
caused to the surface in connection with drilling activities.
3776 In lieu of such consent, the
applicant can provide for a bond which will compensate the surface owner for any and all
damages occasioned by its drilling.3777
In addition to ensuring the surface owner is properly compensated for damage to the
surface, the applicant for a well permit must also provide the owner of the surface no less than 30
3772 Id. 3773 055-003 Wyo. Code R. § 1 (Lexis 2011). 3774 Id. § 8. 3775 Id. 3776 Wyo. Stat. Ann. § 30-5-104 (West 2011). 3777 055-003 Wyo. Code R § 8 (stating that application for drilling permit must contain certification that person requesting permit to drill has complied with Wyo. Stat. Ann. section 30-5-402, which requires notice to and compensation for the owners of the surface before conducting drilling activities on their property).
750
days’ advance notice of the date it intends to commence drilling.3778 The applicant for a drilling
permit and the owner of the surface must attempt to negotiate a surface use agreement.3779 That
agreement covers the scope of drilling activities which are permitted for the oil and gas operator
on the surface. Either party to that surface use agreement has the right to have any dispute
resolved through mediation or arbitration.3780
The procedure for drilling a horizontal well is largely the same as for a vertical well. The
only significant difference is that certain additional information is required to permit a horizontal
well. An applicant for a permit proposing to drill a horizontal well must also provide the
following information:
a diagram clearly showing the wellbore path from the surface through the terminus of the lateral. A horizontal well's number shall be appended with an “H” suffix, denoting horizontal, in Block 8 of Form 1. If more than one lateral borehole extends from the same vertical wellbore, each such lateral must be permitted as an individual horizontal well with an “H” suffix. The surface location and the proposed footage locations of both the initial penetration into the productive formation and the terminus of the lateral shall be entered under “Location.” If the application is for a permit to drill a horizontal well, notice of the application shall be given by certified mail to all Owners within one-half mile of any point on the entire length of the horizontal wellbore, from the surface location through the terminus of the lateral. In the absence of any special Commission order, notice is not required for horizontal wells in federally supervised units or in API units provided that no portion of the horizontal interval is closer than six hundred sixty feet (660′) from a drilling or spacing unit boundary or any uncommitted tract.3781
[b] Voluntary vs. Involuntary Pooling.
If a drilling unit contains two or more separately owned tracts of land, persons who own
such tracts may voluntarily pool their interests for the development of oil and gas operations on
3778 Wyo. Stat. Ann. § 30-5-402 (West 2011). 3779 Id. § 30-5-402. 3780 Id. 3781 055-003 Wyo. Code R. § 8 (Lexis 2011).
751
the unit.3782 If such parties cannot voluntarily agree to pool their interests, the Commission,
upon application and hearing, may force the non-consenting party to pool.3783
Notice and a hearing are required before a party is forced to pool.
3784 Operations on any
part of the unit are deemed operations on any part of an interest forcibly pooled into that unit.3785
The portion of production allocated or applicable to each tract forcibly pooled in a unit is deemed
to have been produced from the tract as if by a well drilled on that tract.3786
A pooling order shall provide for reimbursement for the costs of drilling and operating
the well on each unit.
3787 After paying the landowner’s royalty and other obligations payable out
of production, the party(s) that drills the well is entitled to receive out of the production from that
well the costs incurred in drilling and operating the well.3788 Any dispute regarding whether
those costs are reasonable is resolved by the Commission.3789
Where there are multiple owners of the right to drill within a unit, the Commission will
determine each owner’s proportionate interest in the unit.
3790 If each such owner agrees to share
in his or her proportionate share of the expense incurred by the party(s) in drilling and operating
the well, that owner is entitled to his proportionate share of production, from the well on the
unit.3791
3782 Wyo. Stat. Ann. § 30-5-109(f) (West 2011).
However, if an owner does not agree to share in such expenses, that non-consenting
owner is only entitled to receive his proportionate share of production after the person(s) who
(i) One hundred percent (100%) of each such nonconsenting owner’s share of the cost of any newly acquired surface equipment beyond the wellhead connections (including, but not limited to, stock tanks, separators, treaters, pumping equipment and piping), plus one hundred percent (100%) of each such nonconsenting owner’s share of the cost of operation of the well commencing with first production and continuing until each such nonconsenting owner’s relinquished interest shall revert to it under other provisions in this section, it being intended that each nonconsenting owner’s share of such costs and equipment will be that interest which would have been chargeable to each nonconsenting owner had it initially agreed to pay its share of the costs of said well from the beginning of the operation; and (ii) Up to three hundred percent (300%) of that portion of the costs and expenses of drilling, reworking, deepening or plugging back, testing and completing, after deducting any cash contributions received and up to two hundred percent (200%) of that portion of the cost of newly acquired equipment in the well, to and including the wellhead connections, which would have been chargeable to the nonconsenting owner if he had participated therein.3792
Moreover, until the above described expenses are recouped, the other owners of the right
to drill within the unit, who have agreed to share in the expenses of drilling and operating the
well, may share proportionately in the share of production the non-consenting owners would
have been entitled to had it also shared in the expenses of drilling and operating the well.
3793
There is no minimum operator control required. Nor are there different restrictions based on
whether the well drilled is vertical or horizontal. Finally, coverage under the Wyoming
Conservation Act is not restricted according to the depth of a well drilled.3794
The statutory and regulatory framework governing pooling applies to only oil and gas
and does not extend to cover any other organic or inorganic material.3795
[2] – Split by Depth.
The statute and regulatory framework governing pooling applies to both vertical and horizontal
wells. However, it does not distinguish depth.3796
[3] – Size and Spacing Rules/Size and Spacing Hearings.
Wyoming has mandatory spacing rules. The Wyoming Conservation Act requires that no
unit covering a pool is smaller than the maximum area necessary to drain one well.3797 Each unit
shall contain only one well.3798 All wells must be spaced on 40-acre tracts with the well at its
center. 3799
However, the Commission has the power to vary from these mandatory spacing rules
when it declares a pool and forms drilling units to cover that pool.
3800 The size of the pool and
the number of units it covers is determined by the Commission at a hearing.3801
If party requests a hearing to determine if a well, which is requested for permitting,
should be included within a unit, the permit for the well is stayed until after that hearing.
3802
(i) Owner has the right or obligation under the terms of an existing contract to drill said well; and
However, the applicant for the well may be issued a permit if it provides that the
(ii) Owner has a leasehold estate or right to acquire a leasehold estate under said contract which will be terminated unless he is permitted to commence the drilling of said well before the matter