1 November 5, 2018 Indicator Current Value Week's Change % Change Direction Prompt Oil Price ($/bbl) $63.69 ($3.64) (5.4%) Prompt Gas Price ($/mmbtu) $3.24 $0.04 1.3% Wkly Trans. Value ($mm) $13,728 $13,727 nmf Wkly Trans. Count 6 3 100% US Rig Count 1,067 (1) (0.1%) US Oil Prod'n (mmbbl/d) 11.2 0.3 2.8% US Gas Prod'n (bcf/d) (1) 102.5 2.3 2.3% US Oil Storage (mmbbl) 426.0 3.2 0.8% US Gas Storage (tcf) 3.1 0.0 1.6% $2.2 $8.0 $9.9 $10.7 $4.9 $15.8 $21.2 $21.9 $24.1 $17.0 $9.1 $9.2 $20.8 $8.0 $31.5 $16.5 -- 50 100 150 200 250 300 350 400 450 500 -- $5 $10 $15 $20 $25 $30 $35 $40 1Q15 2Q15 3Q15 4Q15 1Q16 2Q16 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 61% 83% 74% 79% 39% 52% 62% 71% 93% 24% 68% 82% 91% 64% 46% 99% Number of Transactions Transaction Value ($bn) Asset Corporate Number of Transactions % Oil Debt Markets Five issuers priced six tranches for $2.6 billion in proceeds U.S. volume is down 33% year-on-year U.S. high yield funds reported an outflow of $1 billion ETFs reported an inflow of $153 million, while mutual funds reported an outflow of $1.2 billion High yield index yield was 6.87%; high yield energy index yield was 7.57% Encana Corporation acquired Newfield Exploration for approximately $7.7 billion (see page 4 for more details) Chesapeake acquired WildHorse for approximately $4.0 billion (see page 5 for more detail) Denbury Resources acquired Penn Virginia for approximately $1.7 billion (see page 6 for more detail) Parsley Energy sold Midland Basin assets for $170 million Pioneer Natural Resources divested its South Texas Sinor Nest assets for $132 million Halcón Resources divested its Delaware Basin water infrastructure assets for $325 million. BMO Capital Markets acted as co-advisor on this transaction BMO is hosting a call to discuss U.S. midterm elections and market implications on November 7, 2018 at 9:00 am ET (1-800-952-5114, conference code 3279053#) Source: BMO Transaction Database, Baker Hughes, BMO Commodity Products Group, Bloomberg, EIA, PLS Note: Current quarter’s data is through the week covered by this issue. 1. EIA U.S. natural gas gross withdrawals and production reported monthly as of August 2018. 2. S&P E&P = S&P Oil & Gas E&P Select Industry, SPX = S&P 500 Index. Key Industry Indicators Quarterly Deal Activity S&P E&P (2) underperformed last week 1.1% vs. SPX (2) 1.3% The major U.S. equity indexes finished slightly higher last week, with generally higher sector performance. Consumer discretionary, consumer staples, financials, health care, industrials, materials, and tech were all up. Real estate ended down 0.3% Equity Markets Oil ended last week down as sanctions on Iran are expected to start soon. Initial indications suggest that OPEC output in October reached the highest level since late 2016. Libya and Saudi Arabia showed the biggest gains month-over-month. Refineries returning to service should help alleviate pressure from an abundance of lighter barrels. WCS diffs were supported by BP’s announcement that BP Whiting work will finish in late November. The near-term contract closed down $3.64, or 5.4%, at $63.69 Natural gas ended last week up. Gas production and gas storage increased. Mid-day weather runs showed some impressive cold creeping into the longer term forecast. The near-term contract closed up $0.04, or 1.3%, at $3.24 Commodities Week in Review Covering the Week of October 26 to November 1, 2018
19
Embed
Prompt Oil Price ($/bbl) $63.69 ($3.64) (5.4%) Prompt Gas ... · 01-Nov-18 Undisclosed Buyer Parsley Energy LP Permian 11,850 net acres in Midland Basin $170 n.a. $141,667 $14,346
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2. Calculated as percentage of total LTM transaction count (number of transactions, not dollar value).
3. 59 transactions from January 2015 to 2018YTD with transaction value >$20mm. Adjusted for changes in price outlooks. Recalculated boe reserves are on a 15:1
(gas:oil) basis. Acreage transactions excluded by using deals with PDP of >= 40% of total proved.
Asset descriptions are all hard-coded and need to be
adjusted if new deals are added
(2) (2) (2)
Confirm number of transactions weekly --->
[TBU]
[TBU]
[TBU]
3
November 5, 2018
10/28/2018
Appalachia 2
Ark-La-Tex 6
Bakken 7
Eagle Ford 6
Mid-Con 8
Other 15
Permian 20
Rockies 10
74
Select Significant Deals on the Market
Disclaimer: The foregoing links are for convenience only and relate to materials that were not prepared or reviewed by BMO Capital Markets. BMO Capital Markets takes
no responsibility for and makes no representations with respect to the contents thereof. These materials may be inconsistent with the views of BMO Capital Markets.
Source of Select Significant Deals on the Market: BMO Transaction Database
Industry Headlines
Appalachia
2 Deals
Mid-Con
8 Deals
Eagle Ford
6 Deals
Permian
20 Deals
Other
15 Deals
Rockies
10 Deals
(Click headline to link to the full article)
A&D Headlines
Bakken
7 Deals
Ark-La-Tex
6 Deals
Upstream Uncertainty Tempers Otherwise Upbeat
Outlook
Rising U.S. Crude Output Sparks Race to Build Export
Terminals
China's Tariff on U.S. Natural Gas Delays Louisiana
LNG Project
Adams County Approves Moratorium on New Drilling
Permits Through End of November
Big Oil Outspends Billionaires in Washington State
Carbon Tax Fight
Encana Announces Strategic Combination with
Newfield Exploration Company; Intends to Raise
Dividend by 25 Percent and Expand its Share
Buyback Program to $1.5 Billion, Post Closing
Chesapeake Energy Corporation Accelerates
Strategic Plan with Acquisition of WildHorse Resource
Development Corporation For a Combination of
Chesapeake Common Stock and Cash
Denbury to Acquire Penn Virginia in $1.7 Billion
Transaction
Parsley Energy Announces Third Quarter 2018
Financial and Operating Results (includes A&D
announcement)
Pioneer Natural Resources Sells South Texas Assets
for $132 Million
Halcón Resources Announces the Sale of its
Delaware Basin Water Infrastructure Assets for $325
Encana will acquire Newfield for a total consideration
of $7.7 billion
Newfield shareholders will receive 2.6719 Encana
common shares for each share of Newfield
common stock
– Valued at approximately $5.5 billion
Encana will also assume $2.2 billion in net debt
Upon completion of the transaction, Encana
shareholders will own approximately 63.5% of the
combined company and Newfield shareholders will
own approximately 36.5%
The transaction is expected to close in Q1 2019
TRANSACTION SUMMARY
Source: Company press release, Company presentation, PLS, 1Derrick, Company teaser
1. Excludes China production.
2. Value adjusted by $35,000 per flowing boe/d.
ASSET SUMMARY
~874,000 total net acres across the Anadarko,
Williston, Uinta, and Arkoma basins
369,000 net acres in the Anadarko Basin
82,000 net acres in the Williston Basin
221,000 net acres in the Uinta Basin
144,000 net acres in the Arkoma Basin
~283,000 net acres in mineral interests and other
areas
Q3 2018 production of 199 mboe/d (61% liquids)(1)
2017 YE proved reserves of 678 mmboe
Q3 2018 LTM Adj. EBITDA of $1.4 billion
~6,000 gross risked locations with ~3 billion BOE of
net unrisked resources in Anadarko Basin
Interesting Deal of the Week #1:
Encana Corporation Acquires Newfield Exploration for $7.7 Billion
ACQUIRED ASSETS ACQUISITION METRICS
Purchase Price (US$ mm)
Cash $2,200
Stock $5,500
Total Consideration $7,700
Metrics
3Q 2018 Production (boe/d) 199,000
Proved Reserves (mboe) 678,000
Net Acres 874,000
3Q 2018 LTM Adj. EBITDA ($mm) $1,400
Multiples
TEV / 3Q 2018 Production ($/boe/d) $38,693
TEV / Proved Reserves ($/boe) $11.36
TEV / Net Acre $8,810
TEV / Adj. Net Acre(2) $841
TEV / 3Q 2018 LTM Adj. EBITDA 5.5x
Newfield Assets
5
November 5, 2018
On October 30, 2018, Chesapeake Resources
Corporation (NYSE: CHK) (“Chesapeake”) announced
that it entered into an agreement to buy WildHorse
Resource Development Corporation (NYSE: WRD)
(“WildHorse”) for a total consideration of $3,977 million
The transaction consideration consists of $930
million of assumed debt and the option to
exchange each WildHorse share for either:
– 5.989 Chesapeake shares
– 5.336 Chesapeake shares and $3.00 cash
The cash consideration is expected to be between
$275 million and $400 million
Upon closing of the transaction, Chesapeake
stockholders will own ~55% of the combined company
and WildHorse shareholders will own ~45%
The transaction is expected to close in Q1 2019
TRANSACTION SUMMARY
Source: Company press release, Company presentation, PLS, 1Derrick, Company teaser
1. Pro forma for sale of Louisiana assets.
2. Consideration consists of $930 million of assumed debt and the option of either 5.989 shares of CHK or 5.336 shares of CHK and $3.00 per share of WRD.
3. Value adjusted by $35,000 per flowing boe/d.
ASSET SUMMARY
420,000 net acres in the Eagle Ford
84% WI, 66% NRI
~80% undeveloped
2Q 2018 production of 47,000 boe/d
88% liquids / 73% oil
Proved reserves of 385.6 mmboe(1)
Proved PV-10 of $3,209 million(1)
3,207 net locations
Interesting Deal of the Week #2:
Chesapeake Resources Acquires WildHorse Resource Development for $4.0 Billion
ACQUIRED ASSETS
WildHorse
ACQUISITION METRICS
Purchase Price (US$ mm)
Assumed Debt(2) $930
Stock(2) $3,047
Total Consideration $3,977
Metrics
2Q 2018 Production (boe/d) 47,000
Proved Reserves (mboe) 385,640
Net Acres 420,000
Net Locations 3,207
Proved PV-10 ($mm) $3,209
Multiples
TEV / 2Q 2018 Production ($/boe/d) $84,617
TEV / Proved Reserves ($/boe) $10.31
TEV / Net Acre $9,469
TEV / Adj. Net Acre(3) $5,552
TEV / Net Location $1,240,100
TEV / Adj. Net Location(3) $727,159
TEV / Proved PV-10 1.24x
6
November 5, 2018
On October 28, 2018, Denbury Resources Inc.
(NYSE: DNR) (“Denbury”) announced that it entered
into an agreement to acquire Penn Virginia
Corporation (NASDAQ: PVAC) (“Penn Virginia”) for a
total consideration of $1,716 million
The transaction consideration consists of $400
million in cash, the assumption of $483 million in
debt, and approximately 191.6 million shares of
Denbury stock valued at $833 million (assuming
26-Oct-18 closing price of $4.35)
Upon closing of the transaction, Denbury stockholders
will own 71% of the combined company and Penn
Virginia shareholders will own 29%
The transaction is expected to close in Q1 2019
TRANSACTION SUMMARY
Source: Company press release, Company presentation, PLS, 1Derrick, Company teaser
1. As of 1Q earnings presentation at strip pricing.
2. Value adjusted by $35,000 per flowing boe/d.
ASSET SUMMARY
84,060 net (97,900 gross) acres in the Eagle Ford
Ongoing nearby EOR pilots
99% operated
93% HBP
2Q 2018 production of 22,000 boe/d
87% liquids / 74% oil
Proved reserves of 85 mmboe(1)
Proved PV-10 of $823 million(1)
461 net (560 gross) locations
Interesting Deal of the Week #3:
Denbury Resources Inc. Acquires Penn Virginia Corporation for $1.7 Billion
ACQUIRED ASSETS
Penn Virginia
ACQUISITION METRICS
Purchase Price (US$ mm)
Cash $883
Stock $833
Total Consideration $1,716
Metrics
2Q 2018 Production (boe/d) 22,000
Proved Reserves (mboe)(1) 85,000
Net Acres 84,060
Net Locations 461
Proved PV-10 ($mm)(1) $823
Multiples
TEV / 2Q 2018 Production ($/boe/d) $78,000
TEV / Proved Reserves ($/boe) $20.19
TEV / Net Acre $20,414
TEV / Adj. Net Acre(2) $11,254
TEV / Net Location $3,722,343
TEV / Adj. Net Location(2) $2,052,061
TEV / Proved PV-10 2.09x
7
November 5, 2018
Opportunity to acquire ~37,206 net contiguous acres in the core of
the San Andres horizontal play in Northern Central Basin Platform
Operated average WI/NRI of 77%/58%
Approaching 50% HBP with minimal annual drilling
commitments
96% operated by production
Net production of ~8,100 boe/d (November 2018E)
80% oil, 13% NGL
100%+ ROR oil play in the highly coveted Permian Basin
Future drilling opportunities have reserve models of 385 to
700 Mboe (80% oil)
Position has largely been de-risked through active development by
Wishbone and offset operators
Extensive inventory of high return drilling remains with over 344
San Andres horizontal drilling locations
5,000’ laterals – 323 locations
7,500’ laterals – 21 locations
Controlled surface lands/water infrastructure creates high margins
and empowers the buyer to be a play consolidator
WTS barrels and crude pipeline infrastructure in place with no
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 10-Jan-15. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, and $40,000/boepd in 2018.
[TBU]
[TBU]
[TBU] [TBU]
[TBU] [TBU]
[TBU]
11
November 5, 2018
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-15. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, and $40,000/boepd in 2018.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
12
November 5, 2018
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-15. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $3,000/mcfepd in 2014, and $2,000/mcfepd in 2015, 2016, 2017, and 2018.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
13
November 5, 2018
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-15. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $3,000/mcfepd in 2014, and $2,000/mcfepd in 2015, 2016, 2017, and 2018.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
14
November 5, 2018
-$1.00
-$0.50
$0.00
$0.50
Jan-15 Nov-15 Sep-16 Jul-17 May-18
-$20.00
-$10.00
$0.00
$10.00
$ /
mm
btu
$ /
bb
l
Clearbrook CIG
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-15. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, and $40,000/boepd in 2018.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
15
November 5, 2018
-$1.00
-$0.50
$0.00
$0.50
Jan-15 Nov-15 Sep-16 Jul-17 May-18
-$20.00
-$10.00
$0.00
$10.00
$ /
mm
btu
$ /
bb
l
Clearbrook CIG
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-15. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, and $40,000/boepd in 2018.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
16
November 5, 2018
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Rig Count 157 1 156 Oil Differential -- -- --
Permitting Activity 50 (17) 67 Gas Differential ($0.46) ($0.11) ($0.36)
Note: Current quarter’s data is through the week covered by this issue.
1. Represents total enterprise value. Excludes transactions with deal value <$20 million. 2. $/acre multiple not adjusted for value associated with production.
3. Red line denotes average since 01-Jan-15. Calculated as the weighted average of each quarter’s transactions.
4. Production valued at $45,000/boepd in 2014, $30,000/boepd in 2015, $35,000/boepd in 2016 & 2017, and $40,000/boepd in 2018.
TRANSACTION PRODUCTION MULTIPLES(3) TRANSACTION ADJUSTED NET ACRE MULTIPLES(3,4)
GROSS PRODUCTION
17
November 5, 2018
Item Value Wkly Change Last Week Item Value Wkly Change Last Week
Note: Current quarter’s data is through the week covered by this issue.
1. Permits include directional and unidentified drilling permits. 2. Represents total enterprise value. Excludes transactions with deal value <$20 million.
3. $/acre multiple not adjusted for value associated with production.
4. Red line denotes average since 01-Jan-15. Calculated as the weighted average of each quarter’s transactions.
GROSS PRODUCTION
TRANSACTION ACTIVITY (EXCLUDES CORPORATE DEALS)
TRANSACTION PRODUCTION MULTIPLES(4) TRANSACTION PROVED RESERVE MULTIPLES(4)
18
November 5, 2018
Upcoming Industry Events
Disclaimer: The foregoing links are for convenience only and relate to materials that were not prepared or reviewed by BMO Capital Markets. BMO Capital Markets takes
no responsibility for and makes no representations with respect to the contents thereof. These materials may be inconsistent with the views of BMO Capital Markets.
Click event to open
August 2018 Aug 19-22 Enercom Oil & Gas Conference
Aug 21 Houston Producers Forum Luncheon
September 2018 Sep 24-26 SPE Annual Technical Conference and Exhibition
November 2018 Nov 5-7 Executive Oil Conference
Nov 7-9 IADC Annual General Meeting
Nov 9 Rice Energy Finance Summit 2018
Nov 11-13 IPAA Annual Meeting
Nov 11-13 AICPA Oil & Gas Conference
Nov 13-15 DUG Midcontinent
Nov 14 IPAA Leaders in Industry Luncheon
Nov 16 ADAM-Houston Monthly Luncheon
Nov 28 Houston Producers Forum Luncheon
July 2019 Jul 16 Houston Producers Forum Luncheon
Jul 19 ADAM-Houston Monthly Luncheon
December 2018 Dec 3-5 Marcellus-Utica Midstream Conference & Exhibition
Dec 12 IPAA Leaders in Industry Luncheon
Dec 18 Houston Producers Forum Luncheon
Dec 21 ADAM-Houston Monthly Luncheon
January 2019 Jan 15 Houston Producers Forum Luncheon
Jan 18 ADAM-Houston Monthly Luncheon
Jan 24 IPAA Private Capital Conference
February 2019 Feb 5-7 SPE Hydraulic Fracturing Technology Conference
Feb 11-15 NAPE Summit Week
Feb 15 ADAM-Houston Monthly Luncheon
Feb 19 Houston Producers Forum Luncheon
Feb 19-20 DUG Haynesville
March 2019 Mar 5-7 IADC/SPE Drilling Conference
Mar 15 ADAM-Houston Monthly Luncheon
Mar 19 Houston Producers Forum Luncheon
Mar 26-28 International Petroleum Technology Conference
April 2019 Apr 8-10 IPAA Oil & Gas Investment Symposium
Apr 15-17 DUG Permian
Apr 16 Houston Producers Forum Luncheon
Apr 19 ADAM-Houston Monthly Luncheon
ADAM-Houston Monthly Luncheon – 3rd Friday
Houston Producers Forum Luncheon – 3rd Tuesday
2019
Nov 19 IPAA Oil & Gas for Newcomers
Nov 19-21 DUG Midcontinent
July 2018 Jul 23-25 SPE Unconventional Resources Technology
May 2019 May 6-9 Offshore Technology Conference
May 13-17 SPE Electric Submersible Pumps Symposium
May 14-15 DUG Rockies
May 14 Houston Producers Forum Luncheon
May 17 ADAM-Houston Monthly Luncheon
June 2019 Jun 5-6 Midstream Texas Conference & Exhibition
Jun 18 Houston Producers Forum Luncheon
Jun 18-20 DUG East
Jun 21 ADAM-Houston Monthly Luncheon
Jun 24-26 IPAA Midyear Meeting
August 2019 Aug 16 ADAM-Houston Monthly Luncheon
Aug 20 IPAA Oil & Gas Overview Course
Aug 20 Houston Producers Forum Luncheon
Aug 21-22 Summer NAPE
October 2018 Oct 22-23 Midstream Finance Conference
Oct 23-24 IADC International Well Control 2018 Conference
Oct 23-25 SPE Asia Pacific Oil & Gas Conference
Covering the Week of October 19 to October 25, 2018
September 2019 Sep 17 Houston Producers Forum Luncheon
Sep 20 ADAM-Houston Monthly Luncheon
Sep 24-26 DUG Eagle Ford
Sep 30-Oct 2 SPE Annual Technical Conference and Exhibition
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The opinions, estimates and projections contained in this report are those of BMO Capital Markets as of the date of this report and are subject to change without notice. BMO Capital
Markets endeavors to ensure that the contents have been compiled or derived from sources that we believe are reliable and contain information and opinions that are accurate and
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All values in this document are in US$ unless otherwise specified.
BMO uses updated basin outlines, and the resulting rig counts, to more accurately represent current basin knowledge. The data below reflect these changes
and is different than those shown by Baker Hughes. The totals are the same.