API Well Number: 43047541960000 API Well Number · 2020. 1. 21. · API Well Number : 43047541960000 & 2 1 ), ' ( 1 7 , / API Well Number: 43047541960000 Crescent Point Energy U.S.

RECEIVED: April 02, 2014

STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER

Deep Creek 2-22-4-2E

2. TYPE OF WORK

DRILL NEW WELL REENTER P&A WELL DEEPEN WELL 3. FIELD OR WILDCAT

UNDESIGNATED

4. TYPE OF WELLOil Well Coalbed Methane Well: NO

5. UNIT or COMMUNITIZATION AGREEMENT NAME

6. NAME OF OPERATORCRESCENT POINT ENERGY U.S. CORP

7. OPERATOR PHONE720 880-3621

8. ADDRESS OF OPERATOR555 17th Street, Suite 750, Denver, CO, 80202

9. OPERATOR [email protected]

10. MINERAL LEASE NUMBER(FEDERAL, INDIAN, OR STATE)

Fee

11. MINERAL OWNERSHIP

FEDERAL INDIAN STATE FEE 12. SURFACE OWNERSHIP

FEDERAL INDIAN STATE FEE

13. NAME OF SURFACE OWNER (if box 12 = 'fee')Lee Smith

14. SURFACE OWNER PHONE (if box 12 = 'fee')801-322-1235

15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee')2400 Sunnyside, Salt Lake City, UT 84108

16. SURFACE OWNER E-MAIL (if box 12 = 'fee')

17. INDIAN ALLOTTEE OR TRIBE NAME(if box 12 = 'INDIAN')

18. INTEND TO COMMINGLE PRODUCTION FROMMULTIPLE FORMATIONS

YES (Submit Commingling Application) NO

19. SLANT

VERTICAL DIRECTIONAL HORIZONTAL

20. LOCATION OF WELL FOOTAGES QTR-QTR SECTION TOWNSHIP RANGE MERIDIAN

LOCATION AT SURFACE 272 FNL 1968 FEL NWNE 22 4.0 S 2.0 E U

Top of Uppermost Producing Zone 272 FNL 1968 FEL NWNE 22 4.0 S 2.0 E U

At Total Depth 272 FNL 1968 FEL NWNE 22 4.0 S 2.0 E U

21. COUNTYUINTAH

22. DISTANCE TO NEAREST LEASE LINE (Feet)272

23. NUMBER OF ACRES IN DRILLING UNIT40

25. DISTANCE TO NEAREST WELL IN SAME POOL(Applied For Drilling or Completed)

920

26. PROPOSED DEPTHMD: 7335 TVD: 7335

27. ELEVATION - GROUND LEVEL

4974

28. BOND NUMBER

LPM9080271

29. SOURCE OF DRILLING WATER /WATER RIGHTS APPROVAL NUMBER IF APPLICABLE

437478

Hole, Casing, and Cement Information

String Hole Size Casing Size Length Weight Grade & Thread Max Mud Wt. Cement Sacks Yield Weight

COND 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0

Surf 12.25 8.625 0 - 1000 24.0 J-55 ST&C 8.3 Class G 641 1.15 15.8

Prod 7.875 5.5 0 - 7335 17.0 N-80 LT&C 10.0 Light (Hibond) 159 4.31 10.5

Class G 490 1.65 13.1

ATTACHMENTS

VERIFY THE FOLLOWING ARE ATTACHED IN ACCORDANCE WITH THE UTAH OIL AND GAS CONSERVATION GENERAL RULES

WELL PLAT OR MAP PREPARED BY LICENSED SURVEYOR OR ENGINEER COMPLETE DRILLING PLAN

AFFIDAVIT OF STATUS OF SURFACE OWNER AGREEMENT (IF FEE SURFACE) FORM 5. IF OPERATOR IS OTHER THAN THE LEASE OWNER

DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLY OR HORIZONTALLY DRILLED) TOPOGRAPHICAL MAP

NAME Emily Kate DeGrasse TITLE Regulatory & Government Affairs Analyst PHONE 720 880-3644

SIGNATURE DATE 11/08/2013 EMAIL [email protected]

API NUMBER ASSIGNED

43047541960000

Permit Manager

APPROVAL

FORM 3

AMENDED REPORT

API Well Number: 43047541960000

CONFIDE

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FORM 3STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME andDNeUeMpBCErReek2-22-4-2E

2. TYPE OF WORK 3. FIELD OR WILDCATDRILLNEWWELL REENTER P&AWELL DEEPEN WELLI UNDESIGNATED

4. TYPE OF WELL 5. UNIT or COMMUNITIZATION AGREEMENT NAMEOil Well Coalbed Methane Well: NO

6. NAME OF OPERATOR 7. OPERATOR PHONECRESCENT POINT ENERGY U.S. CORP 720 880-3621

8. ADDRESS OF OPERATOR 9. OPERATOR E-MAIL555 17th Street, Suite 750, Denver, CO, 80202 [email protected]

10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL,INDIAN,ORSTATEFee FEDERAL INDIANISTATE FEE FEDERAL INDIAN STATE FEEI

13. NAME OF SURFACE OWNER (if box 12 = 'fee') 14. SURFACE OWNER PHONE (if box 12 = 'fee')Lee Smith 801-322-1235

15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee') 16. SURFACE OWNER E-MAIL (if box 12 = 'fee')2400 Sunnyside, Salt Lake City, UT 84108

17. INDIAN ALLOTTEE OR TRIBE NAME 18. INTEND TO COMMINGLE PRODUCTION FROM 19. SLANT

(if box 12 = 'INDIAN')MULTIPLE FORMATIONS

YES (Submit Commingling Application) NO VERTICAL DIRECTIONAL HORIZONTAL


LOCATION ATSURFACE 272 FNL 1968 FEL NWNE 22 4.0 S 2.0 E U



21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITUINTAH 272 40

25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 7335 TVD: 7335

920

27. ELEVATION - GROUND LEVEL 28. BOND NUMBER 29. SOURCE OF DRILLING WATERIWATER RIGHTS APPROVAL NUMBER IF APPLICABLE

4974 LPM9080271 437478



COND 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0

Surf 12.25 8.625 0 - 1000 24.0 J-55ST&C 8.3 ClassG 641 1.15 15.8


Class G 490 1.65 13.1

ATTACHMENTS


WELL PLATOR MAP PREPARED BY LICENSED SURVEYOR OR ENGINEER COMPLETE DRILLING PLAN

AFFIDAVIT OF STATUS OF SURFACE OWNER AGREEMENT(IF FEE SURFACE) FORM 5. IF OPERATOR IS OTHER THAN THE LEASE OWNER

DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLYOR HORIZONTALLY DRILLED) TOPOGRAPHICAL MAP



API NUMBER ASSIGNED APPROVAL43047541960000

Permit Manager

RECEIVED: April 02,


FORM 3STATE OF UTAH



















920


4974 LPM9080271 437478



COND 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0

Surf 12.25 8.625 0 - 1000 24.0 J-55ST&C 8.3 ClassG 641 1.15 15.8


Class G 490 1.65 13.1

ATTACHMENTS








Permit Manager

RECEIVED: April 02,


FORM 3STATE OF UTAH



















920


4974 LPM9080271 437478



COND 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0

Surf 12.25 8.625 0 - 1000 24.0 J-55ST&C 8.3 ClassG 641 1.15 15.8


Class G 490 1.65 13.1

ATTACHMENTS








Permit Manager

RECEIVED: April 02,


FORM 3STATE OF UTAH



















920


4974 LPM9080271 437478



COND 24 16 0 - 40 65.0 H-40 ST&C 8.3 No Used 0 0.0 0.0

Surf 12.25 8.625 0 - 1000 24.0 J-55ST&C 8.3 ClassG 641 1.15 15.8


Class G 490 1.65 13.1

ATTACHMENTS








Permit Manager

RECEIVED: April 02,

RECEIVED: March 28, 2014

Crescent Point Energy | Deep Creek 2-22-4-2E | Drilling Plan 1

Crescent Point Energy U.S. Corp Deep Creek 2-22-4-2E NW/NE of Section 22, T4S, R2E, USB&M SHL: 272’ FNL & 1968’ FEL Uintah County, Utah

DRILLING PLAN

1-2. Geologic Surface Formation and Estimated Tops of Important Geologic Markers

Formation Depth – TVD/MD

Uinta Surface

Upper Green River Marker 3,298’

Mahogany 3,771’

Garden Gulch (TGR3) 4,792’

Douglas Creek 5,542’

Black Shale 6,043’

Castle Peak 6,299’

Uteland 6,586’

Wasatch 6,735’

TD 7,335’

3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals Green River Formation (Oil) 3,298’ – 6,735’ Wasatch Formation (Oil) 6,735’ – 7,335’ Fresh water may be encountered in the Uinta Formation, but would not be expected below 350’. All

usable (>10,000 PPM TDS) water and prospectively valuable minerals (as described by DOGM at onsite) encountered during drilling will be recorded by depth and adequately protected.

All water shows and water bearing geologic units will be reported to the geologic and engineering staff of the DOGM prior to running the next string of casing or before plugging orders are requested. Usage of the State of Utah form Report of Water Encountered is acceptable, but not required. All water shows must be reported within one (1) business day after being encountered. Detected water flows shall be sampled, analyzed, and reported to the geologic and engineering staff at the DOGM. The DOGM may request additional water samples for further analysis. The following information is requested for water shows and samples where applicable: Location & Sample Interval Date Sampled Flow Rate Temperature Hardness pH Water Classification (State of Utah) Dissolved Calcium (Ca) (mg/l) Dissolved Iron (Fe) (ug/l) Dissolved Sodium (Na) (mg/l) Dissolved Magnesium (Mg) (mg/l) Dissolved Carbonate (CO3) (mg/l) Dissolved Bicarbonate (NaHCO3) (mg/l) Dissolved Chloride (Cl) (mg/l) Dissolved Sulfate (SO4) (mg/l) Dissolved Total Solids (TDS) (mg/l)


CONFIDE

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Crescent Point Energy U.S. CorpDeep Creek 2-22-4-2ENW/NE of Section 22, T4S, R2E, USB&MSHL:272' FNL& 1968' FELUintah County, Utah

DRILLINGPLAN


Formation Depth -TVD/MDUinta Surface

Upper Green River Marker 3,298'

Mahogany 3,771'

Garden Gulch (TGR3) 4,792'

Douglas Creek 5,542'

Black Shale 6,043'

Castle Peak 6,299'

Uteland 6,586'

Wasatch 6,735'

TD 7,335'

3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals

Green River Formation (Oil) 3,298'-6,735'Wasatch Formation (Oil) 6,735'-7,335'

Fresh water may be encountered in the Uinta Formation, but would not be expected below 350'. Allusable (>10,000PPM TDS) water and prospectively valuable minerals (as described by DOGM at onsite)encountered during drilling will be recorded by depth and adequately protected.

All water shows and water bearing geologic units will be reported to the geologic and engineering staff ofthe DOGM prior to running the next string of casing or before plugging orders are requested. Usage ofthe State of Utah form Report of Water Encountered is acceptable, but not required. Allwater showsmust be reported within one (1) business day after being encountered. Detected water flows shall besampled, analyzed, and reported to the geologic and engineering staff at the DOGM. The DOGM mayrequest additional water samples for further analysis.

The following information is requested for water shows and samples where applicable:

Location & Sample Interval Date SampledFlow Rate TemperatureHardness pHWater Classification (State of Utah) Dissolved Calcium (Ca) (mg/l)Dissolved Iron (Fe) (ug/l) Dissolved Sodium (Na) (mg/l)Dissolved Magnesium (Mg) (mg/l) Dissolved Carbonate (CO3)(mg/l)Dissolved Bicarbonate (NaHCOs) (mg/l) Dissolved Chloride (CI)(mg/l)Dissolved Sulfate (SO4) (mg/l) Dissolved Total Solids (TDS)(mg/l)

Crescent Point Energy | Deep Creek 2-22-4-2E | Drilling Plan

RECEIVED: March 28,


Crescent Point Energy U.S. CorpDeep Creek 2-22-4-2E

NW/NE of Section 22, T4S, R2E, USB&MSHL: 272' FNL & 1968' FELUintah County, Utah

DRILLINGPLAN


Formation Depth - TVD/MDUinta Surface


Mahogany 3,771'



Black Shale 6,043'

Castle Peak 6,299'

Uteland 6,586'

Wasatch 6,735'

TD 7,335'



Fresh water may be encountered in the Uinta Formation, but would not be expected below 350'. Allusable (>10,000PPM TDS)water and prospectively valuable minerals (as described by DOGM at onsite)encountered during drilling will be recorded by depth and adequately protected.

Allwater shows and water bearing geologic units will be reported to the geologic and engineering staff ofthe DOGM prior to running the next string of casing or before plugging orders are requested. Usage ofthe State of Utah form Report of Water Encountered is acceptable, but not required. All water showsmust be reported within one (1) business day after being encountered. Detected water flows shall besampled, analyzed, and reported to the geologic and engineering staff at the DOGM. The DOGM mayrequest additional water samples for further analysis.


Location & Sample Interval Date SampledFlow Rate TemperatureHardness pHWater Classification (State of Utah) Dissolved Calcium (Ca) (mg/l)Dissolved Iron (Fe) (ug/l) Dissolved Sodium (Na) (mg/l)Dissolved Magnesium (Mg) (mg/l) Dissolved Carbonate (COs) (mg/l)Dissolved Bicarbonate (NaHCOs) (mg/l) Dissolved Chloride (CI) (mg/l)Dissolved Sulfate (SO4)(mg/l) Dissolved Total Solids (TDS)(mg/l)


RECEIVED: March 28,




DRILLINGPLAN




Mahogany 3,771'



Black Shale 6,043'

Castle Peak 6,299'

Uteland 6,586'

Wasatch 6,735'

TD 7,335'








RECEIVED: March 28,




DRILLINGPLAN




Mahogany 3,771'



Black Shale 6,043'

Castle Peak 6,299'

Uteland 6,586'

Wasatch 6,735'

TD 7,335'








RECEIVED: March 28,



4. Proposed Casing & Cementing Program Casing Design:

Size Interval

Weight Grade Coupling Design Factors

Top Bottom Burst Collapse Tension

Conductor

0' 40' 65 H-40 STC

16" 1,640 670 439 API

Hole Size 24"

Surface casing

0' 1000' 24 J-55 STC

2,950 1,370 244,000 API

8-5/8" 405 696 24,000 Load

Hole Size 12-1/4" 7.27 1.97 10.17 SF

Prod casing

0' 7,335’ 17 E-80 LTC

7,740 6,290 348,000 API

5-1/2" 6,200 3,700 124,000 Load

Hole Size 7-7/8" 1.25 1.70 2.80 SF

Assumptions: 1. Surface casing max anticipated surface pressure (MASP) = Frac gradient – gas gradient 2. Production casing MASP (production mode) = Pore pressure – gas gradient 3. All collapse calculations assume fully evacuated casing w/gas gradient 4. All tension calculations assume air weight

Frac gradient at surface casing shoe = 10.0 ppg Pore pressure at surface casing shoe = 8.33 ppg Pore pressure at prod casing shoe = 8.33 ppg Gas gradient = 0.115 psi/ft

Minimum Safety Factors: Burst = 1.000 Collapse = 1.125 Tension = 1.800

All casing shall be new or, if used, inspected and tested. Used casing shall meet or exceed API standards for new casing.

All casing strings shall have a minimum of one (1) centralizer per joint on the bottom three joints.


CONFIDE

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4. Proposed Casing & Cementing Program

Casing Design:

Interval Design FactorsSize Weight Grade Coupling


Conductor16" O' 40' 65 H-40 STC 1,640 670 439 APIHole Size 24"Surface casing 2,950 1,370 244,000 API8-5/8" O' 1000' 24 J-55 STC 405 696 24,000 Load

Hole Size 12-1/4" 7.27 1.97 10.17 SF

Prod casing 7,740 6,290 348,000 API5-1/2" 0' 7,335' 17 E-80 LTC 6,200 3,700 124,000 LoadHole Size 7-7/8" 1.25 1.70 2.80 SF

Assumptions:1. Surface casing max anticipated surface pressure (MASP) = Frac gradient -gas gradient2. Production casing MASP (production mode) = Pore pressure -gas gradient3. All collapse calculations assume fully evacuated casing w/gas gradient4. All tension calculations assume air weight

Frac gradient at surface casing shoe = 10.0 ppgPore pressure at surface casing shoe = 8.33 ppgPore pressure at prod casing shoe = 8.33 ppgGas gradient = 0.115 psi/ft

Minimum Safety Factors:Burst = 1.000Collapse = 1.125Tension = 1.800

All casing shall be new or, if used, inspected and tested. Used casing shall meet or exceed API standardsfor new casing.



RECEIVED: March 28,



Casing Design:



Conductor16" 0' 40' 65 H-40 STC 1,640 670 439 APIHole Size 24"Surface casing 2,950 1,370 244,000 API8-5/8" 0' 1000' 24 J-55 STC 405 696 24,000 LoadHole Size 12-1/4" 7.27 1.97 10.17 SFProd casing 7,740 6,290 348,000 API5-1/2" 0' 7,335' 17 E-80 LTC 6,200 3,700 124,000 LoadHole Size 7-7/8" 1.25 1.70 2.80 SF







RECEIVED: March 28,



Casing Design:










RECEIVED: March 28,



Casing Design:










RECEIVED: March 28,



Cementing Design:

Job Fill Description Excess Sacks Weight Yield

(ppg) (ft3/sk)

Surface casing

1000' - surface Class V 2% chlorides 75% 641 15.8 1.15

Prod casing Lead

3290' to Surface

Hifill Class V 3% chlorides 25% in open-hole, 0% in cased hole

159 10.5 4.31

Prod casing Tail

TD to 3290’ Class G 10% chlorides 15% 490 13.1 1.65

*Actual volume pumped will have excess over gauge hole or caliper log if available - Compressive strength of tail cement: 500 psi @ 7 hours Waiting On Cement: A minimum of four (4) hours shall elapse prior to attempting any pressure testing of the BOP equipment which would subject the surface casing cement to pressure, and a minimum of six (6) hours shall elapse before drilling out of the wiper plug, cement, or shoe. WOC time shall be recorded in the Driller’s Log. Compressive strength shall be a minimum of 500 psi prior to drilling out.

The DOGM Roosevelt Field Office shall be notified, with sufficient lead time, in order to have a DOGM representative on location while running all casing strings and cementing.

The 8-5/8” surface casing shall in all cases be cemented back to surface. In the event that during the primary surface cementing operation the cement does not circulate to surface, or if the cement level should fall back more than 8 feet from surface, then a remedial surface cementing operation shall be performed to insure adequate isolation and stabilization of the surface casing.

The production casing cementing program shall be conducted as approved to protect and/or isolate all usable water zones, potentially productive zones, lost circulation zones, abnormally pressured zones, and any prospectively valuable deposits of minerals.

As a minimum, usable water zones shall be isolated and/or protected by having a cement top for the production casing at least 200 feet above the base of the usable water. If gilsonite is encountered while drilling, it shall be isolated and/or protected via the cementing program.

Top plugs shall be used to reduce contamination of cement by displacement fluid. A Tuned spacer will be used to prevent contamination of the lead cement by the drilling mud.

All casing strings below the conductor shall be pressure tested to 0.22 psi per foot of casing string length or to 1500 psi, whichever is greater, but not to exceed 70% of the minimum internal yield. If pressure declines more than 10% in 30 minutes, corrective action shall be taken.

A Form 9, “Sundry Notices and Reports on Wells” shall be filed with the DOGM within 30 days after the work is completed. This report must include the following information:

Setting of each string of casing showing the size, grade, weight of casing set, depth, amounts and type of cement used, whether cement circulated of the top of the cement behind the casing,


CONFIDE

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Cementing Design:

Weight YieldJob Fill Description Excess Sacks

(ppg)(ft3/Sk)

Surface1000' - surface Class V 2% chlorides 75% 641 15.8 1.15

casing25% in open-

Prod casing 3290' toHifillClass V 3% chlorides hole, 0% in 159 10.5 4.31

Lead Surfacecased hole

Prod casingTD to 3290' Class G 10% chlorides 15% 490 13.1 1.65

Tail

*Actual volume pumped will have excess over gauge hole or caliper log if available- Compressive strength of tail cement: 500 psi @ 7 hoursWaiting On Cement: A minimum of four (4) hours shall elapse prior to attempting any pressure testing ofthe BOP equipment which would subject the surface casing cement to pressure, and a minimum of six (6)hours shall elapse before drilling out of the wiper plug, cement, or shoe. WOC time shall be recorded inthe Driller's Log. Compressive strength shall be a minimum of 500 psi prior to drilling out.

The DOGM Roosevelt Field Office shall be notified, with sufficient lead time, in order to have a DOGMrepresentative on location while running all casing strings and cementing.

The 8-5/8" surface casing shall in all cases be cemented back to surface. In the event that during theprimary surface cementing operation the cement does not circulate to surface, or if the cement levelshould fall back more than 8 feet from surface, then a remedial surface cementing operation shall beperformed to insure adequate isolation and stabilization of the surface casing.

The production casing cementing program shall be conducted as approved to protect and/or isolate allusable water zones, potentially productive zones, lost circulation zones, abnormally pressured zones, andany prospectively valuable deposits of minerals.

As a minimum, usable water zones shall be isolated and/or protected by having a cement top for theproduction casing at least 200 feet above the base of the usable water. If gilsonite is encountered whiledrilling, it shall be isolated and/or protected via the cementing program.

Top plugs shall be used to reduce contamination of cement by displacement fluid. A Tuned spacer will beused to prevent contamination of the lead cement by the drilling mud.

All casing strings below the conductor shall be pressure tested to 0.22 psi per foot of casing string lengthor to 1500 psi, whichever is greater, but not to exceed 70% of the minimum internal yield. If pressuredeclines more than 10% in 30 minutes, corrective action shall be taken.

A Form 9, "Sundry Notices and Reports on Wells" shall be filed with the DOGM within 30 days after thework is completed. This report must include the following information:

Setting of each string of casing showing the size, grade, weight of casing set, depth, amounts andtype of cement used, whether cement circulated of the top of the cement behind the casing,


RECEIVED: March 28,


Cementing Design:


(ppg) (ft'/sk)


casing25% in open-




Tail

*Actual volume pumped will have excess over gauge hole or caliper log if available- Compressive strength of tail cement: 500 psi @7 hoursWaiting On Cement: A minimum of four (4) hours shall elapse prior to attempting any pressure testing ofthe BOP equipment which would subject the surface casing cement to pressure, and a minimum of six (6)hours shall elapse before drilling out of the wiper plug, cement, or shoe. WOC time shall be recorded inthe Driller's Log. Compressive strength shall be a minimum of 500 psi prior to drilling out.










RECEIVED: March 28,


Cementing Design:


(ppg) (ft'/sk)


casing25% in open-




Tail











RECEIVED: March 28,


Cementing Design:


(ppg) (ft'/sk)


casing25% in open-




Tail











RECEIVED: March 28,



depth of the cementing tools used, casing method and results, and the date of the work done. Spud date will be shown on the first reports submitted.

5. Drilling Fluids Program

The Conductor section (from 0’ to 40’) will be drilled by Auger and final depth determined by when the black shale is encountered with a minimum depth of 40’. The surface interval will then be drilled to ±1000’ with air/mist system. The air rig is equipped with a 6 ½” blooie line that is straight run to the reserve pit. A variance is in request for this operation. The request can be found in Section 12 of this plan. From ±1000’ to TD, a brine water system will be utilized. Clay inhibition and hole stability will be achieved with a polymer (DAP) additive; the reserve pit will be lined to address this additive. This brine water system will typically contain Total Dissolved Solids (TDS) of less than 3000 PPM. Anticipated mud weight is 9.5 lbs/gal. If it is necessary to control formation fluids or pressure, the system will be weighted with the addition of brine, and if pressure conditions warrant, barite and/or calcium carbonate will be used as a weighting agent. There will be enough weighting agent on location to increase the entire system to 11.0 ppg MW. No chromate additives will be used in the mud system on Federal and/or Indian lands without prior DOGM approval to ensure adequate protection of fresh water aquifers. No chemicals subject to reporting under SARA Title III in an amount equal to or greater than 10,000 pounds will be used, produced, stored, transported, or disposed of annually in association with the drilling, testing, or completing of this well. Furthermore, no extremely hazardous substances, as defined in 40 CFR 355, in threshold planning quantities, will be used, produced, stored, transported, or disposed of in association with the drilling, testing, or completing of this well. Hazardous substances specifically listed by the EPA as a hazardous waste or demonstrating characteristics of a hazardous waste will not be used in drilling, testing, or completion operations. Crescent Point Energy will visually monitor pit levels and flow from the well during drilling operations.

6. Minimum Specifications for Pressure Control A 3,000 psi BOP system or better will be used on this well. All equipment will be installed and tested per Onshore Order No. 2.

The configuration is as follows:

Float in drillstring

Inside BOP or safety valve

Safety valve with same pipe threading

Rotating Head below rotary table

Fillup line

11” Annular Preventer – rated to 3,000 psi minimum

11” bore, 4-1/2” pipe ram – rated to 3,000 psi minimum

11” bore, Blind Ram – rated to 3,000 psi minimum

11” bore Drilling Spool with 2 side outlets (Choke side at 3” minimum & Kill side at 2” minimum) o 2 Kill line valves at 2” minimum – one with a check valve o Kill line at 2” minimum


CONFIDE

NTIAL


depth of the cementing tools used, casing method and results, and the date of the work done.Spud date will be shown on the first reports submitted.


The Conductor section (from O' to 40') will be drilled by Auger and final depth determined by when theblack shale is encountered with a minimum depth of 40'.

The surface interval will then be drilled to ±1000' with air/mist system. The air rig is equipped with a 6 ½"blooie line that is straight run to the reserve pit. A variance is in request for this operation. The requestcan be found in Section 12 of this plan.

From ±1000' to TD, a brine water system will be utilized. Clay inhibition and hole stability will be achievedwith a polymer (DAP) additive; the reserve pit will be lined to address this additive. This brine watersystem will typically contain Total Dissolved Solids (TDS)of less than 3000 PPM. Anticipated mud weightis 9.5 lbs/gal. If it is necessary to control formation fluids or pressure, the system will be weighted withthe addition of brine, and if pressure conditions warrant, barite and/or calcium carbonate will be used asa weighting agent. There will be enough weighting agent on location to increase the entire system to 11.0ppg MW.

No chromate additives will be used in the mud system on Federal and/or Indian lands without priorDOGM approval to ensure adequate protection of fresh water aquifers.

No chemicals subject to reporting under SARA Title Ill in an amount equal to or greater than 10,000pounds will be used, produced, stored, transported, or disposed of annually in association with thedrilling, testing, or completing of this well. Furthermore, no extremely hazardous substances, as definedin 40 CFR355, in threshold planning quantities, will be used, produced, stored, transported, or disposedof in association with the drilling, testing, or completing of this well.

Hazardous substances specifically listed by the EPA as a hazardous waste or demonstrating characteristicsof a hazardous waste will not be used in drilling, testing, or completion operations.

Crescent Point Energy will visually monitor pit levels and flow from the well during drilling operations.

6. Minimum Specifications for Pressure Control

A 3,000 psi BOP system or better will be used on this well. All equipment will be installed and tested perOnshore Order No. 2.


• Float in drillstring• Inside BOP or safety valve• Safety valve with same pipe threading• Rotating Head below rotary table• Fillup line• 11" Annular Preventer - rated to 3,000 psi minimum• 11" bore, 4-1/2" pipe ram - rated to 3,000 psi minimum• 11" bore, Blind Ram - rated to 3,000 psi minimum• 11" bore Drilling Spool with 2 side outlets (Choke side at 3" minimum & Kill side at 2" minimum)

o 2 Kill line valves at 2" minimum -one with a check valveo Kill line at 2" minimum


RECEIVED: March 28,








No chemicals subject to reporting under SARATitle Ill in an amount equal to or greater than 10,000pounds will be used, produced, stored, transported, or disposed of annually in association with thedrilling, testing, or completing of this well. Furthermore, no extremely hazardous substances, as definedin 40 CFR355, in threshold planning quantities, will be used, produced, stored, transported, or disposedof in association with the drilling, testing, or completing of this well.

Hazardous substances specifically listed by the EPAas a hazardous waste or demonstrating characteristicsof a hazardous waste will not be used in drilling, testing, or completion operations.





• Float in drillstring• Inside BOP or safety valve• Safety valve with same pipe threading• Rotating Head below rotary table• Fillup line• 11" Annular Preventer - rated to 3,000 psi minimum• 11" bore, 4-1/2" pipe ram - rated to 3,000 psi minimum• 11" bore, Blind Ram - rated to 3,000 psi minimum• 11" bore Drilling Spool with 2 side outlets (Choke side at 3" minimum & Killside at 2" minimum)

o 2 Killline valves at 2" minimum-one with a check valveo Killline at 2" minimum


RECEIVED: March 28,

















RECEIVED: March 28,

















RECEIVED: March 28,



o 2 Choke line valves at 3” minimum o Choke line at 3” minimum o 2 adjustable chokes on manifold o Pressure gauge on choke manifold

7. BOPE Test Criteria

A Function Test of the Ram BOP equipment shall be made every trip and annular preventer every week. All required BOP tests and/or drills shall be recorded in the Driller’s Report. Chart recorders will be used for all pressure tests. Test charts, with individual test results identified, shall be maintained on location while drilling and shall be made available to DOGM representatives upon request. At a minimum, the Annular preventer will be tested to 50% of its rating for ten minutes. All other equipment (Rams, valves, manifold) will be tested at 3,000 psi for 10 minutes with a test plug. If rams are to be changed for any reason post drillout, the rams will be tested to 70% of surface casing internal yield. At a minimum, the above pressure tests will be performed when such conditions exist:

BOP’s are initially installed

Whenever a seal subject to pressure test is broken

Following repairs to the BOPs

Every 30 days 8. Accumulator The Accumulator will have sufficient capacity to open the hydraulically-controlled choke line valve (HCR), close both rams and annular preventer as well maintain 200 psi above nitrogen precharge of the accumulator without use of accumulator pumps. The fluid reservoir volume will be double the usable volume of the accumulator system. The fluid level will be maintained per manufacturer’s specifications.

The BOP system will have two independent power sources to close both rams and annular preventer, while opening HCR. Nitrogen bottles will be one source and electric and/or air powered pumps will be the other. The accumulator precharge will be conducted every 6 months and maintained to be within the specifications of Onshore Order No. 2 A manual locking device or automatic locking device will be installed on both ram preventers and annular preventer. Remote controls will be readily accessible to the driller and be capable of closing all preventers. Main controls will be available to allow full functioning of all preventers and HCR.

9. Testing, Logging and Coring Programs

The logging program will consist of a Gamma Ray log from TD to base of surface casing @ +/- 1100’. A cement bond log will be run from PBTD to top of cement. No drill stem testing or coring is planned for this well.


CONFIDE

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o 2 Choke line valves at 3" minimumo Choke line at 3" minimumo 2 adjustable chokes on manifoldo Pressure gauge on choke manifold

7. BOPETest Criteria

A Function Test of the Ram BOP equipment shall be made every trip and annular preventer every week.All required BOP tests and/or drills shall be recorded in the Driller's Report.

Chart recorders will be used for all pressure tests. Test charts, with individual test results identified, shallbe maintained on location while drilling and shall be made available to DOGM representatives uponrequest.

At a minimum, the Annular preventer will be tested to 50% of its rating for ten minutes. All otherequipment (Rams, valves, manifold) will be tested at 3,000 psi for 10 minutes with a test plug. If rams areto be changed for any reason post drillout, the rams will be tested to 70% of surface casing internal yield.

At a minimum, the above pressure tests will be performed when such conditions exist:• BOP's are initially installed• Whenever a seal subject to pressure test is broken• Following repairs to the BOPs• Every 30 days

8. Accumulator

The Accumulator will have sufficient capacity to open the hydraulically-controlled choke line valve (HCR),close both rams and annular preventer as well maintain 200 psi above nitrogen precharge of theaccumulator without use of accumulator pumps. The fluid reservoir volume will be double the usablevolume of the accumulator system. The fluid level will be maintained per manufacturer's specifications.

The BOP system will have two independent power sources to close both rams and annular preventer,while opening HCR. Nitrogen bottles will be one source and electric and/or air powered pumps will be theother.

The accumulator precharge will be conducted every 6 months and maintained to be within thespecifications of Onshore Order No. 2

A manual locking device or automatic locking device will be installed on both ram preventers and annularpreventer.

Remote controls will be readily accessible to the driller and be capable of closing all preventers. Maincontrols will be available to allow full functioning of all preventers and HCR.


The logging program will consist of a Gamma Ray log from TD to base of surface casing @ +/-1100'. Acement bond log will be run from PBTD to top of cement. No drill stem testing or coring is planned forthis well.


RECEIVED: March 28,








8. Accumulator


The BOP system will have two independent power sources to close both rams and annular preventer,while opening HCR.Nitrogen bottles will be one source and electric and/or air powered pumps will be theother.





The logging program will consist of a Gamma Ray log from TD to base of surface casing @+/- 1100'. Acement bond log will be run from PBTDto top of cement. No drill stem testing or coring is planned forthis well.


RECEIVED: March 28,








8. Accumulator









RECEIVED: March 28,








8. Accumulator









RECEIVED: March 28,



10. Anticipated Abnormal Pressures or Temperature

No abnormal temperatures or pressures are anticipated. No hydrogen sulfide has been encountered or is known to exist from previous wells drilled to similar depths in this area.

Maximum anticipated bottomhole pressure will be approximately equal to total depth in feet multiplied by a 0.52 psi/ft gradient, and a maximum anticipated surface pressure will be approximately equal to the bottomhole pressure calculated minus the pressure of a partially evacuated hole calculated at a 0.22 psi/foot gradient.

11. Anticipated Starting Date and Duration of Operations

It is anticipated that drilling operations will commence in September 2014, and take approximately seven (7) days from spud to rig release and two weeks for completions.

12. Variances Requested from Onshore Order No. 2

1. A diverter is utilized for surface air drilling, rather than a lubricated rotating head. 2. The blooie line is 45 ft from the wellbore rather than 100 ft and is not anchored down. 3. The blooie line is not equipped with an automatic igniter or continuous pilot light. 4. The compressor is located on the rig itself and not 100 ft from the wellbore. 5. The requirement for an Formation Integrity Test (FIT) or a Leak Off Test (LOT)


CONFIDE

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No abnormal temperatures or pressures are anticipated. No hydrogen sulfide has been encountered or isknown to exist from previous wells drilled to similar depths in this area.

Maximum anticipated bottomhole pressure will be approximately equal to total depth in feet multipliedby a 0.52 psi/ft gradient, and a maximum anticipated surface pressure will be approximately equal to thebottomhole pressure calculated minus the pressure of a partially evacuated hole calculated at a 0.22psi/foot gradient.


It is anticipated that drilling operations will commence in September 2014, and take approximately seven(7) days from spud to rig release and two weeks for completions.


1. A diverter is utilized for surface air drilling, rather than a lubricated rotating head.2. The blooie line is 45 ft from the wellbore rather than 100 ft and is not anchored down.3. The blooie line is not equipped with an automatic igniter or continuous pilot light.4. The compressor is located on the rig itself and not 100 ft from the wellbore.5. The requirement for an Formation Integrity Test (FIT) or a Leak Off Test (LOT)


RECEIVED: March 28,








1. A diverter is utilized for surface air drilling, rather than a lubricated rotating head.2. The blooie line is 45 ft from the wellbore rather than 100 ft and is not anchored down.3. The blooie line is not equipped with an automatic igniter or continuous pilot light.4. The compressor is located on the rig itself and not 100 ft from the wellbore.5. The requirement for an Formation Integrity Test (FIT)or a Leak Off Test (LOT)


RECEIVED: March 28,










RECEIVED: March 28,










RECEIVED: March 28,

RECEIVED: November 08, 2013


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R. 2 E. NSTN NSB'49'41"E 2639.34' S S89'35'53"W 2691.27' AC

.

(1345.64') (1345.64')

1966'

DEEP CREEK2-22-4-2E

UNGRADEDELEVATION: SCALE 1" = 1000'GRID NORTH4974.6' - -

BASIS OF ELEVATION: USGS SPOTELEVATIONLOCATED AT THE NWCORNER SECTION 23. T4S, R2E, IELEVATION: 4969' LAT/TUDE(NAD 83)

NORTH 40.128652 DEG.LONGITUDE (NAD 83)

STN --- - -- --- - - - AC WEST 109.751549 DEG.

LATITUDE (NAD 27)NORTH 40.128689 DEG.LONGITUDE (NAD 27)

io WEST 109.750852 DEG,

NORTHING658702.53EASTING

2489063.93L

P DATUMz SPCS UTC (NAD 27)

AC NSB'59'19"E 2639.91' AC N88 58'37"E 2639.61' AC

1000 500 0 1000 2000

SURVEYOR'SSTATEMENT SCALE FEET

I, DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO, HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURlNG AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON THE 13th DAY OF AUGUST,2013 AND THAT THIS PLAT CORRECTLY SHOWS THE LOCATIONOF DEEP CREEK 2-22-4-2E AS 5TAKED ON THEGROUND.

LEGEND À 2 oo 826260e WELL LOCATioN

O BOTTOM HOLE LOC. (APPROX)

O FOUND MONUMENT UTAH P '03-2201& PREVIOUSLY FOUND MONUMENT

PIAT OF DRH2LWG LOCATIONWRIFFIN & ASSOCIATES, INC. NWNE, SECTION 22, FOR

taanser-sorg 1414 ELK ST., ROCKSPRINGS, WY82001 CRESCENT PORT ENERGYORAPVN:9/1&f3- DEH SCALE: 1"= 1000' 272'F/NL, &1968'F/EL, SECTION 22,

REVISED:N/A-. DRG JOBNo.20025 T.4S., R. 2E., U.S.M.,E¥HIBIT1-1 MAH COUNTY,



.

(1345.64') (1345.64')

1966'

DEEP CREEK2-22-4-2E




STN --- - -- --- - - - AC WEST 109.751549 DEG.


io WEST 109.750852 DEG,


2489063.93L


AC NSB'59'19"E 2639.91' AC N88 58'37"E 2639.61' AC

1000 500 0 1000 2000











.

(1345.64') (1345.64')

1966'

DEEP CREEK2-22-4-2E




STN --- - -- --- - - - AC WEST 109.751549 DEG.


io WEST 109.750852 DEG,


2489063.93L


AC NSB'59'19"E 2639.91' AC N88 58'37"E 2639.61' AC

1000 500 0 1000 2000











.

(1345.64') (1345.64')

1966'

DEEP CREEK2-22-4-2E




STN --- - -- --- - - - AC WEST 109.751549 DEG.


io WEST 109.750852 DEG,


2489063.93L


AC NSB'59'19"E 2639.91' AC N88 58'37"E 2639.61' AC

1000 500 0 1000 2000











CONFIDE

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API Well Number: 43047541960000nauwen

CorralRANDLETT

PEL1CIN LAKE

31

6

PROPOSED ACCESS FOR&ASSOCIATES, INC. CRESCENT POINT ENERGY

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, WY82901 DEEP CREEK 2-22-4-2EDRAWN:8/26/2013-TCM SCALE:1"=1MILE SECTION 22, T.4 S., R.2 E.

REVISED: N/A -

. DRG JOB No. 20025

TOPO A - 1 OF2 PROPOSED ROAD- - - - EXISTING ROAD

RECEIVED: November 08,


CorralRANDLETT

PEL1CIN LAKE

31

6



REVISED: N/A -

. DRG JOB No. 20025




CorralRANDLETT

PEL1CIN LAKE

31

6



REVISED: N/A -

. DRG JOB No. 20025




CorralRANDLETT

PEL1CIN LAKE

31

6



REVISED: N/A -

. DRG JOB No. 20025





CONFIDE

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DL E

2 ST3S

6



REVISED: N/A -

. DRG JOB No. 20025

. TOPO A - 2 OF2 PROPOSED ROAD- - - - EXISTING ROAD



DL E

2 ST3S

6



REVISED: N/A -

. DRG JOB No. 20025




DL E

2 ST3S

6



REVISED: N/A -

. DRG JOB No. 20025





CONFIDE

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-LMS---tWB ÌRI162 -2E #1-16-4-2 -15-4-2E #3-15-4-2E

-15-4 E O 2000

1 E- -2E #6- 5 ¯ 7 2

1

2

-ElD4EE15

DEEP CREEKese c 2-22-4-2E

3-22-4-2E# 22

¯

EE

DEEP CREEKESTMENTS E A

262.1'±

15-22-

QUIDRANGLERANDLETT .

PELICAV LAKEOURAY

UTEL4ND BUTTE APPROX. ROAD DISTURBANCE: 0.3± ACRES

PROPOSED ROAD FOR& ASSOCIATES, INC. CRESCENT POINT ENERGY

(son 362-502¿ 1414 ELK ST., ROCK SPRINGS, WY82901 DEEP CREEK 2-22-4-2EDRAWN:8/26/2013-TCM SCALE:1"=200o· SECTION 22, T.4S., R.2 E.

REVISED: N/A -. DRG JOB No. 20025 TOTAL PROPOSED LENGTH: 262.1'±

TOPO B PROPOSED ROAD - - - - EXISTING ROAD



-LMS---tWB ÌRI162 -2E #1-16-4-2 -15-4-2E #3-15-4-2E

-15-4 E O 2000

1 E- -2E #6- 5 ¯ 7 2

1

2

-ElD4EE15


3-22-4-2E# 22

¯

EE


262.1'±

15-22-


PELICAV LAKEOURAY








-LMS---tWB ÌRI162 -2E #1-16-4-2 -15-4-2E #3-15-4-2E

-15-4 E O 2000

1 E- -2E #6- 5 ¯ 7 2

1

2

-ElD4EE15


3-22-4-2E# 22

¯

EE


262.1'±

15-22-


PELICAV LAKEOURAY









CONFIDE

NTIAL


#3-15-4 E -- 0 2000

-2E

DEEP CREE2-22-4

EK

GERANDLETT .

BCE

ONE MILE RADIUS FOR& ASSOCIATES, INC. CRESCENT POINT ENERGY

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, WY82901 DEEP CREEK 2-22-4-2EDRAWN:8/26/2013-TCM SCALE:1"=2000' SECTION 22, T.4S., R.2 E.

REVISED: N/A -

. DRG JOB No. 20025

TOPO C PROPOSED ROAD - - - - EXISTING ROAD



#3-15-4 E -- 0 2000

-2E

DEEP CREE2-22-4

EK

GERANDLETT .

BCE



REVISED: N/A -

. DRG JOB No. 20025




#3-15-4 E -- 0 2000

-2E

DEEP CREE2-22-4

EK

GERANDLETT .

BCE



REVISED: N/A -

. DRG JOB No. 20025





CONFIDE

NTIAL


-ËE #1-16-4- -2E - 4 E # 1 0 000

.E

-2E #6-

UTE TRI

3"- UTEDEEl 4EE1 CREE

2-22-4-2EBEGIN SURVEY .a

END SURVEYATL-. -.

e2- - - STAKED PIPEIINE

QEIDRANGÌE :I

RANDLETT .

-

EPROPOSED PIPELINE FOR

& ASSOCIATES, INC. CRESCENT POINT ENERGYson se2 so2e 1414 ELK ST., ROCK SPRINGS, WY82901 DEEP CREEK 2-22-4-2E

DRAWN:8/26/2013-TCM SCALE:1"=200o· SECTION 22, T.4S., R.2 E.REVISED: N/A -. DRG JOB No. 20025 TOTAL PROPOSED LENGTH: 335.0'±

TOPO D PROPOSED PIPELINE- - - EXISTING ROAD



-ËE #1-16-4- -2E - 4 E # 1 0 000

.E

-2E #6-

UTE TRI



END SURVEYATL-. -.


QEIDRANGÌE :I

RANDLETT .

-







-ËE #1-16-4- -2E - 4 E # 1 0 000

.E

-2E #6-

UTE TRI



END SURVEYATL-. -.


QEIDRANGÌE :I

RANDLETT .

-







. .EntrY 2011004320Book 1239 Page 57

MEMORANDUM of SURFACE USE AGREEMENT and GRANT OF EASEMENTS

David Eckelberger is Landman for Ute Energy LLC and Ute Energy Upstream Holdings LLC.authorized to do business in Utah (hereinafter referred to as “Ute Energy”). Ute Energy owns,operates and manages oil and gas interests In Uintah and Duchesne Counties, Utah.

WHEREAS, that certain Surface Use Agreement and Grant of Easements (“Agreement”) datedeffective June 2nd 2011 has been entered into by and between Deep Creek Investments, whoseaddress is do Lee M. Smith. General Partner, 2400 Sunnyside, Salt Lake City, Utah 84108(“Owner”) and Ute Energy, whose address is 1 875 Lawrence Street, Suite 200, Denver, CO80202 (“Operator”).

WHEREAS, Owner owns the surface estate of the real prope Utah (the“Property”), legally described as:1239 Page 57 $14.00

i—JUN—11 09:00Township 4 South, Range 2 East, Ui11, OTMMfl\IOS t 9 S12 NEI4 r\MPWT jiiuiuI’u

Secti 10: W12W12 RECORDERS UINTAH COUNTY UTAHSection 15’ SI’ UTE ENER8YSection 16: N12 P0 BOX 789 FT DUCHESNE UT 84026Section 22: All Rec BY: DEBRA ROOKS DEPUTY

WHEREAS, for an agreed upon monetary consideration. Operator may construct the necessarywell site pads for drilling. (ompletion, re-completion, reworking, re-entry, production,maintenance and operation of wells (“\VelI Pads”) on the Property. Ute Energy, its agents,employees, assigns, contraclors and subcontractors. may enter upon and use the Well Pads for thepurposes of drillIng, completing, producing, maintaining. and operating Wells to produce oil, gasand associated hdrocarhons produced from the Property, including the construction and use offrac pits, tank batteries, water disposal pits, production equipment, compressor sites and otherfacilities used to produce and market the oil, gas and associated hydrocarbons.

WHEREAS, Operator has the right to a non-exclusive access easement (“Road Easement”) on theProperty for ingress and egress by Operator and its employees, contractors, sub-contractors,agents. and business invitees as needed to conduct oil and gas operations.

WHEREAS, Operator, its employees, contractors, sub-contractors, agents and business inviteeshas the right to a non-exclusive pipeline easement to construct, maintain, inspect, operate andrepair a pipeline or pipelines, pigging facilities and related appurtenances for the transportation ofoil, gas. petroleum products, water and any other substances recovered during oil and gasproduction.

WI-TEREAS, this Agreement shall run with the Property and be binding upon and inure to thebenefit of the parties and their respective heirs, successors and assigns as stated in thisAgreement.

TE-JERFORE, Operator is granted access to the surface estate and the Agreement constitutes avalid and binding surface use agreement as required under Utah Admin. Code Rule R649-3-34(7).

This Memorandum is executed this 14th day ofJune.

David EckelbergerLan dmanSTATE OF COLORADO

ssCOUNTY 01- DENVER

The toreguing instrument was acknowledged before me by D id Eckelb e Landman for ‘Ic Enersy LI_C and Ute EnergyUpsirearn Holdings LLC ibis I4 day of June.

Notary Seal:

Mv Commission expires:

2L/ KARl QUARLESI)atc / NOTARY PUBLIC, STATE OF COLORADO

My Comm. Expires September 15, 2014


CONFIDE

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Entry 2011004320Book1239 Page 57


David Eckelberger is Landman for Ute Energy LLC and Ute Energy Upstream Holdings LLC,authorized to do business in Utah (hereinafter referred to as "Ute Energy"). Ute Energy owns,operates and manages oil and gas interests In Uintah and Duchesne Counties, Utah.WHEREAS, that certain Surface Use Agreement and Grant of Easements ("Agreement") datedeffective June 2nd,2011 has been entered into by and between Deep Creek Investments, whoseaddress is clo Lee M. Smith, General Partner, 2400 Sunnyside, Salt Lake City, Utah 84108("Owner") and Ute Energy, whose address is 1875 Lawrence Street, Suite 200, Denver, CO80202 ("Operator").

WHEREAS, Owner owns the surface estate of the real prope, Utah (the"Property"), legally described as:

Book1239 Page 57 $14.00Township 4SSohuthnRange 2 East. U JUN 1 09:00

Section 10: W/2W/2 RECORDER,UINTAHCOUNTY,UTAHSection 15: S/2 UTEENER6YSection 16: N/2 POBOX789 FT DUCHESNE,UT84026Section 22: All Rec By: DEBRAROOKS , DEPUTY

WHEREAS, for an agreed upon monetary consideration, Operator may construct the necessarywell site pads for drilling, completion, re-completion, reworking, re-entry, production,maintenance and operation of wells ("Well Pads") on the Property. Ute Energy, its agents,employees, assigns, contractors and subcontractors, may enter upon and use the Well Pads for thepurposes of drilling, completing, producing, maintaining, and operating Wells to produce oil, gasand associated hydrocarbons produced from the Property, including the construction and use offrac pits, tank batteries, water disposal pits, production equipment, compressor sites and otherfacilities used to produce and market the oil, gas and associated hydrocarbons.

WHEREAS, Operator has the right to a non-exclusive access easement ("Road Easement") on theProperty for ingress and egress by Operator and its employees, contractors, sub-contractors,agents, and business invitees as needed to conduct oil and gas operations.

WHEREAS, Operator, its employees, contractors, sub-contractors, agents and business inviteeshas the right to a non-exclusive pipeline easement to construct, maintain, inspect, operate andrepair a pipeline or pipelines, pigging facilities and related appurtenances for the transportation ofoil, gas, petroleum products, water and any other substances recovered during oil and gasproduction.

WHEREAS, this Agreement shall run with the Property and be binding upon and inure to thebenefit of the parties and their respective heirs, successors and assigns as stated in thisAgreement.

THERFORE, Operator is granted access to the surface estate and the Agreement constitutes avalid and binding surface use agreement as required under Utah Admin. Code Rule R649-3-34(7).

This Memorandum is executed this 14thday of June, 2011

David EckelbergerLandmanSTATE OF COLORADO )

) ssCOUNTY OF DENVER )The foregoing instrument was acknowledged before me by Dyid Eckel Landman fo te Energy LLC and Ute EnergyUpstæam Holdings LLC this 14*day of June, 2011.

Notary PuNotary Seal:

commissionL KARIQUARLES

Date /NOTARYPUBUC,STATEOFCOLORADO

MyComm. Expires September 15,



























































9.5" TIME SAVER WELLHEAD SYSTEMWITH DRILL SPOOL,

AND BOP CONFIGURATION

Top of Casing Head

Bottom of Casing Head

11" 3MTop of BOP Adapter

11" 3M

519 E . 300 S.

Vernal, U T 84078

P435-781-0434

F435-789-5656

11" 3M

11" 3M

Rotating Head

3" 3K Outlet

Pipe Rams

Blind Rams

Double 11" 3K BOP

BOP Adapter QuickConnect

9.5" Time SaverCasing Head

Inlet to Manifold

3K Choke 3K Choke

3-1/8" 3K Gate Valves


Choke Manifold

Oct, 18, 2013


CONFIDE

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CAMERON Oct, 18, 2013519 E. 300 S.Vernal, UT 84078P435-781-0434F435-789-5656

Choke Manifold

Crescent Point

9.5" T1MESAVERWELLHEADSYSTEMWITHDRILLSPOOL,

AND BOP CONFIGURAT10N 3-1/8" 3K Gate Valves


Rotating Head

11" 3M 3K Choke 3K Choke

ANNULAR Inlet to Manifold

11"3M

Pipe Rams

L Double 11"3K BOP

Blind Rams

11" 3M 3" 3KOutlet

DRILLINGSPOOL

TopofBOPAdapter 11"3M

9.5" Time Saver. Casing Head


2" BALL VALVE

Bottomof Casing Head

9-5/8" CASING




Choke Manifold

Crescent Point




Rotating Head



11"3M

Pipe Rams

L Double 11"3K BOP

Blind Rams

11" 3M 3" 3KOutlet

DRILLINGSPOOL




2" BALL VALVE


9-5/8" CASING




Choke Manifold

Crescent Point




Rotating Head



11"3M

Pipe Rams

L Double 11"3K BOP

Blind Rams

11" 3M 3" 3KOutlet

DRILLINGSPOOL




2" BALL VALVE


9-5/8" CASING




Choke Manifold

Crescent Point




Rotating Head



11"3M

Pipe Rams

L Double 11"3K BOP

Blind Rams

11" 3M 3" 3KOutlet

DRILLINGSPOOL




2" BALL VALVE


9-5/8" CASING



555 17th Street, Suite 750

Denver, CO 80202

Phone: (720) 880-3610

November 6, 2013 State of Utah Division of Oil, Gas and Mining Attention: Diana Mason 1594 West North Temple Salt Lake City, UT 84116 RE: Exception Location Request (R649-3-3) Deep Creek 2-22-4-2E NW/NE of Section 22, T4S, R2E

272’ FNL & 1968’ FEL UBS&M, Uintah County, Utah Dear Ms. Mason: Please be advised that Crescent Point Energy U.S. Corp (Crescent Point) is requesting approval from the Utah Division of Oil, Gas and Mining for the captioned well that has a surface and bottom hole location of 272’ FNL & 1968’ FEL of Section 22, Township 4S, Range 2E, USB&M, Uintah County, Utah. A copy of the survey plat is included in the APD package for your reference. This well was moved outside of the legal window from the center of the quarter quarter due to topographical constraints. Please be advised that Crescent Point has obtained written consent from 100% of the oil and gas owners within a radius of 460’ along the intended wellbore. If you have any questions or need further information, please contact myself or Lori Browne at 720-880-3610. Sincerely, Crescent Point Energy U.S. Corp

Ryan Waller

Ryan Waller Landman


CONFIDE

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,555 17th Street, Suite 750

Crescent Point Denver,CO80202ENERGY U S. CORP Phone: (720) 880-3610

November 6, 2013

State of Utah Division of Oil, Gas and MiningAttention: Diana Mason1594 West North TempleSalt Lake City, UT84116

RE: Exception Location Request (R649-3-3)

Deep Creek 2-22-4-2E

NW/NE of Section 22, T4S, R2E272' FNL& 1968' FELUBS&M, Uintah County, Utah

Dear Ms. Mason:

Please be advised that Crescent Point Energy U.S. Corp (Crescent Point) is requesting approval from the Utah Divisionof Oil, Gas and Mining for the captioned well that has a surface and bottom hole location of 272' FNL & 1968' FEL ofSection 22, Township 4S, Range 2E, USB&M, Uintah County, Utah. A copy of the survey plat is included in the APDpackage for your reference. This well was moved outside of the legal window from the center of the quarter quarterdue to topographical constraints.

Please be advised that Crescent Point has obtained written consent from 100% of the oil and gas owners within aradius of 460' along the intended wellbore.

If you have any questions or need further information, please contact myself or Lori Browne at 720-880-3610.

Sincerely,Crescent Point Energy U.S. Corp

RyanWaŒer

Ryan WallerLandman




Cresce nt Point Denver, CO 80202ENERGY U. S. CORP Phone: (720) 880-3610

November 6, 2013


RE: Exception Location Request (R649-3-3)Deep Creek 2-22-4-2ENW/NE of Section 22, T4S, R2E272' FNL& 1968' FELUBS&M, Uintah County, Utah

Dear Ms. Mason:

Please be advised that Crescent Point Energy U.S. Corp (Crescent Point) is requesting approval from the Utah Divisionof Oil, Gas and Mining for the captioned well that has a surface and bottom hole location of 272' FNL& 1968' FELofSection 22, Township 4S, Range 2E, USB&M, Uintah County, Utah. A copy of the survey plat is included in the APDpackage for your reference. This well was moved outside of the legal window from the center of the quarter quarterdue to topographical constraints.




Ryan WaŒer

Ryan WallerLandman





November 6, 2013



Dear Ms. Mason:





Ryan WaŒer

Ryan WallerLandman





November 6, 2013



Dear Ms. Mason:





Ryan WaŒer

Ryan WallerLandman




CONFIDE

NTIAL


/ / / APPROXIMATE DISTURBANCE AREA 2.6±ACRES/ 0.8% GRADE OF AN EASTERLY SLOPE

UNGRADED ELEVATION: 4974.6'FINISHED ELEVATION: 4973.9'

E 150' STA. 3+ 50| 30' | 120'

00z

I

| 30'

sosassrw STA. 1+38392' TO BHL

I STA. 0+75

4975

77

o' | 120' STA. 0+00150

TOPSOIL PILE

BEFORE DIGGING 8CALL FOR

TJTILITY LINE LOCATIONNOTE: THE EARTH QUANTITIES ON 60 0 60

ANDTHDER lENOFAREHISE MAATEDHE

4976RESPONSIBILITY OF THE USER. SCALE FEET

CRESCENT POINT ENERGY&ASSOCIATES, INC. DEEP CREEK2-22-4-2E

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, WY82901 SECTION 22 , T. 4 S., R. 2 E.DRAWN: 8/26/2013 - TCM SCALE: 1"= 60'

REVISED: N/A -. DRG JOB No. 20025 UNGRADED ELEVATION: 4974.6'FIGURE 1 FINISHED ELEVATION: 4973.9'





E 150' STA. 3+ 50| 30' | 120'

00z

I

| 30'


I STA. 0+75

4975

77

o' | 120' STA. 0+00150

TOPSOIL PILE












E 150' STA. 3+ 50| 30' | 120'

00z

I

| 30'


I STA. 0+75

4975

77

o' | 120' STA. 0+00150

TOPSOIL PILE












E 150' STA. 3+ 50| 30' | 120'

00z

I

| 30'


I STA. 0+75

4975

77

o' | 120' STA. 0+00150

TOPSOIL PILE











CONFIDE

NTIAL


30' 120'

30'

47'

60' 30'

oô

o

77'o

30' 120'

BEFORE DIGGINGCALL FOR

TJTILITY LINE LOCATIONNOTE: THE EARTH QUANTITIES ON 60 0 60ANDHISTHDERAUENOFAREHIS SMAATEDHE

RESPONSIBILITY OF THE USER. SCALE FEET

PAD LAYOUTCRESCENT POINT ENERGY&ASSOCIATES, INC.

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, WY82901 DEEP CREEK 2-22-4-2EDRAWN:8/26/2013-TCM SCALE:1"=6o. SECTION 22, T.4S., R.2E.

REVISED: N/A -. DRG JOB No. 20025 UNGRADED ELEVATION: 4974.6'FIGURE 1A FINISHED ELEVATION: 4973.9'



30' 120'

30'

47'

60' 30'

oô

o

77'o

30' 120'









30' 120'

30'

47'

60' 30'

oô

o

77'o

30' 120'









30' 120'

30'

47'

60' 30'

oô

o

77'o

30' 120'










CONFIDE

NTIAL


4975 4075-GRADE

/ FILL

4070 4070-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

3+50

4975RADE

4075

CUT

4070 4070-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

1+38

GRADE

CUT

4970 4070

4965 40GG

40GO 40GO-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

0+75

GRADE

4975 1075CUT

-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

0+00

CRESCENT POINT ENERGY& ASSOCIATES, INC. DEEP CREEK 2-22-4-2E

(son 362-502¿ 1414 ELK ST., ROCK SPRINGS, WY82901 SECTION 22 , T. 4 S., R.2 E.DRAWN:8/26/2013-TCM SCALE:HORZ1"=50'VERT1"=5'




4975 4075-GRADE

/ FILL

4070 4070-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

3+50

4975RADE

4075

CUT

4070 4070-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

1+38

GRADE

CUT

4970 4070

4965 40GG

40GO 40GO-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

0+75

GRADE

4975 1075CUT

-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

0+00






4975 4075-GRADE

/ FILL

4070 4070-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

3+50

4975RADE

4075

CUT

4070 4070-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

1+38

GRADE

CUT

4970 4070

4965 40GG

40GO 40GO-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

0+75

GRADE

4975 1075CUT

-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

0+00






4975 4075-GRADE

/ FILL

4070 4070-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

3+50

4975RADE

4075

CUT

4070 4070-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

1+38

GRADE

CUT

4970 4070

4965 40GG

40GO 40GO-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

0+75

GRADE

4975 1075CUT

-1+50 -1+00 -0+50 0+00 0+50 1+00 1+50

0+00







CONFIDE

NTIAL

N

10'

BEN

CH

RES

ERV

EPI

T10

0'X

60'X

12'

7,22

4B

bls

MU

DTA

NK

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200'

RIG

BA

SEC

ATW

ALK

IJG

HT

PLA

NT

R

PRO

POSE

RO

AD

PAR

TSH

OU

SE

II

138'

212'

350'

IN

84°5

5'39

"W

-A

PPR

OX

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RB

AN

CE

AR

EA-

----

975

EX/S

TIN

G

N

10'

BEN

CH

RES

ERV

EPI

T10

0'X

60'X

12'

7,22

4B

bls

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DTA

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200'

RIG

BA

SEC

ATW

ALK

IJG

HT

PLA

NT

R

PRO

POSE

RO

AD

PAR

TSH

OU

SE

II

138'

212'

350'

IN

84°5

5'39

"W

-A

PPR

OX

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CE

AR

EA-

----

975

EX/S

TIN

G

N

10'

BEN

CH

RES

ERV

EPI

T10

0'X

60'X

12'

7,22

4B

bls

MU

DTA

NK

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200'

RIG

BA

SEC

ATW

ALK

IJG

HT

PLA

NT

R

PRO

POSE

RO

AD

PAR

TSH

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SE

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138'

212'

350'

IN

84°5

5'39

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PPR

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----

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RES

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60'X

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7,22

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POSE

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SE

II

138'

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!!

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24

10

23

15

09

13

21

2527

16

14

1211

22

28 26

UTE TRIBAL26-324304734665

UTE TRIBAL13-21-4-2E4304751170

UTE TRIBAL5-21-4-2E4304752028

UTE TRIBAL11-21-4-2E4304752030

Ute Tribal3-28-4-2E4304752037

UTE TRIBAL14-10-4-2E4304752201

UTE TRIBAL2-15-4-2E4304752202

UTE TRIBAL7-15-4-2E4304752203

UTE TRIBAL8-15-4-2E4304752204

UTE TRIBAL9-16-4-2E4304752205UTE TRIBAL

11-16-4-2E4304752206

UTE TRIBAL13-16-4-2E4304752207

UTE TRIBAL15-16-4-2E4304752208

DEEP CREEK13-9-4-2E4304752410

DEEP CREEK15-9-4-2E4304752411

DEEP CREEK1-16-4-2E4304752412

DEEP CREEK3-16-4-2E4304752413

DEEP CREEK5-16-4-2E4304752416

DEEP CREEK7-16-4-2E4304752418

DEEP CREEK11-15-4-2E4304752422

DEEP CREEK13-15-4-2E4304752424

DEEP CREEK15-15-4-2E4304752425 DEEP CREEK

16-15-4-2E4304752426

DEEP CREEK14-9-4-2E4304752445

DEEP CREEK2-16-4-2E4304752446

DEEP CREEK16-9-4-2E4304752447

DEEP CREEK6-16-4-2E4304752449

DEEP CREEK8-16-4-2E4304752450

DEEP CREEK12-15-4-2E4304752451

DEEP CREEK14-15-4-2E4304752452

LAMB3-15-4-2E4304753014

LAMB4-15-4-2E4304753015

LAMB5-15-4-2E4304753016

LAMB6-15-4-2E4304753017

DEEP CREEK9-15-4-2E4304753018

DEEP CREEK10-15-4-2E4304753019

Ute Tribal12-21-4-2E

4304753893

Ute Tribal14-21-4-2E4304753894

Deep Creek13-10-4-2E4304754091

Deep Creek12-22-4-2E4304754101

Deep Creek8-22-4-2E4304754102

Deep Creek1-22-4-2E4304754103

Deep Creek11-22-4-2E4304754179

Deep Creek10-22-4-2E4304754180

Deep Creek9-22-4-2E4304754181

Deep Creek7-22-4-2E

4304754182

Deep Creek16-22-4-2E4304754183

Deep Creek15-22-4-2E

4304754184

Deep Creek14-22-4-2E4304754185

Deep Creek13-22-4-2E

4304754186

Deep Creek6-22-4-2E4304754192

Deep Creek5-22-4-2E4304754193

Deep Creek4-22-4-2E4304754194

Deep Creek3-22-4-2E4304754195

Deep Creek2-22-4-2E4304754196

Map Produced by Diana Mason

F1,700 0 1,700850 Feet

1:16,807

Wells QueryStatus

APD - Aproved Permit

H DRL - Spuded (Drilling Commenced)

4 GIW - Gas Injection

!) GS - Gas Storage

! LOC - New Location

7 OPS - Operation Suspended

ª PA - Plugged Abandoned

* PGW - Producing Gas Well

' POW - Producing Oil Well

¸ SGW - Shut-in Gas Well

· SOW - Shut-in Oil Well

6 TA - Temp. Abandoned

" TW - Test Well

¸ WDW - Water Disposal

¸ WIW - Water Injection Well

=) WSW - Water Supply Well

UnitsSTATUS

ACTIVE

EXPLORATORY

GAS STORAGE

NF PP OIL

NF SECONDARY

PI OIL

PP GAS

PP GEOTHERML

PP OIL

SECONDARY

TERMINATED

FieldsSTATUS

Unknown

ABANDONED

ACTIVE

COMBINED

INACTIVE

STORAGE

TERMINATED

TOOELE

SAN JUAN

MILLARD

KANE

JUAB

IRON

EMERY

UINTAH

BOX ELDER

GARFIELD

GRAND

UTAH

WAYNEBEAVER

DUCHESNE

SEVIER

SUMMIT

RICH

WASHINGTON

CARBON

SANPETE

CACHE

PIUTE

DAVIS

WASATCH

WEBER

SALT LAKE

DAGGETT

MORGAN

Location Map

API Number: 4304754196Well Name: Deep Creek 2-22-4-2E Township: T04.0S Range: R02.0E Section: 22 Meridian: U

Operator: CRESCENT POINT ENERGY U.S. CORP

Map Prepared: 11/12/2013


CONFIDE

NTIAL


DEEP CREEK DEEP CREEK DEEP CREEK13-9-4-2E 14-9-4-2E 15-94-2E

DEEP EEK DeepCreek UTETRI2EAL10 APINumber:43047541964304752410 4304752445 4304752411 16-9-4- e13-10-4-2E

430475 47 4304754091 g4304752201 11 12 Well Name: Deep Creek 2-22-4-2ETownship: TO4.0S Range: RO2.0E Section: 22 Meridian: U

3DEEP4-CREEK 2D P4-C2REEEK 4D3EEPC22lEK

0 73E15

e0M4-23E14

2-lR2EBAL Operator: CRESCENT POINT ENERGY U.S. CORP

4304752413 44304752446 4 4304752202

Map Prepared: 11/12/2013Map Produced by Diana Mason

LAMB LAMBDEEP CREEK DEEP CREEK DEEP CREEK

8DEEP4-CFEEK 5-15-4-2E 6-15-4-2E UTE TRIBAL UTE TRIB/,L5-16-4-2E 6-16-4-2E 7-16-4-2E

43047524504304753016 4304753017 7-15-4-2E 8-15-4-2E welisouery units

4304752416 4304752449 4304752418 * 44304752203 43047522G4 status sTATus

16 15 * APo AproveaPermit AcTivE

ORL spudea<oriiiingcommenceci ExPtosAvoav

UTETRIIALoiw easinection oAssvosAoE

9-16-4-2E DEEPCREEK DEEPCREEK DEEPCRI EK 14 13 Feeoit

UTETRIBAL4304752,05

12-15-4-2EDEEPCREEK 10-15-4-2E 9-15-4-2E o Loc Newtocaion

NFsEcoNDARY3014 2E06 44304752451 3014

54E22 4304753019 4304753018 o

UTE TRIBAL DEEP CREEK DEEP CREEK DEEP CREEK sEcoNDARY

13-16-4-2E UTE TRIBAL 13-15-4-2E 14-15-4-2E 15-15-4-2E TERMiNATED

4304752207 15-16-4-2E4304752424 4304752452 4304752425 DEEP EEK o Temp neonea

Fields4304752208 16-15-4 E sTmus

430475 426 " unknown

4304754194 3-22-4-2E e4304754196Deep Cr k

e usw w ersuppiyweii o NED

4304754195 1-22-4-24304754 3 ST°N^°E

TERMINATED

Deep Creek

UTE TRIBAL5De2e2p4eEek 6-3202424E92

5-21-4-2E 4304754193e Deep Creek4304752028 e 8-22-4-2E ic

Location Map4304754 02

22 D ep Creek eep Crf ek7-22-4-2E 9-22-4-21

Deep Creek 4304754182 4304754 81 23 24

12E14RI2EAL 21

Deep Creek3024

51E79

uvAH ONTAH

+ 4304752030 2-22-4-2EuAsUte Tribal 304754101 cAasoN

12-21-4-2E Deep Creek4304753893 Deep Creek 14-22-4-2E

13-22-4-2E4304754185 "^"

EMERY GRAND

UTE TRIBAL43047541 Deep Cree Deep Creek sevisa

13-21-4-2E Ute Tribal 15-22-4-2 16-22-4-2E

4304751170 0245

28E4 4304754184 ee2p2C eEk e430475418 B^*ER PiuTE wAYNE

*3Ue8

4304754180 IRON GARFiELD

NauAN

301752037 - - w^sHINGTON KANE

UTE TRIBAL26-32 25

28 27 26 4304734665I

oo eso o uooFeet

1:16,807







0 73E15

e0M4-23E14


4304752413 44304752446 4 4304752202





4304752416 4304752449 4304752418 * 44304752203 43047522G4 status sTATus


o ORL spudea<oriiiingcommenceci ExPtosAvoav



UTETRIBAL4304752,05

12-15-4-2EDEEPCREEK 10-15-4-2E 9-15-4-2E e Loc Newtocaion

NFsEcoNDARY3014 2E06 44304752451 3014

54E22 4304753019 4304753018 o

UTE TRIBAL DEEP CREEK DEEP CREEK DEEP CREEK _y_ sEcoNDARY



Fields4304752208 16-15-4 E sTmus

430475 426 " unknown

4304754194 3-22-4-2E 4304754196Deep Cr k


4304754195 1-22-4-24304754 3 ST°N^°E

TERMINATED

Deep Creek




22 Deep Creek Deep Crf ek7-22-4-2E 9-22-4-21

Deep Creek 4304754182 1304754 81 23 24

12E14RI2EAL 21

Deep Creek3024

51E79

uvAH ONTAH



13-22-4-2E4304754185 "^"

EMERY GRAND


13-21-4-2E Ute Tribal 15-22-4-2 16-22-4-2E

4304751170 0245

28E4 4304754184 ee2p2C eEk œ430475418 B^*ER PiuTE wAYNE

*3Ue8


NauAN


UTE TRIBAL26-32 25

28 27 26 4304734665I

oo eso o uooFeet

1:16,807







0 73E15

e0M4-23E14


4304752413 44304752446 4 4304752202





4304752416 4304752449 4304752418 * 44304752203 43047522G4 status sTATus





UTETRIBAL4304752,05


NFsEcoNDARY3014 2E06 44304752451 3014

54E22 4304753019 4304753018 o




Fields4304752208 16-15-4 E sTmus

430475 426 " unknown

4304754194 3-22-4-2E 4304754196Deep Cr k


4304754195 1-22-4-24304754 3 ST°N^°E

TERMINATED

Deep Creek





Deep Creek 4304754182 1304754 81 23 24

12E14RI2EAL 21

Deep Creek3024

51E79

uvAH ONTAH



13-22-4-2E4304754185 "^"

EMERY GRAND


13-21-4-2E Ute Tribal 15-22-4-2 16-22-4-2E

4304751170 0245


*3Ue8


NauAN


UTE TRIBAL26-32 25

28 27 26 4304734665I

oo eso o uooFeet

1:16,807







0 73E15

e0M4-23E14


4304752413 44304752446 4 4304752202





4304752416 4304752449 4304752418 * 44304752203 43047522G4 status sTATus





UTETRIBAL4304752,05


NFsEcoNDARY3014 2E06 44304752451 3014

54E22 4304753019 4304753018 o




Fields4304752208 16-15-4 E sTmus

430475 426 " unknown

4304754194 3-22-4-2E 4304754196Deep Cr k


4304754195 1-22-4-24304754 3 ST°N^°E

TERMINATED

Deep Creek





Deep Creek 4304754182 1304754 81 23 24

12E14RI2EAL 21

Deep Creek3024

51E79

uvAH ONTAH



13-22-4-2E4304754185 "^"

EMERY GRAND


13-21-4-2E Ute Tribal 15-22-4-2 16-22-4-2E

4304751170 0245


*3Ue8


NauAN


UTE TRIBAL26-32 25

28 27 26 4304734665I

oo eso o uooFeet

1:16,807



BOPE REVIEW CRESCENT POINT ENERGY U.S. CORP Deep Creek 2-22-4-2E 43047541960000

Well Name CRESCENT POINT ENERGY U.S. CORP Deep Creek 2-22-4-2E 43047541960000

String COND SURF PROD

Casing Size(") 16.000 8.625 5.500

Setting Depth (TVD) 4 0 1000 7335

Previous Shoe Setting Depth (TVD) 0 4 0 1000

Max Mud Weight (ppg) 8.3 8.3 10.0

BOPE Proposed (psi) 0 500 3000

Casing Internal Yield (psi) 1000 2950 7740

Operators Max Anticipated Pressure (psi) 3814 10.0

Calculations COND String 1 6 . 0 0 0 "

Max BHP (psi) .052*Setting Depth*MW= 1 7

BOPE Adequate For Drilling And Setting Casing at Depth?

MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= 1 2 NO

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= 8 NO

*Can Full Expected Pressure Be Held At Previous Shoe?

Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= 8 NO

Required Casing/BOPE Test Pressure= 4 0 p s i

*Max Pressure Allowed @ Previous Casing Shoe= 0 psi *Assumes 1psi/f t frac gradient

Calculations SURF String 8 . 6 2 5 "

Max BHP (psi) .052*Setting Depth*MW= 432


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= 312 YES air/mist

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= 212 YES Ok


Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= 221 NO OK

Required Casing/BOPE Test Pressure= 1000 p s i

*Max Pressure Allowed @ Previous Casing Shoe= 4 0 psi *Assumes 1psi/f t frac gradient

Calculations PROD String 5 . 5 0 0 "

Max BHP (psi) .052*Setting Depth*MW= 3814


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= 2934 YES 3M BOPE & annular, rotating head, blind ram,

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= 2200 YES pipe rams, kill & choke lines


Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= 2420 NO OK

Required Casing/BOPE Test Pressure= 3000 p s i

*Max Pressure Allowed @ Previous Casing Shoe= 1000 psi *Assumes 1psi/f t frac gradient

Calculations String "

Max BHP (psi) .052*Setting Depth*MW=


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= NO

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= NO


Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= NO

Required Casing/BOPE Test Pressure= p s i

*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes 1psi/f t frac gradient


CONFIDE

NTIAL





Casing Size(") 16.000 8.625 5.500

Setting Depth (TVD) 40 1000 7335

Previous Shoe Setting Depth (TVD) 0 40 1000


BOPE Proposed (psi) o Soo 3000



Calculations COND String 16.000 "Max BHP (psi) .052*Setting Depth*MW=

17


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=12 NO

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=8 NO


Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=8 NO

Required Casing/BOPE Test Pressure=40 psi

*Max Pressure Allowed @ Previous Casing Shoe= psi *Assumes lpsi/ft frac gradient

Calculations SURF String 8.625 "Max BHP (psi) .052*Setting Depth*MW=

432


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=312 air/mist

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=212 Ok


Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=221 NO OK


*Max Pressure Allowed @ Previous Casing Shoe=40 psi *Assumes lpsi/ft frac gradient

Calculations PROD String 5.500 "Max BHP (psi) .052*Setting Depth*MW=

3814


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=2934 3M BOPE & annular, rotating head, blind ram,

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=2200 pipe rams, kill & choke lines





Calculations String



MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=NO

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=NO


Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)=NO

Required Casing/BOPE Test Pressure= psi


RECEIVED: April 01,





Casing Size(") 16.000 8.625 5.500








17









432









3814








Calculations String









RECEIVED: April 01,





Casing Size(") 16.000 8.625 5.500








17









432









3814








Calculations String









RECEIVED: April 01,





Casing Size(") 16.000 8.625 5.500








17









432









3814








Calculations String









RECEIVED: April 01,



CONFIDE

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43047541960000 De p Creek 2-22-4-2ECasing Schemt - N

SurfaceI-TOC @0.

TO @

8-5/8" *SurfaceMW 8.3 1000. MDFrac 19.3

5-1/2" i ProductionMW 10. 7335.



SurfaceI-TOC @0.

TO @

8-5/8" *Surface

MW 8.3 1000. MDFrac 19.3




SurfaceI-TOC @0.

TO @

8-5/8" *Surface

MW 8.3 1000. MDFrac 19.3




SurfaceI-TOC @0.

TO @

8-5/8" *Surface

MW 8.3 1000. MDFrac 19.3




CONFIDE

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Well name: 43047541960000 Deep Creek 2-22-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Surface Project ID:

43-047-54196Location: UINTAH COUNTY

Design parameters: Minimum design factors: Environment:Collapse Collapse: H2S considered? No

Mud weight: 8.300 ppg Design factor 1.125 Surface temperature: 74 °FDesign is based on evacuated pipe. Bottom hole temperature: 88 °F

Temperature gradient: 1.40 °F/100ftMinimum section length: 100 ft

Burst:Design factor 1.00 Cement top: Surface

BurstMax anticipated surface

pressure: 880 psiInternal gradient: 0.120 psilft Tension: Non-directional string.Calculated BHP 1,000 psi 8 Round STC: 1.80 (J)

8 Round LTC: 1.70 (J)No backup mud specified. Buttress: 1.60 (J)

Premium: 1.50 (J)Body yield: 1.50 (B) Re subsequent strings:

Next setting depth: 7,335 ftTension is based on buoyed weight. Next mud weight: 10.000 ppgNeutral point: 875 ft Next setting BHP: 3,810 psi

Fracture mud wt: 19.250 ppgFracture depth: 1,000 ftInjection pressure: 1,000 psi

Run Segment Nominal End True Vert Measured Drift Est.Seq Length Size Weight Grade Finish Depth Depth Diameter Cost

(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 1000 8.625 24.00 J-55 ST&C 1000 1000 7.972 5147

Run Collapse Collapse Collapse Bumt Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design

(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 431 1370 3.178 1000 2950 2.95 21 244 11.62 J

Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: March 31,2014by: Div of Oil,Gas & Mining FAX: 801-359-3940 Salt Lake City, Utah

Remarks:Collapse is based on a vertical depth of 1000 ft, a mud weight of 8.3 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.Burst strength is not adjusted for tension.

Engineering msponsibilityfor use of thisdesign willbe thatof the































































CONFIDE

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Well name: 43047541960000 Deep Creek 2-22-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Production Project ID:




Temperature gradient: 1.40 °F/100ftMinimum section length: 1,000 ft



pressure: 2,197 psiInternal gradient: 0.220 psilft Tension: Non-directional string.Calculated BHP 3,810 psi 8 Round STC: 1.80 (J)


Premium: 1.50 (J)Body yield: 1.60 (B)

Tension is based on buoyed weight.Neutral point: 6,223 ft


(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 7335 5.5 17.00 E-80 LT&C 7335 7335 4.767 242055

Run Collapse Collapse Collapse Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design

(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 3810 6290 1.651 3810 7740 2.03 105.8 320 3.02 J


Remarks:Collapse is based on a vertical depth of 7335 ft, a mud weight of 10 ppg The casing is considered to be evacuated for collapse purposes.Collapse strength is based on the Westcott, Dunlop & Kemler method of biaxial correction for tension.

Burst strength is not adjusted for tension.

Engineering responsibility for use of thisdesign wi/Ibe thatof the






























































ON-SITE PREDRILL EVALUATIONUtah Division of Oil, Gas and Mining

Operator CRESCENT POINT ENERGY U.S. CORP Well Name Deep Creek 2-22-4-2EAPI Number 43047541960000 APD No 9 0 3 6 Field/Unit UNDESIGNATEDLocation: 1/4,1/4 NWNE Sec 22 T w 4.0S Rng 2.0E 272 FNL 1968 FELGPS Coord (UTM) 606357 4442724 Surface Owner Lee Smith

ParticipantsJim Burns - Starpoint, Lori Browne, Brian Foote, Mahe Taufa - Crescent Point; Mark Hecksel-DRGriffin; Allan Smith - landowner

Regional/Local Setting & TopographyThis location is in the Deep Creek area off the Carpenter Ranch road on the eastern extremesof the Leland Bench. Historically this land has been used for winter/ spring grazing of sheepand cattle. The region is not cultivated and is vegetated with naturally occuring native plantsproviding sparse habitat for some wildlife species. The proposed pad and section has a fairlyflat topography as i t si ts on the top of the bench edge. The Duchesne River is about I mile downthe cliff edge east and the Deep Creek North. The region has seen increasing development forpetroleum extract ion.

Surface Use PlanCurrent Surface UseGrazing

New RoadMiles

Well Pad Src Const Material Surface Formation

0 Width 250 Length 1 5 0 Onsi te UNTA

Ancillary Facilities

Waste Management Plan Adequate?

Environmental ParametersAffected Floodplains and/or Wetlands N

Flora / FaunaHigh desert shrubland ecosystem. Expected vegetation consists of black sagebrush,shadscale, Atriplex spp. , mustard spp, rabbit brush, horsebrush, broom snakeweed,Opunt ia spp and spr ing annuals .Dominant vegetation;Gardiner 's atriplexWildlife;Adjacent habitat contains forbs that may be suitable browse for deer, antelope, prairiedogs or rabbits , though none were observed.

Soil Type and Characteristicsl ight colored clayey sediments with gravels and cobbles

Erosion Issues N


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Operator CRESCENT POINT ENERGY U.S. CORPWell Name Deep Creek 2-22-4-2E

API Number 43047541960000 APD No 9036 Field/Unit UNDESIGNATEDLocation: 1/4,1/4NWNE Sec 22 Tw 4.0S Rng 2.0E 272 FNL 1968 FELGPS Coord (UTM) 606357 4442724 Surface Owner Lee Smith


Regional/Local Setting & TopographyThis location is in the Deep Creek area off the Carpenter Ranch road on the eastern extremesof the Leland Bench. Historically this land has been used for winter/ spring grazing of sheepand cattle. The region is not cultivated and is vegetated with naturally occuring native plantsproviding sparse habitat for some wildlife species. The proposed pad and section has a fairlyflat topography as it sits on the top of the bench edge. The Duchesne River is about I mile downthe cliff edge east and the Deep Creek North. The region has seen increasing development forpetroleum extraction.


New Road Well Pad Src Const Material Surface FormationMiles0 Width 250 Length 150 Onsite UNTA




Flora / FaunaHigh desert shrubland ecosystem. Expected vegetation consists of black sagebrush,shadscale, Atriplex spp., mustard spp, rabbit brush, horsebrush, broom snakeweed,Opuntia spp and spring annuals.Dominant vegetation;Gardiner's atriplexWildlife;Adjacent habitat contains forbs that may be suitable browse for deer, antelope, prairiedogs or rabbits, though none were observed.

Soil Type and Characteristicslight colored clayey sediments with gravels and cobbles

Erosion Issues N

RECEIVED: April 02,














Erosion Issues N

RECEIVED: April 02,














Erosion Issues N

RECEIVED: April 02,














Erosion Issues N

RECEIVED: April 02,


Sedimentation Issues N

Site Stability Issues N

Drainage Diverson Required? N

Berm Required? Y

Erosion Sedimentation Control Required? N

Paleo Survey Run? N Paleo Potental Observed? N Cultural Survey Run? N CulturalResources? N

Reserve Pit

Site-Specific Factors Site Ranking

Distance to Groundwater (feet) 100 to 200 5Distance to Surface Water (feet) > 1 0 0 0 0Dist. Nearest Municipal Well (ft) > 5 2 8 0 0

Distance to Other Wells (feet) > 1 3 2 0 0Native Soil Type Mod permeabili ty 1 0

Fluid Type Fresh Water 5Drill Cuttings Normal Rock 0

Annual Precipitation (inches) 0Affected Populations

Presence Nearby Utility Conduits Not Present 0

Final Score 2 0 1 Sensitivity Level

Characteristics / RequirementsA 60’ x 100' x 12' deep reserve pit is planned in an area of cut on the northwest side of thelocation. A pit liner is required. Operator commonly uses a 16 mil liner with a feltunderliner. Pit should be fenced to prevent entry by deer, other wildlife and domesticanimals. A minimum freeboard of two feet shall be maintained at all t imes. Pit to beclosed within one year after drilling activities are complete.

Closed Loop Mud Required? N Liner Required? Y Liner Thickness 16 Pit UnderlaymentRequired? N

Other Observations / Comments

Chris Jensen 1 / 2 9 / 2 0 1 4Evaluator Date / Time


CONFIDE

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Berm Required? Y



Reserve Pit


Distance to Groundwater (feet) 100 to 200 5Distance to Surface Water (feet) >1000 0Dist. Nearest Municipal Well (ft) > 5 2 8 0 0

Distance to Other Wells (feet) >1320 0Native Soil Type Mod permeability 10



Presence Nearby Utility Conduits Not Present 0Final Score 20 1 Sensitivity Level

Characteristics / RequirementsA 60' x 100' x 12' deep reserve pit is planned in an area of cut on the northwest side of thelocation. A pit liner is required. Operator commonly uses a 16 mil liner with a feltunderliner. Pit should be fenced to prevent entry by deer, other wildlife and domesticanimals. A minimum freeboard of two feet shall be maintained at all times. Pit to beclosed within one year after drilling activities are complete.



Chris Jensen 1/29/20 14Evaluator Date / Time

RECEIVED: April 02,





Berm Required? Y



Reserve Pit











RECEIVED: April 02,





Berm Required? Y



Reserve Pit











RECEIVED: April 02,





Berm Required? Y



Reserve Pit











RECEIVED: April 02,


Application for Permit to DrillStatement of Basis

Utah Division of Oil, Gas and Mining

APD No API WellNo Status Well Type Surf Owner CBM9 0 3 6 43047541960000 LOCKED OW P N oOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Lee SmithWell Name Deep Creek 2-22-4-2E UnitField UNDESIGNATED Type of Work DRILL

Location NWNE 22 4S 2E U 272 FNL 1968 FEL GPS Coord(UTM) 606357E 4442725N

Geologic Statement of BasisCrescent Point proposes to set 40' of conductor and 1,000' of surface casing at thislocation. The base of the moderately saline water at this location is estimated to be at adepth of 800'. A search of Division of Water Rights records shows 1 water well within a10,000 foot radius of the center of Section 22. This well islocated in the SE/4 of Section 14.Depth is l isted as 966 feet. Listed uses are irrigation, domestic and stock watering. Thesurface formation at this site is the Uinta Formation. The Uinta Formation is made up ofinterbedded shales and sandstones. The sandstones are most ly lent icular anddiscontinuous and should not be a significant source of useable ground water. Theproposed casing and cement should adequately protect ground water in this area.

Brad HillAPD Evaluator

2 / 1 3 / 2 0 1 4Date / Time

Surface Statement of BasisLocation is proposed in a good location although outside the spacing window. Well is to bedrilled directionally. Access road enters the pad from the East. The landowner or i tsrepresentat ive was in at tendance for the pre-si te inspection.The soil type and topography at present do not combine to pose a significant threat toerosion or sediment/ pollut ion transport in these regional cl imate condit ions.Usual construct ion s tandards of the Operator appear to be adequate for the proposedpurpose as submitted. Reserve pit is in an area of cut. I recognize no special flora or animal species or cultural resources on site that theproposed action may harm. A riparian area (Deep Creek) can be found North of the site. Thelocation was not previously surveyed for cultural and paleontological resources ( as theoperator saw fit) . I have advised the operator take all measures necessary to comply withESA and MBTA and that actions insure no disturbance to species that may have not beenseen during onsite visit .The location should be bermed to prevent f luids from entering or leaving the confines ofthe pad. Fencing around the reserve pit will be necessary to prevent wildlife and livestockfrom entering. A synthetic liner of 16 mils (minimum) should be utilized in the reserve pit .Measures (BMP's) shall be taken to protect steep slopes and topsoil pile from erosion,sedimentation and stabil i ty issues.

Chris JensenOnsite Evaluator

1 / 2 9 / 2 0 1 4Date / Time

Conditions of Approval / Application for Permit to Drill


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I


Utah Division of Oil, Gas and MiningI

APD No API WellNo Status Well Type Surf Owner CBM9036 43047541960000 LOCKED OW P NoOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Lee SmithWell Name Deep Creek 2-22-4-2E UnitField UNDESIGNATED Type of Work DRILL

. NWNE 22 4S 2E U 272 FNL 1968 FEL GPS CoordLocation(UTM) 606357E 4442725N

Geologic Statement of BasisCrescent Point proposes to set 40' of conductor and 1,000' of surface casing at thislocation. The base of the moderately saline water at this location is estimated to be at adepth of 800'. A search of Division of Water Rights records shows 1 water well within a10,000 foot radius of the center of Section 22. This well islocated in the SE/4 of Section 14.Depth is listed as 966 feet. Listed uses are irrigation, domestic and stock watering. Thesurface formation at this site is the Uinta Formation. The Uinta Formation is made up ofinterbedded shales and sandstones. The sandstones are mostly lenticular anddiscontinuous and should not be a significant source of useable ground water. Theproposed casing and cement should adequately protect ground water in this area.

Brad Hill 2/13/20 14APD Evaluator Date / Time

Surface Statement of BasisLocation is proposed in a good location although outside the spacing window. Well is to bedrilled directionally. Access road enters the pad from the East. The landowner or itsrepresentative was in attendance for the pre-site inspection.The soil type and topography at present do not combine to pose a significant threat toerosion or sediment/ pollution transport in these regional climate conditions.Usual construction standards of the Operator appear to be adequate for the proposedpurpose as submitted. Reserve pit is in an area of cut.I recognize no special flora or animal species or cultural resources on site that theproposed action may harm. A riparian area (Deep Creek) can be found North of the site. Thelocation was not previously surveyed for cultural and paleontological resources ( as theoperator saw fit). I have advised the operator take all measures necessary to comply withESA and MBTA and that actions insure no disturbance to species that may have not beenseen during onsite visit.The location should be bermed to prevent fluids from entering or leaving the confines ofthe pad. Fencing around the reserve pit will be necessary to prevent wildlife and livestockfrom entering. A synthetic liner of 16 mils (minimum) should be utilized in the reserve pit.Measures (BMP's) shall be taken to protect steep slopes and topsoil pile from erosion,sedimentation and stability issues.

Chris Jensen 1/29/20 14Onsite Evaluator Date / Time


RECEIVED: April 02,


I










RECEIVED: April 02,


I










RECEIVED: April 02,


I










RECEIVED: April 02,


Category ConditionPits A synthetic l iner with a minimum thickness of 16 mils shall be properly installed and maintained in

the reserve pit .Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of dril l ing operations.Surface Measures (BMP's) shall be taken to protect steep slopes and topsoil pile from erosion, sedimentation

and stabili ty issues.


CONFIDE

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Category ConditionPits A synthetic liner with a minimum thickness of 16 mils shall be properly installed and maintained in

the reserve pit.Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of drilling operations.Surface Measures (BMP's) shall be taken to protect steep slopes and topsoil pile from erosion, sedimentation

and stability issues.

RECEIVED: April 02,





RECEIVED: April 02,





RECEIVED: April 02,





RECEIVED: April 02,


WORKSHEETAPPLICATION FOR PERMIT TO DRILL

APD RECEIVED: 11 /8 /2013 API NO. ASSIGNED: 43047541960000

WELL NAME: Deep Creek 2-22-4-2E

OPERATOR: CRESCENT POINT ENERGY U.S. CORP (N3935) PHONE NUMBER: 720 880-3644

CONTACT: Emily Kate DeGrasse

PROPOSED LOCATION: NWNE 22 040S 020E Permit Tech Review:

SURFACE: 0272 FNL 1968 FEL Engineering Review:

BOTTOM: 0272 FNL 1968 FEL Geology Review:

COUNTY: UINTAH

LATITUDE: 40.12813 LONGITUDE: -109.75170

UTM SURF EASTINGS: 606357.00 NORTHINGS: 4442725.00

FIELD NAME: UNDESIGNATED

LEASE TYPE: 4 - Fee

LEASE NUMBER: Fee PROPOSED PRODUCING FORMATION(S): WASATCH

SURFACE OWNER: 4 - Fee COALBED METHANE: NO

RECEIVED AND/OR REVIEWED: LOCATION AND SITING:

PLAT R649-2 -3 .

Bond: STATE - LPM9080271 Unit:

Potash R649-3-2. General

Oil Shale 190-5

Oil Shale 190-3 R649-3-3. Exception

Oil Shale 190-13 Drilling Unit

Water Permit: 437478 Board Cause No: R649-3-3

RDCC Review: Effective Date:

Fee Surface Agreement Siting:

Intent to Commingle R649-3-11. Directional Drill

Commingling Approved

Comments: Presite Completed

Stipulations: 1 - Exception Location - dmason 5 - Statement of Basis - bhill 12 - Cement Volume (3) - ddoucet 23 - Spacing - dmason 25 - Surface Casing - hmacdonald


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I

I

APD RECEIVED: 11/8/2013 APINO.ASSIGNED: 43047541960000







COUNTY: UINTAH




LEASE TYPE: 4 - Fee



I

RECEIVED ANDIOR REVIEWED: LOCATION AND SITING:

PLAT R649-2-3.



Oil Shale 190-5








I


Stipulations: 1 - Exception Location - dmason5 - Statement of Basis - bhill12 - Cement Volume (3) - ddoucet23 - Spacing - dmason25 - Surface Casing - hmacdonald

RECEIVED: April 02,



I

I








COUNTY: UINTAH




LEASE TYPE: 4 - Fee



I


PLAT R649-2-3.



Oil Shale 190-5








I



RECEIVED: April 02,



I

I








COUNTY: UINTAH




LEASE TYPE: 4 - Fee



I


PLAT R649-2-3.



Oil Shale 190-5








I



RECEIVED: April 02,



I

I








COUNTY: UINTAH




LEASE TYPE: 4 - Fee



I


PLAT R649-2-3.



Oil Shale 190-5








I



RECEIVED: April 02,

Permit To Drill******************

Well Name: Deep Creek 2-22-4-2EAPI Well Number: 43047541960000

Lease Number: FeeSurface Owner: FEE (PRIVATE) Approval Date: 4 / 2 / 2 0 1 4

Issued to:CRESCENT POINT ENERGY U.S. CORP, 555 17th Street, Suite 750, Denver, CO 80202

Authority:Pursuant to Utah Code Ann. 40-6-1 et seq. , and Utah Administrat ive CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-3. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.

Duration:This approval shall expire one year from the above date unless substantial andcontinuous operat ion is underway, or a request for extension is made prior to theexpirat ion date

Exception Location:Appropriate information has been submitted to DOGM and administrat ive approvalof the requested exception location is hereby granted.

General:Compliance with the requirements of Utah Admin. R. 649-1 et seq., the Oil and GasConservation General Rules, and the applicable terms and provisions of theapproved Application for permit to dril l .

Conditions of Approval:This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil , Gas andMining (the “Board”). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been drilled,completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of i ts analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drill ing and spacing units in conformance with such analysis by fil inga Request for Agency Action with the Board.

State of Utaha DEPARTMENT OF NATURAL RESOURCES

-

.,5., MICHAEL R. STYLER

GARY R HERBERT E wcunw Drector

Gowrnor Division of Oil, Gas and MiningSPEINCERJ. COX JOHN R. HAZAL2euternal Gowtror DWslanDirector

Permit To Drillkkkkkkkkkkkkkkkkkk


Lease Number: FeeSurface Owner: FEE (PRIVATE)Approval Date: 4/2/20 14


Authority:Pursuant to Utah Code Ann. 40-6-1 et seq., and Utah Administrative CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-3. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.

Duration:This approval shall expire one year from the above date unless substantial andcontinuous operation is underway, or a request for extension is made prior to theexpiration date

Exception Location:Appropriate information has been submitted to DOGM and administrative approvalof the requested exception location is hereby granted.

General:Compliance with the requirements of Utah Admin. R. 649-1 et seq., the Oil and GasConservation General Rules, and the applicable terms and provisions of theapproved Application for permit to drill.

Conditions of Approval:This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil, Gas andMining (the "Board"). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been drilled,completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of its analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drilling and spacing units in conformance with such analysis by filinga Request for Agency Action with the


-














-














-













Compliance with the Conditions of Approval/Application for Permit to Drilloutlined in the Statement of Basis (copy attached).

Cement volume for the 5 1/2" production str ing shall be determined from actualhole diameter in order to place cement from the pipe set t ing depth back to surfaceand tail brought to above the top of the Green River Formation.

Surface casing shall be cemented to the surface.

Additional Approvals:The operator is required to obtain approval from the Division of Oil, Gas andmining before performing any of the following actions during the dril l ing of thiswell: • Any changes to the approved dri l l ing plan - contact Dustin Doucet • Significant plug back of the well - contact Dustin Doucet • Plug and abandonment of the well - contact Dustin Doucet

Notification Requirements:The operator is required to notify the Division of Oil, Gas and Mining of thefollowing actions during drilling of this well: • Within 24 hours following the spudding of the well - contact Carol Daniels OR submit an electronic sundry notice (pre-registration required) via the Utah Oil &Gas website at ht tp:/ /oi lgas.ogm.utah.gov • 24 hours prior to test ing blowout prevention equipment - contact Dan Jarvis • 24 hours prior to cementing or test ing casing - contact Dan Jarvis • Within 24 hours of making any emergency changes to the approved dril l ingp r o g r a m - contact Dustin Doucet • 24 hours pr ior to commencing operat ions to plug and abandon the well -contact Dan Jarvis

Contact Information:The following are Division of Oil, Gas and Mining contacts and their telephonenumbers (please leave a voicemail message if the person is not available to take thecall): • Carol Daniels 801-538-5284 - off ice • Dust in Doucet 801-538-5281 - off ice 801-733-0983 - after office hours • Dan Jarvis 801-538-5338 - office 801-231-8956 - after office hours

Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas ConservationGeneral Rules will be promptly filed with the Division of Oil, Gas and Mining,including but not l imited to: • Entity Action Form (Form 6) - due within 5 days of spudding the well • Monthly Status Report (Form 9) - due by 5th day of the following calendarm o n t h • Requests to Change Plans (Form 9) - due prior to implementation


Cement volume for the 5 1/2" production string shall be determined from actualhole diameter in order to place cement from the pipe setting depth back to surfaceand tail brought to above the top of the Green River Formation.


Additional Approvals:The operator is required to obtain approval from the Division of Oil, Gas andmining before performing any of the following actions during the drilling of thiswell:

• Any changes to the approved drilling plan - contact Dustin Doucet• Significant plug back of the well - contact Dustin Doucet• Plug and abandonment of the well - contact Dustin Doucet

Notification Requirements:The operator is required to notify the Division of Oil, Gas and Mining of thefollowing actions during drilling of this well:

• Within 24 hours following the spudding of the well - contact Carol DanielsORsubmit an electronic sundry notice (pre-registration required) via the Utah Oil &

Gas websiteat http://oilgas.ogm.utah.gov

• 24 hours prior to testing blowout prevention equipment - contact Dan Jarvis• 24 hours prior to cementing or testing casing - contact Dan Jarvis• Within 24 hours of making any emergency changes to the approved drilling

program- contact Dustin Doucet

• 24 hours prior to commencing operations to plug and abandon the well -

contact Dan Jarvis

Contact Information:The following are Division of Oil, Gas and Mining contacts and their telephonenumbers (please leave a voicemail message if the person is not available to take thecall):

• Carol Daniels 801-538-5284 - office• Dustin Doucet 801-538-5281 - office

801-733-0983 - after office hours• Dan Jarvis 801-538-5338 - office

801-231-8956 - after office hours

Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas ConservationGeneral Rules will be promptly filed with the Division of Oil, Gas and Mining,including but not limited to:

• Entity Action Form (Form 6) - due within 5 days of spudding the well• Monthly Status Report (Form 9) - due by 5th day of the following calendar

month• Requests to Change Plans (Form 9) - due prior to












contact Dan Jarvis



















contact Dan Jarvis



















contact Dan Jarvis








• Written Notice of Emergency Changes (Form 9) - due within 5 days • Notice of Operations Suspension or Resumption (Form 9) - due prior toimplementa t ion • Report of Water Encountered (Form 7) - due within 30 days after completion • Well Completion Report (Form 8) - due within 30 days after completion orplugging

Approved By:

For John RogersAssociate Director, Oil & Gas

• Written Notice of Emergency Changes (Form 9) - due within 5 days• Notice of Operations Suspension or Resumption (Form 9) - due prior to

implementation• Report of Water Encountered (Form 7) - due within 30 days after completion• Well Completion Report (Form 8) - due within 30 days after completion or

plugging

Approved By:

For John RogersAssociate Director, Oil &



plugging

Approved By:




plugging

Approved By:




plugging

Approved By:


RECEIVED: Jun. 10, 2014


DIVISION OF OIL, GAS, AND MINING

FORM 9

5.LEASE DESIGNATION AND SERIAL NUMBER: Fee

SUNDRY NOTICES AND REPORTS ON WELLS

Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATIONFOR PERMIT TO DRILL form for such proposals.

6. IF INDIAN, ALLOTTEE OR TRIBE NAME:

7.UNIT or CA AGREEMENT NAME:

1. TYPE OF WELL Oil Well

8. WELL NAME and NUMBER: Deep Creek 2-22-4-2E

2. NAME OF OPERATOR: CRESCENT POINT ENERGY U.S. CORP

9. API NUMBER: 43047541960000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext

9. FIELD and POOL or WILDCAT: UNDESIGNATED

4. LOCATION OF WELL FOOTAGES AT SURFACE: 0272 FNL 1968 FEL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: NWNE Section: 22 Township: 04.0S Range: 02.0E Meridian: U

COUNTY: UINTAH

STATE: UTAH

11.

CHECK APPROPRIATE BOXES TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA

TYPE OF SUBMISSION TYPE OF ACTION

NOTICE OF INTENTApproximate date work will start:

SUBSEQUENT REPORTDate of Work Completion:

SPUD REPORTDate of Spud:

6 /9 /2014

DRILLING REPORTReport Date:

ACIDIZE ALTER CASING CASING REPAIR

CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME

CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

DEEPEN FRACTURE TREAT NEW CONSTRUCTION

OPERATOR CHANGE PLUG AND ABANDON PLUG BACK

PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION

REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON

TUBING REPAIR VENT OR FLARE WATER DISPOSAL

WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION

WILDCAT WELL DETERMINATION OTHER OTHER:

12. DESCRIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertinent details including dates, depths, volumes, etc.

Crescent Point Energy US Corp spud the Deep Creek 2-22-4-2E withPete Martin Drilling Rig 11 on June 9, 2014 at 8am.

NAME (PLEASE PRINT) PHONE NUMBER Emily Kate DeGrasse 720 880-3644

TITLE Regulatory & Government Affairs Analyst

SIGNATURE N/A

DATE 6 /10 /2014

June 13, 2014

Sundry Number: 52074 API Well Number: 43047541960000Sundry Number: 52074 API Well Number: 43047541960000

FORM 9STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING Fee

SUNDRY NOTICES AND REPORTS ON WELLS 6. IF INDIAN, ALLOTTEE OR TRIBE NAME:

Do not use this form for proposals to drill new wells, significantly deepen existing wells belowcurrent bottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION 7.UNITor CA AGREEMENT NAME:

FOR PERMIT TO DRILL form for such proposals.

1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well Deep Creek 2-22-4-2E

2. NAME OF OPERATOR: 9. API NUMBER:CRESCENT POINT ENERGY U.S. CORP 43047541960000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext UNDESIGNATED

4. LOCATION OF WELL COUNTY:FOOTAGESATSURFACE: UINTAH

0272 FNL 1968 FELQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:

QtrlQtr: NWNE Section: 22 Township: 04.0S Range: 02.0E Meridian: U UTAH

CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE, REPORT, OR OTHER DATA


ACI DIZE ALTER CASING CASING REPAIR

NOTICE OF INTENT CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAMEApproximate date work will start:


SUBSEQUENT REPORTDate of Work Completion: DEEPEN FRACTURE TREAT NEW CONSTRUCTION


SPUD REPORT PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONDate of Spud:

6l9 /2 0 14 REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


DRILLING REPORTReport Date: WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION

WILDCATWELLDETERMINATION OTHER OTHER:


Crescent Point Energy US Corp spud the Deep Creek 2-22-4-2E with Accepted by thePete Martin Drilling Rig 11 on June 9, 2014 at 8am. Utah Division of

Oil, Gas and Mining

FORM 9819 ONLY

NAME (PLEASE PRINT) PHONE NUMBER TITLEEmily Kate DeGrasse 720 880-3644 Regulatory & Government Affairs Analyst

SIGNATURE DATEN/A 6/10/2014

RECEIVED: Jun. 10,

Sundry Number: 52074 API Well Number: 43047541960000

FORM 9STATE OF UTAH

























Oil, Gas and Mining

FORM 9819 ONLY



RECEIVED: Jun. 10,


FORM 9STATE OF UTAH

























Oil, Gas and Mining

FORM 9819 ONLY



RECEIVED: Jun. 10,


FORM 9STATE OF UTAH

























Oil, Gas and Mining

FORM 9819 ONLY



RECEIVED: Jun. 10,

RECEIVED: Aug. 25, 2014



FORM 9









9. API NUMBER: 43047541960000




COUNTY: UINTAH

STATE: UTAH

11.







8 /25 /2014












Please see attached drill report for Crescent Point Energy's Deep Creek2-22-4-2E, encompassing all drilling activities to date.

NAME (PLEASE PRINT) PHONE NUMBER Lauren MacMillan 303 382-6787

TITLE Regulatory Specialist

SIGNATURE N/A

DATE 8 /25 /2014

August 27, 2014


FORM 9STATE OF UTAH






















8/25/2014WILDCATWELLDETERMINATION OTHER OTHER:


Please see attached drill report for Crescent Point Energy's Deep Creek Accepted by the2-22-4-2E, encompassing all drilling activities to date. Utah Division of

Oil, Gas and Mining

FOR RECORD ONLYAugust 27, 2014

NAME (PLEASE PRINT) PHONE NUMBER TITLELauren MacMillan 303 382-6787 Regulatory Specialist


RECEIVED: Aug. 25,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Aug. 25,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Aug. 25,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Aug. 25,


Page 1/1

Well Name: DEEP CREEK 2-22-4-2E

Report Printed: 8/25/2014www.peloton.com

Daily Drilling Report

AFE Number

1753313USStart Depth (ftKB)

0.0End Depth (ftKB)

0.0Target Formation

WasatchTarget Depth (ftKB)

7,335.0Last Casing String

Conductor, 52.0ftKB

Daily ContactsJob Contact Mobile

Rigs

Capstar, 316Contractor

CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422

1, Gardner-Denver, PZ-9Pump #

1Pwr (hp)

750.0Rod Dia (in)

Liner Size (in) Stroke (in) Vol/Stk OR (b…

P (psi) Slow Spd Strokes (s… Eff (%)


2Pwr (hp)

750.0Rod Dia (in)



Mud Additive Amounts

DesField Est

(Cost/unit)Consume

d

Safety ChecksTime Type Des

WellboresWellbore Name KO MD (ftKB)

Original Hole

Report #: 1.0, DFS: -70.94

UWI/API

43-047-54196Surface Legal Location

2-22-4-2License #

FEESpud Date

6/9/2014 08:00Date TD Reached (wellbore) Rig Release Date

8/25/2014 06:00Ground Elevation (ft)

4,974.00Orig KB Elev (ft)

4,986.00Completion Type

Weather Temperature (°F) Road Condition Hole Condition

Operation At 6am

W.O.Air RigOperation Next 24hrs

24 Hr Summary

MIRU PETE MARTIN RIG #11 ,DRILL 52' KB 24" COND. HOLE,RUN & CEMENT 52' KB 16" COND. PIPE,Cmt.To Surf. With ReadyMix RDMO SPUD @08:00 6/09/2014

Time LogStart Time End Time Dur (hr)

Cum Dur (hr)

Aty Code Activity Com

Mud Checks

<depth>ftKB, <dttm>Type Time Depth (ftKB) Density (lb/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (lbf/100ft²)

Gel 10 sec (lbf/100ft²) Gel 10 min (lbf/100ft²) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%)

MBT (lb/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (lbf/100ft²)

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl)

Drill Strings

BHA #<stringno>, <des>Bit Run Drill Bit Length (ft) IADC Bit Dull TFA (incl Noz) (in²) BHA ROP …

Nozzles (1/32") String Length (ft) Max Nominal OD (in)

String Components

Comment

Drilling Parameters

Wellbore Start (ftKB)End Depth

(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf

)RPM (rpm) SPP (psi)

Drill Str Wt (1000lbf)

PU Str Wt (1000lbf) Drill Tq

Depth Progress:

Report for: 6/9/2014


Og Daily Drilling Report Report for: 6/9/2014

c"""YW11 ??MI Report #: 1.0, DFS: -70.94

Well Name: DEEP CREEK 2-22-4-2EDepth Progress:

UWl/API Surface Legal Location License # AFE Number43-047-54196 2-22-4-2 FEE 1753313USSpud Date Date TD Reached (wellbore) Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) Start Depth (ftKB) End Depth (ftKB)

6/9/2014 08:00 8/25/2014 06:00 4,974.00 4,986.00 0.0 0.0Completion Type Target Formation Target Depth (ftKB)

Wasatch 7,335.0Weather Temperature (°F) Road Condition Hole Condition Last Casing String

Conductor, 52.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsW.O.Air Rig

Job Contact Mobile24 Hr Summary

MIRU PETE MARTIN RIG #11 ,DRILL 52' KB 24" COND. HOLE,RUN & CEMENT 52' KB 16" COND. PIPE,Cmt.ToSurf. With ReadyMix RDMO SPUD @08:006/09/2014 Rigs

Time Log Capstar, 316

Start Cum Dur AtyColiticului Rig Number

Time End Time Dur (hr) (hr) Code Activity com Capstar 316Rig Supervisor Phone Mobile

Mud ChecksJAKE 307-315-5422

<depth>ftKB, <dttm>1, Cardner-Derr.or, PZ-0

Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Overnde (cP) YP OR (Ibf/100ft2Piimp u Pwr (hp)

750.0Rod Dia (in)

Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%)i inar Rivo (in) Stroke (in) Vol/Stk OR (b...

MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2P (poi) Slow Spd Strokes (s... Eff (%)

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) 2, Cardner-Den.or, PZ-0Pump# Pwr(hp) RodDia(in)

. 2 750.0Drill Strmgs Limer Size (in) Stroke (in) Vol/Stk OR (b...BHA #<stringno>, <des>

Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP.. P (psi) Slow Spd Strokes (s... Eff (%)

Nozzles (1/32") String Length (ft) Max Nominal OD (in)Mud Additive Amounts

String Components Field Est ConsumeDes (Cost/unit) d

Comment

Safeb CherirsDrilling Parameters Time Type Des

CumDrill WOB

End Depth Cum Depth Time Int ROP Q Flow (1000lbf RPM Drill Str Wt PU Str WtWellbore Start (ftKB) (ftKB) (ft) (hr) (ft/hr) (gpm) ) (rpm) SPP (psi) (1000lbf) (1000lbf) Drill Tq Wellbores

Wellbore Name KO MD (ftKB)

Oiiyiiial i iule

www.peloton.com Page 1/1 Report Printed:



c"""YW11 ??MI Report #: 1.0, DFS: -70.94














750.0Rod Dia (in)








Comment


CumDrill WOB



Oiiyiiial i iule




c"""YW11 ??MI Report #: 1.0, DFS: -70.94














750.0Rod Dia (in)








Comment


CumDrill WOB



Oiiyiiial i iule




c"""YW11 ??MI Report #: 1.0, DFS: -70.94














750.0Rod Dia (in)








Comment


CumDrill WOB



Oiiyiiial i iule



Page 1/1




AFE Number


0.0End Depth (ftKB)

0.0Target Formation



Surface, 1,012.0ftKB


Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422


1Pwr (hp)

750.0Rod Dia (in)




2Pwr (hp)

750.0Rod Dia (in)




DesField Est

(Cost/unit)Consume

d



Original Hole

Report #: 2.0, DFS: -67.94

UWI/API


2-22-4-2License #

FEESpud Date





Weather Temperature (°F) Road Condition Hole Condition

Operation At 6am

W.O.Drlg RigOperation Next 24hrs

24 Hr Summary

MIRU Pro Petro Rig #10,Drill 1020' KB 12 1/4" Surface hole,R/U & run 1000' KB 8 5/8" 24# surface CSG,Cement W/675 sks 15.8 ppg 1.15 cuft/sk yield cement,30 bbls good cement T/Surf,cement stayed @ Surf.


Cum Dur (hr)


Mud Checks





Drill Strings



String Components

Comment

Drilling Parameters


(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Depth Progress:




c"""YW11 ??MI Report #: 2.0, DFS: -67.94





Surface, 1,012.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsW.O.Drlg Rig


MIRU Pro Petro Rig #10,Drill 1020' KB 12 1/4" Surface hole,R/U & run 1000' KB 8 5/8" 24#surface CSG,CementWl675 sks 15.8 ppg 1.15 cuft/sk yield cement,30 bbls good cement T/Surf,cement stayed @Surf. Rigs







750.0Rod Dia (in)








Comment


CumDrill WOB



Oiiyiiial i iule




c"""YW11 ??MI Report #: 2.0, DFS: -67.94














750.0Rod Dia (in)








Comment


CumDrill WOB



Oiiyiiial i iule




c"""YW11 ??MI Report #: 2.0, DFS: -67.94














750.0Rod Dia (in)








Comment


CumDrill WOB



Oiiyiiial i iule




c"""YW11 ??MI Report #: 2.0, DFS: -67.94














750.0Rod Dia (in)








Comment


CumDrill WOB



Oiiyiiial i iule



Page 1/1




AFE Number


0.0End Depth (ftKB)

0.0Target Formation





Floyd Mitchell 435-823-3608

Brent Bascom 970-250-2928

Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422


1Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)

9.02Vol/Stk OR (b…

0.079P (psi) Slow Spd Strokes (s… Eff (%)


2Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




DesField Est

(Cost/unit)Consume

d



Original Hole

Report #: 3.0, DFS: -0.94

UWI/API


2-22-4-2License #

FEESpud Date





Weather Temperature (°F)

73.0Road Condition

GoodHole Condition

Operation At 6am

Rig DownOperation Next 24hrs

M.IR.U.,Pressure Test BOP, Pick Up Steerable BHA , Trip In Hole,Drill Out 8 5/8'' Shoe Track, Drill 7 7/8'' Production Hole F/ 1020'.

24 Hr Summary

Rig Down


Cum Dur (hr)


00:30 06:00 5.50 5.50 1 RIGUP & TEARDOWN

Rig Down

Mud Checks





Drill Strings



String Components

Comment

Drilling Parameters


(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Depth Progress:




c"""YW11 ??MI Report #: 3.0, DFS: -0.94





73.0 Good Surface, 1,012.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsRig Down M.lR.U.,Pressure Test BOP, Pick Up Steerable BHA , Trip

In Hole,Drill Out 8 5/8" Shoe Track, Drill 7 7/8" ProductionJob Contact Mobile

Hole F/ 1020'. Floyd Mitchell 435-823-3608

24 Hr Summary

Rig Down Brent Bascom 970-250-2928

Time LogStart Cum Dur Aty OgSTime End Time Dur (hr) (hr) Code Activity Com apstar, 1ß

00:30 06:00 5.50 5.50 1 RIGUP & Rig Down Contractor Rig NumberTEARDOWN Capstar 316

Mud CheckS Rig Supervisor Phone Mobile

<depth>ftKB, <dttm> JAKE 307-315-5422

Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Overnde (cP) YP OR (Ibf/100ft2) I, Gar drier -Deri ver, FI-3Pump# Pwr(hp) RodDia(in)

Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) I 750.0Liner Size (in) Stroke (in) Vol/Stk OR (b...

MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2) 6 9.02 0.079P (psi) Slow Spd Strokes (s... Eff (%)


2, Gardner-Denver, PZ-9Drill StringS Pump# Pwr (hp) Rod Dia (in)

BHA #<stringno>, <des> 2 750.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP... Lilici 3ize (iii) Stroke (in) Vol/Stk OR (b...

6 9.02 0.079Nozzles (1/32") String Length (ft) Max Nominal OD (in) F (µai) Slow Spd Strokes (s... Eff (%)

String Components Mud Additive AmountsField Est Consume

Comment Des (Cost/unit) d

Drilling ParametersCafet, Checla

CumDrill WOB Time Type Des

End Depth Cum Depth Time Int ROP Q Flow (1000lbf RPM Drill Str Wt PU Str WtWellbore Start (ftKB) (ftKB) (ft) (hr) (ft/hr) (gpm) ) (rpm) SPP (psi) (1000lbf) (1000lbf) Drill Tq


Original Hole




c"""YW11 ??MI Report #: 3.0, DFS: -0.94








24 Hr Summary



















Original Hole




c"""YW11 ??MI Report #: 3.0, DFS: -0.94








24 Hr Summary



















Original Hole




c"""YW11 ??MI Report #: 3.0, DFS: -0.94








24 Hr Summary



















Original Hole



Page 1/1




AFE Number


1,020.0End Depth (ftKB)

1,198.0Target Formation







Doug Hackford 970-640-3882

Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422


1Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




2Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




DesField Est

(Cost/unit)Consume

d

Engineering 450.00 1.0

Rental 50.00 1.0



Original Hole

Report #: 4.0, DFS: 0.06

UWI/API


2-22-4-2License #

FEESpud Date





Weather

Cloudy/ RainTemperature (°F)

73.0Road Condition

GoodHole Condition

GoodOperation At 6am

Drilling @ 1198Operation Next 24hrs

Drilling W MWD Surveys24 Hr Summary

M.IR.U.,Pressure Test BOP, Pick Up Steerable BHA , Trip In Hole,Drill Out 8 5/8'' Shoe Track, Drill 7 7/8'' Production Hole F/ 1020' to 1198' ( 178' @118.6 fph)


Cum Dur (hr)


06:00 12:30 6.50 6.50 1 RIGUP & TEARDOWN

Move In/Rig Up

12:30 16:30 4.00 10.50 14 NIPPLE UP B.O.P

Nipple Up BOP

16:30 21:00 4.50 15.00 15 TEST B.O.P Pressure Test BOP, Pipe Rams, Blind Rams, Safety Valves, Lines, Choke Manifold 3000 PSI/10 Min. Annular BOP 1500 Psi/10 Min., Casing 1500 Psi/ 30 Min.

21:00 22:30 1.50 16.50 22 OPEN Rig Down Rotary Lock, Re-torque Splined Sub, Re-assemble

22:30 00:00 1.50 18.00 14 NIPPLE UP B.O.P

Nipple up Rotating Head & Flowline

00:00 01:30 1.50 19.50 6 TRIPS Pick up Directional Tools, Trip In Hole W/ BHA

01:30 03:00 1.50 21.00 9 CUT OFF DRILL LINE

Cut & Slip 90' Drilling Line

03:00 03:30 0.50 21.50 6 TRIPS Trip In Hole, Tag cement Top @ 911'

03:30 04:30 1.00 22.50 Drill Cement & Float Equiptment 911' to 1020'

04:30 06:00 1.50 24.00 2 DRILL ACTUAL

Drill 7 7/8'' Production Hole f/ 1020' to 1198' (178' @ 118.7 fphj)

Mud Checks

1,020.0ftKB, 8/19/2014 06:00Type

DAPTime

06:00Depth (ftKB)

1,020.0Density (lb/gal)

8.40Funnel Viscosity (s/qt)

27PV Override (cP) YP OR (lbf/100ft²)

Gel 10 sec (lbf/100ft²) Gel 10 min (lbf/100ft²) Filtrate (mL/30min) Filter Cake (1/32") pH

8.0Sand (%) Solids (%)

1.0MBT (lb/bbl) Alkalinity (mL/mL) Chlorides (mg/L)

5,000.000Calcium (mg/L) Pf (mL/mL)

0.1Pm (mL/mL) Gel 30 min (lbf/100ft²)


Drill Strings

BHA #1, SteerableBit Run

1Drill Bit

7 7/8in, MDi616, JH8919 ( PN 65833AD102)Length (ft)

1.00IADC Bit Dull

0-1-CT-G----TDTFA (incl Noz) (in²)

1.18BHA ROP …

70.6Nozzles (1/32")

16/16/16/16/16/16String Length (ft)

556.93Max Nominal OD (in)

6.500String Components

Smith MDi616, Mud Motor, UBHO, NMDC, Drill Collar, HWDPComment

Smith MDi616 (Newsco MM,6.5'' 7/8, 3.3 Stg. .16 Rev. 1.50° Bend)(6.375''x2.5''UBHO) (1-6.375''x2.375''NMDC)(6-6.125''x 2.375'' DC)(10-4.5'' HWDP)Drilling Parameters


(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 1,020.0 1,198.0 178.00 1.50 118.7 394 16 50 830.0 34 50

Depth Progress: 178.00



Og Daily Drilling Report Report for: 8/19/2014cresygr oi5 Report#: 4.0, DFS: 0.06

Well Name: DEEP CREEK 2-22-4-2EDepth Progress: 178.00


6/9/2014 08:00 8/25/2014 06:00 4,974.00 4,986.00 1,020.0 1,198.0Completion Type Target Formation Target Depth (ftKB)


Cloudy/ Rain 73.0 Good Good Surface, 1,012.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDrilling @ 1198 Drilling W MWD Surveys


M.lR.U.,Pressure Test BOP, Pick Up Steerable BHA , Trip In Hole,Drill Out 8 5/8" Shoe Track, Drill 7 7/8" Production Floyd Mitchell 435-823-3608

Hole F/ 1020' to 1198' ( 178' @118.6fph)

Time L3g Brent Bascom 970-250-2928

Start Cum Dur AtyTime End Time Dur (hr) (hr) Code Activity Com Doug Hackford 970-640-3882

06:00 12:30 6.50 6.50 1 RIGUP & Move In/Rig UpTEARDOWN Rigs

12:30 16:30 4.00 10.50 14 NIPPLE UP Nipple Up BOP Capstar, 316B.O.P Contractor Rig Number

16:30 21:00 4.50 15.00 15 TEST B.O.P Pressure Test BOP, Pipe Rams, Blind Rams, Safety Valves, Capstar 316Lines, Choke Manifold 3000 PSI/10 Min. Annular BOP 1500 Rig Supervisor Phone Mobile

Psi/10 Min., Casing 1500 Psil 30 Min. JAKE 307-315-5422

21:00 22:30 1.50 16.50 22 OPEN Rig Down Rotary Lock, Re-torque Splined Sub, Re-assemble I, Gaidilei-Delivel, FT-3Piimpu Pwr(hp) RodDia(in)

22:30 00:00 1.50 18.00 14 NIPPLE UP Nipple up Rotating Head & Flowline 1 750.0B.O.P Liner Size (in) Stroke (in) Vol/Stk OR (b...

00:00 01:30 1.50 19.50 6 TRIPS Pick up Directional Tools, Trip In Hole W/ BHA 6 9.02 0.079

01:30 03:00 1.50 21.00 9 CUT OFF Cut & Slip 90' Drilling Line F (e i) SlowSpd Strokes (s... Eff (%)

DRILL LINE2, Gardner Denver, PT 9

03:00 03:30 0.50 21.50 6 TRIPS Trip In Hole, Tag cement Top @911' Pump# Pwr(hp) Rod Dia (in)

03:30 04:30 1.00 22.50 Drill Cement & Float Equiptment 911' to 1020' 2 750.004:30 06:00 1.50 24.00 2 DRILL Drill 7 7/8" Production Hole f/ 1020' to 1198' (178' @ 118.7 fphj) Liner Size (in) Stroke (in) Vol/Stk OR (b...

ACTUAL 6 9.02 0.079P (poi) Slow Spd Strokes (s... Eff (%)

Mud Checks1,020.0ftKB, 8/19/2014 06:00 IVilidAdditive AmnimtsType Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

DAP 06:00 1,020.0 8.40 27 Des ( ot/uEnst Consume

Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) Engineering 450.00 1.08.0 1.0

MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2 REntal 50.00 1.05,000.000 0.1 Safety Checke

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl)Time Type Des

Drill StringsBHA #1, Steerable WellboresBit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP..- Wellbore Name KO MD (ftKB)1 7 7/8in, MDi616, JH8919 (PN 65833AD102) 1.00 0-1-CT-G----TD 1.18 70.6 Original HoleNozzles (1/32") String Length (ft) Max Nominal OD (in)

16/16/16/16/16/16 556.93 6.500String Components


Smith MDi616 (Newsco MM,6.5" 7/8, 3.3 Stg. .16 Rev. 1.50° Bend)(6.375"x2.5"UBHO) (1-6.375"x2.375"NMDC)(6-6.125"x 2.375" DC)(10-4.5" HWDP)Drilling Parameters

CumDrill WOB


Original Hole 1,020.0 1,198.0 178.00 1.50 118.7 394 16 50 830.0 34 50











Hole F/ 1020' to 1198' ( 178' @118.6fph)













03:30 04:30 1.00 22.50 Drill Cement & Float Equiptment 911' to 1020' 2 750.0

04:30 06:00 1.50 24.00 2 DRILL Drill 7 7/8" Production Hole f/ 1020' to 1198' (178' @ 118.7 fphj) Liner Size (in) Stroke (in) Vol/Stk OR (b...





MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2 REntal 50.00 1.0

5,000.000 0.1 Safety CheckeWhole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl)

Time Type Des





CumDrill WOB


Original Hole 1,020.0 1,198.0 178.00 1.50 118.7 394 16 50 830.0 34 50











Hole F/ 1020' to 1198' ( 178' @118.6fph)





















Time Type Des





CumDrill WOB


Original Hole 1,020.0 1,198.0 178.00 1.50 118.7 394 16 50 830.0 34 50











Hole F/ 1020' to 1198' ( 178' @118.6fph)





















Time Type Des





CumDrill WOB


Original Hole 1,020.0 1,198.0 178.00 1.50 118.7 394 16 50 830.0 34 50



Page 1/1




AFE Number











Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422


1Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)


0.079P (psi)

830.0Slow Spd

NoStrokes (s…

125Eff (%)

95


2Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




DesField Est

(Cost/unit)Consume

d

DAP 35.00 10.0


Liqui Drill 135.00 1.0

Rental 50.00 1.0

Tax 1.00 34.0



Original Hole

Report #: 5.0, DFS: 1.06

UWI/API


2-22-4-2License #

FEESpud Date





Weather

OVER CAST BUT NO RAINTemperature (°F)

78.0Road Condition

GoodHole Condition


DRILLING @ 3650'Operation Next 24hrs

KEEP DRILLING24 Hr Summary

DRILLING 7 7/8 PROD. HOLE F/ 1198 TO 3650 (96 FPH ) BBG 169-378 UNITS CONNS 183-262 PEAK GAS 381 UNITS @ 3466' CURRENTLY DRILLING 60% SH 20% CLAYSTONE & 20% DOLSTONE


Cum Dur (hr)


06:00 16:30 10.50 10.50 2 DRILL ACTUAL

DRILLING & SLIDING F/ 1198 TO 2395 ( 114 FPH ) 14 K ON BIT 395 GAL 117 TOTAL RPMS NO LOSSES

16:30 17:00 0.50 11.00 7 LUBRICATE RIG

RIG SERVICE

17:00 06:00 13.00 24.00 2 DRILL ACTUAL

DRILLING & SLIDING F/ 2395 TO 3650 ( 97 FPH ) 14 K ON BIT 395 GAL 117 TOTAL RPMS NO LOSSES

Mud Checks

1,700.0ftKB, 8/20/2014 10:30Type

Water BaseTime

10:30Depth (ftKB)

1,700.0Density (lb/gal) Funnel Viscosity (s/qt)

27PV Override (cP) YP OR (lbf/100ft²)

Gel 10 sec (lbf/100ft²) Gel 10 min (lbf/100ft²) Filtrate (mL/30min) Filter Cake (1/32") pH

9.0Sand (%)

0.0Solids (%)

MBT (lb/bbl) Alkalinity (mL/mL) Chlorides (mg/L)

1,800.000Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (lbf/100ft²)


Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

70.6Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 1,198.0 3,650.0 2,630.00

25.00 104.3 394 16 55 1,150.0 71 73 10,700.0

Depth Progress: 2,452.00



< p Daily Drilling Report Report for: 8/20/2014cresygr oi5 Report#: 5.0, DFS:1.06

Well Name: DEEP CREEK 2-22-4-2EDepth Progress: 2,452.00




OVER CAST BUT NO RAIN 78.0 Good Good Surface, 1,012.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDRILLING @3650' KEEP DRILLING


DRILLING 7 7/8 PROD. HOLE F/ 1198 TO 3650 (96 FPH ) BBG 169-378 UNITS CONNS 183-262 PEAK GAS 381 Floyd Mitchell 435-823-3608

UNITS @3466' CURRENTLY DRILLING 60% SH 20% CLAYSTONE & 20% DOLSTONE

Time Log Brent Bascom 970-250-2928


06:00 16:30 10.50 10.50 2 DRILL DRILLING & SLIDING F/ 1198 TO 2395 ( 114 FPH ) 14 K ONACTUAL BIT 395 GAL 117 TOTAL RPMS NO LOSSES Rigs

16:30 17:00 0.50 11.00 7 LUBRICATE RIG SERVICE Capstar, 316RIG Contractor Rig Number

17:00 06:00 13.00 24.00 2 DRILL DRILLING & SLIDING F/2395 TO 3650 (97 FPH ) 14 K ON BIT Capstar 316ACTUAL 395 GAL 117 TOTAL RPMS NO LOSSES Rig Supervisor Phone Mobile


1, Cardner-Denver, PZ-01,700.0ftKB, 8/20/2014 10:30 Piimpu Pwr(hp) RodDia(in)Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

1 750.0Water Base 10:30 1,700.0 27 I iner Ri7e (in) Stroke (in) Vol/Stk OR (b...Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) 6 9.02 0.079

9.0 0.0 P (poi) Slow Spd Strokes (s... Eff (%)MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2)

830.0 No 125 951,800.000

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) 2, Cardner-Denver, PZ-0Pump# Pwr(hp) RodDia(in)

. 2 750.0Drill Strmgs Limer Size (in) Stroke (in) Vol/Stk OR (b...BHA #1, Steerable 6 9.02 0.079Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP.. P (psi) Slow Spd Strokes (s... Eff (%)1 7 7/8in, MDi616, JH8919 (PN 65833AD102) 1.00 0-1-CT-G----TD 1.18 70.6Nozzles (1/32") String Length (ft) Max Nominal OD (in)

16/16/16/16/16/16 556.93 6.500 Mud Additive AmountsString Components Field Est Consume

Smith MDi616, Mud Motor, UBHO, NMDC, Drill Collar, HWDP Des (Cost/unit) d

CommentDAP 35.00 10.0

Smith MDi616 (Newsco MM,6.5" 7/8, 3.3 Stg. .16 Rev. 1.50° Bend)(6.375"x2.5"UBHO) (1-6.375"x2.375"NMDC)(6- Engineering 450.00 1.06.125"x 2.375" DC)(10-4.5" HWDP) Liqui Drill 135.00 1.0Drilling Parameters Rental 50.00 1.0

CumDrill WOB Tax 1.00 34.0

End Depth Cum Depth Time Int ROP Q Flow (1000lbf RPM Drill Str Wt PU Str WtWellbore Start (ftKB) (ftKB) (ft) (hr) (ft/hr) (gpm) ) (rpm) SPP (psi) (1000lbf) (1000lbf) Drill Tq Safety Checks

Original Hole 1,198.0 3,650.0 2,630.0 25.00 104.3 394 16 55 1,150.0 71 73 10,70 Time Type Des

O 0.0


Original Hole


















1, Cardner-Denver, PZ-01,700.0ftKB, 8/20/2014 10:30

Piimpu Pwr(hp) RodDia(in)Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

1 750.0Water Base 10:30 1,700.0 27

I iner Ri7e (in) Stroke (in) Vol/Stk OR (b...Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) 6 9.02 0.079

9.0 0.0P (poi) Slow Spd Strokes (s... Eff (%)

MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2)830.0 No 125 95

1,800.000Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) 2, Cardner-Denver, PZ-0

Pump# Pwr(hp) RodDia(in)









O 0.0


Original Hole




















1 750.0Water Base 10:30 1,700.0 27














O 0.0


Original Hole




















1 750.0Water Base 10:30 1,700.0 27














O 0.0


Original Hole



Page 1/1




AFE Number











Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422


1Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




2Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




DesField Est

(Cost/unit)Consume

d

Aluminum Stear. 130.00 1.0

Brine 7.50 300.0

DAP 35.00 50.0


Pallet 20.00 3.0

Rental 50.00 1.0

Sawdust 4.50 20.0

Sea Mud 15.50 130.0

Shrink Wrap 20.00 3.0

Tax 1.00 281.0

Trucking 1.00 1,200.0



Original Hole

Report #: 6.0, DFS: 2.06

UWI/API


2-22-4-2License #

FEESpud Date





Weather

NICETemperature (°F)

88.0Road Condition

GoodHole Condition


DRILLING @ 4975'Operation Next 24hrs

DRILL PROD HOLE24 Hr Summary

DRILLING 7 7/8 PROD HOLE F/ 3650 TO 4975 ( 56 FPH ) BBG 176-432 UNITS CONN 832-1810 PEAK 2656 UNITS @ 4210' TOPPED MAHOGANY BENCH @ 3779' CURRENT DRILLING 40% SH 30% SILT 20% DOLSTN & 10% CLAYSTONE ( NOTE DRILLING IN TARGET )


Cum Dur (hr)


06:00 16:00 10.00 10.00 2 DRILL ACTUAL

DRILLING F/ 3650 TO 4363 ( 70 FPH ) 14-16 K ON BIT 390 GAL 117 TOTAL RPMS LOST 132 BBL TO SEEPAGE

16:00 16:30 0.50 10.50 7 LUBRICATE RIG

RIG SERVICE

16:30 06:00 13.50 24.00 2 DRILL ACTUAL


Mud Checks

4,020.0ftKB, 8/21/2014 11:00Type

Water BaseTime

11:00Depth (ftKB)



31PV Override (cP)

4.0YP OR (lbf/100ft²)

4.000Gel 10 sec (lbf/100ft²)

2.000Gel 10 min (lbf/100ft²)

5.000Filtrate (mL/30min) Filter Cake (1/32") pH

8.5Sand (%) Solids (%)




Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

70.6Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 3,650.0 4,975.0 3,955.00

48.50 56.4 394 16 58 1,150.0 103 105 10,100.0









NICE 88.0 Good Good Surface, 1,012.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDRILLING @4975' DRILL PROD HOLE


DRILLING 7 7/8 PROD HOLE F/ 3650 TO 4975 ( 56 FPH ) BBG 176-432 UNITS CONN 832-1810 PEAK 2656 UNITS Floyd Mitchell 435-823-3608

@4210' TOPPED MAHOGANY BENCH @ 3779' CURRENT DRILLING 40% SH 30% SILT 20% DOLSTN & 10%CLAYSTONE ( NOTE DRILLING IN TARGET ) Brent Bascom 970-250-2928

Time LogStart Cum Dur Aty Doug Hackford 970-640-3882Time End Time Dur (hr) (hr) Code Activity Com

06:00 16:00 10.00 10.00 2 DRILL DRILLING F/ 3650 TO 4363 (70 FPH ) 14-16 K ON BIT 390 GAL RigsACTUAL 117TOTALRPMS LOST132BBLTOSEEPAGE

16:00 16:30 0.50 10.50 7 LUBRICATE RIG SERVICE Contractor Rig NumberRIG Capstar 316

16:30 06:00 13.50 24.00 2 DRILL DRILLING F/ 4363 TO 4975 ( 45 FPH ) 14-16 K ON BIT 390 GAL Rig Supervisor Phone Mobile

ACTUAL 117 TOTAL RPMS LOST 173 BBL TO SEEPAGE JAKE 307-315-5422

Mud Checks I, Gardner-Denver, PZ-9

4,020.0ftKB, 8/21/2014 11:00uliiµ

" Pwr (hp)

750.0Rod Dia (in)

Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2Liner Size (in) Stroke (in) Vol/Stk OR (b...

Water Base 11:00 4,020.0 9.20 31 4.0 4.000 6 9.02 0.079Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%)

P (psi) Slow Spd Strokes (s... Eff (%)2.000 5.000 8.5 5.2

MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2)

32,000.000 2, Gardner-Denver, PZ-9

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Fuliiµ " Pwr (hp) Rod Dia (in)

2 750.0

Drill StringSLilici 3ize (iii) Stroke (in) Vol/Stk OR (b...

6 9.02 0.079BHA #1, Steerable P (psi) Slow Spd Strokes (s... Eff (%)Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...

1 7 7/8in, MDi616, JH8919 (PN 65833AD102) 1.00 0-1-CT-G----TD 1.18 70.6Nozzles (1/32") String Length (ft) Max Nominal OD (in) Faud Ad ditive Am- unta16/16/16/16/16/16 556.93 6.500 Field Est Consume

Des (Cost/unit) dString Components

Smith MDi616, Mud Motor, UBHO, NMDC, Drill Collar, HWDP Aluminum Stear. 130.00 1.0

Comment anne 7.50 300.0Smith MDi616 (Newsco MM,6.5" 7/8, 3.3 Stg. .16 Rev. 1.50° Bend)(6.375"x2.5"UBHO) (1-6.375"x2.375"NMDC)(6- DAP 35.00 50.06.125"x 2.375" DC)(10-4.5" HWDP) Engineering 450.00 1.0Drilling Parameters

Pallét 20.00 3.0CumDrill WOB Rental 50.00 1.0

End Depth Cum Depth Time Int ROP Q Flow (1000lbf RPM Drill Str Wt PU Str WtWellbore Start (ftKB) (ftKB) (ft) (hr) (ft/hr) (gpm) ) (rpm) SPP (psi) (1000lbf) (1000lbf) Drill Tq Sawdust 4.50 20.0

Original Hole 3,650.0 4,975.0 3,955.0 48.50 56.4 394 16 58 1,150.0 103 105 10,10 Sea Mud 15.50 130.00 0.0 Shrink Wrap 20.00 3.0

Tax 1.00 281.0Trucking 1.00 1,200.

O



Original Hole


















4,020.0ftKB, 8/21/2014 11:00uliiµ

" Pwr (hp)

750.0Rod Dia (in)







2 750.0



1 7 7/8in, MDi616, JH8919 (PN 65833AD102) 1.00 0-1-CT-G----TD 1.18 70.6Nozzles (1/32") String Length (ft) Max Nominal OD (in) Faud Ad ditive Am- unta

16/16/16/16/16/16 556.93 6.500 Field Est ConsumeDes (Cost/unit) d

String Components






Tax 1.00 281.0

Trucking 1.00 1,200.O



Original Hole


















4,020.0ftKB, 8/21/2014 11:00uliiµ

" Pwr (hp)

750.0Rod Dia (in)







2 750.0





String Components






Tax 1.00 281.0




Original Hole


















4,020.0ftKB, 8/21/2014 11:00uliiµ

" Pwr (hp)

750.0Rod Dia (in)







2 750.0





String Components






Tax 1.00 281.0




Original Hole



Page 1/1




AFE Number











Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422


1Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




2Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




DesField Est

(Cost/unit)Consume

d

DAP 35.00 22.0


Hole Seal 21.00 67.0

Pallet 20.00 9.0

Rental 50.00 1.0

Sawdust 4.50 168.0

Sea Mud 15.50 36.0


Tax 1.00 269.0



Original Hole

Report #: 7.0, DFS: 3.06

UWI/API


2-22-4-2License #

FEESpud Date





Weather

RAINYTemperature (°F)

74.0Road Condition

WETHole Condition


DRILLING @ 6350' @ 50 FPHOperation Next 24hrs

DRILL PROD HOLE ON TO T.D.24 Hr Summary

DRILL F/ 4975 TO 6350 ( 58 FPH ) BBG 123-228 UNITS CONNS 161-248 PEAK GAS 1582 @ 5790' TOPPED TGR3 @ 4796/ DOUGLAS CREEK 5538' DLACK SHALE @ 5035' DRILLING 50% SH & 50% CLYST


Cum Dur (hr)


06:00 16:30 10.50 10.50 2 DRILL ACTUAL


16:30 17:00 0.50 11.00 7 LUBRICATE RIG

SERVICE RIG

17:00 06:00 13.00 24.00 2 DRILL ACTUAL

DRILLING F/5688 TO 6350 ( 51 FPH ) 16-19 K ON BIT 390 GAL 117 TOTAL RPMS LOST 269 BBL TO SEEPAGE

Mud Checks

5,432.0ftKB, 8/22/2014 06:00Type

Water BaseTime

06:00Depth (ftKB)



32PV Override (cP)


Gel 10 sec (lbf/100ft²)

3.000Gel 10 min (lbf/100ft²)

6.000Filtrate (mL/30min) Filter Cake (1/32") pH

8.5Sand (%)

0.3Solids (%)




Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

70.6Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 4,975.0 6,350.0 5,330.00

72.00 58.5 394 17 58 1,360.0 129 133 10,100.0




< p Daily Drilling Report Report for: 8/22/2014cresygr oi5 Report#:7.0, DFS: 3.06





RAINY 74.0 WET Good Surface, 1,012.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDRILLING @6350' @50 FPH DRILL PROD HOLE ON TO T.D.

Job Contact Mobile2D4RHrLsLumF4975 TO 6350 ( 58 FPH ) BBG 123-228 UNITS CONNS 161-248 PEAK GAS 1582 @5790' TOPPED TGR3 Floyd Mitchell 435-823-3608

@4796/ DOUGLAS CREEK 5538' DLACK SHALE @5035' DRILLING 50% SH & 50% CLYST



06:00 16:30 10.50 10.50 2 DRILL DRILLING F/ 4975 TO 5688 (68 FPH ) 14-16 K ON BIT 390 GALACTUAL 117 TOTAL RPMS LOST 165 BBL TO SEEPAGE Rigs

16:30 17:00 0.50 11.00 7 LUBRICATE SERVICE RIG Capstar, 316RIG Contractor Rig Number

17:00 06:00 13.00 24.00 2 DRILL DRILLING F/5688 TO 6350 ( 51 FPH ) 16-19 K ON BIT 390 GAL Capstar 316ACTUAL 117 TOTAL RPMS LOST 269 BBL TO SEE PAGE Rig Supervisor Phone Mobile


1, Cardner-Denver, PZ-05,432.0ftKB, 8/22/2014 06:00 Piimpu Pwr(hp) RodDia(in)Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

1 750.0Water Base 06:00 5,432.0 9.30 32 4.0 i inar Rivo (in) Stroke (in) Vol/Stk OR (b...Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) 6 9.02 0.079

3.000 6.000 8.5 0.3 7.7 P (poi) Slow Spd Strokes (s... Eff (%)MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2)







Smith MDi616 (Newsco MM,6.5" 7/8, 3.3 Stg. .16 Rev. 1.50° Bend)(6.375"x2.5"UBHO) (1-6.375"x2.375"NMDC)(6- Engineering 450.00 1.06.125"x 2.375" DC)(10-4.5" HWDP) Hole Seal 21.00 67.0Drilling Parameters Pallet 20.00 9.0

CDrWOB Rental 50.00 1.0

End Depth Cum Depth Time Int ROP Q Flow (1000lbf RPM Drill Str Wt PU Str Wt Sawdust 4.50 168.0Wellbore Start (ftKB) (ftKB) (ft) (hr) (ft/hr) (gpm) ) (rpm) SPP (psi) (1000lbf) (1000lbf) Drill Tq


Tax 1.00 269.0



Original Hole



















1 750.0Water Base 06:00 5,432.0 9.30 32 4.0

i inar Rivo (in) Stroke (in) Vol/Stk OR (b...Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) 6 9.02 0.079

3.000 6.000 8.5 0.3 7.7P (poi) Slow Spd Strokes (s... Eff (%)












Tax 1.00 269.0



Original Hole



















1 750.0Water Base 06:00 5,432.0 9.30 32 4.0














Tax 1.00 269.0



Original Hole



















1 750.0Water Base 06:00 5,432.0 9.30 32 4.0














Tax 1.00 269.0



Original Hole



Page 1/1




AFE Number











Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422


1Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




2Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




DesField Est

(Cost/unit)Consume

d

Brine 7.50 300.0

DAP 35.00 40.0



Pallet 20.00 7.0

Rental 50.00 1.0

Sawdust 4.50 130.0

Sea Mud 15.50 180.0


Tax 1.00 380.0



Original Hole

Report #: 8.0, DFS: 4.06

UWI/API


2-22-4-2License #

FEESpud Date





Weather

NICETemperature (°F)

71.0Road Condition

MUDDYHole Condition


TRIPPING OUT @ 2500'Operation Next 24hrs

LOG WELL & RUN 5.5 PROD CASING24 Hr Summary

DRILL F/ 6350 TO 7335 CIRC & COND HOLE SPOT 10.2# KILL PILL UP TO 3500' POOH TO 3500 CIRC CLEAN POOH BBG 48-67 UNITS CONNS 129-173 PEAK GAS 3082 UNIT @ 6590' LAST SAMPLE WAS 40% CLAYSTONE 30% SHALE 30% SANDSTONE TOPPED BLACK SHALE @ 6035' CASTLE PEAK @ 6285' UTELAND BUTTE @ 6580 & THE WASATCH @ 6718 T.D. WELL @ 7335


Cum Dur (hr)


06:00 16:30 10.50 10.50 2 DRILL ACTUAL

DRILLING F/ 6350 TO 6971 ( 59 FPH ) W/ 18 K ON BIT 390 GAL 121 TOTAL RPMS LOST 150 BBL TO SEEPAGE

16:30 17:00 0.50 11.00 7 LUBRICATE RIG

RIG SERVICE

17:00 00:00 7.00 18.00 2 DRILL ACTUAL

DRILLING F/ 6971 TO 7335 ( 45.5 FPH ) W/ 18 K ON BIT 390 GAL 121 TOTAL RPMS LOST 114 BBL TO SEEPAGE

00:00 01:30 1.50 19.50 5 COND MUD & CIRC

CIRC 2 BOTTOMS UPS SPOT KILL PILL UP TO 3500'

01:30 04:30 3.00 22.50 6 TRIPS POOH FOR LOGS TO 3500'

04:30 05:00 0.50 23.00 5 COND MUD & CIRC

CIRC BOTTOMS UP UNTILL ( SHAKERS CLEAN )

05:00 06:00 1.00 24.00 6 TRIPS PULL OUT OF HOLE F/ LOGS

Mud Checks

6,689.0ftKB, 8/23/2014 11:00Type

Water BaseTime

11:00Depth (ftKB)



31PV Override (cP)


3.000Gel 10 sec (lbf/100ft²)

2.000Gel 10 min (lbf/100ft²)

3.000Filtrate (mL/30min) Filter Cake (1/32")

1pH

8.5Sand (%)

0.3Solids (%)




Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

70.6Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 6,350.0 7,335.0 6,315.00

89.50 56.3 394 18 58 1,360.0 145 148 9,500.0




< p Daily Drilling Report Report for: 8/23/2014cresygr oi5 Report#: 8.0, DFS: 4.06





NICE 71.0 MUDDY Good Surface, 1,012.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsTRIPPING OUT @2500' LOG WELL & RUN 5.5 PROD CASING


DRILL F/ 6350 TO 7335 CIRC & COND HOLE SPOT 10.2# KILL PILL UP TO 3500' POOH TO 3500 CIRC CLEAN Floyd Mitchell 435-823-3608

POOH BBG 48-67 UNITS CONNS 129-173 PEAK GAS 3082 UNIT @6590' LAST SAMPLE WAS 40% CLAYSTONE30% SHALE 30% SANDSTONE TOPPED BLACK SHALE @6035' CASTLE PEAK @6285' UTELAND BUTTE @ Brent Bascom 970-250-29286580 & THE WASATCH @6718 T.D. WELL @7335

Time Log Doug Hackford 970-640-3882Start Cum Dur AtyTime End Time Dur (hr) (hr) Code Activity Com Rigo

06:00 16:30 10.50 10.50 2 DRILL DRILLING F/ 6350 TO 6971 ( 59 FPH ) W/ 18 K ON BIT 390 GALACTUAL 121 TOTAL RPMS LOST 150 BBL TO SEEPAGE Capstar, 316

contractor Rig Number16:30 17:00 0.50 11.00 7 LUBRICATE RIG SERVICE Capstar 316

RIG Rig Supervisor Phone Mobile

17:00 00:00 7.00 18.00 2 DRILL DRILLING F/ 6971 TO 7335 ( 45.5 FPH )W/ 18 K ON BIT 390 JAKE 307-315-5422

ACTUAL GAL 121 TOTAL RPMS LOST 114 BBL TO SEEPAGE 1, Gardner-Denver, PZ-9

00:00 01:30 1.50 19.50 5 COND MUD & CIRC 2 BOTTOMS UPS SPOT KILL PILL UP TO 3500, Pump# Pwr(hp) Rod Dia (in)

CIRC 1 750.0i inar Rivo (in) Stroke (in) Vol/Stk OR (b...

01:30 04:30 3.00 22.50 6 TRIPS POOH FOR LOGS TO 3500' 6 9.02 0.07904:30 05:00 0.50 23.00 5 COND MUD & CIRC BOTTOMS UP UNTILL ( SHAKERS CLEAN ) P (psi) SlowSpd Strokes (s... Eff(%)

CIRC

05:00 06:00 1.00 24.00 6 TRIPS PULL OUT OF HOLE F/ LOGS 2, Gardner-Denver, PZ-9Pure.p # Pwr (hp) Rod Dia (in)

Mud Checks 9 750.06,689.0ftKB, 8/23/2014 11:00 Liner Size (in) Stroke (in) Vol/Stk OR (b...Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2) 6 9.02 0.079Water Base 11:00 6,689.0 9.30 31 4.0 3.000 P (psi) SlowSpd Strokes (s... Eff (%)Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%)

2.000 3.000 1 8.5 0.3 7.7 .


29,000.000 Field Est ConsumeDes (Cost/unit) d

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Brine 7.50 300.0

Drill Strings DAP 35.00 40.0

BHA #1, Steerable Engineering 450.00 1.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP... Hole Seal 21.00 51.01 7 7/8in, MDi616, JH8919 (PN 65833AD102) 1.00 0-1-CT-G----TD 1.18 70.6 Pellet 20.00 7.0Nozzles (1/32") String Length (ft) Max Nominal OD (in)

16/16/16/16/16/16 556.93 6.500 Rental 50.00 1.0String Components Sawdust 4.50 130.0Smith MDi616, Mud Motor, UBHO, NMDC, Drill Collar, HWDP 998 Miid 15.50 180.0Comment

Smith MDi616 (Newsco MM,6.5" 7/8, 3.3 Stg. .16 Rev. 1.50° Bend)(6.375"x2.5"UBHO) (1-6.375"x2.375"NMDC)(6- Shrink Wrap 20.00 7.06.125"x 2.375" DC)(10-4.5" HWDP) Tax 1.00 380.0Drilling Parameters

Cafet, CheclaCumDrill WOB Time Type Des


Original Hole 6,350.0 7,335.0 6,315.0 89.50 56.3 394 18 58 1,360.0 145 148 9,500. WellboresO O Wellbore Name KO MD (ftKB)

Original Hole












Time Log Doug Hackford 970-640-3882

Start Cum Dur AtyTime End Time Dur (hr) (hr) Code Activity Com Rigo









CIRC



2.000 3.000 1 8.5 0.3 7.7 .











Original Hole






















CIRC



2.000 3.000 1 8.5 0.3 7.7 .











Original Hole






















CIRC



2.000 3.000 1 8.5 0.3 7.7 .











Original Hole



Page 1/1




AFE Number











Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

307-315-5422


1Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




2Pwr (hp)

750.0Rod Dia (in)

Liner Size (in)

6Stroke (in)




DesField Est

(Cost/unit)Consume

d

Aluminum Stear. 130.00 1.0

Barite 10.65 36.0

Brine 7.50 180.0

DAP 35.00 8.0



Pallet 20.00 3.0

Rental 50.00 1.0

Sawdust 4.50 67.0

Sea Mud 15.50 60.0


Tax 1.00 156.0

Trucking 1.00 1,200.0



Original Hole

Report #: 9.0, DFS: 5.06

UWI/API


2-22-4-2License #

FEESpud Date





Weather

RAININGTemperature (°F)

69.0Road Condition

MUDDYHole Condition


RR @ 0600 RIG DOWNOperation Next 24hrs

MOVE TO DEEP CREEK 6-22-4-2E RIG UP24 Hr Summary

POOH LAY DOWN DIR. TOOLS LOG WELL W/ HALLIBURTON RUN 160 FULL JOINTS & 2 MARKERS OF 5 1/2 17# L80 CASING LAND ON HANGER @ 7303' CEMENT W/ HALLIBURTON NIPPLE DOWN CLEAN PITS R.R. @ 0600 8/25/14


Cum Dur (hr)


06:00 08:30 2.50 2.50 6 TRIPS POOH & LD DIR. TOOLS F/ LOGS

08:30 15:00 6.50 9.00 11 WIRELINE LOGS

LOG WELL RESISTIVITY, PEROSITE, GAMMA. DIELECTRIC & SONIC ALL F/ 7320 UP TO SURFACE PIPE

15:00 23:30 8.50 17.50 12 RUN CASING & CEMENT

RUN 160 FULL JTS & 2 MARKER JOINTS 5 1/2 L80 17# CASING LAND ON HANGER @ 7303'

23:30 02:00 2.50 20.00 12 RUN CASING & CEMENT

HELD SAFETY MEETING TEST LINES & CEMENT W/ HALLIBURTON 10 BBL SPACER 170 SKS 10.3# 4.31 YIELD LEAD THEN 490 SKS 13.1# 1.66 YIELD TAIL DROP PLUG DISPLACE W/ 168 BBL WATER FCP 1680 BUMP PLUG W/ 500 PSI OVER & HELD 90% RETURNS THROUGH OUT JOB

02:00 06:00 4.00 24.00 14 NIPPLE UP B.O.P

NIPPLE DOWN & CLEAN MUD TANKS RELEASE RIG 0600 8/25/14

Mud Checks

7,335.0ftKB, 8/24/2014 13:00Type

Water BaseTime

13:00Depth (ftKB)



31PV Override (cP)


2.000Gel 10 sec (lbf/100ft²)

2.000Gel 10 min (lbf/100ft²)

2.000Filtrate (mL/30min)

1.0Filter Cake (1/32") pH

8.5Sand (%)

0.3Solids (%)




Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

70.6Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 7,335.0 7,335.0 6,315.00

89.50









RAINING 69.0 MUDDY Good Surface, 1,012.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsRR @0600 RIG DOWN MOVE TO DEEP CREEK 6-22-4-2E RIG UP


POOH LAY DOWN DIR. TOOLS LOG WELL W/ HALLIBURTON RUN 160 FULL JOINTS & 2 MARKERS OF 5 1/2 17# Floyd Mitchell 435-823-3608

L80 CASING LAND ON HANGER @7303' CEMENT W/ HALLIBURTON NIPPLE DOWN CLEAN PITS R.R. @06008/25/14 Brent Bascom 970-250-2928


06:00 08:30 2.50 2.50 6 TRIPS POOH & LD DIR. TOOLS F/ LOGS Rigs08:30 15:00 6.50 9.00 11 WIRELINE LOG WELL RESISTIVITY, PEROSITE, GAMMA. DIELECTRIC & Capstar, 316

LOGS SONIC ALL F/ 7320 UP TO SURFACE PIPE Contractor Rig Number

15:00 23:30 8.50 17.50 12 RUN CASING RUN 160 FULL JTS & 2 MARKER JOINTS 5 1/2 L80 17# Capstar 316& CEMENT CASING LAND ON HANGER @7303' Rig Supervisor Phone Mobile

JAKE 307-315-5422

23:30 02:00 2.50 20.00 12 RUN CASING HELD SAFETY MEETING TEST LINES & CEMENT W/ I, Gardrier-Deriver, FI-3

& CEMENT HALLIBURTON 10 BBL SPACER 170 SKS 10.3#4.31 YIELD Pump# Pwr(hp) RodDia(in)

LEAD THEN 490 SKS 13.1#1.66 YIELD TAIL DROP PLUG 1 750.0

DISPLACE W/ 168 BBL WATER FCP 1680 BUMP PLUG W/ 500 Liner Size (in) Stroke (in) Vol/Stk OR (b...

PSI OVER & HELD 90% RETURNS THROUGH OUT JOB 6 9.02 0.079P (psi) Slow Spd Strokes (s... Eff (%)

02:00 06:00 4.00 24.00 14 NIPPLE UP NIPPLE DOWN & CLEAN MUD TANKS RELEASE RIG 0600 2, Gardner-Denver, PZ-9B.O.P 8/25/14 Pump# Pwr(hp) RodDia(in)

Mud Checks 2 750.0

7,335.0ftKB, 8/24/2014 13:00 Liner Size (in) Stroke (in) Vol/Stk OR (b...

6 9.02 0.079Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

Water Base 13:00 7,335.0 9.40 31 3.0 2.000 P (psi) SlowSpd Strokes (s... Eff (%)

Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%)2.000 2.000 1.0 8.5 0.3 8.1 Mud Additive Amou its

MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2) Field Est Consume30,000.000 Des (Cost/unit) d

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Aluminum Stear. 130.00 1.0Barite 10.65 36.0

Drill Strings Rrine 7.50 180.0BHA #1, Steerable DAP 35.00 8.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...

1 7 7/8in, MDi616, JH8919 (PN 65833AD102) 1.00 0-1-CT-G----TD 1.18 70.6 Engineering 450.00 1.0Nozzles (1/32") String Length (ft) Max Nominal OD (in) Hole Seal 21.00 22.016/16/16/16/16/16 556.93 6.500 Pallet 20.00 3.0String Components

Smith MDi616, Mud Motor, UBHO, NMDC, Drill Collar, HWDP Rental 50.00 1.0Comment Sawdust 4.50 67.0Smith MDi616 (Newsco MM,6.5" 7/8, 3.3 Stg. .16 Rev. 1.50° Bend)(6.375"x2.5"UBHO) (1-6.375"x2.375"NMDC)(6-6.125"x 2.375" DC)(10-4.5" HWDP) Sea Mud 15.50 60.0

Drilling Parameters 3|iiiiik WIaµ 20.00 3.0

cum Iax 1.00 156.0Drill WOB Trucking 1.00 1,200.

End Depth Cum Depth Time Int ROP Q Flow (1000lbf RPM Drill Str Wt PU Str WtWellbore Start (ftKB) (ftKB) (ft) (hr) (ft/hr) (gpm) ) (rpm) SPP (psi) (1000lbf) (1000lbf) Drill Tq 0

Original Hole 7,335.0 7,335.0 6,315.0 89.500 Safety Checks

rime Type Des


Original Hole
















JAKE 307-315-5422







Mud Checks 2 750.0






Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Aluminum Stear. 130.00 1.0

Barite 10.65 36.0Drill Strings Rrine 7.50 180.0BHA #1, Steerable DAP 35.00 8.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...







rime Type Des


Original Hole
















JAKE 307-315-5422







Mud Checks 2 750.0














rime Type Des


Original Hole
















JAKE 307-315-5422







Mud Checks 2 750.0














rime Type Des


Original Hole


RECEIVED: Dec. 15, 2014



FORM 9









9. API NUMBER: 43047541960000




COUNTY: UINTAH

STATE: UTAH

11.





12/15 /2014














Please see attached application to commingle production formations forthe Deep Creek 2-22-4-2E

NAME (PLEASE PRINT) PHONE NUMBER Valari Crary 303 880-3637

TITLE Drilling And Completion Tech

SIGNATURE N/A

DATE 12/15/2014

January 29, 2015


FORM 9STATE OF UTAH








4. LOCATION OF WELL COUNTY:FOOTAGESAT SURFACE: UINTAH









12/15/2014OPERATOR CHANGE PLUG AND ABANDON PLUG BACK







Please see attached application to commingle production formations for Approved by thethe Deep Creek 2-22-4-2E UJIarkumyiflih,n2OI15

OFI, Gas and Mining

NAME (PLEASE PRINT) PHONE NUMBER TITLEValari Crary 303 880-3637 Drilling And Completion Tech


RECEIVED: Dec. 15,


FORM 9STATE OF UTAH

























OFI, Gas and Mining



RECEIVED: Dec. 15,


FORM 9STATE OF UTAH

























OFI, Gas and Mining



RECEIVED: Dec. 15,



main|720.880.3610fax|303,292.1562tollfree i 1.888693.0020

Crescent Point 6"""""""*'"°Denver.ColoradoUSA80202

December 3, 2014

Utah Division of Oil, Gas & MiningAttention: Dustin Doucet1594 West North Temple, Suite 1120Salt Lake City, Utah 84116

RE: Sundry NoticesDeep Creek 2-22-4-2EUintah County, UT

Dear Mr. Doucet:

Crescent Point Energy has submitted Sundry Notices to commingle production from theWasatch and Green River formations in the subject well. Pursuant to the Utah OGMregulations, we have enclosed a copy of the Sundry Notice, a plat showing the owners ofcontiguous leases, as well as an affidavit confirming notice.

If you should have any questions regarding these Sundry Notices, please feel free tocontact me at 303-382-6785.

Sincerely,

Jordan WellsLandman

Enclosures

www.crescentpointenergy.com)TSX:CPGj




December 3, 2014



Dear Mr. Doucet:



Sincerely,

Jordan WellsLandman

Enclosures





December 3, 2014



Dear Mr. Doucet:



Sincerely,

Jordan WellsLandman

Enclosures




AFFIDAVITOF NOTICE

Jordan Wells, of lawful age, after having first duly sworn upon his oath, disposes and states:

That he is employed by Crescent Point Energy U.S. Corp. ("Crescent Point") as a Landman.Crescent Point has submitted Sundry Notices to commingle production from the Wasatch andGreen River formations in the following well within the Randlett Exploration and DevelopmentAgreement Area:

DEEPCREEK 2-22-4-2E: NWNESection 22 T45-R2E

That in compliance with the Utah OGM regulation R649-3-22, I have provided a copy of theSundry Notice, via certified mail, to the owners (see listed below) of all contiguous oil and gasleases or drilling units overlying the pool.

Finley Resources Inc.Attn: Zachary Archer1308 Lake St.Fort Worth, TX76102

Broughton Petroleum Inc.ATTN:BillWilsonPO Box 1389Sea ly, TX77474

Kaiser-Francis Oil CompanyAttn: Robert WadleyP.O. Box 21468Tulsa, OK.74121-1468

Date: December 3,


AFFIDAVITOF NOTICE








Date: December 3,


AFFIDAVITOF NOTICE








Date: December 3,



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RECEIVED: Nov. 12, 2014


DIVISION OF OIL, GAS AND MINING

AMENDED REPORT FORM 8 (highlight changes) 5. LEASE DESIGNATION AND SERIAL NUMBER:

WELL COMPLETION OR RECOMPLETION REPORT AND LOG6. IF INDIAN, ALLOTTEE OR TRIBE NAME

1a. TYPE OF WELL: OILWELL

GASWELL DRY OTHER

7. UNIT or CA AGREEMENT NAME

b. TYPE OF WORK: 8. WELL NAME and NUMBER:NEWWELL

HORIZ.LATS.

DEEP-EN

RE-ENTRY

DIFF.RESVR. OTHER

2. NAME OF OPERATOR: 9. API NUMBER:

3. ADDRESS OF OPERATOR:

CITY STATE ZIP

PHONE NUMBER: 10 FIELD AND POOL, OR WILDCAT

4. LOCATION OF WELL (FOOTAGES)

AT SURFACE:

11. QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN:

AT TOP PRODUCING INTERVAL REPORTED BELOW:

AT TOTAL DEPTH:12. COUNTY 13. STATE

UTAH

14. DATE SPUDDED: 15. DATE T.D. REACHED: 16. DATE COMPLETED: ABANDONED READY TO PRODUCE

17. ELEVATIONS (DF, RKB, RT, GL):

18. TOTAL DEPTH: MD

TVD

19. PLUG BACK T.D.: MD

TVD

20. IF MULTIPLE COMPLETIONS, HOW MANY? * 21. DEPTH BRIDGE PLUG SET:

MD

TVD

22. TYPE ELECTRIC AND OTHER MECHANICAL LOGS RUN (Submit copy of each) 23.

WAS WELL CORED? NO YES (Submit analysis)

WAS DST RUN? NO YES (Submit report)

DIRECTIONAL SURVEY? NO YES (Submit copy)

24. CASING AND LINER RECORD (Report all strings set in well)

HOLE SIZE SIZE/GRADE WEIGHT (#/ft.) TOP (MD) BOTTOM (MD)STAGE CEMENTER

DEPTHCEMENT TYPE &NO. OF SACKS

SLURRYVOLUME (BBL) CEMENT TOP ** AMOUNT PULLED

25. TUBING RECORD

SIZE DEPTH SET (MD) PACKER SET (MD) SIZE DEPTH SET (MD) PACKER SET (MD) SIZE DEPTH SET (MD) PACKER SET (MD)

26. PRODUCING INTERVALS 27. PERFORATION RECORD

FORMATION NAME TOP (MD) BOTTOM (MD) TOP (TVD) BOTTOM (TVD) INTERVAL (Top/Bot - MD) SIZE NO. HOLES PERFORATION STATUS

(A) Open Squeezed

(B) Open Squeezed

(C) Open Squeezed

(D) Open Squeezed

28. ACID, FRACTURE, TREATMENT, CEMENT SQUEEZE, ETC.

DEPTH INTERVAL AMOUNT AND TYPE OF MATERIAL

29. ENCLOSED ATTACHMENTS:

ELECTRICAL/MECHANICAL LOGS GEOLOGIC REPORT DST REPORT DIRECTIONAL SURVEY

SUNDRY NOTICE FOR PLUGGING AND CEMENT VERIFICATION CORE ANALYSIS OTHER:

30. WELL STATUS:

(5/2000) (CONTINUED ON BACK)


STATE OF UTAH AMENDED REPORT Ü FORM 8DEPARTMENT OF NATURAL RESOURCES (highlight changes)

DIVISION OF OIL, GAS AND MINING 5. LEASEDESIGNATIONANDSERIALNUMBER:

FEE6. IF INDIAN,ALLOTTEE OR TRIBE NAME

WELL COMPLETION OR RECOMPLETION REPORT AND LOG N/A1a. TYPE OF WELL: O

LLGWAESLL DRY OTHER 7. UNI/Tor CA AGREEMENT NAME

b. TYPE OF ½ORK: 8. WELL NAME and NUMBER:W HORSZ. DEEP- RNE-TRY EFSFVR.

OTHER Deep Creek 2-22-4-2E2. NAME OF OPERATOR: 9. API NUMBER:

Crescent Point Energy US Corp. 43047541963. ADDRESSOF OPERATOR: PHONE NUMBER: 10 FIELD AND POOL, OR WLDCAT

555 17th St., Suite 1800 C TY Denver STATE CO ZP 80202 (720) 880-3637 UNDESIGNATED4. LOCATION OF WELL (FOOTAGES) 11. QTR/QTR, SECTION, TOWNSHIP, RANGE,

MERIDIAN:ATSURFACE: 272 FNL 1968 FEL NWNE 22 4S 2E UAT TOP PRODUCING INTERVAL REPORTED BELOW: 475 FNL 1916 FEL

12. COUNTY 13. STATEATTOTALDEPTH: 562 FNL 1908 FEL Uintah UTAH

14. DATE SPUDDED: 15. DATE T.D. REACHED: 16. DATE COMPLETED: 17. ELEVATIONS (DF, RKB, RT, GL):

6/9/2014 8/25/2014 9/6/2014 ABANDONED READYTO PRODUCE 2 4974' GL18. TOTAL DEPTH: MD 7.335 19. PLUG BACKT.D.: MD 7.220 20. IF MULTIPLE COMPLETIONS, HOW MANY? * 21. DEPTH BRIDGE MD

TVD 7.327 TVD 7.212 9 STAGES PLUG SET:TVD


. WAS WELL CORED? NO YES (Submit analysis)Triple Combo CBL Directional SurveyWAS DST RUN? NO YES (Submit report)



HOLE SIZE SIZE/GRADE WEIGHT (#lft.) TOP (MD) BOTTOM (MD) STAGE CEMHENTER CNEMENFSAYCKES VOSLUMREBL) CEMENT TOP ** AMOUNT PULLED

12-1/4 8-5/8 J-55 24 0 1,012 PREM 675 138 SRFC7-7/8 5-1/2 SB8( 17 0 7,303 HiFillV 490 100 480

65/35 P 170 168

25. TUBING RECORD


2-7/8 7,07526. PRODUCING INTERVALS 27. PERFORATION RECORD

FORMATION NAME TOP (MD) BOTTOM (MD) TOP (TVD) BOTTOM (TVD) INTERVAL (Top/Bot -MD) SIZE NO. HOLES PERFORATION STATUS

(A) Green River 4.911 6.669 4.905 6.661 4.911 7.112 .36 249 OPen 2 Squeezed

(B) Wasatch 6.669 7.112 6.661 7.104 DPen Squeezed

(C) Open Squeezed

(D) Open Squeezed



4911' - 7112' 7852 Bbls Slickwater & XIinked fluid, 4500 gals 15% HCI, 838300 # 20/40 sand

29. ENCLOSED ATTACHMENTS: 30. WELL STATUS:

ELECTRICAL/MECHANICAL LOGS GEOLOGIC REPORT DST REPORT DIRECTIONAL SURVEY FlowingSUNDRY NOTICE FOR PLUGGING AND CEMENT VERIFICATION CORE ANALYSIS OTHER:


RECEIVED: Nov. 12,


STATE OF UTAH AMENDED REPORT Ü FORM 8DEPARTMENT OF NATURAL RESOURCES (highlight changes)

DIVISION OF OIL, GAS AND MINING 5. LEASEDESIGNATIONANDSERIALNUMBER:

FEE6. IF INDIAN,ALLOTTEE OR TRIBE NAME

WELL COMPLETION OR RECOMPLETION REPORT AND LOG N/A1a. TYPE OF WELL: O

LLGWAESLL DRY OTHER 7. UNI/Tor CA AGREEMENT NAME

b. TYPE OF ½ORK: 8. WELL NAME and NUMBER:W HORSZ. DEEP- RNE-TRY EFSFVR.

OTHER Deep Creek 2-22-4-2E2. NAME OF OPERATOR: 9. API NUMBER:

Crescent Point Energy US Corp. 43047541963. ADDRESSOF OPERATOR: PHONE NUMBER: 10 FIELD AND POOL, OR WLDCAT

555 17th St., Suite 1800 C TY Denver STATE CO ZP 80202 (720) 880-3637 UNDESIGNATED4. LOCATION OF WELL (FOOTAGES) 11. QTR/QTR, SECTION, TOWNSHIP, RANGE,

MERIDIAN:ATSURFACE: 272 FNL 1968 FEL NWNE 22 4S 2E UAT TOP PRODUCING INTERVAL REPORTED BELOW: 475 FNL 1916 FEL

12. COUNTY 13. STATEATTOTALDEPTH: 562 FNL 1908 FEL Uintah UTAH

14. DATE SPUDDED: 15. DATE T.D. REACHED: 16. DATE COMPLETED: 17. ELEVATIONS (DF, RKB, RT, GL):

6/9/2014 8/25/2014 9/6/2014 ABANDONED READYTO PRODUCE 2 4974' GL18. TOTAL DEPTH: MD 7.335 19. PLUG BACKT.D.: MD 7.220 20. IF MULTIPLE COMPLETIONS, HOW MANY? * 21. DEPTH BRIDGE MD

TVD 7.327 TVD 7.212 9 STAGES PLUG SET:TVD


. WAS WELL CORED? NO YES (Submit analysis)Triple Combo CBL Directional SurveyWAS DST RUN? NO YES (Submit report)



HOLE SIZE SIZE/GRADE WEIGHT (#lft.) TOP (MD) BOTTOM (MD) STAGE CEMHENTER CNEMENFSAYCKES VOSLUMREBL) CEMENT TOP ** AMOUNT PULLED

12-1/4 8-5/8 J-55 24 0 1,012 PREM 675 138 SRFC7-7/8 5-1/2 SB8( 17 0 7,303 HiFillV 490 100 480

65/35 P 170 168

25. TUBING RECORD


2-7/8 7,07526. PRODUCING INTERVALS 27. PERFORATION RECORD

FORMATION NAME TOP (MD) BOTTOM (MD) TOP (TVD) BOTTOM (TVD) INTERVAL (Top/Bot -MD) SIZE NO. HOLES PERFORATION STATUS

(A) Green River 4.911 6.669 4.905 6.661 4.911 7.112 .36 249 OPen 2 Squeezed

(B) Wasatch 6.669 7.112 6.661 7.104 DPen Squeezed

(C) Open Squeezed

(D) Open Squeezed



4911' - 7112' 7852 Bbls Slickwater & XIinked fluid, 4500 gals 15% HCI, 838300 # 20/40 sand

29. ENCLOSED ATTACHMENTS: 30. WELL STATUS:

ELECTRICAL/MECHANICAL LOGS GEOLOGIC REPORT DST REPORT DIRECTIONAL SURVEY FlowingSUNDRY NOTICE FOR PLUGGING AND CEMENT VERIFICATION CORE ANALYSIS OTHER:


RECEIVED: Nov. 12,

RECEIVED: Nov. 12, 2014

31. INITIAL PRODUCTION INTERVAL A (As shown in item #26)

DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTIONRATES: !!

OIL – BBL: GAS – MCF: WATER – BBL: PROD. METHOD:

CHOKE SIZE: TBG. PRESS. CSG. PRESS. API GRAVITY BTU – GAS GAS/OIL RATIO 24 HR PRODUCTIONRATES: !!

OIL – BBL: GAS – MCF: WATER – BBL: INTERVAL STATUS:

INTERVAL B (As shown in item #26)





INTERVAL C (As shown in item #26)





INTERVAL D (As shown in item #26)





32. DISPOSITION OF GAS (Sold, Used for Fuel, Vented, Etc.)

33. SUMMARY OF POROUS ZONES (Include Aquifers):

Show all important zones of porosity and contents thereof: Cored intervals and all drill-stem tests, including depth intervaltested, cushion used, time tool open, flowing and shut-in pressures and recoveries.

34. FORMATION (Log) MARKERS:

FormationTop(MD)

Bottom(MD)

Descriptions, Contents, etc. NameTop

(Measured Depth)

35. ADDITIONAL REMARKS (Include plugging procedure)

36. I hereby certify that the foregoing and attached information is complete and correct as determined from all available records.

NAME (PLEASE PRINT) TITLE

SIGNATURE DATE

This report must be submitted within 30 days of ! completing or plugging a new well ! reentering a previously plugged and abandoned well! drilling horizontal laterals from an existing well bore ! significantly deepening an existing well bore below the previous bottom-hole depth! recompleting to a different producing formation ! drilling hydrocarbon exploratory holes, such as core samples and stratigraphic tests

* ITEM 20: Show the number of completions if production is measured separately from two or more formations.

** ITEM 24: Cement Top – Show how reported top(s) of cement were determined (circulated (CIR), calculated (CAL), cement bond log (CBL), temperature survey (TS)).

Send to: Utah Division of Oil, Gas and Mining Phone: 801-538-53401594 West North Temple, Suite 1210Box 145801 Fax: 801-359-3940Salt Lake City, Utah 84114-5801

(5/2000)


31. INITIALPRODUCTION INTERVAL A (As shown in item #26)

DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: PROD. METHOD:

9/11/2014 9/11/2014 24 RATES: 133 20 446 FlowingCHOKE SIZE: TBG. PRESS. CSG. PRESS. Pl GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: INTERVALSTATUS:

14 0 40 40.00 RATES: 133 20 446 FlowingINTERVAL B (As shown in item #26)

DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: PROD. METHOD:RATES: a

CHOKE SIZE: TBG. PRESS. CSG. PRESS. Pl GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: INTERVALSTATUS:RATES: *






CHOKE SIZE: TBG. PRESS. CSG. PRESS. Pl GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: INTERVALSTATUS:RATES: 4


Sold33. SUMMARY OF POROUS ZONES (Include Aquifers): 34. FORMATION (Log) MARKERS:


Formation MDp) Bo om Descriptions, Contents, etc. Name (Measuedp

Depth)

Mahogany 3,954TGR3 4,778Douglas Creek 5,630Black Shale 6,029Castle Peak 6,273Uteland Butte 6,566Wasatch 6,669



NAME (PLEASE PRINT) Valari Crary TITLE D&C Technician

SIGNATURE

raay

crraerse tp intenergy.co DATE 11/12/2014

Date:20l4.11.1209:15:07-0700'

This report must be submitted within 30 days of• completing or plugging a new well • reentering a previously plugged and abandoned well• drilling horizontal laterals from an existing well bore • significantly deepening an existing well bore below the previous bottom-hole depth• recompleting to a different producing formation • drilling hydrocarbon exploratory holes, such as core samples and stratigraphic tests


**lTEM 24: Cement Top -Show how reported top(s) of cement were determined (circulated (CIR), calculated (CAL), cement bond log (CBL), temperature survey (TS)).


(5/2000)

RECEIVED: Nov. 12,


31. INITIALPRODUCTION INTERVAL A (As shown in item #26)

DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: PROD. METHOD:

9/11/2014 9/11/2014 24 RATES: 133 20 446 FlowingCHOKE SIZE: TBG. PRESS. CSG. PRESS. Pl GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: INTERVALSTATUS:

14 0 40 40.00 RATES: 133 20 446 FlowingINTERVAL B (As shown in item #26)








CHOKE SIZE: TBG. PRESS. CSG. PRESS. Pl GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: INTERVALSTATUS:RATES: 4


Sold33. SUMMARY OF POROUS ZONES (Include Aquifers): 34. FORMATION (Log) MARKERS:


Formation MDp) Bo om Descriptions, Contents, etc. Name (Measuedp

Depth)

Mahogany 3,954TGR3 4,778Douglas Creek 5,630Black Shale 6,029Castle Peak 6,273Uteland Butte 6,566Wasatch 6,669



NAME (PLEASE PRINT) Valari Crary TITLE D&C Technician

SIGNATURE

raay

crraerse tp intenergy.co DATE 11/12/2014

Date:20l4.11.1209:15:07-0700'

This report must be submitted within 30 days of• completing or plugging a new well • reentering a previously plugged and abandoned well• drilling horizontal laterals from an existing well bore • significantly deepening an existing well bore below the previous bottom-hole depth• recompleting to a different producing formation • drilling hydrocarbon exploratory holes, such as core samples and stratigraphic tests


**lTEM 24: Cement Top -Show how reported top(s) of cement were determined (circulated (CIR), calculated (CAL), cement bond log (CBL), temperature survey (TS)).


(5/2000)

RECEIVED: Nov. 12,

RECEIVED: Nov. 12, 2014file:///Q|/...onument%20Butte/02-22-4-2E%20Deep%20Creek/Drilling/Directional/Deep%20Creek%202-22-4-2E%20Final%20Survey's.txt[11/12/2014 8:55:18 AM]

Job Number: 34313 State/Country: Utah/US Company: Crescent Point Energy Corp. Declination: Lease/Well: Deep Creek 2-22-4-2E Grid: Location: Deep Creek 2-22-4-2E File name: C:\WINSERVE\ACCESS\34313.SVY Rig Name: Capstar 316 Date/Time: 24-Aug-14 / 07:18 RKB: Curve Name: As Drilled G.L. or M.S.L.: As Drilled WINSERVE SURVEY CALCULATIONS Minimum Curvature Method Vertical Section Plane 180.00 Vertical Section Referenced to offset from Wellhead: EW =.00 Ft , NS=.00 Ft Rectangular Coordinates Referenced to Wellhead Measured Incl Drift True Vertical CLOSURE CLOSURE Dogleg Depth Angle Direction Vertical N-S E-W Section Distance Direction Severity FT Deg Deg Depth FT FT FT FT Deg Deg/100 .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 1020.00 1.00 128.30 1019.95 -5.52 6.99 5.52 8.90 128.30 .10 1063.00 1.00 136.00 1062.94 -6.02 7.54 6.02 9.65 128.60 .31 1105.00 1.00 132.60 1104.94 -6.53 8.06 6.53 10.38 129.00 .14 1148.00 1.10 146.00 1147.93 -7.13 8.57 7.13 11.15 129.74 .61 1191.00 1.80 152.20 1190.91 -8.07 9.12 8.07 12.17 131.50 1.67 1277.00 2.50 166.70 1276.85 -11.09 10.18 11.09 15.05 137.44 1.02 1360.00 3.20 169.80 1359.75 -15.13 11.01 15.13 18.71 143.96 .86 1448.00 3.40 170.40 1447.60 -20.12 11.88 20.12 23.36 149.45 .23 1533.00 3.30 166.40 1532.46 -24.98 12.87 24.98 28.10 152.74 .30 1619.00 3.40 166.00 1618.31 -29.86 14.07 29.86 33.01 154.77 .12 1704.00 3.20 166.40 1703.17 -34.61 15.24 34.61 37.82 156.24 .24 1790.00 3.20 163.60 1789.04 -39.25 16.48 39.25 42.57 157.22 .18 1876.00 3.20 161.90 1874.90 -43.83 17.90 43.83 47.35 157.78 .11 1961.00 3.60 165.60 1959.75 -48.67 19.30 48.67 52.36 158.37 .54 2047.00 3.60 176.80 2045.59 -53.98 20.13 53.98 57.61 159.55 .82 2132.00 3.80 178.40 2130.41 -59.46 20.35 59.46 62.85 161.10 .26 2218.00 3.80 179.00 2216.22 -65.16 20.48 65.16 68.31 162.55 .05 2303.00 3.10 181.40 2301.06 -70.28 20.48 70.28 73.20 163.76 .84 2389.00 3.00 179.80 2386.94 -74.85 20.43 74.85 77.59 164.74 .15


Job Number: 34313 State/Country: Utah/USCompany: Crescent Point Energy Corp. Declination:Lease/Well: Deep Creek 2-22-4-2E Grid:Location: Deep Creek 2-22-4-2E File name: C:\WINSERVE\ACCESS\34313.SVYRig Name: Capstar 316 Date/Time: 24-Aug-14 / 07:18RKB: Curve Name: As DrilledG.L. or M.S.L.:

As Drilled

WINSERVE SURVEY CALCULATIONSMinimum Curvature Method

Vertical Section Plane 180.00Vertical Section Referenced to offset from Wellhead: EW =.00 Ft ,

NS=.00 FtRectangular Coordinates Referenced to Wellhead

Measured Incl Drift True Vertical CLOSURE CLOSURE DoglegDepth Angle Direction Vertical N-S E-W Section Distance Direction SeverityFT Deg Deg Depth FT FT FT FT Deg Deg/100

.00 .00 .00 .00 .00 .00 .00 .00 .00 .00

1020.00 1.00 128.30 1019.95 -5.52 6.99 5.52 8.90 128.30 .10

1063.00 1.00 136.00 1062.94 -6.02 7.54 6.02 9.65 128.60 .31

1105.00 1.00 132.60 1104.94 -6.53 8.06 6.53 10.38 129.00 .14

1148.00 1.10 146.00 1147.93 -7.13 8.57 7.13 11.15 129.74 .61

1191.00 1.80 152.20 1190.91 -8.07 9.12 8.07 12.17 131.50 1.671277.00 2.50 166.70 1276.85 -11.09 10.18 11.09 15.05 137.44 1.021360.00 3.20 169.80 1359.75 -15.13 11.01 15.13 18.71 143.96 .86

1448.00 3.40 170.40 1447.60 -20.12 11.88 20.12 23.36 149.45 .23

1533.00 3.30 166.40 1532.46 -24.98 12.87 24.98 28.10 152.74 .30

1619.00 3.40 166.00 1618.31 -29.86 14.07 29.86 33.01 154.77 .12

1704.00 3.20 166.40 1703.17 -34.61 15.24 34.61 37.82 156.24 .24

1790.00 3.20 163.60 1789.04 -39.25 16.48 39.25 42.57 157.22 .18

1876.00 3.20 161.90 1874.90 -43.83 17.90 43.83 47.35 157.78 .11

1961.00 3.60 165.60 1959.75 -48.67 19.30 48.67 52.36 158.37 .54

2047.00 3.60 176.80 2045.59 -53.98 20.13 53.98 57.61 159.55 .82

2132.00 3.80 178.40 2130.41 -59.46 20.35 59.46 62.85 161.10 .26

2218.00 3.80 179.00 2216.22 -65.16 20.48 65.16 68.31 162.55 .05

2303.00 3.10 181.40 2301.06 -70.28 20.48 70.28 73.20 163.76 .84

2389.00 3.00 179.80 2386.94 -74.85 20.43 74.85 77.59 164.74 .15

file:///Q|/...onument%20Butte/02-22-4-2E%20Deep%20Creek/Drilling/Directional/Deep%20Creek%202-22-4-2E¾Eil sur


Job Number: 34313 State/Country: Utah/USCompany: Crescent Point Energy Corp. Declination:Lease/Well: Deep Creek 2-22-4-2E Grid:Location: Deep Creek 2-22-4-2E File name: C:\WINSERVE\ACCESS\34313.SVYRig Name: Capstar 316 Date/Time: 24-Aug-14 / 07:18RKB: Curve Name: As DrilledG.L. or M.S.L.:

As Drilled

WINSERVE SURVEY CALCULATIONSMinimum Curvature Method

Vertical Section Plane 180.00Vertical Section Referenced to offset from Wellhead: EW =.00 Ft ,

NS=.00 FtRectangular Coordinates Referenced to Wellhead


.00 .00 .00 .00 .00 .00 .00 .00 .00 .00

1020.00 1.00 128.30 1019.95 -5.52 6.99 5.52 8.90 128.30 .10

1063.00 1.00 136.00 1062.94 -6.02 7.54 6.02 9.65 128.60 .31

1105.00 1.00 132.60 1104.94 -6.53 8.06 6.53 10.38 129.00 .14

1148.00 1.10 146.00 1147.93 -7.13 8.57 7.13 11.15 129.74 .61

1191.00 1.80 152.20 1190.91 -8.07 9.12 8.07 12.17 131.50 1.671277.00 2.50 166.70 1276.85 -11.09 10.18 11.09 15.05 137.44 1.021360.00 3.20 169.80 1359.75 -15.13 11.01 15.13 18.71 143.96 .86

1448.00 3.40 170.40 1447.60 -20.12 11.88 20.12 23.36 149.45 .23

1533.00 3.30 166.40 1532.46 -24.98 12.87 24.98 28.10 152.74 .30

1619.00 3.40 166.00 1618.31 -29.86 14.07 29.86 33.01 154.77 .12

1704.00 3.20 166.40 1703.17 -34.61 15.24 34.61 37.82 156.24 .24

1790.00 3.20 163.60 1789.04 -39.25 16.48 39.25 42.57 157.22 .18

1876.00 3.20 161.90 1874.90 -43.83 17.90 43.83 47.35 157.78 .11

1961.00 3.60 165.60 1959.75 -48.67 19.30 48.67 52.36 158.37 .54

2047.00 3.60 176.80 2045.59 -53.98 20.13 53.98 57.61 159.55 .82

2132.00 3.80 178.40 2130.41 -59.46 20.35 59.46 62.85 161.10 .26

2218.00 3.80 179.00 2216.22 -65.16 20.48 65.16 68.31 162.55 .05

2303.00 3.10 181.40 2301.06 -70.28 20.48 70.28 73.20 163.76 .84

2389.00 3.00 179.80 2386.94 -74.85 20.43 74.85 77.59 164.74 .15

file:///Q|/...onument%20Butte/02-22-4-2E%20Deep%20Creek/Drilling/Directional/Deep%20Creek%202-22-4-2E¾Eil sur


2474.00 2.80 172.90 2471.83 -79.14 20.69 79.14 81.80 165.35 .47 2560.00 2.90 173.60 2557.73 -83.38 21.19 83.38 86.03 165.74 .12 2646.00 2.80 175.10 2643.62 -87.64 21.62 87.64 90.26 166.14 .15 2731.00 2.70 175.80 2728.52 -91.70 21.94 91.70 94.29 166.54 .12 2817.00 2.70 171.60 2814.43 -95.73 22.38 95.73 98.31 166.84 .23 PAGE - 1 Measured Incl Drift True Vertical CLOSURE CLOSURE Dogleg Depth Angle Direction Vertical N-S E-W Section Distance Direction Severity FT Deg Deg Depth FT FT FT FT Deg Deg/100 2902.00 2.90 174.60 2899.33 -99.85 22.88 99.85 102.44 167.09 .29 2988.00 2.80 172.80 2985.22 -104.10 23.35 104.10 106.68 167.36 .16 3074.00 2.70 174.20 3071.12 -108.20 23.81 108.20 110.79 167.59 .14 3159.00 3.00 167.80 3156.02 -112.36 24.49 112.36 115.00 167.71 .51 3244.00 3.20 167.40 3240.89 -116.85 25.47 116.85 119.60 167.70 .24 3330.00 3.50 167.60 3326.74 -121.76 26.56 121.76 124.62 167.69 .35 3416.00 3.40 168.00 3412.59 -126.82 27.66 126.82 129.80 167.70 .12 3501.00 3.50 167.40 3497.43 -131.81 28.75 131.81 134.91 167.70 .13 3587.00 3.00 168.20 3583.30 -136.58 29.78 136.58 139.79 167.70 .58 3672.00 2.90 165.10 3668.18 -140.83 30.79 140.83 144.16 167.67 .22 3758.00 2.60 163.80 3754.08 -144.81 31.89 144.81 148.28 167.58 .36 3843.00 3.50 162.50 3838.96 -149.14 33.21 149.14 152.79 167.45 1.06 3928.00 3.60 156.70 3923.80 -154.06 35.04 154.06 158.00 167.19 .44 4014.00 3.40 155.60 4009.64 -158.86 37.17 158.86 163.15 166.83 .25 4100.00 3.40 154.50 4095.49 -163.49 39.32 163.49 168.15 166.48 .08 4185.00 3.10 152.90 4180.35 -167.81 41.45 167.81 172.85 166.13 .37 4271.00 3.20 151.90 4266.22 -172.00 43.64 172.00 177.45 165.76 .13 4356.00 3.00 154.70 4351.10 -176.10 45.71 176.10 181.93 165.45 .30 4442.00 2.90 160.80 4436.98 -180.19 47.38 180.19 186.31 165.27 .38 4527.00 2.70 161.30 4521.88 -184.12 48.73 184.12 190.46 165.17 .24 4612.00 2.60 163.90 4606.79 -187.86 49.91 187.86 194.38 165.12 .18 4698.00 2.40 166.60 4692.71 -191.49 50.87 191.49 198.13 165.12 .27 4783.00 2.60 167.30 4777.63 -195.10 51.70 195.10 201.84 165.16 .24 4869.00 2.60 176.30 4863.54 -198.95 52.26 198.95 205.70 165.28 .47 4954.00 2.60 182.00 4948.45 -202.80 52.32 202.80 209.44 165.53 .30 5040.00 2.50 180.00 5034.37 -206.63 52.25 206.63 213.13 165.81 .16 5168.00 3.00 171.20 5162.22 -212.73 52.76 212.73 219.17 166.07 .51


2474.00 2.80 172.90 2471.83 -79.14 20.69 79.14 81.80 165.35 .47

2560.00 2.90 173.60 2557.73 -83.38 21.19 83.38 86.03 165.74 .12

2646.00 2.80 175.10 2643.62 -87.64 21.62 87.64 90.26 166.14 .15

2731.00 2.70 175.80 2728.52 -91.70 21.94 91.70 94.29 166.54 .12

2817.00 2.70 171.60 2814.43 -95.73 22.38 95.73 98.31 166.84 .23

PAGE - 1

Measured Incl Drift True Vertical CLOSURE CLOSURE DoglegDepth Angle Direction Vertical N-S E-W Section Distance Direction SeverityFT Deg Deg Depth FT FT FT FT Deg Deg/1002902.00 2.90 174.60 2899.33 -99.85 22.88 99.85 102.44 167.09 .29

2988.00 2.80 172.80 2985.22 -104.10 23.35 104.10 106.68 167.36 .16

3074.00 2.70 174.20 3071.12 -108.20 23.81 108.20 110.79 167.59 .14

3159.00 3.00 167.80 3156.02 -112.36 24.49 112.36 115.00 167.71 .51

3244.00 3.20 167.40 3240.89 -116.85 25.47 116.85 119.60 167.70 .24

3330.00 3.50 167.60 3326.74 -121.76 26.56 121.76 124.62 167.69 .35

3416.00 3.40 168.00 3412.59 -126.82 27.66 126.82 129.80 167.70 .12

3501.00 3.50 167.40 3497.43 -131.81 28.75 131.81 134.91 167.70 .13

3587.00 3.00 168.20 3583.30 -136.58 29.78 136.58 139.79 167.70 .58

3672.00 2.90 165.10 3668.18 -140.83 30.79 140.83 144.16 167.67 .22

3758.00 2.60 163.80 3754.08 -144.81 31.89 144.81 148.28 167.58 .36

3843.00 3.50 162.50 3838.96 -149.14 33.21 149.14 152.79 167.45 1.063928.00 3.60 156.70 3923.80 -154.06 35.04 154.06 158.00 167.19 .44

4014.00 3.40 155.60 4009.64 -158.86 37.17 158.86 163.15 166.83 .25

4100.00 3.40 154.50 4095.49 -163.49 39.32 163.49 168.15 166.48 .08

4185.00 3.10 152.90 4180.35 -167.81 41.45 167.81 172.85 166.13 .37

4271.00 3.20 151.90 4266.22 -172.00 43.64 172.00 177.45 165.76 .13

4356.00 3.00 154.70 4351.10 -176.10 45.71 176.10 181.93 165.45 .30

4442.00 2.90 160.80 4436.98 -180.19 47.38 180.19 186.31 165.27 .38

4527.00 2.70 161.30 4521.88 -184.12 48.73 184.12 190.46 165.17 .24

4612.00 2.60 163.90 4606.79 -187.86 49.91 187.86 194.38 165.12 .18

4698.00 2.40 166.60 4692.71 -191.49 50.87 191.49 198.13 165.12 .27

4783.00 2.60 167.30 4777.63 -195.10 51.70 195.10 201.84 165.16 .24

4869.00 2.60 176.30 4863.54 -198.95 52.26 198.95 205.70 165.28 .47

4954.00 2.60 182.00 4948.45 -202.80 52.32 202.80 209.44 165.53 .30

5040.00 2.50 180.00 5034.37 -206.63 52.25 206.63 213.13 165.81 .16

5168.00 3.00 171.20 5162.22 -212.73 52.76 212.73 219.17 166.07 .51

file:///Q|/...onument%20Butte/02-22-4-2E%20Deep%20Creek/Drilling/Directional/Deep%20Creek%202-22-4-2E¾Eilk


2474.00 2.80 172.90 2471.83 -79.14 20.69 79.14 81.80 165.35 .47

2560.00 2.90 173.60 2557.73 -83.38 21.19 83.38 86.03 165.74 .12

2646.00 2.80 175.10 2643.62 -87.64 21.62 87.64 90.26 166.14 .15

2731.00 2.70 175.80 2728.52 -91.70 21.94 91.70 94.29 166.54 .12

2817.00 2.70 171.60 2814.43 -95.73 22.38 95.73 98.31 166.84 .23

PAGE - 1

Measured Incl Drift True Vertical CLOSURE CLOSURE DoglegDepth Angle Direction Vertical N-S E-W Section Distance Direction SeverityFT Deg Deg Depth FT FT FT FT Deg Deg/1002902.00 2.90 174.60 2899.33 -99.85 22.88 99.85 102.44 167.09 .29

2988.00 2.80 172.80 2985.22 -104.10 23.35 104.10 106.68 167.36 .16

3074.00 2.70 174.20 3071.12 -108.20 23.81 108.20 110.79 167.59 .14

3159.00 3.00 167.80 3156.02 -112.36 24.49 112.36 115.00 167.71 .51

3244.00 3.20 167.40 3240.89 -116.85 25.47 116.85 119.60 167.70 .24

3330.00 3.50 167.60 3326.74 -121.76 26.56 121.76 124.62 167.69 .35

3416.00 3.40 168.00 3412.59 -126.82 27.66 126.82 129.80 167.70 .12

3501.00 3.50 167.40 3497.43 -131.81 28.75 131.81 134.91 167.70 .13

3587.00 3.00 168.20 3583.30 -136.58 29.78 136.58 139.79 167.70 .58

3672.00 2.90 165.10 3668.18 -140.83 30.79 140.83 144.16 167.67 .22

3758.00 2.60 163.80 3754.08 -144.81 31.89 144.81 148.28 167.58 .36

3843.00 3.50 162.50 3838.96 -149.14 33.21 149.14 152.79 167.45 1.063928.00 3.60 156.70 3923.80 -154.06 35.04 154.06 158.00 167.19 .44

4014.00 3.40 155.60 4009.64 -158.86 37.17 158.86 163.15 166.83 .25

4100.00 3.40 154.50 4095.49 -163.49 39.32 163.49 168.15 166.48 .08

4185.00 3.10 152.90 4180.35 -167.81 41.45 167.81 172.85 166.13 .37

4271.00 3.20 151.90 4266.22 -172.00 43.64 172.00 177.45 165.76 .13

4356.00 3.00 154.70 4351.10 -176.10 45.71 176.10 181.93 165.45 .30

4442.00 2.90 160.80 4436.98 -180.19 47.38 180.19 186.31 165.27 .38

4527.00 2.70 161.30 4521.88 -184.12 48.73 184.12 190.46 165.17 .24

4612.00 2.60 163.90 4606.79 -187.86 49.91 187.86 194.38 165.12 .18

4698.00 2.40 166.60 4692.71 -191.49 50.87 191.49 198.13 165.12 .27

4783.00 2.60 167.30 4777.63 -195.10 51.70 195.10 201.84 165.16 .24

4869.00 2.60 176.30 4863.54 -198.95 52.26 198.95 205.70 165.28 .47

4954.00 2.60 182.00 4948.45 -202.80 52.32 202.80 209.44 165.53 .30

5040.00 2.50 180.00 5034.37 -206.63 52.25 206.63 213.13 165.81 .16

5168.00 3.00 171.20 5162.22 -212.73 52.76 212.73 219.17 166.07 .51

file:///Q|/...onument%20Butte/02-22-4-2E%20Deep%20Creek/Drilling/Directional/Deep%20Creek%202-22-4-2E¾Eilk


5296.00 2.60 172.80 5290.07 -218.92 53.64 218.92 225.39 166.23 .32 5424.00 2.40 173.70 5417.95 -224.46 54.29 224.46 230.94 166.40 .16 5553.00 2.60 184.90 5546.82 -230.06 54.34 230.06 236.39 166.71 .41 5681.00 3.10 189.70 5674.66 -236.37 53.51 236.37 242.35 167.24 .43 5809.00 2.20 181.60 5802.53 -242.23 52.86 242.23 247.94 167.69 .76 5937.00 1.60 165.50 5930.46 -246.42 53.24 246.42 252.11 167.81 .62 6066.00 1.60 161.00 6059.41 -249.87 54.27 249.87 255.69 167.75 .10 6194.00 1.80 162.70 6187.35 -253.48 55.45 253.48 259.47 167.66 .16 6322.00 2.00 168.80 6315.28 -257.59 56.49 257.59 263.71 167.63 .22 6451.00 1.80 174.40 6444.21 -261.81 57.12 261.81 267.97 167.69 .21 6579.00 1.70 169.70 6572.15 -265.68 57.66 265.68 271.86 167.76 .14 6707.00 1.70 170.10 6700.09 -269.42 58.32 269.42 275.66 167.79 .01 6836.00 1.70 169.20 6829.04 -273.18 59.01 273.18 279.48 167.81 .02 6964.00 2.10 173.30 6956.97 -277.38 59.64 277.38 283.72 167.87 .33 7092.00 2.10 177.90 7084.88 -282.05 60.00 282.05 288.36 167.99 .13 PAGE - 2 Measured Incl Drift True Vertical CLOSURE CLOSURE Dogleg Depth Angle Direction Vertical N-S E-W Section Distance Direction Severity FT Deg Deg Depth FT FT FT FT Deg Deg/100 7221.00 2.10 179.80 7213.79 -286.78 60.09 286.78 293.00 168.16 .05 7285.00 1.80 182.40 7277.76 -288.95 60.06 288.95 295.13 168.26 .49Projection To Bit @ TD 7335.00 1.80 182.40 7327.73 -290.52 59.99 290.52 296.65 168.33 .00


5296.00 2.60 172.80 5290.07 -218.92 53.64 218.92 225.39 166.23 .32

5424.00 2.40 173.70 5417.95 -224.46 54.29 224.46 230.94 166.40 .16

5553.00 2.60 184.90 5546.82 -230.06 54.34 230.06 236.39 166.71 .41

5681.00 3.10 189.70 5674.66 -236.37 53.51 236.37 242.35 167.24 .43

5809.00 2.20 181.60 5802.53 -242.23 52.86 242.23 247.94 167.69 .76

5937.00 1.60 165.50 5930.46 -246.42 53.24 246.42 252.11 167.81 .62

6066.00 1.60 161.00 6059.41 -249.87 54.27 249.87 255.69 167.75 .10

6194.00 1.80 162.70 6187.35 -253.48 55.45 253.48 259.47 167.66 .16

6322.00 2.00 168.80 6315.28 -257.59 56.49 257.59 263.71 167.63 .22

6451.00 1.80 174.40 6444.21 -261.81 57.12 261.81 267.97 167.69 .21

6579.00 1.70 169.70 6572.15 -265.68 57.66 265.68 271.86 167.76 .14

6707.00 1.70 170.10 6700.09 -269.42 58.32 269.42 275.66 167.79 .01

6836.00 1.70 169.20 6829.04 -273.18 59.01 273.18 279.48 167.81 .02

6964.00 2.10 173.30 6956.97 -277.38 59.64 277.38 283.72 167.87 .33

7092.00 2.10 177.90 7084.88 -282.05 60.00 282.05 288.36 167.99 .13

PAGE - 2


7221.00 2.10 179.80 7213.79 -286.78 60.09 286.78 293.00 168.16 .05

7285.00 1.80 182.40 7277.76 -288.95 60.06 288.95 295.13 168.26 .49

Projection To Bit @TD7335.00 1.80 182.40 7327.73 -290.52 59.99 290.52 296.65 168.33 .00

file:///Q|/...onument%20Butte/02-22-4-2E%20Deep%20Creek/Drilling/Directional/Deep%20Creek%202-22-4-2E¾Eil2BE sur


5296.00 2.60 172.80 5290.07 -218.92 53.64 218.92 225.39 166.23 .32

5424.00 2.40 173.70 5417.95 -224.46 54.29 224.46 230.94 166.40 .16

5553.00 2.60 184.90 5546.82 -230.06 54.34 230.06 236.39 166.71 .41

5681.00 3.10 189.70 5674.66 -236.37 53.51 236.37 242.35 167.24 .43

5809.00 2.20 181.60 5802.53 -242.23 52.86 242.23 247.94 167.69 .76

5937.00 1.60 165.50 5930.46 -246.42 53.24 246.42 252.11 167.81 .62

6066.00 1.60 161.00 6059.41 -249.87 54.27 249.87 255.69 167.75 .10

6194.00 1.80 162.70 6187.35 -253.48 55.45 253.48 259.47 167.66 .16

6322.00 2.00 168.80 6315.28 -257.59 56.49 257.59 263.71 167.63 .22

6451.00 1.80 174.40 6444.21 -261.81 57.12 261.81 267.97 167.69 .21

6579.00 1.70 169.70 6572.15 -265.68 57.66 265.68 271.86 167.76 .14

6707.00 1.70 170.10 6700.09 -269.42 58.32 269.42 275.66 167.79 .01

6836.00 1.70 169.20 6829.04 -273.18 59.01 273.18 279.48 167.81 .02

6964.00 2.10 173.30 6956.97 -277.38 59.64 277.38 283.72 167.87 .33

7092.00 2.10 177.90 7084.88 -282.05 60.00 282.05 288.36 167.99 .13

PAGE - 2


7221.00 2.10 179.80 7213.79 -286.78 60.09 286.78 293.00 168.16 .05

7285.00 1.80 182.40 7277.76 -288.95 60.06 288.95 295.13 168.26 .49

Projection To Bit @TD7335.00 1.80 182.40 7327.73 -290.52 59.99 290.52 296.65 168.33 .00

file:///Q|/...onument%20Butte/02-22-4-2E%20Deep%20Creek/Drilling/Directional/Deep%20Creek%202-22-4-2E¾Eil2BE sur




FORM 9









9. API NUMBER: 43047541960000


9. FIELD and POOL or WILDCAT: LELAND BENCH


COUNTY: UINTAH

STATE: UTAH

11.




12/13 /2014















As requested, please find the attached Direction Drill and ExceptionLocation Letter request along with a plat showing the surface andbottom hole location. Previous submitted letter only included an

exception location request and a plat that only showed the surfacehole.

NAME (PLEASE PRINT) PHONE NUMBER Kristen Johnson 303 308-6270

TITLE Regulatory Technician

SIGNATURE N/A

DATE 12/15/2014

April 14, 2015


FORM 9STATE OF UTAH







3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:555 17th Street, Suite 750 , Denver, CO, 80202 720 880-3621 Ext LELANDBENCH






ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT

Approximate date work will start: CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME

12/13/2014CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

SUBSEQUENT REPORT DEEPEN FRACTURE TREAT NEW CONSTRUCTIONDate of Work Completion:


PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONSPUD REPORT

Date of Spud: REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


DRILLING REPORT WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSIONReport Date:



As requested, please find the attached Direction Drill and Exception Approved by theLocation Letter request along with a plat showing the surface and UtpNIDi4i,s2fbl6f

bottom hole location. Previous submitted letter only included an oil, Gas anci Mining

exception location request and a plat that only showed the surface Date:hole.

NAME (PLEASE PRINT) PHONE NUMBER TITLEKristen Johnson 303 308-6270 Regulatory Technician


RECEIVED: Dec. 15,

RECEIVED: Apr. 14, 2015


555 17* Street, Suite 1800Crescent Point oeuver,coso2o2

ENERGY U. S. CORP Phone: (720) 880-3610

April 14, 2015

State of Utah Division of Oil, Gas and MiningAttention: Brad Hill1594 West North TempleSalt Lake City, UT84116

RE: Directional Drilling (R649-3-11) & Exception Location Request (R649-3-3)

Deep Creek 2-22-4-2ESurface Location: NWNE of Section 22

272' FNL& 1968' FELTarget Location: NWNE of Section 22

562' FNL & 1908' FELT45-R2E, USMUintah County, Utah

Dear Mr. Hill:

Pursuant to the filing of Crescent Point Energy U.S. Corp's (Crescent Point) Application for Permit to Drill regardingthe above referenced well, and in accordance with Oli & Gas Conservation Rules R649-3-11 and R649-3,3, we arehereby submitting this letter as notice of our intention to directionally drill the captioned well and request thatDOGM administratively grant an exception location for the Deep Creek 2-22-4-2E.

• The surface location was moved outside the legal window from the center of the quarter/quarter due todifficult topography. In order to be in the target window of 460' from the lot lines we needed to drift aminimum of 188' to the south of our SHL(but no more than 588' south). We ended up 291' south of our SHLputting us basically in the middle of the 40 acre lot north/south. We couldn't drift more than 162' east or263' west in order to maintain the 460' boundary lines and we ended up 60' east of our SHL.

• Crescent Point has notified and obtained consent from all other working interest owners within a 460'radius of the intended wellbore, which include Petroglyph Energy, Inc., Dusty Sanderson, Argo EnergyPartners, Slover Minerals, LP, Kerr-McGee Oil and Gas Onshore LP,and Mark Chapman.

Therefore, based on the above stated information, Crescent Polnt requests the permit be granted pursuant to R649-3-11 and R649-3-3. If you have any questions or require further information, please don't hesitate to contact theundersigned at 303-382-6766 or by email at [email protected]. Your consideration of this matter isgreatly appreciated.

Sincerely,

Jordan WellsLandman - Crescent Point Energy U.S. Corp



SCANNED

Please be advised that Petroglyph Energy, Inc does not have an objection to the directional drilling or exceptionlocation of the Deep Creek 2 22-4-2E.

BY

Name & Title

Date



Please be advised that Dusty Sanderson does not have an obyction to the directional drilling or exception location ofthe Deep Creek 2-22-4 2E

By

NarTie & Title



Please be advised that Argo Energy Partners does not have an objection to the directional drilling or exceptionlocation of the Deep Creek 2 22-4-2E.

By

Irene LaSusa, President, Argo Energy Inc. GPName & Title

10/11/13



Please be advised that Slover Minerals, LP does not have an objection to the directional drilling and surface locationof the Deep Cree 2-22-4 2E.

Name & Title



Please be advised that Kerr-McGee Oil and Gas Onshore LP does not have an objection to the directional drilling andsurface location of the Deep Creek 2-22-4-2E.

Name & Title



Please be advised that Mark Chapman does not have an objection to the directional drilling and surface location ofthe Deep Creek 2-22-4-2E.

By /

Name & Title

Division of Oil, Gas and Mining Operator Change/Name Change Worksheet-for State use only

Effective Date ' 9/ 1120 19

FORMER OPERA TOR: NEW OPERATOR: Crescent Point Energy U.S. Corporation CH4-Finley Operating, LLC

Groups: Ouray Valley-Unit

Horseshoe Bend (GR)-EOR Randlett-EOR Antelope Creek-EOR

Antelope-Unit -

Range Dir

Total Well Count: 1405

OPERATOR C HANGES DOC UMENTATION:

1. Sundry or legal documentation was received fTom the FORME R operator on: 2. Sundry or legal documentation was received fTom the NEW operator on: 3. New operator Division of Corporations Business Number: I 1468999-0161

REVIEW: Receipt of Acceptance of Drilling Procedures for APD on: Reports current for ProductionlDisposition & undries: OPS/SlrrA well(s) reviewed for full cost bonding: Approved by Dustin

12/3112019 12/ 18120 19

12/ 1812019 UIC5 on all disposal/injection/storage well(s) Approved on : Approved by Dayne Surface Facil ity(s) included in operator change:

NEW OPERATOR BOND VERIFICATION: State/fee well(s) covered by Bond Number(s):

DATA ENTRY: Well(s) update in the RBDMS on: Group(s) update in ROBMS on: Surface Facilities update in RBDMS on :

Entities Updated in RBDMS on :

COMMENTS:

None

LPM9282986-Blanket

LPM9282991-lndividual

LPM 9336805-Shut-In Bond

12/31 /20 19 12/3112019

NA 12/3 1/2019

10125/20 19

10125120 19 10/25/20 19

Shut-Ln well have until 6/1 /2020 to get into comliance or they will need to be plugged, if the well bore is need for furture use full cost bonding will be required.

Status

1/7/2020

FORM 9 STATE OF UTAH DEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING 5. LEASE DESIGNATION AND SERIAL NUMBER: see attached well list


Do not use this form for proposals to drill new wells, significantly deepen existing wells below current bottom·hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION FOR PERMIT TO DRILL form for such proposals.

1. TYPE OF WELL OIL WELL IZI GAS WELL 0 OTHER injection wells

2. NAME OF OPERATOR: Crescent Point Energy U,S, Corp,

STATE CO ZIp 80228 I PHONE NUMBER: (720) 880-3610

3. ADDRESS OF OPERATOR: 555 17th Street, Suite 1800 CITY Denver

4. LOCATION OF WELL

FOOTAGES AT SURFACE:

OTRIOTR, SECTION, TOWNSHIP, RANGE, MERIDIAN:

6. IF INDIAN, ALlOTIEE OR TRIBE NAME: see attached

7. UNIT or CA AGREEMENT NAME:

8. WELL NAME and NUMBER: see attached

9. API NUMBER: attached

10. FIELD AND POOL, OR WILDCAT: attached

COUNTY:

STATE: UTAH

11 . CHECK APPROPRIATE BOXES TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA


[l] 0 ACIDIZE 0 DEEPEN 0 REPERFORATE CURRENT FORMATION NOTICE OF INTENT

(Submit in Duplicate) 0 ALTER CASING 0 FRACTURE TREAT 0 SIDETRACK TO REPAIR WELL Approximate date wort< will start 0 CASING REPAIR 0 NEW CONSTRUCTION 0 TEMPORAflIL Y ABANDON

9/1/2019 0 CHANGE TO PREVIOUS PLANS III OPERATOR CHANGE 0 TUBING REPAIR

0 CHANGE TUBING 0 PLUG AND ABANDON 0 VENT OR FLARE

0 SUBSEQUENT REPORT 0 CHANGE WEll NAME 0 PLUG BACK 0 WATER DISPOSAL (Submit Original Form Only)

0 0 0 CHANGE WELL STATUS PRODUCTION (STARTIRESUME) WATER SHUT -OFF Date of work completion:

0 COMMINGLE PRODUCING FORMATIONS 0 RECLAMATION OF WELL SITE 0 OTHER:

0 CONVERT WELL TYPE 0 RECOMPLETE -DIFFERENT FORMATION


Please consider this sundry as notification of the transfer of operatorship of the wells listed on the attached exhibit from Crescent Point Energy U,S, Corp, to CH4-Finley Operating , LLC effective September 1, 2019.

PREVIOUS OPERATOR: Crescent Point Energy US Corp 555 17th Street, Suite 1800 Denver, CO 80202

Signature - 0 aldwin, President State/Fee ond #LPM9080271 BLM Bond #LPM9080275 BIA Bond #LPM9247918

r

NAME (PLEASE PRINT) ____________________ _

SIGNATURE ______________________ _

. .. (This space for State use 0

t ' . -DEC 3 t 2019

(

\

NEW OPERATOR: CH4-Finley Operating, LLC 5128 Apache Plume Road, Suite 300 Fort Worth, TX 76109

Signature - a hew E, Cooper, VP-Land State/Fee Bond #LPM9282986 BLM Bond #LPM9282988 BIA Bond #LPM9282987

TITLE

DATE 10/17/2019

RECEIVED

OCT 2 5 2019 (512000) (See Instructions on Reverse Side)

DIV OF Oil , GAS & MINING

API Well Number: 43047541960000 API Well Number · 2020. 1. 21. · API Well Number : 43047541960000 & 2 1 ), ' ( 1 7 , / API Well Number: 43047541960000 Crescent Point Energy U.S.

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