RECEIVED - Utah - Oil and Gas

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 6-22-4-2E

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 1586 FNL 1726 FWL SENW 22 4.0 S 2.0 E U

Top of Uppermost Producing Zone 1586 FNL 1726 FWL SENW 22 4.0 S 2.0 E U

At Total Depth 1586 FNL 1726 FWL SENW 22 4.0 S 2.0 E U

21. COUNTYUINTAH

22. DISTANCE TO NEAREST LEASE LINE (Feet)1586

23. NUMBER OF ACRES IN DRILLING UNIT40

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

920

26. PROPOSED DEPTHMD: 7259 TVD: 7259

27. ELEVATION - GROUND LEVEL

4935

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 - 7259 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

43047541920000

Permit Manager

APPROVAL

FORM 3

AMENDED REPORT

API Well Number: 43047541920000

CONFIDE

NTIAL


FORM 3STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME andDNeUeMpBCErReek6-22-4-2E

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





21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITUINTAH 1586 40

25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 7259 TVD: 7259

920

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

4935 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 APPROVAL43047541920000

Permit Manager

RECEIVED: April 02,


FORM 3STATE OF UTAH



















920


4935 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


4935 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


4935 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


4935 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 6-22-4-2E | Drilling Plan 1

Crescent Point Energy U.S. Corp Deep Creek 6-22-4-2E SE/NW of Section 22, T4S, R2E, USB&M SHL: 1586’ FNL & 1726’ FWL 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 3,214’

Mahogany 3,684’

Garden Gulch (TGR3) 4,703’

Douglas Creek 5,466’

Black Shale 5,966’

Castle Peak 6,216’

Uteland 6,508’

Wasatch 6,659’

TD 7,259’

3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals Green River Formation (Oil) 3,214’ – 6,659’ Wasatch Formation (Oil) 6,659’ – 7,259’ 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

NTIAL


Crescent Point Energy U.S. CorpDeep Creek 6-22-4-2ESE/NW of Section 22, T4S, R2E, USB&MSHL:1586' FNL& 1726' FWLUintah County, Utah

DRILLINGPLAN


Formation Depth -TVD/MDUinta Surface

Upper Green River Marker 3,214'

Mahogany 3,684'

Garden Gulch (TGR3) 4,703'

Douglas Creek 5,466'

Black Shale 5,966'

Castle Peak 6,216'

Uteland 6,508'

Wasatch 6,659'

TD 7,259'

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

Green River Formation (Oil) 3,214'-6,659'Wasatch Formation (Oil) 6,659'-7,259'

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 6-22-4-2E | Drilling Plan

RECEIVED: March 28,


Crescent Point Energy U.S. CorpDeep Creek 6-22-4-2E

SE/NW of Section 22, T4S, R2E, USB&MSHL: 1586' FNL & 1726' FWLUintah County, Utah

DRILLINGPLAN


Formation Depth - TVD/MDUinta Surface


Mahogany 3,684'



Black Shale 5,966'

Castle Peak 6,216'

Uteland 6,508'

Wasatch 6,659'

TD 7,259'



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 3,684'



Black Shale 5,966'

Castle Peak 6,216'

Uteland 6,508'

Wasatch 6,659'

TD 7,259'








RECEIVED: March 28,




DRILLINGPLAN




Mahogany 3,684'



Black Shale 5,966'

Castle Peak 6,216'

Uteland 6,508'

Wasatch 6,659'

TD 7,259'








RECEIVED: March 28,




DRILLINGPLAN




Mahogany 3,684'



Black Shale 5,966'

Castle Peak 6,216'

Uteland 6,508'

Wasatch 6,659'

TD 7,259'








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

API

16" 1,640 670 439

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' 7,259’ 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

NTIAL


4. Proposed Casing & Cementing Program

Casing Design:

Interval Design FactorsSize Weight Grade Coupling


Conductor API16" O' 40' 65 H-40 STC 1,640 670 439Hole 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' 7,259' 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:



Conductor API16" 0' 40' 65 H-40 STC 1,640 670 439Hole 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' 7,259' 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,



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,


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,

















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

NTIAL


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,








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

NTIAL



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: March 28,

RECEIVED: November 08, 2013


CONFIDE

NTIAL


R. 2 E. N

SN NB8°49'41"E 263134, STN SB9°35'53"W 2691,27'

(1319.67') (1319.67')

DEEP CREEK6-22-4-2E SCALE 1" = 1000'

UNGRADEDELEVATION: GRID NORTH

I 4936.1-----

¯¯ ¯

T. 4S.1726' ,, BASIS OF ELEVATION: USGS SPOT" ELEVATION LOCATED AT THE NW pcoRNER SECTION 23, T4S, R2E, 5ELEVATION: 4969' z LATITUDE(NADB3)

NORTH 40.125067 DEG.LONGITUDE (NAD 83)WEST 109.757409 DEG.

-- I ---- ----- - -- - - - - -

AcLATITUDE (NAD 27)

STN NORTH 40.125104 DEG.LONGITUDE (NAD 27)WEST 109.756712 DEG.

"o NORTHING657364.79EASTING

2487451.17'

DATUMSPCS UTC (NAD 27)

AC N8859'19"E 2639.91 AC NB8'S8'37"E 2639.81' AC1000 500 0 1000 2000

SURVEYOR'S STATEhiENT SC ALE FEET

I, DAVID E. HENDERAHAN, OF GRAND JUNCITON, COLORADO, HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURING AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON THE 9th DAY OF AUGUST,2013 AND THAT THIS PLAT CORRECTLY SHOWS THE LOCATION OF DEEP CREEK 6-22-4-2E AS STAKED ON THEGROUND.

LEGEND = o82626 3 gWELL LOCATION

BOTTOM HOLE LOC. (APPROX) /O FOUND MONUMENT UTAH P '03-2201

PREVIOUSLYFOUND MONUMENT

PLAT OF DRH2LWG LOCATION && ASSOCIATES, INC. SENW, SECTION 22, FOR

(307)302-5028 1414 ELKST., ROCK SPRINGS, WY82001 CRESCENT POLVT ENERGYDRAWN: 9/18/13- DEH SCALE: 1"=10W 1586'F/NL, &1726'F/WL, SECTION 22,

REVISED:N/A-. DRG.10BNo.20029 T.4S., R.1E., U.S.kl.,EXHIBIT 1-1 UINTAH COTINTY, flTAf


R. 2 E. N

SN NB8°49'41"E 263134, STN SB9°35'53"W 2691,27'

(1319.67') (1319.67')



I 4936.1-----

¯¯ ¯



-- I ---- ----- - -- - - - - -

AcLATITUDE (NAD 27)



2487451.17'


AC N8859'19"E 2639.91 AC NB8'S8'37"E 2639.81' AC

1000 500 0 1000 2000




BOTTOM HOLE LOC. (APPROX) /

O FOUND MONUMENT UTAH P '03-2201PREVIOUSLYFOUND MONUMENT





R. 2 E. N

SN NB8°49'41"E 263134, STN SB9°35'53"W 2691,27'

(1319.67') (1319.67')



I 4936.1-----

¯¯ ¯



-- I ---- ----- - -- - - - - -

AcLATITUDE (NAD 27)



2487451.17'


AC N8859'19"E 2639.91 AC NB8'S8'37"E 2639.81' AC

1000 500 0 1000 2000










R. 2 E. N

SN NB8°49'41"E 263134, STN SB9°35'53"W 2691,27'

(1319.67') (1319.67')



I 4936.1-----

¯¯ ¯



-- I ---- ----- - -- - - - - -

AcLATITUDE (NAD 27)



2487451.17'


AC N8859'19"E 2639.91 AC NB8'S8'37"E 2639.81' AC

1000 500 0 1000 2000










R. 2 E. N

SN NB8°49'41"E 263134, STN SB9°35'53"W 2691,27'

(1319.67') (1319.67')



I 4936.1-----

¯¯ ¯



-- I ---- ----- - -- - - - - -

AcLATITUDE (NAD 27)



2487451.17'


AC N8859'19"E 2639.91 AC NB8'S8'37"E 2639.81' AC

1000 500 0 1000 2000











CONFIDE

NTIAL


NeeTank

GUSHER

I FORT1)UCHESNE

BOTTLE

sos rRANDLETT' MSD Corra> 0.1 MILE 466

(191 ) 0

7000 S

PROI OSED ACCESS FORRIFFIN &ASSOCIATES, INC. CRESC ENT POINT ENERGY

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, WY82901 DELP CREEK 6-22-4-2EDRAWN:8/26/2013-RAS SCALE:1"=1MILE SECT1JN 22, T.4 S., R.2 E.

REVISED: N/A -

. DRG JOB No. 20029

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

RECEIVED: November 08,


NeeTank

GUSHER

I FORT1)UCHESNE

BOTTLE


(191 ) 0

7000 S



REVISED: N/A -

. DRG JOB No. 20029




NeeTank

GUSHER

I FORT1)UCHESNE

BOTTLE


(191 ) 0

7000 S



REVISED: N/A -

. DRG JOB No. 20029




NeeTank

GUSHER

I FORT1)UCHESNE

BOTTLE


(191 ) 0

7000 S



REVISED: N/A -

. DRG JOB No. 20029




NeeTank

GUSHER

I FORT1)UCHESNE

BOTTLE


(191 ) 0

7000 S



REVISED: N/A -

. DRG JOB No. 20029





CONFIDE

NTIAL


> 0.1 MILE .

(191)

DEEP CREE6-22-4-2E

<0.1 MILE '

PROPOSED ACCESS FOR&ASSOCIATES, INC. CRESCENT POINT ENERGY

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

REVISED: N/A -

. DRG JOB No. 20029

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



> 0.1 MILE .

(191)

DEEP CREE6-22-4-2E

<0.1 MILE '



REVISED: N/A -

. DRG JOB No. 20029




> 0.1 MILE .

(191)

DEEP CREE6-22-4-2E

<0.1 MILE '



REVISED: N/A -

. DRG JOB No. 20029




> 0.1 MILE .

(191)

DEEP CREE6-22-4-2E

<0.1 MILE '



REVISED: N/A -

. DRG JOB No. 20029




> 0.1 MILE .

(191)

DEEP CREE6-22-4-2E

<0.1 MILE '



REVISED: N/A -

. DRG JOB No. 20029





CONFIDE

NTIAL


-2- -

48-1 2E

-2E #6- -2

3E-14 1 -1

CR #2-22-

DEEP CREE

16 A #15-2

QE4DR VGLERANDLETT

UE TRIBEPELIC4N LAKE

OURAYUTEL4ND BUTTE APPROX. ROAD DISTURBANCE: 0.3± ACRES --- INSTALL CMP:

PROPOSED ROAD FOR& ASSOCIATES, INC. CRESCENT POINT ENERGY

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, WY82901 DEEP CREEK 6-22-4-2EDRAWN: 8/26/2013- RAS SCALE: 1"=200o· SECTION 22, T.4 S., R.2 E.

REVISED: N/A -. DRG JOB No. 20029 TOTAL PROPOSED LENGTH: 227.7'±

TOPO B PROPOSED ROAD - - - - EXISTING ROAD



-2- -

48-1 2E

-2E #6- -2

3E-14 1 -1

CR #2-22-

DEEP CREE

16 A #15-2

QE4DR VGLERANDLETT









-2- -

48-1 2E

-2E #6- -2

3E-14 1 -1

CR #2-22-

DEEP CREE

16 A #15-2

QE4DR VGLERANDLETT









-2- -

48-1 2E

-2E #6- -2

3E-14 1 -1

CR #2-22-

DEEP CREE

16 A #15-2

QE4DR VGLERANDLETT









-2- -

48-1 2E

-2E #6- -2

3E-14 1 -1

CR #2-22-

DEEP CREE

16 A #15-2

QE4DR VGLERANDLETT










CONFIDE

NTIAL


L B5-1 4-2E -- 0 2000

1 MILE RADIUS - -

DÉEP CREEEINVESTMENTS ET AL

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

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, WY82901 DEEP CREEK 6-22-4-2EDRAWN: 8/26/2013- RAS SCALE: 1"=2000' SECTION 22, T.4 S., R.2 E.

REVISED: N/A -

. DRG JOB No. 20029

TOPO C PROPOSED ROAD - - - - EXISTING ROAD



L B5-1 4-2E -- 0 2000

1 MILE RADIUS - -




REVISED: N/A -

. DRG JOB No. 20029




L B5-1 4-2E -- 0 2000

1 MILE RADIUS - -




REVISED: N/A -

. DRG JOB No. 20029




L B5-1 4-2E -- 0 2000

1 MILE RADIUS - -




REVISED: N/A -

. DRG JOB No. 20029




L B5-1 4-2E -- 0 2000

1 MILE RADIUS - -




REVISED: N/A -

. DRG JOB No. 20029





CONFIDE

NTIAL


P 2E-2E #3- 2E 4 -

---

BEGIN SURVEY .

ÚŒCR END SURVEYAT2 5-22 FUTURE PIPLEINE

DEEP CREEKINVESTMENTS ET AL EEP

PROPOSED PIPELINE FOR

& ASSOCIATES, INC. CRESCENT POINT ENERGYson se2.so2e 1414 ELK ST., ROCK SPRINGS, WY82901 DEEP CREEK 6-22-4-2E

DRAWN: 8/26/2013- RAS SCALE: 1"=200o· SECTION 22, T.4 S., R.2 E.REVISED: N/A -. DRG JOB No. 20029 TOTAL PROPOSED LENGTH: 207.9'±

TOPO D PROPOSED PIPELINE- - - EXISTING ROAD



P2E

-2E #3- 2E 4 ----

BEGIN SURVEY .









P2E

-2E #3- 2E 4 ----

BEGIN SURVEY .









P2E

-2E #3- 2E 4 ----

BEGIN SURVEY .









P2E

-2E #3- 2E 4 ----

BEGIN SURVEY .









. .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

NTIAL


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

NTIAL


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




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 6-22-4-2E SE/NW of Section 22, T4S, R2E

1586’ FNL & 1726’ FWL 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 1586’ FNL & 1726’ FWL 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)


SE/NW of Section 22, T4S, R2E1586' FNL& 1726' FWLUBS&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 1586' FNL & 1726' FWLof Section 22, Township 45, 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

RyamWaßer

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 6-22-4-2ESE/NW of Section 22, T4S, R2E1586' FNL& 1726' FWLUBS&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 1586' FNL& 1726' FWLof Section 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.




RyawWaßer

Ryan WallerLandman





November 6, 2013



Dear Ms. Mason:





RyawWaßer

Ryan WallerLandman





November 6, 2013



Dear Ms. Mason:





RyawWaßer

Ryan WallerLandman





November 6, 2013



Dear Ms. Mason:





RyawWaßer

Ryan WallerLandman




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120' 30'ô

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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 6-22-4-2E

DRAWN: 8/26/2013- RAS SCALE: 1"=6o. SECTION 22, T.4 S., R.2 E.REVISED: N/A -. DRG JOB No. 20029 UNGRADED ELEVATION: 4936.1

FIGURE 1A FINISHED ELEVATION: 4935.2



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(son 362-502¿ 1414 ELK ST., ROCK SPRINGS, WY82901 SECTION 22 , T. 4 S., R.2 E.DRAWN:8/26/2013-RAS SCALE:HORZ1"=50'VERT1"=10'

REVISED: N/A -. DRG JOB No. 20029 UNGRADED ELEVATION: 4936.1FIGURE2 FINISHED ELEVATION: 4935.2



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DEEP CREEKTRIBAL 8-17-4-2E4304751736

UTE TRIBAL5-21-4-2E4304752028

UTE TRIBAL11-21-4-2E4304752030

Ute Tribal3-28-4-2E4304752037

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

COLEMAN TRIBAL9-17-4-2E4304752212

COLEMAN TRIBAL16-17-4-2E4304752217

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 CREEK2-16-4-2E4304752446

DEEP CREEK4-16-4-2E4304752448

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 Tribal5-28-4-2E4304753890

Ute Tribal7-28-4-2E4304753891

Ute Tribal6-28-4-2E

4304753892

Ute Tribal12-21-4-2E

4304753893

Ute Tribal14-21-4-2E4304753894

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

R A N D L E T TR A N D L E T TW A T E R F L O O DW A T E R F L O O D

P R O J E C TP R O J E C T

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

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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: 4304754192Well Name: Deep Creek 6-22-4-2E Township: T04.0S Range: R02.0E Section: 22 Meridian: U

Operator: CRESCENT POINT ENERGY U.S. CORP

Map Prepared: 11/12/2013


CONFIDE

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DEEPCREEK 3D PC2REEEK 2DEEP4-CREEK D PC4EEKLAMB LAMB 2 - EBAL

API Number: 43047541924-16-4-2E 4304752446 43047521i12 +4-15-4-2E 3-15-4-2E 43047522024304752448 4304752413 4304753015 4304753014 * Well Name: Deep Creek 6-22-4-2E

DEEP CRE EK Township: TO4.0S Range: RO2.0E Section: 22 Meridian: UTRIBA5L187-7-4-2E

DEEPCREEK DEEPCREEK DEEPCREEKEP4-C EEK 5

MB4-2E6

MB4-2EUTE TRIBAL UTETRIB/,L Operator: CRESCENT POINT ENERGY U.S. CORP

5-16-4-2E 6-16-4-2E 7-16-4-2E4304752450

4304753016 4304753017 7-15-4-2E 8-15-4-2E

17 4304752416 4304752449 4304752418 * 44304752203 43047522C4*

1615 Map Prepared: 11/12/2013


COLEMAtl TRIBAL 9-4-R2IllAL

DEEP CREEK DEEP CREEK DEEP CRI EK9-17-4-2 UTETRIBAL

4304752 0512-15-4-2E

DEEPCREEK 10-15-4-2E 9-15-4-2E 14 MllsQuery Units

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52E l R2EBAL 5-320

74E93e4304754192

Deep Creeke usw w ersuppiyweii coMeiNED

4304752028 e 8-22-4-214304754 02 37°"^°E

2122 Deep Creek eep Crt ek : TERMiNATED

7-22-4-2E 9-22-4-21.

Ute TribalD1ee2p2-eeEk 4304754182 1304754 81

20 12-21-4-2E UTE TRIBAL 234304753893 11-21-4-2E Deep Creek 4304754179

icLocation Map

4304752030 12-22-4-2E4304754101

Deep CreekD4ee2p2-CeEk

13-22-4-2E4304754185

UTE TRIBAL430475418 Deep Cree Deep Cree

13-21-4-2E Ute Tribal 15-22-4-2 16-22-4-2E UT^H ^H

4304751170 14-21-4-2E 4304754184 Deep Creek 4304754184304753894 10-22-4-2E e cAasoN

27

lJ30E24 IBAL

29 Ute Tribal Ute Tribal Ute Tribal 26

6-28-4-2E 5-28-4-2E 7-28-4-2E

aand753AAQ e43047538904304753891

I00 850 0 1.700Feet

I 1:16,807







MB4-2E6


5-16-4-2E 6-16-4-2E 7-16-4-2E4304752450

4304753016 4304753017 7-15-4-2E 8-15-4-2E

17 4304752416 4304752449 4304752418 * 44304752203 43047522C4*

1615 Map Prepared: 11/12/2013




4304752 0512-15-4-2E



WATERFLOOD "s".s

"" ""'°



FsEcoNDARY



4304752217 2D-2 EckDARY


4304754195 1-3207 41 3

Temp Abandonea


ABANooNED


52E l R2EBAL 5-320

74E93e4304754192


4304752028 e 8-22-4-214304754 02 37°"^°E


7-22-4-2E 9-22-4-21.



icLocation Map

4304752030 12-22-4-2E4304754101


13-22-4-2E4304754185




27

lJ30E24 IBAL


6-28-4-2E 5-28-4-2E 7-28-4-2E

aand753AAQ e43047538904304753891

I00 850 0 1.700Feet

I 1:16,807







MB4-2E6


5-16-4-2E 6-16-4-2E 7-16-4-2E4304752450

4304753016 4304753017 7-15-4-2E 8-15-4-2E

17 4304752416 4304752449 4304752418 * 44304752203 43047522C4*

1615 Map Prepared: 11/12/2013




4304752 0512-15-4-2E



WATERFLOOD "s".s

"" ""'°



FsEcoNDARY



4304752217 2D-2 EckDARY


4304754195 1-3207 41 3

Temp Abandonea


ABANooNED


52E l R2EBAL 5-320

74E93e4304754192


4304752028 e 8-22-4-214304754 02 37°"^°E


7-22-4-2E 9-22-4-21.



icLocation Map

4304752030 12-22-4-2E4304754101


13-22-4-2E4304754185




27

lJ30E24 IBAL


6-28-4-2E 5-28-4-2E 7-28-4-2E

aand753AAQ e43047538904304753891

I00 850 0 1.700Feet

I 1:16,807







MB4-2E6


5-16-4-2E 6-16-4-2E 7-16-4-2E4304752450

4304753016 4304753017 7-15-4-2E 8-15-4-2E

17 4304752416 4304752449 4304752418 * 44304752203 43047522C4*

1615 Map Prepared: 11/12/2013




4304752 0512-15-4-2E



WATERFLOOD "s".s

"" ""'°



FsEcoNDARY



4304752217 2D-2 EckDARY


4304754195 1-3207 41 3

Temp Abandonea


ABANooNED


52E l R2EBAL 5-320

74E93e4304754192


4304752028 e 8-22-4-214304754 02 37°"^°E


7-22-4-2E 9-22-4-21.



icLocation Map

4304752030 12-22-4-2E4304754101


13-22-4-2E4304754185




27

lJ30E24 IBAL


6-28-4-2E 5-28-4-2E 7-28-4-2E

aand753AAQ e43047538904304753891

I00 850 0 1.700Feet

I 1:16,807



BOPE REVIEW CRESCENT POINT ENERGY U.S. CORP Deep Creek 6-22-4-2E 43047541920000

Well Name CRESCENT POINT ENERGY U.S. CORP Deep Creek 6-22-4-2E 43047541920000

String Cond Surf Prod

Casing Size(") 16.000 8.625 5.500

Setting Depth (TVD) 4 0 1000 7259

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) 3775 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= 3775


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= 2904 YES 3M BOPE & annular, rotating head, blind ram,

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= 2178 YES pipe rams, kill & choke lines


Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= 2398 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

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Casing Size(") 16.000 8.625 5.500

Setting Depth (TVD) 40 1000 7259

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=

3775


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=2904 3M BOPE & annular, rotating head, blind ram,

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=2178 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









3775








Calculations String









RECEIVED: April 01,





Casing Size(") 16.000 8.625 5.500








17









432









3775








Calculations String









RECEIVED: April 01,





Casing Size(") 16.000 8.625 5.500








17









432









3775








Calculations String









RECEIVED: April 01,





Casing Size(") 16.000 8.625 5.500








17









432









3775








Calculations String









RECEIVED: April 01,



CONFIDE

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43047541920000 Det p Creek 6-22-4-2ECasing Schemt i: N

surface '

I TOC @ L0.

oc o

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

5-1/2" r ProductionMW 10. 259.



surface '

I TOC @ L0.

oc o





surface '

I TOC @ L0.

oc o





surface '

I TOC @ L0.

oc o





surface '

I TOC @ L0.

oc o





CONFIDE

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Well name: 43047541920000 Deep Creek 6-22-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Surface Project ID:

43-047-54192Location: 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: 7,259 ftTension is based on buoyed weight. Next mud weight: 10.000 ppgNeutral point: 875 ft Next setting BHP: 3,771 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 Burst Burst Burst Tension Tension TensionSeq Load Strength Design Load Strength Design Load Strength Design

(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factori 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 responsibility for use of thisdesign wi/Ibe thatof the























































































CONFIDE

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Well narne: 43047541920000 Deep Creek 6-22-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Production Project ID:




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



pressure: 2,174 psiInternal gradient: 0.220 psilft Tension: Non-directional string.Calculated BHP 3,771 psi 8 Round STC: 1.80 (J)


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

Tension is based on buoyed weight.Neutral point: 6,158 ft


(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 7259 5.5 17.00 E-80 LT&C 7259 7259 4.767 239547


(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 3771 6290 1.668 3771 7740 2.05 104.7 320 3.06 J


Remarks:Collapse is based on a vertical depth of 7259 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.




















































































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

Operator CRESCENT POINT ENERGY U.S. CORP Well Name Deep Creek 6-22-4-2EAPI Number 43047541920000 APD No 9 0 4 1 Field/Unit UNDESIGNATEDLocation: 1/4,1/4 SENW Sec 22 T w 4.0S Rng 2.0E 1586 FNL 1726 FWLGPS Coord (UTM) 605889 4442339 Surface Owner Lee Smith

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

Regional/Local Setting & TopographyLocation is in the Deep Creek area in an historic floodplain below two benches Known as theLeland bench in Uintah County. The region is deeply incised and eroded clay sedimentssurrounded by a bench and the occassional butte with sandstone caps. The area hastradit ionally been used for Spring graze for sheep but, has seen heavy development forpetroleum extraction. The ground is rather bare of vegetation and wildlife sightings are rare.Numerous drainages though shal low and ephemeral are noted throughout the region.

Surface Use PlanCurrent Surface UseGrazing

New RoadMiles

Well Pad Src Const Material Surface Formation

0 .04 Width 150 Length 3 5 0 Onsi te UNTA

Ancillary Facilities

Waste Management Plan Adequate?

Environmental ParametersAffected Floodplains and/or Wetlands Y

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

Erosion Issues Y


CONFIDE

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Operator CRESCENT POINT ENERGY U.S. CORPWell Name Deep Creek 6-22-4-2E

API Number 43047541920000 APD No 9041 Field/Unit UNDESIGNATEDLocation: 1/4,1/4SENW Sec 22 Tw 4.0S Rng 2.0E 1586 FNL 1726 FWLGPS Coord (UTM) 605889 4442339 Surface Owner Lee Smith


Regional/Local Setting & TopographyLocation is in the Deep Creek area in an historic floodplain below two benches Known as theLeland bench in Uintah County. The region is deeply incised and eroded clay sedimentssurrounded by a bench and the occassional butte with sandstone caps. The area hastraditionally been used for Spring graze for sheep but, has seen heavy development forpetroleum extraction. The ground is rather bare of vegetation and wildlife sightings are rare.Numerous drainages though shallow and ephemeral are noted throughout the region.


New Road Well Pad Src Const Material Surface FormationMiles0.04 Width 150 Length 350 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

Erosion Issues Y

RECEIVED: April 02,














Erosion Issues Y

RECEIVED: April 02,














Erosion Issues Y

RECEIVED: April 02,














Erosion Issues Y

RECEIVED: April 02,














Erosion Issues Y

RECEIVED: April 02,


Sedimentation Issues Y

Site Stability Issues N

Drainage Diverson Required? Y

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 / Commentspad si tuated between to outcroppings and pretty f lat . # drainages exist across pad. Plans showdiversion for these

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.


Other Observations / Commentspad situated between to outcroppings and pretty flat. # drainages exist across pad. Plans showdiversion for these

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,





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 4 1 43047541920000 LOCKED OW P N oOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Lee SmithWell Name Deep Creek 6-22-4-2E UnitField UNDESIGNATED Type of Work DRILL

Location SENW 22 4S 2E U 1586 FNL 1726 FWL GPS Coord(UTM) 605888E 4442340N

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 900'. 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 bedril led directionally. Access road enters the pad from the North. The landowner or i tsrepresentat ive was in at tendance for the pre-si te inspection.The soil type and topography at present do combine to pose a significant threat to erosionor 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. Plans include measures for the diversion of drainages and padfootprint has been modified to lessen disturbance to these. Reserve pit is in an area of cut. I quickly 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 adjacent the site tothe North. The location was not previously surveyed for cultural and paleontologicalresources ( as the operator saw fit) . I have advised the operator take all measures necessaryto comply with ESA and MBTA and that actions insure no disturbance to species that mayhave not been seen 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 stabili ty issues. A diversion is to be built sufficient to conduct overlandor channel f low from a natural channel west of the pad between corners 4 and 2, aroundthe corner North and past marker 1 to reintroduce f lows back into the natural channeloffsite.


CONFIDE

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I


Utah Division of Oil, Gas and MiningI

APD No API WellNo Status Well Type Surf Owner CBM9041 43047541920000 LOCKED OW P NoOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Lee SmithWell Name Deep Creek 6-22-4-2E UnitField UNDESIGNATED Type of Work DRILL

. SENW 22 4S 2E U 1586 FNL 1726 FWL GPS CoordLocation(UTM) 605888E 4442340N

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 900'. 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 North. The landowner or itsrepresentative was in attendance for the pre-site inspection.The soil type and topography at present do combine to pose a significant threat to erosionor sediment/ pollution transport in these regional climate conditions.Usual construction standards of the Operator appear to be adequate for the proposedpurpose as submitted. Plans include measures for the diversion of drainages and padfootprint has been modified to lessen disturbance to these. Reserve pit is in an area of cut.I quickly 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 adjacent the site tothe North. The location was not previously surveyed for cultural and paleontologicalresources ( as the operator saw fit). I have advised the operator take all measures necessaryto comply with ESA and MBTA and that actions insure no disturbance to species that mayhave not been seen 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. A diversion is to be built sufficient to conduct overlandor channel flow from a natural channel west of the pad between corners 4 and 2, aroundthe corner North and past marker 1 to reintroduce flows back into the natural channeloffsite.

RECEIVED: April 02,


I








RECEIVED: April 02,


I








RECEIVED: April 02,


I








RECEIVED: April 02,


I








RECEIVED: April 02,


Chris JensenOnsite Evaluator

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

Conditions of Approval / Application for Permit to DrillCategory ConditionPits A synthetic l iner with a minimum thickness of 16 mils with a felt subliner shall be properly installed

and maintained in the reserve pit .Surface Drainages adjacent to the proposed pad shall be diverted around the location.Surface The well site shall be bermed to prevent fluids from entering or leaving the pad.Surface The reserve pit shall be fenced upon completion of dril l ing operations.


CONFIDE

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

Conditions of Approval / Application for Permit to DrillCategory ConditionPits A synthetic liner with a minimum thickness of 16 mils with a felt subliner shall be properly installed

and maintained in the reserve pit.Surface Drainages adjacent to the proposed pad shall be diverted around the location.Surface The well site shall be bermed to prevent fluids from entering or leaving the pad.Surface The reserve pit shall be fenced upon completion of drilling operations.

RECEIVED: April 02,





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: 43047541920000

WELL NAME: Deep Creek 6-22-4-2E

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

CONTACT: Emily Kate DeGrasse

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

SURFACE: 1586 FNL 1726 FWL Engineering Review:

BOTTOM: 1586 FNL 1726 FWL Geology Review:

COUNTY: UINTAH

LATITUDE: 40.12472 LONGITUDE: -109.75726

UTM SURF EASTINGS: 605888.00 NORTHINGS: 4442340.00

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


CONFIDE

NTIAL



I

I

APD RECEIVED: 11/8/2013 APINO.ASSIGNED: 43047541920000







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








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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,



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I








COUNTY: UINTAH




LEASE TYPE: 4 - Fee



I


PLAT R649-2-3.



Oil Shale 190-5








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RECEIVED: April 02,

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

Well Name: Deep Creek 6-22-4-2EAPI Well Number: 43047541920000

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



















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:




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 6-22-4-2E

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

9. API NUMBER: 43047541920000

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: 1586 FNL 1726 FWL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: SENW 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 6-22-4-2E withPete Martin Drilling Rig 11 on June 9, 2014 at 10am.

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: 52076 API Well Number: 43047541920000Sundry Number: 52076 API Well Number: 43047541920000

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 6-22-4-2E

2. NAME OF OPERATOR: 9. API NUMBER:CRESCENT POINT ENERGY U.S. CORP 43047541920000

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

1586 FNL 1726 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:

QtrlQtr: SENW 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 6-22-4-2E with Accepted by thePete Martin Drilling Rig 11 on June 9, 2014 at 10am. 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: 52076 API Well Number: 43047541920000

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,


FORM 9STATE OF UTAH

























Oil, Gas and Mining

FORM 9819 ONLY



RECEIVED: Jun. 10,

RECEIVED: Sep. 02, 2014



FORM 9









9. API NUMBER: 43047541920000




COUNTY: UINTAH

STATE: UTAH

11.







9 /2 /2014












Attached please find driling report for Crescent Point Energy's DeepCreek 6-22-4-2E, encompassing all drilling activities to date.

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

TITLE Regulatory Specialist

SIGNATURE N/A

DATE 9 /2 /2014

September 02, 2014


FORM 9STATE OF UTAH






















9/2/2014WILDCATWELLDETERMINATION OTHER OTHER:


Attached please find driling report for Crescent Point Energy's Deep Accepted by theCreek 6-22-4-2E, encompassing all drilling activities to date. Utah Division of

Oil, Gas and Mining

FOR RECORD ONLYSeptember 02, 2014

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


RECEIVED: Sep. 02,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Sep. 02,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Sep. 02,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Sep. 02,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Sep. 02,


Page 1/1

Well Name: DEEP CREEK 6-22-4-2E

Report Printed: 9/2/2014www.peloton.com

Daily Drilling Report

AFE Number

1753213USStart Depth (ftKB)

1,020.0End Depth (ftKB)

1,020.0Target Formation

WASATCHTarget Depth (ftKB)

7,259.0Last Casing String

Surface, 1,013.0ftKB

Daily ContactsJob Contact Mobile

Rigs

Capstar, 316Contractor

CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601

<des>, <make>, <model>Pump # Pwr (hp) Rod Dia (in)

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

P (psi) Slow Spd Strokes (s… Eff (%)

Mud Additive Amounts

DesField Est

(Cost/unit)Consume

d

Barite 10.65 304.0

Engineering 450.00 1.0

Rental 50.00 1.0

Safety ChecksTime Type Des

WellboresWellbore Name KO MD (ftKB)

Original Hole

Report #: 1.0, DFS: 0.13

UWI/API

43-047-54192Surface Legal Location

6-22-4-2License #

FEESpud Date

6/9/2014 10:00Date TD Reached (wellbore) Rig Release Date

9/2/2014 06:00Ground Elevation (ft)

4,935.00Orig KB Elev (ft)

4,947.00Completion Type

Weather Temperature (°F) Road Condition Hole Condition

Operation At 6am

W.O.Drilling 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 @10:00 6/09/2014MIRU Pro Petro Rig #10, Drill 1032' KB 12 1/4" Surface hole,R/U & run 1013' KB 8 5/8" 24# surface CSG,Cement W/675 sks 15.8 ppg 1.15 cuft/sk yield cement,25 bbls good cement T/Surf,cement stayed @ Surf,R/D cementers,wait on drillling rig

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 #1, Kick OffBit Run

1Drill Bit

7 7/8in, MDI616, JJ6889Length (ft)

1.00IADC Bit Dull

0-0-0---i-0-TDTFA (incl Noz) (in²)

1.18BHA ROP …

52.8Nozzles (1/32")

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

583.98Max 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

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

Original Hole 1,020.0 1,020.0

Depth Progress: 0.00

Report for: 8/25/2014


< p Daily Drilling Report Report for: 8/25/2014

c"""YW11 ??NT Report #: 1.0, DFS: 0.13

Well Name: DEEP CREEK 6-22-4-2EDepth Progress: 0.00

UWl/API Surface Legal Location License # AFE Number43-047-54192 6-22-4-2 FEE 1753213USSpud Date Date TD Reached (wellbore) Rig Release Date Ground Elevation (ft) Orig KB Elev (ft) Start Depth (ftKB) End Depth (ftKB)

6/9/2014 10:00 9/2/2014 06:00 4,935.00 4,947.00 1,020.0 1,020.0Completion Type Target Formation Target Depth (ftKB)

WASATCH 7,259.0Weather Temperature (°F) Road Condition Hole Condition Last Casing String

Surface, 1,013.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsW.O.Drilling 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 @10:006/09/2014MIRU Pro Petro Rig #10, Drill 1032' KB 12 1/4" Surface hole,R/U Rigs& run 1013' KB 8 5/8" 24# surface CSG,Cement Wl675 sks 15.8 ppg 1.15 cuft/sk yield cement,25 bbls good cement Capstar, 316T/Surf,cement stayed @Surf,R/D cementers,wait on drillling rig Contractor Rig Number

Time Log Capstar 316

Start Cum Dur AtyRiy 3uµeisiaal Phone Mobile

Time End Time Dur (hr) (hr) Code Activity Com JAKE 713-481-7601

<des>, <make>, <model>

Mud CheckS Pump# Pwr (hp) Rod Dia (in)

<depth>ftKB, <dttm>I inar Rive fin) Stroke (in) Vol/Stk OR (b...

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

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

Field Est Consume

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Des (Cost/unit) d

Barite 10.65 304.0

Drill Strings Engineering 450.00 1.0BHA #1, Kick Off Rental 50.00 1.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...

1 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8 Safety ChecksNozzles (1/32") String Length (ft) Max Nominal OD (in) Time Type Des

16/16/16/16/16/16 583.98 6.500String Components

SMITH MDI616, Mud Motor, UBHO, NMDC, Drill Collar, HWDP WellboresComment Wellbore Name KO MD (ftKB)

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- Original Hole6.125"x 2.375" DC)(10-4.5" HWDP)Drilling Parameters

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


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



c"""YW11 ??NT Report #: 1.0, DFS: 0.13

















Field Est Consume


Barite 10.65 304.0

Drill Strings Engineering 450.00 1.0

BHA #1, Kick Off Rental 50.00 1.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...





CumDrill WOB






c"""YW11 ??NT Report #: 1.0, DFS: 0.13

















Field Est Consume


Barite 10.65 304.0







CumDrill WOB






c"""YW11 ??NT Report #: 1.0, DFS: 0.13

















Field Est Consume


Barite 10.65 304.0







CumDrill WOB






c"""YW11 ??NT Report #: 1.0, DFS: 0.13

















Field Est Consume


Barite 10.65 304.0







CumDrill WOB





Page 1/1




AFE Number








Floyd Mitchell 823-3608

DOUG HACKFORD 970-640-3882

Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601





DesField Est

(Cost/unit)Consume

d

Barite 10.65 304.0


Rental 50.00 1.0



Original Hole

Report #: 2.0, DFS: 0.13

UWI/API


6-22-4-2License #

FEESpud Date





Weather

RAININGTemperature (°F)

66.0Road Condition

FAIRHole Condition

GoodOperation At 6am

TEST BOPSOperation Next 24hrs

PICK UP BHA & DRILL OUT24 Hr Summary

WAIT ON LOCATION BLADE OFF MUD & HAUL IN ROCK / MOVE IN RIG UP NIPPLE UP & TEST BOPS


Cum Dur (hr)


06:00 13:00 7.00 7.00 1 RIGUP & TEARDOWN

WAIT ON LOCATION HAULING IN ROCK

13:00 23:00 10.00 17.00 1 RIGUP & TEARDOWN

MOVE IN RIG UP CAPSTAR # 316

23:00 03:00 4.00 21.00 14 NIPPLE UP B.O.P

NIPPLE UP BOPS

03:00 06:00 3.00 24.00 15 TEST B.O.P TEST BOPS PIPE BLINES & CHOKE ALL 3000 PSI F/ 10 MIN ANN 1500 F/ 10 MIN & CASING 1500 F/ 30 MINS

Mud Checks





Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

52.8Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf








< p Daily Drilling Report Report for: 8/25/2014cr esygr oi 5 Report #: 2.0, DFS: 0.13





RAINING 66.0 FAIR Good Surface, 1,013.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsTEST BOPS PICK UP BHA & DRILL OUT


WAIT ON LOCATION BLADE OFF MUD & HAUL IN ROCK / MOVE IN RIG UP NIPPLE UP & TEST BOPS Floyd Mitchell 823-3608

Time LogDOUG HAGKFORD 970-640-3882

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

06:00 13:00 7.00 7.00 1 RIGUP & WAIT ON LOCATION HAULING IN ROCK Capstar, 316TEARDOWN Contractor Rig Number

13:00 23:00 10.00 17.00 1 RIGUP & MOVE IN RIG UP CAPSTAR # 316 Gapstar 316TEARDOWN Rig Supervisor Phone Mobile

JAKE 713-481-760123:00 03:00 4.00 21.00 14 NIPPLE UP NIPPLE UP BOPS

B.O.P <des>, <make>, <model>

Pump# Pwr(hp) RodDia(in)03:00 06:00 3.00 24.00 15 TEST B.O.P TEST BOPS PIPE BLINES & CHOKE ALL 3000 PSI F/ 10 MIN

ANN 1500 F/ 10 MIN & CASING 1500 F/ 30 MINS Liner Size (in) Stroke (in) Vol/Stk OR (b...

Mud Checks<depth>ftKB, <dttm>

F (psi) Slow Spd Strokes (s... Eff (%)


Mud Additive AmountsGel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) Field Est Consume

Des (Cost/unit) d

MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2) Bar|Le 10.65 304.0Engineering 450.00 1.0

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Rental 50.00 1.0

Drill Strings Safety ChecksBHA #1, Kick Off Time Type Des

Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...

1 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8Nozzles (1/32") String Length (ft) Max Nominal OD (in) Wellbores16/16/16/16/16/16 583.98 6.500 Wellbore Name KO MD (ftKB)

String Components Original HoleSMITH 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

CumDrill WOB

























Des (Cost/unit) d

MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2) Bar|Le 10.65 304.0

Engineering 450.00 1.0Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Rental 50.00 1.0






CumDrill WOB

























Des (Cost/unit) d








CumDrill WOB

























Des (Cost/unit) d








CumDrill WOB

























Des (Cost/unit) d








CumDrill WOB





Page 1/1




AFE Number










Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601





DesField Est

(Cost/unit)Consume

d

DAP 35.00 10.0


Rental 50.00 1.0

Tax 1.00 25.0



Original Hole

Report #: 3.0, DFS: 1.13

UWI/API


6-22-4-2License #

FEESpud Date





Weather

RAINING OFF & ONTemperature (°F)

66.0Road Condition

FAIR / LOC. MUDDYHole Condition


DRILLING & SLIDING W/ MWD @ 2075' 95 FPHOperation Next 24hrs

DRILL PROD. HOLE24 Hr Summary

TEST BOPS PICK UP BHA , TRIP IN . CUT DRILLING LINE DRILL CEMENT THEN FORMATION


Cum Dur (hr)


06:00 09:30 3.50 3.50 15 TEST B.O.P TEST BOPS PIPE ; BLINES & CHOKE 3000 F/5 MINS ANULAR 1500 PSI F/ 10 MINS CASING 1500 F/ 30 MIN ALL OK

09:30 12:00 2.50 6.00 6 TRIPS PICK UP BHA & DIR. TOOLS & TRIP IN HOLE

12:00 13:00 1.00 7.00 9 CUT OFF DRILL LINE

CUT DRILLING LINE

13:00 18:00 5.00 12.00 21 OPEN TAG @ 890 DRILL PLUG CEMENT FLOAT & SHOE

18:00 00:00 6.00 18.00 2 DRILL ACTUAL

DRILLING F/ 1020 TO 1537 ( 86 FPH ) 390 GAL 12 K ON BIT 122 TOTAL RPMS NO LOSSES

00:00 00:30 0.50 18.50 7 LUBRICATE RIG

RIG SERVICE

00:30 06:00 5.50 24.00 2 DRILL ACTUAL

DRILLING F/ 1537 TO 2075 ( 98 FPH ) 390 GAL 14 -16 K ON BIT 122 TOTAL RPMS 40 BBL LOST TO HOLE

Mud Checks

1,100.0ftKB, 8/26/2014 17:00Type

WaterTime

17:00Depth (ftKB)

1,100.0Density (lb/gal)

8.80Funnel Viscosity (s/qt) PV Override (cP) YP OR (lbf/100ft²)

Gel 10 sec (lbf/100ft²)

1.000Gel 10 min (lbf/100ft²)

1.000Filtrate (mL/30min) Filter Cake (1/32") pH

8.0Sand (%)

0.0Solids (%)

2.0MBT (lb/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (lbf/100ft²)


Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

52.8Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 1,020.0 2,075.0 1,055.00

11.50 91.7 390 16 60 1,100.0 59 63 8,000.0

Depth Progress: 1,055.00




c"""YW11 ??NT Report #: 3.0, DFS: 1.13

Well Name: DEEP CREEK 6-22-4-2EDepth Progress: 1,055.00




RAINING OFF & ON 66.0 FAIR / LOC. MUDDY Good Surface, 1,013.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDRILLING & SLIDING W/ MWD @2075'95 FPH DRILL PROD. HOLE


TEST BOPS PICK UP BHA , TRIP IN . CUT DRILLING LINE DRILL CEMENT THEN FORMATION Floyd Mitchell 823-3608

Time Log UUUU HAUKEukU 970-640-3882


06:00 09:30 3.50 3.50 15 TEST B.O.P TEST BOPS PIPE ; BLINES & CHOKE 3000 F/5 MINS ANULAR Capstar, 3161500 PSI F/ 10 MINS CASING 1500 F/ 30 MIN ALL OK Contractor Rig Number

Capstar 31609:30 12:00 2.50 6.00 6 TRIPS PICK UP BHA & DIR. TOOLS & TRIP IN HOLE Rig Supervisor Phone Mobile

^l'E 713-481-760112:00 13:00 1.00 7.00 9 CUT OFF CUT DRILLING LINE

DRILL LINE <des>, <make>, <model>

13:00 18:00 5.00 12.00 21 OPEN TAG @890 DRILL PLUG CEMENT FLOAT & SHOEPiimpu Pwr(hp) RodDia(in)

18:00 00:00 6.00 18.00 2 DRILL DRILLING F/ 1020 TO 1537 ( 86 FPH ) 390 GAL 12 K ON BIT Liner Size (in) Stroke (in) Vol/Stk OR (b...

ACTUAL 122 TOTAL RPMS NO LOSSES

00:00 00:30 0.50 18.50 7 LUBRICATE RIG SERVICE F (e i) SlowSpd Strokes (s... Eff(%)

RIG

00:30 06:00 5.50 24.00 2 DRILL DRILLING F/ 1537 TO 2075 (98 FPH ) 390 GAL 14 -16 K ON f.1ud Additive Arna unta

ACTUAL BIT 122 TOTAL RPMS 40 BBL LOST TO HOLE Des ( ot/uEnst Consume

Mud Checks DAP 35.00 10.01,100.0ftKB, 8/26/2014 17:00 Engineering 450.00 1.0Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

Rental 50.00 1.0Water 17:00 1,100.0 8.80Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) Tax 1.00 25.0

1.000 1.000 8.0 0.0 2.0MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2 Safety Checks

Time Type Des


WollboresDrill StringS

Wellbore Name KO MD (ftKB)BHA #1, Kick Off Original HoleBit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...

1 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8Nozzles (1/32") String Length (ft) Max Nominal OD (in)




CumDrill WOB


Original Hole 1,020.0 2,075.0 1,055.0 11.50 91.7 390 16 60 1,100.0 59 63 8,000.O O




c"""YW11 ??NT Report #: 3.0, DFS: 1.13


















RIG






Time Type Des








CumDrill WOB


Original Hole 1,020.0 2,075.0 1,055.0 11.50 91.7 390 16 60 1,100.0 59 63 8,000.O O




c"""YW11 ??NT Report #: 3.0, DFS: 1.13


















RIG






Time Type Des








CumDrill WOB


Original Hole 1,020.0 2,075.0 1,055.0 11.50 91.7 390 16 60 1,100.0 59 63 8,000.O O




c"""YW11 ??NT Report #: 3.0, DFS: 1.13


















RIG






Time Type Des








CumDrill WOB


Original Hole 1,020.0 2,075.0 1,055.0 11.50 91.7 390 16 60 1,100.0 59 63 8,000.O O




c"""YW11 ??NT Report #: 3.0, DFS: 1.13


















RIG






Time Type Des








CumDrill WOB


Original Hole 1,020.0 2,075.0 1,055.0 11.50 91.7 390 16 60 1,100.0 59 63 8,000.O O



Page 1/1




AFE Number










Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601





DesField Est

(Cost/unit)Consume

d

DAP 35.00 14.0


Hole Seal 21.00 8.0

Rental 50.00 1.0

Sea Mud 15.50 60.0

Tax 1.00 110.0



Original Hole

Report #: 4.0, DFS: 2.13

UWI/API


6-22-4-2License #

FEESpud Date





Weather

STILL RAIN OFF & ONTemperature (°F)

62.0Road Condition

POORHole Condition


DRILLING @ 3825' 70 FPHOperation Next 24hrs

DRILL 7 7/8 PROD. HOLE24 Hr Summary

DRILL F/ 2075' TO 3825 STARTED LIGHT MUD UP AT 3500' BBG 456-757 UNITS CONNS 320-546 W/ A PEAK OF 1246 UNITS @ 3626 DRILLING 50% CLAY STONE & 50% SHALE


Cum Dur (hr)


06:00 16:30 10.50 10.50 2 DRILL ACTUAL

DRILLING F/ 2075 TO 2949 ( 83 FPH ) 390 GAL 14 -16 K ON BIT 122 TOTAL RPMS 80 BBL LOST TO HOLE

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 F/ 2949 TO 3825 ( 67 FPH ) 390 GAL 14 -16 K ON BIT 122 TOTAL RPMS 130 BBLS LOST TO HOLE

Mud Checks

2,948.0ftKB, 8/27/2014 17:00Type

waterTime

17:00Depth (ftKB)


9.10Funnel Viscosity (s/qt)

31PV Override (cP)

1.0YP OR (lbf/100ft²)

1.000Gel 10 sec (lbf/100ft²)

1.000Gel 10 min (lbf/100ft²)


8.0Sand (%)

0.1Solids (%)

6.0MBT (lb/bbl) Alkalinity (mL/mL) Chlorides (mg/L)

11,000.000Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (lbf/100ft²)


Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

52.8Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 2,075.0 3,825.0 2,805.00

35.00 74.5 390 16 60 1,100.0 90 92 9,900.0




< p Daily Drilling Report Report for: 8/27/2014cresygr oi5 Report#: 4.0, DFS:2.13





STILL RAIN OFF & ON 62.0 POOR Good Surface, 1,013.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDRILLING @3825' 70 FPH DRILL 7 7/8 PROD. HOLE


DRILL F/ 2075' TO 3825 STARTED LIGHT MUD UP AT 3500' BBG 456-757 UNITS CONNS 320-546 W/ A PEAK OF Floyd Mitchell 823-3608

1246 UNITS @3626 DRILLING 50% CLAY STONE & 50% SHALE DOUG HACKFORD 970-640-3882

Time LogStart Cum Dur Aty RigsTime End Time Dur (hr) (hr) Code Activity Com Capstar 316

06:00 16:30 10.50 10.50 2 DRILL DRILLING F/ 2075 TO 2949 (83 FPH ) 390 GAL 14 -16 K ON Contractor Rig NumberACTUAL BIT 122 TOTAL RPMS 80 BBL LOST TO HOLE Capstar 316

16:30 17:00 0.50 11.00 7 LUBRICATE RIG SERVICE Rig Supervisor Phone Mobile

RIG JAKE 713-481-7601

17:00 06:00 13.00 24.00 2 DRILL DRILLING F/2949 TO 3825 (67 FPH ) 390 GAL 14 -16 K ONACTUAL BIT 122 TOTAL RPMS 130 BBLS LOST TO HOLE Pump# Pwr(hp) Rod Dia (in)

Mud CheckS Liner Size (in) Stroke (in) Vol/Stk OR (b...

2,948.0ftKB, 8/27/2014 17:00Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2) P (psi) Slow Spd Strokes (s... Eff (%)water 17:00 2,948.0 9.10 31 1.0 1.000Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) Mud Additive Amounts

1.000 1.000 8.0 0.1 6.0Field Est Consume

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

11,000.000 DAP 35.00 14.0Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl)


Drill Strings Mole Seal 21.00 8.0

BHA #1, Kick Off Rental 50.00 1.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP..- Sea Mud 15.50 60.01 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8 Tax 1.00 110.0Nozzles (1/32") String Length (ft) Max Nominal OD (in)

16/16/16/16/16/16 583.98 6.500 Safeb ChecksString Components

SMITH MDI616, Mud Motor, UBHO, NMDC, Drill Collar, HWDPTime Type Des

Comment

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- Wellbores6.125"x 2.375" DC)(10-4.5" HWDP) Wellbore Name KO MD (ftKB)Drilling Parameters Original Hole

CumDrill WOB


Original Hole 2,075.0 3,825.0 2,805.0 35.00 74.5 390 16 60 1,100.0 90 92 9,900.O O















RIG JAKE 713-481-7601












Comment


CumDrill WOB


Original Hole 2,075.0 3,825.0 2,805.0 35.00 74.5 390 16 60 1,100.0 90 92 9,900.O O















RIG JAKE 713-481-7601












Comment


CumDrill WOB


Original Hole 2,075.0 3,825.0 2,805.0 35.00 74.5 390 16 60 1,100.0 90 92 9,900.O O















RIG JAKE 713-481-7601












Comment


CumDrill WOB


Original Hole 2,075.0 3,825.0 2,805.0 35.00 74.5 390 16 60 1,100.0 90 92 9,900.O O















RIG JAKE 713-481-7601












Comment


CumDrill WOB


Original Hole 2,075.0 3,825.0 2,805.0 35.00 74.5 390 16 60 1,100.0 90 92 9,900.O O



Page 1/1




AFE Number










Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601





DesField Est

(Cost/unit)Consume

d

Aluminum Stear. 130.00 1.0

DAP 35.00 3.0


Gel 7.50 140.0

Hole Seal 21.00 16.0

Pallet 20.00 3.0

Rental 50.00 1.0

Sea Mud 15.50 42.0

Shrink Wrap 20.00 3.0

Tax 1.00 167.0



Original Hole

Report #: 5.0, DFS: 3.13

UWI/API


6-22-4-2License #

FEESpud Date





Weather

WARMTemperature (°F)

78.0Road Condition

GOODHole Condition



DRILL 7 7/8 PROD. HOLE24 Hr Summary

DRILL F/ 3825 TO 4975 TOPPED THE TGR3 IN TARGET @ 4695' BGG 183 - 334 UNITS CONNS 338 - 559 & A PEAK OF 3224 @ 4270 DRILLING 40 % SH 40% SS & 20 % CLYST


Cum Dur (hr)


06:00 16:00 10.00 10.00 2 DRILL ACTUAL

DRILLING F/ 3825 TO 4361 ( 44 FPH ) 390 GAL 18 K ON BIT 122 TOTAL RPMS 30 BBLS MUD LOST TO HOLE

16:00 16:30 0.50 10.50 7 LUBRICATE RIG

RIG SERVICE

16:30 06:00 13.50 24.00 2 DRILL ACTUAL

DRILLING F/ 4361 TO 4975 ( 45 FPH ) 390 GAL 18 K ON BIT 122 TOTAL RPMS ONLY LOST 97 BBLS OF MUD TO THE HOLE

Mud Checks

4,360.0ftKB, 8/28/2014 16:30Type

WATERTime

16:30Depth (ftKB)



32PV Override (cP)


4.000Gel 10 sec (lbf/100ft²)

3.000Gel 10 min (lbf/100ft²)


8.5Sand (%)

0.3Solids (%)

5.8MBT (lb/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (lbf/100ft²)


Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

52.8Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 3,825.0 4,975.0 3,955.00

58.50 48.9 390 18 60 1,270.0 107 115 10,300.0




< p Daily Drilling Report Report for: 8/28/2014cresygr oi5 Report #: 5.0, DFS: 3.13





WARM 78.0 GOOD Good Surface, 1,013.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDRILLING @4975' 40 FPH DRILL 7 7/8 PROD. HOLE

Job Contact Mobile2D4RHrLsLumF3825 TO 4975 TOPPED THE TGR3 IN TARGET @4695' BGG 183 - 334 UNITS CONNS 338 - 559 & A Floyd Mitchell 823-3608

PEAK OF 3224 @4270 DRILLING 40 % SH 40% SS & 20 % CLYST DOUG HACKFORD 970-640-3882


06:00 16:00 10.00 10.00 2 DRILL DRILLING F/ 3825 TO 4361 (44 FPH ) 390 GAL 18 K ON BIT Contractor Rig NumberACTUAL 122 TOTAL RPMS 30 BBLS MUD LOST TO HOLE Capstar 316


RIG JAKE 713-481-7601

16:30 06:00 13.50 24.00 2 DRILL DRILLING F/ 4361 TO 4975 (45 FPH ) 390 GAL 18 K ON BITACTUAL 122 TOTAL RPMS ONLY LOST 97 BBLS OF MUD TO THE Pump# Pwr(hp) Rod Dia (in)

HOLELiner Size (in) Stroke (in) Vol/Stk OR (b...

Mud Checks4,360.0ftKB, 8/28/2014 16:30 P (psi) Slow Spd Strokes (s... Eff (%)Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

WATER 16:30 4,360.0 9.30 32 5.0 4.000 Mud Additive AmountsGel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) Field Est Consume

3.000 5.000 8.5 0.3 5.8 Des (Cost/unit) dMBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2) Aluminum Stear. 130.00 1.0

DAP 35.00 3.0Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl)

Engineering 450.00 1.0Drill Strings Gel 7.50 140.0BHA #1, Kick Off Hole Seal 21.00 16.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP... Pallet 20.00 3.01 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8Nozzles (1/32") String Length (ft) Max Nominal OD (in) Rei ital 50.00 1.016/16/16/16/16/16 583.98 6.500 Sea Mud 15.50 42.0String Components Shrink Wrap 20.00 3.0SMITH MDI616, Mud Motor, UBHO, NMDC, Drill Collar, HWDPComment Tax 1.00 167.0Smith 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) Safety Checks

Timo Type DesDrilling Parameters

CumDrill WOB

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

Original Hole 3,825.0 4,975.0 3,955.0 58.50 48.9 390 18 60 1,270.0 107 115 10,30 Original HoleO 0.0














RIG JAKE 713-481-7601








Drill Strings Gel 7.50 140.0BHA #1, Kick Off Hole Seal 21.00 16.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP... Pallet 20.00 3.01 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8Nozzles (1/32") String Length (ft) Max Nominal OD (in) Rei ital 50.00 1.016/16/16/16/16/16 583.98 6.500 Sea Mud 15.50 42.0String Components Shrink Wrap 20.00 3.0SMITH MDI616, Mud Motor, UBHO, NMDC, Drill Collar, HWDPComment Tax 1.00 167.0Smith 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) Safety Checks


CumDrill WOB
















RIG JAKE 713-481-7601










CumDrill WOB
















RIG JAKE 713-481-7601










CumDrill WOB
















RIG JAKE 713-481-7601










CumDrill WOB





Page 1/1




AFE Number










Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601





DesField Est

(Cost/unit)Consume

d

DAP 35.00 40.0


Hole Seal 21.00 8.0

Sawdust 4.50 22.0

Tax 1.00 117.0

Trucking 1.00 800.0



Original Hole

Report #: 6.0, DFS: 4.13

UWI/API


6-22-4-2License #

FEESpud Date





Weather

NICETemperature (°F)

81.0Road Condition

GOODHole Condition



DRILL 7 7/8 DROD HOLE24 Hr Summary

DRILL F/ 4975 TO 6025' TOPPED DOUGLAS CREEK @ 5523' BGG 133-423 CONNS 148-279 & PEAK GAS 1250 @ 5134' DRILLING 50% CLYS 50% SH


Cum Dur (hr)


06:00 16:00 10.00 10.00 2 DRILL ACTUAL

DRILLING F/ 4975 TO 5430' ( 46 FPH ) 390 GAL 18 K ON BIT 122 TOTAL RPMS LOST 67 BBLS OF MUD TO THE HOLE

16:00 16:30 0.50 10.50 7 LUBRICATE RIG

SERVICE RIG

16:30 06:00 13.50 24.00 2 DRILL ACTUAL

DRILLING F/ 5430 TO 6025 ( 44 FPH ) 390 GAL 18 K ON BIT 122 TOTAL RPMS LOST 124 BBLS OF MUD TO THE HOLE

Mud Checks

5,342.0ftKB, 8/29/2014 14:00Type

Water BaseTime

14:00Depth (ftKB)



32PV Override (cP)


5.000Gel 10 sec (lbf/100ft²)

3.000Gel 10 min (lbf/100ft²)


8.5Sand (%)

0.3Solids (%)




Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

52.8Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 4,975.0 6,025.0 5,005.00

82.00 44.7 390 18 60 1,390.0 122 128 8,100.0









NICE 81.0 GOOD Good Surface, 1,013.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDRILLING @6025' 48 FPH DRILL 7 7/8 DROD HOLE

Job Contact Mobile2D4RHrLsLumF4975 TO 6025' TOPPED DOUGLAS CREEK @5523' BGG 133-423 CONNS 148-279 & PEAK GAS 1250 @ Floyd Mitchell 823-3608

5134' DRILLING 50% CLYS 50% SH DOUG HACKFORD 970-640-3882


06:00 16:00 10.00 10.00 2 DRILL DRILLING F/ 4975 TO 5430' (46 FPH ) 390 GAL 18 K ON BIT Contractor Rig NumberACTUAL 122 TOTAL RPMS LOST 67 BBLS OF MUD TO THE HOLE Capstar 316

Rig Supervisor Phone Mobile

16:00 16:30 0.50 10.50 7 LUBRICATE SERVICE RIG JAKE 713-481-7601

RIG <des>, <make>, <model>

16:30 06:00 13.50 24.00 2 DRILL DRILLING F/ 5430 TO 6025 (44 FPH ) 390 GAL 18 K ON BIT Fuliiµ " Pwr(hp) Rod Dia (in)

ACTUAL 122 TOTAL RPMS LOST 124 BBLS OF MUD TO THE HOLELiner Size (in) Stroke (in) Vol/Stk OR (b...

Mud CheckS P (psi) Slow Spd Strokes (s... Eff (%)5,342.0ftKB, 8/29/2014 14:00Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2) Mud Additive AmountsWater Base 14:00 5,342.0 9.50 32 5.0 5.000 Field Est ConsumeGel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) Des (Cost/unit) d

3.000 5.000 8.5 0.3 9.0 DAP 35.00 40.0MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2)

Engineering 450.00 1.024,000.000

Whole Mud Added (bbl) Mud Lostto Hole (bbl) Mud Lostto Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) i iule 3eal 21.00 8.0Sawdust 4.50 22.0

Drill Strings Tax 1.00 117.0BHA #1, Kick Off Trucking 1.00 800.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...

1 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8 Safety ChecksNozzles (1/32") String Length (ft) Max Nominal OD (in) Time Type Des16/16/16/16/16/16 583.98 6.500String Components

SMITH MDI616, Mud Motor, UBHO, NMDC, Drill Collar, HWDP WellboresComment Wellbore Name KO MD (ftKB)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- Original Hole6.125"x 2.375" DC)(10-4.5" HWDP)Drilling Parameters

CumDrill WOB


Original Hole 4,975.0 6,025.0 5,005.0 82.00 44.7 390 18 60 1,390.0 122 128 8,100.O O




















Engineering 450.00 1.024,000.000

Whole Mud Added (bbl) Mud Lostto Hole (bbl) Mud Lostto Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) i iule 3eal 21.00 8.0

Sawdust 4.50 22.0Drill Strings Tax 1.00 117.0BHA #1, Kick Off Trucking 1.00 800.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...



CumDrill WOB


Original Hole 4,975.0 6,025.0 5,005.0 82.00 44.7 390 18 60 1,390.0 122 128 8,100.O O




















Engineering 450.00 1.024,000.000





CumDrill WOB


Original Hole 4,975.0 6,025.0 5,005.0 82.00 44.7 390 18 60 1,390.0 122 128 8,100.O O




















Engineering 450.00 1.024,000.000





CumDrill WOB


Original Hole 4,975.0 6,025.0 5,005.0 82.00 44.7 390 18 60 1,390.0 122 128 8,100.O O




















Engineering 450.00 1.024,000.000





CumDrill WOB


Original Hole 4,975.0 6,025.0 5,005.0 82.00 44.7 390 18 60 1,390.0 122 128 8,100.O O



Page 1/1




AFE Number










Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601





DesField Est

(Cost/unit)Consume

d

Brine 7.50 300.0

DAP 35.00 16.0


Hole Seal 21.00 5.0

Rental 50.00 1.0

Sawdust 4.50 28.0

Sea Mud 15.50 6.0

Tax 1.00 62.0



Original Hole

Report #: 7.0, DFS: 5.13

UWI/API


6-22-4-2License #

FEESpud Date





Weather


78.0Road Condition

GOODHole Condition



DRILL ON TO TD CIRC CLEAN SPOT KILL PILL POOH & LOG WELL

24 Hr Summary

DRILL F/ 6025 TO 6975 TOPPED BLACK SHALE @ 5968' THE CASTLE @ 6205' UTELAND BUTTE @ 6485 & THEWASATCH @ 6650 BGG 195-282 CONNS 245-276 PEAK 1533 UNIT @ 6573' DRILLING 50% CLYST 30% SH 20% SS


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

RIG SERVICE

17:00 06:00 13.00 24.00 2 DRILL ACTUAL


Mud Checks

6,264.0ftKB, 8/30/2014 12:00Type

Water BaseTime

12:00Depth (ftKB)



30PV Override (cP)


3.000Gel 10 sec (lbf/100ft²)

2.000Gel 10 min (lbf/100ft²)


8.5Sand (%)

0.3Solids (%)




Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

52.8Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 6,025.0 6,975.0 5,955.00

105.50

40.4 390 18 60 1,400.0 136 143 7,800.0




< p Daily Drilling Report Report for: 8/30/2014cresygr oi5 Report#:7.0, DFS: 5.13





NICE 78.0 GOOD Good Surface, 1,013.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsDRILLING @6975' 30 FPH DRILL ON TO TD CIRC CLEAN SPOT KILL PILL POOH &

Job Contact MobileLOG WELL

Floyd Mitchell 823-360824 Hr Summary

DRILL F/ 6025 TO 6975 TOPPED BLACK SHALE @ 5968' THE CASTLE @6205' UTELAND BUTTE @6485 & DOUG HACKFORD 970-640-3882

THEWASATCH @6650 BGG 195-282 CONNS 245-276 PEAK 1533 UNIT @6573' DRILLING 50% CLYST 30% SH20% SS RigsTime Log Capstar, 316

Start Cum Dur Aty Contractor Rig NumberTime End Time Dur (hr) (hr) Code Activity Com Capstar 316

06:00 16:30 10.50 10.50 2 DRILL DRILLING F/ 6025 TO 6457 ( 41 FPH ) 390 GAL 18 K ON BIT Rig Supervisor Phone Mobile

ACTUAL 122 TOTAL RPMS LOST 105 BBLS OF MUD TO THE HOLE JAKE 713-481-7601


16:30 17:00 0.50 11.00 7 LUBRICATE RIGSERVICE Pump# Pwr(hp) RodDia(in)

RIG

17:00 06:00 13.00 24.00 2 DRILL DRILLING F/ 6457 TO 6975 ( 40 FPH ) 390 GAL 18 K ON BITLir.or Cize (|r.) Stroke (in) Vol/Stk OR (b...

ACTUAL 122 TOTAL RPMS LOST 85 BBLS OF MUD TO THE HOLE P (psi) SlowSpd Strokes (s... Eff(%)

Mud Checks6,264.0ftKB, 8/30/2014 12:00 Mud Additive AmountsType Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

Field Est ConsumeWater Base 12:00 6,264.0 9.50 30 4.0 3.000 Des (Cost/unit) d

Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) Brine 7.50 300.02.000 3.000 8.5 0.3 9.0 DAP 35.00 16.0

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

30,000.000 Engineering 450.00 1.0Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Hole Seal 21.00 5.0

Rental 50.00 1.0Drill Strings

Sawduct 4.50 28.0BHA #1, Kick OffBit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP... OEa Mud 15.50 6.01 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8 Tax 1.00 62.0Nozzles (1/32") String Length (ft) Max Nominal OD (in)

16/16/16/16/16/16 583.98 6.500 Safety ChecksString Components Time Type Des


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- Wellbores6.125"x 2.375" DC)(10-4.5" HWDP) Wellbore Name KO MD (ftKB)

Drilling Parameters Unginal HoleCumDrill WOB


Original Hole 6,025.0 6,975.0 5,955.0 105.5 40.4 390 18 60 1,400.0 136 143 7,800.O O O


















RIG









Sawduct 4.50 28.0BHA #1, Kick OffBit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP... OEa Mud 15.50 6.0

1 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8 Tax 1.00 62.0Nozzles (1/32") String Length (ft) Max Nominal OD (in)
























RIG


































RIG


































RIG



















Page 1/1




AFE Number










Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601





DesField Est

(Cost/unit)Consume

d

Aluminum Stear. 130.00 2.0

Barite 10.65 144.0

DAP 35.00 17.0


Hole Seal 21.00 20.0

Pallet 20.00 8.0

Rental 50.00 1.0

Sea Mud 15.50 192.0

Shrink Wrap 20.00 8.0

Tax 1.00 329.0



Original Hole

Report #: 8.0, DFS: 6.13

UWI/API


6-22-4-2License #

FEESpud Date





Weather


81.0Road Condition

GOODHole Condition


LOGGING WELL W/ HALLIBURTONOperation Next 24hrs

FINNISH LOGGING RUN 5 1/2 CASING CEMENT NIPPLE BOPS DOWN CLEAN MUD PITS R.R.

24 Hr Summary

DRILL F/ 6975 TO 7275 T.D. BGG 79-268 CONNS 188-298 PEAK 2719 @ 7260 CIRC CLEAN SPOT KILL PILL POOH TIGHT @ 3800' CIRC CLEAN @ 3500' PULL ON OUT LOG WELL


Cum Dur (hr)


06:00 19:00 13.00 13.00 2 DRILL ACTUAL


19:00 21:00 2.00 15.00 5 COND MUD & CIRC

PUMP SWEEP & CIRC 2 BOTTOMS UP SPOT 10.2 # KILL PILL THEN DRY JOB

21:00 23:30 2.50 17.50 6 TRIPS POOH F/ LOGS UP TO 3500'

23:30 00:30 1.00 18.50 5 COND MUD & CIRC

CIRC 2 BOTTOMS UP ( SHAKERS CLEAN )

00:30 03:30 3.00 21.50 6 TRIPS PULL ON OUT LAY DOWN DIR. TOOLS

03:30 06:00 2.50 24.00 11 WIRELINE LOGS

HELD SAFETY MEETING RIG UP H.L.S. & LOG WELL

Mud Checks

7,077.0ftKB, 8/31/2014 11:00Type

Water BaseTime

11:00Depth (ftKB)



30PV Override (cP)


3.000Gel 10 sec (lbf/100ft²)

2.000Gel 10 min (lbf/100ft²)


8.5Sand (%)

0.3Solids (%)




Drill Strings


1Drill Bit


1.00IADC Bit Dull


1.18BHA ROP …

52.8Nozzles (1/32")







(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf




Original Hole 6,975.0 7,275.0 6,255.00

118.50

23.1 390 18 60 1,400.0 140 145 7,800.0





c"""YW11 ??NT Report #: 8.0, DFS: 6.13





NICE 81.0 GOOD Good Surface, 1,013.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsLOGGING WELL W/ HALLIBURTON FINNISH LOGGING RUN 5 1/2 CASING CEMENT NIPPLE

BOPS DOWN CLEAN MUD PITS R.R.JobContact Mobile


DRILL F/ 6975 TO 7275 T.D. BGG 79-268 CONNS 188-298 PEAK 2719 @7260 CIRC CLEAN SPOT KILL PILL DOUG HACKFORD 970-640-3882

POOH TIGHT @3800' CIRC CLEAN @3500' PULL ON OUT LOG WELL

Time Log RigsStart Cum Dur Aty Capstar, 316Time End Time Dur (hr) (hr) Code Activity Com Contractor Rig Number

06:00 19:00 13.00 13.00 2 DRILL DRILLING F/6975 TO 7275 (23 FPH ) 390 GAL 18 K ON BIT Capstar 316ACTUAL 122 TOTAL RPMS LOST 88 BBLS OF MUD TO THE HOLE Rig Supervisor Phone Mobile

19:00 21:00 2.00 15.00 5 COND MUD & PUMP SWEEP & CIRC 2 BOTTOMS UP SPOT 10.2 # KILL PILL JAKE 713-481-7601

CIRC THEN DRY JOB <des>, <make>, <model>

21:00 23:30 2.50 17.50 6 TRIPS POOH F/ LOGS UP TO 3500, Fuliiµ " Pwr(hp) Rod Dia (in)

23:30 00:30 1.00 18.50 5 COND MUD & CIRC 2 BOTTOMS UP ( SHAKERS CLEAN ) Liner Size (in) Stroke (in) Vol/Stk OR (b...CIRC

00:30 03:30 3.00 21.50 6 TRIPS PULL ON OUT LAY DOWN DIR. TOOLS P (psi) SlowSpd Strokes (s... Eff(%)

03:30 06:00 2.50 24.00 11 WIRELINE HELD SAFETY MEETING RIG UP H.L.S. & LOG WELLLOGS Mud Additive Amounts

Mud CheckS Des ( ot/uEnst Consume

7,077.0ftKB, 8/31/2014 11:00 Aluminum Stear. 130.00 2.0Type Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Override (cP) YP OR (Ibf/100ft2)

Barite 10.65 144.0Water Base 11:00 7,077.0 9.50 30 4.0 3.000Gel 10 sec (Ibf/100ft2) Gel 10 min (Ibf/100ft2) Filtrate (mL/30min) Filter Cake (1/32") pH Sand (%) Solids (%) DAP 35.00 17.0

2.000 3.000 8.5 0.3 9.0 Engineering 450.00 1.0MBT (Ib/bbl) Alkalinity (mL/mL) Chlorides (mg/L) Calcium (mg/L) Pf (mL/mL) Pm (mL/mL) Gel 30 min (Ibf/100ft2)

Hole Seal 21.00 20.030,000.000

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Pallet 20.00 8.0Rental 50.00 1.0

Drill Strings Sea Mud 15.50 192.0BHA #1, Kick Off Shrink Wrap 20.00 8.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...

1 7 7/8in, MDI616, JJ6889 1.00 0-0-0---i-0-TD 1.18 52.8 Tax 1.00 329.0Nozzles (1/32") String Length (ft) Max Nominal OD (in) Safety Checks16/16/16/16/16/16 583.98 6.500String Components

Timo Type Des


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- Wellbores

6.125"x 2.375" DC)(10-4.5" HWDP) Wellbore Name KO MD (ftKB)

Original HoloDrilling Parameters

CumDrill WOB






c"""YW11 ??NT Report #: 8.0, DFS: 6.13






















Hole Seal 21.00 20.030,000.000

Whole Mud Added (bbl) Mud Lost to Hole (bbl) Mud Lost to Surface (bbl) Reserve Mud Volume (bbl) Active Mud Volume (bbl) Pallet 20.00 8.0

Rental 50.00 1.0Drill Strings Sea Mud 15.50 192.0BHA #1, Kick Off Shrink Wrap 20.00 8.0Bit Run Drill Bit Length (ft) lADC Bit Dull TFA (incl Noz) (in2) BHA ROP...


Timo Type Des





CumDrill WOB






c"""YW11 ??NT Report #: 8.0, DFS: 6.13






















Hole Seal 21.00 20.030,000.000




Timo Type Des





CumDrill WOB






c"""YW11 ??NT Report #: 8.0, DFS: 6.13






















Hole Seal 21.00 20.030,000.000




Timo Type Des





CumDrill WOB






c"""YW11 ??NT Report #: 8.0, DFS: 6.13






















Hole Seal 21.00 20.030,000.000




Timo Type Des





CumDrill WOB





Page 1/1




AFE Number






Production, 7,260.0ftKB




Rigs


CapstarRig Number

316Rig Supervisor

JAKEPhone Mobile

713-481-7601





DesField Est

(Cost/unit)Consume

d

Barite 10.65 80.0


Rental 50.00 1.0

Tax 1.00 30.0



Original Hole

Report #: 9.0, DFS: 7.13

UWI/API


6-22-4-2License #

FEESpud Date





Weather

COOLTemperature (°F)

66.0Road Condition

GOODHole Condition


RELEASE RIG 0600 8/2/14Operation Next 24hrs

MOVE TO DEEP CREEK 16-22-4-2E RIG UP TEST BOP PICK UP BHA SPUD IN

24 Hr Summary

LOG WELL LOG TO 7260' LOG UP TO 1007' W/ TRIPLE COMBO PUSS GAMMA UP TO 200' / RUN 5 1/2 CASING TO 7260 CEMENT W/HALLIBURTON PUMP 10 BBL WATER /PUMP 160 SKS 10.5# 4.31 YIELD LEAD THEN 505 SKS 13.1# 1.66 YIELD TAIL CEMENT / 167 BBL WATER DISPLACEMENT BUMP PLUG @ 10 :55 500 PSI OVER 40 BBL CEMENT TO SURFACE FCP 1675 CLEAN UP & RIG DOWN NIPPLE DOWN BOP & CLEAN MUD PITS W/ BADGER


Cum Dur (hr)


06:00 10:30 4.50 4.50 11 WIRELINE LOGS

LOG WELL W/ HALLIBURTON LOG TO 7260' RUN TRIPLE COMBO PUSS UP TO SURFACE PIPE 1007' GAMMA UP TO 200'

10:30 19:30 9.00 13.50 12 RUN CASING & CEMENT

RUN 159 FULL JTS 5 1/2 17# L80 CASING & 2 MARKERS LAND ON HANGER @ 7260'

19:30 23:30 4.00 17.50 12 RUN CASING & CEMENT

HELD SAFETY MEETING & RIG UP AND CEMENT W/ HALLIBURTON PUMP 10 BBL WATER /PUMP 160 SKS 10.5# 4.31 YIELD LEAD THEN 505 SKS 13.1# 1.66 YIELD TAIL CEMENT / 167 BBL WATER BUMP PLUG 10:"55 CIRC 40 BBL CEMENT TO SURFACE CLEAN UP & RIG DOWN

23:30 06:00 6.50 24.00 14 NIPPLE UP B.O.P

NIPPLE DOWN CLEAN MUD PITS W/ BADGER RELEASE RIG @ 0600 8/2/14

Mud Checks





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


(ftKB)Cum Depth

(ft)

Cum Drill Time (hr)

Int ROP (ft/hr)

Q Flow (gpm)

WOB (1000lbf







< p Daily Drilling Report Report for: 9/1/2014cresygr oi5 Report#:9.0, DFS:7.13





COOL 66.0 GOOD Good Production, 7,260.0ftKBOperation At 6am Operation Next 24hrs Daily ContactsRELEASE RIG 0600 8/2/14 MOVE TO DEEP CREEK 16-22-4-2E RIG UP TEST BOP

PICK UP BHA SPUD INJob Contact Mobile


LOG WELL LOG TO 7260' LOG UP TO 1007' W/ TRIPLE COMBO PUSS GAMMA UP TO 200' / RUN 5 1/2 CASING DOUG HACKFORD 970-640-3882

TO 7260 CEMENT WlHALLIBURTON PUMP 10 BBL WATER /PUMP 160 SKS 10.5# 4.31 YIELD LEAD THEN 505SKS 13.1# 1.66 YIELD TAIL CEMENT / 167 BBL WATER DISPLACEMENT BUMP PLUG @ 10 :55 500 PSI OVER 40 RigsBBL CEMENT TO SURFACE FCP 1675 CLEAN UP & RIG DOWN NIPPLE DOWN BOP & CLEAN MUD PITS W/BADGER

Capstar, 316Contractor Rig Number

Time Log Capstar 316Start Cum Dur Aty Rig Supervisor Phone MobileTime End Time Dur (hr) (hr) Code Activity Com JAKE 713-481-7601

06:00 10:30 4.50 4.50 11 WIRELINE LOG WELL W/ HALLIBURTON LOG TO 7260' RUN TRIPLE <des>, <make>, <model>LOGS COMBO PUSS UP TO SURFACE PIPE 1007' GAMMA UP TO Pump# Pwr(hp) Rod Dia (in)

200'

10:30 19:30 9.00 13.50 12 RUN CASING RUN 159 FULL JTS 5 1/2 17# L80 CASING & 2 MARKERS Liner Size (in) Stroke (in) Vol/Stk OR (b...

& CEMENT LAND ON HANGER @7260'P (psi) Slow Spd Strokes (s... Eff (%)

19:30 23:30 4.00 17.50 12 RUN CASING HELD SAFETY MEETING & RIG UP AND CEMENT W/& CEMENT HALLIBURTON PUMP 10 BBL WATER /PUMP 160 SKS 10.5# Mud Additive Amounts

4.31 YIELD LEAD THEN 505 SKS 13.1# 1.66 YIELD TAIL Field Est Consume

CEMENT / 167 BBL WATER BUMP PLUG 10:"55 CIRC 40 BBLDes (Cost/unit) d

CEMENT TO SURFACE CLEAN UP & RIG DOWN Barite 10.65 80.0

23:30 06:00 6.50 24.00 14 NIPPLE UP NIPPLE DOWN CLEAN MUD PITS W/ BADGER RELEASE RIGEngineering 450.00 1.0

B.O.P @0600 8/2/14 Rental 50.00 1.0

Mud Checks Tax 1.00 30.0

<depth>ftKB, <dttm> Safety ChecksType Time Depth (ftKB) Density (Ib/gal) Funnel Viscosity (s/qt) PV Overnde (cP) YP OR (Ibf/100ft2)

Time Type Des

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

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

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

Drill StringsBHA #<stringno>, <des>



String Components

Comment

Drilling ParametersCumDrill WOB

















200'








B.O.P @0600 8/2/14 Rental 50.00 1.0



Time Type Des







String Components

Comment


















200'








B.O.P @0600 8/2/14 Rental 50.00 1.0



Time Type Des







String Components

Comment


















200'








B.O.P @0600 8/2/14 Rental 50.00 1.0



Time Type Des







String Components

Comment


















200'








B.O.P @0600 8/2/14 Rental 50.00 1.0



Time Type Des







String Components

Comment




RECEIVED: Oct. 08, 2014



FORM 9









9. API NUMBER: 43047541920000




COUNTY: UINTAH

STATE: UTAH

11.





9 /21 /2014














Crescent Point Energy US Corp reports the first production ofhydrocarbons from Deep Creek 6-22-4-2E on September 21st, 2014.

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

TITLE Regulatory & Government Affairs Analyst

SIGNATURE N/A

DATE 10 /8 /2014

October 09, 2014


FORM 9STATE OF UTAH

















9/21/2014OPERATOR CHANGE PLUG AND ABANDON PLUG BACK







Crescent Point Energy US Corp reports the first production of Accepted by thehydrocarbons from Deep Creek 6-22-4-2E on September 21st, 2014. Utah Division of

Oil, Gas and Mining

FOR RECORD ONLYOctober 09, 2014



RECEIVED: Oct. 08,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Oct. 08,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Oct. 08,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Oct. 08,


Per Hour Rates:

→

Casing Pressure:

10.17 49.36

Water: Bbl/Hr

1

Gas: MCF/Hr

0

100

64/64

Choke Size:

Oil: Bbl/Hr

6-22-4-2E Deep Creek

9/21/2013

Date First Produced:

Well Name and Number:

1-16-4-2E Deep CreekHours Tested:Test Date: 9/22/2013

1


CrescentPoint



I I1-16-4-2E Deep Creek

Date First Produced: Test Date: 9/22/2013 Hours Tested:

9/21/2013

asing Pressure:100

0

Choke Size:

64/64

Per Hour Rates: Oil: Bbl/Hr Gas: MCF/Hr Water: Bbl/Hr

10.17 1 49.36

RECEIVED: Oct. 08,


CrescentPoint





9/21/2013

asing Pressure:100

0

Choke Size:

64/64


10.17 1 49.36

RECEIVED: Oct. 08,


CrescentPoint





9/21/2013

asing Pressure:100

0

Choke Size:

64/64


10.17 1 49.36

RECEIVED: Oct. 08,


CrescentPoint





9/21/2013

asing Pressure:100

0

Choke Size:

64/64


10.17 1 49.36

RECEIVED: Oct. 08,


40



24

2


| 40

RECEIVED: Oct. 08,


| 40

RECEIVED: Oct. 08,


| 40

RECEIVED: Oct. 08,


| 40

RECEIVED: Oct. 08,

RECEIVED: Dec. 15, 2014



FORM 9









9. API NUMBER: 43047541920000




COUNTY: UINTAH

STATE: UTAH

11.





12/15 /2014














Please see attached application to commingle production formations forthe Deep Creek 6-22-4-2E.

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
















Please see attached application to commingle production formations for Approved by thethe Deep Creek 6-22-4-2E. 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,



maini 720.880.3610fax 303.2921562tollfreei 1.888.693.0020

Crescent Point 36""""""*16®Denver,Colo<adoUSA80202

December 3, 2014

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

RE: Sundry NoticesDeep Creek 6-22-4-2EUintah 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,

JordãI e lsLandman

Enclosures

www.crescentpointenergy.com/TSX:CPB




December 3, 2014



Dear Mr. Doucet:



Sincerely,

JordãI e lsLandman

Enclosures





December 3, 2014



Dear Mr. Doucet:



Sincerely,

JordãI e lsLandman

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 followingwell within the Randlett Exploration and DevelopmentAgreement Area:

DEEPCREEK6-22-4-2E: SENW Section 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 1389Sealy, TX77474

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

Date: December 3, 2014

Affiant

ordan WellsLa


AFFIDAVITOF NOTICE









Affiant

ordan WellsLa


AFFIDAVITOF NOTICE









Affiant

ordan WellsLa



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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 6-22-4-2E2. NAME OF OPERATOR: 9. API NUMBER:

Crescent Point Energy US Corp. 43047541923. 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: 1586 FNL 1726 FWL SENW 22 4S 2E UAT TOP PRODUCING INTERVAL REPORTED BELOW: 1791 FNL 1826 FWL

12. COUNTY 13. STATEAT TOTAL DEPTH: 1911 FNL 1856 FWL Uintah UTAH

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

6/9/2014 9/2/2014 9/12/2014 ABANDONED READYTO PRODUCE 2 4935' GL18. TOTAL DEPTH: MD 7.275 19. PLUG BACKT.D.: MD 7.175 20. IF MULTIPLE COMPLETIONS, HOW MANY? * 21. DEPTH BRIDGE MD

TVD 7.266 TVD 7.166 8 STAGES PLUGSET: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 1,013 PREM 675 138 SRFC7-7/8 5-1/2 SB8( 17 0 7,260 HiFillV 505 100 160

65/35 P 160 167

25. TUBING RECORD


2-7/8 7,05726. 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 4.830 6.604 4.823 6.594 4.830 7.094 .36 261 OPen 2 Squeezed

(B) Wasatch 6.604 7.094 6.594 7.085 DPen Squeezed

(C) Open Squeezed

(D) Open Squeezed



4830' - 7094' 6852 Bbls Slickwater & XIinked fluid, 4000 gals 15% HCI, 338000 # 20/40 sand& 440000 # 30/50 SA

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 6-22-4-2E2. NAME OF OPERATOR: 9. API NUMBER:

Crescent Point Energy US Corp. 43047541923. 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: 1586 FNL 1726 FWL SENW 22 4S 2E UAT TOP PRODUCING INTERVAL REPORTED BELOW: 1791 FNL 1826 FWL

12. COUNTY 13. STATEAT TOTAL DEPTH: 1911 FNL 1856 FWL Uintah UTAH

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

6/9/2014 9/2/2014 9/12/2014 ABANDONED READYTO PRODUCE 2 4935' GL18. TOTAL DEPTH: MD 7.275 19. PLUG BACKT.D.: MD 7.175 20. IF MULTIPLE COMPLETIONS, HOW MANY? * 21. DEPTH BRIDGE MD

TVD 7.266 TVD 7.166 8 STAGES PLUGSET: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 1,013 PREM 675 138 SRFC7-7/8 5-1/2 SB8( 17 0 7,260 HiFillV 505 100 160

65/35 P 160 167

25. TUBING RECORD


2-7/8 7,05726. 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 4.830 6.604 4.823 6.594 4.830 7.094 .36 261 OPen 2 Squeezed

(B) Wasatch 6.604 7.094 6.594 7.085 DPen Squeezed

(C) Open Squeezed

(D) Open Squeezed



4830' - 7094' 6852 Bbls Slickwater & XIinked fluid, 4000 gals 15% HCI, 338000 # 20/40 sand& 440000 # 30/50 SA

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:

9/17/2014 9/17/2014 24 RATES: 5 2 17 FlowingCHOKE SIZE: TBG. PRESS. CSG. PRESS. Pl GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: INTERVALSTATUS:

20 0 50 40.00 RATES: 5 2 17 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 3,874TGR3 4,695Douglas Creek 5,555Black Shale 5,963Castle Peak 6,193Uteland Butte 6,504Wasatch 6,604



NAME(PLEASEPRINT) Valari Crary TITLE D&C Technician

SIGNATURE DATE 11/12/2014

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:

9/17/2014 9/17/2014 24 RATES: 5 2 17 FlowingCHOKE SIZE: TBG. PRESS. CSG. PRESS. Pl GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL: GAS- MCF: WATER - BBL: INTERVALSTATUS:

20 0 50 40.00 RATES: 5 2 17 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 3,874TGR3 4,695Douglas Creek 5,555Black Shale 5,963Castle Peak 6,193Uteland Butte 6,504Wasatch 6,604



NAME(PLEASEPRINT) Valari Crary TITLE D&C Technician

SIGNATURE DATE 11/12/2014

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|/...ated%20Wells/N%20Monument%20Butte/06-22-4-2E%20Deep%20Creek/Drilling/Deep%20Creek%206-22-4-2E%20Survey.txt[11/12/2014 9:39:40 AM]

Job Number: 34338 State/Country: Utah/ USA Company: Cresent Point Declination: 11.0 Lease/Well: Deep Creek 6-22-4-2E Grid: Location: Deep Creek 6-22-4-2E File name: C:\WINSERVE\ACCESS\34338.SVY Rig Name: Capstar 316 Date/Time: 02-Sep-14 / 14:45 RKB: 18 Curve Name: As Drilled G.L. or M.S.L.: 4937 Newsco WINSERVE SURVEY CALCULATIONS Minimum Curvature Method Vertical Section Plane .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 Course Depth Angle Direction Vertical N-S E-W Section Distance Direction Severity Length FT Deg Deg Depth FT FT FT FT Deg Deg/100 FT .00 .00 .00 .00 .00 .00 .00 .00 .00 .00 1062.00 1.00 140.90 1061.95 -7.19 5.84 -7.19 9.27 140.90 .09 1062.00 1190.00 2.10 163.80 1189.90 -10.31 7.20 -10.31 12.58 145.06 .97 128.00 1319.00 3.30 152.70 1318.75 -15.88 9.57 -15.88 18.54 148.94 1.01 129.00 1447.00 4.10 151.70 1446.49 -23.18 13.43 -23.18 26.79 149.93 .63 128.00 1575.00 4.50 152.50 1574.13 -31.67 17.91 -31.67 36.38 150.50 .32 128.00 1704.00 3.90 148.30 1702.78 -39.89 22.56 -39.89 45.82 150.51 .52 129.00 1832.00 3.50 150.20 1830.51 -46.98 26.78 -46.98 54.08 150.31 .33 128.00 1960.00 3.80 142.60 1958.25 -53.74 31.30 -53.74 62.19 149.78 .44 128.00 2088.00 3.50 141.10 2085.99 -60.15 36.33 -60.15 70.27 148.87 .25 128.00 2217.00 2.60 143.60 2214.81 -65.57 40.54 -65.57 77.09 148.27 .71 129.00 2345.00 2.60 140.20 2342.68 -70.14 44.12 -70.14 82.86 147.83 .12 128.00 2473.00 2.80 137.70 2470.53 -74.68 48.08 -74.68 88.82 147.22 .18 128.00 2602.00 2.20 136.10 2599.41 -78.80 51.92 -78.80 94.36 146.62 .47 129.00 2731.00 2.20 142.70 2728.32 -82.55 55.14 -82.55 99.27 146.26 .20 129.00 2859.00 2.30 135.00 2856.22 -86.32 58.44 -86.32 104.24 145.90 .25 128.00 2987.00 2.30 129.90 2984.12 -89.78 62.23 -89.78 109.24 145.27 .16 128.00 3116.00 2.50 140.90 3113.00 -93.63 65.99 -93.63 114.55 144.82 .39 129.00 3244.00 2.80 145.60 3240.87 -98.37 69.52 -98.37 120.46 144.75 .29 128.00 3373.00 4.30 156.60 3369.62 -105.41 73.22 -105.41 128.35 145.22 1.27 129.00


Job Number: 34338 State/Country: Utah/ USACompany: Cresent Point Declination: 11.0Lease/Well: Deep Creek 6-22-4-2E Grid:Location: Deep Creek 6-22-4-2E File name: C:\WINSERVE\ACCESS\34338.SVYRig Name: Capstar 316 Date/Time: 02-Sep-14 / 14:45RKB: 18 Curve Name: As DrilledG.L. or M.S.L.: 4937

Newsco

WINSERVE SURVEY CALCULATIONSMinimum Curvature Method

Vertical Section Plane .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 CourseDepth Angle Direction Vertical N-S E-W Section Distance Direction Severity LengthFT Deg Deg Depth FT FT FT FT Deg Deg/100 FT

.00 .00 .00 .00 .00 .00 .00 .00 .00 .00

1062.00 1.00 140.90 1061.95 -7.19 5.84 -7.19 9.27 140.90 .09 1062.001190.00 2.10 163.80 1189.90 -10.31 7.20 -10.31 12.58 145.06 .97 128.001319.00 3.30 152.70 1318.75 -15.88 9.57 -15.88 18.54 148.94 1.01 129.001447.00 4.10 151.70 1446.49 -23.18 13.43 -23.18 26.79 149.93 .63 128.00

1575.00 4.50 152.50 1574.13 -31.67 17.91 -31.67 36.38 150.50 .32 128.001704.00 3.90 148.30 1702.78 -39.89 22.56 -39.89 45.82 150.51 .52 129.001832.00 3.50 150.20 1830.51 -46.98 26.78 -46.98 54.08 150.31 .33 128.001960.00 3.80 142.60 1958.25 -53.74 31.30 -53.74 62.19 149.78 .44 128.002088.00 3.50 141.10 2085.99 -60.15 36.33 -60.15 70.27 148.87 .25 128.00

2217.00 2.60 143.60 2214.81 -65.57 40.54 -65.57 77.09 148.27 .71 129.002345.00 2.60 140.20 2342.68 -70.14 44.12 -70.14 82.86 147.83 .12 128.002473.00 2.80 137.70 2470.53 -74.68 48.08 -74.68 88.82 147.22 .18 128.002602.00 2.20 136.10 2599.41 -78.80 51.92 -78.80 94.36 146.62 .47 129.002731.00 2.20 142.70 2728.32 -82.55 55.14 -82.55 99.27 146.26 .20 129.00

2859.00 2.30 135.00 2856.22 -86.32 58.44 -86.32 104.24 145.90 .25 128.002987.00 2.30 129.90 2984.12 -89.78 62.23 -89.78 109.24 145.27 .16 128.003116.00 2.50 140.90 3113.00 -93.63 65.99 -93.63 114.55 144.82 .39 129.003244.00 2.80 145.60 3240.87 -98.37 69.52 -98.37 120.46 144.75 .29 128.003373.00 4.30 156.60 3369.62 -105.41 73.22 -105.41 128.35 145.22 1.27 129.00


Job Number: 34338 State/Country: Utah/ USACompany: Cresent Point Declination: 11.0Lease/Well: Deep Creek 6-22-4-2E Grid:Location: Deep Creek 6-22-4-2E File name: C:\WINSERVE\ACCESS\34338.SVYRig Name: Capstar 316 Date/Time: 02-Sep-14 / 14:45RKB: 18 Curve Name: As DrilledG.L. or M.S.L.: 4937

Newsco

WINSERVE SURVEY CALCULATIONSMinimum Curvature Method

Vertical Section Plane .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 CourseDepth Angle Direction Vertical N-S E-W Section Distance Direction Severity LengthFT Deg Deg Depth FT FT FT FT Deg Deg/100 FT

.00 .00 .00 .00 .00 .00 .00 .00 .00 .00

1062.00 1.00 140.90 1061.95 -7.19 5.84 -7.19 9.27 140.90 .09 1062.001190.00 2.10 163.80 1189.90 -10.31 7.20 -10.31 12.58 145.06 .97 128.001319.00 3.30 152.70 1318.75 -15.88 9.57 -15.88 18.54 148.94 1.01 129.001447.00 4.10 151.70 1446.49 -23.18 13.43 -23.18 26.79 149.93 .63 128.00

1575.00 4.50 152.50 1574.13 -31.67 17.91 -31.67 36.38 150.50 .32 128.001704.00 3.90 148.30 1702.78 -39.89 22.56 -39.89 45.82 150.51 .52 129.001832.00 3.50 150.20 1830.51 -46.98 26.78 -46.98 54.08 150.31 .33 128.001960.00 3.80 142.60 1958.25 -53.74 31.30 -53.74 62.19 149.78 .44 128.002088.00 3.50 141.10 2085.99 -60.15 36.33 -60.15 70.27 148.87 .25 128.00

2217.00 2.60 143.60 2214.81 -65.57 40.54 -65.57 77.09 148.27 .71 129.002345.00 2.60 140.20 2342.68 -70.14 44.12 -70.14 82.86 147.83 .12 128.002473.00 2.80 137.70 2470.53 -74.68 48.08 -74.68 88.82 147.22 .18 128.002602.00 2.20 136.10 2599.41 -78.80 51.92 -78.80 94.36 146.62 .47 129.002731.00 2.20 142.70 2728.32 -82.55 55.14 -82.55 99.27 146.26 .20 129.00

2859.00 2.30 135.00 2856.22 -86.32 58.44 -86.32 104.24 145.90 .25 128.002987.00 2.30 129.90 2984.12 -89.78 62.23 -89.78 109.24 145.27 .16 128.003116.00 2.50 140.90 3113.00 -93.63 65.99 -93.63 114.55 144.82 .39 129.003244.00 2.80 145.60 3240.87 -98.37 69.52 -98.37 120.46 144.75 .29 128.003373.00 4.30 156.60 3369.62 -105.41 73.22 -105.41 128.35 145.22 1.27 129.00

RECEIVED: Nov. 12, 2014file:///Q|/...ated%20Wells/N%20Monument%20Butte/06-22-4-2E%20Deep%20Creek/Drilling/Deep%20Creek%206-22-4-2E%20Survey.txt[11/12/2014 9:39:40 AM]

3501.00 4.50 156.60 3497.24 -114.42 77.12 -114.42 137.99 146.02 .16 128.00 3629.00 4.30 151.40 3624.86 -123.25 81.41 -123.25 147.71 146.55 .35 128.00 3758.00 4.20 147.20 3753.51 -131.46 86.28 -131.46 157.25 146.72 .25 129.00 3886.00 4.00 146.00 3881.18 -139.10 91.32 -139.10 166.40 146.72 .17 128.00 4014.00 4.40 163.00 4008.84 -147.50 95.25 -147.50 175.58 147.15 1.02 128.00 PAGE - 1 Measured Incl Drift True Vertical CLOSURE CLOSURE Dogleg Course Depth Angle Direction Vertical N-S E-W Section Distance Direction Severity Length FT Deg Deg Depth FT FT FT FT Deg Deg/100 FT 4143.00 4.50 172.20 4137.45 -157.25 97.39 -157.25 184.96 148.23 .56 129.00 4271.00 4.40 173.00 4265.07 -167.10 98.67 -167.10 194.05 149.44 .09 128.00 4399.00 4.40 175.00 4392.69 -176.86 99.69 -176.86 203.02 150.59 .12 128.00 4528.00 4.10 178.70 4521.34 -186.40 100.23 -186.40 211.64 151.73 .31 129.00 4656.00 4.20 180.50 4649.00 -195.66 100.29 -195.66 219.87 152.86 .13 128.00 4785.00 3.90 179.30 4777.68 -204.77 100.30 -204.77 228.02 153.90 .24 129.00 4913.00 3.20 184.80 4905.43 -212.69 100.06 -212.69 235.05 154.81 .61 128.00 5041.00 3.70 205.80 5033.20 -219.96 97.96 -219.96 240.79 155.99 1.05 128.00 5169.00 3.10 198.70 5160.98 -226.96 95.05 -226.96 246.06 157.28 .57 128.00 5298.00 3.60 164.30 5289.77 -234.16 95.03 -234.16 252.71 157.91 1.58 129.00 5426.00 3.30 158.60 5417.54 -241.46 97.46 -241.46 260.39 158.02 .36 128.00 5555.00 3.00 156.90 5546.34 -248.03 100.14 -248.03 267.48 158.01 .24 129.00 5683.00 2.80 164.10 5674.18 -254.11 102.31 -254.11 273.94 158.07 .32 128.00 5811.00 2.60 167.00 5802.04 -259.95 103.82 -259.95 279.91 158.23 .19 128.00 5939.00 2.30 157.70 5929.92 -265.15 105.45 -265.15 285.35 158.31 .39 128.00 6067.00 2.50 161.70 6057.81 -270.18 107.30 -270.18 290.71 158.34 .20 128.00 6196.00 2.80 153.10 6186.67 -275.66 109.61 -275.66 296.65 158.32 .39 129.00 6324.00 2.90 151.90 6314.51 -281.31 112.55 -281.31 302.99 158.19 .09 128.00 6452.00 2.60 155.30 6442.37 -286.80 115.29 -286.80 309.10 158.10 .27 128.00 6580.00 2.60 155.90 6570.24 -292.09 117.69 -292.09 314.91 158.05 .02 128.00 6709.00 2.70 161.50 6699.10 -297.64 119.85 -297.64 320.86 158.07 .22 129.00 6837.00 3.00 160.60 6826.94 -303.66 121.91 -303.66 327.22 158.13 .24 128.00 6965.00 2.90 156.80 6954.77 -309.79 124.30 -309.79 333.80 158.14 .17 128.00 7093.00 3.10 158.00 7082.59 -315.98 126.87 -315.98 340.50 158.12 .16 128.00 7228.00 3.20 159.40 7217.39 -322.89 129.57 -322.89 347.92 158.14 .09 135.00 Projection to Bit 7275.00 3.20 159.40 7264.32 -325.35 130.49 -325.35 350.54 158.15 .00 47.00


3501.00 4.50 156.60 3497.24 -114.42 77.12 -114.42 137.99 146.02 .16 128.003629.00 4.30 151.40 3624.86 -123.25 81.41 -123.25 147.71 146.55 .35 128.003758.00 4.20 147.20 3753.51 -131.46 86.28 -131.46 157.25 146.72 .25 129.003886.00 4.00 146.00 3881.18 -139.10 91.32 -139.10 166.40 146.72 .17 128.004014.00 4.40 163.00 4008.84 -147.50 95.25 -147.50 175.58 147.15 1.02 128.00

PAGE - 1

Measured Incl Drift True Vertical CLOSURE CLOSURE Dogleg CourseDepth Angle Direction Vertical N-S E-W Section Distance Direction Severity LengthFT Deg Deg Depth FT FT FT FT Deg Deg/100 FT4143.00 4.50 172.20 4137.45 -157.25 97.39 -157.25 184.96 148.23 .56 129.004271.00 4.40 173.00 4265.07 -167.10 98.67 -167.10 194.05 149.44 .09 128.004399.00 4.40 175.00 4392.69 -176.86 99.69 -176.86 203.02 150.59 .12 128.004528.00 4.10 178.70 4521.34 -186.40 100.23 -186.40 211.64 151.73 .31 129.004656.00 4.20 180.50 4649.00 -195.66 100.29 -195.66 219.87 152.86 .13 128.00

4785.00 3.90 179.30 4777.68 -204.77 100.30 -204.77 228.02 153.90 .24 129.004913.00 3.20 184.80 4905.43 -212.69 100.06 -212.69 235.05 154.81 .61 128.005041.00 3.70 205.80 5033.20 -219.96 97.96 -219.96 240.79 155.99 1.05 128.005169.00 3.10 198.70 5160.98 -226.96 95.05 -226.96 246.06 157.28 .57 128.005298.00 3.60 164.30 5289.77 -234.16 95.03 -234.16 252.71 157.91 1.58 129.00

5426.00 3.30 158.60 5417.54 -241.46 97.46 -241.46 260.39 158.02 .36 128.005555.00 3.00 156.90 5546.34 -248.03 100.14 -248.03 267.48 158.01 .24 129.005683.00 2.80 164.10 5674.18 -254.11 102.31 -254.11 273.94 158.07 .32 128.005811.00 2.60 167.00 5802.04 -259.95 103.82 -259.95 279.91 158.23 .19 128.005939.00 2.30 157.70 5929.92 -265.15 105.45 -265.15 285.35 158.31 .39 128.00

6067.00 2.50 161.70 6057.81 -270.18 107.30 -270.18 290.71 158.34 .20 128.006196.00 2.80 153.10 6186.67 -275.66 109.61 -275.66 296.65 158.32 .39 129.006324.00 2.90 151.90 6314.51 -281.31 112.55 -281.31 302.99 158.19 .09 128.006452.00 2.60 155.30 6442.37 -286.80 115.29 -286.80 309.10 158.10 .27 128.006580.00 2.60 155.90 6570.24 -292.09 117.69 -292.09 314.91 158.05 .02 128.00

6709.00 2.70 161.50 6699.10 -297.64 119.85 -297.64 320.86 158.07 .22 129.006837.00 3.00 160.60 6826.94 -303.66 121.91 -303.66 327.22 158.13 .24 128.006965.00 2.90 156.80 6954.77 -309.79 124.30 -309.79 333.80 158.14 .17 128.007093.00 3.10 158.00 7082.59 -315.98 126.87 -315.98 340.50 158.12 .16 128.007228.00 3.20 159.40 7217.39 -322.89 129.57 -322.89 347.92 158.14 .09 135.00

Projection to Bit7275.00 3.20 159.40 7264.32 -325.35 130.49 -325.35 350.54 158.15 .00 47.00


3501.00 4.50 156.60 3497.24 -114.42 77.12 -114.42 137.99 146.02 .16 128.003629.00 4.30 151.40 3624.86 -123.25 81.41 -123.25 147.71 146.55 .35 128.003758.00 4.20 147.20 3753.51 -131.46 86.28 -131.46 157.25 146.72 .25 129.003886.00 4.00 146.00 3881.18 -139.10 91.32 -139.10 166.40 146.72 .17 128.004014.00 4.40 163.00 4008.84 -147.50 95.25 -147.50 175.58 147.15 1.02 128.00

PAGE - 1

Measured Incl Drift True Vertical CLOSURE CLOSURE Dogleg CourseDepth Angle Direction Vertical N-S E-W Section Distance Direction Severity LengthFT Deg Deg Depth FT FT FT FT Deg Deg/100 FT4143.00 4.50 172.20 4137.45 -157.25 97.39 -157.25 184.96 148.23 .56 129.004271.00 4.40 173.00 4265.07 -167.10 98.67 -167.10 194.05 149.44 .09 128.004399.00 4.40 175.00 4392.69 -176.86 99.69 -176.86 203.02 150.59 .12 128.004528.00 4.10 178.70 4521.34 -186.40 100.23 -186.40 211.64 151.73 .31 129.004656.00 4.20 180.50 4649.00 -195.66 100.29 -195.66 219.87 152.86 .13 128.00

4785.00 3.90 179.30 4777.68 -204.77 100.30 -204.77 228.02 153.90 .24 129.004913.00 3.20 184.80 4905.43 -212.69 100.06 -212.69 235.05 154.81 .61 128.005041.00 3.70 205.80 5033.20 -219.96 97.96 -219.96 240.79 155.99 1.05 128.005169.00 3.10 198.70 5160.98 -226.96 95.05 -226.96 246.06 157.28 .57 128.005298.00 3.60 164.30 5289.77 -234.16 95.03 -234.16 252.71 157.91 1.58 129.00

5426.00 3.30 158.60 5417.54 -241.46 97.46 -241.46 260.39 158.02 .36 128.005555.00 3.00 156.90 5546.34 -248.03 100.14 -248.03 267.48 158.01 .24 129.005683.00 2.80 164.10 5674.18 -254.11 102.31 -254.11 273.94 158.07 .32 128.005811.00 2.60 167.00 5802.04 -259.95 103.82 -259.95 279.91 158.23 .19 128.005939.00 2.30 157.70 5929.92 -265.15 105.45 -265.15 285.35 158.31 .39 128.00

6067.00 2.50 161.70 6057.81 -270.18 107.30 -270.18 290.71 158.34 .20 128.006196.00 2.80 153.10 6186.67 -275.66 109.61 -275.66 296.65 158.32 .39 129.006324.00 2.90 151.90 6314.51 -281.31 112.55 -281.31 302.99 158.19 .09 128.006452.00 2.60 155.30 6442.37 -286.80 115.29 -286.80 309.10 158.10 .27 128.006580.00 2.60 155.90 6570.24 -292.09 117.69 -292.09 314.91 158.05 .02 128.00

6709.00 2.70 161.50 6699.10 -297.64 119.85 -297.64 320.86 158.07 .22 129.006837.00 3.00 160.60 6826.94 -303.66 121.91 -303.66 327.22 158.13 .24 128.006965.00 2.90 156.80 6954.77 -309.79 124.30 -309.79 333.80 158.14 .17 128.007093.00 3.10 158.00 7082.59 -315.98 126.87 -315.98 340.50 158.12 .16 128.007228.00 3.20 159.40 7217.39 -322.89 129.57 -322.89 347.92 158.14 .09 135.00

Projection to Bit7275.00 3.20 159.40 7264.32 -325.35 130.49 -325.35 350.54 158.15 .00 47.00




FORM 9









9. API NUMBER: 43047541920000


9. FIELD and POOL or WILDCAT: LELAND BENCH


COUNTY: UINTAH

STATE: UTAH

11.




12/12 /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 surface hole

NAME (PLEASE PRINT) PHONE NUMBER Kristen Johnson 303 308-6270

TITLE Regulatory Technician

SIGNATURE N/A

DATE 12/10/2014

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

12/12/2014CHANGE 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 hole Date:

By:

NAME (PLEASE PRINT) PHONE NUMBER TITLEKristen Johnson 303 308-6270 Regulatory Technician


RECEIVED: Dec. 10,

RECEIVED: Apr. 14, 2015


555 17"' Street, Suite 1800Crescent Point Denver,CO80202

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, UT 84116

RE: Directional Drilling (R649-3-11) & Exception Location Request (R649-3-3)Deep Creek 6-22-4-2E

Surface Location: SENW of Section 221586' FNL & 1726' FWL

Torget Location: SENW of Section 221986' FNL& 1995' FWL

T4S-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 Oil & 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 6-22-4-2E.

• For the Deep Creek 6-22-4-2E in order to be in the target window of 460' from the lot lines we needed todrift a minimum of 190' to the south of our SHL (but no more than 590' south). We ended up 325' south ofour SHLputting us basically in the middle of the 40 acre lot north/south. We also needed to drift a minimumof 53' east of our SHL{but no more than 453' east). We ended up 130' east of our SHL.

• Crescent Polnt has notifled 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 Point 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



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 aave an objection to the directional dniling or exception location ofthe Deep Creek 2-22-4-2E

By

FName Tit e



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 Sfover 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.

By

Name & Tit e



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

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