api well number: 43047540820000 api well number · 2017. 2. 8. · api well number : 43047540820000...

RECEIVED: January 27, 2014

STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER

ULT 12-5-4-2E

2. TYPE OF WORK

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

LELAND BENCH

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')Golbert Maggs

14. SURFACE OWNER PHONE (if box 12 = 'fee')321-917-4999

15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee')230 Park Avenue, ,

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 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U

Top of Uppermost Producing Zone 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U

At Total Depth 2091 FSL 948 FWL NWSW 5 4.0 S 2.0 E U

21. COUNTYUINTAH

22. DISTANCE TO NEAREST LEASE LINE (Feet)663

23. NUMBER OF ACRES IN DRILLING UNIT40

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

920

26. PROPOSED DEPTHMD: 8006 TVD: 8006

27. ELEVATION - GROUND LEVEL

5063

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 450 1.15 15.8

Prod 7.875 5.5 0 - 8006 17.0 N-80 LT&C 10.0 Light (Hibond) 300 3.66 10.5

Class G 150 2.95 11.0

Class G 450 1.65 13.0

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 Lauren MacMillan TITLE Regulatory Specialist PHONE 303 382-6787

SIGNATURE DATE 10/25/2013 EMAIL [email protected]

API NUMBER ASSIGNED

43047540820000

Permit Manager

APPROVAL

FORM 3

AMENDED REPORT

API Well Number: 43047540820000

CONFIDE

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FORM 3STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER12-5-4-2E

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

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')Golbert Maggs 321-917-4999

15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee') 16. SURFACE OWNER E-MAIL (if box 12 = 'fee')230 Park Avenue, ,

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 663 40

25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 8006 TVD: 8006

920

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

5063 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-55 ST&C 8.3 Class G 450 1.15 15.8


Class G 150 2.95 11.0

Class G 450 1.65 13.0

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


SIGNATURE DATE 10/25/201 3 EMAIL [email protected]

API NUMBER ASSIGNED APPROVAL43047540820000

Permit Manager

RECEIVED: January 27,


FORM 3STATE OF UTAH



















920


5063 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-55 ST&C 8.3 Class G 450 1.15 15.8


Class G 150 2.95 11.0

Class G 450 1.65 13.0

ATTACHMENTS








Permit Manager



FORM 3STATE OF UTAH



















920


5063 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-55 ST&C 8.3 Class G 450 1.15 15.8


Class G 150 2.95 11.0

Class G 450 1.65 13.0

ATTACHMENTS








Permit Manager



FORM 3STATE OF UTAH



















920


5063 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-55 ST&C 8.3 Class G 450 1.15 15.8


Class G 150 2.95 11.0

Class G 450 1.65 13.0

ATTACHMENTS








Permit Manager


RECEIVED: October 25, 2013

Crescent Point Energy | ULT 12-5-4-2E | Drilling Plan 1

Crescent Point Energy U.S. Corp ULT 12-5-4-2E NW/SW of Section 5, T4S, R2E, USB&M SHL & BHL: 2091’ FSL & 948’ 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 3,910’

Mahogany 4,399’

Garden Gulch (TGR3) 5,443’

Douglas Creek 6,303’

Black Shale 6,766’

Castle Peak 6,976’

Uteland 7,262’

Wasatch 7,406’

TD 8,006’

3. Estimated Depths of Anticipated Water, Oil, Gas Or Minerals Green River Formation (Oil) 3,910’ – 7,406’ Wasatch Formation (Oil) 7,406’ – 8,006’ Fresh water may be encountered in the Uinta Formation, but would not be expected below 350’. All

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

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


CONFIDE

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Crescent Point Energy U.S. CorpULT12-5-4-2ENW/SW of Section 5, T4S, R2E, USB&MSHL& BHL:2091' FSL& 948' FWLUintah County, Utah

DRILLINGPLAN


Formation Depth -TVD/MDUinta Surface

Upper Green River Marker 3,910'

Mahogany 4,399'

Garden Gulch (TGR3) 5,443'

Douglas Creek 6,303'

Black Shale 6,766'

Castle Peak 6,976'

Uteland 7,262'

Wasatch 7,406'

TD 8,006'

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

Green River Formation (Oil) 3,910'-7,406'Wasatch Formation (Oil) 7,406'-8,006'

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 | ULT 12-5-4-2E | Drilling Plan

RECEIVED: October 25,


Crescent Point Energy U.S. CorpULT 12-5-4-2E

NW/SW of Section 5, T4S, R2E, USB&MSHL & BHL: 2091' FSL & 948' FWLUintah County, Utah

DRILLINGPLAN


Formation Depth - TVD/MDUinta Surface


Mahogany 4,399'



Black Shale 6,766'

Castle Peak 6,976'

Uteland 7,262'

Wasatch 7,406'

TD 8,006'



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)






DRILLINGPLAN




Mahogany 4,399'



Black Shale 6,766'

Castle Peak 6,976'

Uteland 7,262'

Wasatch 7,406'

TD 8,006'












DRILLINGPLAN




Mahogany 4,399'



Black Shale 6,766'

Castle Peak 6,976'

Uteland 7,262'

Wasatch 7,406'

TD 8,006'











4. Proposed Casing & Cementing Program Casing Design:

Size Interval

Weight Grade Coupling Design Factors

Top Bottom Burst Collapse Tension

Conductor

0' 40' 65 H-40 STC

16" 1,640 670 439

Hole Size 24"

Surface casing

0' 1000' 24 J-55 STC

2,950 1,370 244,000

8-5/8"

Hole Size 12-1/4" 9.27 2.63 10.17

Prod casing

0' 8,006’ 17 E-80 LTC

7,740 6,280 348,000

5-1/2"

Hole Size 7-7/8" 2.62 1.30 2.20

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

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

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

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

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


CONFIDE

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4. Proposed Casing & Cementing Program

Casing Design:

Interval Design FactorsSize Weight Grade Coupling


Conductor16" O' 40' 65 H-40 STC 1,640 670 439Hole Size 24"Surface casing 2,950 1,370 244,0008-5/8" O' 1000' 24 J-55 STCHole Size 12-1/4" 9.27 2.63 10.17Prod casing 7,740 6,280 348,0005-1/2" 0' 8,006' 17 E-80 LTC

Hole Size 7-7/8" 2.62 1.30 2.20

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.






Casing Design:



Conductor16" 0' 40' 65 H-40 STC 1,640 670 439Hole Size 24"Surface casing 2,950 1,370 244,0008-5/8" 0' 1000' 24 J-55 STCHole Size 12-1/4" 9.27 2.63 10.17Prod casing 7,740 6,280 348,0005-1/2" 0' 8,006' 17 E-80 LTCHole Size 7-7/8" 2.62 1.30 2.20










Casing Design:













Casing Design:













Cementing Design:

Job Fill Description Excess Sacks Weight Yield

(ppg) (ft3/sk)

Surface casing

1000' - surface Class V 2% chlorides 100% 450 15.8 1.15

Prod Lead 2

4500' to Surface

Hifill Class V 3% chlorides 45% in open-

hole 0% in Cased hole

300 10.5 3.66

Prod casing Lead

6500’ to 4500' Hifill Class V 3% chlorides 25% 150 11 2.95

Prod casing Tail

TD to 6500’ Class G 10% chlorides 15% 450 13 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:


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Cementing Design:

Weight YieldJob Fill Description Excess Sacks

(ppg)(ft3/Sk)

Surface1000' - surface Class V 2% chlorides 100% 450 15.8 1.15

casing45% in open-

Prod 4500' toHifillClass V 3% chlorides hole 0% in 300 10.5 3.66

Lead 2 SurfaceCased hole

Prod casing6500' to 4500' Hifill Class V 3% chlorides 25% 150 11 2.95

Lead

Prod casingTD to 6500' Class G 10% chlorides 15% 450 13 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:




Cementing Design:


(ppg) (ft'/sk)


casing45% in open-



Prod casing6500' to 4500' HifillClass V 3% chlorides 25% 150 11 2.95

Lead


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.




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. Ifgilsonite is encountered whiledrilling, it shall be isolated and/or protected via the cementing program.







Cementing Design:


(ppg) (ft'/sk)


casing45% in open-




Lead


Tail












Cementing Design:


(ppg) (ft'/sk)


casing45% in open-




Lead


Tail













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, 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)


CONFIDE

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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,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 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 CFR 355, 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.

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)










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.






• 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 Kill line valves at 2” minimum – one with a check valve o Kill line at 2” minimum 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 Kill line valves at 2" minimum -one with a check valveo Kill line at 2" minimumo 2 Choke line valves at 3" minimumo Choke line at 3" minimumo 2 adjustable chokes on manifoldo 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, 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.




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





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.










8. Accumulator

















8. Accumulator












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 as soon as possible following permit approval and will take approximately ten (10) 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 as soon as possible following permit approval andwill take approximately ten (10) 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)










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


R. 2 E. N

S 88'20 45" w N 88'16'32" E N 88°33 14" E N 86 13 56" ES¾a 1321.02° 5TN 1324.56' AC 1308.99' 1308.66' AC

.. LOT 2 LOT 1

LOT 4 LOT 3 m 12-5-4-2EGMEDEWAHOM

SCALE 1" = 1000'

STNAk - - - - -

·¯

¯-- SM.2' - -

z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATED AT THE SWCORNER SECTION 5, T4S, R2E,ELEVATION: 5117'

LATITUDE (NAD 83)NORTH 40.162717 DEG.

N 88 23'23" E 5 s2eo.44LONGITUDE (NAD 83)

STNd ----- .,

---·--- ,--- STN WEST 109.799299 DEG

1320.11 1320.11 1320.11 1320.11·

LATITUDE (NAD 27)

. oNORTH 40.162755 DEG.

948 LONGITUDE (MAD27)

ioWEST 109.798601 DEG.

NORTHING670851.36

STN --8 211 NJS610 ---

N 88'42 32" E 2657,37 EASTWG1332.24 5TN 1312.89 STN 1328.69 1328.68 Ž475479.09

DATUMSPCS UTC (NAD 27)

STNiS 88'55'01" W STN 1326.92 STN 1334.24 STN 1320.17 SN

1331.78'1000 500 0 1000 2000

§URVEVOR'SSTATEMENT SCALE FEET

DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO, HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURtNG AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLY SHOWS THE LOCATIONOF ULT 12-5-4-2E AS STAKED ON THE G

LEGENDe WELL LOCATION 8262603O BOTTOM HOLE LOC. (APPROX) q.O CALCULATEDCORNERO FOUND MONUMENT UTAH PL 603--ÊÊÒ1A PREVIOUSLY FOUND MONUMENT

PIAT OF DRIEEEVG LOCATIONRIFFIN & ASSOCIATES, INC. FOR

panær6028 1414 ELNST, ROCKSPRINGS, WY82001 UTE ENERGYDRAWN:7/9/12- TCM SCALE: 1"= 1000' 2092 F/SL & 948'F NWSW, SECTION 5,

REVISED: NA DRG JOB No. 19386 T. 4 S., R. 2 E., U.S.MEXHIBIT f N


R. 2 E. N


.. LOT 2 LOT 1


SCALE 1" = 1000'

STNAk - - - - -

·¯

¯-- SM.2' - -




STNd ----- .,

---·--- ,--- STN WEST 109.799299 DEG

1320.11 1320.11 1320.11 1320.11·

LATITUDE (NAD 27)

. oNORTH 40.162755 DEG.



NORTHING670851.36

STN --8 211 NJS610 ---

N 88'42 32" E 2657,37 EASTWG1332.24 5TN 1312.89 STN 1328.69 1328.68 Ž475479.09



1331.78'1000 500 0 1000 2000








R. 2 E. N


.. LOT 2 LOT 1


SCALE 1" = 1000'

STNAk - - - - -

·¯

¯-- SM.2' - -




STNd ----- .,

---·--- ,--- STN WEST 109.799299 DEG

1320.11 1320.11 1320.11 1320.11·

LATITUDE (NAD 27)

. oNORTH 40.162755 DEG.



NORTHING670851.36

STN --8 211 NJS610 ---

N 88'42 32" E 2657,37 EASTWG1332.24 5TN 1312.89 STN 1328.69 1328.68 Ž475479.09



1331.78'1000 500 0 1000 2000








R. 2 E. N


.. LOT 2 LOT 1


SCALE 1" = 1000'

STNAk - - - - -

·¯

¯-- SM.2' - -




STNd ----- .,

---·--- ,--- STN WEST 109.799299 DEG

1320.11 1320.11 1320.11 1320.11·

LATITUDE (NAD 27)

. oNORTH 40.162755 DEG.



NORTHING670851.36

STN --8 211 NJS610 ---

N 88'42 32" E 2657,37 EASTWG1332.24 5TN 1312.89 STN 1328.69 1328.68 Ž475479.09



1331.78'1000 500 0 1000 2000









CONFIDE

NTIAL


PROPOSED ACCESS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY

(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2EDRAWN: 7/10/12-DEH SCALE: 1"= MALE SECTION S, T4S, R2E

REVISED: NA DRG JOB No. 19386

TOPO A - 1 OF2 PROPOSED ROAD -•--·•-- EXJSTING ROAD






















CONFIDE

NTIAL


T4S.

ULT12-5-4-2E

ILES -

15W




TOPOA-20F2 PROPOSEDROAD-•--·•-- EXJSTINGROAD



T4S.

ULT12-5-4-2E

ILES -

15W







T4S.

ULT12-5-4-2E

ILES -

15W







T4S.

ULT12-5-4-2E

ILES -

15W








CONFIDE

NTIAL


ULTU1LIS-

DEEP RI 2E4-32-3-2E

l 3-2E

T

EgEP CRK TRIBALDE CRK GIB IC (JTE TRI AL-2EN 5- E 5-4 41-5 4-2E

-- I

DEEP CREEKA N OVERS y WERS , BOVE MSTMENTS TRIBAL

-6-4-at 46 4-2E eks-4 ETALTRHMLLAND§ ·¯

-

---- 6 ULT

12- -4-2E e 1- -

N10-6 ULT 12-5 4-2E -2E 0- I

UTE TRIBALUTE T AL-

. FRANI( D.#L3-4-4-2Ett4-4-44E

ULT ULT CWEATER13-6-4-2E 14- 4-2E

#15-6-4-2E 816- -2E 1 TRUSTEEETAL746.9'± TE

L4-9 4-2E

0-8-4-2E .CRK..RK TRIB LL 4-2E

-4 E 8 4 1-ß 4-2E

15 7 4 7 4C TR Br,L

4

RK TR[B 7 4 CRK T - 7 - 2E

. RANDLETT 95-17-4.-25 e --A-

APPROX. ROAD DISTURBANCE: 0.9± ACRES 1NST4LL CMP: Ci ,v ¡ , ,

. r'

PROPOSED ROAD FOR

RIFF/N & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCK SPRINGS. WY82901 ULT 12-5-4-2E

DRAWN: 7/10/12-DEH SCALE: 1"=2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 748.9'±

TOPO B PROPOSED ROAD - - - - - - - EXJSTING ROAD



ULTU1LIS-

DEEP RI 2E4-32-3-2E

l 3-2E

T


-- I



-

---- 6 ULT

12- -4-2E e 1- -

N10-6 ULT 12-5 4-2E -2E 0- I

UTE TRIBALUTE T AL-

. FRANI( D.#L3-4-4-2Ett4-4-44E



L4-9 4-2E


-4 E 8 4 1-ß 4-2E

15 7 4 7 4C TR Br,L

4

RK TR[B 7 4 CRK T - 7 - 2E

. RANDLETT 95-17-4.-25 e --A-


. r'

PROPOSED ROAD FOR






ULTU1LIS-

DEEP RI 2E4-32-3-2E

l 3-2E

T


-- I



-

---- 6 ULT

12- -4-2E e 1- -

N10-6 ULT 12-5 4-2E -2E 0- I

UTE TRIBALUTE T AL-

. FRANI( D.#L3-4-4-2Ett4-4-44E



L4-9 4-2E


-4 E 8 4 1-ß 4-2E

15 7 4 7 4C TR Br,L

4

RK TR[B 7 4 CRK T - 7 - 2E

. RANDLETT 95-17-4.-25 e --A-


. r'

PROPOSED ROAD FOR






ULTU1LIS-

DEEP RI 2E4-32-3-2E

l 3-2E

T


-- I



-

---- 6 ULT

12- -4-2E e 1- -

N10-6 ULT 12-5 4-2E -2E 0- I

UTE TRIBALUTE T AL-

. FRANI( D.#L3-4-4-2Ett4-4-44E



L4-9 4-2E


-4 E 8 4 1-ß 4-2E

15 7 4 7 4C TR Br,L

4

RK TR[B 7 4 CRK T - 7 - 2E

. RANDLETT 95-17-4.-25 e --A-


. r'

PROPOSED ROAD FOR







CONFIDE

NTIAL


ULT DEEP RK ;- -1E 4- E #2-

UT ' DE CRK uit REBAL-31 - 88 31 6¯ ¯3¯2E

32

DEEP CREEKA N INVESTMKVTS

ETAL

ULT 12-5-4 E

FRANK D

14- L EEEET

1L

UTE TREBAt#6-9-4-2E

COLEMnN FRIE

-ÙTEL3 COLÈMAN fRIBA2-19-4-2E

L½DKINGLE DEEP CRK TR2EBAL

ONE MILE RADIUS FORRIFF/N & ASSOCIATES, INC. UTE ENERGY

(sonas2 so2e 1414 ELK ST., ROCK SPRINGS, WY82901 ULT 12-5-4-2EDRAI/VN:7/10/12-DEH SCALE: 1"=2000' SECTION Æ,T4S, R2E


TOPO C PROPOSED ROAD - - - - - - - EXJSTING ROAD





32


ETAL

ULT 12-5-4 E

FRANK D

14- L EEEET

1L

UTE TREBAt#6-9-4-2E

COLEMnN FRIE











32


ETAL

ULT 12-5-4 E

FRANK D

14- L EEEET

1L

UTE TREBAt#6-9-4-2E

COLEMnN FRIE











32


ETAL

ULT 12-5-4 E

FRANK D

14- L EEEET

1L

UTE TREBAt#6-9-4-2E

COLEMnN FRIE










CONFIDE

NTIAL


- -__ IE 1RIBAL- -ULT /

SU1LIDE P RK

4-32-3-2E- -1E 94- E

-

5-3U 3-2E ULT 7 3 - DE CR EBA

--

1 6 -2E

1 -

Eet. 3-

---- EgEP RK TRIBALDE CRK GIB IC - UTE TRIÈAL

T 4 S -2EN 5- E 5- - - 41-5 4-2E

-- _ - r END SERVEY ATDEEP CREEK '

A ES B E4 IN ThfENTS T in EI7EELIVE

yggg IBALBEGIN SURVE) I ---~ -4-4-2E

- LANDSULTULT so-¿_» - T UT TRIBAL

12- -4-2E#10-6 ULT 12-5-4-2E 4-2E#10- 4-2E I '--

· - UTE TRIBALUTE T AL-

. FRANK D,#L3-4-4-2E#l4-4 <<E

CARPENTER UT TRIBAL13-6 4-2E 14-ULT4-2E

#15-6LT4-2E816- 2E

1 TRUSTEEETAL16- 4-2E

I4E

4

N

10-9-4-2E

-4

4 ELL 4-2E

DE 7 4 3 8 4 8 42EBr,L

COL TR

41742

EMANT Alg3-18-4-4 2E

-18-4-2

L 7 4 CRK T -CL7¯E

2E

AN TT 5-1 ._4-2Ç.

PROPOSED PIPELINE FOR

RIFFIN & ASSOCIATES, INC. UTE ENERGY(son362-5028 1414 ELK ST., ROCN SPRINGS. WY82901 ULT 12-5-4-2E

DRAI/VN:7/10/12-DEH SCALE: 1"-2000' SECT10N 5, T4S, R2EREVISED: NA DRG JOB No. 19386 TOTAL PROPOSED LENGTH: 725.7'±

TOPO D PROPOSED P/PELINE - - - - - EXJSTING ROAD




SU1LIDE P RK

4-32-3-2E- -1E 94- E

-


--

1 6 -2E

1 -

Eet. 3-


T 4 S -2EN 5- E 5- - - 41-5 4-2E





12- -4-2E#10-6 ULT 12-5-4-2E 4-2E#10- 4-2E I '--


. FRANK D,#L3-4-4-2E#l4-4 <<E

CARPENTER UT TRIBAL

13-6 4-2E 14-ULT4-2E#15-6LT4-2E

816- 2E1 TRUSTEEETAL

16- 4-2E

I4E

4

N

10-9-4-2E

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4 ELL 4-2E

DE 7 4 3 8 4 8 42EBr,L

COL TR

41742


-18-4-2

L 7 4 CRK T -CL7¯E

2E

AN TT 5-1 ._4-2Ç.








SU1LIDE P RK

4-32-3-2E- -1E 94- E

-


--

1 6 -2E

1 -

Eet. 3-


T 4 S -2EN 5- E 5- - - 41-5 4-2E





12- -4-2E#10-6 ULT 12-5-4-2E 4-2E#10- 4-2E I '--


. FRANK D,#L3-4-4-2E#l4-4 <<E

CARPENTER UT TRIBAL

13-6 4-2E 14-ULT4-2E#15-6LT4-2E


16- 4-2E

I4E

4

N

10-9-4-2E

-4

4 ELL 4-2E

DE 7 4 3 8 4 8 42EBr,L

COL TR

41742


-18-4-2

L 7 4 CRK T -CL7¯E

2E

AN TT 5-1 ._4-2Ç.








SU1LIDE P RK

4-32-3-2E- -1E 94- E

-


--

1 6 -2E

1 -

Eet. 3-


T 4 S -2EN 5- E 5- - - 41-5 4-2E





12- -4-2E#10-6 ULT 12-5-4-2E 4-2E#10- 4-2E I '--


. FRANK D,#L3-4-4-2E#l4-4 <<E

CARPENTER UT TRIBAL

13-6 4-2E 14-ULT4-2E#15-6LT4-2E


16- 4-2E

I4E

4

N

10-9-4-2E

-4

4 ELL 4-2E

DE 7 4 3 8 4 8 42EBr,L

COL TR

41742


-18-4-2

L 7 4 CRK T -CL7¯E

2E

AN TT 5-1 ._4-2Ç.








CONFIDE

NTIAL

API Well Number: 430475Ù820000

MEMORANDUM of SURFACE USE AGREEMENT AND GRANT OF EASEMENTS

Todd Kalstrom is the Vice President of Land for Ute Energy LLC and Ute Energy UpstreamHoldings LLC, authorized to do business in Utah (hereinafter referred to as "Ute Energy"). UteEnergy 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 April 26th, 2011 has been entered into by and between Utah Land Trust, whose addressis c/o Gilbert Maggs, as Trustee, 230 Park Avenue, Satellite Beach, FL 32937 ("Owner") and UteEnergy Upstfeam Holdings LLC, whose address is 1875 Lawrence Street, Suite 200, Denver, CO80202 ("Operator").

WHEREAS, as of the date referenced above, this Agreement replaces in all respect the existingagreement covering a portion of the Property listed below and made and entered into betweenFlying J Oil and Gas Inc., a Utah corporation and Utah Land Trust, and found at Entry Number2008007507 of the Uintah County Recorder's Office in Uintah County, Utah.

WHEREAS, Owner owns the surface estate of the real property in Uintah County, Utah (the"Property"), legally described as:

Township 3 South, Range 1 East, USMSection 25: S/2SWl4Section 26: S/2, S/2N/2Section 34: AIISection 35: N/2Section 36: All

Township 3 South, Range 2 East, USMSection 29: W/2Section 31: Wl2

Township 4 South, Range 2 East, USMSection 5: SW/4Section 6: S/2

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 land and be binding upon and inure to the benefitof the parties and their respective heirs, successors and assigns as stated in this Agreement.

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

This Memorandum is executed this 28 day of April,

To KalstromVi e President of



















































CONFIDE

NTIAL


Entry 2011003143Book 1231 Page 5?6

ACKNOWLEDGEMENT

STATE OF COLORADO)) ss

COUNTY OF DENVER )

The foregoing instrument was acknowledged before me by Todd Kalstrom, Vice President of Land for UteEnergy LLC and Ute Energy Upstream Holdings LLC thi 8th day of il, 201l.

Notary PublicNotary Seal:

y Commission expires: KARIQUARLESNOTARYPUBLIC,STATEOFCOLORADO

Dat MyComm. Expires September 15, 2014i

I

Book 1231 Page 575-sk son0029- PR-11 0 :56RANDYSIMMONGRECORDER:UINTAHCOUNTY,UTAHUTEENERGYLLCATTNFELICIAGATES-MPD BOX789 FT DUCHEGNE,UT84026Rec By: SYLENEACCUTTORODP,


Entry 2011003143Book 1231 Page 5?6

ACKNOWLEDGEMENT


COUNTY OF DENVER )





I

Book 1231 Page 575-sk son0029- PR-11 0 :56

RANDYSIMMONGRECORDER:UINTAHCOUNTY,UTAHUTEENERGYLLCATTNFELICIAGATES-MPD BOX789 FT DUCHEGNE,UT84026Rec By: SYLENEACCUTTORODP,


Entry 2011003143Book 1231 Page 5?6

ACKNOWLEDGEMENT


COUNTY OF DENVER )





I




Entry 2011003143Book 1231 Page 5?6

ACKNOWLEDGEMENT


COUNTY OF DENVER )





I




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




CONFIDE

NTIAL

API Well Number: 43047540820000I

Crescent Point assivisstreet.suiteisooENERGY U.S . CCRP Denver,CO80202

September 4, 2013

5tate of Utah, Division of Oil, Gas and MiningAttention: Diana Mason1594 West North TempleSalt Lake City, UT 84116

RE: Exception Location RequestULT 12-5-4-2ETownship 4 South, Range 2 East, USMSection 5: NW/4SW/4Uintah County, Utah

Dear Ms. Mason:

Crescent Point Energy U.S. Corp (Crescent Point) proposes to drill the captioned well with a surface location of 2,091'FSL; 948' FWL of Section 5, Township 4 South, Range 2 East, USM, Uintah County, Utah. A copy of the survey plat isattached hereto for your reference. Crescent Point is the only owner of oil and gas leases within a 460' radius of theintended wellbore.

Due to these circumstances, Crescent Point respectfully requests that DOGM administratively grant an exceptionlocation for the ULT12-5-4-2E.

Landman

www.crescentpointenergy.com



September 4, 2013



Dear Ms. Mason:



Landman




September 4, 2013



Dear Ms. Mason:



Landman




September 4, 2013



Dear Ms. Mason:



Landman




CONFIDE

NTIAL


R. 2 E. N

S 88¯20'45" w N 88'15'32" E N 88 33 14" E N 88'13'56" ESTN' 1321.02' STN 1324.56" AC 1308.99' 1308.66' AC

LOT 2 LOT 1

09 LOT 4 LOT 3 o.12-5-4-2E 4

UNGNEDÉWAHOM scALE 1" = 1000'

z BASIS OF ELEVATION: USGS SPOTELEVATION LOCATEDAT THE SWCORNER SECTION 5, T45, R2E,ELEVATION: 5117'


5 ,

LONGITUDE/NAD83) 'N 88'2523" E 5280.44 • /

STN - ---- -- -'- .-----

--- --- -- )-- .-- STN WEST 109.799299 DEG1320.11 1320.11 1320.11 liil

LATITUDE (NAD27)NORTH 40.162755 DEG.LONGITUDE (NAD 27)WEST 109.798601 DEG.

NORTHING6¯/0851.36

s1N 3--?U211"_.....

-89

N 88'42'32 E 265137'- EASTWG

1332 24' STN 1312 89 STN 1328.69 1328.68 2475479.09

z z z

- o o - E - 9 DATUMSPCS UTC (NAD 27)

STN 5 88'55'01" W STN 1328.92 STN 1334.2 STN 132017 S(N

1331.781000 500 0 1000 20DO

STIRVEYOR'SSTATEMENT SCALE FEET

I, DAVID E. HENDERHAN, OF GRAND JUNCTION, COLORADO.HEREBY STATE: THIS MAP WAS MADE FROM NOTESTAKEN DURING AN ACTUAL FIELD SURVEY DONE UNDER MY DIRECT SUPERVISION ON JUNE 29, 2012 AND THAT THISPLAT CORRECTLYSHOWS THE LOCATJON OF ULT 12-5-4-2E AS STAKED ON THE GROUND

LEGEND< > WELLLOCATION 82626 3

BOTTOM HOLE LOC. (APPROX)

O CALCULATED CORNERO FOUND MONUMENT UTAH 03-2201& PREVIOUSLY FOUND MONUMENT

PLAT OF DRELEVG LOCATIONRIFFIN & ASSOC/ATES, ING. FOR

(907)362-502B 1414 ELKST., ROCK SPRINGS, WY82901 f/TE ENERGYDRAWN: 7/9/12 - TCM SCALE: i"= 1000' 2091' F/SL & 948' F/WL, NWSW, SECTION 5,

REVISED: NA ORG JOB No. 19386 T. 4 S., R. 2 E., U.S.ME¥HIB/T 1 *


R. 2 E. N


LOT 2 LOT 1

09 LOT 4 LOT 3 o.12-5-4-2E 4




5 ,

LONGITUDE/NAD83) 'N 88'2523" E 5280.44 • /

STN - ---- -- -'- .-----

--- --- -- )-- .-- STN WEST 109.799299 DEG1320.11 1320.11 1320.11 liil


NORTHING6¯/0851.36

s1N 3--?U211"_.....

-89

N 88'42'32 E 265137'- EASTWG

1332 24' STN 1312 89 STN 1328.69 1328.68 2475479.09

z z z



1331.781000 500 0 1000 20DO










R. 2 E. N


LOT 2 LOT 1

09 LOT 4 LOT 3 o.12-5-4-2E 4




5 ,

LONGITUDE/NAD83) 'N 88'2523" E 5280.44 • /

STN - ---- -- -'- .-----

--- --- -- )-- .-- STN WEST 109.799299 DEG1320.11 1320.11 1320.11 liil


NORTHING6¯/0851.36

s1N 3--?U211"_.....

-89

N 88'42'32 E 265137'- EASTWG

1332 24' STN 1312 89 STN 1328.69 1328.68 2475479.09

z z z



1331.781000 500 0 1000 20DO










R. 2 E. N


LOT 2 LOT 1

09 LOT 4 LOT 3 o.12-5-4-2E 4




5 ,

LONGITUDE/NAD83) 'N 88'2523" E 5280.44 • /

STN - ---- -- -'- .-----

--- --- -- )-- .-- STN WEST 109.799299 DEG1320.11 1320.11 1320.11 liil


NORTHING6¯/0851.36

s1N 3--?U211"_.....

-89

N 88'42'32 E 265137'- EASTWG

1332 24' STN 1312 89 STN 1328.69 1328.68 2475479.09

z z z



1331.781000 500 0 1000 20DO











CONFIDE

NTIAL


o APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±5.2% GRADE OF A NORTHERLY SLOPE

UNGRADED ELEVATION: 5064.2'FINISHED ELEVATION: 5063.7'

/ 158' STA 4+00162'

I I / \\

' COMPLET/ONSP/T/ 140' x 100' x 12'

24, J8J Bb/s/ 19,478 Bb/s STA 3+00| | WITH 2' FREEBOARD \

/ 1.5 C 6.

/ --RESERVE P/T,/ 100' X 60' X 12'/

\ / 9,JJ6 Bb/s /| 15 FLARE PIT7,224 Bb/s/ I \

/38

2' FREEBOCARD \STA 2+2000 / 5

162' 148 STA 0+00S 14 56'57" E ..' . 310

EXCE3S M TER AL P

BHLBEFORE DIGGING

CALL FORTJTILITY LINE LOCATION

NOTE: THE EARTH QUANTITIES ON 80 0 80ANDHSTHDER lENOFAREHISE MAATEDHE

RESPONSIBILITY OF THE USER. SCALE FEET

UTE ENERGYIFFIN & ASSOCIATES, INC. ULT12-5-4-2E

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM SCALE: 1"= 80'

REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1 FINISHED ELEVATION: 5063.7'





/ 158' STA 4+00162'

I I / \\



/ 1.5 C 6.

/ --RESERVE P/T,/ 100' X 60' X 12'/


/38


162' 148 STA 0+00S 14 56'57" E ..' . 310

EXCE3S M TER AL P

BHLBEFORE DIGGING











/ 158' STA 4+00162'

I I / \\



/ 1.5 C 6.

/ --RESERVE P/T,/ 100' X 60' X 12'/


/38


162' 148 STA 0+00S 14 56'57" E ..' . 310

EXCE3S M TER AL P

BHLBEFORE DIGGING











/ 158' STA 4+00162'

I I / \\



/ 1.5 C 6.

/ --RESERVE P/T,/ 100' X 60' X 12'/


/38


162' 148 STA 0+00S 14 56'57" E ..' . 310

EXCE3S M TER AL P

BHLBEFORE DIGGING










CONFIDE

NTIAL


120'162' 38'

100' FI BIII

I ¯

l 100'I

I

ô

'¯ lIII

162' 148'

PAD LAYOUTUTE ENERGYIFFIN & ASSOCIATES, INC.

(307) 362-5028 1414 ELK ST., ROCK SPRINGS, VVY82901 ULT 12-5-4-2EDRAWN: 7/9/12- TCM SCALE: 1"= 80' SECTION 5, T4S, R2E

REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'FIGURE#1A FINISHED ELEVATION: 5063.7'



120'162' 38'

100' FI BIII

I ¯

l 100'I

I

ô

'¯ lIII

162' 148'






120'162' 38'

100' FI BIII

I ¯

l 100'I

I

ô

'¯ lIII

162' 148'






120'162' 38'

100' FI BIII

I ¯

l 100'I

I

ô

'¯ lIII

162' 148'







CONFIDE

NTIAL


GRADE

5060 FILL.---- - I

' CUT5060

I I I II I I I5050 5050

-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 4+00

5080 5080

5070 -GRADF 5070

5060 / ILL py 5060

I II I

5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 3+00

5080 5080

GRADE

6 FILL

CT

6

5050 5050-2 -00 -1 ·50 -1 00 -0 -50 0+00 0+50 1+00 1+50 2+00

STA 2+20III

5080 5080I

GRADE

5070 - pyy I 5070

5060 Fl L_

5060

I I5050 5050

-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 0+00

UTE ENERGYRIFFIN & ASSOCIATES, INC. ULT 12-5-4-2E

(son se2-so28 1414 ELK ST., ROCK SPRINGS, WY82901 SECTION 5, T4S, R2EDRAWN: 7/9/12- TCM HORZ. 1"= 60' VERT. 1"=20'

REVISED: NA DRG JOB No. 19386 UNGRADED ELEVATION: 5064.2'F/GURE#2 FINISHED ELEVATION: 5063.7'



GRADE

5060 FILL.---- - I

' CUT5060

I I I II I I I

5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 4+00

5080 5080

5070 -GRADF 5070

5060 / ILL py 5060

I II I

5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 3+00

5080 5080

GRADE

6 FILL

CT

6

5050 5050-2 -00 -1 ·50 -1 00 -0 -50 0+00 0+50 1+00 1+50 2+00

STA 2+20III

5080 5080I

GRADE

5070 - pyy I 5070

5060 Fl L_

5060

I I5050 5050

-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 0+00






GRADE

5060 FILL.---- - I

' CUT5060

I I I II I I I

5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 4+00

5080 5080

5070 -GRADF 5070

5060 / ILL py 5060

I II I

5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 3+00

5080 5080

GRADE

6 FILL

CT

6

5050 5050-2 -00 -1 ·50 -1 00 -0 -50 0+00 0+50 1+00 1+50 2+00

STA 2+20III

5080 5080I

GRADE

5070 - pyy I 5070

5060 Fl L_

5060

I I5050 5050

-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 0+00






GRADE

5060 FILL.---- - I

' CUT5060

I I I II I I I

5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 4+00

5080 5080

5070 -GRADF 5070

5060 / ILL py 5060

I II I

5050 5050-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 3+00

5080 5080

GRADE

6 FILL

CT

6

5050 5050-2 -00 -1 ·50 -1 00 -0 -50 0+00 0+50 1+00 1+50 2+00

STA 2+20III

5080 5080I

GRADE

5070 - pyy I 5070

5060 Fl L_

5060

I I5050 5050

-2+00 -1+50 -1+00 -0+50 0+00 0+50 1+00 1+50 2+00

STA 0+00







CONFIDE

NTIAL


APPROX/MATE DISTURBANCE AREA: 5.5 ACRES±co / 5.2% GRADE OF A NORTHERLY SLOPE

UNGRADED ELEVATION: 5064.2'

/ ---

--

-----....._.

FINISHEDELEVATION 50

158' c. STA 4+00162'

ll / . O

I II

KAGE ' COMPLET/ONSP/T/ 140' X 100' X 12'

| 24, J8J Bb/s || 19,478 Bb/s | STA 3+00U WITH2' FREEBOARD \TOILET

/ 1.5 C 6.- / - -RESERVE P/T,

/ 100' X 60' X 12'// 9,JJ6 Bb/s /| 15 FLARE PIT

7,224 Bb/s/ iMTH22' FREEBOCARD

30 STA 2+20

PE RACKS

I / /

162' 148 STA 0+00S 14 56'57" E ' 310

-

·~" EXCE3S M TER AL PI

BHLBEFORE DIGGING



RESPONSIBILITY OF THE USER. SCALE FEETf/TE ENERGYULT 12-5-4-2E

SECTION 5, T4S, R2ERIFFIN & ASSOCIATES, INC. ESTIMATED EARTHWORK

(307) 362-50281414 ELK ST., ROCK SPRINGS, WY82901

ITEM CUT FILL TOPSOIL EXCESSDRAWN:7/9/12-TCM SCALE: 1"=80' PAD 13,351CY 8,482CY 2,347CY 2,522CY

REVISED: NA DRG JOB No. 19386 PIT 7,011 CY 7,011 CY

FIGURE#3 TOTALS 20,362 CY 8,482 CY 2,347 CY 9,533 CY





/ ---

--

-----....._.


158' c. STA 4+00162'

ll / . O

I II



/ 1.5 C 6.- / - -RESERVE P/T,



30 STA 2+20

PE RACKS

I / /

162' 148 STA 0+00S 14 56'57" E ' 310

-


BHLBEFORE DIGGING













/ ---

--

-----....._.


158' c. STA 4+00162'

ll / . O

I II



/ 1.5 C 6.- / - -RESERVE P/T,



30 STA 2+20

PE RACKS

I / /

162' 148 STA 0+00S 14 56'57" E ' 310

-


BHLBEFORE DIGGING













/ ---

--

-----....._.


158' c. STA 4+00162'

ll / . O

I II



/ 1.5 C 6.- / - -RESERVE P/T,



30 STA 2+20

PE RACKS

I / /

162' 148 STA 0+00S 14 56'57" E ' 310

-


BHLBEFORE DIGGING











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RANDLETT 24304730253

DEEP CREEK8-314304740032

COLEMAN TRIBAL7-8-4-2E4304751496

UTE TRIBAL6-32-3-2E4304751555

UTE TRIBAL1-5-4-2E4304751556

UTE TRIBAL10-5-4-2E4304751557

UTE TRIBAL6-9-4-2E4304751558

ULT 10-6-4-2E4304751569ULT 12-6-4-2E

4304751571

ULT 14-6-4-2E4304751572

ULT 16-6-4-2E4304751573

ULT 11-5-4-2E4304751574

DEEP CREEK13-32-3-2E4304751575

ULT14-31-3-2E4304751576

ULT16-36-3-1E4304751580

ULT12-31-3-2E4304751585

ULT 6-31-3-2E4304751661

DEEP CREEK11-32-3-2E4304751664


COLEMAN TRIBAL7-7-4-2E

4304751728

DEEP CREEKTRIBAL 9-7-4-2E4304751729





ULT 9-36-3-1E4304751900

ULT 9-6-4-2E4304751916

ULT 15-6-4-2E4304751928

ULT 8-36-3-1E4304751931

ULT 11-6-4-2E4304751932

ULT 13-6-4-2E4304751934



DEEP CREEKTRIBAL 9-8-4-2E4304752007DEEP CREEK

TRIBAL 11-8-4-2E4304752008



UTE TRIBAL15-32-3-2E4304752195

UTE TRIBAL16-5-4-2E4304752196

UTE TRIBAL11-4-4-2E4304752197

UTE TRIBAL13-4-4-2E4304752198

UTE TRIBAL14-4-4-2E4304752199

UTE TRIBAL4-9-4-2E4304752200





DEEP CREEK13-9-4-2E4304752410

DEEP CREEK11-9-4-2E4304752415

ULT 14-5-4-2E4304752417

BOWERS1-6-4-2E4304752419

BOWERS2-6-4-2E4304752420

BOWERS3-6-4-2E4304752421

ULT 13-5-4-2E4304752423

BOWERS5-6-4-2E4304752427

BOWERS6-6-4-2E4304752428

BOWERS7-6-4-2E4304752430

BOWERS8-6-4-2E4304752431

BOWERS4-6-4-2E4304752432

DEEP CREEK12-9-4-2E4304752440

UTE TRIBAL1-1-4-1E4304752441

UTE TRIBAL9-1-4-1E4304752443

DEEP CREEK14-9-4-2E4304752445

DEEP CREEK12-32-3-2E4304752453

DEEP CREEK14-32-3-2E4304752455

















UTE TRIBAL1-12-4-1E4304752517

ULT 5-31-3-2E4304752956

ULT11-31-3-2E4304752957

ULT13-31-3-2E4304752958

DEEP CREEK7-31-3-2E4304752984

UTE ENERGY16-31-3-2E4304752985

UTE ENERGY15-31-3-2E4304752986

Ute Tribal7-5-4-2E4304753782

Ute Tribal2-5-4-2E4304753783

Ute Tribal10-32-3-2E4304753784

Ute Tribal5-32-3-2E4304753785

Ute Tribal3-9-4-2E

4304753787

Ute Tribal15-5-4-2E4304753788

Ute Tribal9-5-4-2E4304753789

Ute Tribal5-9-4-2E4304753790

Ute Tribal8-5-4-2E4304753791

Deep CreekTribal 5-4-4-2E4304754005

Deep CreekTribal 12-4-4-2E4304754006

Deep CreekTribal 15-4-4-2E

4304754008

ULT 12-5-4-2E4304754082

Deep Creek5-33-3-2E4304754087

Deep Creek6-33-3-2E

4304754094

Deep Creek7-32-3-2E4304754095

Deep Creek8-32-3-2E

4304754099

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

TOOELE

SAN JUAN

MILLARD

KANE

JUAB

IRON

EMERY

UINTAH

BOX ELDER

GARFIELD

GRAND

UTAH

WAYNEBEAVER

DUCHESNE

SEVIER

SUMMIT

RICH

WASHINGTON

CARBON

SANPETE

CACHE

PIUTE

DAVIS

WASATCH

WEBER

SALT LAKE

DAGGETT

MORGAN

Location Map

API Number: 4304754082Well Name: ULT 12-5-4-2E Township: T04.0S Range: R02.0E Section: 05 Meridian: U

Operator: CRESCENT POINT ENERGY U.S. CORP

Map Prepared: 10/30/2013


CONFIDE

NTIAL


ULT8-36 3-1E ULT6-31-3-2E DEEP CREEK Ute Tribal UTE TRIBAL Deep Creek D CreeDeep Creek

4304751 31 443LO457-532193562E4304751661 443301472E84 EPCREEK +5-3302473E85 33024755

e433024734E95e 43

3p73302 API Number: 4304754082430474(032 De8e3p2 2ek Well Name: ULT 12-5-4-2E

ULT 1 31-3-2E DEEP C EEK Ute Tribal Township: TO4.0S Range: RO2.0E Section: 05 Meridian: UULT9-36 3-1E 12-31-3-2E 4304752957 DEEP CREEK 11-32-3- 10-32-3-2E

Operator: CRESCENT POINT ENERGY U.S. CORP4304751 00 4304751585 12-32-3-2E 4304751064 4304753784

36 31 4304752453 3332 Map Prepared: 10/30/2013

9


ULT ULT4LT31-3-2E UTE ENE GY DEEP CREEK DEEP CI,EEK UTE TRIBAL

0345 0

0345

29E8 4304751576 R3A0N4D3L0E25320341322

5034'5 5E5 034'5 E5 034

5 5

TE ENERGY15-31-3-2E4304752986 Welle Query Units

UTE TRI AL BOWERS BOWERS BOWERS DEEP CREEK DEEP CREEK Ute Tribal5E T2RI AL sta s

APo-Aprovec Permit AcnvE

3 4 5 41 4E2RES 3604 5E421

3 45E420

3 45E419

3RIBA5L2422554-2ERIBA5L2322534-2E 3504 5E783 4304751 56 DRL spude ori ngcommenceci ExPSLSosAvoav

4304752432 Deep Creek os osss NFPPat

BOWERS BOWERS BOWERS 8-E2 DEEP CREEK DEEP CREEK 7 4

bEal

4

5br30bal75544452E oNDARY

5-6-4-2E 6-6-4-2E 7-6-4-2E 430475 431 TRIBAL5-5-4-2E TRIBAL6-5-4-2E 4304753782 4 sposoyeesse4304752427 4304752428 4304752430 + 4304752224 4304752226 * 04 PPat

06 05 sEcoNDARY

Ute Triba Deep Creek UTE TRIBAL TERMiNATED

UTETRIBAL 9-5-4-2E Tribal12-4-4-2E30 7

2Egyve neone

UTE T1R ALULT 12-6-4-2E ULT 11-6-4-2E

43LO417051654692E43LO756-49-2 3LO417254504822E

ULT 11-5-4-2E0547

574304753 89 4304754006

014304752- 43 4304751571 4304751932 + 4304751574 se

Ute Tribal UTE TRIBAL SUPP

15-5-4-2E UTE T IBAL UTE TRIBAL 14-4-4-2E4304753788 16-5-4- E

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BOPE REVIEW CRESCENT POINT ENERGY U.S. CORP ULT 12-5-4-2E 43047540820000

Well Name CRESCENT POINT ENERGY U.S. CORP ULT 12-5-4-2E 43047540820000

String Cond Surf Prod

Casing Size(") 16.000 8.625 5.500

Setting Depth (TVD) 4 0 1000 8006

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) 4163 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= 4163


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)= 3202 NO 3M BOPE, rotating head, annular preventer,

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)= 2402 YES dbl rams, choke & kill lines


Pressure At Previous Shoe Max BHP-.22*(Setting Depth - Previous Shoe Depth)= 2622 NO OK

Required Casing/BOPE Test Pressure= 3000 p s i

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

Calculations String "

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


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

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


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

Required Casing/BOPE Test Pressure= p s i

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


CONFIDE

NTIAL



Well Name CRESCENT POINT ENERGY U.S. CORP ULT 12-5 4-2E 43047540820


Casing Size(") 16.000 8.625 5.500

Setting Depth (TVD) 40 1000 8006

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=

4163


MASP (Gas) (psi) Max BHP-(0.12*Setting Depth)=3202 NO 3M BOPE, rotating head, annular preventer,

MASP (Gas/Mud) (psi) Max BHP-(0.22*Setting Depth)=2402 dbl rams, choke & kill 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







Casing Size(") 16.000 8.625 5.500








17









432









4163








Calculations String














Casing Size(") 16.000 8.625 5.500








17









432









4163








Calculations String














Casing Size(") 16.000 8.625 5.500








17









432









4163








Calculations String












CONFIDE

NTIAL


43047540820000 LT 12-5-4-2ECasing Schema ,

' oosurface -

Tocoo.Toco295.

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

5-1/2" 'Production

MW 10. 8006.



' oosurface -

Tocoo.Toco295.


5-1/2" 'Production

MW 10. 8006.



' oosurface -

Tocoo.Toco295.


5-1/2" 'Production

MW 10. 8006.



' oosurface -

Tocoo.Toco295.


5-1/2" 'Production

MW 10. 8006.



CONFIDE

NTIAL


Well name: 43047540820000 ULT 12-6-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Surface Project ID:

43-047-54082Location: 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: 295 ft

BurstMax anticipated surface

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

8 Round LTC: 1.70 (J)Annular backup: 1.50 ppg Buttress: 1.60 (J)

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

Next setting depth: 8,006 ftTension is based on buoyed weight. Next mud weight: 10.000 ppgNeutral point: 875 ft Next setting BHP: 4,159 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) Factor1 431 1370 3.178 922 2950 3.20 21 244 11.61 J

Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: 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

NTIAL


Well name: 43047540820000 ULT 12-5-4-2EOperator: CRESCENT POINT ENERGY U.S. CORPString type: Production Project ID:




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

Burst:Design factor 1.00 Cement top: Surface


pressure: 2,398 psiInternal gradient: 0.220 psilft Tension: Non-directional string.Calculated BHP 4,159 psi 8 Round STC: 1.80 (J)

8 Round LTC: 1.80 (J)No backup mud specified. Buttress: 1.60 (J)

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

Tension is based on buoyed weight.Neutral point: 6,792 ft

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

(ft) (in) (Ibs/ft) (ft) (ft) (in) ($)1 8006 5.5 17.00 E-80 LT&C 8006 8006 4.767 264198


(psi) (psi) Factor (psi) (psi) Factor (kips) (kips) Factor1 4159 6290 1.512 4159 7740 1.86 115.5 320 2.77 J

Prepared Helen Sadik-Macdonald Phone: 801 538-5357 Date: January 23,2014by: Div of Oil,Gas & Mining FAX: 801-359-3940 Salt Lake City, Utah

Remarks:Collapse is based on a vertical depth of 8006 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 ULT 12-5-4-2EAPI Number 43047540820000 APD No 8 8 6 1 Field/Unit LELAND BENCHLocation: 1/4,1/4 NWSW Sec 5 T w 4.0S Rng 2.0E 2091 FSL 948 FWLGPS Coord (UTM) 602247 4446509 Surface Owner Golbert Maggs

ParticipantsTed Smith-DOGM, Bryan Foote, Mike Wock,Phillip Taufa-Cresent Point Energy, Don HamiltonStar Point Enterprises, Allen Smith-Landowner,Mark Hecksel-D.R.Griffin and Associates

Regional/Local Setting & TopographyThe general area is on Leland Bench, which is located about 8 miles southeast of Ft. Duchesne,Uintah County, Utah. Broad flats with low growing desert shrub type vegetation characterizeLeland Bench. A few rolling hills and slopes leading to higher flats occur. No springs, seeps orflowing streams are known to occur in the area. The Duchesne River is approximately 2 milesto the north. All lands in the immediate are privately owned. Ute Tribal lands lie to thenor theas t and southwest .

Access to the proposed well site is by State Of Utah and Uintah County roads and existing orproposed oilfield development roads. Distance from Roosevelt , Utah is approximately 18 miles.Approximately 0.14 miles of low standard new road will be constructed to reach the locationusing a culvert as needed at intersect with county road.

The proposed ULT 12-5-4-2E oil well is on a flat with a slight slope to the south. A rise orhigher level occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, Utah LandTrust owns the surface. Mr.Maggs was contacted by telephone and invited to attend thepre-site visit . He said he would not attend. Mr. Allen Smith is representing Mr. Maggs and hadno issues with this location. A surface use agreement has been completed. The locationappears to be a good site for constructing a pad, dril l ing and operating a well .

Surface Use PlanCurrent Surface UseGrazingWildlfe Habitat

New RoadMiles

Well Pad Src Const Material Surface Formation

0 .14 Width 320 Length 4 0 0 Onsi te ALLU

Ancillary Facilities N

Waste Management Plan Adequate? Y

Environmental ParametersAffected Floodplains and/or Wetlands N

Flora / Fauna


CONFIDE

NTIAL



Operator CRESCENT POINT ENERGY U.S. CORPWell Name ULT 12-5-4-2E

APINumber 43047540820000 APDNo 8861 Field/Unit LELANDBENCHLocation: 1/4,1/4 NWSW Sec 5 Tw 4.0S Rng 2.0E 2091 FSL 948 FWLGPS Coord (UTM) 602247 4446509 Surface Owner Golbert Maggs


Regional/Local Setting & TopographyThe general area is on Leland Bench, which is located about 8 miles southeast of Ft. Duchesne,Uintah County, Utah. Broad flats with low growing desert shrub type vegetation characterizeLeland Bench. A few rolling hills and slopes leading to higher flats occur. No springs, seeps orflowing streams are known to occur in the area. The Duchesne River is approximately 2 milesto the north. All lands in the immediate are privately owned. Ute Tribal lands lie to thenortheast and southwest.

Access to the proposed well site is by State Of Utah and Uintah County roads and existing orproposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18 miles.Approximately 0.14 miles of low standard new road will be constructed to reach the locationusing a culvert as needed at intersect with county road.

The proposed ULT 12-5-4-2E oil well is on a flat with a slight slope to the south. A rise orhigher level occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, Utah LandTrust owns the surface. Mr.Maggs was contacted by telephone and invited to attend thepre-site visit. He said he would not attend. Mr. Allen Smith is representing Mr. Maggs and hadno issues with this location. A surface use agreement has been completed. The locationappears to be a good site for constructing a pad, drilling and operating a well.


New Road Well Pad Src Const Material Surface FormationMiles0.14 Width 320 Length 400 Onsite ALLU




Flora / Fauna















Flora / Fauna















Flora / Fauna















Flora / Fauna



Vegetation is a fair desert shrub-forb type. Main plants are horse-brush, Gardnersal t-brush, broom snakeweed, bud sagebrush, black sagebrush, cheatgrass, curlymesquite grass, prickly pear, globe mallow, squirrel tail and annual forbs.

Because of the lack of water and cover the area is not rich in fauna. Antelope, coyotes,prair ie dogs and small mammals and rodents occur . Some shrub dependent birds mayoccur but were not observed. Historically but not currently sheep grazed the area. Cattlenow graze the area

Soil Type and CharacteristicsSoils are a deep sandy loam with little rock.

Erosion Issues N

Sedimentation Issues N

Site Stability Issues N

Drainage Diverson Required? N

Berm Required? N

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) > 2 0 0 0Distance 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 Unknown 1 0

Final Score 2 5 3 Sensitivity Level

Characteristics / RequirementsOne 140’ x 100’ x 12’ and one 100' x 60' x 12' deep reserve pits are planned in a cut on thesouthwest corner of the location. A liner with a minimum thickness of 16-mils isrequired. A sub-liner may not be needed because of the lack of rock in the area. Operatorsays they will lay a subliner. Flare pit will be constructed 15' x 30 ' x 5 '

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


CONFIDE

NTIAL


Vegetation is a fair desert shrub-forb type. Main plants are horse-brush, Gardnersalt-brush, broom snakeweed, bud sagebrush, black sagebrush, cheatgrass, curlymesquite grass, prickly pear, globe mallow, squirrel tail and annual forbs.

Because of the lack of water and cover the area is not rich in fauna. Antelope, coyotes,prairie dogs and small mammals and rodents occur. Some shrub dependent birds mayoccur but were not observed. Historically but not currently sheep grazed the area. Cattlenow graze the area


Erosion Issues N




Berm Required? N



Reserve Pit


Distance to Groundwater (feet) >200 0Distance 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 Unknown 10Final Score 2 5 3 Sensitivity Level

Characteristics / RequirementsOne 140' x 100' x 12' and one 100' x 60' x 12' deep reserve pits are planned in a cut on thesouthwest corner of the location. A liner with a minimum thickness of 16-mils isrequired. A sub-liner may not be needed because of the lack of rock in the area. Operatorsays they will lay a subliner. Flare pit will be constructed 15' x 30 ' x 5 '







Erosion Issues N




Berm Required? N



Reserve Pit














Erosion Issues N




Berm Required? N



Reserve Pit














Erosion Issues N




Berm Required? N



Reserve Pit











Other Observations / CommentsGilbert Maggs, Utah Land Trust owns the surface. Mr.Maggs was contacted by telephone andinvited to attend the pre-site visit . He said he would not attend. Mr. Alen Smith representedhim and had no issues with this location.

Ted Smith 1 1 / 1 4 / 2 0 1 3Evaluator Date / Time


CONFIDE

NTIAL


Other Observations / CommentsGilbert Maggs, Utah Land Trust owns the surface. Mr.Maggs was contacted by telephone andinvited to attend the pre-site visit. He said he would not attend. Mr. Alen Smith representedhim and had no issues with this location.

Ted Smith 11/14/2013Evaluator Date / Time















Application for Permit to DrillStatement of Basis

Utah Division of Oil, Gas and Mining

APD No API WellNo Status Well Type Surf Owner CBM8 8 6 1 43047540820000 LOCKED OW P N oOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Golbert MaggsWell Name ULT 12-5-4-2E UnitField LELAND BENCH Type of Work DRILL

Location NWSW 5 4S 2E U 2091 FSL 948 FWL GPS Coord(UTM) 602249E 4446516N

Geologic Statement of BasisCrescent Point proposes to set 1,000' of surface casing at this location. The base of themoderately saline water at this location is estimated to be at a depth of 1,400 feet. A searchof Division of Water Rights records shows 1 water well within a 10,000 foot radius of thecenter of Section 5. It produces from a depth of 500 feet and is used for irrigation, stockwatering and domestic use. The surface formation at this si te is the Uinta Formation. TheUinta Formation is made up of interbedded shales and sandstones. The sandstones aremostly lenticular and discontinuous and should not be a significant source of useableground water . Cement for the production str ing should be brought up above the base of themoderately saline groundwater in order to isolate fresher waters uphole.

Brad HillAPD Evaluator

1 2 / 1 8 / 2 0 1 3Date / Time

Surface Statement of BasisThe general area is on Leland Bench, which is located about 8 miles southeast of Ft.Duchesne, Uintah County, Utah. Broad flats with low growing desert shrub type vegetationcharacterize Leland Bench. A few rolling hills and slopes leading to higher flats occur. Nosprings, seeps or flowing streams are known to occur in the area. The Duchesne River isapproximately 2 miles to the north. All lands in the immediate are privately owned. UteTribal lands l ie to the northeast and southwest .

Access to the proposed well site is by State Of Utah and Uintah County roads and existingor proposed oilfield development roads. Distance from Roosevelt , Utah is approximately 18miles. Approximately 0.14 miles of low standard new road will be constructed to reach thelocation using one a culvert as needed at intersect with county road.

The proposed ULT 12-5-4-2E oil well is on a flatwith a slope to the south. A rise or higherlevel occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, UtahLand Trust owns the surface. Mr.Maggs was contacted by telephone and invited to attendthe pre-site visit . He said he would not attend. Mr. Allen Smith attended in his place. Asurface use agreement has been completed. The location appears to be a good si te forconstructing a pad, drill ing and operating a well.

Ted SmithOnsite Evaluator

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


CONFIDE

NTIAL


I


Utah Division of Oil, Gas and MiningI

APD No API WellNo Status Well Type Surf Owner CBM8861 43047540820000 LOCKED OW P NoOperator CRESCENT POINT ENERGY U.S. CORP Surface Owner-APD Golbert MaggsWell Name ULT 12-5-4-2E UnitField LELAND BENCH Type of Work DRILL

. NWSW 5 4S 2E U 2091 FSL 948 FWL GPS CoordLocation(UTM) 602249E 4446516N

Geologic Statement of BasisCrescent Point proposes to set 1,000' of surface casing at this location. The base of themoderately saline water at this location is estimated to be at a depth of 1,400 feet. A searchof Division of Water Rights records shows 1 water well within a 10,000 foot radius of thecenter of Section 5. It produces from a depth of 500 feet and is used for irrigation, stockwatering and domestic use. The surface formation at this site is the Uinta Formation. TheUinta Formation is made up of interbedded shales and sandstones. The sandstones aremostly lenticular and discontinuous and should not be a significant source of useableground water. Cement for the production string should be brought up above the base of themoderately saline groundwater in order to isolate fresher waters uphole.

Brad Hill 12/18/20 13APD Evaluator Date / Time

Surface Statement of BasisThe general area is on Leland Bench, which is located about 8 miles southeast of Ft.Duchesne, Uintah County, Utah. Broad flats with low growing desert shrub type vegetationcharacterize Leland Bench. A few rolling hills and slopes leading to higher flats occur. Nosprings, seeps or flowing streams are known to occur in the area. The Duchesne River isapproximately 2 miles to the north. All lands in the immediate are privately owned. UteTribal lands lie to the northeast and southwest.

Access to the proposed well site is by State Of Utah and Uintah County roads and existingor proposed oilfield development roads. Distance from Roosevelt, Utah is approximately 18miles. Approximately 0.14 miles of low standard new road will be constructed to reach thelocation using one a culvert as needed at intersect with county road.

The proposed ULT 12-5-4-2E oil well is on a flatwith a slope to the south. A rise or higherlevel occurs approximately 1 mile to the south. No swales or drainages occur in theimmediate area. Both the surface and minerals are privately owned. Gilbert Maggs, UtahLand Trust owns the surface. Mr.Maggs was contacted by telephone and invited to attendthe pre-site visit. He said he would not attend. Mr. Allen Smith attended in his place. Asurface use agreement has been completed. The location appears to be a good site forconstructing a pad, drilling and operating a well.

Ted Smith 11/14/20 13Onsite Evaluator Date / Time



I













I













I













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

the reserve pit .Pits The reserve pit should be located on the south side of the location.Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of dril l ing operations.


CONFIDE

NTIAL


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

the reserve pit.Pits The reserve pit should be located on the south side of the location.Surface The well site shall be bermed to prevent fluids from leaving the pad.Surface The reserve pit shall be fenced upon completion of drilling operations.















WORKSHEETAPPLICATION FOR PERMIT TO DRILL

APD RECEIVED: 10/25 /2013 API NO. ASSIGNED: 43047540820000

WELL NAME: ULT 12-5-4-2E

OPERATOR: CRESCENT POINT ENERGY U.S. CORP (N3935) PHONE NUMBER: 303 382-6787

CONTACT: Lauren MacMillan

PROPOSED LOCATION: NWSW 05 040S 020E Permit Tech Review:

SURFACE: 2091 FSL 0948 FWL Engineering Review:

BOTTOM: 2091 FSL 0948 FWL Geology Review:

COUNTY: UINTAH

LATITUDE: 40.16278 LONGITUDE: -109.79930

UTM SURF EASTINGS: 602249.00 NORTHINGS: 4446516.00

FIELD NAME: LELAND BENCH

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/FEE - 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) - hmacdonald 23 - Spacing - dmason 25 - Surface Casing - hmacdonald


CONFIDE

NTIAL



I

I

APD RECEIVED: 10/25/2013 API NO. ASSIGNED: 43047540820000




PROPOSED LOCATION: NWSWO5 040S 020E Permit Tech Review:



COUNTY: UINTAH



FIELD NAME: LELANDBENCH

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) - hmacdonald23 - Spacing - dmason25 - Surface Casing - hmacdonald




I

I








COUNTY: UINTAH




LEASE TYPE: 4 - Fee



I


PLAT R649-2-3.



Oil Shale 190-5








I






I

I








COUNTY: UINTAH




LEASE TYPE: 4 - Fee



I


PLAT R649-2-3.



Oil Shale 190-5








I






I

I








COUNTY: UINTAH




LEASE TYPE: 4 - Fee



I


PLAT R649-2-3.



Oil Shale 190-5








I




Permit To Drill******************Well Name: ULT 12-5-4-2E

API Well Number: 43047540820000Lease Number: FEESurface Owner: FEE (PRIVATE) Approval Date: 1 / 2 7 / 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

Well Name: ULT 12-5-4-2EAPI Well Number: 43047540820000

Lease Number: FEESurface Owner: FEE (PRIVATE)Approval Date: 1/27/20 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 surfaceas indicated in the submitted dril l ing plan.

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 surfaceas indicated in the submitted drilling plan.


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

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

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

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

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

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

program- contact Dustin Doucet

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

contact Dan Jarvis

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

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

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

801-231-8956 - after office hours

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

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

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












contact Dan Jarvis



















contact Dan Jarvis



















contact Dan Jarvis








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

Approved By:

For John RogersAssociate Director, Oil & Gas

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

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

plugging

Approved By:

For John RogersAssociate Director, Oil &



plugging

Approved By:




plugging

Approved By:




plugging

Approved By:


RECEIVED: Dec. 18, 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: ULT 12-5-4-2E

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

9. API NUMBER: 43047540820000

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

9. FIELD and POOL or WILDCAT: LELAND BENCH

4. LOCATION OF WELL FOOTAGES AT SURFACE: 2091 FSL 0948 FWL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: NWSW Section: 05 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:

1 /27 /2014

SUBSEQUENT REPORTDate of Work Completion:

SPUD REPORTDate of Spud:

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 U.S. Corp respectfully requests a one-yearextension of the state drilling permit for the ULT 12-5-4-2E.

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

TITLE Regulatory Technician

SIGNATURE N/A

DATE 12/18/2014

December 18, 2014

Sundry Number: 59145 API Well Number: 43047540820000Sundry Number: 59145 API Well Number: 43047540820000

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 ULT 12-5-4-2E

2. NAME OF OPERATOR: 9. API NUMBER:CRESCENT POINT ENERGY U.S. CORP 43047540820000

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

4. LOCATION OF WELL COUNTY:FOOTAGESAT SURFACE: UINTAH

2091 FSL 0948 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:

QtrlQtr: NWSW Section: 05 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 REPAIRNOTICE OF INTENT

Approximate date work will start: CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME

1/27/2014CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate 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:



Crescent Point Energy U.S. Corp respectfully requests a one-year Approved by theextension of the state drilling permit for the ULT 12-5-4-2E. GlaholinItietohSp12014

OFI, Gas and Mining

Date:

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

SIGNATURE DATEN/A 12/18/2014

RECEIVED: Dec. 18,

Sundry Number: 59145 API Well Number: 43047540820000

FORM 9STATE OF UTAH

























OFI, Gas and Mining

Date:



RECEIVED: Dec. 18,


FORM 9STATE OF UTAH

























OFI, Gas and Mining

Date:



RECEIVED: Dec. 18,

RECEIVED: Dec. 18, 2014

The Utah Division of Oil, Gas, and Mining

- State of Utah- Department of Natural Resources

Electronic Permitting System - Sundry Notices

Request for Permit Extension Validation Well Number 43047540820000

API: 43047540820000Well Name: ULT 12-5-4-2E

Location: 2091 FSL 0948 FWL QTR NWSW SEC 05 TWNP 040S RNG 020E MER UCompany Permit Issued to: CRESCENT POINT ENERGY U.S. CORP

Date Original Permit Issued: 1 /27 /2014

The undersigned as owner with legal rights to drill on the property as permitted above, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not require revision.Following is a checklist of some items related to the application, which should be verified.

If located on private land, has the ownership changed, if so, has the surface agreement been updated? Yes No

Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? Yes No

Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? Yes No

Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? Yes No

Has the approved source of water for drilling changed? Yes No

Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No

Is bonding still in place, which covers this proposed well? Yes No

Signature: Kristen Johnson Date: 12/18 /2014

Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP


UTAH

DNR The Utah Division of Oil, Gas, and Mining'


Electronic Permitting System - Sundry NoticesOTI. EMI Pr N1NTrie




Date Original Permit Issued: 1/27/2014


* If located on private land, has the ownership changed, if so, has the surface agreement been updated? OYes No

• Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? O Yes No

• Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? (_) Yes No

• Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? O Yes i No

· Has the approved source of water for drilling changed? O Yes No

• Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No

' Is bonding still in place, which covers this proposed well? Yes No

Signature: Kristen Johnson Date: 12/18/2014Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP

RECEIVED: Dec. 18,


UTAH

















RECEIVED: Dec. 18,


UTAH

















RECEIVED: Dec. 18,

RECEIVED: Jan. 04, 2016


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: ULT 12-5-4-2E

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

9. API NUMBER: 43047540820000

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

9. FIELD and POOL or WILDCAT: LELAND BENCH

4. LOCATION OF WELL FOOTAGES AT SURFACE: 2091 FSL 0948 FWL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: NWSW Section: 05 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


NOTICE OF INTENTApproximate date work will start:

1 /27 /2016

SUBSEQUENT REPORTDate of Work Completion:

SPUD REPORTDate of Spud:

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


PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION

REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION



Crescent Point Energy US Corp respectfully requests a one-yearextension of the state drilling permit for the referenced well.

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

TITLE Regulatory Technician

SIGNATURE N/A

DATE 1 /4 /2016

January 05, 2016


FORM 9STATE OF UTAH
























Crescent Point Energy US Corp respectfully requests a one-year Approved by theextension of the state drilling permit for the referenced well. UJIarkumyiBlia,n2OI16

OFI, Gas and Mining

Date:



RECEIVED: Jan. 04,


FORM 9STATE OF UTAH
























Crescent Point Energy US Corp respectfully requests a one-year Approved by theextension of the state drilling permit for the referenced well. UJIarkumyiBlia,n2OI16

OFI, Gas and Mining

Date:



RECEIVED: Jan. 04,

RECEIVED: Jan. 04, 2016

The Utah Division of Oil, Gas, and Mining


Electronic Permitting System - Sundry Notices




Date Original Permit Issued: 1 /27 /2014


If located on private land, has the ownership changed, if so, has the surface agreement been updated? Yes No

Have any wells been drilled in the vicinity of the proposed well which would affect the spacing or sitingrequirements for this location? Yes No

Has there been any unit or other agreements put in place that could affect the permitting or operation of thisproposed well? Yes No

Have there been any changes to the access route including ownership, or rightof- way, which could affect theproposed location? Yes No

Has the approved source of water for drilling changed? Yes No

Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation? Yes No

Is bonding still in place, which covers this proposed well? Yes No

Signature: Kristen Johnson Date: 1 /4 /2016

Title: Regulatory Technician Representing: CRESCENT POINT ENERGY U.S. CORP


UTAH

















RECEIVED: Jan. 04,


UTAH

















RECEIVED: Jan. 04,

State of UtahDEPARTMENT OF NATURAL RESOURCES

MICHAEL R. STYLER

GARY R.HERBERT Executive Director

Governor Division of Oil, Gas and MiningSPENCER J. COX JOHN R. BAZALieutenant Governor Division Director

February 7, 2017

Crescent Point Energy U.S. Corp.555 17th Street, Suite 750Denver, CO 80202

Re: APDs Rescinded for Crescent Point Enerav U.S. Corp, Uintah County

Ladies and Gentlemen:

Enclosed find the list of APDs that is being rescinded. No drilling activityat these locations has been reported to the division. Therefore, approval to drillthese wells is hereby rescinded as of February 7, 2017.

A new APD must be filed with this office for approval orior to thecommencement of any future work on the subject location.

If any previously unreported operations have been performed on this welllocation, it is imperative that you notify the Division immediately.

Sincerely,

D míaMasonEn ironmental Scientist

cc: Well FileBrad Hill, Technical Service Manager

UTAH

DNR1594 West North Temple, Suite 1210, Salt Lake City, UT 84116PO Box 145801, Salt Lake City, UT 84114-5801telephone (801) 538-5340 •facsimile (801) 359-3940•TTY (801) 538-7458 •www.ogm.utah.gov

OIL, GAS &

43-047-54088 Hicken 10-9-3-1E43-047-54089 Deep Creek 9-29-3-2E43-047-54093 Deep Creek 5-10-4-2E43-047-54094 Deep Creek 6-33-3-2E43-047-54097 Deep Creek 4-33-3-2E43-047-54098 Deep Creek Tribal 1-32-3-2E43-047-54142 Deep Creek 1-29-3-2E43-047-54082 ULT 12-5-4-2E43-047-54087 Deep Creek 5-33-3-2E43-047-54190 Deep Creek

api well number: 43047540820000 api well number · 2017. 2. 8. · api well number : 43047540820000...

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