1. ESTIMATED TOPS OF IMPORTANT GEOLOGIC MARKERS-p 24.0 j-55st&c s typef 81 1.15 15.8 prod r r m-1833 15.5 j-55st&c s typef u 2.04 12.5 typef 66 1.15 15.8 attachp verifyb d b attachedinaccordancewith

STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER

Wellington Fee 12-23

2. TYPE OF WORK

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

UNDESIGNATED

4. TYPE OF WELLGas Well Coalbed Methane Well: YES

5. UNIT or COMMUNITIZATION AGREEMENT NAME

6. NAME OF OPERATORKERR-MCGEE OIL & GAS ONSHORE, L.P.

7. OPERATOR PHONE720 929-6515

8. ADDRESS OF OPERATORP.O. Box 173779, Denver, CO, 80217

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')Lynda Varner

14. SURFACE OWNER PHONE (if box 12 = 'fee')435-630-1182

15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee')PO Box 866, ,

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 1680 FNL 1280 FWL SWNW 23 14.0 S 10.0 E S

Top of Uppermost Producing Zone 1680 FNL 1280 FWL SWNW 23 14.0 S 10.0 E S

At Total Depth 1680 FNL 1280 FWL SWNW 23 14.0 S 10.0 E S

21. COUNTYCARBON

22. DISTANCE TO NEAREST LEASE LINE (Feet)160

23. NUMBER OF ACRES IN DRILLING UNIT160

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

1800

26. PROPOSED DEPTHMD: 1833 TVD: 1833

27. ELEVATION - GROUND LEVEL

5608

28. BOND NUMBER

22013542

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

City of Price

Hole, Casing, and Cement Information

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

Cond 24 14 0 - 35 36.0 Unknown 8.6 Unknown 0 0.0 0.0

Surf 11 8.625 0 - 183 24.0 J-55 ST&C 8.6 Type III 81 1.15 15.8

Prod 7.875 5.5 0 - 1833 15.5 J-55 ST&C 8.6 Type III 238 2.04 12.5

Type III 66 1.15 15.8

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 Kathy Schneebeck-Dulnoan TITLE Staff Regulatory Analyst PHONE 720 929-6007

SIGNATURE DATE 01/16/2011 EMAIL [email protected]

API NUMBER ASSIGNED 43007501100000 APPROVAL

FORM 3

AMENDED REPORT

API Well No: 43007501100000 Received: 1/16/2011

Returned Unapproved

API Well No: 43007501100000 Received: 1/16/2011

FORM 3STATE OF UTAH

DEPARTMENT OF NATURAL RESOURCES AMENDED REPORTDIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME anWeNI nMBEnRFee12-23

2. TYPE OF WORK 3. FIELD OR WILDCATDRILL NEW WELLI REENTER P&A WELL DEEPEN WELL I UNDESIGNATED

4. TYPE OF WELL 5. UNIT or COMMUNITIZATION AGREEMENT NAMEGas Well Coalbed Methane Well: YES

6. NAME OF OPERATOR 7. OPERATOR PHONEKERR-MCGEE OIL & GAS ONSHORE, L.P. 720 929-6515

8. ADDRESS OF OPERATOR 9. OPERATOR E-MAILP.O. Box 173779, Denver, CO, 80217 [email protected]

10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL,INDIAN,ORSTATeE)

FEDERAL I INDIAN I STATE FEE FEDERAL INDIAN STATEI FEEl

13. NAME OF SURFACE OWNER (if box 12 = 'fee') 14. SURFACE OWNER PHONE (if box 12 = 'fee')Lynda Varner 435-630-1182

15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee') 16. SURFACE OWNER E-MAIL (if box 12 = 'fee')PO Box 866, ,

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 I

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

LOCATION AT SURFACE 1680 FNL 1280 FWL SWNW 23 14.0 S 10.0 E S

Top of Uppermost Producing Zone 1680 FNL 1280 FWL SWNW 23 14.0 S 10.0 E S

At Total Depth 1680 FNL 1280 FWL SWNW 23 14.0 S 10.0 E S

21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITCARBON 160 160

25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 1833 TVD: 1833

1800

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

5608 22013542 City of Price

Hole, Casing, and Cement Information

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

Cond 24 14 0 - 35 36.0 Unknown 8.6 Unknown 0 0.0 0.0

Surf 11 8.625 0 - 183 24.0 J-55 ST&C 8.6 Type III 81 1.15 15.8

Prod 7.875 5.5 0 - 1833 15.5 J-55 ST&C 8.6 Type III 238 2.04 12.5

Type III 66 1.15 15.8

ATTACH MENTS

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 TOPOGRAPHICAL MAPDRILLED)

NAME Kathy Schneebeck-Dulnoan TITLE Staff Regulatory Analyst PHONE 720 929-6007

SIGNATURE DATE 01/16/2011 EMAIL [email protected]

API NUMBER ASSIGNED 43007501100000

OPERATOR: Kerr-McGee Oil & Gas Onshore LP1099 18th. St., #1200Denver, Colorado 80202Phone: 720.929.6000

Federal Surface No. Well Name Well No. Qtr/Qtr Sec. Twn Rng Lease No. Ownership

1 Wellington Fee 12-23 SW/NW 23 14S 10E NA Lynda Varner2 Wellington Fee 13-25 NW/SW 25 14S 10E NA Verdis Barker3 Wellington Fee 21-26 NE/NW 26 14S 10E NA Circle K Ranch4 Wellington Fee 23-23 NE/SW 23 14S 10E NA Lynda Varner5 Wellington Fee 34-25 SW/SE 25 14S 10E NA BLM / Shimmons6 Wellington Fee 41-26 NE/NE 26 14S 10E NA Verdis Barker

Cardinal Draw 2011 Plan of DevelopmentWELL LIST AND LEASE REFERENCE

Included are the Master MSU, Master Drilling Prognosis, Master Geological Prognosis, and Project Maps.

The Archeological Survey has been/will be submitted by the Archeology contractor under a separate cover.

12/21/2010

Returned Unapproved

Cardinal Draw 2011 Plan of DevelopmentWELLLISTAND LEASEREFERENCE

OPERATOR: Kerr-McGee Oil & Gas Onshore LP1099 18th. St., #1200Denver, Colorado 80202Phone: 720.929.600C

Federal SurfaceNo. Well Name Well No. Otr/Otr Sec. Twn _Rng Lease No. Ownership

1 Wellington Fee 12-23 SW/N½ 23 14S 10E NA Lynda Varner2 Wellington Fee 13-25 NW/S½ 25 14S 10E NA Verdis Barker3 Wellington Fee 21-26 NE/NW 26 14S 10E NA Circle K Ranch4 Wellington Fee 23-23 NE/SW 23 14S 10E NA Lynda Varner5 Wellington Fee 34-25 SW/SE 25 14S 10E NA BLM/ Shimmons6 Wellinqton Fee 41-26 NE/NE 26 14S 10E NA Verdis Barker

Included are the Master MSU, Master Drilling Prognosis, Master Geological Prognosis, and Project Maps.

The Archeological Survey has been/will be submitted by the Archeology contractor under a separate cover.

1. ESTIMATED TOPS OF IMPORTANT GEOLOGIC MARKERS

GROUNDPROPOSED WELL ELEV TOP KB BASE KB TD KB COALWellington Fee 12-23 5608 1033 1533 1833 FerronWellington Fee 13-25 5523 713 1213 1513 FerronWellington Fee 21-26 5537 797 1297 1597 FerronWellington Fee 23-23 5604 974 1474 1774 FerronWellington Fee 34-25 5647 822 1322 1622 FerronWellington Fee 41-26 5603 853 1353 1653 Ferron

2. ESTIMATED DEPTH OF ANTICIPATED WATER, OIL, GAS OR MINERAL FORMATIONS

Primary Objective: Ferron Methane Gas

Several coal seams may be tested for gas producing formations to total depth. All shallow water zones will be protected with casing and cement. Cement will be brought to surface to isolate formations.

The casing and cementing programs shall be conducted as approved to protect and/or isolate all usable water zones and any prospectively valuable deposits of minerals. All indications of usable water shall be reported to the authorized officer prior to running the next string of casing or before plugging orders are requested, whichever occurs first.

3. MINIMUM BOP REQUIREMENTS: (Refer to attached schematics)

a) The BOPE shall be closed whenever the well is unattended.b) The BOPE shall be pressure tested when initially installed, whenever any seal subject to pressure testing

is broken, after repairs, or every 30 days.c) Kerr-McGee shall notify the UDOGM-Price office 24 hours prior to the BOPE test.d) All BOPE shall meet or exceed the requirements of a2M system as set forth in Onshore Order No. 2.e) An accumulator unit will be used that has sufficient capacity to open the hydraulically-controlled choke

line valve (if so equipped), close all rams plus the annular preventer and retain 200 psi above precharge onthe closing manifold without the use of the closing pumps. The accumulator unit will be located at the master accumulator and on the rig floor.

f) Annular type preventers shall be tested to 50 percent of rated working pressure. Pressure shall be maintained at least 10 minutes or until provisions of test are met, whichever is longer.

g) Accessories to BOP's include upper and lower Kelly cock valves with handles and floor safety valve, drill string BOP.

4. SUPPLEMENTARY INFORMATION:

The primary objective of this project is to drill, stimulate and produce coalbed methane gas from the coal seams of the Mesa Verde Group Formations.

Kerr-McGee proposes to test the coal formations.Stimulation of the perforated coal seams will be done by hydraulic fracturing. Fresh water, gelled water, and/or foam fracturing techniques will be used.

5. CASING PROGRAM:

Hole Size

Casing Size

Weight Grade Joint Depth Set New/Used Collapse Burst

17 1/2" 13 3/8" 48 H-40 ST&C 0-35' New 740 1730

11" 8 5/8" 24 J-55 ST&C 0-151 to 183’ New 1370 2950

7 7/8" 5 1/2" 15.5 J-55 ST&C 0-TD New 4040 4810

Cardinal Draw 2011 Plan of DevelopmentCarbon County, Wyoming

OPERATOR: Kerr-McGee Oil & Gas Onshore LP

MASTER DRILLING PROGNOSIS PRODUCTION WELLS

1/16/2011

Returned Unapproved

Cardinal Draw 2011 Plan of DevelopmentCarbon County, Wyoming


MASTERDRILLINGPROGNOSIS PRODUCTION WELLS

1. ESTIMATEDTOPS OF IMPORTANT GEOLOGIC MARKERS

GROUNDPROPOSED WELL ELEV TOP KB BASE KB TD KB COALWellinqton Fee 12-23 5608 1033 1533 1833 FerronWellington Fee 13-25 5523 713 1213 1513 FerronWellinqton Fee 21-26 5537 797 1297 1597 FerronWellington Fee 23-23 5604 974 1474 1774 FerronWellinqton Fee 34-25 5647 822 1322 1622 FerronWellington Fee 41-26 5603 853 1353 1653 Ferron

2. ESTIMATED DEPTH OF ANTICIPATED WATER, OIL, GAS OR MINERAL FORMATIONS

Primary Objective: Ferron Methane Gas

Several coal seams may be tested for gas producing formations to total depth. All shallow water zones willbe protected with casing and cement. Cement will be brought to surface to isolate formations.

The casing and cementing programs shall be conducted as approved to protect and/or isolate all usablewater zones and any prospectively valuable deposits of minerals. All indications of usable water shallbe reported to the authorized officer prior to running the next string of casing or before plugging ordersare requested, whichever occurs first.

3. MINIMUM BOP REQUIREMENTS: (Refer to attached schematics)

a) The BOPE shall be closed whenever the well is unattended.b) The BOPE shall be pressure tested when initially installed, whenever any seal subject to pressure testing

is broken, after repairs, or every 30 days.c) Kerr-McGee shall notify the UDOGM-Price office 24 hours prior to the BOPE test.d) All BOPE shall meet or exceed the requirements of a2M system as set forth in Onshore Order No. 2e) An accumulator unit will be used that has sufficient capacity to open the hydraulically-controlled choke

line valve (if so equipped), close all rams plus the annular preventer and retain 200 psi above precharge onthe closing manifold without the use of the closing pumps. The accumulator unit will be located at themaster accumulator and on the rig floor.

f) Annular type preventers shall be tested to 50 percent of rated working pressure. Pressure shall bemaintained at least 10 minutes or until provisions of test are met, whichever is longer.

g) Accessories to BOP's include upper and lower Kelly cock valves with handles and floor safety valve,drill string BOP.

4. SUPPLEMENTARY INFORMATION:

The primary objective of this project is to drill, stimulate and produce coalbed methane gas from thecoal seams of the Mesa Verde Group Formations.

Kerr-McGee proposes to test the coal formations.Stimulation of the perforated coal seams will be done by hydraulic fracturing. Fresh water, gelled water,and/or foam fracturing techniques will be used.

5. CASING PROGRAM:

Hole Casing Weight Grade Joint Depth Set New/Used Collapse BurstSize Size

17 1/2" 13 3/8" 48 H-40 ST&C 0-35' New 740 1730

0-151 to11" 8 5/8" 24 J-55 ST&C New 1370 2950

183'

7 7/8" 5 1/2" 15.5 J-55 ST&C 0-TD New 4040 4810

Surface Casing:

a) Burst = 0.052 * MW * TVD(shoe) = 0.052 * 10.0 ppg * 375’ = 195 psi Safety Factor = Rating/Burst

= 2950/195= 15.1

b) Collapse = [0.052 * MW * TVD(shoe)] - [Gas Gradient * TVD] = [.052 * 10.0 ppg *375’] - [0.1 * 375’]

= 158 psi Safety Factor = Rating/Collapse

= 1370/158= 8.7

c) Tension = Weight * TVD * [1 – (MW/65.5ppg)]= 24 * 375’ * [1 - 10.0/65.5]= 7,626 lbs.

Safety Factor = Rating/Tension= 244,000/7,626= 32

Surface casing shall have centralizers on the bottom 3 joints of the casing, starting with the shoe joint (minimum of 4centralizers.)Production Casing:

a) Burst = 0.052 * 13 ppg * 3345'= 2261 psi

Safety Factor = Rating/Burst= 4810/2261= 2.1

b) Collapse = [0.052 * 13 ppg * 3345' – [0.1 psi/ft * 3345’]]= 1927 psi

Safety Factor = Rating/Collapse= 2950/1927= 1.5

c) Tension Weight = 15.5 lbs/ft * 3345’* [1-(13 ppg/65.5 ppg)]= 41,557 lbs

Safety Factor = Rating/Tension= 202,000/41,557= 4.9

6. MUD PROGRAM:

Kerr-McGee intends to drill the surface casing setting depth using air. Therefore, Kerr-McGee requests a variance from Onshore Order 2 in regards to the 100 foot blooie line. Whendrilling the surface hole no gas will be encountered and a BOP system will not be used. The lengthof the blooie line will be sufficient to reach the middle of the reserve pit. Since no gas will be encountered we will not have an ignition device. In the event that gas is encountered, then a continuous ignition system will be installed and utilized on remaining and subsequent wells drilled.

Air flow line is 6" Schedule 80 pipe that runs 90 degrees from the well bore to the reserve pit. The last7' of flow line is 14" pipe with three, 45 degree, 8" Schedule 80 pipe to disperse cuttings to reserve pit.Dust supression system is used by water injection to flow line. There is no gas ignition in place.

Location and capacity of equipment is located on site map provided and made an attachment to this plan.Kerr-McGee will use whip checks on all compressor equipment and hoses. There are several fire extinguishersplaced on all equipment as well as up to date safety training and paper work.

1/16/2011

Returned Unapproved

Surface Casing:

a) Burst = 0.052 * MW * TVD(shoe)= 0.052 * 10.0 ppg * 375'= 195 psi


b) Collapse = [0.052* MW * TVD(shoe)] - [Gas Gradient * TVD]= [.052* 10.0 ppg *375'] - [0.1* 375']= 158 psi


c) Tension = Weight * TVD * [1 - (MW/65.5ppg)]= 24 * 375' * [1 - 10.0/65.5]= 7,626 lbs.

Safety Factor = Rating/Tension= 244,000/7,626= 32

Surface casing shall have centralizers on the bottom 3 joints of the casing, starting with the shoe joini (minimum of 4centralizers.)Production Casing:

a) Burst = 0.052 * 13 ppg * 3345'= 2261 psi


b) Collapse = [0.052* 13 ppg * 3345' - [0.1psi/ft * 3345']]= 1927 psi


c) Tension Weight = 15.5 lbs/ft * 3345'* [l-(13 ppg/65.5 ppg)]= 41,557 lbs

Safety Factor = Rating/Tension= 202,000/41,557= 4.9

6. MUD PROGRAM:

Kerr-McGee intends to drill the surface casing setting depth using air. Therefore,Kerr-McGee requests a variance from Onshore Order 2 in regards to the 100 foot blooie line. Whendrilling the surface hole no gas will be encountered and a BOP system will not be used. The lengthof the blooie line will be sufficient to reach the middle of the reserve pit. Since no gas will beencountered we will not have an ignition device. In the event that gas is encountered, then a continuousignition system will be installed and utilized on remaining and subsequent wells drilled.

Air flow line is 6" Schedule 80 pipe that runs 90 degrees from the well bore to the reserve pit. The last7' of flow line is 14" pipe with three, 45 degree, 8" Schedule 80 pipe to disperse cuttings to reserve pit.Dust supression system is used by water injection to flow line. There is no gas ignition in place.

Location and capacity of equipment is located on site map provided and made an attachment to this plan.Kerr-McGee will use whip checks on all compressor equipment and hoses. There are several fire extinguishersplaced on all equipment as well as up to date safety training and paper work.

1/l

While drilling with air, Kerr-McGee will maintain sufficient mud and weight materials to kill the water flow or containgas production if necessary. These materials will not be pre-mixed, but the ability to mix and pump will be onlocation.

Should water be used to drill through the surface casing setting depth, only fresh water will be used from the source listed in the MSUP.

Drilling of through production casing setting depth will be done with drilling mud as the circulation medium. A fresh water, polymer, gel drilling mud will be used and visual monitoring will be done upon mudding up to total depth. The anticipated mud weight will be between 8.5 - 13 ppg. Sufficient quantities of lostcirculation material and barite will be available at the well site at all times for the purpose of assuring well control.

A mud test shall be performed at least once every 24 hours after mudding up to determine, as applicable: density, viscosity, gel strength, filtration, and pH.

7. CEMENTING PROGRAM:

The following is the proposed procedure for cementing the 8 5/8” surface pipe and 5 1/2” long string:

8 5/8” Surface Casing:

Lead: Type III Cement with 0.25#/sk celloflake and 2% CaCl2, mixed at 15.8 ppg, 1.15 cuft/sk yield with 100% excess.

The surface casing shall be cemented back to surface. In the event cement does not circulate to surface or fall back of the cement column occurs, remedial cementing shall be done to cement the casing back to surface.

5 1/2” Production Casing:

Lead: Type III Cement with 2% CaCl2, 0.2% CFR, 0.3% CFL-3 and .5#/sk cello-flake, mixed at 12.5 ppg, 2.04 cuft/sk yield.

Tail: Type III with 2% CaCl2, 0.2% CFR, 0.3% CFL-3 and .5#/sk cello-flake, mixed at 15.8 ppg, 1.15 cuft/sk yield.

Volumes calculated to circulate cement from TD to surface.

8. LOGGING PROGRAM

Well completion and stimulation procedures will be determined following the evaluation of the drilling results and open hole logs. A Sundry Notice will be submitted for approval outlining the planned completion procedure at that time.

Cores: None

DSTs: None

Logs: From ToGR TD SurfaceResistivity TD Surface CasingNeutron-Density-Cal TD Surface CasingHigh Res Pass TBD TBD

9. PRESSURE DATA, POTENTIAL HAZARDS

Bottom hole pressures anticipated at 800-1000 psiThere is no history of hydrogen sulfide gas in the area and none is anticipated.

10. ANTICIPATED STARTING DATES AND NOTIFICATION OF OPERATIONS:

a) Anticipated Days:Drilling Days: Approximately 4 Days/WellCompletion Days: Approximately 2 Days/WellTesting Days: Approximately 7-14 Days/Well

1/16/2011

Returned Unapproved

While drilling with air, Kerr-McGee will maintain sufficient mud and weight materials to kill the water flow or containgas production if necessary. These materials will not be pre-mixed, but the ability to mix and pump will be onlocation.

Should water be used to drill through the surface casing setting depth, only fresh water will be used from thesource listed in the MSUP.

Drilling of through production casing setting depth will be done with drilling mud as the circulation medium.A fresh water, polymer, gel drilling mud will be used and visual monitoring will be done upon mudding upto total depth. The anticipated mud weight will be between 8.5 - 13 ppg. Sufficient quantities of lostcirculation material and barite will be available at the well site at all times for the purpose of assuring well control.

A mud test shall be performed at least once every 24 hours after mudding up to determine, as applicable:density, viscosity, gel strength, filtration, and pH.

7. CEMENTING PROGRAM:

The following is the proposed procedure for cementing the 8 5/8" surface pipe and 5 1/2" long string:

8 5/8" Surface Casing:

Lead: Type III Cement with 0.25#/sk celloflake and 2% CaCl2, mixed at 15.8 ppg, 1.15 cuft/sk yield with 100% excess.

The surface casing shall be cemented back to surface. In the event cement does not circulate to surface orfall back of the cement column occurs, remedial cementing shall be done to cement the casing back to surface.

5 1/2" Production Casing:

Lead: Type III Cement with 2% CaCl2, 0.2% CFR, 0.3% CFL-3 and .5#/sk cello-flake, mixed at12.5 ppg, 2.04 cuft/sk yield.

Tail: Type III with 2% CaCl2, 0.2% CFR, 0.3% CFL-3 and .5#/sk cello-flake, mixed at 15.8ppg, 1.15 cuft/sk yield.

Volumes calculated to circulate cement from TD to surface.

8. LOGGING PROGRAM

Well completion and stimulation procedures will be determined following the evaluation of the drillingresults and open hole logs. A Sundry Notice will be submitted for approval outlining the planned completionprocedure at that time.

Cores: None

DSTs: None

Logs: From ToGR TD SurfaceResistivity TD SurfaceCasingNeutron-Density-Cal TD SurfaceCasingHigh Res Pass TBD TBD

9. PRESSURE DATA, POTENTIAL HAZARDS

Bottom hole pressures anticipated at 800-1000 psiThere is no history of hydrogen sulfide gas in the area and none is anticipated.

10. ANTICIPATED STARTING DATES AND NOTIFICATION OF OPERATIONS:

a) Anticipated Days:Drilling Days: Approximately 4 Days/WellCompletion Days: Approximately 2 Days/WellTesting Days: Approximately 7-14 Days/Well

b) Notification of Operations:Main Address:

Bureau of Land ManagementPrice Field Office125 South 600 WestPrice, UT 84501Main: 435-636-3600Fax: 435-636-3657

Main Address: Mailing Address:Utah Division of Oil, Gas, and Mining Utah Division of Oil, Gas, and Mining1594 West North Temple, Suite 1210 PO Box 145801Salt Lake City, UT 84116 Salt Lake City, UT 84114-5801Main: 801-538-5340Fax: 801-359-3940

1/16/2011

Returned Unapproved

b) Notification of Operations:Main Address:

Bureau of Land ManagementPrice Field Office125 South 600 WestPrice, UT 84501Main: 435-636-3600Fax: 435-636-3657

Main Address: Mailing Address:Utah Division of Oil, Gas, and Mining Utah Division of Oil, Gas, and Mining1594 West North Temple, Suite 1210 PO Box 145801Salt Lake City, UT 84116 Salt Lake City, UT 84114-5801Main: 801-538-5340

Fax: 801-359-3940

PROPOSED SETTING Cement SETTING Ferron Top of Top of Production Production. WELL DEPTH-KB (Sacks) DEPTH-KB Depth Cement Tail Lead Tail

1 Wellington Fee 12-23 183' 81 1,833' 1,533' 1,133' 1,433' 238 662 Wellington Fee 13-25 151' 67 1,513' 1,213' 813' 1,113' 184 663 Wellington Fee 21-26 160' 71 1,597' 1,297' 897' 1,197' 198 664 Wellington Fee 23-23 177' 78 1,774' 1,474' 1,074' 1,374' 228 665 Wellington Fee 34-25 162' 72 1,622' 1,322' 922' 1,222' 203 666 Wellington Fee 41-26 165' 73 1,653' 1,353' 953' 1,253' 208 66

8-5/8", 24# CASING 5-1/2", 15.5# CASING Cement (sacks)

Helper Plan of DevelopmentCarbon County, Utah


1/16/2011

Returned Unapproved

Helper Plan of DevelopmentCarbon County, Utah


8-5/8", 24# CASING 5-1/2", 15.5# CASING Cement (sacks)PROPOSED SETTING Cement SETTING Ferron Top of Top of Production ProductionWEL_L DEPTH-KB (Sacks) DEPTH-KB Depth Cement Tail Lead Tail

1 Wellinqton Fee 12-23 183' 81 1,833' 1,533' 1,133' 1,433' 238 662 Wellington Fee 13-25 151' 67 1,513' 1,213' 813' 1,113' 184 663 Wellinqton Fee 21-26 160' 71 1,597' 1,29T 89T 1,197' 198 664 Wellington Fee 23-23 17T 78 1,774' 1,474' 1,074' 1,374' 228 665 Wellinqton Fee 34-25 162' 72 1,622' 1,322' 922' 1,222' 203 666 Wellinqton Fee 41-26 165' 73 1,653' 1,353' 953' 1,253' 208 66

3K POSITIVE BEAN CHOKE

2 1/

16 -

30

00

FROM DRILLING SPOOL

2 1/16 - 3000

3K ADJUSTABLE CHOKE

2 1/16 - 3000

TO RESERVE PIT

2 1/

16 -

30

00

2 1/16 - 3000

TO RESERVE PIT

TO RESERVE PIT

9" - 3000 SPHERICAL B.O.P.

STRIPPING HEAD

9" - 3000 DRILLING

SPOOL

TO RESERVE PIT

2 1/

16 -

30

00

2 1/

16 -

30

00

TO CHOKE MANIFOLDTO MUD PUMP 9" - 3000

DRILLING SPOOL

3000 PSI

CARDINAL DRAW 9" - 3000 BOP

Returned Unapproved

CARDINAL DRAW9" - 3000 BOP

,TO RESERVE PIT

STRIPPINGHEAD

9" - 3000SPHERICAL B.O.P.

I I

TOMUIL

NOG

3K POSITIVE BEANERVE PIT

FRO

21/16-SERVE PIT

3000 PSI

2 1/16 -3000

TO RESERVE PIT

3K ADJUSTABLE

23

NO

RTH

80.

00ch

(R)

T14S, R10E

40.776ch (R)

NO

RTH

80.

00ch

(R)

40.3

53ch

(R)

N 0

0°09

.9' W

80.

693c

h (R

)

20.1

70ch

(R)

20.1

70ch

(R)

20.361ch (R) 20.361ch (R)

S 89°27'39" W 2692.92' (M)

WEST 80.52ch (R)

40.802ch (R)

S 89°51.4' W 81.524ch (R)

40.3

24ch

(R)

WEST 80.50ch (R)

N 0

°04.

5' W

N 89°57.7' W

HORIZONTAL

10000 2000

SCALE: 1" = 1000'

SHEET NO:

1

WELL PAD - WELLINGTON FEE 12-23

DATE DRAFTED:

DRAFTED BY: CHECKED BY:

DATE SURVEYED:

BJRSEA

REVISED:

8/22/10 7/2010

FILE NAME: 10-33

CONSULTING, LLC2155 North Main Street

Sheridan Wyoming 82801Phone 307-674-0609

Fax 307-674-0182

OF 131

NOTES:

1. INDICATES FOUND BLM BRASS CAP

2. INDICATES CALCULATED CORNER

POSITION FROM RECORD

3. ELEVATION BASED ON NAVD88 (GEOID09)

4. BASIS OF BEARING DERIVED FROM NAD83

5. ALL MEASURED DISTANCES ARE GRID.

COMBINED SCALE FACTOR: .99963522

6. 1 CHAIN = 66 FEET

NAD 83STPC (UTC)

N: 7,022,514'E: 1,845,081'

Lat: 39° 35' 46.700"N(39.596306°N)

Lon: 110° 46' 25.194"W(110.773665°W)

NAD 27STPC (UTC)N: 460,853'

E: 2,204,871'Lat: 39° 35' 46.826"N

(39.596340°N)Lon: 110° 46' 22.625"W

(110.772951°W)

STATE OF UTAHREGISTRATION No. 7263818

CERTIFICATE OF SURVEYOR:

THIS IS TO CERTIFY THAT THE ABOVE PLAT WAS PREPAREDFROM FIELD NOTES OF ACTUAL SURVEYS MADE BY ME ORUNDER MY SUPERVISION AND THAT THE SAME ARE TRUEAND CORRECT TO THE BEST OFMY KNOWLEDGE AND BELIEF.

REGISTERED LAND SURVEYOR

UNGRADED ELEV =5608'

WELLINGTONFEE 12-23

WELLINGTON FEE 12-23WELL PLAT

1680' FNL & 1280' FWLSW1/4 NW1/4, SECTION 23, T14S, R10E,

S.L.M., CARBON COUNTY, UTAH

KERR-MCGEE OIL & GASONSHORE L.P.

1099 18th StreetDenver, CO 80202

an

1680

'

1280'

12/14/10

WELL LEGALWINDOW

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14/2

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8:55

:12

AM

Returned Unapproved

T14S, R10EWEST 80.50ch (R)

S 89°27'39" W 2692.92· (M)

N 89°57.7' W40.776ch (R)

WELL LEGAL

I WINDOW

WELLINGTONFEE 12-23UNGRADED ELEV =5608'

S 89°51.4 W 81.524ch (R) 2340.802ch (R) 20.361ch (R) 20.361ch (R)NAD83

STPC (UTC)N: 7,022,514'E: 1,845,081'

Lat: 39° 35' 46.700"N(39.596306°N)

Lon: 110° 46' 25.194"W(110.773665°W)

NAD 27STPC (UTC)N: 460,853'

E: 2,204,871'Lat: 39° 35' 46.826"N

(39.596340°N)

i Lon: 110° 46' 22.625"W(110.772951°W)

WEST 80.52ch (R)

I CERTIFICATEOF SURVEYOR:NOTES•

THIS IS TO CERTIFYTHAT THE ABOVE PLo FROM FIELD NOTES OF ACTUAL SURV R 1. A INDICATES FOUND BLM BRASSCAP

UNDERMYSUPERVISIONANDTHA .ARI IllÛË ••.

AND CORRECT TO THE BESTOF .• •. 2. INDICATES CALCULATED CORNERMY KNOWLEDGE AND BELIEF f . BENJAMINJAY N POSITION FROM RECORD

REENDERS : 3. ELEVATION BASED ON NAVD88 (GEOID09)

PROFESSIONAL.- g 4. BASIS OF BEARING DERIVED FROM NAD83

0 1000 20005. ALL MEASURED DISTANCES AREGRID.

ERRETOLNANNDSURV OR •.

6.

COMBINNED56CA FACTOR: .99963522

STATEOF UTAHSCHA

:

00L0'

WELL PAD - WELLINGTON FEE 12-23 KERR-MCGEE OIL & GAS CONSULTING, LLCONSHORE L.P. 609 2155NorthMainStreet

WELLINGTON FEE 12-23 an SheridanWyoming 82801Phone 307-674-0609

WELL PLAT Fax 307-674-0182

1680' FNL & 1280' FWLSW1/4 NW1/4, SECTION 23, T14S, R10E, Petroleum Corporation DRAFTED BY: SEA CHECKED BY: BjR SIIEETNO:

S.L.M., CARBON COUNTY, UTAH 1099 18th Street DATE DRAFTED: 8/22/10 DATE SURVEYED: 7/2010

Denver, CO 80202 REVISED: 12/14/10 FILENAME: 10-33 1 OF

10' WIDE BENCH

C7.3A C9.7

B

C9.4C

4

32

1

9

8

6

5

C6.8

F1.5C3.1

F3.0

C5.4

C9.8

C10.1

C6.1

WELL LOCATIONEXISTING CONTOURS (2' INTERVAL)PROPOSED CONTOURS (2' INTERVAL)

WELL PAD LEGEND

CONSULTING, LLC

Sheridan, WY 82801Phone 307-674-0609

2155 North Main Street

Fax 307-674-0182

1099 18th Street - Denver, Colorado 80202


10C3.7

11C0.3

12F4.9

WC1.9

C6.8D

TOPSOILSTOCKPILE

WELLINGTON FEE 12-23WELL PAD - LOCATION LAYOUT

1680' FNL, 1280' FWLSW1/4 NW1/4, SECTION 23, T14S, R10E,


B

B'

RESERVE PIT

50' X 50'

SLOPE 1.5:1

(10' DEPTH)

RESERVE PIT AND

EXCESS CUT SPOIL PILE

WELLINGTON FEE 12-23 DESIGN SUMMARY

FINISHED GRADE ELEVATION = 5606.5'CUT SLOPES = 1.5:1FILL SLOPES = 1.5:1

TOTAL CUT FOR WELL PAD = 4,240 C.Y.TOTAL FILL FOR WELL PAD = 1,451 C.Y.TOPSOIL @ 6" DEPTH = 941 C.Y.

TOTAL DISTURBANCE = 1.17 ACRESSHRINKAGE FACTOR = 1.15SWELL FACTOR = 1.00

TOTAL PIT CAPACITY WITH 2' OF FREEBOARD+/- 1,540 BARRELSTOTAL PIT VOLUME+/- 480 CY

EXISTING GRADE @ LOC. STAKE = 5608.4'

EXCESS MATERIAL = 2,789 C.Y.

WELL PAD QUANTITIES

RESERVE PIT QUANTITIES

CUT

FILL

Scale: Date: SHEET NO:HORIZONTAL300 60

1" = 60'

22' CONTOURS

9/28/101"=60'

2 OF 13

55'

85'

90'

35'

75'

100'

125'

90'

100'

75'

35'

PROPOSEDACCESS ROAD

7C10.1

REVISED:SEA

12/14/10

K:\

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12/

14/2

010

4:10

:18

PM

Returned Unapproved

A WELL PAD LEGEND

WELL LOCATIONEXISTING CONTOURS (2· INTERVAL)PROPOSED CONTOURS (2· INTERVAL)

300, C3. WELLINGTON FEE 12-23 DESIGN SUMMARY\pt EXISTING GRADE @ LOC. STAKE = 5608.4'

A C9.7' FINISHED GRADE ELEVATION = 5606.5'

C6.1 C7.3 9\ 7 \ CUT SLOPES = 1.5:1

50 C10. \ FILL SLOPES= 1.5:1TOTAL DISTURBANCE = 1.17 ACRES

500 SHRINKAGE FACTOR = 1.1510' C9.4 SWELL FACTOR = 1.00

C6.8 C9.8 WELL PAD QUANTITIES

1C1.9 \ TOTAL CUT FOR WELL PAD = 4,240 C.Y.

F3.0 \ TOTAL FILL FOR WELL PAD = 1,451 C.Y.

C5.4 L LE EXOCESMAT

RDAEL 2,789941C.

RESERVEPIT QUANTITIES

TOTAL PIT CAPACITY WITH 2· OF FREEBOARD+/-1,540 BARRELSTOTAL PIT VOLUME

\ +/- 480 CY

C3.7

75PROPOSED

C0.3 ACCESS ROAD

TOPSOIL _....

---

'STOCKPILE


1099 18th Street - Denver, Colorado 80202 609 NWELLINGTON FEE12-23

WELL PAD - LOCATION LAYOUT1680' FNL, 1280' FWL CONSULTING, LLC

SW1/4 NW1/4, SECTION 23, T14S, R10E,215h5 NorthWMa Str0elet HORIZONTAL

0 01" =

60: Scale: 1"=60l Date: 9/28/10 SHEET NO:

S.L.M., CARBON COUNTY, UTAH Fhone300 086209 2' CONTOURSREVISED: 12/14/9 2 2 OF

CROSS SECTION A-A'

CROSS SECTION B-B'

125'90'

50'100'100' 10'

0+00

0+60

1+20

1+80

2+40

3+00

5600

5620

5600

5620

0+00

0+60

1+20

1+80

2+40

3+00

3+60

5600

5620

5600

5620

EXISTING GRADE

STAK

EW

ELL

FINISHED PADELEV = 5606.5'

FINISHED PAD

EXISTING GRADE

ELEV = 5606.5'

1.5:

1

1.5:1

STAK

EW

ELL

RESERVEPIT 1.

5:11.5:1

1.5:

1

1.5:

1

HORIZONTAL300 60

1" = 60'

VERTICAL100 20

1" = 20'Scale:

REVISED:

Date: SHEET NO:

CONSULTING, LLC



Fax 307-674-0182 3 OF 1339/28/101"=60'

WELLINGTON FEE 12-23WELL PAD - CROSS SECTIONS





SEA12/14/10

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8:58

:32

AM

Returned Unapproved

5620 562090' 125'

EXISTING GRADE

FWISHED PAD5600 ELEV = 5606.5' 5600

CROSS SECTION A-A

5620 5620100' 100' 50' 10'

EXISTING GRADE

5600-

~~

.RESERVE * 5600

FINISHED PAD PIT'

ELEV = 5606.5'

CROSS SECTION B-BI


1099 18th Street - Denver, Colorado 80202, 609

WELLINGTON FEE12-23

WELL PAD - CROSS SECTIONS1680' FNL, 1280' FWL CONSULTING, LLC HORIZONTAL 1" = 60'

2155 North Main Street 0 10 20 Scale: 1"=60l Date: 9/28/10 SHEET NO:SW1/4 NW1/4, SECTION 23, T14S, R10E, Sheridan, WY 82801 VERTICAL 1" = 20'

S.L.M., CARBON COUNTY, UTAH Phone30370 647-10b20REVISED:

12/14S/3 OF

CONSULTING, LLC



Fax 307-674-0182



WELLINGTON FEE 12-23WELL PAD - RECLAMATION LAYOUT



PROPOSEDACCESS ROAD

TOPSOIL PILE (TO BE

SPREAD OVER

RE-CONTOURED AREA)

WELL PAD LEGEND

WELL LOCATION

RECLAIMED AREA

RECLAIMED BOUNDARY

EXISTING PIPELINE

PROPOSED PIPELINE

Scale: Date: SHEET NO:HORIZONTAL300 60

1" = 60'

41"=60' 9/28/10

4 OF 13

PLEASE NOTE: LOCATIONS OF FACILITIES ANDPROPOSED PIPELINES DISPLAYED WITHIN THEPAD AREA ARE FOR VISUAL PURPOSES ONLY.ACTUAL LOCATIONS TO BE DETERMINEDDURING CONSTRUCTION.

RE-C

ON

TOU

R

AN

D R

E-SEED

RE-C

ON

TOU

R

AN

D R

E-SEED

RESERV

E PIT180'

120'

180'

120'

CUT AND FILL SLOPES WILL BERE-CONTOURED TO 3:1 SLOPES OR

FLATTER AND RE-SEEDED

TO BE USED TO RECLAIM RESERVE PIT AND

RE-CONTOUR RECLAIMED WELL PAD AREA

REVISED:SEA

12/14/10

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:11

AM

Returned Unapproved

PLEASENOTE: LOCATIONS OF FACILITIESANDPROPOSED PIPELINES DISPLAYEDWITHIN THE WELL PAD LEGENDPAD AREAARE FOR VISUAL PURPOSES ONLY.ACTUAL LOCATIONS TO BE DETERMINED WELL LOCATIONDURING CONSTRUCTION.

RECLAIMED AREA

RECLAIMED BOUNDARY

2Û EXISTING PIPELINE- PPL - PROPOSED PIPELINE

TO BEUSEDTO

RECLAIMRESERVEPITAND

RE-CONTOURRECLAIMED

WELLPADAREA

PPL PL

CUT AND FILLSLOPES WILL BERE-CONTOURED TO 3:1 SLOPES OR

FLATTERAND RE-SEEDED

NO O

PROPOSEDACCESS ROAD


1099 18th Street - Denver, Colorado 80202,, 609 N

WELLINGTON FEE12-23WELL PAD - RECLAMATION LAYOUT

CONSULTING, LLC1680' FNL, 1280' FWL o 30 60SW1/4 NW1/4, SECTION 23, T14S, R10E,

2 5eNorthWMan S elet HORIZONTAL 1" =60: Scale: 1"=60l Date: 9/28/10 SHEET NO:

Phone 307-674-0609 SEAS.L.M., CARBON COUNTY, UTAH Fax 307-674-0182 REVISED: 12/14/10 . 4 OF

Scale:

REVISED:

Date: SHEET NO:NTS

PHOTOGRAPH OF WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE NORTH

PHOTOGRAPH OF WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE EAST

CONSULTING, LLC

Sheridan WY 82801Phone 307-674-0609


Fax 307-674-0182 5 OF 1358/20/10


LOCATION PHOTOGRAPHSWELLINGTON FEE 12-23




SEA12/14/10

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12/

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010

8:59

:50

AM

Returned UnapprovedPHOTOGRAPH OF WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE NORTH

PHOTOGRAPH OF WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE EAST





21c5No h

aGi SLtrCeetScale: NTS Date: 8/20/10 SHEET NO:

Sheridan WY 82801S.L.M., CARBON COUNTY, UTAH Phone 307-674-0609 SEA

Fax 307-674-0182 REVISED: 12/14/10 5 OF

PHOTOGRAPH OF WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE SOUTH

PHOTOGRAPH OF WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE WEST

Scale:

REVISED:

Date: SHEET NO:CONSULTING, LLC



Fax 307-674-0182

NTS

6 OF 1368/20/10






SEA12/14/10

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9:00

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Returned UnapprovedPHOTOGRAPH OF WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE SOUTH

o

PHOTOGRAPH OF WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE WEST

KERR-MCGEEOIL & GASONSHORE L.P.


LOCATION PHOTOGRAPHSWELLINGTON FEE12-23

1680' FNL, 1280' FWLCONSULTING, LLCSW1/4 NW1/4, SECTION 23, T14S, R10Er 2155NorthMainStreet Scale: NTS Date: 8/20/10 SHEET NO:Sheridan WY 82801S.L.M., CARBON COUNTY, UTAH Phone 307-674-0609 SEAFax 307-674-0182 REVISED: 12/14/10 6 OF

PHOTOGRAPH OF PROPOSED ACCESS TO THE WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE SOUTH

Scale:

REVISED:

Date: SHEET NO:

7 OF 137CONSULTING, LLC



Fax 307-674-0182

8/20/10NTS






SEA12/14/10

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12/

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9:00

:25

AM

Returned Unapproved

PHOTOGRAPH OF PROPOSED ACCESS TO THE WELLINGTON FEE 12-23 WELL LOCATION - CAMERA ANGLE SOUTH





21c5No h

aGi SLtrCeetScale: NTS Date: 8/20/10 SHEET NO:

Sheridan WY 82801S.L.M., CARBON COUNTY, UTAH Phone 307-674-0609 SEA

Fax 307-674-0182 REVISED: 12/14/10 7 OF

CONSULTING, LLCSheet No:2155 North Main Street

Sheridan, WY 82801Phone (307) 674-0609

Fax (307) 674-0182 8 8 of 13

!(

WELLINGTON FEE12-23

³

Legend!( Proposed Wellington Fee 12-23 Well Location

Access Route - Proposed

Scale: NAD83 USP Central

Revised:

1:100,000

Drawn: TL Date:Date:

T13S

R10E

R11E

T14S

R9E

T15S

East Main Street

R10E

T14S

Kerr-McGee Oil & Gas Onshore, LP1099 18th Street, Denver, Colorado 80202

WELLINGTON FEE 12-23TOPO A

1680' FNL, 1280' FWLSW¼ NW¼, SECTION 23, T14S, R10E

S.L.M., CARBON COUNTY, UTAH 1 Sept 2010TL 14 Dec 2010

Returned Unapproved

RR RR :.

9 10 10 11EE E E

T13ST14S

.

ELLINGTON FEE12-2:

East Main Street

T14STiss

Legend

Proposed Wellington Fee 12-23 Well Location

Access Route - Proposed

Kerr-McGee Oil & Gas Onshore, LP1099 18th Street, Denver, Colorado Bo2o2 N

609WELLINGTON FEE 12-23

TOPO A1680' FNL, 1280' FWL cONSULTING, LLC

2155 North Main Street cale. 1:100,000 AD83 USP Centra¡ Sheet No:SW¼ NW¼, SECTION 23, T14S, R10E Sheridan,WYB2801

S.L.M., CARBON COUNTY, UTAHFon Dra n e 114SDee22001100

8 Of



Fax (307) 674-0182 9 9 of 13

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Lessor: COOK GEORGE S AND SARAH MLessee: TURNER PETROLEUM LAND SERVICES

UT-000005606

ST UT ML-45805

VERDIS L BARKER FAMILY TR

VARNER LYNDA C

ST UT ML-47556

BABCOCK REX DELROD KAREN WWILLIAMS RICK DWILLIAMS BARRY

MARSING CALEEN

HAMILTON CONNIE S


BOOTH SHARRA

ALASKA WESTERN, INC.

UTU 081694 UTU 082541

UTU 073409

UTU 065762

UTU 085163

UTU 073409

UTU 085163

UTU 073409

UTU 065762

UTU 084536 UTU 073409 UTU 085163

UTU 084536

UTU 084536

UTU 078246UTU 065762

UTU 073409

UTU 084535WELLINGTON FEE41-26

WELLINGTON FEE21-26

WELLINGTON FEE13-25

WELLINGTON FEE23-23

WELLINGTON FEDERAL21-25



WELLINGTON FEE12-23

BAWDEN 1

LDS 28-861

TOMADAKIS 1

WELLINGTON FED 12-24







WELLINGTON FEDERAL 31-23

³ Scale: NAD83 USP Central

Revised:

1" = 2,000ft

Drawn: Date:Date:

Legend!( Well - Proposed!( Well - Existing

Well PadAPC Lease

Road - ProposedRoad - Existing

Private Surface OwnershipBLM Surface Ownerhip

State of Utah Surface OwnershipCarbon County Surface Ownership

ú Culvert - Proposed

T14SR10E


TL

WELLINGTON FEE 12-23TOPO B



EAST MAIN ST AIRPORT RD

1 Sept 2010TL

Total Proposed Road Length: ±950ft

Proposed RoadTie-In Point

±730ft

±220ft

14 Dec 2010

±1.1mi

Returned Unapproved

-, (A seti

'--

, UTU 65709i Ÿ\JT Mb47556 LASK ESTE NC ST U $805 UTU 065762 /078249

0ECOUNTy

L T FED 21-14 L GTON F 31 AIRPORT

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L NGl )M ERAL

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WEL NGT FED -24

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MLROD KAREN I

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Legend Total Proposed Road Length: ±950ft

Well - Proposed Well Pad Road - Proposed Private Surface Ownership State of Utah Surface Ownership

$ Well - Existing APC Lease ---- Road - Existing BLMSurface Ownerhip Carbon County Surface Ownership

Culvert - Proposed

Kerr-McGee Oil & Gas Onshore, LP1099 18th Street, Denver, Colorado 80202 N

WELLING N FEE 12-23

1680' FNL, 1280' FWL cONSULTING, LLC2155 North Main Street cale. 1" = 2,000ft AD83 USP Central Sheet No:

SW¼ NW¼, SECTION 23, T14S, R10E Sheridan,WY82801

S.L.M., CARBON COUNTY, UTAH °" s209 Der n e 114Dee 20011009 Of



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!

BAWDEN1

WELLINGTONFED 23-14

WELLINGTONFED 34-14

WELLINGTONFEDERAL 31-23

WELLINGTON FEE41-26

WELLINGTON FEE21-26

WELLINGTON FEE13-25

WELLINGTON FEE23-23




WELLINGTON FEE12-23


Revised:

1" = 2,000ft

Drawn: Date:Date:

Legend!( Well - Proposed

Well - 1 Mile RadiusWell Pad

ú Culvert - ProposedRoad - ProposedRoad - Existing



Well 1 Mile Radius

Well locations derived from State of Utah, Dept. of Natural Resources, Division of Oil, Gas and Mining

! Producing

L Active

Spudded# Approved permit

· Shut-In

q Drilling Operations Suspended

· Temporarily-Abandoned

M Plugged and Abandoned


TL 1 Sept 2010

T14SR10E

WELLINGTON FEE 12-23TOPO C


S.L.M., CARBON COUNTY, UTAH TL 14 Dec 2010

Returned Unapproved



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ST UT ML-45805


VARNER LYNDA C

ST UT ML-47556

BABCOCK REX DELROD KAREN WWILLIAMS RICK DWILLIAMS BARRY

MARSING CALEEN

HAMILTON CONNIE S


BOOTH SHARRA

ALASKA WESTERN, INC.

UTU 081694 UTU 082541

UTU 073409

UTU 065762

UTU 085163

UTU 073409

UTU 085163

UTU 073409

UTU 065762

UTU 084536 UTU 073409 UTU 085163

UTU 084536

UTU 084536

UTU 078246UTU 065762

UTU 073409

UTU 084535BAWDEN 1

LDS 28-861

TOMADAKIS 1

WELLINGTONFED 12-24

WELLINGTONFED 32-24

WELLINGTONFED 23-24

WELLINGTONFED 21-14

WELLINGTONFED 23-14

WELLINGTONFED 31-14

WELLINGTONFED 34-14


WELLINGTON FEE41-26

WELLINGTON FEE21-26

WELLINGTON FEE13-25

WELLINGTON FEE23-23




WELLINGTON FEE12-23


Revised:

1" = 2,000ft

Drawn: Date:Date:


Well PadAPC Lease

Pipeline - ProposedPipeline - Existing





Tie-In Point

T14SR10E


TL

WELLINGTON FEE 12-23TOPO D



Proposed Pipeline Length From Edge of Pad to Tie-In Point: ±1,885ftProposed Pipeline Length From Edge of Pad to Gas Production Unit: ±170ft

±1,680ft

±1,990ft

±205ft

1 Sept 2010TL 14 Dec 2010

Distance ToProposed Well Nearest Lease Boundary=============================================WELLINGTON FEE 160ft 12-23

Returned Unapproved



Fax (307) 674-0182 12 12 of 13

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VARNER LYNDA C

UTU 085163

UTU 085163

UTU 084536UTU 065762


WELLINGTON FEE23-23

WELLINGTON FEE12-23


Revised:

1" = 500ft

Drawn: Date:Date:


Well PadAPC Lease

Pipeline - ProposedPipeline - Existing





Tie-In Point

T14SR10E

TL


14 Dec 2010

±1,680ft

±205ft

Distance ToProposed Well Nearest Lease Boundary=============================================WELLINGTON FEE 160ft 12-23

WELLINGTON FEE 12-23TOPO D2 (PAD & PIPELINE DETAIL)



Proposed Pipeline Length From Edge of Pad to Tie-In Point: ±1,885ftProposed Pipeline Length From Edge of Pad to Gas Production Unit: ±170ft

±1,990ftReturned Unapproved

IL

T1,4S,

- Ri0 E--, mhRAL 31-23 ·

TU UTU 085183 .. I UTU 4536

205ft

R R LYND -C

. . .

Tie-In Point

-UU Q 163

Distance ToProposed Well Nearest Lease Boundary

WELLINGTON FEE 160ft .

12-23

Proposed Pipeline Length From Edge of Pad to Tie-In Point: ±1,885ft

Legend Proposed Pipeline Length From Edge of Pad to Gas Production Unit: ±170ft

Well -Proposed Well Pad " " Pipeline -Proposed Road -Proposed Private Surface Ownership State of Utah Surface Ownership

Well -Existing APC Lease Pipeline -Existing - Road -Existing BLM Surface Ownerhip Carbon County Surface Ownership

Culvert -ProposedKerr-McGee Oil & Gas Onshore, LP

1099 18th Street, Denver, Colorado 80202 NWELLINGTON FEE 12-23 09

TOPO D2 (PAD & PIPELINE DETAIL)1680' FNL, 1280' FWL cONSULTING, LLC

2155 North Main Street cale: 1" = 500ft AD83 USP Central Sheet No:SW¼ NW¼, SECTION 23, T14S, R10E Sheridan,WY82801

S.L.M., CARBON COUNTY, UTAH °" 'g,"i TL 14 Dec2010 I 12 of

SHEET 13 OF 13

KERR-MCGEE OIL & GAS ONSHORE L.P.WELLINGTON FEE 12-23

SECTION 23, T14S, R10E, S.L.M.

Proceed in an easterly direction from Price, Utah, along East Main Street approximately

0.7 miles to the junction of East Main Street and Airport Road. Exit left and proceed

along Airport Road in an easterly direction approximately 1.1 miles to the proposed

access road to the south. Exit right and follow the road flags in a southerly, then westerly

direction approximately 950 feet to the proposed well location.

Total distance from Price, Utah, to the proposed Wellington Fee 12-23 well location is

approximately 2.0 miles.

Returned Unapproved

KERR-MCGEE OIL & GAS ONSHORE L.P.WELLINGTON FEE 12-23

SECTION 23, T14S, R10E, S.L.M.

Proceed in an easterly direction from Price, Utah, along East Main Street approximately

0.7 miles to the junction of East Main Street and Airport Road. Exit left and proceed

along Airport Road in an easterly direction approximately 1.1 miles to the proposed

access road to the south. Exit right and follow the road flags in a southerly, then westerly

direction approximately 950 feet to the proposed well location.

Total distance from Price, Utah, to the proposed Wellington Fee 12-23 well location is

approximately 2.0 miles.

SHEET 13 OF

SURFACE USE PLAN of OPERATIONS (SUPO) Cardinal Draw Field

Carbon County, Utah

Kerr-McGee Oil & Gas Onshore LP

Wellington Fee 12-23 Section 23 T14S R10E

1680’ FNL 1280’ FWL (SW/4 NW/4) Fee Surface (Lynda Varner)

Fee Minerals


1481’ FSL 534’ FWL (NW/4 SW/4) Fee Surface (Verdis Barker)

Fee Minerals


1066’ FNL 1608’ FWL (NE/4 NW/4) Fee Surface (Circle K Ranch)

Fee Minerals


1837’ FSL 1899’ FWL (NE/4 SW/4) Fee Surface (Lynda Varner)

Fee Minerals


625’ FSL 2678’ FEL (SW/4 SE/4) Fee (Shimmon) / Federal Surface

Fee Minerals


572’ FNL 1117’ FEL (NE/4 NE/4) Fee Surface (Verdis Barker)

Fee Minerals

This Surface Use Plan of Operations (SUPO) contains surface operating procedures for Kerr-McGee Oil & Gas Onshore LP (KMG) pertaining to actions that involve the State of Utah School and Institutional Trust Lands Administration (SITLA) in the development of minerals leased to KMG (including, but not limited to, APDs/SULAs/ROEs/ROWs and/or easements).

See associated Utah Division of Oil, Gas, and Mining (UDOGM) Form 3(s), plats, maps, and other attachments for site-specific information on projects represented herein.

A. Existing Roads:

Existing roads consist of county roads and improved/unimproved lease roads. KMG will maintain existing roads in a condition that is the same as or better than before operations began and in a safe and usable condition. Maintenance of existing roads will continue until final abandonment and reclamation of well pads and/or other facilities. The road maintenance may include, but is not limited to, blading, ditching, culvert installation/cleanout, surfacing, and dust control.

Typically, roads, gathering lines and electrical distribution lines will occupy common disturbance corridors and roadways will be used as working space. All disturbances located in the same corridor will overlap each other to the maximum extent possible.

Returned Unapproved

SURFACE USE PLAN of OPERATIONS (SUPO)Cardinal Draw Field

Carbon County, UtahKerr-McGee Oil & Gas Onshore LP

Wellington Fee 12-23 Wellington Fee 23-23Section 23 Tl4S Rl0E Section 23 Tl4S Rl0E

1680' FNL 1280' FWL (SW/4 NW/4) 1837' FSL 1899' FWL (NE/4 SW/4)Fee Surface (Lynda Varner) Fee Surface (Lynda Varner)

Fee Minerals Fee Minerals


1481' FSL 534' FWL (NW/4 SW/4) 625' FSL 2678' FEL (SW/4 SE/4)Fee Surface (Verdis Barker) Fee (Shimmon) / Federal Surface



1066' FNL 1608' FWL (NE/4 NW/4) 572' FNL 1117' FEL (NE/4 NE/4)Fee Surface (Circle K Ranch) Fee Surface (Verdis Barker)


This Surface Use Plan of Operations (SUPO) contains surface operating procedures for Kerr-McGee Oil &Gas Onshore LP (KMG) pertaining to actions that involve the State of Utah School and Institutional TrustLands Administration (SITLA) in the development of minerals leased to KMG (including, butnot limited to,APDs/SULAs/ROEs/ROWs and/or easements).

See associated Utah Division of Oil, Gas, and Mining (UDOGM) Form 3(s), plats, maps, and otherattachments for site-specific information on projects represented herein.

A. Existing Roads:

Existing roads consist of county roads and improved/unimproved lease roads. KMG will maintainexisting roads in a condition that is the same as or better than before operations began and in a safe andusable condition. Maintenance of existing roads will continue until final abandonment and reclamation ofwell pads and/or other facilities. The road maintenance may include, but is not limited to, blading,ditching, culvert installation/cleanout, surfacing, and dust control.

Typically, roads, gathering lines and electrical distribution lines will occupy common disturbancecorridors and roadways will be used as working space. All disturbances located in the same corridor willoverlap each other to the maximum extent

Cardinal Draw Field: Six Wellington Fee wells Surface Use Plan of Operations Wellington Fee 12-23, 13-25, 21-26, 23-23, 34-25, 41-26 Page 2 B. Planned Access Roads:

New access roads to these well locations are summarized below in Table 1, and shown in each well’s Topo B map. Applicable Carbon County encroachment and/or pipeline crossing permits will be obtained prior to construction/development, if needed.

Table 1 New Access Road Details

Section/Township/Range

Well Name

New Access Road Length

(Amount with Concurrent Use) 1

Starting Ending (at well pad)

Surface Owner2


±950’ (±730’) 23-T14S-R10E 14-T14S-R10E Lynda Varner


±5880’ (±1875’) 26-T14S-R10E 23-T14S-R10E Verdis Barker

Wellington Fee 21-26 ±3030’ 25-T14S-R10E 25-T14S-R10E Circle K

Ranch Wellington Fee

23-23 ±3155 26-T14S-R10E 26-T14S-R10E Lynda Varner


±1670’ (±730’) 23-T14S-R10E 23-T14S-R10E

Donna Shimmon

Perry Trust / BLM


±105’ (±1980’) 25-T14S-R10E 23-T13S-R10E Verdis Barker

1 Concurrent use indicates the length of new access road that will be used by two or more

wells See each well’s Topo B map for additional information. 2 See Table 4 for detailed surface owner information, including full name and contact

information.

Where roads are new or to be reconstructed, they will be located, designed, and maintained to meet the standards of SITLA and other commonly accepted Best Management Practices (BMPs). If a new road/corridor were to cross a water of the United States, KMG will adhere to the requirements of applicable Nationwide or Individual Permits of the Department of Army Corps of Engineers (COE).

The running surface will be crowned/ditched with a running surface of ±16’ and the total disturbance width of 45’. The temporary construction width is 75’. Plans for improvement and/or maintenance of existing roads are to maintain in as good or better conditions than at present. A regular maintenance plan will include, but not be limited to, blading, ditching, and surfacing.

Returned Unapproved

Cardinal Draw Field: Six Wellington Fee wells Surface Use Plan of OperationsWellington Fee 12-23, 13-25, 21-26, 23-23, 34-25, 41-26 Page 2

B. Planned Access Roads:

New access roads to these well locations are summarized below in Table 1, and shown in each well'sTopo B map. Applicable Carbon County encroachment and/or pipeline crossing permits will be obtainedprior to construction/development, if needed.

Table 1New Access Road Details

New Access Road Section/Towaship/RangeLength . SurfaceWell Name . Ending (at well 2(Amount with Startmg Owner

Concurrent Use) i pad)

Wellington Fee ±950' 23-Tl4S-Rl0E 14-Tl4S-Rl0E Lynda Varner12-23 (±730')Wellington Fee ±5880' 26-Tl4S-Rl0E 23-Tl4S-Rl0E Verdis Barker13-25 (±1875')Wellington Fee Circle K

±3030' 25-Tl4S-Rl0E 25-Tl4S-Rl0E21-26 RanchWellington Fee

±3155 26-Tl4S-Rl0E 26-Tl4S-Rl0E Lynda Varner23-23Donna

Wellington Fee ±1670' Shimmon23-Tl4S-Rl0E 23-Tl4S-Rl0E34-25 (±730') Perry Trust /BLM

Wellington Fee ±105' 25-Tl4S-Rl0E 23-T13S-Rl0E Verdis Barker41-26 (±1980')

* Concurrent use indicates the length of new access road that will be used by two or morewells See each well's Topo B map for additional information.

2 See Table 4 for detailed surface owner information, including full name and contactinformation.

Where roads are new or to be reconstructed, they will be located, designed, and maintained to meet thestandards of SITLA and other commonly accepted Best Management Practices (BMPs). If a newroad/corridor were to cross a water of the United States, KMG will adhere to the requirements ofapplicable Nationwide or Individual Permits of the Department of Army Corps of Engineers (COE).

The running surface will be crowned/ditched with a running surface of ±16' and the total disturbancewidth of 45'. The temporary construction width is 75'. Plans for improvement and/or maintenance ofexisting roads are to maintain in as good or better conditions than at present. A regular maintenance planwill include, but not be limited to, blading, ditching, and

Cardinal Draw Field: Six Wellington Fee wells Surface Use Plan of Operations Wellington Fee 12-23, 13-25, 21-26, 23-23, 34-25, 41-26 Page 3

Turnouts; major cut and fills; culverts; bridges; gates; cattle guards; low water crossings; or modifications needed to existing infrastructure/facilities were determined at the on-site and, as applicable, are typically shown on attached Exhibits and Topo maps.

C. Location of Existing and Proposed Facilities:

Gathering Facilities/Utility Trenches:

The following pipeline information will apply if the wells are productive (see Topo D). There will be a gas pipeline and a water transmission pipeline in the same trench. Additionally, electrical power will be buried in a separate, but adjacent, trench with appropriate safety measures in place. The trenches for the pipelines will follow the access road whenever possible. All trenches will be within the corridor as surveyed by the archaeologist. Each gathering pipeline will have the following specifications:

Gas Gathering Water Gathering Diameter: 4” – 6” 4” – 6” Type: SDR 11 SDR 9 Material: poly HDPE 4710 poly HDPE 4710 Buried depth: 4’ 4’ Design pressure: 100 psi 200 psi Test pressures: 120 psi 120 psi Test material: Air Air

Table 2 New Gas Gathering Pipeline Details

New Pipeline Length Section/Township/Range

Well Name

to Existing Pipeline

(Amount with Concurrent

Use) 1

to Tie-in point


Use) 1

Starting (at existing pipeline)

Ending (at well pad)

Surface Owner 2


±3875’ (±3670’)

±2055’ (±1680’)

NW/4 SE/4 23-T14S-R10E 23-T14S-R10E Lynda Varner,

others Wellington Fee 13-25

±6150 (±1940’) ±4210’ C-SE/4

23-T14S-R10E 25-T14S-R10E Verdis Barker


±5135’ (±2045) ±3090’ C-SE/4

23-T14S-R10E 26-T14S-R10E Circle K Ranch, others

Wellington Fee 23-23 ±2005’ ±2005 NW/4 SE/4

23-T14S-R10E 23-T14S-R10E Lynda Varner, others


±5425 (±4520’) ±4520’ NE/4 NW/4

25-T14S-R10E 25-T14S-R10E Donna

Shimmon Perry Trust, others


±2140’ (±2065’)

±2140’ (±2065’)

C-SE/4 23-T14S-R10E 26-T13S-R10E Verdis Barker

Returned Unapproved


Turnouts; major cut and fills; culverts; bridges; gates; cattle guards; low water crossings; or modificationsneeded to existing infrastructure/facilities were determined at the on-site and, as applicable, are typicallyshown on attached Exhibits and Topo maps.

C. Location of Existing and Proposed Facilities:

Gathering Facilities/Utility Trenches:

The following pipeline information will apply if the wells are productive (see Topo D). There will be agas pipeline and a water transmission pipeline in the same trench. Additionally, electrical power will beburied in a separate, but adjacent, trench with appropriate safety measures in place. The trenches for thepipelines will follow the access road whenever possible. All trenches will be within the corridor assurveyed by the archaeologist.

Each gathering pipeline will have the following specifications:Gas Gathering Water Gathering

Diameter: 4" - 6" 4" - 6"Type: SDR 11 SDR 9Material: poly HDPE 4710 poly HDPE 4710Buried depth: 4' 4'Design pressure: 100 psi 200 psiTest pressures: 120 psi 120 psiTest material: Air Air

Table 2New Gas Gathering Pipeline Details

New Pipeline Length Section/Township/Rangeto Existing to Tie-in

Pipeline point Starting (at 2Well Name . Ending (at well Surface Owner(Amount with (Amount with existingConcurrent Concurrent pipeline) pad)

Use) * Use)Wellington ±3875' ±2055' NW/4 SE/4 Lynda Varner23-Tl4S-Rl0E 'Fee 12-23 (±3670') (±1680') 23-Tl4S-Rl0E others

Wellington ±6150 C-SE/4±4210' 25-Tl4S-Rl0E Verdis BarkerFee 13-25 (±1940') 23-Tl4S-Rl0E

Wellington ±5135',

C-SE/4 Circle K Ranch,±3090 26-Tl4S-Rl0E

Fee 21-26 (±2045) 23-Tl4S-Rl0E othersWellington , NW/4 SE/4 Lynda Varner

±2005 ±2005 23-Tl4S-Rl0E 'Fee 23-23 23-Tl4S-Rl0E others

DonnaWellington ±5425 , NE/4 NW/4 .

±4520 25-Tl4S-Rl0E Shimmon PerryFee 34-25 (±4520') 25-Tl4S-Rl0ETrust, others

Wellington ±2140' ±2140' C-SE/4 26-T13S-Rl0E Verdis BarkerFee 41-26 (±2065') (±2065')


1 Concurrent use indicates the length of new pipeline that will be used by two or more wells See each well’s Topo D and D2 maps for additional information.

2 See Table 4 for detailed surface owner information, including full name and contact information.

Table 3

New Liquids Gathering Pipeline Details New Liquids Gathering

Pipeline Length Section/Township/Range

Well Name

to Existing Pipeline (Amount

with Concurrent

Use) 1

to Tie-in point


Use) 1

Starting (at existing pipeline)

Ending (at well pad)

Surface Owner 2


±3875’ (±3670’)

±2055’ (±1680’)

NW/4 SE/4 23-T14S-R10E 23-T14S-R10E Lynda Varner,

others Wellington Fee 13-25

±6150 (±1940’) ±4210’ C-SE/4

23-T14S-R10E 25-T14S-R10E Verdis Barker


±5135’ (±2045) ±3090’ C-SE/4

23-T14S-R10E 26-T14S-R10E Circle K Ranch, others

Wellington Fee 23-23 ±2005’ ±2005 NW/4 SE/4

23-T14S-R10E 23-T14S-R10E Lynda Varner, others


±5425 (±4520’) ±4520’ NE/4 NW/4

25-T14S-R10E 25-T14S-R10E Donna

Shimmon Perry Trust, others


±2140’ (±2065’)

±2140’ (±2065’)

C-SE/4 23-T14S-R10E 26-T13S-R10E Verdis Barker

1 Concurrent use indicates the length of new pipeline that will be used by two or more wells See each well’s Topo D and D2 maps for additional information.

2 See Table 4 for detailed surface owner information, including full name and contact information.

The proposed pipelines will be buried and will include separate lines for gas gathering and liquid gathering in one trench, and electrical lines in an adjacent, separate trench. Where the utility trench is adjacent to the road or well pad, the road and/or well pad will be utilized for construction activities and staging. KMG requests a permanent 45' right-of-way (ROW) adjacent to the road for the life of the project for maintenance, repairs, and/or upgrades. For construction purposes, KMG requests a temporary 75’ ROW. Where the pipeline is not adjacent to the road or well pad, KMG requests a temporary 45’ construction ROW and 30' permanent ROW.

Returned Unapproved


* Concurrent use indicates the length ofnew pipeline that will be used by two or more wellsSee each well's Topo D and D2 maps for additional information.

' See Table 4 for detailed surface owner information, including full name and contactinformation.

Table 3New Liquids Gathering Pipeline Details

New Liquids Gathering .

. Section/Township/RangePipeline Lengthto Existing . .

. to Tie-inPipeline . Surface OwnerWell Name point Starting (at .(Amount . . . Ending (at well

. (Amount with existingwith . . pad)Concurrent pipeline)Concurrent i

i Use)Use)Wellington ±3875' ±2055' NW/4 SE/4 Lynda Varner,23-Tl4S-Rl0EFee 12-23 (±3670') (±1680') 23-Tl4S-Rl0E others

Wellington ±6150 C-SE/4±4210' 25-Tl4S-Rl0E Verdis BarkerFee 13-25 (±1940') 23-Tl4S-Rl0E

Wellington ±5135' C-SE/4 Circle K±3090' 26-Tl4S-Rl0E

Fee 21-26 (±2045) 23-Tl4S-Rl0E Ranch, othersWellington , NW/4 SE/4 Lynda Varner

±2005 ±2005 23-Tl4S-Rl0E 'Fee23-23 23-Tl4S-Rl0E others

DonnaWellington ±5425 NE/4 NW/4 .

±4520' 25-Tl4S-Rl0E Shimmon PerryFee 34-25 (±4520') 25-Tl4S-Rl0ETrust, others

Wellington ±2140' ±2140' C-SE/4 26-T13S-Rl0E Verdis BarkerFee 41-26 (±2065') (±2065') 23-Tl4S-Rl0E* Concurrent use indicates the length ofnew pipeline that will be used by two or more wells

See each well's Topo D and D2 maps for additional information.

2 See Table 4 for detailed surface owner information, including full name and contactinformation.

The proposed pipelines will be buried and will include separate lines for gas gathering and liquidgathering in one trench, and electrical lines in an adjacent, separate trench. Where the utility trench isadjacent to the road or well pad, the road and/or well pad will be utilized for construction activities andstaging. KMG requests a permanent 45' right-of-way (ROW) adjacent to the road for the life of theproject for maintenance, repairs, and/or upgrades. For construction purposes, KMG requests a temporary75' ROW. Where the pipeline is not adjacent to the road or well pad, KMG requests a temporary 45'construction ROW and 30' permanent


The proposed trench width for the pipeline would range from 18-48 inches and will be excavated to a depth of 48 to 60 inches of normal soil cover.

Pipeline signs will be installed along the right-of-way to indicate the pipeline proximity, ownership, and to provide emergency contact phone numbers. Above ground valves and T's, will be installed at various locations for connection, corrosion prevention and/or for safety purposes. Trace wires follow the poly lines.

D. Location and Type of Water Supply:

Water use for drilling and completion purposes will be minimal as these wells will be air drilled. When water is needed, it will be obtained from the city of Price

E. Source of Construction Materials:

Construction operations will typically be completed with native materials found on location. If needed, construction materials that must be imported to the site (mineral material aggregate, soils or materials suitable for fill/surfacing) will be obtained from a nearby permitted source and described in subsequent Sundry requests. No construction materials will be removed from State lands without prior approval from SITLA.

F. Methods of Handling Waste Materials:

Should the well be productive, produced water will be contained in a water tank and will be transported by pipeline and/or truck to an approved disposal sites facilities and/or Salt Water Disposal (SWD) injection well.

Drill cuttings and/or fluids will be contained in the reserve pit. Cuttings will be buried in pit(s) upon closure. Unless otherwise approved, no oil or other oil-based drilling additives, chromium/metals-based, or saline muds will be used during drilling. Only fresh water (as specified above), biodegradable polymer soap, bentonite clay, and/or non-toxic additives will be used in the mud system.

Pits will be constructed to minimize the accumulation of surface runoff. Should fluid hydrocarbons be encountered during drilling, completions or well testing, product will either be contained in test tanks on the well site or evacuated by vacuum trucks and transported to an approved disposal/sales facility. Should petroleum hydrocarbons unexpectedly be released into a pit, they will be removed as soon as practical but in no case will they remain longer than 72 hours unless an alternate is approved by SITLA. Hydrocarbon removal will also take place prior to the closure of the pit, unless authorization is provided for disposal via alternative pit closure methods (e.g. solidification).

The reserve pit will be lined with a synthetic material 20-mil or thicker, the liner will be installed over smooth fill subgrade that is free of pockets, loose rocks, or other materials (i.e. sand, sifted dirt, bentonite, straw, etc.) that could damage the liner. Any additional pits necessary to subsequent operations, such as

Returned Unapproved


The proposed trench width for the pipeline would range from 18-48 inches and will be excavated to adepth of 48 to 60 inches of normal soil cover.

Pipeline signs will be installed along the right-of-way to indicate the pipeline proximity, ownership, andto provide emergency contact phone numbers. Above ground valves and T's, will be installed at variouslocations for connection, corrosion prevention and/or for safety purposes. Trace wires follow the polylines.

D. Location and Type of Water Supplv:

Water use for drilling and completion purposes will be minimal as these wells will be air drilled. Whenwater is needed, it will be obtained from the city of Price

E. Source of Construction Materials:

Construction operations will typically be completed with native materials found on location. If needed,construction materials that must be imported to the site (mineral material aggregate, soils or materialssuitable for fill/surfacing) will be obtained from a nearby permitted source and described in subsequentSundry requests.No construction materials will be removed from State lands without prior approval fromSITLA.

F. Methods of Handling Waste Materials:

Should the well be productive, produced water will be contained in a water tank and will be transportedby pipeline and/or truck to an approved disposal sites facilities and/or Salt Water Disposal (SWD)injection well.

Drill cuttings and/or fluids will be contained in the reserve pit. Cuttings will be buried in pit(s) uponclosure. Unless otherwise approved, no oil or other oil-based drilling additives, chromium/metals-based,or saline muds will be used during drilling. Only fresh water (as specified above), biodegradablepolymersoap, bentonite clay, and/or non-toxic additives will be used in the mud system.

Pits will be constructed to minimize the accumulation of surface runoff. Should fluid hydrocarbons beencountered during drilling, completions or well testing, product will either be contained in test tanks onthe well site or evacuated by vacuum trucks and transported to an approved disposal/sales facility. Shouldpetroleum hydrocarbons unexpectedly be released into a pit, they will be removed as soon as practical butin no case will they remain longer than 72 hours unless an alternate is approved by SITLA. Hydrocarbonremoval will also take place prior to the closure of the pit, unless authorization is provided for disposalvia alternative pit closure methods (e.g. solidification).

The reserve pit will be lined with a synthetic material 20-mil or thicker, the liner will be installed oversmooth fill subgrade that is free of pockets, loose rocks, or other materials (i.e. sand, sifted dirt, bentonite,straw, etc.) that could damage the liner. Any additional pits necessary to subsequent operations, such


temporary flare or workover pits, will be contained within the originally approved well pad and disturbance boundaries. Such temporary pits will be backfilled and reclaimed the next full summer after completion of work at a well location.

For the protection of livestock and wildlife, all open pits and cellars will be fenced and covered to prevent wildlife or livestock entry. The fence to be used is 45” net fence.

Pits containing drilling cuttings, mud, and/or completions fluids will be allowed to dry. Reserve pit liners will be cut off or folded as near to the mud surface as possible and as safety considerations allow and buried on location.

No garbage or non-exempt substances as defined by Resource Conservation and Recovery Act (RCRA) subtitle C will be placed in the reserve pit. All refuse generated during construction, drilling, completion, and well testing activities will be contained in an enclosed receptacle, removed from the drill locations promptly, and transported to an approved disposal facility.

Portable, self-contained chemical toilets and/or sewage processing facilities will be provided for human waste disposal. Upon completion of operations, or as required, the toilet holding tanks will be pumped and the contents disposed of in an approved sewage disposal facility. All applicable regulations pertaining to disposal of human and solid waste will be observed.

Any undesirable event, accidental release, or in excess of reportable quantities will be managed according to the notification requirements of UDOGM’s “Reporting Oil and Gas Undesirable Events” rule, and, where State wells are participatory to a Federal agreement, according to NTL-3A.

Materials Management

Hazardous materials above reportable quantities will not be produced by drilling or completing proposed wells or constructing the pipelines/facilities. The term “hazardous materials” as used here means: (1) any substance, pollutant, or containment listed as hazardous under the Comprehensive Environmental Response, Compensation, and Liability Act (CERCLA) of 1980, as amended 42 U.S.C. 9601 et seq., and the regulations issued under CERCLA; and (2) any hazardous waste as defined in RCRA of 1976, as amended. In addition, no extremely hazardous substance, as defined in 40 CFR 355, in threshold planning quantities, would be used, produced, stored, transported, or disposed of while producing any well.

Chemicals subject to reporting under Title III of the Superfund Amendments and Reauthorization Act (SARA) in quantities of 10,000 pounds or more may be produced and/or stored at production facilities and may be kept in limited quantities on drilling sites and well locations for short periods of time during drilling or completion activities.

G. Ancillary Facilities:

None are anticipated.

Returned Unapproved


temporary flare or workover pits, will be contained within the originally approved well pad anddisturbance boundaries. Such temporary pits will be backfilled and reclaimed the next full summer aftercompletion of work at a well location.

For the protection of livestock and wildlife, all open pits and cellars will be fenced and covered to preventwildlife or livestock entry. The fence to be used is 45" net fence.

Pits containing drilling cuttings, mud, and/or completions fluids will be allowed to dry. Reserve pit linerswill be cut off or folded as near to the mud surface as possible and as safety considerations allow andburied on location.

No garbage or non-exempt substances as defined by Resource Conservation and Recovery Act (RCRA)subtitle C will be placed in the reserve pit. All refuse generated during construction, drilling, completion,and well testing activities will be contained in an enclosed receptacle, removed from the drill locationspromptly, and transported to an approved disposal facility.

Portable, self-contained chemical toilets and/or sewage processing facilities will be provided for humanwaste disposal. Upon completion of operations, or as required, the toilet holding tanks will be pumpedand the contents disposed ofin an approved sewage disposal facility. All applicable regulations pertainingto disposal of human and solid waste will be observed.

Any undesirable event, accidental release, or in excess of reportable quantities will be managed accordingto the notification requirements of UDOGM's "Reporting Oil and Gas Undesirable Events" rule, and,where State wells are participatory to a Federal agreement, according to NTL-3A.

Materials Management

Hazardous materials above reportable quantities will not be produced by drilling or completing proposedwells or constructing the pipelines/facilities. The term "hazardous materials" as used here means: (1) anysubstance, pollutant, or containment listed as hazardous under the Comprehensive EnvironmentalResponse, Compensation, and Liability Act (CERCLA) of 1980, as amended 42 U.S.C. 9601 et seq., andthe regulations issued under CERCLA; and (2) any hazardous waste as defined in RCRA of 1976, asamended. In addition, no extremely hazardous substance, as defined in 40 CFR 355, in thresholdplanningquantities, would be used, produced, stored, transported, or disposed of while producing any well.

Chemicals subject to reporting under Title III of the Superfund Amendments and Reauthorization Act(SARA) in quantities of 10,000 pounds or more may be produced and/or stored at production facilitiesand may be kept in limited quantities on drilling sites and well locations for short periods of time duringdrilling or completion activities.

G. Ancillary Facilities:

None are

Cardinal Draw Field: Six Wellington Fee wells Surface Use Plan of Operations Wellington Fee 12-23, 13-25, 21-26, 23-23, 34-25, 41-26 Page 7 H. Well Site Layout (see Well Pad Design Summary ):

The location, orientation and aerial extent of each drill pad; reserve/completion/flare pit; access road ingress/egress points, drilling rig, dikes/ditches, existing wells/infrastructure; proposed cuts and fills; and topsoil and spoil material stockpile locations are depicted on the exhibits for each project, where applicable. Site-specific conditions may require slight deviation in actual equipment and facility layout; however, the area of disturbance, as described in the survey, will not be exceeded.

Coordinates are provided in the National Spatial Reference System, North American Datum, 1983 (NAD83) or latest edition. Distances are depicted on each plat to the nearest two adjacent section lines.

I. Plans for Reclamation of the Surface:

Surface reclamation will be undertaken in two phases: interim and final. Interim reclamation is conducted following well completion and extends through the period of production. This reclamation is for the area of the well pad that is not required for production activities. Final reclamation is conducted following well plugging/conversion and/or facility abandonment processes.

Reclamation activities in both phases may include but are not limited to: re-contouring or re-configuration of topographic surfaces, restoration of drainage systems, segregation of spoils materials, minimizing surface disturbance, re-evaluating backfill requirements, pit closure, topsoil redistribution, soil treatments, seeding and weed control.

Interim Reclamation

Interim reclamation includes pit closure, re-contouring (where possible), soil bed preparation, topsoil placement, seeding, and/or weed control.

Interim re-contouring involves bringing all construction material from cuts and fills back onto the well pad and site and reestablishing the natural contours where desirable and practical. Fill and stockpiled spoils no longer necessary to the operation will be spread on the cut slopes and covered with stockpiled topsoil. All stockpiled top soils will be used for interim reclamation where practical to maintain soil viability. Where possible, the land surface will be left “rough” after re-contouring to ensure that the maximum surface area will be available to support the reestablishment of vegetative cover.

A reserve pit, upon being allowed to dry, will be backfilled and compacted with cover materials that are void of any topsoil, vegetation, large stones, rocks or foreign objects. Soils that are moisture laden, saturated, or partially/completely frozen will not be used for backfill or cover. The pit area will be mounded to allow for settling and to promote positive surface drainage away from the pit.

Final Reclamation

Final reclamation will be performed for newly drilled unproductive wells and/or at the end of the life of a productive well. As soon as practical after the conclusion of drilling and testing operations, unproductive drill holes will be plugged and abandoned (P&A). Site and road reclamation will commence following plugging. In no case will reclamation at non-producing locations be initiated later than six (6) months from the date a well is plugged. A joint inspection of the disturbed area to be reclaimed may be requested

Returned Unapproved


H. Well Site Lavout (see Well Pad Design Summarv ):

The location, orientation and aerial extent of each drill pad; reserve/completion/flare pit; access roadingress/egress points, drilling rig, dikes/ditches, existing wells/infrastructure; proposed cuts and fills; andtopsoil and spoil material stockpile locations are depicted on the exhibits for each project, whereapplicable. Site-specific conditions may require slight deviation in actual equipment and facility layout;however, the area of disturbance, as described in the survey, will not be exceeded.

Coordinates are provided in the National Spatial Reference System, North American Datum, 1983(NAD83) or latest edition. Distances are depicted on each plat to the nearest two adjacent section lines.

I. Plans for Reclamation of the Surface:

Surface reclamation will be undertaken in two phases: interim and final. Interim reclamation is conductedfollowing well completion and extends through the period of production. This reclamation is for the areaof the well pad that is not required for production activities. Final reclamation is conducted followingwell plugging/conversion and/or facility abandonment processes.

Reclamation activities in both phases may include but are not limited to: re-contouring or re-configurationof topographic surfaces, restoration of drainage systems, segregation of spoils materials, minimizingsurface disturbance, re-evaluating backfill requirements, pit closure, topsoil redistribution, soil treatments,seeding and weed control.

Interim Reclamation

Interim reclamation includes pit closure, re-contouring (where possible), soil bed preparation, topsoilplacement, seeding, and/or weed control.

Interim re-contouring involves bringing all construction material from cuts and fills back onto the wellpad and site and reestablishing the natural contours where desirable and practical. Fill and stockpiledspoils no longer necessary to the operation will be spread on the cut slopes and covered with stockpiledtopsoil. All stockpiled top soils will be used for interim reclamation where practical to maintain soilviability. Where possible, the land surface will be left "rough" after re-contouring to ensure that themaximum surface area will be available to support the reestablishment of vegetative cover.

A reserve pit, upon being allowed to dry, will be backfilled and compacted with cover materials that arevoid of any topsoil, vegetation, large stones, rocks or foreign objects. Soils that are moisture laden,saturated, or partially/completely frozen will not be used for backfill or cover. The pit area will bemounded to allow for settling and to promote positive surface drainage away from the pit.

Final Reclamation

Final reclamation will be performed for newly drilled unproductive wells and/or at the end of the life of aproductive well. As soon as practical after the conclusion of drilling and testing operations, unproductivedrill holes will be plugged and abandoned (P&A). Site and road reclamation will commence followingplugging. In no case will reclamation at non-producing locations be initiated later than six (6) monthsfrom the date a well is plugged. A joint inspection of the disturbed area to be reclaimed may be


by KMG. The primary purpose of this inspection will be to review the existing conditions, or agree upon a revised final reclamation and abandonment plan. A Notice of Intent to Abandon will be filed for final recommendations regarding surface reclamation.

After plugging, all wellhead equipment that is no longer needed will be removed, and the well site will be reclaimed. Final contouring will blend with and follow as closely as practical the natural terrain and contours of the original site and surrounding areas. After re-contouring, final grading will be conducted over the entire surface of the well site and access road. Where practical, the area will be ripped to a depth of 18 to 24 inches on 18 to 24-inch centers and surface materials will be pitted with small depressions to form longitudinal depressions 12 to 18 inches deep perpendicular to the natural flow of water.

All unnecessary surface equipment and structures (e.g. cattle guards) and water control structures (e.g. culverts, drainage pipes) not needed to facilitate successful reclamation will be removed during final reclamation. Roads that will be reclaimed will be ripped to a depth of 18 inches where practical, re-contoured to approximate the original contour of the ground and seeded.

Upon successfully completing reclamation of a P&A location, a Final Abandonment Notice will be submitted to UDOGM.

Seeding and Measures Common to Interim and Final Reclamation

Reclaimed areas may be fenced to exclude grazing and encourage re-vegetation.

On slopes where severe erosion can become a problem and the use of machinery is not practical, seed will be hand broadcast and raked with twice the specified amount of seed. The slope will be stabilized using materials specifically designed to prevent erosion on steep slopes and hold seed in place so vegetation can become permanently established. These materials will include, but are not limited to, erosion control blankets and bonded fiber matrix at a rate to achieve a minimum of 80 percent soil coverage.

Seeding will occur year-round as conditions allow. Seed mixes appropriate to the native plant community as determined and specified for each project location based on the site specific soils will be used for re-vegetation. The site specific seed mix will be provided by SITLA.

J. Surface/Mineral Ownership:

See Table 4

Returned Unapproved


by KMG. The primary purpose of this inspection will be to review the existing conditions, or agree upona revised final reclamation and abandonment plan. A Notice of Intent to Abandon will be filed for finalrecommendations regarding surface reclamation.

After plugging, all wellhead equipment that is no longer needed will be removed, and the well site will bereclaimed. Final contouring will blend with and follow as closely as practical the natural terrain andcontours of the original site and surrounding areas. After re-contouring, final grading will be conductedover the entire surface of the well site and access road. Where practical, the area will be ripped to a depthof 18 to 24 inches on 18 to 24-inch centers and surface materials will be pitted with small depressions toform longitudinal depressions 12 to 18 inches deep perpendicular to the natural flow of water.

All unnecessary surface equipment and structures (e.g. cattle guards) and water control structures (e.g.culverts, drainage pipes) not needed to facilitate successful reclamation will be removed during finalreclamation. Roads that will be reclaimed will be ripped to a depth of 18 inches where practical, re-contoured to approximate the original contour of the ground and seeded.

Upon successfully completing reclamation of a P&A location, a Final Abandonment Notice will besubmitted to UDOGM.

Seeding and Measures Common to Interim and Final Reclamation

Reclaimed areas may be fenced to exclude grazing and encourage re-vegetation.

On slopes where severe erosion can become aproblem and the use of machinery is not practical, seed willbe hand broadcast and raked with twice the specified amount of seed. The slope will be stabilized usingmaterials specifically designedto prevent erosion on steep slopes and hold seed in place so vegetation canbecome permanently established. These materials will include, but are not limited to, erosion controlblankets and bonded fiber matrix at a rate to achieve a minimum of 80 percent soil coverage.

Seeding will occur year-round as conditions allow. Seedmixes appropriate to the native plant communityas determined and specified for each project location based on the site specific soils will be used for re-vegetation. The site specific seed mix will be provided by SITLA.

J. Surface/Mineral Ownership:

See Table

TABLE 4 Surface Ownership Information

Well Pad, Pipelines, Access Roads Well Name Pipeline/Landowner (1) Pipeline/Landowner (2) Landowner

1 Wellington Fee 12-23 Section 23 T14S R10E 1680’ FNL 1280’ FWL SW/4 NW/4 Fee Surface (Lynda Varner) Fee Minerals

Lynda Varner, et al PO Box 866 Price, Utah 84501 Dave Varner: 435-630-1182

Ralph C. Keele, Jr. 117 S 400 E Price, UT 84501 &/or Denis Merrelli PO Box 833 Price, UT 84501-0833

Leona F Leautaud Trust c/o Jack Leautaud 1771 E 300 S Price, UT 84501 Jack Leautaud, Cell: 435-636-5966

2 Wellington Fee 13-25 Section 25 T14S R10E 1481’ FSL 534’ FWL NW/4 SW/4 Fee Surface (Verdis Barker) Fee Minerals

Verdis L. Barker & Pauline R. Barker Trust 1400 S 3250 E Price, UT 84501 435-637-3417 or 435-637-0538

Same Same

3 Wellington Fee 21-26 Section 26 T14S R10E 1066’ FNL 1608’ FWL NE/4 NW/4 Fee Surface (Circle K Ranch) Fee Minerals

Anita Kiahtipes Family Limited Partnership (same as Circle K) PO Box 700 Price, Utah 84501 Dino: 435-650-0039

James N. & Jeanne P Marres P O Box 1005 Price, UT 84501-1005 Jim Marrs Realty Services PO Box 1005 Price, UT 84501 (435) 636-8824


4 Wellington Fee 23-23 Section 23 T14S R10E 1837’ FSL 1899’ FWL NE/4 SW/4 Fee Surface (Lynda Varner) Fee Minerals

Lynda Varner, et al PO Box 866 Price, Utah 84501 Dave Varner: 435-630-1182


Note: The 12-23 pipeline ties into this line, then crosses the road to the north and continues to the 14-14 and 12-14.

5 Wellington Fee 34-25 Section 25 T14S R10E 625’ FSL 2678’ FEL SW/4 SE/4 Fee (Shimmons) / Federal Surface Fee Minerals

Donna Shimmon Perry Trst. 207 W 1400 N American Fork, UT 84003-3732 Phone 801-763-8862 Attorney: Cell: 801-836-7597 Office: 801-562-8888

Ms. Karla Rhodes PO Box 145 Wellington, UT 84542-0145 Phone: 435-650-5229

Multiple landowners Well = Flintstone Rock/Shimmons &/or Jimmy Jay Joregensen; then Shimmons, Rhodes, BLM, ending on Verdis Barker

6

Wellington Fee 41-26 Section 26 T14S R10E 572’ FNL 1117’ FEL NE/4 NE/4 Fee Surface (Verdis Barker) Fee Minerals


same same

Returned Unapproved

TABLE 4Surface Ownership Information

Well Pad, Pipelines, Access RoadsWell Name Pipeline/Landowner (1) Pipeline/Landowner (2) Landowner

1 Wellington Fee 12-23 Lynda Varner, et al Ralph C. Keele, Jr. Leona F Leautaud TrustSection 23 Tl4S Rl0E PO Box 866 117 S 400 E c/o Jack Leautaud1680' FNL 1280' FWL Price, Utah 84501 Price, UT 84501 1771 E 300 SSW/4 NW/4 Dave Varner: 435-630-1182 &/or Denis Merrelli Price, UT 84501Fee Surface (Lynda Varner) PO Box 833 Jack Leautaud, Cell: 435-636-5966Fee Minerals Price, UT 84501-0833

2 Wellington Fee 13-25 Verdis L. Barker & Pauline R. Barker Same SameSection 25 Tl4S Rl0E Trust1481' FSL 534' FWL 1400 S 3250 ENW/4 SW/4 Price, UT 84501Fee Surface (Verdis Barker) 435-637-3417 or 435-637-0538Fee Minerals

3 Wellington Fee 21-26 Anita Kiahtipes Family Limited James N. & Jeanne P Marres Verdis L. Barker & Pauline R.Section 26 Tl4S Rl0E Partnership (same as Circle K) PO Box 1005 Barker Trust1066' FNL 1608' FWL PO Box 700 Price, UT 84501-1005 1400 S 3250 ENE/4 NW/4 Price, Utah 84501 Jim Marrs Realty Services Price, UT 84501Fee Surface (Circle K Ranch) Dino: 435-650-0039 PO Box 1005 435-637-3417 or 435-637-0538Fee Minerals Price, UT 84501

(435) 636-88244 Wellington Fee 23-23 Lynda Varner, et al Verdis L. Barker & Pauline R. Barker Note: The 12-23 pipeline ties into

Section 23 Tl4S Rl0E PO Box 866 Trust this line, then crosses the road to1837' FSL 1899' FWL Price, Utah 84501 1400 S 3250 E the north and continues to the 14-14NE/4 SW/4 Dave Varner: 435-630-1182 Price, UT 84501 and 12-14.Fee Surface (Lynda Varner) 435-637-3417 or 435-637-0538Fee Minerals

5 Wellington Fee 34-25 Donna Shimmon Perry Trst. Ms. Karla Rhodes Multiple landownersSection 25 Tl4S Rl0E 207 W 1400 N PO Box 145 Well = Flintstone Rock/Shimmons625' FSL 2678' FEL American Fork, UT 84003-3732 Wellington, UT 84542-0145 &/or Jimmy Jay Joregensen; thenSW/4 SE/4 Phone 801-763-8862 Phone: 435-650-5229 Shimmons, Rhodes, BLM, endingFee (Shimmons) / Federal Surface Attorney: Cell: 801-836-7597 on Verdis BarkerFee Minerals Office: 801-562-8888

6 Wellington Fee 41-26 Verdis L. Barker & Pauline R. Barker same sameSection 26 Tl4S Rl0E Trust572' FNL 1117' FEL 1400 S 3250 ENE/4 NE/4 Price, UT 84501Fee Surface (Verdis Barker) 435-637-3417 or 435-637-0538Fee

K. Other Information:

A Class I literature review is being conducted by SWCA Environmental Consultants (SWCA). A report will be submitted upon completion.

A paleontological reconnaissance survey, if needed, will be conducted by SWCA, and a report will be provided under separate cover.

Returned Unapproved

K. Other Information:

A Class I literature review is being conducted by SWCA Environmental Consultants (SWCA). A reportwill be submitted upon completion.

A paleontological reconnaissance survey, if needed, will be conducted by SWCA, and a report will beprovided under separate

Returned Unapproved


L. Lessee's or Operators' Representative & Certification:

Kathy Schneebeck Dulnoan Tommy ThompsonStaff Regulatory Analyst General Manager, DrillingKerr-McGee Oil & Gas Onshore LP Kerr-McGee Oil & Gas Onshore LPPO Box 173779 PO Box 173779Denver, CO 80217-3779 Denver, CO 80217-3779(720) 929-6007 (720) 929-6724

Certification: All lease and/or unit operations will be conducted in such a manner that full compliance ismade with all applicable state and Federal laws, regulations, Onshore Oil and Gas Orders, the approvedPlan of Operations, and any applicable Notice to Lessees.

The Operator will be fully responsible for the actions of its subcontractors. A complete copy of theapproved "Application for Permit to Drill" will be furnished to the field representative(s) to ensurecompliance and shall be on location during all construction and drilling operations.

Kerr-McGee Oil & Gas Onshore LP is considered to be the operator of the subject well. Kerr-McGee Oil& Gas Onshore LP agrees to be responsible under terms and conditions of the lease for the operationsconducted upon leased lands.

Bond coverage for State lease activities is provided by State Surety Bond 22013542, and for applicableFederal lease activities and pursuant to 43 CFR 3104, by Bureau of Land Management Nationwide BondWYB000291.

I hereby certify that I, or persons under my supervision, have inspected the proposed drill site and accessroute, that I am familiar with the conditions that currently exist; that I have full knowledge of the State andFederal laws applicable to this operation; that the statements made in this plan are, to the best of myknowledge, true and correct; and the work associated with the operations proposed herein will beperformed in conformity with this APD package and the terms and conditions under which it is approved. Ialso certify that I, or the company I represent, am responsible for operations conducted under this application.These statements are subject to the provisions of 18 U.S.C. 1001 for the filing of false statements.

January 13, 2011

Kath Schneebeck Dulnoan DateStaff Regulatory AnalystKerr-McGee Oil & Gas Onshore

ª

*

*

*

*

H

H

!

!

!

!Wellington Fee 41-26 4300750115

Wellington Fee 23-23 4300750113



WELLINGTON FED 31-23 4300750019

D AMBROSIO 27-866 4300731426





BAWDEN 1 4300730092

H E L P E R F I E L DH E L P E R F I E L D

D R U N K A R D S W A S H F I E L DD R U N K A R D S W A S H F I E L D

2322

1415

24

2627

13

25

T 14 S R 10 E

Map Produced by Diana MasonMap Prepared:

Well Name: Wellington Fee 12-23API Number: 4300750110

Township 14.0 S Section 23Range 10.0 EMeridian: SLBM

F1,400 0 1,400700 Feet

1:13,324

UnitsSTATUS

ACTIVE

EXPLORATORY

GAS STORAGE

NF PP OIL

NF SECONDARY

PI OIL

PP GAS

PP GEOTHERML

PP OIL

SECONDARY

TERMINATED

FieldsSTATUS

Unknown

ABANDONED

ACTIVE

COMBINED

INACTIVE

STORAGE

TERMINATED

Sections

Township

Wells QueryStatus

APD - Aproved Permit

H DRL - Spuded (Drilling Commenced)

4 GIW - Gas Injection

!* GS - Gas Storage

N LA - Location Abandoned

! LOC - New Location

7 OPS - Operation Suspended

ª PA - Plugged Abandoned

* PGW - Producing Gas Well

' POW - Producing Oil Well

O RET - Returned APD

¸ 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

Tooele

Millard

Iron

San Juan

Kane

Juab

Uintah

Box Elder

Emery

Garfield

Grand

Utah

Beaver Wayne

Duchesne

Sevier

Summit

Rich

Washington

Carbon

Sanpete

Cache

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Location Map

Operator: KERR-MCGEE OIL & GAS ONSHORE, L.P.

Returned Unapproved

API Number: 4300750110Well Name: Wellington Fee 12-23

Township 14.0 S Range 10.0 E Section 23Meridian: SLBM

Operator: KERR-MCGEE OIL & GAS ONSHORE, L.P.

Map Prepared:

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June 12, 2013

KERR-MCGEE OIL & GASONSHORE, L.P.P.O. Box 173779Denver, CO 80217

Re: Application for Permit to Drill - CARBON County, Utah

Ladies and Gentlemen:

The Application for Permit to Drill (APD) for the Wellington Fee12-23 well , API 43007501100000 that was submitted January 16,2011 is being returned unapproved. If you plan on drill ing this wellin the future, you must f irst submit a new application.

Should you have any questions regarding this matter, please call meat (801) 538-5312.

Sincerely,

Diana Mason

Environmental Scientist

Enclosure

cc: Bureau of Land Management, Vernal, Utah

State of UtahDEPARTMENT OF NATURAL RESOURCES

- MICHAEL R. STYLER

GAR R HERT Exoutnw Drotor

muror Division of Oil, Gas and MiningGREGORY S. BELL JOHN R. BAZALieuterunt Gorrnor Dumon Drector

June 12, 2013

KERR-MCGEE OIL & GASONSHORE, L.P.P.O. Box 173779Denver, CO 80217

Re: Application for Permit to Drill - CARBON County, Utah

Ladies and Gentlemen:

The Application for Permit to Drill (APD) for the Wellington Fee12-23 well, API 43007501100000 that was submitted January 16,2011 is being returned unapproved. If you plan on drilling this wellin the future, you must first submit a new application.

Should you have any questions regarding this matter, please call meat (801) 538-5312.

Sincerely,

Diana MasonEnvironmental Scientist

Enclosurecc: Bureau of Land Management, Vernal, Utah

UTAN

DNR

1594 West II.:rth Temple. Suite 121I:I.P¯B.:e 1458I:I1. Salt Lake City, UT 84114-SSI:I1

teleph.:.ne (31.11)533-534I.I•facsimile (31.11)359-3941.1.TTY (31.11)533-7453. www.ogm.utah.gov or Gas

Documents

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