oo O O B Wellington, Utah P.O. Box12-1/4" 8-5/8" ST&C 32# 2,000' Lead, 219 sks, tail, 100 sks top attached Drilling Plan 5-1/2" 17# 9,200' Lead, 435 sks Tai see attached Drilling is

oo2 O OB P.O. Box 164

Wellington, Utah 84542

Env i ronment a l Consult a nts435/637-4075 435/637-4073 Fax

December 13, 2004

Fluid Minerals GroupBureau of Land ManagementVernal Field Office170 South 500 EastVernal, Utah 84078

RE: Application for Permit to Drill-Dominion Exploration & Production, Inc.LCU 6-6G, 2,019' FNL, 1,596' FWL, SE/4 NW/4Section/, TllS, R21E, SLB&M, Uintah County, Utah

Dear Fluid Minerals Group:

On behalf of Dominion Exploration & Production, Inc. (Dominion), Buys & Associates, Inc. respectfully sub-

mits the enclosed original and two copies of the Application forPermit to Drill (APD) for the above referencedwell. Included with the APD is the following supplemental information:

Exhibit "A" - Survey plats, layouts and photos of the proposed well site;

Exhibit "B" - Proposed location maps with access and utility corridors;

Exhibit "C" - Production site layout;

Exhibit "D" - Drilling Plan;

Exhibit "E" - Surface Use Plan;

Exhibit "F" - Typical BOP and Choke Manifold diagram.

Please accept this letter as Dominion's, written request for confidential treatment of all information contained inand pertaining to this application.

Thank you very much for your timely consideration of this application. Please feel free to contact myself orCarla Christian of Dominion at 405-749-5263 if you have any questions or need additional information.

Sincerely,

D- ÑA RECEIVEDDon Hamilton

Agent for Dominion DEC17mcc: Diana Whitney, Division of Oil, Gas and Mining OlV.OFOlL,GAS&MINING

Carla Christian, DominionMarty Buys, Buys & Associates, Inc.

FILECOPY

oo2 O OB P.O. Box 164

Wellington, Utah 84542

Env i ronment a l Consult a nts435/637-4075 435/637-4073 Fax

December 13, 2004

Fluid Minerals GroupBureau of Land ManagementVernal Field Office170 South 500 EastVernal, Utah 84078

RE: Application for Permit to Drill-Dominion Exploration & Production, Inc.LCU 6-6G, 2,019' FNL, 1,596' FWL, SE/4 NW/4Section/, TllS, R21E, SLB&M, Uintah County, Utah

Dear Fluid Minerals Group:

On behalf of Dominion Exploration & Production, Inc. (Dominion), Buys & Associates, Inc. respectfully sub-

mits the enclosed original and two copies of the Application forPermit to Drill (APD) for the above referencedwell. Included with the APD is the following supplemental information:

Exhibit "A" - Survey plats, layouts and photos of the proposed well site;

Exhibit "B" - Proposed location maps with access and utility corridors;

Exhibit "C" - Production site layout;

Exhibit "D" - Drilling Plan;

Exhibit "E" - Surface Use Plan;

Exhibit "F" - Typical BOP and Choke Manifold diagram.

Please accept this letter as Dominion's, written request for confidential treatment of all information contained inand pertaining to this application.

Thank you very much for your timely consideration of this application. Please feel free to contact myself orCarla Christian of Dominion at 405-749-5263 if you have any questions or need additional information.

Sincerely,

D- ÑA RECEIVEDDon Hamilton

Agent for Dominion DEC17mcc: Diana Whitney, Division of Oil, Gas and Mining OlV.OFOlL,GAS&MINING

Carla Christian, DominionMarty Buys, Buys & Associates, Inc.

FILECOPY

Fopn 3160-3 SUBMIT IN ATE* Form approved.

(December 1990) (Other insuuctions BudgetBureau No. 1004-0136

UNITED STATES reverse side) Expires: December 31, 1991

DEPARTMENT OF THE INTERIOR 5 LEASE DESIGNATION AND SERIAL NO.

BUREAU OF LAND MANAGEMENT UTU-75700

APPLICATION FOR PERMIT TO DRILL OR DEEPEN 6 IFINDRN,AŒOTTEEORTRIBENAME

N/Ala TYPEOFWORK

O 7 UNIT AGREEMENT NAME

DRILL DEEPENb TYPE OF WELLOIL GAS SINGLE MULTIPLE 8 FARM OR LEASE NAME WELL NO.

WE OWR ZOW ZONE O LCU 6-6G2. NAME OF OPERATOR 9 APl WELL NO

Dominion Exploration & Production, Inc.3. ADDRESS AND TELEPHONE NO. 10. FIELD AND POOL, OR WILDCAT

14000 QuailSprings Parkway, Suite 600, Oklahoma City, OK 73134, 405-749-5263 9*- **= (g4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.*)

A I 2/, 757 39. F Ÿ/ / 3 SEC.,T.,lt,M, OR BLK.

At proposed prod.zoo2,019' FNL, 1,596' FWL SE/4 NW/4 yt ¡ ¿py¿, Section 6,

2,019' FNL. 1,596' FWL SE/4 NW/4 TI IS. R21E. SLB&M14.. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. COUNTY OR PARISH 13. STATE

14.06 miles southeast of Ouray, Utah Uintah Utab15. DISTANCE FROM PROPOSED* 16. NO. OF ACRES IN LEASE 17 NO OF ACRES ASSIGNED

LOCATION TO NEAREST TO THIS WELL

PROPERTY OR LEASE LlNE, FT.(Also to neard drjg. unit line, ifuy) 623' 298.33 40 acres

18 DISTANCE FROM PROPOSED 19. PROPOSEDDEFTH 20 ROTARY OR CABLE TOOLS

LOCATION TO NEAREST WELL,DR1LLING, COMPLETED, ORAPPLIED FOR, ON THIS LEASEFT None 9,200' Rotary

2L ELEVATIONS (Show whether DF,RT,GR,etc) 22. APPROX DATE WORK WILL START*

5.414' GR March 15, 200523. PROPOSED CASING AND CEMENTING PROGRAM

SIZE OF HOLE GRADE, SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH QUANTITY OF CEMENT

12-1/4" 8-5/8" J-55 ST&C 32# 2,000' 252 sks Lead, 219 sks, tail, 100 sks top out-see attached Drilling Plan

7-7/8" 5-1/2" Mav 80 LT&C 17# 9,200' 160 sks Lead, 435 sks Tai see attached Drilling Plan

Bond Information:Bond coverage is provided by Travelers Casualty and Surety Company of America, Bond #76S 63050 0330

Other Information:Drilling Plan and Surface Use Plan are attached.Dominion requests that this complete application for permit to drill be held confidential.

RECElVEDFederalApprovalofihie

AcuonisHacessary * DEC1 / 2004DNOFOIL,GAS&MINING TOf gg

IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deeper give data present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give

pertinent data on subsurfacelocations and measured and true vertical depths. Give blowout preventer program, if any.

24.

sie Don Hamilton RE Agent for DominioD DATE December 13, 2004

(This space for Federal or State office use)

PERMIT NO OR $ Q Ê .g

APPROVALDATE

Application does not warrant or the applicant holds legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon.CONDITIONS ANY:

BRADLEYG.HILLAPPROVED BY TITLE DATE

*See Instructions On Reverse SideTitle 18 U.S.C. Section 1001, makes it a crime for any person knowingly and willfully to make to any department or agency or

Fopn 3160-3 SUBMIT IN ATE* Form approved.

(December 1990)(Other insuuctions BudgetBureau No. 1004-0136

UNITED STATES reverse side) Expires: December 31, 1991

DEPARTMENT OF THE INTERIOR 5 LEASE DESIGNATION AND SERIAL NO.


APPLICATION FOR PERMIT TO DRILL OR DEEPEN 6 IFINDRN,AŒOTTEEORTRIBENAME

N/Ala TYPEOFWORK

O 7 UNIT AGREEMENT NAME

DRILL DEEPENb TYPE OF WELLOIL GAS SINGLE MULTIPLE 8 FARM OR LEASE NAME WELL NO.

WE OWR ZOW ZONE O LCU 6-6G2. NAME OF OPERATOR 9 APl WELL NO

Dominion Exploration & Production, Inc.3. ADDRESS AND TELEPHONE NO. 10. FIELD AND POOL, OR WILDCAT

14000 QuailSprings Parkway, Suite 600, Oklahoma City, OK 73134, 405-749-5263 9*- **= (g4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.*)

A I 2/, 757 39. F Ÿ/ / 3 SEC.,T.,lt,M, OR BLK.

At proposed prod.zoo2,019' FNL, 1,596' FWL SE/4 NW/4 yt ¡ ¿py¿, Section 6,

2,019' FNL. 1,596' FWL SE/4 NW/4 TI IS. R21E. SLB&M14.. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 12. COUNTY OR PARISH 13. STATE

14.06 miles southeast of Ouray, Utah Uintah Utab15. DISTANCE FROM PROPOSED* 16. NO. OF ACRES IN LEASE 17 NO OF ACRES ASSIGNED

LOCATION TO NEAREST TO THIS WELL

PROPERTY OR LEASE LlNE, FT.(Also to neard drjg. unit line, ifuy) 623' 298.33 40 acres

18 DISTANCE FROM PROPOSED 19. PROPOSEDDEFTH 20 ROTARY OR CABLE TOOLS

LOCATION TO NEAREST WELL,DR1LLING, COMPLETED, ORAPPLIED FOR, ON THIS LEASEFT None 9,200' Rotary

2L ELEVATIONS (Show whether DF,RT,GR,etc) 22. APPROX DATE WORK WILL START*

5.414' GR March 15, 200523. PROPOSED CASING AND CEMENTING PROGRAM

SIZE OF HOLE GRADE, SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH QUANTITY OF CEMENT


7-7/8" 5-1/2" Mav 80 LT&C 17# 9,200' 160 sks Lead, 435 sks Tai see attached Drilling Plan

Bond Information:Bond coverage is provided by Travelers Casualty and Surety Company of America, Bond #76S 63050 0330

Other Information:Drilling Plan and Surface Use Plan are attached.Dominion requests that this complete application for permit to drill be held confidential.

RECElVEDFederalApprovalofihie

AcuonisHacessary * DEC1 / 2004DNOFOIL,GAS&MINING TOf gg

IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deeper give data present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give

pertinent data on subsurfacelocations and measured and true vertical depths. Give blowout preventer program, if any.

24.

sie Don Hamilton RE Agent for DominioD DATE December 13, 2004


PERMIT NO OR $ Q Ê .g

APPROVALDATE

Application does not warrant or the applicant holds legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon.CONDITIONS ANY:

BRADLEYG.HILLAPPROVED BY TITLE DATE


TiiS, R2iE, S.L.B.&M. DOMINION EXPLR. & PROD., INC.Well location, LCU fj6--6G, located as shown

SB9°54'00"W- SB Sf2JT -

çNN89W°51'28"E- 2672.06'

AS -N89°37'E

_

in the SE 1/4 NW 1/4 of Section & T11S,ts4s.or fueos.) 1336.89' (Meas.) 20.32' (G.L.O.) iTiOS 20.17' (G.L.O.) - 939.84' (G.LO.) R21E, S.L.B.&M. Uintah County Utah.

o towest cor. see.see TiŒ pa oss/co BASIS OF ELEVATION36 T/OS, R20E 1928 PHe of Stones 2 ss Cap'

Stones, Set MarkedBrosse ta'High' piteorston° * stone SPOT ELEVATIONAT THE SOUTHWEST CORNER OF SECTION20, T10S, R20E, S.L.B.&M. TAKEN FROM THE BIG PACKLOT 4 LOT J LOT 2 LOT 1 MTN. NW QUADRANGLE,UTAH, UlNTAH COUNTY, 7.5 MINUTEQUAD. (TOPOGRAPHIC MAP)PUBLISHED BY THE UNITEDSTATES DEPARTMENT OF TNE INTERIOR, GEOLOGICALSURVEY. SAID ELEVATIONIS MARKED AS BElNG 5251 FEET.

---

BASIS OF BEARINGSBASIS OF BEARINGS IS A G.P.S. OBSERVATION.

LOT 5 c

Elev. Ungraded Ground 5414'N

Set Marked Stone1.4' High, Pile ofStones

R R20 21 LOT 6 -o

EE

1----

ICATE -

THIS IS TO CERTlFY TH VE S ED FROMFIELD NOTES OF ACTUS NE O ER MYSUPERVISIONAND THA UE ANDC ECT TO THBEST OF MY KNOWLEDGND BELIE

LOT 7

SURVEYSet Marked Stones REGISTRATIONNO. 161Prie or stones

LLN89 39'E - 4954.62' (G.L.O.)

sTATEOF UTAH

UNTAH ENGDŒERlhG & LAño SURVEYlNGBASIS OF BEARINGS85 SOUTH ß00 EAST - VERNAL, UTAH 84078BASIS OF BEARINGS IS A 0.P.S. OBSERVATION.

(435) 789-1017LEGEND: (NAD 83)SCALE DATESURVEYED: DATEDRAWN:LATITUDE= 39 53'27.95" (39.891097) 1" = 1000' 9--21-04 9-23-04=

90° SYMBOL LONGITUDE= 109°36'45.42" (109.612617) PARTY REFERENCES= PROPOSED WELL HEAD. (NAD 27) M.A. W.L. K.G. G.L.O. PLATLAT1TUDE= 39°53'28.07" (38.891131) WEATHER FILEA = SECTIONCORNERSLOCATED.LONGITUDE= 109°36'42.94" (109.611928) WARM DOMINIONEXPLR. & PROD.,

TiiS, R2iE, S.L.B.&M. DOMINION EXPLR. & PROD., INC.Well location, LCU fj6--6G, located as shown

SB9°54'00"W- SB Sf2JT -

çNN89W°51'28"E- 2672.06'

AS -N89°37'E

_

in the SE 1/4 NW 1/4 of Section & T11S,ts4s.or fueos.) 1336.89' (Meas.) 20.32' (G.L.O.) iTiOS 20.17' (G.L.O.) - 939.84' (G.LO.) R21E, S.L.B.&M. Uintah County Utah.

o towest cor. see.see TiŒ pa oss/co BASIS OF ELEVATION36 T/OS, R20E 1928 PHe of Stones 2 ss Cap'

Stones, Set MarkedBrosse ta'High' piteorston° * stone SPOT ELEVATIONAT THE SOUTHWEST CORNER OF SECTION20, T10S, R20E, S.L.B.&M. TAKEN FROM THE BIG PACKLOT 4 LOT J LOT 2 LOT 1 MTN. NW QUADRANGLE,UTAH, UlNTAH COUNTY, 7.5 MINUTEQUAD. (TOPOGRAPHIC MAP)PUBLISHED BY THE UNITEDSTATES DEPARTMENT OF TNE INTERIOR, GEOLOGICALSURVEY. SAID ELEVATIONIS MARKED AS BElNG 5251 FEET.

---

BASIS OF BEARINGSBASIS OF BEARINGS IS A G.P.S. OBSERVATION.

LOT 5 c

Elev. Ungraded Ground 5414'N

Set Marked Stone1.4' High, Pile ofStones

R R20 21 LOT 6 -o

EE

1----

ICATE -

THIS IS TO CERTlFY TH VE S ED FROMFIELD NOTES OF ACTUS NE O ER MYSUPERVISIONAND THA UE ANDC ECT TO THBEST OF MY KNOWLEDGND BELIE

LOT 7

SURVEYSet Marked Stones REGISTRATIONNO. 161Prie or stones

LLN89 39'E - 4954.62' (G.L.O.)

sTATEOF UTAH

UNTAH ENGDŒERlhG & LAño SURVEYlNGBASIS OF BEARINGS85 SOUTH ß00 EAST - VERNAL, UTAH 84078BASIS OF BEARINGS IS A 0.P.S. OBSERVATION.

(435) 789-1017LEGEND: (NAD 83)SCALE DATESURVEYED: DATEDRAWN:LATITUDE= 39 53'27.95" (39.891097) 1" = 1000' 9--21-04 9-23-04=

90° SYMBOL LONGITUDE= 109°36'45.42" (109.612617) PARTY REFERENCES= PROPOSED WELL HEAD. (NAD 27) M.A. W.L. K.G. G.L.O. PLATLAT1TUDE= 39°53'28.07" (38.891131) WEATHER FILEA = SECTIONCORNERSLOCATED.LONGITUDE= 109°36'42.94" (109.611928) WARM DOMINIONEXPLR. & PROD.,

DRILLING PLAN

APPROVAL OF OPERATIONS

Attachment for Permit to Drill

Name of Operator: Dominion Exploration & ProductionAddress: 14000 QuailSprings Parkway, Suite 600

Oklahoma City, OK 73134Well Location: LCU 6-6G

2019 FNL & 1596' FWLSection 6-11S-2]EUintah County, UT

1. GEOLOGIC SURFACE FORMATION Uintah

2. ESTIMATED DEPTHS OF IMPORTANT GEOLOGIC MARKERS

Formation Depth

Green River 79TWasatach Tongue 3,692'Green River Tongue 4.022'Wasatch 4.147'Chapita Wells 5.00TUteland Buttes 6.207'Mesaverde 7,.032'

3. ESTIMATED DEPTHS OF ANTICIPATED WATER. OIL, GAS OR MINERALS

Formation Death Tygg

Green River 797' OilWasatch Tongue 3.692' OilGreen River Tongue 4,022' OilWasatch 4,14T GasChapita Wells 5,00T GasUteland Buttes 6.20T GasMesaverde 7,032' Gas

4. PROPOSED CASING PROGRAM

All casing used to drill this well will be new casing.

T-1pe Bjze Weicht Grade Conn. T Bottom IIglg

Surface 8-5/8" 32.0 ppf J-55 STC O' 2,000' 12-1/4"

Production 5-1/2" 17.0 ppf MAV-80 LTC 0' 9,200' 7-7/8"

Note: The drilled depth of the surface hole and the setting depth of the surface casing may vary from 1,700' to 2,000'.

Should a lost circulation zone be encountered while drilling, casing will be set approximately 300' below the lost

circulation zone. If no lost circulation zone is encountered, casing to be set at 2,000'±.

DRILLING PLAN


Attachment for Permit to Drill



2019 FNL & 1596' FWL

Section 6-11S-2]EUintah County, UT

1. GEOLOGIC SURFACE FORMATION Uintah

2. ESTIMATED DEPTHS OF IMPORTANT GEOLOGIC MARKERS

Formation Depth

Green River 79TWasatach Tongue 3,692'Green River Tongue 4.022'Wasatch 4.147'Chapita Wells 5.00T

Uteland Buttes 6.207'Mesaverde 7,.032'

3. ESTIMATED DEPTHS OF ANTICIPATED WATER. OIL, GAS OR MINERALS

Formation Death Tygg

Green River 797' OilWasatch Tongue 3.692' OilGreen River Tongue 4,022' OilWasatch 4,14T GasChapita Wells 5,00T GasUteland Buttes 6.20T GasMesaverde 7,032' Gas

4. PROPOSED CASING PROGRAM

All casing used to drill this well will be new casing.

T-1pe Bjze Weicht Grade Conn. T Bottom IIglg

Surface 8-5/8" 32.0 ppf J-55 STC O' 2,000' 12-1/4"

Production 5-1/2" 17.0 ppf MAV-80 LTC 0' 9,200' 7-7/8"

Note: The drilled depth of the surface hole and the setting depth of the surface casing may vary from 1,700' to 2,000'.

Should a lost circulation zone be encountered while drilling, casing will be set approximately 300' below the lost

circulation zone. If no lost circulation zone is encountered, casing to be set at 2,000'±.

O ODRILLING PLAN


5. OPERATOR'S MINIMUM SPECIFICATIONS FOR PRESSURE CONTROL

Surface hole: No BOPE will be utilized. Air foam mist, rotating head and diverter system will be utilized.

Production hole: Prior to drilling out the surface casing shoe, 3,000 psi or greater BOP equipment will be installed. The

pipe rams will be operated at least once per day from intermediate casing to total depth. The blind rams will be tested once

per day from intermediate casing to total depth if operations permit.

A diagram of the planned BOP equipment for normal drilling operations in this area is attached. As denoted there will be

two valves and one check valve on the kill line, two valves on the choke line, and two adjustable chokes on the manifold

system. The BOP "stack" will consist of two BOP rams (1 pipe, 1 blind) and one annular type preventer, all rated to a

minimum of 3,000 psi working pressure.

The BOP equipment will be pressure tested prior to drilling below the intermediate casing shoe. All test pressures will be

maintained for fifteen (15) minutes without any significant pressure decrease. Clear water will be circulated into the BOP

stack and lines prior to pressure testing. The following test pressures will be used as a minimum for various equipment

items.

1. Annular BOP 1,500 psi

2. Ram type BOP 3,000 psi3. Kill line valves 3,000 psi4. Choke line valves and choke manifold valves 3,000 psi5. Chokes 3,000 psi6. Casing, casinghead & weld 1,500 psi7. Upper kelly cock and safety valve 3,000 psi

8. Dart valve 3,000 psi

6. MUD SYSTEMS• An air or an air/mist system may be used to drill to drill the surface hole until water influx becomes too great.• KCL mud system will be used to drill well.

Depths Mud Weight (ppel Mud SystemO' - 2,000' 8.4 Air foam mist, rotating head and diverter

2,000' -9,200'8.6 Fresh water/2%KCL/KCL mud system

7. BLOOIE LINE• An automatic igniter will not be installed on blooie line. The blooie will have a contant ignition source.

• A "target tee" connection will be installed on blooie line for 90° change of directions for abrasion resistance.

• "Target tee" connections will be a minimum of 50' from wellhead.• The blooie line discharge will be a minimum of 100' from the wellhead.

8. AUXILIARY EQUIPMENT TO BE USEDa. Kelly cock.b. Full opening valve with drill pipe connection will be kept on floor. Valve will be used when the kelly is not in string.

9. TESTING. LOGGING, AND CORING PROGRAMS TO BE FOLLOWED• A drillstem test in the Wasatch Tongue is possible.• One electric line wire-log will be run from total depth to surface casing.• The gamma ray will be left on to record from total depth to surface casing.• Other log curves (resistivities, porosity, and caliper) will record from total depth to surince casing.• A dipmeter, percussion cores, or rotary cores may be run over selected intervals.

10. ANTICIPATED ABNORMAL PRESSURES OR TEMPERATURES EXPECTED• Expected BHP 1,500-2,000 psi (lower than normal pressure gradient).• No abnormal temperature or pressures are anticipated.• The formations to be penetrated do not contain known H2S gas.

O ODRILLING PLAN


5. OPERATOR'S MINIMUM SPECIFICATIONS FOR PRESSURE CONTROL

Surface hole: No BOPE will be utilized. Air foam mist, rotating head and diverter system will be utilized.

Production hole: Prior to drilling out the surface casing shoe, 3,000 psi or greater BOP equipment will be installed. The

pipe rams will be operated at least once per day from intermediate casing to total depth. The blind rams will be tested once

per day from intermediate casing to total depth if operations permit.

A diagram of the planned BOP equipment for normal drilling operations in this area is attached. As denoted there will be

two valves and one check valve on the kill line, two valves on the choke line, and two adjustable chokes on the manifold

system. The BOP "stack" will consist of two BOP rams (1 pipe, 1 blind) and one annular type preventer, all rated to a

minimum of 3,000 psi working pressure.

The BOP equipment will be pressure tested prior to drilling below the intermediate casing shoe. All test pressures will be

maintained for fifteen (15) minutes without any significant pressure decrease. Clear water will be circulated into the BOP

stack and lines prior to pressure testing. The following test pressures will be used as a minimum for various equipment

items.

1. Annular BOP 1,500 psi

2. Ram type BOP 3,000 psi

3. Kill line valves 3,000 psi

4. Choke line valves and choke manifold valves 3,000 psi5. Chokes 3,000 psi

6. Casing, casinghead & weld 1,500 psi7. Upper kelly cock and safety valve 3,000 psi

8. Dart valve 3,000 psi

6. MUD SYSTEMS• An air or an air/mist system may be used to drill to drill the surface hole until water influx becomes too great.• KCL mud system will be used to drill well.

Depths Mud Weight (ppel Mud SystemO' - 2,000' 8.4 Air foam mist, rotating head and diverter

2,000' -9,200'8.6 Fresh water/2%KCL/KCL mud system

7. BLOOIE LINE• An automatic igniter will not be installed on blooie line. The blooie will have a contant ignition source.

• A "target tee" connection will be installed on blooie line for 90° change of directions for abrasion resistance.

• "Target tee" connections will be a minimum of 50' from wellhead.

• The blooie line discharge will be a minimum of 100' from the wellhead.

8. AUXILIARY EQUIPMENT TO BE USEDa. Kelly cock.b. Full opening valve with drill pipe connection will be kept on floor. Valve will be used when the kelly is not in string.

9. TESTING. LOGGING, AND CORING PROGRAMS TO BE FOLLOWED• A drillstem test in the Wasatch Tongue is possible.• One electric line wire-log will be run from total depth to surface casing.• The gamma ray will be left on to record from total depth to surface casing.• Other log curves (resistivities, porosity, and caliper) will record from total depth to surince casing.• A dipmeter, percussion cores, or rotary cores may be run over selected intervals.

10. ANTICIPATED ABNORMAL PRESSURES OR TEMPERATURES EXPECTED• Expected BHP 1,500-2,000 psi (lower than normal pressure gradient).• No abnormal temperature or pressures are anticipated.• The formations to be penetrated do not contain known H2S gas.

O ODRILLING PLAN


11. WATER SUPPLY• No water pipelines will be laid for this well.• No water well will be drilled for this well.• Drilling water for this will be hauled on the road(s) shown in Attachment No. 3.

• Water will be hauled from: Water Permit # 43-10447 Section 9. Township 8 South. Range 20 East

12. CEMENTSYSTEMS

a. Surface Cement:• Drill 12-1/4" hole to 2,000'±, run and cement 8-5/8" to surface (depth to vary based on depth of lost circulation

zone).• Pump 20 bbls lightly weighted water spacer followed by 5 bbls fresh water. Displace with any available water.

• Casing to be run with: a) guide shoe b) insert float c) three (3) centralizers, one on each of first 3 jointsd) stop ring

for plug two joints off bottom e) bottom three joints thread locked f) pump jobwith bottom plug only.

• Cement the casing annulus to surface. Top out jobs to be performed if needed. Depending to depth of top of

cement in the annulus, a 1" tubing string may or may not be utilized.Hol_e Cement

Tyge Sac_11s Interval Density Yi.el_d Volume Volume Excess

Lead 252 O'-1,500' 11.0 ppg 3.82 CFS 619 CF 835 CF 35%

Tail 219 1,500'-2,000' 15.6 ppg 1.18 CFS 220 CF 297 CF 35%

Top Out 100 O'-200' 15.6 ppg 1.18 CFS 95 CF 118 CF 24% (if required)

Lead Mix: Premium Plus V blend. Blend includes Class "G" cement, gel, salt, gilsonite.Slurry yield: 3.82 cf/sack Slurry weight: 11.00#/gal.Water requirement: 22.95 gallsack

Tail Mix: Class "G" Cement, 1/4 lb/sk Cellophane Flakes + 2% bwoc Calcium Chloride + 44.3% fresh water.

Slurry yield: 1.18 cf/sack Slurry weight: 15.60 #/gal.Water requirement: 5.2 gal/sack

Top Out: Class "G" Cement, 1/4 lb/sk Cellophane Flakes + 2% bwoc Calcium Chloride + 44.3% fresh water.


c. Production Casing Cement:• Drill 7-7/8" hole to 9,200'±, run and cement 5 1/2".• Cement interface is at 4,000', which is typically 500'-l,000' above shallowest pay.• Pump 20 bbl Mud Clean II unweighted spacer, followed by 20 Bbls fresh H20 spacer.• Displace with 3% KCL.

H_ple Cement

Tyge Sacks Interval Density M Volume Volume Excess

Lead 160 3,700'-4,700' 11.5 ppg 3.12 CFS 175 CF 350 CF 100%

Tail 435 4,700'-9,200' 13.0 ppg 1.75 CFS 473 CF 946 CF 100%

Note: A caliper log will be ran to determine cement volume requirements.

Lead Mix: Halliburton Prem Plus V blend. Blend includes Class "C" cement, gel, salt, gilsonite, EX-1 and HR-7.

Slurry yield: 3.12 cf/sack Slurry weight: 11.60 #/gal.Water requirement: 17.71 gallsackCompressives @130 F: 157 psi after 24 hours

Tail Mix: Halliburton HLC blend (Prem Plus VIJB flyash). Blend includes Class "G" cement, KC1,EX-1, Halad 322,

& HR-5.Slurry yield: 1.75 cf/sack Slurry weight: 13.00 #/gal.Water requirement: 9.09 gal/sackCompressives 165 F: 905 psi after 24 hours

13. ANTICIPATED STARTING DATE AND DURATION OF THE OPERATIONS

Starting Date: March 15, 2005Duration: 14 Days

O ODRILLING PLAN


11. WATER SUPPLY• No water pipelines will be laid for this well.• No water well will be drilled for this well.• Drilling water for this will be hauled on the road(s) shown in Attachment No. 3.

• Water will be hauled from: Water Permit # 43-10447 Section 9. Township 8 South. Range 20 East

12. CEMENTSYSTEMS

a. Surface Cement:• Drill 12-1/4" hole to 2,000'±, run and cement 8-5/8" to surface (depth to vary based on depth of lost circulation

zone).• Pump 20 bbls lightly weighted water spacer followed by 5 bbls fresh water. Displace with any available water.

• Casing to be run with: a) guide shoe b) insert float c) three (3) centralizers, one on each of first 3 jointsd) stop ring

for plug two joints off bottom e) bottom three joints thread locked f) pump jobwith bottom plug only.

• Cement the casing annulus to surface. Top out jobs to be performed if needed. Depending to depth of top of

cement in the annulus, a 1" tubing string may or may not be utilized.Hol_e Cement

Tyge Sac_11s Interval Density Yi.el_d Volume Volume Excess

Lead 252 O'-1,500' 11.0 ppg 3.82 CFS 619 CF 835 CF 35%

Tail 219 1,500'-2,000' 15.6 ppg 1.18 CFS 220 CF 297 CF 35%

Top Out 100 O'-200' 15.6 ppg 1.18 CFS 95 CF 118 CF 24% (if required)

Lead Mix: Premium Plus V blend. Blend includes Class "G" cement, gel, salt, gilsonite.Slurry yield: 3.82 cf/sack Slurry weight: 11.00#/gal.Water requirement: 22.95 gallsack

Tail Mix: Class "G" Cement, 1/4 lb/sk Cellophane Flakes + 2% bwoc Calcium Chloride + 44.3% fresh water.


Top Out: Class "G" Cement, 1/4 lb/sk Cellophane Flakes + 2% bwoc Calcium Chloride + 44.3% fresh water.


c. Production Casing Cement:• Drill 7-7/8" hole to 9,200'±, run and cement 5 1/2".• Cement interface is at 4,000', which is typically 500'-l,000' above shallowest pay.• Pump 20 bbl Mud Clean II unweighted spacer, followed by 20 Bbls fresh H20 spacer.• Displace with 3% KCL.

H_ple Cement

Tyge Sacks Interval Density M Volume Volume Excess

Lead 160 3,700'-4,700' 11.5 ppg 3.12 CFS 175 CF 350 CF 100%

Tail 435 4,700'-9,200' 13.0 ppg 1.75 CFS 473 CF 946 CF 100%

Note: A caliper log will be ran to determine cement volume requirements.

Lead Mix: Halliburton Prem Plus V blend. Blend includes Class "C" cement, gel, salt, gilsonite, EX-1 and HR-7.

Slurry yield: 3.12 cf/sack Slurry weight: 11.60 #/gal.Water requirement: 17.71 gallsackCompressives @130 F: 157 psi after 24 hours

Tail Mix: Halliburton HLC blend (Prem Plus VIJB flyash). Blend includes Class "G" cement, KC1,EX-1, Halad 322,

& HR-5.Slurry yield: 1.75 cf/sack Slurry weight: 13.00 #/gal.Water requirement: 9.09 gal/sackCompressives 165 F: 905 psi after 24 hours

13. ANTICIPATED STARTING DATE AND DURATION OF THE OPERATIONS

Starting Date: March 15, 2005Duration: 14 Days

O OSURFACE USE PLAN

CONDITIONS OF APPROVAL

Attachment forPermit to Drill



2019' FNL & 1596' FMiSection 6-11S-21E

Uintah County, UT

The dirt contractor will be provided with an approved copy of the surface use plan of operationsbefore initiating construction.

The onsite inspection for the referenced well was conducted on Monday, November 8, 2004.

1. Existine Roads:

a. The proposed well site is located approximately 14.06 miles southeast of Ouray, UT.

b. Directions to the proposed well site have been attached at the end of Exhibit B.

c. The use of roads under State and County Road Department maintenance are necessary toaccess the Little Canyon Unit. However, an encroachment permit is not anticipated since noupgrades to the State or County Road system are proposed at this time.

d. All existing roads will be maintained and kept in good repair during all phases of operation.

e. Vehicle operators will obey posted speed restrictions and observe safe speeds commensuratewith road and weather conditions.

f. Since no improvements are anticipated to the State, County, Tribal or BLM access roads notopsoil striping will occur.

g. An off-lease federal Right-of-Way is not anticipated for the access road or utility corridorsince both are located within the proposed Little Canyon Unit

O OSURFACE USE PLAN

CONDITIONS OF APPROVAL

Attachment forPermit to Drill

Name of Operator: Dominion Exploration & Production

Address: 14000 QuailSprings Parkway, Suite 600Oklahoma City, OK 73134

Well Location: LCU 6-6G2019' FNL & 1596' FMiSection 6-11S-21E

Uintah County, UT

The dirt contractor will be provided with an approved copy of the surface use plan of operationsbefore initiating construction.

The onsite inspection for the referenced well was conducted on Monday, November 8, 2004.

1. Existine Roads:

a. The proposed well site is located approximately 14.06 miles southeast of Ouray, UT.

b. Directions to the proposed well site have been attached at the end of Exhibit B.

c. The use of roads under State and County Road Department maintenance are necessary toaccess the Little Canyon Unit. However, an encroachment permit is not anticipated since noupgrades to the State or County Road system are proposed at this time.

d. All existing roads will be maintained and kept in good repair during all phases of operation.

e. Vehicle operators will obey posted speed restrictions and observe safe speeds commensuratewith road and weather conditions.

f. Since no improvements are anticipated to the State, County, Tribal or BLM access roads notopsoil striping will occur.

g. An off-lease federal Right-of-Way is not anticipated for the access road or utility corridorsince both are located within the proposed Little Canyon Unit

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2. Planned Access Roads:

a. From the proposed LCU 16-1H an access is proposed trending northeast approximately 0.8miles to the proposed well site. The access consists of entirely new disturbance and crossesno significant drainages. A road design plan is not anticipated at this time.

b. The proposed access road will consist of a 14' travel surface within a 30' disturbed area.

c. BLM approval to construct and utilize the proposed access road is requested with thisapplication.

d. A maximum grade of 10% will be maintained throughout the project with no cuts and fillsrequired to access the well.

e. No turnouts are proposed since the access road is only 0.8 miles long and adequate sitedistance exists in all directions.

f. No culverts are anticipated. Adequate drainage structures will be incorporated intothe road.

g. No surfacing material will come from federal or Indian lands.

h. No gates or cattle guards are anticipated at this time.

i. Surfàce disturbance and vehicular travel will be limited to the approved location access road.

j. All access roads and surface disturbing activities will conform to the standards outlined in theBureau of Land Management and Forest Service publication: Surface Operating Standardsfor Oil and Gas Exploration and Development, (1989).

k. The operator will be responsible for all maintenance of the access road including drainagestructures.

3. Location of Existing Wells:

a. Following is a list of existing wells within a one mile radius of the proposed well:

i. Water wells Noneii. Injection wells None

iii. Disposal wells Noneiv. Drilling wells Nonev. Temp. shut-in wells None

vi. Producing wells Nonevii. Abandon wells 1

b. Exhibit B has a map reflecting these wells within a one mile radius of the proposed

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2. Planned Access Roads:

a. From the proposed LCU 16-1H an access is proposed trending northeast approximately 0.8miles to the proposed well site. The access consists of entirely new disturbance and crossesno significant drainages. A road design plan is not anticipated at this time.

b. The proposed access road will consist of a 14' travel surface within a 30' disturbed area.

c. BLM approval to construct and utilize the proposed access road is requested with thisapplication.

d. A maximum grade of 10% will be maintained throughout the project with no cuts and fillsrequired to access the well.

e. No turnouts are proposed since the access road is only 0.8 miles long and adequate sitedistance exists in all directions.

f. No culverts are anticipated. Adequate drainage structures will be incorporated intothe road.

g. No surfacing material will come from federal or Indian lands.

h. No gates or cattle guards are anticipated at this time.

i. Surfàce disturbance and vehicular travel will be limited to the approved location access road.

j. All access roads and surface disturbing activities will conform to the standards outlined in theBureau of Land Management and Forest Service publication: Surface Operating Standardsfor Oil and Gas Exploration and Development, (1989).

k. The operator will be responsible for all maintenance of the access road including drainagestructures.

3. Location of Existing Wells:

a. Following is a list of existing wells within a one mile radius of the proposed well:

i. Water wells Noneii. Injection wells None

iii. Disposal wells Noneiv. Drilling wells Nonev. Temp. shut-in wells None

vi. Producing wells Nonevii. Abandon wells 1

b. Exhibit B has a map reflecting these wells within a one mile radius of the proposed

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4. Location of Production Facilities:

a. All permanent structures will be painted a flat, non-reflective Desert Brown to match thestandard environmental colors. All facilities will be painted within sixmonthsof installation.Facilities required to comply with the Occupational Safety and Health Act (OSHA) may be

excluded.

b. Site security guidelines identified in 43 CFR 3163.7-5 and Onshore Oil and Gas OrderNo. 3will be adhered to.

c. A gas meter run will be constructed and located on Iease within 500 feet of the wellhead.Meter runs will be housed and/or fenced. All gas production and measurement shallcomplywith the provisions of 43 CFR 3162. 7-3, Onshore Oil and Gas Order No. 5, and AmericanGas Association (AGA) Report No. 3.

d. A tank battery will be constructed on this lease, it will be surrounded by a dike of sufficientcapacity to contain the storage capacity of the largest tank. All loading lines and valves willbe placed inside the berm surrounding the tank battery. All liquid hydrocarbons productionand measurement shall conform to the provisions of43 CFR 3162.7-3 and Onshore Oil andGas Order No. 4 and Onsbore Oil and Gas Order No. 5 for natural gas production andmeasurement.

e. Any necessary pits will be properly fenced to prevent any wildlife and livestock entry.

f. All access roads will be maintained as necessary to prevent erosion and accommodate year-round traffic. The road will be maintained in a safe useable condition.

g. The site will require periodic maintenance to ensure that drainages are kept open and free ofdebris, ice, and snow, and that surfaces are properly treated to reduce erosion, fugitive dust,and impacts to adjacent areas.

h. A gas pipeline is associated with this application and is being applied for at this time. Theproposed 6" gas pipeline corridor will leave the southwest side of the well site and traverse1,390' northeast to the existing 3" pipeline corridor that services existing wells west of theLittle Canyon Unit. The existing pipeline will then be upgraded from a 3" steel surfacepipeline to a 6" steel surface pipeline for approximately 3,200' to its end at the existingCanyon Gas Pipeline.

i. The new gas pipeline will be a 6" steel surface line within a 40' wide utility corridor. Theuse of the proposed well site and access roads will facilitate the staging of the pipelineconstruction. A new pipeline length of approximately 1,390' is associatedwith this well. Anupgraded pipeline length of approximately 3,200' is associated with this well.

j. Dominion intends on installing the pipeline on the surface by welding manyjoints into longlengths, dragging the long lengths into position and then completing a final welding pass tojoin the long lengthstogether. Dominion intends on connecting the pipelinetogetherutilizingconventional welding technology.

5. Location and Type of Water Supplv:

a. The location and type of water supply has been addressed as number 11within the previousdrilling plan

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4. Location of Production Facilities:

a. All permanent structures will be painted a flat, non-reflective Desert Brown to match thestandard environmental colors. All facilities will be painted within sixmonthsof installation.Facilities required to comply with the Occupational Safety and Health Act (OSHA) may be

excluded.

b. Site security guidelines identified in 43 CFR 3163.7-5 and Onshore Oil and Gas OrderNo. 3will be adhered to.

c. A gas meter run will be constructed and located on Iease within 500 feet of the wellhead.Meter runs will be housed and/or fenced. All gas production and measurement shallcomplywith the provisions of 43 CFR 3162. 7-3, Onshore Oil and Gas Order No. 5, and AmericanGas Association (AGA) Report No. 3.

d. A tank battery will be constructed on this lease, it will be surrounded by a dike of sufficientcapacity to contain the storage capacity of the largest tank. All loading lines and valves willbe placed inside the berm surrounding the tank battery. All liquid hydrocarbons productionand measurement shall conform to the provisions of43 CFR 3162.7-3 and Onshore Oil andGas Order No. 4 and Onsbore Oil and Gas Order No. 5 for natural gas production andmeasurement.

e. Any necessary pits will be properly fenced to prevent any wildlife and livestock entry.

f. All access roads will be maintained as necessary to prevent erosion and accommodate year-round traffic. The road will be maintained in a safe useable condition.

g. The site will require periodic maintenance to ensure that drainages are kept open and free ofdebris, ice, and snow, and that surfaces are properly treated to reduce erosion, fugitive dust,and impacts to adjacent areas.

h. A gas pipeline is associated with this application and is being applied for at this time. Theproposed 6" gas pipeline corridor will leave the southwest side of the well site and traverse1,390' northeast to the existing 3" pipeline corridor that services existing wells west of theLittle Canyon Unit. The existing pipeline will then be upgraded from a 3" steel surfacepipeline to a 6" steel surface pipeline for approximately 3,200' to its end at the existingCanyon Gas Pipeline.

i. The new gas pipeline will be a 6" steel surface line within a 40' wide utility corridor. Theuse of the proposed well site and access roads will facilitate the staging of the pipelineconstruction. A new pipeline length of approximately 1,390' is associatedwith this well. Anupgraded pipeline length of approximately 3,200' is associated with this well.

j. Dominion intends on installing the pipeline on the surface by welding manyjoints into longlengths, dragging the long lengths into position and then completing a final welding pass tojoin the long lengthstogether. Dominion intends on connecting the pipelinetogetherutilizingconventional welding technology.

5. Location and Type of Water Supplv:

a. The location and type of water supply has been addressed as number 11within the previousdrilling plan

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6. Source of Construction Material:

a. The use of materials will conform to 43 CFR 3610.2-3.

b. No construction materials will be removed from Ute Tribal or BLM lands.

c. If any gravel is used, it will be obtained from a state approved gravel pit.

7. Methods of Handling Waste Disposal:

a. All wastes associated with this application will be contained and disposed of utilizingapproved facilities.

b. Drill cuttings will be contained and buried on site.

c. The reserve pit will be located outboard of the location and along the southeast side of thepad.

d. The reserve pit will be constructed so as not to leak, break, or allow any discharge.

e. The reserve pit will be lined with 12 mil minimum thickness plastic nylon reinforced linermaterial. The liner will overlay a felt liner pad only if rock is encountered duringexcavation.The pit liner will overlap the pit walls and be covered with dirt and/or rocks to hold it inplace. No trash, scrap pipe, etc., that could puncture the liner will be disposed of in the pit.Pit walls will be sloped no greater than 2:1. A minimum 2-foot freeboard will be maintainedin the pit at all times during the drilling and completion operation.

f. The reserve pit has been located in cut material. Three sides of the reserve pit will be fencedbefore drilling starts. The fourth side will be fenced as soon as drilling is completed, andshall remain until the pit is dry. After the reserve pit has dried, all areas not needed forproduction will be rehabilitated.

g. No chemicals subject to reporting under SARATitle III (hazardous materials) in an amountgreater than 10,000 pounds will be used, produced, stored, transported, or disposed of

annually in association with the drilling, testing, or completion of the well. Furthermore, noextremely hazardous substances, as defined in 40 CFR 355, in threshold planning quantities,will be used, produced, stored, transported, or disposed of in association with the drilling,testing, or completion of the well.

h. Trash will be contained in a trash cage and hauled away to an approved disposal site asnecessary but no later than at the completion of drilling operations. The contents of the trashcontainer will be hauled off periodically to the approved UintahCountyLandfill near Vernal,Utah.

i. Produced fluids from the well other than water will be produced into a test tank until suchtime as construction of production facilities is completed. Any spills of oil, gas, salt water orother produced fluids will be cleaned up and removed.

j. After initial clean-up, a 400 bbl tank will be installed to contain produced waste water. Thiswater will be transported fromthe tank to an approved Dominion disposal well for

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6. Source of Construction Material:

a. The use of materials will conform to 43 CFR 3610.2-3.

b. No construction materials will be removed from Ute Tribal or BLM lands.

c. If any gravel is used, it will be obtained from a state approved gravel pit.

7. Methods of Handling Waste Disposal:

a. All wastes associated with this application will be contained and disposed of utilizingapproved facilities.

b. Drill cuttings will be contained and buried on site.

c. The reserve pit will be located outboard of the location and along the southeast side of thepad.

d. The reserve pit will be constructed so as not to leak, break, or allow any discharge.

e. The reserve pit will be lined with 12 mil minimum thickness plastic nylon reinforced liner

material. The liner will overlay a felt liner pad only if rock is encountered duringexcavation.

The pit liner will overlap the pit walls and be covered with dirt and/or rocks to hold it inplace. No trash, scrap pipe, etc., that could puncture the liner will be disposed of in the pit.Pit walls will be sloped no greater than 2:1. A minimum 2-foot freeboard will be maintainedin the pit at all times during the drilling and completion operation.

f. The reserve pit has been located in cut material. Three sides of the reserve pit will be fencedbefore drilling starts. The fourth side will be fenced as soon as drilling is completed, andshall remain until the pit is dry. After the reserve pit has dried, all areas not needed forproduction will be rehabilitated.

g. No chemicals subject to reporting under SARATitle III (hazardous materials) in an amount

greater than 10,000 pounds will be used, produced, stored, transported, or disposed of

annually in association with the drilling, testing, or completion of the well. Furthermore, noextremely hazardous substances, as defined in 40 CFR 355, in threshold planning quantities,will be used, produced, stored, transported, or disposed of in association with the drilling,testing, or completion of the well.

h. Trash will be contained in a trash cage and hauled away to an approved disposal site asnecessary but no later than at the completion of drilling operations. The contents of the trashcontainer will be hauled off periodically to the approved UintahCountyLandfill near Vernal,Utah.

i. Produced fluids from the well other than water will be produced into a test tank until suchtime as construction of production facilities is completed. Any spills of oil, gas, salt water orother produced fluids will be cleaned up and removed.

j. After initial clean-up, a 400 bbl tank will be installed to contain produced waste water. Thiswater will be transported fromthe tank to an approved Dominion disposal well for

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k. Produced water from the production well will be disposed of at the RBU 13-11F orRBU 16-19F disposal wells in accordance with Onshore Order #7.

1. Any salts and/or chemicals, which are an integral part ofthe drilling system,will be disposedof in the same manner as the drilling fluid.

m. Sanitary facilities will be on site at all times during operations. Sewage will be placed in aportable chemical toilet and the toilet replaced periodically utilizing a licensed contractor totransport by truck the portable chemical toilet so that its contents can be delivered to theVernal Wastewater Treatment Facility in accordance with state and county regulations.

8. Ancillary Facilities:

a. Garbage Containers and Portable Toilets are the only ancillary facilities proposed in thisapplication.

9. Well Site Layout: (See Exhibit B)

a. The well will be properly identified in accordance with 43 CFR 3162.6.

b. Access to the well pad will be from the west.

c. The pad and road designs are consistent with BLM and Tribal specification

d. A pre-construction meeting with responsible company representative, contractors, and the BLMwill be conducted at the project site prior to commencement of surface-disturbing activities. Thepad and road will be construction-staked prior to this meeting.

e. The pad has been staked at its maximum size of 355' X 200'; however it will be constructedsmaller if possible, depending upon rig availability. Should the layout change, this applicationwill be amended and approved utilizing a sundry notice.

f. All surface disturbing activities, will be supervised by a qualified, responsible companyrepresentative who is aware of the terms and conditions of the APD and specifications in theapproved plans.

g. All cut and fill slopes will be such that stability can be maintained for the life of the activity.

h. Diversion ditches will be constructedas shown around the well site to prevent surface waters formentering the well site area.

i. The site surface will be graded to drain away from the pit to avoid pit spillage during large stormevents.

j. The stockpiled topsoil (first 6 inches or maximum available) will be stored in a windrow on theuphill side of the location to prevent any possible contamination. All topsoil will be stockpiledfor reclamation in such a way as to prevent soil loss and contamination.

k. Pits will remain fenced until site

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k. Produced water from the production well will be disposed of at the RBU 13-11F orRBU 16-19F disposal wells in accordance with Onshore Order #7.

1. Any salts and/or chemicals, which are an integral part ofthe drilling system,will be disposedof in the same manner as the drilling fluid.

m. Sanitary facilities will be on site at all times during operations. Sewage will be placed in aportable chemical toilet and the toilet replaced periodically utilizing a licensed contractor totransport by truck the portable chemical toilet so that its contents can be delivered to theVernal Wastewater Treatment Facility in accordance with state and county regulations.

8. Ancillary Facilities:

a. Garbage Containers and Portable Toilets are the only ancillary facilities proposed in thisapplication.

9. Well Site Layout: (See Exhibit B)

a. The well will be properly identified in accordance with 43 CFR 3162.6.

b. Access to the well pad will be from the west.

c. The pad and road designs are consistent with BLM and Tribal specification

d. A pre-construction meeting with responsible company representative, contractors, and the BLMwill be conducted at the project site prior to commencement of surface-disturbing activities. Thepad and road will be construction-staked prior to this meeting.

e. The pad has been staked at its maximum size of 355' X 200'; however it will be constructedsmaller if possible, depending upon rig availability. Should the layout change, this applicationwill be amended and approved utilizing a sundry notice.

f. All surface disturbing activities, will be supervised by a qualified, responsible companyrepresentative who is aware of the terms and conditions of the APD and specifications in theapproved plans.

g. All cut and fill slopes will be such that stability can be maintained for the life of the activity.

h. Diversion ditches will be constructedas shown around the well site to prevent surface waters formentering the well site area.

i. The site surface will be graded to drain away from the pit to avoid pit spillage during large stormevents.

j. The stockpiled topsoil (first 6 inches or maximum available) will be stored in a windrow on theuphill side of the location to prevent any possible contamination. All topsoil will be stockpiledfor reclamation in such a way as to prevent soil loss and contamination.

k. Pits will remain fenced until site

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l. The blooie line will be located at least 100 feet from the well head.

m. Water injection may be implemented if necessary to minimize the amount of fugitive dust.

10. Plans for Restoration of the Surface:

a. Site reclamation for a producing well will be accomplished for portions ofthe sitenot required forthe continued operation of the well.

b. The Operator will control noxious weeds along access road use authorizations, pipeline routeauthorizations, well sites, or other applicable facilities by spraying or mechanical removal. A listof noxious weeds may be obtained from the BLM or the appropriate County Extension Office.On Ute Tribal and BLM administered land, it is required that a Pesticide Use Proposal besubmitted and approved prior to the application of herbicides, pesticides or possibly hazardouschemicals.

c. Upon well completion, any hydrocarbons in the pit shall be removed in accordance with 43 CFR3162.7-1.Once the reserve pit is dry, the plastic nylon reinforced liner shall be torn and perforatedbefore backfilling of the reserve pit. The reserve pit and that portion of the location not neededfor production facilitiesloperations will be recontoured to the approximate natural contours.

d. The cut and fill slopes and all other disturbed areas not needed for the production operation willbe top soiled and re-vegetated. The stockpiled topsoil will be evenly distributed over thedisturbed area.

e. Prior to reseeding the site, all disturbed areas, including the access road, will be scarified and leftwith a rough surface. The site will then be seeded and/or planted as prescribed by the BIA. TheBIA recommended seed mix will be detailed within their approval documents.

11. Surface and Mineral Ownership:

a. Surface Ownership - Federal under the management of the Bureau of LandManagement - VernalField Office, 170 South 500 East, Vernal, Utah 84078; 435-781-4400.

b. Mineral Ownership -Federal under the management of the BureauofLand Management - VernalField Office, 170 South 500 East, Vernal, Utah 84078; 435-781-4400.

12. Other Information:

a. AIA Archaeological has conducted a Class III archeological survey. A copy ofthe report will besubmitted under separate cover to the appropriate agencies by AIA Archaeological.

b. Our understanding of the results of the onsite inspection are:

a. No Threatened and Endangered flora and fauna species were found during the onsiteinspection.

b. No drainage crossings that require additional State or Federal approval are beingcrossed.

c. Construction and drilling activities should not occur betweenMay 15and June 20 ofanygiven year for the protection of fawning

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l. The blooie line will be located at least 100 feet from the well head.

m. Water injection may be implemented if necessary to minimize the amount of fugitive dust.

10. Plans for Restoration of the Surface:

a. Site reclamation for a producing well will be accomplished for portions ofthe sitenot required forthe continued operation of the well.

b. The Operator will control noxious weeds along access road use authorizations, pipeline route

authorizations, well sites, or other applicable facilities by spraying or mechanical removal. A listof noxious weeds may be obtained from the BLM or the appropriate County Extension Office.On Ute Tribal and BLM administered land, it is required that a Pesticide Use Proposal besubmitted and approved prior to the application of herbicides, pesticides or possibly hazardouschemicals.

c. Upon well completion, any hydrocarbons in the pit shall be removed in accordance with 43 CFR3162.7-1.Once the reserve pit is dry, the plastic nylon reinforced liner shall be torn and perforatedbefore backfilling of the reserve pit. The reserve pit and that portion of the location not neededfor production facilitiesloperations will be recontoured to the approximate natural contours.

d. The cut and fill slopes and all other disturbed areas not needed for the production operation will

be top soiled and re-vegetated. The stockpiled topsoil will be evenly distributed over thedisturbed area.

e. Prior to reseeding the site, all disturbed areas, including the access road, will be scarified and leftwith a rough surface. The site will then be seeded and/or planted as prescribed by the BIA. TheBIA recommended seed mix will be detailed within their approval documents.

11. Surface and Mineral Ownership:

a. Surface Ownership - Federal under the management of the Bureau of LandManagement - Vernal

Field Office, 170 South 500 East, Vernal, Utah 84078; 435-781-4400.

b. Mineral Ownership -Federal under the management of the BureauofLand Management - VernalField Office, 170 South 500 East, Vernal, Utah 84078; 435-781-4400.

12. Other Information:

a. AIA Archaeological has conducted a Class III archeological survey. A copy ofthe report will besubmitted under separate cover to the appropriate agencies by AIA Archaeological.

b. Our understanding of the results of the onsite inspection are:

a. No Threatened and Endangered flora and fauna species were found during the onsiteinspection.

b. No drainage crossings that require additional State or Federal approval are beingcrossed.

c. Construction and drilling activities should not occur betweenMay 15and June 20 ofanygiven year for the protection of fawning

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13. Operator's Representative and Certification

Title Name Office PhoneCompany Representative (Roosevelt) Mitchiel Hall 1-435-722-4521Company Representative (Oklahoma) Carla Christian 1-405-749-5263Agent for Dominion Don Hamilton 1-435-637-4075

Certification:

I hereby certify that I, or persons under my direct supervision, have inspected the proposeddrill site and access route; that I am familiar with the conditions which currently exists; thatthe statements made in this APD package are, to the best of my knowledge, true and correct;and that the work associated with the operations proposed herein will be performed byDominion Exploration & Production, Inc. and its contractors and subcontractors inconformity with this APD package and the terms and conditions under which it is approved. Ialso certify responsibility for the operations conducted on that portion of the leased landsassociated with this application, with bond coverage being provided under Dominion's BLMbond. This statement is subject to the provisions of 18U.S.C. 1001 for the filing of a falsestatement.

Signature: so Date: )2 - Q

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13. Operator's Representative and Certification

Title Name Office PhoneCompany Representative (Roosevelt) Mitchiel Hall 1-435-722-4521

Company Representative (Oklahoma) Carla Christian 1-405-749-5263

Agent for Dominion Don Hamilton 1-435-637-4075

Certification:

I hereby certify that I, or persons under my direct supervision, have inspected the proposeddrill site and access route; that I am familiar with the conditions which currently exists; thatthe statements made in this APD package are, to the best of my knowledge, true and correct;and that the work associated with the operations proposed herein will be performed byDominion Exploration & Production, Inc. and its contractors and subcontractors inconformity with this APD package and the terms and conditions under which it is approved. Ialso certify responsibility for the operations conducted on that portion of the leased landsassociated with this application, with bond coverage being provided under Dominion's BLMbond. This statement is subject to the provisions of 18U.S.C. 1001 for the filing of a falsestatement.

Signature: so Date: )2 - Q

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DOMINION EXPLR. & PROD., INC.LCU #6-6G

SECTION T, T11S, R2ðE, S.L.B.&M.

PROCEED IN A WESTERLY DIRECTION FROM VERNAL, UTAH ALONG U.S.HIGHWAY 40 APPROXIMATELY 14.0 MILES TO THE JUNCTION OF STATEHIGHWAY 88; EXIT LEFT AND PROCEED IN A SOUTHERLY DIRECTIONAPPROXIMATELY 17.0 MILES TO OURAY, UTAH; PROCEED IN ASOUTHERLY DIRECTION APPROXIMATELY 13.5 MILES ON THE SEEP RIDGEROAD TO THE JUNCTION OF THIS ROAD AND AN EXISTING ROAD TO THESOUTHWEST; TURN RIGHT AND PROCEED IN A SOUTHWESTERLYDIRECTION APPROXIMATELY 1.8 MILES TO THE JUNCTION OF THIS ROADAND AN EXISTING ROAD TO THE SOUTH; TURN LEFT AND PROCEED IN ASOUTHERLY DIRECTION APPROXIMATELY 0.25 MILES TO THE BEGINNINGOF THE PROPOSED ACCESS FOR WELL #10-2H TO THE SOUTHWEST, THENSOUTH; FOLLOW ROAD FLAGS IN A SOUTHWESTERLY, THEN SOUTHERLYDIRECTION APPROXIMATELY 1.1 MILES TO THE BEGINNING OF THEPROPOSED ACCESS FOR WELL #2-12H TO THE SOUTHEAST; FOLLOW ROADFLAGS IN A SOUTHEASTERLY DIRECTION APPROXIMATELY 0.8 MILES TOTHE BEGINNING OF THE PROPOSED ACCESS FOR WELL #16-1H TO THENORTHEAST; FOLLOW ROAD FLAGS IN A NORTHEASTERLY DIRECTIONAPPROXIMATELY 0.3 MILES TO THE BEGINNING OF THE PROPOSED ACCESSTO THE NORTH; FOLLOW ROAD FLAGS IN A NORTHERLY, THENNORTHEASTERLY DIRECTION APPROXIMATELY 0.8 MILES TO THEPROPOSED LOCATION.

TOTAL DISTANCE FROM VERNAL, UTAH TO THE PROPOSED WELLLOCATION IS APPROXIMATELY 49.6

O O

DOMINION EXPLR. & PROD., INC.LCU #6-6G

SECTION T, T11S, R2ðE, S.L.B.&M.

PROCEED IN A WESTERLY DIRECTION FROM VERNAL, UTAH ALONG U.S.HIGHWAY 40 APPROXIMATELY 14.0 MILES TO THE JUNCTION OF STATEHIGHWAY 88; EXIT LEFT AND PROCEED IN A SOUTHERLY DIRECTIONAPPROXIMATELY 17.0 MILES TO OURAY, UTAH; PROCEED IN ASOUTHERLY DIRECTION APPROXIMATELY 13.5 MILES ON THE SEEP RIDGEROAD TO THE JUNCTION OF THIS ROAD AND AN EXISTING ROAD TO THESOUTHWEST; TURN RIGHT AND PROCEED IN A SOUTHWESTERLYDIRECTION APPROXIMATELY 1.8 MILES TO THE JUNCTION OF THIS ROADAND AN EXISTING ROAD TO THE SOUTH; TURN LEFT AND PROCEED IN ASOUTHERLY DIRECTION APPROXIMATELY 0.25 MILES TO THE BEGINNINGOF THE PROPOSED ACCESS FOR WELL #10-2H TO THE SOUTHWEST, THENSOUTH; FOLLOW ROAD FLAGS IN A SOUTHWESTERLY, THEN SOUTHERLYDIRECTION APPROXIMATELY 1.1 MILES TO THE BEGINNING OF THEPROPOSED ACCESS FOR WELL #2-12H TO THE SOUTHEAST; FOLLOW ROADFLAGS IN A SOUTHEASTERLY DIRECTION APPROXIMATELY 0.8 MILES TOTHE BEGINNING OF THE PROPOSED ACCESS FOR WELL #16-1H TO THENORTHEAST; FOLLOW ROAD FLAGS IN A NORTHEASTERLY DIRECTIONAPPROXIMATELY 0.3 MILES TO THE BEGINNING OF THE PROPOSED ACCESSTO THE NORTH; FOLLOW ROAD FLAGS IN A NORTHERLY, THENNORTHEASTERLY DIRECTION APPROXIMATELY 0.8 MILES TO THEPROPOSED LOCATION.

TOTAL DISTANCE FROM VERNAL, UTAH TO THE PROPOSED WELLLOCATION IS APPROXIMATELY 49.6

INION EXPLR. & PROD., .

LOCATION LAYOUTFOR

LCU #6-6G

SECTION 6, T11S, R21E, S.L.B.&M. Proposed Access

2019' FNL 1596' FWL

C- J.4' C-2.1'E. 417 0 E/. 415.7, 8. 411.7

I

---- 65' Sto. J thuSCALE: 1" = 50'DATE: 9--24-04Drawn By K.G.

IIllii

Approx.Top of

PIPE RACKS

Cut S FL /

E/. 416.6 20 WlDE BENCH - DOG HOUSE

C-11.0 30' 35''° l 135' sto. 1+80

(htm. pif) «- J.o¯¯ Total Pit Copacity -

8. 410.6'

-- W/2' of Freeboard -

10,750 Bb/s. ± -

Tota/ Pit VolumeJ,120 Cu. Yds. PUMP

CLTOILET

HMUDPERHED

POWER

--- TR SH

RESERVE P/TS·¯¯ TOOLS

(8' Deep)¯¯

-- FUEL ApprCX.

sto. 0+52 Toe of

8. 476.

Fill Slope

C-10.5' 20' WIDE BENCH C-0.4' ST RAGE

(b tm. E/. 414.0

Sto. O O

E-0.5'B. 413.

- 7. F- 4.9'E/. 412.4' E/. 408.7'

Ðev. Ungraded Ground at Location Stoke = 5414.1', UINTAH ENGINEERING & LAND SURVEYINGBev. Graded Ground at Location Stoke = 5413.6 86 So. ß00 East * Vernal, Utah 84078 * (435)


LOCATION LAYOUTFOR

LCU #6-6G

SECTION 6, T11S, R21E, S.L.B.&M. Proposed Access

2019' FNL 1596' FWL

C- J.4' C-2.1'E. 417 0 E/. 415.7, 8. 411.7

I

---- 65' Sto. J thuSCALE: 1" = 50'DATE: 9--24-04Drawn By K.G.

IIllii

Approx.Top of

PIPE RACKS

Cut S FL /

E/. 416.6 20 WlDE BENCH - DOG HOUSE

C-11.0 30' 35''° l 135' sto. 1+80

(htm. pif) «- J.o¯¯ Total Pit Copacity -

8. 410.6'

-- W/2' of Freeboard -

10,750 Bb/s. ± -

Tota/ Pit VolumeJ,120 Cu. Yds. PUMP

CLTOILET

HMUDPERHED

POWER

--- TR SH

RESERVE P/TS·¯¯ TOOLS

(8' Deep)¯¯

-- FUEL ApprCX.

sto. 0+52 Toe of

8. 476.

Fill Slope

C-10.5' 20' WIDE BENCH C-0.4' ST RAGE

(b tm. E/. 414.0

Sto. O O

E-0.5'B. 413.

- 7. F- 4.9'E/. 412.4' E/. 408.7'

Ðev. Ungraded Ground at Location Stoke = 5414.1', UINTAH ENGINEERING & LAND SURVEYINGBev. Graded Ground at Location Stoke = 5413.6 86 So. ß00 East * Vernal, Utah 84078 * (435)


TYPICAL CROSS SECTIONSFORX-Section

scale LCU #6-6G AND 4.SECTION 6, T11S, R21E, S.L.B.&M.

1" = 50' 2019' FNL 1596' FWLDATE: 9-24-04Drawn By K.G.

65' 135'PreconstructionGrade

STA. J+55

145' 135'

LOCAT/ON STAKE

\ CUT

STA. 1+80

10 100' 35' 135'

35' 135'

Slope= 1 1/2: 1(Typ.) Finished Grade

NOTE:F/LL -

Topsoil should not beStripped Below Finished STA. 0+00Grade on Substructure Area.

* NOTE:APPROXIMATE YARDAGES FILL QUANT/TY INCLUDES

5X FOR COMPACT/ONCUT EXCESS MATERIAL = 4,150 Cu. Yds.(6") Topsoil Stripping = 1,710 Cu. Yds.

Topsoil & Pit Bockfill = 3,270 Cu. Yds.

Rernoining Location = 5,580 Cu. Yds. (1/2 Pit Vol.)

EXCESS UNBALANCE = 880 Cu. Yds.TOTAL CUT = 7,290 CU.YDS. (After Rehabilitation)

FILL = J,140 CU.YDS- UINTAH ENGINEERING & LAND SURVEYING86 So. ß00 £ast * Vernal, Utah 84078 * (435)


TYPICAL CROSS SECTIONSFORX-Section

scale LCU #6-6G AND 4.SECTION 6, T11S, R21E, S.L.B.&M.

1" = 50' 2019' FNL 1596' FWLDATE: 9-24-04Drawn By K.G.

65' 135'PreconstructionGrade

STA. J+55

145' 135'

LOCAT/ON STAKE

\ CUT

STA. 1+80

10 100' 35' 135'

35' 135'

Slope= 1 1/2: 1(Typ.) Finished Grade

NOTE:F/LL -

Topsoil should not beStripped Below Finished STA. 0+00Grade on Substructure Area.

* NOTE:APPROXIMATE YARDAGES FILL QUANT/TY INCLUDES

5X FOR COMPACT/ONCUT EXCESS MATERIAL = 4,150 Cu. Yds.(6") Topsoil Stripping = 1,710 Cu. Yds.

Topsoil & Pit Bockfill = 3,270 Cu. Yds.

Rernoining Location = 5,580 Cu. Yds. (1/2 Pit Vol.)

EXCESS UNBALANCE = 880 Cu. Yds.TOTAL CUT = 7,290 CU.YDS. (After Rehabilitation)

FILL = J,140 CU.YDS- UINTAH ENGINEERING & LAND SURVEYING86 So. ß00 £ast * Vernal, Utah 84078 * (435)

O ODOMINION EXPLR. & PROD., INC.

LCU #6-6GLOCATED IN UINTAH COUNTY, UTAH

SECTION 6, T11S, R21E, S.L.B.&M.

(LOCATION STAKE)

PHOTO: VIEW FROM CORNER #5 TO LOCATION STAKE CAMERA ANGLE: NORTHWESTERLY

PROPOSED ACCESS

PHOTO: VIEW FROM BEGINNING OF PR POSED ACCESS CAMERA ANGLE: NORTHEASTERLY

y, Uintah Engineering & Land Surveying LOCATIONPHOTOs 09 26 04 enoro85 South 200 East Vernal, Utah 84078 MONTH DAY YEAR

- Smee 1964 -

435-789-1017 [email protected] TAKENBY:M.A. DRAWNBY:C.P. REVISED:

ash

as

e

1.8 MI. +/-

it!S

31 36 31

T10S • TSEE TOPO "B"

2.3 MI. +/-1 sT11S *

,·

R R - PROPOSED LOCATION:

LEGEND: DOMINION EXPLR. & PROD., INC.PROPOSED LOCATION

N LCU #6-6GSECTION 6, T11S, R21E, S.L.B.&M.

2019' FNL 1596' FWL

Uintah Engineering & Land Surveying TOPOGR A PH I c 26 0485 South 200 East Vernal, Utah 84078 M A P ONT DAY YEAR

(435) 789-1017 * FAX (435) 789-1813SCALE:1:100,000 DRAWNBY:C.P.

ash

as

e

1.8 MI. +/-

it!S

31 36 31

T10S • TSEE TOPO "B"

2.3 MI. +/-1 sT11S *

,·

R R - PROPOSED LOCATION:

LEGEND: DOMINION EXPLR. & PROD., INC.PROPOSED LOCATION

N LCU #6-6GSECTION 6, T11S, R21E, S.L.B.&M.

2019' FNL 1596' FWL

Uintah Engineering & Land Surveying TOPOGR A PH I c 26 0485 South 200 East Vernal, Utah 84078 M A P ONT DAY YEAR

(435) 789-1017 * FAX (435) 789-1813SCALE:1:100,000 DRAWNBY:C.P.

OURAY 15.3 MI. +/

.o /

31

PROPOSED ACCESS FOR

T1

WELL H 1.1 MI. +

PROP SED LOCATION:T11S 'L LCU #6-6G

PR ED RH 0.

PROPOS D ACCESS FOR

LEGEND: DOMINION EXPLR. & PROD., INC.EXISTING ROAD N LCU #6-6G

------------ PROPOSED ACCESS ROAD SECTION 6, T11S, R21E, S.L.B.&M.

-2019' FNL 1596' FWL

Uintah Engineering & Land Surveying TOPOGR A PH I c 09 26 0485 South 2OO East Vernal, Utah 84078 M A P ONT DAY YEAR

(435) 789-1017 * FAX (435) 789-1813SCALE:1" = 2000' DRAWNBY:C.P. ED:

OURAY 15.3 MI. +/

.o /

31

PROPOSED ACCESS FOR

T1

WELL H 1.1 MI. +

PROP SED LOCATION:T11S 'L LCU #6-6G

PR ED RH 0.

PROPOS D ACCESS FOR

LEGEND: DOMINION EXPLR. & PROD., INC.EXISTING ROAD N LCU #6-6G

------------ PROPOSED ACCESS ROAD SECTION 6, T11S, R21E, S.L.B.&M.

-2019' FNL 1596' FWL

Uintah Engineering & Land Surveying TOPOGR A PH I c 09 26 0485 South 2OO East Vernal, Utah 84078 M A P ONT DAY YEAR

(435) 789-1017 * FAX (435) 789-1813SCALE:1" = 2000' DRAWNBY:C.P. ED:

o

NB 6 -

10SIT11S

o PROPOSED LOCATION:LC -6G 0

1

LEGEND: DOMINION EXPLR. & PROD., INC.ff DISPOSAL WELLS WATER WELLS N LCU #6-6Ge PRODUCING WELLS ABANDONED WELLS SECTION 6, T11S, R21E, S.L.B.&M.

SHUT IN WELLS -O- TEMPORARILY ABANDONED 2019' FNL 1596' FWL

- Uintah Engineering & Land Surveying TOPOGR A PH I c 09 26 0485 South 200 East Vernal, Utah 84078 M A P ONTH DAY YEAR

(435) 789-1017 * FAX (435) 789-1813SCALE:1" = 2000' DRAWNBY:C.P. REVISED:00-00-00

o

NB 6 -

10SIT11S

o PROPOSED LOCATION:LC -6G 0

1

LEGEND: DOMINION EXPLR. & PROD., INC.ff DISPOSAL WELLS WATER WELLS N LCU #6-6Ge PRODUCING WELLS ABANDONED WELLS SECTION 6, T11S, R21E, S.L.B.&M.

SHUT IN WELLS -O- TEMPORARILY ABANDONED 2019' FNL 1596' FWL

- Uintah Engineering & Land Surveying TOPOGR A PH I c 09 26 0485 South 200 East Vernal, Utah 84078 M A P ONTH DAY YEAR

(435) 789-1017 * FAX (435) 789-1813SCALE:1" = 2000' DRAWNBY:C.P. REVISED:00-00-00

EXIS PELINE

PROPOSED 6"N " PIPELINE UP RAD

1PROPOSED LOCATION: OL #6-6G

APPROXIMATE 1OTAL PIPELINE DISTANCE = 1390' +/-

LEGEND: DOMINION EXPLR. & PROD., INC.PROPOSED ACCESS ROAD N LCU #6-6G

------------ EXISTINGPIPELINE SECTION 6, T11S, R2#E, S.L.B.&M.----------- PROPOSED PIPELINE

2019' FNL 1596' FWL

MIUintah Engineering & Land Surveying TOPOGR A PH I C 09 26 0485 South 200 East Vernal, Utah 84078 M A P ONT DAY YEAR

(435) 789-1017 * FAX (435) 789-1813SCALE:1" = 1000' DRAWNBY:C.P. REV:12-02-04

EXIS PELINE

PROPOSED 6"N " PIPELINE UP RAD

1PROPOSED LOCATION: OL #6-6G

APPROXIMATE 1OTAL PIPELINE DISTANCE = 1390' +/-

LEGEND: DOMINION EXPLR. & PROD., INC.PROPOSED ACCESS ROAD N LCU #6-6G

------------ EXISTINGPIPELINE SECTION 6, T11S, R2#E, S.L.B.&M.----------- PROPOSED PIPELINE

2019' FNL 1596' FWL

MIUintah Engineering & Land Surveying TOPOGR A PH I C 09 26 0485 South 200 East Vernal, Utah 84078 M A P ONT DAY YEAR

(435) 789-1017 * FAX (435) 789-1813SCALE:1" = 1000' DRAWNBY:C.P. REV:12-02-04

. e eLEGEND

O = Oil Line '

G = Gos wLine

R = Relief Line (Pressore)C = Condensole L.neV = Vent LineD = Droin LineM = Gos Meter *

P = PumpBP = Bock Pressure VotveSVS = Seoted Vhen Shipp;ngSUS = Seoted Unless ShippingT = Heot Troced Line

VELLHEAD (typ> c H = HeoterciS BL = Buried Line

C><]= Volve= Check Volve

SC = Seoted Closed VolveNC = Nornolly ClosedBD = Blowdown L ne

BD. BL

31T + 100• Re lie f

30 X 30

SEP -

W. BL 300 bbt Tonk(condensote)

I BL. C

SCSUS

GLYCOLREBOILER

- The site security plan is on filein DEPI s district office located at

CONTACT1400 N. State St., Roosevelt, UTah.

TOWERIt can be inspected during officehours, from 6:30 AM thru 3:30 PM,Monday thru Friday..

7

DOMINIONEXPLORATION& PRODUCTION,INC.

I: , not to scote

-,, i TYPICAL FLOV DIAGRAM Íd

. e eLEGEND

O = Oil Line '

G = Gos wLine

R = Relief Line (Pressore)C = Condensole L.neV = Vent LineD = Droin LineM = Gos Meter *

P = PumpBP = Bock Pressure VotveSVS = Seoted Vhen Shipp;ngSUS = Seoted Unless ShippingT = Heot Troced Line

VELLHEAD (typ> c H = HeoterciS BL = Buried Line

C><]= Volve= Check Volve

SC = Seoted Closed VolveNC = Nornolly ClosedBD = Blowdown L ne

BD. BL

31T + 100• Re lie f

30 X 30

SEP -

W. BL 300 bbt Tonk(condensote)

I BL. C

SCSUS

GLYCOLREBOILER

- The site security plan is on filein DEPI s district office located at

CONTACT1400 N. State St., Roosevelt, UTah.

TOWERIt can be inspected during officehours, from 6:30 AM thru 3:30 PM,Monday thru Friday..

7

DOMINIONEXPLORATION& PRODUCTION,INC.

I: , not to scote

-,, i TYPICAL FLOV DIAGRAM Íd

BOP STACK

RILLING NIPPLE

-F"LOW LINE

FILLUP LINE

.. HYORIL

PIPE RAMS

BLIND RAMS

ORILLING

sPoot . )

KILL LINE CHOKE LINE

HEAD

CHOl<E MANIFOLD

ADJUSTABLE CHOKE> TO MUO TANK

VALVECHOKE LINE

D1 : To

BOP STACK

RILLING NIPPLE

-F"LOW LINE

FILLUP LINE

.. HYORIL

PIPE RAMS

BLIND RAMS

ORILLING

sPoot . )

KILL LINE CHOKE LINE

HEAD

CHOl<E MANIFOLD

ADJUSTABLE CHOKE> TO MUO TANK

VALVECHOKE LINE

D1 : To

WORKSHEET

0 03 PLICATION FOR PERMIT TO DRILL

APD RECEIVED: 12/17/2004 API NO. ASSIGNED: 43-047-36164

WELL NAME: LCU 6-6G

OPERATOR: DOMINION EXPL & PROD ( N1095 )

CONTACT: DON HAMILTON PHONE NUMBER: 435-650-1886

PROPOSED LOCATION:

SENW 06 110s 210E INSPECT LOCATN BY: / /

SURFACE: 2019 FNL 1596 FWL Tech Review Initials DateBOTTOM: 2019 FNL 1596 FWL

UINTAH Engineering

LOVE ( 622 ) Geology

LEASE TYPE: 1 - Federal SurfaceLEASE NUMBER: UTU-75700

SURFACE OWNER: 1 - FederalLATITUDE: 39.89113

PROPOSED FORMATION: MVRD

COALBED METHANE WELL? NO LONGITUDE: -109.6120

RECEIVED AND/OR REVIEWED: LOCATION AND SITING:

/ Plat R649-2-3.

Bond: Fed[1] Ind[] Sta[] Fee[]Unit

(No.76S630500330 )A Potash (Y/N) at

' R649-3-2. General

AÍ Oil Shale 190-5 (B) or 190-3 or 190-13 Siting:460 From Qtr/Qtr & 920'Between Wells

y/' Water Permit R649-3-3. Exception(No.43-10447 )

Drilling UnitRDCC Review (Y/N)

Board Cause No:(Date: )Eff Date:

Fee Surf Agreement (Y/N) Siting:

R649-3-11. Directional Drill

COMMENTS:

STIPULATIONS: '

WORKSHEET

0 03 PLICATION FOR PERMIT TO DRILL

APD RECEIVED: 12/17/2004 API NO. ASSIGNED: 43-047-36164

WELL NAME: LCU 6-6G

OPERATOR: DOMINION EXPL & PROD ( N1095 )

CONTACT: DON HAMILTON PHONE NUMBER: 435-650-1886

PROPOSED LOCATION:

SENW 06 110s 210E INSPECT LOCATN BY: / /

SURFACE: 2019 FNL 1596 FWL Tech Review Initials DateBOTTOM: 2019 FNL 1596 FWL

UINTAH Engineering

LOVE ( 622 ) Geology

LEASE TYPE: 1 - Federal SurfaceLEASE NUMBER: UTU-75700

SURFACE OWNER: 1 - FederalLATITUDE: 39.89113

PROPOSED FORMATION: MVRD

COALBED METHANE WELL? NO LONGITUDE: -109.6120

RECEIVED AND/OR REVIEWED: LOCATION AND SITING:

/ Plat R649-2-3.

Bond: Fed[1] Ind[] Sta[] Fee[]Unit

(No.76S630500330 )A Potash (Y/N) at

' R649-3-2. General

AÍ Oil Shale 190-5 (B) or 190-3 or 190-13 Siting:460 From Qtr/Qtr & 920'Between Wells

y/' Water Permit R649-3-3. Exception(No.43-10447 )

Drilling UnitRDCC Review (Y/N)

Board Cause No:(Date: )Eff Date:

Fee Surf Agreement (Y/N) Siting:

R649-3-11. Directional Drill

COMMENTS:

STIPULATIONS: '

I

CAUSE.19 32HCL 1 34Fo

('105 R20E T105 R20ET11S R20E T11S R21E

LCUl1·tH

LCL 12-1H© LOVE FIELD

LCU 16 1H

LCL 14 1H

l.CU 2-12H

NATUKAL1-7+

GOVT-WOLF 2

12

OPERATOR: DOMINION EXPLPROD (N1095)

SEC. 6 T.11S R.21E

FIELD:LOVE (622)

COUNTY: UINTAH+•k

SPACING:R669-3-3/EXCEFFIONLOCATION Utah OilGas and MiningWells Units.shp Fields.shp

= GAS INJECTION EXPLORATORY ABANDONEDe GAS STORAGE GAS STORAGE ACTIVE× LOCATION ABANDONEDCi NEW LOCATION NF PP OIL COMBINED

+ PLUGGED & ABANDONED NF SECONDARY INACITVEPRODUCING GAS PENDING PROPOSEDPRODUCING OIL PI GIL STORAGESHUT-IN GAS PP GAS TERMINATEDSHUT-IN OIL

PP GEOTHERML SX TEMP. ABANDONEDc TEST WElla WATER INJECTION SECONDARY

• WATER SUPPLY TERMINATED FREPARED BY:DIANA WHITNEYe WATER DISPOSAL DATE:

I

CAUSE.19 32HCL 1 34Fo

('105 R20E T105 R20ET11S R20E T11S R21E

LCUl1·tH

LCL 12-1H© LOVE FIELD

LCU 16 1H

LCL 14 1H

l.CU 2-12H

NATUKAL1-7+

GOVT-WOLF 2

12

OPERATOR: DOMINION EXPLPROD (N1095)

SEC. 6 T.11S R.21E

FIELD:LOVE (622)

COUNTY: UINTAH+•k

SPACING:R669-3-3/EXCEFFIONLOCATION Utah OilGas and MiningWells Units.shp Fields.shp

= GAS INJECTION EXPLORATORY ABANDONEDe GAS STORAGE GAS STORAGE ACTIVE× LOCATION ABANDONEDCi NEW LOCATION NF PP OIL COMBINED

+ PLUGGED & ABANDONED NF SECONDARY INACITVEPRODUCING GAS PENDING PROPOSEDPRODUCING OIL PI GIL STORAGESHUT-IN GAS PP GAS TERMINATEDSHUT-IN OIL

PP GEOTHERML SX TEMP. ABANDONEDc TEST WElla WATER INJECTION SECONDARY

• WATER SUPPLY TERMINATED FREPARED BY:DIANA WHITNEYe WATER DISPOSAL DATE:

O OOLENE S. WALKER

Governor

GAYLE F. McKEACHNIELieutenant Governor

State of Utah December 27, 2004

Department ofNatural Resources

ROBERT L. MORGAN Dominion Exploration & Production, Inc.Executive Director14000 QuailSprings Parkway, Suite 600

Division of Oklahoma City, OK 73134Oil, Gas & Mining

MARY ANN WRIGHTActing Division Director Re: LCU 6-6G Well, 2019' FNL, 1596' FWL, SE NW, Sec. 6, T. 11 South,

R. 21 East, Uintah County, Utah

Gentlemen:

Pursuant to the provisions and requirements of Utah Code Ann.§ 40-6-1 etseq., Utah Administrative Code R649-3-1 et seq., and the attached Conditions ofApproval, approval to drill the referenced well is granted.

This approval shall expire one year from the above date unless substantial andcontinuous operation is underway, or a request for extension is made prior to theexpiration date. The API identification number assigned to this well is 43-047-36164.

John R. BazaAssociate Director

pabEnclosures

cc: Uintah County AssessorBureau of Land Management, Vernal District Office

/1594 West North Temple, Suite 1210, PO Box 145801, Salt Lake City, UT 84114-5801telephone(801)538-5340•facsimile (801) 359-3940•TTY (801) 538-7458 •www.ogm.utah.gov Where ideas

O OOLENE S. WALKER

Governor

GAYLE F. McKEACHNIELieutenant Governor

State of Utah December 27, 2004

Department ofNatural Resources

ROBERT L. MORGAN Dominion Exploration & Production, Inc.Executive Director14000 QuailSprings Parkway, Suite 600

Division of Oklahoma City, OK 73134Oil, Gas & Mining

MARY ANN WRIGHTActing Division Director Re: LCU 6-6G Well, 2019' FNL, 1596' FWL, SE NW, Sec. 6, T. 11 South,

R. 21 East, Uintah County, Utah

Gentlemen:

Pursuant to the provisions and requirements of Utah Code Ann.§ 40-6-1 etseq., Utah Administrative Code R649-3-1 et seq., and the attached Conditions ofApproval, approval to drill the referenced well is granted.

This approval shall expire one year from the above date unless substantial andcontinuous operation is underway, or a request for extension is made prior to theexpiration date. The API identification number assigned to this well is 43-047-36164.

John R. BazaAssociate Director

pabEnclosures

cc: Uintah County AssessorBureau of Land Management, Vernal District Office

/1594 West North Temple, Suite 1210, PO Box 145801, Salt Lake City, UT 84114-5801telephone(801)538-5340•facsimile (801) 359-3940•TTY (801) 538-7458 •www.ogm.utah.gov Where ideas

O OOperator: Dominion Exploration & Production, Inc.Well Name & Number LCU 6-6G

API Number: 43-047-36164Lease: UTU-75700

Location: SE NW Sec._6_ T. 11 South R. 21 East

Conditions of Approval

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

2. Notification RequirementsNotify the Division within 24 hours of spudding the well.• Contact Carol Daniels at (801) 538-5284.

Notify the Division prior to commencing operations to plug and abandon the well.• Contact Dan Jarvis at (801) 538-5338

3. Reporting RequirementsAll required reports, forms and submittals will be promptly filed with the Division,including but not limited to the Entity Action Form (Form 6), Report of WaterEncountered During Drilling (Form 7), Weekly Progress Reports for drilling andcompletion operations, and Sundry Notices and Reports on Wells requesting approval ofchange of plans or other operational actions.

4. State approval of this well does not supersede the required federal approval, which must beobtained prior to drilling.

5. This proposed well is located in an area for which drilling units (well spacing patterns) havenot been established through an order of the Board of Oil, Gas and Mining (the "Board").In order to avoid the possibility of waste or injury to correlative rights, the operator isrequested, once the well has been drilled, completed, and has produced, to analyzegeological and engineering data generated therefrom, as well as any similar data fromsurrounding areas if available. As soon as is practicable after completion of its analysis,and if the analysis suggests an area larger than the quarter-quarter section upon which thewell is located is being drained, the operator is requested to seek an appropriate orderfrom the Board establishing drilling and spacing units in conformance with such analysisby filing a Request for Agency Action with the

O OOperator: Dominion Exploration & Production, Inc.Well Name & Number LCU 6-6G

API Number: 43-047-36164Lease: UTU-75700

Location: SE NW Sec._6_ T. 11 South R. 21 East

Conditions of Approval

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

2. Notification RequirementsNotify the Division within 24 hours of spudding the well.• Contact Carol Daniels at (801) 538-5284.

Notify the Division prior to commencing operations to plug and abandon the well.• Contact Dan Jarvis at (801) 538-5338

3. Reporting RequirementsAll required reports, forms and submittals will be promptly filed with the Division,including but not limited to the Entity Action Form (Form 6), Report of WaterEncountered During Drilling (Form 7), Weekly Progress Reports for drilling andcompletion operations, and Sundry Notices and Reports on Wells requesting approval ofchange of plans or other operational actions.

4. State approval of this well does not supersede the required federal approval, which must beobtained prior to drilling.

5. This proposed well is located in an area for which drilling units (well spacing patterns) havenot been established through an order of the Board of Oil, Gas and Mining (the "Board").In order to avoid the possibility of waste or injury to correlative rights, the operator isrequested, once the well has been drilled, completed, and has produced, to analyzegeological and engineering data generated therefrom, as well as any similar data fromsurrounding areas if available. As soon as is practicable after completion of its analysis,and if the analysis suggests an area larger than the quarter-quarter section upon which thewell is located is being drained, the operator is requested to seek an appropriate orderfrom the Board establishing drilling and spacing units in conformance with such analysisby filing a Request for Agency Action with the

Form 3160-3 SUBMIT IN LICATE* Form approved.(December1990) (Other instrueño Budget Bureau No. 1004-0136

U ED STATES reverse side) Expires: December 31, 1991

0 0 5 DEPARTMENT OF THE INTERIOR 5: LEASE DESIGNATION AND SERIAL NO


APPLICATION FOIUPERMIT TO DRILL OR DEEPEN & IF INDIAN,ALLOTTEE OR TRIBE NAME

N/Ala. TYPE OF WORK 7 UNIT AGREEMENT NAMEDRILL DEEPEN

b. TYPE OF WELLOIL GAS SINGLE MULTIPLE 8 FARM OR LEASE NAME,WELL NO

WELL WELL OTHER ZONE ZONE LCU 6-6G2. NAME OF OPERAT ROminion

Exploration & Production, Inc.3. ADDRESS AND TELEPHONE NO 10. FIELD AND POOL, OR WILDÓAT

14000 OuailSprings Parkway, Suite 600, Oklahoma City, OK ,-

' Natural Buttes4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.*) 11. SEC.,T.,R.,M., ORBLK.

At surface A

2,019' FNL, 1,596' FWL SE/4 NW/4 Section 6,At proposed prod. zone

2.019' FNL 1,596' FWL SE/4 NW/4 ,, ,, . . Tl lS, R21E, SLB&M14.. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* U o auQ# 12. COUNTY OR PARISH 13. STATE

14.06 miles southeast of Ourav, Utah Uintah Utah15. DISTANCE FROM PROPOSED* 16. NO. OF ACRESIN LEASE 17. NO ACRES ASSIGNED

LOCATION TO NEAREST S WELLPROPERTY OR LEASE LINE, FT.(Also to nearest drig. unit line, ifany) 623' 298.33 40 acres

18. DISTANCE FROM PROPOSED 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLSLOCATION TO NEAREST WßLL,DRILLING, COMPLETED, ORAPPLIED FOR, ON THIS LEASEST None 9,200' Rotary

21. ELEVATIONS (Show whether DF,RT,GR,etc.) 22. APPROX. DATE WORK WILL START*

. 5..414' GR | March 15, 200523. PROPOSED CASING AND CEMENTING PROGRAM

SIZE OF HOLE GRADE, SIZE OF CASING WEIGHT PERFOOT SETTING DEPTH QUANTITY OF CEMENT


7-7/8" 5-1/2" Mav 80 LT&C 17# 9,200' 160 sks Lead, 435 sks Tail-see attached Drilling Plan

Bond Information:Bond coverage is provided by Travelers Casualty and Surety Company of America, Bond #768 63050 0330

RECElVEDOther Information:

Drilling Plan and Surfàce Use Plan are attached· MAY24 2005Dominion requests that this complete application for permit to drill be held confidential.

DIV.0FOlL,GAS&MINING

NOTICEOF APPROVALORIGINAL

CÓNDIT4GNSOFAPPROVALATTACHECONl1DENTIAL

IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen, give data present productive zone and proposed new productive zone If proposal is to drill or deepen directionany, givepertinent dataon subsurface locations and measured and true vertical depths. Give blowout preventer program, if any.

24.

SIGE DOn Hamilton TrrLE Agent for Dominion DATE December 13, 2004


PERMITNO. APPROVALDATF

Application approval does not warrant or c applicant legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon,CONDITIONS OF IF AssistantReid ManagerAPPRO TITLE AGÍÑACOUrnOR DATE - r V


Form 3160-3 SUBMIT IN LICATE* Form approved.(December1990) (Other instrueño Budget Bureau No. 1004-0136

U ED STATES reverse side) Expires: December 31, 1991

0 0 5 DEPARTMENT OF THE INTERIOR 5: LEASE DESIGNATION AND SERIAL NO


APPLICATION FOIUPERMIT TO DRILL OR DEEPEN & IF INDIAN,ALLOTTEE OR TRIBE NAME

N/Ala. TYPE OF WORK 7 UNIT AGREEMENT NAMEDRILL DEEPEN

b. TYPE OF WELLOIL GAS SINGLE MULTIPLE 8 FARM OR LEASE NAME,WELL NO

WELL WELL OTHER ZONE ZONE LCU 6-6G2. NAME OF OPERAT ROminion

Exploration & Production, Inc.3. ADDRESS AND TELEPHONE NO 10. FIELD AND POOL, OR WILDÓAT

14000 OuailSprings Parkway, Suite 600, Oklahoma City, OK ,-

' Natural Buttes4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.*) 11. SEC.,T.,R.,M., ORBLK.

At surface A

2,019' FNL, 1,596' FWL SE/4 NW/4 Section 6,At proposed prod. zone

2.019' FNL 1,596' FWL SE/4 NW/4 ,, ,, . . Tl lS, R21E, SLB&M14.. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* U o auQ# 12. COUNTY OR PARISH 13. STATE

14.06 miles southeast of Ourav, Utah Uintah Utah15. DISTANCE FROM PROPOSED* 16. NO. OF ACRESIN LEASE 17. NO ACRES ASSIGNED

LOCATION TO NEAREST S WELLPROPERTY OR LEASE LINE, FT.(Also to nearest drig. unit line, ifany) 623' 298.33 40 acres

18. DISTANCE FROM PROPOSED 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLSLOCATION TO NEAREST WßLL,DRILLING, COMPLETED, ORAPPLIED FOR, ON THIS LEASEST None 9,200' Rotary

21. ELEVATIONS (Show whether DF,RT,GR,etc.) 22. APPROX. DATE WORK WILL START*

. 5..414' GR | March 15, 200523. PROPOSED CASING AND CEMENTING PROGRAM

SIZE OF HOLE GRADE, SIZE OF CASING WEIGHT PERFOOT SETTING DEPTH QUANTITY OF CEMENT


7-7/8" 5-1/2" Mav 80 LT&C 17# 9,200' 160 sks Lead, 435 sks Tail-see attached Drilling Plan

Bond Information:Bond coverage is provided by Travelers Casualty and Surety Company of America, Bond #768 63050 0330

RECElVEDOther Information:

Drilling Plan and Surfàce Use Plan are attached· MAY24 2005Dominion requests that this complete application for permit to drill be held confidential.

DIV.0FOlL,GAS&MINING

NOTICEOF APPROVALORIGINAL

CÓNDIT4GNSOFAPPROVALATTACHECONl1DENTIAL

IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen, give data present productive zone and proposed new productive zone If proposal is to drill or deepen directionany, givepertinent dataon subsurface locations and measured and true vertical depths. Give blowout preventer program, if any.

24.

SIGE DOn Hamilton TrrLE Agent for Dominion DATE December 13, 2004


PERMITNO. APPROVALDATF

Application approval does not warrant or c applicant legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon,CONDITIONS OF IF AssistantReid ManagerAPPRO TITLE AGÍÑACOUrnOR DATE - r V


COAs Page 1 of 6Well No.: LCU 6-6G

CONDITIONS ORAPPROVALAPPLICATIONFOR PERMIT TO DRlLI

Company/Operator: Dominion E&P Inc.

Well Name & Number: LCU 6-6G

API Number: 43-047-36164

Lease Number: U-75700

Location: SENW Sec. _6_ T.11S R. 21E

Agreement: N/A

For more specific details on notificationrequirements, please check the Conditions ofApproval for Notice to Drilland Surface Use Program.

CONDITIONS OF APPROVAL FOR NOTICE TO DRILL

Approval of this application does not warrant or certifythat the applicant holds legal orequitable titleto those rights in the subject lease which would entitle the applicant toconduct operations thereon.

Be aware fire restrictions may be in effect when location is being constructed and/orwhen well is being drilled. Contact the appropriate Surface Management Agency forinformation.

1. Estimated Depth at Which Oil, Gas, Water, or Other Mineral Bearinq Zones areExpected to be Encountered

Report AL water shows and water-bearing sands to John Mayers of this office prior tosetting the next casing string or requesting plugging orders. Faxed copies ofState of Utah form OGC-8-X are acceptable. If noticeable water flows are detected,submit samples to this office along with any water analyses conducted.

All usable water and prospectively valuable minerals (as described by BLM at onsite)encountered during drilling, willbe recorded by depth and adequately protected. Alloiland gas shows willbe tested to determine commercial potential.

2. Pressure Control Equipment

The BOP and related equipment shall meet the minimumrequirements of Onshore Oiland Gas Order No. 2 for equipment and testing requirements, procedures, etc., for a2 system and individual components shall be operable as designed. Chart recordersshall be used for all pressure


CONDITIONS ORAPPROVALAPPLICATIONFOR PERMIT TO DRlLI

Company/Operator: Dominion E&P Inc.

Well Name & Number: LCU 6-6G

API Number: 43-047-36164

Lease Number: U-75700

Location: SENW Sec. _6_ T.11S R. 21E

Agreement: N/A

For more specific details on notificationrequirements, please check the Conditions ofApproval for Notice to Drilland Surface Use Program.

CONDITIONS OF APPROVAL FOR NOTICE TO DRILL

Approval of this application does not warrant or certifythat the applicant holds legal orequitable titleto those rights in the subject lease which would entitle the applicant toconduct operations thereon.

Be aware fire restrictions may be in effect when location is being constructed and/orwhen well is being drilled. Contact the appropriate Surface Management Agency forinformation.

1. Estimated Depth at Which Oil, Gas, Water, or Other Mineral Bearinq Zones areExpected to be Encountered

Report AL water shows and water-bearing sands to John Mayers of this office prior tosetting the next casing string or requesting plugging orders. Faxed copies ofState of Utah form OGC-8-X are acceptable. If noticeable water flows are detected,submit samples to this office along with any water analyses conducted.

All usable water and prospectively valuable minerals (as described by BLM at onsite)encountered during drilling, willbe recorded by depth and adequately protected. Alloiland gas shows willbe tested to determine commercial potential.

2. Pressure Control Equipment

The BOP and related equipment shall meet the minimumrequirements of Onshore Oiland Gas Order No. 2 for equipment and testing requirements, procedures, etc., for a2 system and individual components shall be operable as designed. Chart recordersshall be used for all pressure

O O COAs Page 2 of 6Well No.: LCU 6-6G

Test charts, with individual test results identified, shall be maintainecfon löcatión whiledrillingand shall be made available to a BLM representative upon request.

3. Casinq Proqram and Auxiliary Equipment

Surface casing shall have centralizers on the bottom three joints,with a minimumof onecentralizer per joint.Surface casing setting depths are based on gräund level elevationsonly

As a minimumrequirement, the cement behind production casing must extend at least200' above the base of usable water which has been identified at ±3714'.

4. Mud Proqram and Circulatinq Medium

None

5. Corinq; Loqqinq and Testinq Program

A cement bond log (CBL)willbe run from the production casing shoe to the surfacecasing shoe and shall be utilizedto determine the bond quality for the production casing

Please submit to this office, in LAS format, an electronic copy of all logs run onthis well This submission will replace the requirement for submittal of paper logsto the BLM. The cement bond log must be submitted in raster format (TIF, PDF orother).

Daily drilling and completion progress reports shall be submitted to this office on aweekly basis.

6. Notifications of Operations

Operator shall report production data to MMS pursuant to 30 CFR 216.5 using formMMS/3160.

The date on which production is commenced or resumed will be construed for oil wellsas the date on which liquid hydrocarbons are first sold or shipped from a temporarystorage facility, such as a test tank, and for which a run ticket is required to begenerated or, the date on which liquid hydrocarbons are first produced into a permanentstorage facility, whichever first occurs; and, for gas wells as the date on whichassociated liquid hydrocarbons are first sold or shipped from a temporarystoragefacility, such as a test tank, and for which a run ticket is required to be generated or, thedate on which gas is first measured throughpermanent metering facilities, whicheverfirst occurs.

Should gas be vented or flared without approval beyond the authorized test period, theoperator may be directed to shut-in the well untilthe gas can be captured or approval tocontinue venting or flaring as uneconomic is granted and the operator shall be requiredto compensate the lessor for that portion of the gas vented or flared without


Test charts, with individual test results identified, shall be maintainecfon löcatión whiledrillingand shall be made available to a BLM representative upon request.

3. Casinq Proqram and Auxiliary Equipment

Surface casing shall have centralizers on the bottom three joints,with a minimumof onecentralizer per joint.Surface casing setting depths are based on gräund level elevationsonly

As a minimumrequirement, the cement behind production casing must extend at least200' above the base of usable water which has been identified at ±3714'.

4. Mud Proqram and Circulatinq Medium

None

5. Corinq; Loqqinq and Testinq Program

A cement bond log (CBL)willbe run from the production casing shoe to the surfacecasing shoe and shall be utilizedto determine the bond quality for the production casing

Please submit to this office, in LAS format, an electronic copy of all logs run onthis well This submission will replace the requirement for submittal of paper logsto the BLM. The cement bond log must be submitted in raster format (TIF, PDF orother).

Daily drilling and completion progress reports shall be submitted to this office on aweekly basis.

6. Notifications of Operations

Operator shall report production data to MMS pursuant to 30 CFR 216.5 using formMMS/3160.

The date on which production is commenced or resumed will be construed for oil wellsas the date on which liquid hydrocarbons are first sold or shipped from a temporarystorage facility, such as a test tank, and for which a run ticket is required to begenerated or, the date on which liquid hydrocarbons are first produced into a permanentstorage facility, whichever first occurs; and, for gas wells as the date on whichassociated liquid hydrocarbons are first sold or shipped from a temporarystoragefacility, such as a test tank, and for which a run ticket is required to be generated or, thedate on which gas is first measured throughpermanent metering facilities, whicheverfirst occurs.

Should gas be vented or flared without approval beyond the authorized test period, theoperator may be directed to shut-in the well untilthe gas can be captured or approval tocontinue venting or flaring as uneconomic is granted and the operator shall be requiredto compensate the lessor for that portion of the gas vented or flared without

COAs Page 3 of 6Well No.; LCU 6-6G

which is determined to have been avoidably lost.

7. Other Information

All loading lines will be placed inside the berm surrounding the tank battery

All off-lease storage, off-lease measurement, or comminglirtgonlease or off-lease willhave prior written approval from the AO.

The oil and gas measurement facilities willbe installed on the well location. The oilandgas meters willbe calibrated in place prior to any deliveries and tested for meteraccuracy at least quarterly thereafter. The AO willbe provided with a date and timeforthe initial meter calibration and all future meter proving schedules. A copy of the metercalibration reports will be submitted to the Vernal District Office. All metermeasurement facilitieswillconform with Onshore Oil & Gas Order No. 4 for liquidhydrocarbons and Onshore Oil& Gas Order No. 5 for natural gas measurement.

The use of materials under BLMjurisdictionwillconform to 43 CFR 3610.2-3.

There will be no deviation from the proposed drilling and/or workover program withoutprior approval from the AO. Safe drilling and operating practices must be observed. Allwells, whether drilling, producing, suspended, or abandoned willbe identified inaccordance with 43 CFR 3162.

"Sundry Notice and Report on Wells" (Form 3160-5) willbe filed for approval for allchanges of plans and other operations in accordance with 43 CFR 3162.3-2.

Section 102(b)(3) of the Federal Oil and Gas Royalty Management Act of 1982, asimplemented by the applicable provisions of the operating regulations at Title 43 CFR3162.4-1(c), requires that "not later than the 5th business day after any well beginsproduction on which royalty is due anywhere on a lease site or allocated to a lease site,or resumes production in the case of a wellwhich has been off production for more than90 days, the operator shall notifythe authorized officer by letter or sundry notice, Form3160-5, or orally to be followed by a letter or sundry notice, of the date on which suchproduction has begun or resumed."

If you fail to comply with this requirement in the manner and timeallowed, you shall beliable for a civilpenalty of up to $10,000 per violation for each day such violationcontinues, not to exceed a maximum of 20 days. See Section 109(c)(3) of the FederalOil and Gas Royalty Management Act of 1982 and the implementing regulations at Title43 CFR 3162.4-1(b)(5)(ii). APD approval is valid for a period of one (1) year from thesignature date. An extension period may be granted, if requested, prior to the expirationof the original approval

COAs Page 3 of 6Well No.; LCU 6-6G

which is determined to have been avoidably lost.

7. Other Information

All loading lines will be placed inside the berm surrounding the tank battery

All off-lease storage, off-lease measurement, or comminglirtgonlease or off-lease willhave prior written approval from the AO.

The oil and gas measurement facilities willbe installed on the well location. The oilandgas meters willbe calibrated in place prior to any deliveries and tested for meteraccuracy at least quarterly thereafter. The AO willbe provided with a date and timeforthe initial meter calibration and all future meter proving schedules. A copy of the metercalibration reports will be submitted to the Vernal District Office. All metermeasurement facilitieswillconform with Onshore Oil & Gas Order No. 4 for liquidhydrocarbons and Onshore Oil& Gas Order No. 5 for natural gas measurement.

The use of materials under BLMjurisdictionwillconform to 43 CFR 3610.2-3.

There will be no deviation from the proposed drilling and/or workover program withoutprior approval from the AO. Safe drilling and operating practices must be observed. Allwells, whether drilling, producing, suspended, or abandoned willbe identified inaccordance with 43 CFR 3162.

"Sundry Notice and Report on Wells" (Form 3160-5) willbe filed for approval for allchanges of plans and other operations in accordance with 43 CFR 3162.3-2.

Section 102(b)(3) of the Federal Oil and Gas Royalty Management Act of 1982, asimplemented by the applicable provisions of the operating regulations at Title 43 CFR3162.4-1(c), requires that "not later than the 5th business day after any well beginsproduction on which royalty is due anywhere on a lease site or allocated to a lease site,or resumes production in the case of a wellwhich has been off production for more than90 days, the operator shall notifythe authorized officer by letter or sundry notice, Form3160-5, or orally to be followed by a letter or sundry notice, of the date on which suchproduction has begun or resumed."

If you fail to comply with this requirement in the manner and timeallowed, you shall beliable for a civilpenalty of up to $10,000 per violation for each day such violationcontinues, not to exceed a maximum of 20 days. See Section 109(c)(3) of the FederalOil and Gas Royalty Management Act of 1982 and the implementing regulations at Title43 CFR 3162.4-1(b)(5)(ii). APD approval is valid for a period of one (1) year from thesignature date. An extension period may be granted, if requested, prior to the expirationof the original approval

O COAs Page 4 of 6Well No.: LCU 6-6G

In the event after÷hoursapprovals ãre necessary you rriust contáct one of theiolloWiniindividuals:

KirkFleetwood (435) 828-7874Petroleum Engineer

Michael Lee (435) 828-7875Petroleum Engineer

BLM FAX Machine 435)

O COAs Page 4 of 6Well No.: LCU 6-6G

In the event after÷hoursapprovals ãre necessary you rriust contáct one of theiolloWiniindividuals:

KirkFleetwood (435) 828-7874Petroleum Engineer

Michael Lee (435) 828-7875Petroleum Engineer

BLM FAX Machine 435)


EPA'S blŠT OF NONEXEMPT EXPEORATION AND PRODUCTION WASTES

While the following wastes are nónexempt, they are not necessarily hazardous.

Unused fracturing fluids or acids

Gas plant cooling towercleaning wastesPainting wastes

Oil and gas service company wastes, such as empty drums, drum rinsate, vacuum truckrinsate, sandblast media, painting wastes, spend solvents, spilled chemicals, and waste

acids

Vacuum truckand drum rinsate from trucksand drums, transportingor containing

nonexempt waste

Refinery wastesLiquid and solid wastes generated by crude oil and tank bottom reclaimers

Used equipment lubrication oilsWaste compressor oil, filters, and blowdown

Used hydraulic fluids

Waste solventsWaste in transportationpipeline-related pits

Caustic or acid cleaners

Boiler cleaning wastesBoiler refractory bricks

incinerator ashLaboratory wastes

Sanitary wastesPesticide wastes

Radioactive tracer wastesDrums, insulation and miscellaneous


EPA'S blŠT OF NONEXEMPT EXPEORATION AND PRODUCTION WASTES

While the following wastes are nónexempt, they are not necessarily hazardous.

Unused fracturing fluids or acids

Gas plant cooling towercleaning wastesPainting wastes

Oil and gas service company wastes, such as empty drums, drum rinsate, vacuum truckrinsate, sandblast media, painting wastes, spend solvents, spilled chemicals, and waste

acids

Vacuum truckand drum rinsate from trucksand drums, transportingor containing

nonexempt waste

Refinery wastesLiquid and solid wastes generated by crude oil and tank bottom reclaimers

Used equipment lubrication oils

Waste compressor oil, filters, and blowdown

Used hydraulic fluids

Waste solventsWaste in transportationpipeline-related pits

Caustic or acid cleaners

Boiler cleaning wastesBoiler refractory bricks

incinerator ashLaboratory wastes

Sanitary wastesPesticide wastes

Radioactive tracer wastesDrums, insulation and miscellaneous


At the timethat any of the wells are no longer in operation, Each well shall be pluggedand the location and access road shall be reclaimed. All disturbed surfaces shall be re-contoured to near natural contours. Ary stockpiled top soils shall be spread over the re-contoured surfaces and reseeded with the following seed mixture:

Seed Mixture: Ibslacreshadscale Atriplex confertifolia 4Gardners salt bush Atriplexgardneri 4Galleta grass Hilaria jamesil 4

Seed should be drilled but if broadcasted double the pounds per acre used andwork the soils mechanically to cover the seed.

Stock piled top soils shall be seed immediately after development with the sameseed mixture as for reclamation and the seed worked into the soil with the tracksof the "cat".

1. No surface disturbance or drilling shall occur April 1 -- August 15 to protectpotential burrowing owl nesting unless the authorized officer determines thatthe species is not utilizingthe area and provides a waiver.

No surface disturbance or drilling shall occur May 15 - June 20 to protect potentialantelope kidding unless the authorized officerdetermines that the species is notutilizingthe area and provides a


At the timethat any of the wells are no longer in operation, Each well shall be pluggedand the location and access road shall be reclaimed. All disturbed surfaces shall be re-contoured to near natural contours. Ary stockpiled top soils shall be spread over the re-contoured surfaces and reseeded with the following seed mixture:

Seed Mixture: Ibslacreshadscale Atriplex confertifolia 4Gardners salt bush Atriplexgardneri 4Galleta grass Hilaria jamesil 4

Seed should be drilled but if broadcasted double the pounds per acre used andwork the soils mechanically to cover the seed.

Stock piled top soils shall be seed immediately after development with the sameseed mixture as for reclamation and the seed worked into the soil with the tracksof the "cat".

1. No surface disturbance or drilling shall occur April 1 -- August 15 to protectpotential burrowing owl nesting unless the authorized officer determines thatthe species is not utilizingthe area and provides a waiver.

No surface disturbance or drilling shall occur May 15 - June 20 to protect potentialantelope kidding unless the authorized officerdetermines that the species is notutilizingthe area and provides a

OSTATE OF UTAH FORM 6

DEPARTMENT OF NATURALRESOURCESDIVISION OF OIL,GAS AND MINING

ENTITY ACTION FORM

Operator: Dominion Exploration & Production, Inc· Operator Account Number: N 1095

Address: 14000 Quail Springs Parkway, Suite 600

city Oklahoma City

state Ok zip 73134 Phone Number: (405) 749-1300

Well 1

API Number Well Name QQ Sec Twp Rng County43-047-36164 LCU 6-6G SENW 6 11S 21E Uintah

Action Code Current Entity New Entity Spud Date Entity AssignmentNumber Number Effective Date

9/21/2005 /Û AO OfComments:

Well 2

API Number Well Name QQ Sec Twp Rng County


Comments:

Well 3



Comments:

ACTION CODES:A - Establish new entity for new well (single well only) Carla Christian

B - Add new well to existing entity (groupor unit well) ge (Please Pring, I

C - Re-assign well from one existing entity to another existing entityD - Re-assign well from one existing entity to a new entity S gnature

E - Other(Explain in'comments'section) RECEIVEDÊegulatorySpecialist ia0/14/2005

(5/2000) OCT18 2005DiV.0FOlL,GAS&

OSTATE OF UTAH FORM 6

DEPARTMENT OF NATURALRESOURCESDIVISION OF OIL,GAS AND MINING

ENTITY ACTION FORM



city Oklahoma City


Well 1


43-047-36164 LCU 6-6G SENW 6 11S 21E Uintah


9/21/2005 /Û AO OfComments:

Well 2



Comments:

Well 3



Comments:


B - Add new well to existing entity (groupor unit well) ge (Please Pring, I

C - Re-assign well from one existing entity to another existing entityD - Re-assign well from one existing entity to a new entity S gnature

E - Other(Explain in'comments'section) RECEIVEDÊegulatorySpecialist ia0/14/2005

(5/2000) OCT18 2005DiV.0FOlL,GAS&

Form 3160-5

(August, 1999) UNITE ATES FORM APPROVEDDEPARTMENT HE INTERIOR OMB No. 1004-0135BUREAU OF LAND MANAGEMENT Expires: November 30, 2000

5. Lease Serial No.

SUNDRY NOTICES AND REPORTS ON WELLS UTU-75700Do not use this form for proposals to drill or to re-enter an 6. If Indian, Allottee or Tribe Name

abandoned well. Use Form 3160-3 (APD) for such proposals.7. If Unit or CA/Agreement, Nameand/or No.

l.Type ellWell

GasWell ther CONFilENTlR= - ""'°"2. NameofOperator LCU 6-6G

9. API Well No.Dominion Exploration & Production, Inc.3a. Address Suite 600 3b. Phone No (include area code) 43-047-3616414000 Quail Springs Parkway, OKC, OK 73134 (405) 749-5263 10. Field and Pool, or Exploratory Area4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Natural Buttes

11. County or Parish, State2019' FNL & 1596' FWL, Sec. 6-118-21E Uintah, UT

12.. CHECK APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT OR OTHER DATA

TYPE OF SUBMISSION TYPE OF ACTION

O Notice of Intent Acidize Deepen Production (Start/Resume) Water Shut-Off

Altering Casing Fracture Treat Reclamation Well Integrity

Subsequent Report Casing Repair New Construction Recomplete Other

Change Plans Plug and Abandon Temporarily Abandon Drilling Operations

O Final Abandonment Notice Convert to Injection Plug Back Water Disposal

13 Describe Proposed or Completed Operation (clearly state all pertinent details, including estimated starting date of any proposed work and approximate duration thereof.If the proposal is to deepen directionallyor recomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones.Attach the Bond under which the work willbe performed or provide the Bond No. on filewith BLM/BIA. Required subsequent reports shall be filedwithin 30 daysfollowing completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval, a Form 3160-4 shall be filed oncetesting has been completed. Final Abandonment Notices shall be filedonly after all requirements, including reclamation, have been completed and the operator hasdetermined that the site is ready for final inspection.)

Spud well 9/21/05. 9/21/05 ran 52 jts. 8 5/8", 32#, J-55 csg., set @2218'. Cemented lead w/250 sks Hi-Fil V, 11.0 ppg,3.82 yld, tailedw/225 sks Class G, 15.8 ppg, 1.15 yld, top offwl200 sks pump thru200' of 1" @ 15.8 ppg, 1.15 yld., 35bbis cmt. to pit.

14. I hereby certify that the foregoing is true and correctName (Pnnted/Oped)

Carla Christian Title Regulatory Specialist

SignatureDate 10/17/2005

Approved by Title DateConditiÖÑËÃr ËÍ, , ÃÏeÃÑache(L Ãpprovalof this notice does not warrant orcertify that the applicant holds legal or equitable titleto those rights in the subject lease Officewhich would entitle the applicant to conduct operations thereon.

Title 18 U.S.C. Section 1001 and Title 43 U.S.C. Section 1212, makes it a crime for any person knowingly and willfully to make to any department or agency of theUnited States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction.

BECENED

004i § 2005

DN,07OLGAS&

Form 3160-5


5. Lease Serial No.


abandoned well. Use Form 3160-3 (APD) for such proposals.7. If Unit or CA/Agreement, Nameand/or No.

l.Type ellWell

GasWell ther CONFilENTlR= - ""'°"2. NameofOperator LCU 6-6G

9. API Well No.Dominion Exploration & Production, Inc.3a. Address Suite 600 3b. Phone No (include area code) 43-047-3616414000 Quail Springs Parkway, OKC, OK 73134 (405) 749-5263 10. Field and Pool, or Exploratory Area4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Natural Buttes

11. County or Parish, State

2019' FNL & 1596' FWL, Sec. 6-118-21E Uintah, UT




Altering Casing Fracture Treat Reclamation Well Integrity


Change Plans Plug and Abandon Temporarily Abandon Drilling Operations


13 Describe Proposed or Completed Operation (clearly state all pertinent details, including estimated starting date of any proposed work and approximate duration thereof.If the proposal is to deepen directionallyor recomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones.Attach the Bond under which the work willbe performed or provide the Bond No. on filewith BLM/BIA. Required subsequent reports shall be filedwithin 30 daysfollowing completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval, a Form 3160-4 shall be filed oncetesting has been completed. Final Abandonment Notices shall be filedonly after all requirements, including reclamation, have been completed and the operator hasdetermined that the site is ready for final inspection.)

Spud well 9/21/05. 9/21/05 ran 52 jts. 8 5/8", 32#, J-55 csg., set @2218'. Cemented lead w/250 sks Hi-Fil V, 11.0 ppg,3.82 yld, tailedw/225 sks Class G, 15.8 ppg, 1.15 yld, top offwl200 sks pump thru200' of 1" @ 15.8 ppg, 1.15 yld., 35bbis cmt. to pit.

14. I hereby certify that the foregoing is true and correctName (Pnnted/Oped)


SignatureDate 10/17/2005

Approved by Title DateConditiÖÑËÃr ËÍ, , ÃÏeÃÑache(L Ãpprovalof this notice does not warrant orcertify that the applicant holds legal or equitable titleto those rights in the subject lease Officewhich would entitle the applicant to conduct operations thereon.

Title 18 U.S.C. Section 1001 and Title 43 U.S.C. Section 1212, makes it a crime for any person knowingly and willfully to make to any department or agency of theUnited States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction.

BECENED

004i § 2005

DN,07OLGAS&

From ominion E&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 10/26/2005 Time: 2:55:16 PM Page 1 of 2

FACSIMILECOVER PAGETo : Utah Division of Oil, Gas & Mining From : gSent : 10/26/2005 at 2:16:04 PM Pages : 2 (including Cover)Subject : LCU6-6G p gg gg gg

CONFilENTA

RECElVEDOCT282005

DIV.0F0lL,GAS&

From ominion E&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 10/26/2005 Time: 2:55:16 PM Page 1 of 2

FACSIMILECOVER PAGETo : Utah Division of Oil, Gas & Mining From : gSent : 10/26/2005 at 2:16:04 PM Pages : 2 (including Cover)Subject : LCU6-6G p gg gg gg

CONFilENTA

RECElVEDOCT282005

DIV.0F0lL,GAS&

'From: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 10/26/2005 Time: 2:55:16 PM Page 2 of 2

Page: 1

9- WELL CHRONOLOGYREPORT

WELL NAME: LCU 6-6G Event No: 1DISTRICT:WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019' FNL1596' FWLSEC 6 T 118 R 21E

COUNTY&STATE: UINTAH UT CONTRACTOR:

WI % : 100.00 AFE#: 0503657 API#: 43-047-36164 PLANDEPTH :9,000 SPUDDATE : 09/21/05

DHC: $485,900 CWC: $597,000 AFETOTAL: $1,082,900 FORMATION: WASATCHIMESAVERDE

EVENTDC: $191,191.00 EVENTCC: $0.00 EVENTTC: $191,191.00 WELLTOTLCOST: $191,191

REPORTDATE: 09/23/05 MD:2,250 TVD:2,250 DAYS: MW: VISC:

DAILY: DC: $191,191.00 CC: $0.00 TC: $191,191.00 CUM : DC:$191,191.0D CC: $0.00 TC: $191,191.00DAILYDETAILS: MIRUBILLJRS#4. SPUD WELLON 9-21-05 @11:00 AM.DRILLL2250' OF 12.25" HOLE.RUN 52 JT'S8.625", 32#,

J-55 CSGN. SET @2218'. CEMENTW/ 250 SKS [email protected] PPG &3.82 YLD.THEN225 SKS [email protected] PPG & 1.15 YLD.THENTOP OFF W/ 200 SKS PUMPTHRU 200' OF 1 [email protected] PPG & 1.15 YLD.WI 35BBLSCEMENTTO PIT.

RECEIVEDOCT2 6 2005

Copyright© 1993-2005 by Epoch WellServices Inc. Allrightsreselved.DIVOFOIL,GAS&

'From: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 10/26/2005 Time: 2:55:16 PM Page 2 of 2

Page: 1

9- WELL CHRONOLOGYREPORT

WELL NAME: LCU 6-6G Event No: 1DISTRICT:WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019' FNL1596' FWLSEC 6 T 118 R 21E

COUNTY&STATE: UINTAH UT CONTRACTOR:

WI % : 100.00 AFE#: 0503657 API#: 43-047-36164 PLANDEPTH :9,000 SPUDDATE : 09/21/05

DHC: $485,900 CWC: $597,000 AFETOTAL: $1,082,900 FORMATION: WASATCHIMESAVERDE


REPORTDATE: 09/23/05 MD:2,250 TVD:2,250 DAYS: MW: VISC:

DAILY: DC: $191,191.00 CC: $0.00 TC: $191,191.00 CUM : DC:$191,191.0D CC: $0.00 TC: $191,191.00DAILYDETAILS: MIRUBILLJRS#4. SPUD WELLON 9-21-05 @11:00 AM.DRILLL2250' OF 12.25" HOLE.RUN 52 JT'S8.625", 32#,

J-55 CSGN. SET @2218'. CEMENTW/ 250 SKS [email protected] PPG &3.82 YLD.THEN225 SKS [email protected] PPG & 1.15 YLD.THENTOP OFF W/ 200 SKS PUMPTHRU 200' OF 1 [email protected] PPG & 1.15 YLD.WI 35BBLSCEMENTTO PIT.

RECEIVEDOCT2 6 2005

Copyright© 1993-2005 by Epoch WellServices Inc. Allrightsreselved.DIVOFOIL,GAS&

FÅ:DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 11/2/2005 Time: 2:46:58 PM Page 1 of 2

FACSIMILECOVER PAGETo : Utah Division of Oil, Gas & Mining From : gSent : 11/2/2005 at 2:32:30 PM Pages : 2 (including Cover)Subject: LCU6-6G Ñ$ K 34 3- RP-¾gg

CONFIDENTIAL

RECEIVEDNOVO22005

DIV.0F0tL,GAS&

FÅ:DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 11/2/2005 Time: 2:46:58 PM Page 1 of 2

FACSIMILECOVER PAGETo : Utah Division of Oil, Gas & Mining From : gSent : 11/2/2005 at 2:32:30 PM Pages : 2 (including Cover)Subject: LCU6-6G Ñ$ K 34 3- RP-¾gg

CONFIDENTIAL

RECEIVEDNOVO22005

DIV.0F0tL,GAS&

From:DominionE&P 94057496657 To: Utah Division of Oil,Gas &Mining Date: 11/2/2005 Time:2:46:58 PM Page 2 of 2

Page: 1

WELL CHRONOLOGYREPORT

WELL NAME : LCU6-6G Event No: 1DISTRICT: WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019' FNL1596' FWLSEC6 T 118 R 21E

COUNTY&STATE : UINTAH UT CONTRACTOR:

Wl*/o : 100.00 AFE#: 0503657 API#: 41047-36164 PLANDEPTH:9,000 SPUDDATE: 09/21/05

DHC: $485,900 CWC: $597,000 AFE TOTAL: $1,082,900 FORMATION: WASATCH/MESAVERDE


REPORTDATE: 10/27/05 MD:2,250 TVD:2,250 DAYS: 1 MW: VISC:

DAILY: DC: $23,280.00 CC:$0.00 TC:$23,280.00 CUM: DC:$214,471.00 CC: $0.00 TC:$214,471.00

DAILYDETAILS: MIRUPATTERSON#104. SET EQUIPMENT.FUNCTIONTEST EQUIPMENT.

REPORTDATE: 10/28/05 MD:2,250 TVD:2,250 DAYS: 2 MW:8.4 VISC:26

DAILY: DC: $22,130.00 CC:$0.00 TC:$22,130.00 CUM: DC:$236,601.00 CC: $0.00 TC:$236,601.00DAILYDETAILS:CON'TTO RIG UP. TEST EQUlPMENT.WORKON RIG PUMPS. PRESSURE TEST KELLY,TlW, FLOORVALVETO

3,000 PSI HIGHI250PSI LOW.TEST BLIND&PIPE RAMSTO 3000 PSI HIGH/250PSI LOW.CHOKEMANIFOLD3000 PSI HIGHI250PSI LOW.CSGN&ANNULARTO 1500 PSI HIGH/250PSI LOW.PU BHA& DRILLSTRING.TAGCEMENT@2140'

REPORT DATE: 10/29/05 MD: 3,424 TVD:3,424 DAYS: 3 MW:8.4 VISC: 26


DAILYDETAILS:TAG CEMENT@2169'. DRILLCEMENT&SHOE @2215'. DRILL7.875" HOLEFROM2215' TO A DEPTHOF 2291'.Wl8KWOB &75 RPMS. FITTEST @2291'. HELD220 PSI FOR 15 MINS.WIRELINESURVEY@2251' = 1*.DRLGFROM 2291' TO 3330'. W/ 15KWOB &45/90 RPMS.WlRELINESURVEY@3258' = .75*. DRLGFROM3330' TO3424'. WI18 KWOB&45/90 RPMS.

REPORTDATE: 10/30/05 MD:5,314 TVD:5,314 DAYS: 4 MW:8.4 VISC:26DAILY: DC: $26,810.00 CC:$0.00 TC:$26,810.00 CUM: DC:$286,026.00 CC: $0.00 TC:$286,026.00

DAILYDETAILS:DRILLING7.875" HOLEFROM3424' TO 4306'. Wl15K WOB &45/75 RPMS. WIRELINESURVEY@4236' = 1.5*.RIG SERVICE. BOP FUNCTIONTEST. BOP/FIREDRILL(90 SEC.) DRLGFROM4306'TO 5314'. Wl20 K WOB &45/65 RPMS.



DAILYDETAILS:WIRELINESURVEY@5242' = 2*. DRILLINGA 7.875" HOLEFROM 5314' TO A DEPTHOF 5784'. Wl18K WOB &45/75 RPMS. RIGSERVICE & BOP FUNCTIONTEST. BOP / FIRE DRILL(100 SEC) DRLGFROM 5784' TO 6319'.W/ 18KWOB &45 RPMS. WIRELINESURVEY@6247' = 2*. DRLGFROM6319' TO 6698'. W/ 20KWOB&50 RPMS.

REPORTDATE: 11/01/05 MD:7,987 TVD:7,987 DAYS: 6 MW:8.6 VISC:26DAILY: DC: $27,505.00 CC: $0.00 TC: $27,505.00 CUM: DC:$383,455.00 CC: $0.00 TC: $383,455.00DAILYDETAILS: DRILLING7.875" HOLEFROM6698' TO 7326'. Wl18K WOB &50 RPMS. RIGSERVICE. BOP FUNCTIONTEST.

BOP/FIRE DRILL(75 SEC.) WIRELINESURVEY@7256' = 2.25*. DRLGFROM7326' TO 7987'. Wl22K WOB&50RPMS.



DAILYDETAILS: DRILLING7.875" HOLEFROM7987' TO A DEPTHOF 8144'. WI25K WOB &45/65 RPMS. TOH W/ DRILLSTRING&BHA.CHANGEBITTO #2. TIHW/ BIT#2, & BHA. FILLPlPE, BREAKCIRCULATION.CIRCULATEWELLBORECLEAN.DRLGFROM 8144' TO 8239'. Wl13K WOB&55 RPMS. WIRELINESURVEY@8169' = 2.75*. DRLGFROM8239' TO 8553'. W/ 15KWOB & 45 RPMS.

RECEIVEDCopyright© 199&2005 by Epoch WellServices Inc. Allrightsreserved.

DIV.0F0lkGAS&

From:DominionE&P 94057496657 To: Utah Division of Oil,Gas &Mining Date: 11/2/2005 Time:2:46:58 PM Page 2 of 2

Page: 1


WELL NAME : LCU6-6G Event No: 1DISTRICT: WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019' FNL1596' FWLSEC6 T 118 R 21E

COUNTY&STATE : UINTAH UT CONTRACTOR:

Wl*/o : 100.00 AFE#: 0503657 API#: 41047-36164 PLANDEPTH:9,000 SPUDDATE: 09/21/05

DHC: $485,900 CWC: $597,000 AFE TOTAL: $1,082,900 FORMATION: WASATCH/MESAVERDE


REPORTDATE: 10/27/05 MD:2,250 TVD:2,250 DAYS: 1 MW: VISC:


DAILYDETAILS: MIRUPATTERSON#104. SET EQUIPMENT.FUNCTIONTEST EQUIPMENT.



DAILYDETAILS:CON'TTO RIG UP. TEST EQUlPMENT.WORKON RIG PUMPS. PRESSURE TEST KELLY,TlW, FLOORVALVETO3,000 PSI HIGHI250PSI LOW.TEST BLIND&PIPE RAMSTO 3000 PSI HIGH/250PSI LOW.CHOKEMANIFOLD3000 PSI HIGHI250PSI LOW.CSGN&ANNULARTO 1500 PSI HIGH/250PSI LOW.PU BHA& DRILLSTRING.TAGCEMENT@2140'

REPORT DATE: 10/29/05 MD: 3,424 TVD:3,424 DAYS: 3 MW:8.4 VISC: 26


DAILYDETAILS:TAG CEMENT@2169'. DRILLCEMENT&SHOE @2215'. DRILL7.875" HOLEFROM2215' TO A DEPTHOF 2291'.Wl8KWOB &75 RPMS. FITTEST @2291'. HELD220 PSI FOR 15 MINS.WIRELINESURVEY@2251' = 1*.DRLGFROM 2291' TO 3330'. W/ 15KWOB &45/90 RPMS.WlRELINESURVEY@3258' = .75*. DRLGFROM3330' TO3424'. WI18 KWOB&45/90 RPMS.

REPORTDATE: 10/30/05 MD:5,314 TVD:5,314 DAYS: 4 MW:8.4 VISC:26DAILY: DC: $26,810.00 CC:$0.00 TC:$26,810.00 CUM: DC:$286,026.00 CC: $0.00 TC:$286,026.00

DAILYDETAILS:DRILLING7.875" HOLEFROM3424' TO 4306'. Wl15K WOB &45/75 RPMS. WIRELINESURVEY@4236' = 1.5*.RIG SERVICE. BOP FUNCTIONTEST. BOP/FIREDRILL(90 SEC.) DRLGFROM4306'TO 5314'. Wl20 K WOB &45/65 RPMS.



DAILYDETAILS:WIRELINESURVEY@5242' = 2*. DRILLINGA 7.875" HOLEFROM 5314' TO A DEPTHOF 5784'. Wl18K WOB &45/75 RPMS. RIGSERVICE & BOP FUNCTIONTEST. BOP / FIRE DRILL(100 SEC) DRLGFROM 5784' TO 6319'.W/ 18KWOB &45 RPMS. WIRELINESURVEY@6247' = 2*. DRLGFROM6319' TO 6698'. W/ 20KWOB&50 RPMS.

REPORTDATE: 11/01/05 MD:7,987 TVD:7,987 DAYS: 6 MW:8.6 VISC:26DAILY: DC: $27,505.00 CC: $0.00 TC: $27,505.00 CUM: DC:$383,455.00 CC: $0.00 TC: $383,455.00DAILYDETAILS: DRILLING7.875" HOLEFROM6698' TO 7326'. Wl18K WOB &50 RPMS. RIGSERVICE. BOP FUNCTIONTEST.

BOP/FIRE DRILL(75 SEC.) WIRELINESURVEY@7256' = 2.25*. DRLGFROM7326' TO 7987'. Wl22K WOB&50RPMS.



DAILYDETAILS: DRILLING7.875" HOLEFROM7987' TO A DEPTHOF 8144'. WI25K WOB &45/65 RPMS. TOH W/ DRILLSTRING&BHA.CHANGEBITTO #2. TIHW/ BIT#2, & BHA. FILLPlPE, BREAKCIRCULATION.CIRCULATEWELLBORECLEAN.DRLGFROM 8144' TO 8239'. Wl13K WOB&55 RPMS. WIRELINESURVEY@8169' = 2.75*. DRLGFROM8239' TO 8553'. W/ 15KWOB & 45 RPMS.

RECEIVEDCopyright© 199&2005 by Epoch WellServices Inc. Allrightsreserved.

DIV.0F0lkGAS&

Fr¾: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 11/10/2005 Time: 1:14:02 PM Page 1 of 2

FACSIMILECOVER PAGEUtah Division of Oil, Gas & Mining From : g

Sent : 11/10/2005 at 12:40:08 PM Pages : 2 (including Cover)Subject: LCU6-6G gg/ 5 3-Oý'ÿ... y‡¿y

RECEIVEDNOV1 0 2005

DIV.0FOIL,GAS&

Fr¾: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 11/10/2005 Time: 1:14:02 PM Page 1 of 2

FACSIMILECOVER PAGEUtah Division of Oil, Gas & Mining From : g

Sent : 11/10/2005 at 12:40:08 PM Pages : 2 (including Cover)Subject: LCU6-6G gg/ 5 3-Oý'ÿ... y‡¿y

RECEIVEDNOV1 0 2005

DIV.0FOIL,GAS&

From:Dominion E&P 94057496657 To: Utah Divisionof Oil, Gas &Mining Date: 11/10/2005 Time: 1:14:02 PM Page 2 of 2

Page: 1


WELL NAME : LCU6-6G Event No: 1DISTRICT: WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019'FNL1596'FWl..SEC6 T 11S R 21ECOUNTY&STATE : UINTAH UT CONTRACTOR:

WI */o : 100.00 AFE #: 0503657 API #: 43-047-36164 PLANDEPTH :9,000 SPUDDATE: 09/21/05DHC:$485,900 CWC:$597,000 AFETOTAL:$1,082,900 FORMATION: WASATCHIMESAVERDEEVENTDC: $780,612.00 EVENTCC: $0.00 EVENTTC: $780,612.00 WELLTOTLCOST: $883,667

REPORT DATE: 11/02/05 MD: 8,553 TVD:8,553 DAYS: 7 MW:8.6 VISC: 26DAILY: DC: $33,573.00 CC:$0.00 TC:$33,573.00 CUM: DC:$417,028.00 CC: $0.00 TC:$417,028.00DAILYDETAILS: DRILLING7.875" HOLEFROM7987' TO A DEPTHOF 8144'. W/ 25KWOB & 45/65 RPMS. TOH WI DRILLSTRING&

BHA.CHANGEBITTO #2. TlHW/ BIT#2, & BHA. FILLPIPE, BREAKClRCULATION.CIRCULATEWELLBORECLEAN.DRLGFROM8144' TO 8239'. W/ 13KWOB&55 RPMS. WlRELINESURVEY@8169' = 2.75*. DRLGFROM8239' TO 8553'. WI15K WDB &45 RPMS.

REPORT DATE: 11/03/05 MD: 8,822 TVD:8,822 DAYS: 8 MW:9 VISC: 34DAILY: DC: $35,230.00 CC: $0.00 TC:$35,230.00 CUM: DC:$452,258.00 CC: $0.00 TC: $452,258.00DAILYDETAILS:DRILLING7.875" HOLEFROM 8553' TO A DEPTHOF 8585'. Wl20KWOB &45 RPMS. RIGSERVICE. SAFTEY

INSPECTION.BOP FUNCTIONTEST. DRLGFROM8585' TO 8616'. W. 25 KWOB &45 RPMS. WORKTIGHTSPOT,CONDITIONMUD/ HOLE. DRLG FROM8616' TO 8655' W/ 25K WOB&45/75 RPMS. TOH FOR BHAINSPECTION.REPLACEBIT(#3).TlHW/ BHA.SLIP &CUT DRILLLINE.TlHW/ DRILLSTRING &BHA.FILLPIPE BREAKCIRCULATION.DRILL7.875" HOLEFROM8655' TO 8822'. W/ 13 KWOB &45 / 65 RPMS.

REPORTDATE: 11/04/05 MD:9,068 TVD:9,068 DAYS: 9 MW:9.2 VISC:38DAILY: DC: $84,205.00 CC:$0.00 TC:$84,205.00 CUM: DC:$536,463.00 CC: $0.00 TC:$536,463.00DAILYDETAILS:DRILLING7.875" HOLEFROM8822' TO 8895'. W/25K WOB &45 RPMS. TOH W/ 5 STANDS. REPAIRWASHOUT

INSTANDPIPE. TlHW/ 5 STANDS. BREAKCIRCULATIONDRLGFROM 8895' TO A TD DEPTHOF 9068' @11:30PM ON 11-3-05. CIRCULATEWELLBORE CLEAN.PUlMP PILL.TOHW/ DRILLSTRING& BHA.FOR LOGS. RIGUPSCHLUMBERGERWlRELINE& RUN LOGS.

REPORT DATE: 11/05/05 MD:9,068 TVD:9,068 DAYS: 10 MW:9 VISC: 34DAILY:DC: $52,182.00 CC:$0.00 TC:$52,182.00 CUM: DC:$588,645.00 CC: $0.00 TC:$588,645.00DAILYDETAILS:TRIP INHOLE FOR CLEANOUT RUN FOR LOGSCIRC/COND MUD-HOLEWAITON SCHLUMBERGERTRIP OOH

FOR LOGS RIG UP SCHLUMBERGERMAKEUP ANDPICKUP TOOLS RIHWITHLOGGINGTOOLS RUNTRIPPLECOMBO FROM9040 TO 2232 KBMRIG DOWNSCHLUMBERGER RELEASESAMELAYDOWNBHATRIP INHOLEClRC/CONDTO LAYDOWNDRLGPIPE RIG UP T&MCASINGSERVICE SAFETYMEETINGLAYDOWNDRLGPIPE

REPORT DATE: 11/06/05 MD:9,068 TVD:9,068 DAYS: 11 MW:9 VISC: 34DAILY: DC: $191,967.00 CC:$0.0D TC:$191,967.00 CUM: DC:$780,612.00 CC: $0.00 TC:$780,612.00DAILYDETAILS: LAYDOWNDRLGPIPE ANDBHARIG UPT&MCASINGSERVICE SAFETYMEETING RUNCASING5.50 IN-80

/17#lLTC/212JTS PLUS2 MARKERJTS ATTEMPTTO CIRCULATECASINGTO LANDCANNOTCIRC CSGLANDCSG SHOE AT-9032 KB FLOAT8988 KB NIPPLEUP RIG PUMP CIRC HOLE RIG DOWNT&MCASINGSERVICE RIG UP HALLIBURTONHOLDSAFETYMEETING PRESSURE TEST PUMPILINESSTARTCEMENTJOB START MUDFLUSHSTARTSPACER SHUT DOWNPUMPINGWELLPRESSURED UP /WELLPACKEDOFFSURGE TO ESTABLISHCIRCULATIONGETTINGPARTIALRETURNSSHUT DOWNPUMPINGWITHHALLlBURTONCHANGEOVER TO RIG PUMP CIRCHOLEWITHMUDCONTINUETO PUMP MUDTO CLEANUPPACKEDOFF CSG SURGE /PUMP TO GET RETURNS PARTIALRETURNS/FULLRETURNSClRCULATEHOLECLEANUP PACKEDOFF CSG /HOLETO NORMALCIRC PSI 124-STROKES AT560-PSI CIRC PRESSURECHANGEOVER TO HALLIBURTONTO CEMENTCSG START MUDFLUSHISPACER / START LEADCEMENT60-SX TAILCEMENT-850SXCEMENTJOB WENTGOOD END CEMENTJOB WASH UP /RIG DOWNHALLIBURTONRELEASE SAMESET SLIPS WITH120KCLEANPITS RIG DOWNPATTERSON-104 RELEASERIG11/6/2005 AT10;00HRS

RECEIVEDNOV1O2005

Copyright© 1993-2005 by Epoch WellServices Inc. Alllights reserved.DIV.0F0lL,GAS&

From:Dominion E&P 94057496657 To: Utah Divisionof Oil, Gas &Mining Date: 11/10/2005 Time: 1:14:02 PM Page 2 of 2

Page: 1


WELL NAME : LCU6-6G Event No: 1DISTRICT: WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019'FNL1596'FWl..SEC6 T 11S R 21ECOUNTY&STATE : UINTAH UT CONTRACTOR:

WI */o : 100.00 AFE #: 0503657 API #: 43-047-36164 PLANDEPTH :9,000 SPUDDATE: 09/21/05DHC:$485,900 CWC:$597,000 AFETOTAL:$1,082,900 FORMATION: WASATCHIMESAVERDEEVENTDC: $780,612.00 EVENTCC: $0.00 EVENTTC: $780,612.00 WELLTOTLCOST: $883,667

REPORT DATE: 11/02/05 MD: 8,553 TVD:8,553 DAYS: 7 MW:8.6 VISC: 26DAILY: DC: $33,573.00 CC:$0.00 TC:$33,573.00 CUM: DC:$417,028.00 CC: $0.00 TC:$417,028.00DAILYDETAILS: DRILLING7.875" HOLEFROM7987' TO A DEPTHOF 8144'. W/ 25KWOB & 45/65 RPMS. TOH WI DRILLSTRING&

BHA.CHANGEBITTO #2. TlHW/ BIT#2, & BHA. FILLPIPE, BREAKClRCULATION.CIRCULATEWELLBORECLEAN.DRLGFROM8144' TO 8239'. W/ 13KWOB&55 RPMS. WlRELINESURVEY@8169' = 2.75*. DRLGFROM8239' TO 8553'. WI15K WDB &45 RPMS.

REPORT DATE: 11/03/05 MD: 8,822 TVD:8,822 DAYS: 8 MW:9 VISC: 34DAILY: DC: $35,230.00 CC: $0.00 TC:$35,230.00 CUM: DC:$452,258.00 CC: $0.00 TC: $452,258.00DAILYDETAILS:DRILLING7.875" HOLEFROM 8553' TO A DEPTHOF 8585'. Wl20KWOB &45 RPMS. RIGSERVICE. SAFTEY

INSPECTION.BOP FUNCTIONTEST. DRLGFROM8585' TO 8616'. W. 25 KWOB &45 RPMS. WORKTIGHTSPOT,CONDITIONMUD/ HOLE. DRLG FROM8616' TO 8655' W/ 25K WOB&45/75 RPMS. TOH FOR BHAINSPECTION.REPLACEBIT(#3).TlHW/ BHA.SLIP &CUT DRILLLINE.TlHW/ DRILLSTRING &BHA.FILLPIPE BREAKCIRCULATION.DRILL7.875" HOLEFROM8655' TO 8822'. W/ 13 KWOB &45 / 65 RPMS.

REPORTDATE: 11/04/05 MD:9,068 TVD:9,068 DAYS: 9 MW:9.2 VISC:38DAILY: DC: $84,205.00 CC:$0.00 TC:$84,205.00 CUM: DC:$536,463.00 CC: $0.00 TC:$536,463.00DAILYDETAILS:DRILLING7.875" HOLEFROM8822' TO 8895'. W/25K WOB &45 RPMS. TOH W/ 5 STANDS. REPAIRWASHOUT

INSTANDPIPE. TlHW/ 5 STANDS. BREAKCIRCULATIONDRLGFROM 8895' TO A TD DEPTHOF 9068' @11:30PM ON 11-3-05. CIRCULATEWELLBORE CLEAN.PUlMP PILL.TOHW/ DRILLSTRING& BHA.FOR LOGS. RIGUPSCHLUMBERGERWlRELINE& RUN LOGS.

REPORT DATE: 11/05/05 MD:9,068 TVD:9,068 DAYS: 10 MW:9 VISC: 34DAILY:DC: $52,182.00 CC:$0.00 TC:$52,182.00 CUM: DC:$588,645.00 CC: $0.00 TC:$588,645.00DAILYDETAILS:TRIP INHOLE FOR CLEANOUT RUN FOR LOGSCIRC/COND MUD-HOLEWAITON SCHLUMBERGERTRIP OOH

FOR LOGS RIG UP SCHLUMBERGERMAKEUP ANDPICKUP TOOLS RIHWITHLOGGINGTOOLS RUNTRIPPLECOMBO FROM9040 TO 2232 KBMRIG DOWNSCHLUMBERGER RELEASESAMELAYDOWNBHATRIP INHOLEClRC/CONDTO LAYDOWNDRLGPIPE RIG UP T&MCASINGSERVICE SAFETYMEETINGLAYDOWNDRLGPIPE

REPORT DATE: 11/06/05 MD:9,068 TVD:9,068 DAYS: 11 MW:9 VISC: 34DAILY: DC: $191,967.00 CC:$0.0D TC:$191,967.00 CUM: DC:$780,612.00 CC: $0.00 TC:$780,612.00DAILYDETAILS: LAYDOWNDRLGPIPE ANDBHARIG UPT&MCASINGSERVICE SAFETYMEETING RUNCASING5.50 IN-80

/17#lLTC/212JTS PLUS2 MARKERJTS ATTEMPTTO CIRCULATECASINGTO LANDCANNOTCIRC CSGLANDCSG SHOE AT-9032 KB FLOAT8988 KB NIPPLEUP RIG PUMP CIRC HOLE RIG DOWNT&MCASINGSERVICE RIG UP HALLIBURTONHOLDSAFETYMEETING PRESSURE TEST PUMPILINESSTARTCEMENTJOB START MUDFLUSHSTARTSPACER SHUT DOWNPUMPINGWELLPRESSURED UP /WELLPACKEDOFFSURGE TO ESTABLISHCIRCULATIONGETTINGPARTIALRETURNSSHUT DOWNPUMPINGWITHHALLlBURTONCHANGEOVER TO RIG PUMP CIRCHOLEWITHMUDCONTINUETO PUMP MUDTO CLEANUPPACKEDOFF CSG SURGE /PUMP TO GET RETURNS PARTIALRETURNS/FULLRETURNSClRCULATEHOLECLEANUP PACKEDOFF CSG /HOLETO NORMALCIRC PSI 124-STROKES AT560-PSI CIRC PRESSURECHANGEOVER TO HALLIBURTONTO CEMENTCSG START MUDFLUSHISPACER / START LEADCEMENT60-SX TAILCEMENT-850SXCEMENTJOB WENTGOOD END CEMENTJOB WASH UP /RIG DOWNHALLIBURTONRELEASE SAMESET SLIPS WITH120KCLEANPITS RIG DOWNPATTERSON-104 RELEASERIG11/6/2005 AT10;00HRS

RECEIVEDNOV1O2005

Copyright© 1993-2005 by Epoch WellServices Inc. Alllights reserved.DIV.0F0lL,GAS&

From: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 11/16/2005 Time: 1:34:48 PM Page 1 of 4FAbSIMILE COVERPAGFTo : Utah Division of Oil, Gas & Mining From : gSent : 11/16/2005 at 1:15:02 PM Pages : 4 (including Cover)Subject: LCU6-6G 3 çŸrk. 3£//

RECEIVEDNOV162005

DIVOFOILGAS&

From: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 11/16/2005 Time: 1:34:48 PM Page 1 of 4FAbSIMILE COVERPAGFTo : Utah Division of Oil, Gas & Mining From : gSent : 11/16/2005 at 1:15:02 PM Pages : 4 (including Cover)Subject: LCU6-6G

3 çŸrk. 3£//

RECEIVEDNOV162005

DIVOFOILGAS&

From:DominionE&P 94057496657 To: UtahDivisionof Oil,Gas &Mining Date: 11/16/2005 Time:1:34:48 PM Page 2 of 4

Page: 1


WELL NAME : LCU 6-6G Event No: 1DISTRICT: WESTERN FIELD:NATURALBUTTES630 LOCATION: 2019' FNL1596' FWLSEC6 T 118 R 21ECOUNTY&STATE : UINTAH UT CONTRACTOR:WI% : 100.00 AFE#: 0503657 API#: 43-047-36164 PLANDEPTH:9,000 SPUDDATE : 09/21/05DHC: $485,900 CWC: $597,000 AFE TOTAL: $1,082,900 FORMATION:WASATCHIMESAVERDEEVENTDC: $780,612.00 EVENTCC:$251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST:$1,135,009

REPORTDATE: 11/12/05 MD: 9,068 TVD:9,068 DAYS: 13 MW: VISC:DAILY:DC: $0.00 CC:$251,342.00 TC:$251,342.00 CUM: DC:$780,612.00 CC: $251,342.00 TC:$1,031,954.00DAILYDETAILS:

RECEIVEDNOV16 2005

DIV.0F0lL,GAS&MINING

Copyright© 199 2005by EpochWellServices Inc. Allrights

From:DominionE&P 94057496657 To: UtahDivisionof Oil,Gas &Mining Date: 11/16/2005 Time:1:34:48 PM Page 2 of 4

Page: 1


WELL NAME : LCU 6-6G Event No: 1DISTRICT: WESTERN FIELD:NATURALBUTTES630 LOCATION: 2019' FNL1596' FWLSEC6 T 118 R 21ECOUNTY&STATE : UINTAH UT CONTRACTOR:WI% : 100.00 AFE#: 0503657 API#: 43-047-36164 PLANDEPTH:9,000 SPUDDATE : 09/21/05DHC: $485,900 CWC: $597,000 AFE TOTAL: $1,082,900 FORMATION:WASATCHIMESAVERDEEVENTDC: $780,612.00 EVENTCC:$251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST:$1,135,009

REPORTDATE: 11/12/05 MD: 9,068 TVD:9,068 DAYS: 13 MW: VISC:DAILY:DC: $0.00 CC:$251,342.00 TC:$251,342.00 CUM: DC:$780,612.00 CC: $251,342.00 TC:$1,031,954.00DAILYDETAILS:

RECEIVEDNOV16 2005

DIV.0F0lL,GAS&MINING

Copyright© 199 2005by EpochWellServices Inc. Allrights

From:DominionE&P 94057496657 To: Utah Divisionof Oil,Gas & Mining Date: 11/16/2005 Time: 1:34:48 PM Page 3 of 4

e O Page: 2


WELL NAME: LCU 6-6G Event No: 1DISTRICT: WESTERN FIELD:NATURALBUTTES630 LOCATION: 2019' FNL 1596' FWLSEC 6 T 11S R21ECOUNTY&STATE:UINTAH UT CONTRACTOR:Wl% : 100.00 AFE#: 0503657 API #: 43-047-36164 PLANDEPTH :9,000 SPUDDATE : 09/21/05DHC: $485,900 CWC: $597,000 AFE TOTAL: $1,082,900 FORMATION: WASATCHIMESAVERDEEVENTDC: $780,612.00 EVENTCC:$251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST: $1,135,009

FRAC STAGE#1, PREFORATE ANDFRACSTAGES #2 THRU#6. 11-04-05 LCU6-6G. MIRUSCHLUMBERGERfrac equipment, tested lines to 7000 psi. Held safety meeting with all personnel. Qualitycontrol on gel & breakersystems withon-site lab was verified. Frac'd Mesa Verde Intelval #1, 8700-8704', 8746-56', 8782-84', 8850-56', 3 spf,70 holes, with50,106#20/40 PR6000 sand. Pumped frac at an average rate of 40.6 bpm, using 313.6 mscf of N2and698 bbis of fluid. Average surface treatingpressure was 4667 psi withsand concentrations stair stepping from 1.0 ppgto 4.0 ppg.5591 gallons Pad YF120ST/N2 gel.2800 gallons YF120STIN2 pumped @1.0 ppg sand concentration.4218 gallons YF 120ST/N2 pumped @2.0 ppg sand concentration.4230 gallons YF 120STIN2 pumped @3.0 ppg sand concentration.

3156 gallons YF 120ST/N2 pumped @4.0 ppg sand concentration.8477 gallons WF110 slickwater flush.Total frac fluidpumped 698 bbis.N2 was cut during flush. Ru wire line, RIHand set SKfrac plug @8660'. RlHandperforate interval#2 @8412-16', 8562-64', 8599-8611', 3 spf, 57 holes. Fraced interval#2 w/ 61,326#20/40 PR6000sand. Pumped frac at an avg rate of 40.3 bpm, using 411 mscf of N2 and 821 bbis of fluid.Avgsulface treatingpressurewas 4290 psi w/ sand concentrations stair stepping from 1.0 ppg to 4.0 ppg.8336 gallons Pad YF120STIN2 gel.4206 gallons YF1205f/N2 pumped @1.0 ppg sand concentration.4215 gallons YF120ST/N2 pumped @2.0 ppg sand concentration.4213 gallons YF120STIN2 pumped @3.0 ppg sand concentration.4790 gallons YF120ST/N2 pumped @4.0 ppg sand concentration.8220 gallons WF110 slickwater flush.Total frac fluidpumped 821 bbis. N2 was cut during flush. RIHand set 8Kfrac plug @8200', perforate interval#3 @8036-45', 6 spf, 55 holes. Fraced interval#3 wl 42,451#20/40 PR6000 sand. Pumped frac at an avg rate of 29.1 bpm,using 231.7 msof of N2 and 554 bbis of fluid.Avgsurface treatingpressure was 3638 psi w/ sand concentrations stairstepping from 1.0 ppg to 4.0 ppg.4492 gallons Pad YF120LGIN2gel.2101 gallons YF120LGIN2 pumped @1.0 ppg sand concentration.2112 gallons YF120LGIN2 pumped @2.0 ppg sand concentration.2110 gallons YF120LGIN2 pumped @3.0 ppg sand concentration.4636 gallons YF120LGIN2 pumped @4.0 ppg sand concentration.7803 gallons WF110 slick water flush.Total frac fluidpumped 554 bbs. N2 was cut during flush. RIHand set 5K frac plug @7700', perforate interval#4 @7540-49', 6 spf, 55 holes. Fraced interval #4 w/ 30,797#20/40 Ottawa sand. Pumped frac at an avg rate of 23.8 bpm,using 122.5 mscf of N2 and 398 bbls of fluid.Avgsurface treatingpressure was 3582 psi w/ sand concentrations stairstepping from 2.0 ppg to 6.0 ppg.2800 gallons Pad YF120LGIN2gel.1755 gallons pumped YF120LGIN2 @2.0 ppg sand concentration.1763 gallons pumped YF120LGIN2 @4.0 ppg sand concentration.2284 gallons pumped YF120LG/N2 @6.0 ppg sand concentration.7369 gallons WF110 slick water flush.Total frac fluidpumped 398 bbis. N2 was cut during flush. RIHand set 5K frac plug @7400', perforate interval#5 @7140-44', 7220-22', 7224-26', 7292-94', 7313-15', 4 spf, 53 holes. Fraced interval#5 w/ 70,782#20/40 Ottawa sand.Pumped frac at an avg rate of 38.2 bpm, using 252.3 mscf of N2 and 629 bbis of fluid.Avgsurface treatingpressurewas 3434 psi w/ sand concentrations stair stepping from2.0 ppg to 6.0 ppg.5594 gallonsPadYF115LGIN2gel. RECEIVED2100 gallons YF115LGIN2 pumped @2.0 ppg sand concentration.2113 gallons YF115LGIN2 pumped @3.0 ppg sand concentration NOV16 20052111 gallons YF115LGIN2 pumped @4.0 ppg sand concentration.

2809 gallons YF115LGIN2 pumped @5.0 ppg sand concentration.

6952 gallons WF110 slick water flush.3267 gallons YF115LGIN2 pumped @6.0 ppg san§| büë@ki S&MINING

Total frac fluidpumped 629 bbs. N2 was cut during flush. RIHand set 5K frac plug @7050', perforate interval#6 @6774-78', 6832-37', 6 spf, 56 holes. Fraced interval#6 wl 59,275#20/40 Ottawa sand. Pumped frac at an avg rate of29.4 bpm, using260.3 msofof N2 and 500 bbis of fluid.Avgsurface treatingpressure was 3691 psi w/ sandconcentrations stair stepping from 2.0 ppg to 5.0 ppg.3499 gallons Pad YF115LGIN2gel.

Copyright© 1993-2005 by EpochWellServices Inc. Allrights

From:DominionE&P 94057496657 To: Utah Divisionof Oil,Gas & Mining Date: 11/16/2005 Time: 1:34:48 PM Page 3 of 4

e O Page: 2


WELL NAME: LCU 6-6G Event No: 1DISTRICT: WESTERN FIELD:NATURALBUTTES630 LOCATION: 2019' FNL 1596' FWLSEC 6 T 11S R21ECOUNTY&STATE:UINTAH UT CONTRACTOR:Wl% : 100.00 AFE#: 0503657 API #: 43-047-36164 PLANDEPTH :9,000 SPUDDATE : 09/21/05DHC: $485,900 CWC: $597,000 AFE TOTAL: $1,082,900 FORMATION: WASATCHIMESAVERDEEVENTDC: $780,612.00 EVENTCC:$251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST: $1,135,009

FRAC STAGE#1, PREFORATE ANDFRACSTAGES #2 THRU#6. 11-04-05 LCU6-6G. MIRUSCHLUMBERGERfrac equipment, tested lines to 7000 psi. Held safety meeting with all personnel. Qualitycontrol on gel & breakersystems withon-site lab was verified. Frac'd Mesa Verde Intelval #1, 8700-8704', 8746-56', 8782-84', 8850-56', 3 spf,70 holes, with50,106#20/40 PR6000 sand. Pumped frac at an average rate of 40.6 bpm, using 313.6 mscf of N2and698 bbis of fluid. Average surface treatingpressure was 4667 psi withsand concentrations stair stepping from 1.0 ppgto 4.0 ppg.5591 gallons Pad YF120ST/N2 gel.2800 gallons YF120STIN2 pumped @1.0 ppg sand concentration.4218 gallons YF 120ST/N2 pumped @2.0 ppg sand concentration.4230 gallons YF 120STIN2 pumped @3.0 ppg sand concentration.

3156 gallons YF 120ST/N2 pumped @4.0 ppg sand concentration.8477 gallons WF110 slickwater flush.Total frac fluidpumped 698 bbis.N2 was cut during flush. Ru wire line, RIHand set SKfrac plug @8660'. RlHandperforate interval#2 @8412-16', 8562-64', 8599-8611', 3 spf, 57 holes. Fraced interval#2 w/ 61,326#20/40 PR6000sand. Pumped frac at an avg rate of 40.3 bpm, using 411 mscf of N2 and 821 bbis of fluid.Avgsulface treatingpressurewas 4290 psi w/ sand concentrations stair stepping from 1.0 ppg to 4.0 ppg.8336 gallons Pad YF120STIN2 gel.4206 gallons YF1205f/N2 pumped @1.0 ppg sand concentration.4215 gallons YF120ST/N2 pumped @2.0 ppg sand concentration.4213 gallons YF120STIN2 pumped @3.0 ppg sand concentration.4790 gallons YF120ST/N2 pumped @4.0 ppg sand concentration.8220 gallons WF110 slickwater flush.Total frac fluidpumped 821 bbis. N2 was cut during flush. RIHand set 8Kfrac plug @8200', perforate interval#3 @8036-45', 6 spf, 55 holes. Fraced interval#3 wl 42,451#20/40 PR6000 sand. Pumped frac at an avg rate of 29.1 bpm,using 231.7 msof of N2 and 554 bbis of fluid.Avgsurface treatingpressure was 3638 psi w/ sand concentrations stairstepping from 1.0 ppg to 4.0 ppg.4492 gallons Pad YF120LGIN2gel.2101 gallons YF120LGIN2 pumped @1.0 ppg sand concentration.2112 gallons YF120LGIN2 pumped @2.0 ppg sand concentration.2110 gallons YF120LGIN2 pumped @3.0 ppg sand concentration.4636 gallons YF120LGIN2 pumped @4.0 ppg sand concentration.7803 gallons WF110 slick water flush.Total frac fluidpumped 554 bbs. N2 was cut during flush. RIHand set 5K frac plug @7700', perforate interval#4 @7540-49', 6 spf, 55 holes. Fraced interval #4 w/ 30,797#20/40 Ottawa sand. Pumped frac at an avg rate of 23.8 bpm,using 122.5 mscf of N2 and 398 bbls of fluid.Avgsurface treatingpressure was 3582 psi w/ sand concentrations stairstepping from 2.0 ppg to 6.0 ppg.2800 gallons Pad YF120LGIN2gel.1755 gallons pumped YF120LGIN2 @2.0 ppg sand concentration.1763 gallons pumped YF120LGIN2 @4.0 ppg sand concentration.2284 gallons pumped YF120LG/N2 @6.0 ppg sand concentration.7369 gallons WF110 slick water flush.Total frac fluidpumped 398 bbis. N2 was cut during flush. RIHand set 5K frac plug @7400', perforate interval#5 @7140-44', 7220-22', 7224-26', 7292-94', 7313-15', 4 spf, 53 holes. Fraced interval#5 w/ 70,782#20/40 Ottawa sand.Pumped frac at an avg rate of 38.2 bpm, using 252.3 mscf of N2 and 629 bbis of fluid.Avgsurface treatingpressurewas 3434 psi w/ sand concentrations stair stepping from2.0 ppg to 6.0 ppg.5594 gallonsPadYF115LGIN2gel. RECEIVED2100 gallons YF115LGIN2 pumped @2.0 ppg sand concentration.2113 gallons YF115LGIN2 pumped @3.0 ppg sand concentration NOV16 20052111 gallons YF115LGIN2 pumped @4.0 ppg sand concentration.

2809 gallons YF115LGIN2 pumped @5.0 ppg sand concentration.

6952 gallons WF110 slick water flush.3267 gallons YF115LGIN2 pumped @6.0 ppg san§| büë@ki S&MINING

Total frac fluidpumped 629 bbs. N2 was cut during flush. RIHand set 5K frac plug @7050', perforate interval#6 @6774-78', 6832-37', 6 spf, 56 holes. Fraced interval#6 wl 59,275#20/40 Ottawa sand. Pumped frac at an avg rate of29.4 bpm, using260.3 msofof N2 and 500 bbis of fluid.Avgsurface treatingpressure was 3691 psi w/ sandconcentrations stair stepping from 2.0 ppg to 5.0 ppg.3499 gallons Pad YF115LGIN2gel.

Copyright© 1993-2005 by EpochWellServices Inc. Allrights

From: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas & Mining Date: 11/16/2005 Time: 1:34:48 PM Page 4 of 4

Page: 3

WELLCHRONOLOGYREPORT

WELL NAME : LCUS·8G Event No: 1DISTRICT: WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019' FNL 1596' FWLSEC 6 T 118 R 21ECOUNTY&STATE : UINTAH UT CONTRACTOR:

Wl% : 100.00 AFE #: 0503657 API #: 43-047-36164 PLANDEPTH:9,000 SPUDDATE : 09/21/05

DHC:$485,900 CWC: $597,000 AFE TOTAL: $1,082,900 FORMATION: WASATCHIMESAVERDEEVENTDC: $780,612.00 EVENTCC: $251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST:$1,135,009

2101 gallons pumped YF115LGIN2 @2.0 ppg sand concentration.2110 gallons pumped YF115LGIN2 @3.0 ppg sand concentration.2807 gallons pumped YF115LGIN2 @4.0 ppg sand concentration.4281 gallons pumped YF115LGIN2 @5.0 ppg sand concentration.4762 gallons WF110 slick water flush.Total frac fluidpumped 500 bbls. N2 was not cut during flush. Opened well to the piton a 12/64 choke. Turned well overto production.

REPORTDATE: 11/13/05 MD:9,068 TVD:9,068 DAYS: 14 MW: VISC:DAILY: DC: $0.00 CC:$0.00 TC:$0.00 CUM: DC:$780,612.00 CC: $251,342.00 TC:$1,031,954.00

DAILYDETAILS: FLOWREPORT WELLFLOWINGUP CSG. TO PIT ON 12/64 CHOKEFCP1900# PUMPED3600 BBLSFRAC FLUIDRECOVERED593 BBLSCHANGEDTO 18/64 CHOKE

REPORTDATE: 11/14/05 MD:9,068 TVD:9,068 DAYS: 15 MW: VISC:DAILY:DC: $0.00 CC:$0.00 TC:$0.00 CUM: DC:$780,612.0D CC: $251,342.00 TC:$1,031,954.00

DAILYDETAILS: FLOW REPORT WELLFLOWINGUP CSG. TO PIT ON 18/64 CHOKEFCP1280# RECOVERED450 BBLSFRACFLUIDRU FLOWLINETURN TO SALES @7:30 AMON 18/64 CHOKE EST. RATE900 MCF.

REPORTDATE: 11/15/05 MD:9,068 TVD:9,068 DAYS: 16 MW: VISC:DAILY: DC: $0.00 CC:$0.00 TC:$0.00 CUM: DC:$780,612.00 CC: $251,342.00 TC:$1,031,954.00DAILYDETAILS: FLOW REPORT MADE522 MCF,FCP 1388, SLP 145, 0 OIL,352 WTR. 18/64 CHOKE19 HRS, PRD.

RECElVEDNOV16 2005

DIV,0F0lL,GAS&MINING

Copyright© 199 2005 by Epoch WellServices Inc. AIIlights

From: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas & Mining Date: 11/16/2005 Time: 1:34:48 PM Page 4 of 4

Page: 3


WELL NAME : LCUS·8G Event No: 1DISTRICT: WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019' FNL 1596' FWLSEC 6 T 118 R 21ECOUNTY&STATE : UINTAH UT CONTRACTOR:

Wl% : 100.00 AFE #: 0503657 API #: 43-047-36164 PLANDEPTH:9,000 SPUDDATE : 09/21/05

DHC:$485,900 CWC: $597,000 AFE TOTAL: $1,082,900 FORMATION: WASATCHIMESAVERDEEVENTDC: $780,612.00 EVENTCC: $251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST:$1,135,009

2101 gallons pumped YF115LGIN2 @2.0 ppg sand concentration.2110 gallons pumped YF115LGIN2 @3.0 ppg sand concentration.2807 gallons pumped YF115LGIN2 @4.0 ppg sand concentration.4281 gallons pumped YF115LGIN2 @5.0 ppg sand concentration.4762 gallons WF110 slick water flush.Total frac fluidpumped 500 bbls. N2 was not cut during flush. Opened well to the piton a 12/64 choke. Turned well overto production.


DAILYDETAILS: FLOWREPORT WELLFLOWINGUP CSG. TO PIT ON 12/64 CHOKEFCP1900# PUMPED3600 BBLSFRAC FLUIDRECOVERED593 BBLSCHANGEDTO 18/64 CHOKE

REPORTDATE: 11/14/05 MD:9,068 TVD:9,068 DAYS: 15 MW: VISC:DAILY:DC: $0.00 CC:$0.00 TC:$0.00 CUM: DC:$780,612.0D CC: $251,342.00 TC:$1,031,954.00

DAILYDETAILS: FLOW REPORT WELLFLOWINGUP CSG. TO PIT ON 18/64 CHOKEFCP1280# RECOVERED450 BBLSFRACFLUIDRU FLOWLINETURN TO SALES @7:30 AMON 18/64 CHOKE EST. RATE900 MCF.

REPORTDATE: 11/15/05 MD:9,068 TVD:9,068 DAYS: 16 MW: VISC:DAILY: DC: $0.00 CC:$0.00 TC:$0.00 CUM: DC:$780,612.00 CC: $251,342.00 TC:$1,031,954.00DAILYDETAILS: FLOW REPORT MADE522 MCF,FCP 1388, SLP 145, 0 OIL,352 WTR. 18/64 CHOKE19 HRS, PRD.

RECElVEDNOV16 2005

DIV,0F0lL,GAS&MINING

Copyright© 199 2005 by Epoch WellServices Inc. AIIlights

Form3l60-5

(August, 1999) UNITE ATES FORM APPROVEDDEPARTMENT O HE INTERIOR OMB No. 1004-0135BUREAU OF LAND MANAGEMENT Expires: November 30, 2000

5. Lease Serial No.

SUNDRY NOTICES AND REPORTS ON WELLS UTU-75700Do not use this form for proposals ta drill or to re-enter an 6. If Indian, Allottee or Tribe Name

abandoned well. Use Form 3160-3 (APD) for such proposals.7. If Unit or CA/Agreement, Name and/or No.

1. Type of Well LittleCanyon Unitil Well Gas Well ther 8. We11Name and No.

2. NameofOperator LCU 6-6G9. API Well No.

Dominion Exploration &Production, Inc.3a. Address Suite 600 3b. Phone No. (include area code) 43-047-3616414000 Quail Springs Parkway, OKC, OK 73134 (405) 749-5263 10. Field and Pool, or Exploratory Area4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Natural Buttes

11. Countyor Parish, State

2019' FNL & 1596' FWL, Sec. 6-11S-21E Uintah, UT

12. CHECK APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT OR OTHER DATA

TYPE OF SUBMISSION TYPE OE ACTION


Altering Casing Fractura Treat Reclamation Well Integrity

SubsequentReport Casing Repair New Construction Recomplete Other

Changa Plans Plug and Abandon Temporarily Abandon Drilling Operations


13 Describe Proposed or Completed Operation (clearly state all pertinent details, including estimated starting data of any proposed work and approximate duration thereof.Ifthe proposal is to deepen directionally otrecomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones.Attach tha.Bond under which the work willbe performed or provida the Bond No. on file with BLM/BIA. Required subsequent reports shall be filedwithin.30 daysfollowing completion of the involved operations. Ifthe operation results in.a.multiple completion or recompletion in a new interval, a Form 3160-4 shall be filed oncetesting has been completed.. Final Abandonment Notices shall be filed only after all requirements, including reclamation, have been completed and the operator hasdetermined that the site is ready for final inspection.)

11/5/05 ran 212 jts. 5 1/2", 17#, N-80, LT&Ccsg., set @9032'. Cemented lead w/60 sks Hi-Fill"V", 3.12 cuft/sk, 11.60ppg, tailedw/850 sks HCLType V, 1.69 cuft/sk, 13.0 ppg. Cleaned pits, released rig. WOCU.

14. I herebycertify that the foregoingis true and correctName (Printeddyped)


SignatureÁA Date 11/11/2005

Approved by Title DateConditions of approval, ifany, are attached. Approval of this notice does not warrant orcertify that the applicant holds legal or equitable titleto those rights in the subject lease Officewhich would entitle the applicant to conduct operations thereon.

Title 18 U.S.C. Section 1001 and Title 43 U.S.C. Section 1212, makes it a crime for any person knowingly and willfullyto make to any department or agency of theUnited States any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction.

RECENED

NOVi 8 2005

DN.0F0\L,GAS&

Form3l60-5

(August, 1999) UNITE ATES FORM APPROVEDDEPARTMENT O HE INTERIOR OMB No. 1004-0135BUREAU OF LAND MANAGEMENT Expires: November 30, 2000

5. Lease Serial No.

SUNDRY NOTICES AND REPORTS ON WELLS UTU-75700Do not use this form for proposals ta drill or to re-enter an 6. If Indian, Allottee or Tribe Name


1. Type of Well LittleCanyon Unitil Well Gas Well ther 8. We11Name and No.

2. NameofOperator LCU 6-6G9. API Well No.

Dominion Exploration &Production, Inc.3a. Address Suite 600 3b. Phone No. (include area code) 43-047-3616414000 Quail Springs Parkway, OKC, OK 73134 (405) 749-5263 10. Field and Pool, or Exploratory Area

4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Natural Buttes11. Countyor Parish, State

2019' FNL & 1596' FWL, Sec. 6-11S-21E Uintah, UT

12. CHECK APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT OR OTHER DATA

TYPE OF SUBMISSION TYPE OE ACTION


Altering Casing Fractura Treat Reclamation Well Integrity

SubsequentReport Casing Repair New Construction Recomplete Other

Changa Plans Plug and Abandon Temporarily Abandon Drilling Operations


13 Describe Proposed or Completed Operation (clearly state all pertinent details, including estimated starting data of any proposed work and approximate duration thereof.Ifthe proposal is to deepen directionally otrecomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones.Attach tha.Bond under which the work willbe performed or provida the Bond No. on file with BLM/BIA. Required subsequent reports shall be filedwithin.30 daysfollowing completion of the involved operations. Ifthe operation results in.a.multiple completion or recompletion in a new interval, a Form 3160-4 shall be filed oncetesting has been completed.. Final Abandonment Notices shall be filed only after all requirements, including reclamation, have been completed and the operator hasdetermined that the site is ready for final inspection.)

11/5/05 ran 212 jts. 5 1/2", 17#, N-80, LT&Ccsg., set @9032'. Cemented lead w/60 sks Hi-Fill"V", 3.12 cuft/sk, 11.60ppg, tailedw/850 sks HCLType V, 1.69 cuft/sk, 13.0 ppg. Cleaned pits, released rig. WOCU.

14. I herebycertify that the foregoingis true and correctName (Printeddyped)


SignatureÁA Date 11/11/2005

Approved by Title Date

Conditions of approval, ifany, are attached. Approval of this notice does not warrant orcertify that the applicant holds legal or equitable titleto those rights in the subject lease Officewhich would entitle the applicant to conduct operations thereon.


RECENED

NOVi 8 2005

DN.0F0\L,GAS&

m: DominionE&P 94057496657 To: Utah Divisionof Oil, Gas &Mining Date: 11/30/2005 Time: S:32:20 PM Page 1 of 2

To : Utah Division of Oil, Gas & Mining From : gSent : 11/30/2005 at 5:13:52 PM Pages : 2 (including Cover)Subject

RECEIVEDNOV38 2005

DN.0F0tL,GAS&

m: DominionE&P 94057496657 To: Utah Divisionof Oil, Gas &Mining Date: 11/30/2005 Time: S:32:20 PM Page 1 of 2

To : Utah Division of Oil, Gas & Mining From : gSent : 11/30/2005 at 5:13:52 PM Pages : 2 (including Cover)Subject

RECEIVEDNOV38 2005

DN.0F0tL,GAS&

From: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas & Mining Date: 11/30/2005 Time:5:32:20 PM Page 2 of 2

O O Page: 1


WELLNAME : LCU 6·6G Event No: 1DISTRICT:WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019'FNL 1596' FWLSEC6 T 118 R 21ECOUNTY&STATE : UINTAH UT CONTRACTOR:

WI% : 100.00 AFE#: 0503657 API#: 43-047-36164 PLANDEPTH:9,000 SPUDDATE: 09/21/05

DHC:$485,900 CWC:$597,000 AFETOTAL:$1,082,900 FORMATION: WASATCHIMESAVERDEEVENTDC: $780,612,00 EVENTCC: $251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST: $1,135,299

REPORTDATE: 11/16/05 MD:9,068 TVD:9,068 DAYS: 17 MW: VISC:DAILY: DC: $0.00 CC:$0.00 TC:$0.00 CUM: DC:$780,612.00 CC: $251,342.00 TC:$1,031,954.00DAILYDETAILS: FLOW REPORT MADE995 MCF, FCP 1394, SLP 161 20 OIL,537 WTR.

RECEIVEDNOV30 2005

Copyright© 199 2005 by Epoch WellServices Inc. AIIrightsreserved.

DIVOFOIL,GAS&

From: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas & Mining Date: 11/30/2005 Time:5:32:20 PM Page 2 of 2

O O Page: 1


WELLNAME : LCU 6·6G Event No: 1DISTRICT:WESTERN FIELD: NATURALBUTTES630 LOCATION: 2019'FNL 1596' FWLSEC6 T 118 R 21ECOUNTY&STATE : UINTAH UT CONTRACTOR:

WI% : 100.00 AFE#: 0503657 API#: 43-047-36164 PLANDEPTH:9,000 SPUDDATE: 09/21/05

DHC:$485,900 CWC:$597,000 AFETOTAL:$1,082,900 FORMATION: WASATCHIMESAVERDEEVENTDC: $780,612,00 EVENTCC: $251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST: $1,135,299


DAILYDETAILS: FLOW REPORT MADE995 MCF, FCP 1394, SLP 161 20 OIL,537 WTR.

RECEIVEDNOV30 2005

Copyright© 199 2005 by Epoch WellServices Inc. AIIrightsreserved.

DIVOFOIL,GAS&

om: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 12/7/2005 Time: 3:10:22 PM Page 1 of 2

FACSIMILECOVER PAGETo : Utah Division of Oil, Gas & Mining From : gSent : 12/7/2005 at 3:06:48 PM Pages : 2 (including Cover)Subject: LCU6-6G fg gg/SS dÚ

EECEiVEDDECO72005

om: DominionE&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 12/7/2005 Time: 3:10:22 PM Page 1 of 2

FACSIMILECOVER PAGETo : Utah Division of Oil, Gas & Mining From : gSent : 12/7/2005 at 3:06:48 PM Pages : 2 (including Cover)Subject: LCU6-6G fg gg/SS dÚ

EECEiVEDDECO72005

From:Dominion E&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 12/7/2005 Time:3:10:22 PM Page 2 of 2

Page: 1


WELL NAME : LCU6-6G Event No: 1DISTRICT: WESTERN FIELD:NATURALBUTTES630 LOCATION: 2019' FNL 1596' FWLSEC6 T 11S R 21ECOUNTY& STATE : UlNTAH UT CONTRACTOR:

WI% : 100.00 AFE#: 0503657 API #: 4&O47-36164 PLANDEPTH:9,000 SPUD DATE: 09/21/05DHC: $485,900 CWC: $597,000 AFETOTAL: $1,082,900 FORMATION: WASATCH/MESAVERDEEVENTDC: $780,612.00 EVENTCC: $251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST: $1,135,299

REPORTDATE: 11/16/05 MD: 9,068 TVD:9,068 DAYS: 17 MW: VISC:DAILY: DC: $0.00 CC:$0.00 TC:$0.00 CUM: DC:$780,612.00 CC: $251,342.00 TC:$1,031,954.00DAILYDETAILS: FLOW REPORT MADE995 MCF, FCP 1394, SLP 161 20 OIL,537 WTR.

DECO12005DB/.0FOIL,GAS° MCopyright© 1993-2005 by Epoch WellServices Inc. Allrights

From:Dominion E&P 94057496657 To: Utah Divisionof Oil,Gas &Mining Date: 12/7/2005 Time:3:10:22 PM Page 2 of 2

Page: 1


WELL NAME : LCU6-6G Event No: 1DISTRICT: WESTERN FIELD:NATURALBUTTES630 LOCATION: 2019' FNL 1596' FWLSEC6 T 11S R 21ECOUNTY& STATE : UlNTAH UT CONTRACTOR:

WI% : 100.00 AFE#: 0503657 API #: 4&O47-36164 PLANDEPTH:9,000 SPUD DATE: 09/21/05DHC: $485,900 CWC: $597,000 AFETOTAL: $1,082,900 FORMATION: WASATCH/MESAVERDEEVENTDC: $780,612.00 EVENTCC: $251,342.00 EVENTTC: $1,031,954.00 WELLTOTLCOST: $1,135,299

REPORTDATE: 11/16/05 MD: 9,068 TVD:9,068 DAYS: 17 MW: VISC:DAILY: DC: $0.00 CC:$0.00 TC:$0.00 CUM: DC:$780,612.00 CC: $251,342.00 TC:$1,031,954.00DAILYDETAILS: FLOW REPORT MADE995 MCF, FCP 1394, SLP 161 20 OIL,537 WTR.

DECO12005DB/.0FOIL,GAS° MCopyright© 1993-2005 by Epoch WellServices Inc. Allrights

Form3160-5


5. Lease Serial No.



1. Type of Well Little Canyon Unitil Well Gas Well her 8. Well Name and No.

2. Name ofOperator LCU 6-6G9. API Well No.

Dominion Exploration & Production, Inc.3a. Address Suita 600 3b. Phone No. (include area code) 43-047-3616414000 Quail Springs Parkway, OKC, OK 73134 (405) 749-5263 10.Field and Pool, or Exploratory Area4. Location of Well (Footage, Sec., T., R., M., or SurveyDescription) Natural Buttes






Altering Casing Fracture Treat Reclamation Well integrity


Change Plans Plug and Abandon Temporarily Abandon DrillingOperations

O Final Abandonment Notice Convert to Injection Pfug Back Water Disposal

13 Describe Proposed or Completed Operation (clearly state all pertinent details, including estimated starting date of any.proposed work and approximate duration thereof.Ifthe proposal is to deepen directionallyor recomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones.Attach the Bond underwhich the work willbe performed or provide the Bond No. on file withBLM/BIA. Required subsequent reports shall be filed within 30 daysfollowing completion of the involved operations. If the operation results in a multiplecompletion or recompletion in a new interval, a Form 3160-4 shall be filedoncetesting has been completed. Final Abandonment Notices shall be filed only after all requirements, including reclamation, have been completed and the operator hasdetermined.that the site is ready for final inspection.)

11/11/05 Perf'd and frac'd welL First sales 11/13/05.

14. I hereby certify that the foregoingis true and correctName gWnted)ped)


Signature Date 11/30/2005

Approved by Title DateConditions of approval, if any, are attached. Approval of this notice does not warrant orcertify that the applicant holds legal or equitable titleto those rights in the subject lease Officewhich would entitle the applicant to conduct operations thereon.


RECEiVEDDECO72005

DIV.OFO!L,GE &

Form3160-5


5. Lease Serial No.



1. Type of Well Little Canyon Unitil Well Gas Well her 8. Well Name and No.

2. Name ofOperator LCU 6-6G9. API Well No.

Dominion Exploration & Production, Inc.3a. Address Suita 600 3b. Phone No. (include area code) 43-047-3616414000 Quail Springs Parkway, OKC, OK 73134 (405) 749-5263 10.Field and Pool, or Exploratory Area4. Location of Well (Footage, Sec., T., R., M., or SurveyDescription) Natural Buttes






Altering Casing Fracture Treat Reclamation Well integrity


Change Plans Plug and Abandon Temporarily Abandon DrillingOperations

O Final Abandonment Notice Convert to Injection Pfug Back Water Disposal

13 Describe Proposed or Completed Operation (clearly state all pertinent details, including estimated starting date of any.proposed work and approximate duration thereof.Ifthe proposal is to deepen directionallyor recomplete horizontally, give subsurface locations and measured and true vertical depths of all pertinent markers and zones.Attach the Bond underwhich the work willbe performed or provide the Bond No. on file withBLM/BIA. Required subsequent reports shall be filed within 30 daysfollowing completion of the involved operations. If the operation results in a multiplecompletion or recompletion in a new interval, a Form 3160-4 shall be filedoncetesting has been completed. Final Abandonment Notices shall be filed only after all requirements, including reclamation, have been completed and the operator hasdetermined.that the site is ready for final inspection.)

11/11/05 Perf'd and frac'd welL First sales 11/13/05.

14. I hereby certify that the foregoingis true and correctName gWnted)ped)


Signature Date 11/30/2005

Approved by Title DateConditions of approval, if any, are attached. Approval of this notice does not warrant orcertify that the applicant holds legal or equitable titleto those rights in the subject lease Officewhich would entitle the applicant to conduct operations thereon.


RECEiVEDDECO72005

DIV.OFO!L,GE &

STATE OF UTAH FORM 6DEPARTMENT OF NATURALRESOURCES

DIVISIONOF OIL,GAS AND MINING

ENTITY ACTION FORM



city Oklahoma City


Well 1


Action Code Current Entity New Entity Epud Da e En Ity AssignmentNumber Number Effective Date

C 14988 14619 11/1/2005

Comments: W-« 6 CONFllENTIAL"/**

Well 2API Number Well Name QQ Sec Twp Rng County

Action Code Current Entity New Entity Spud Date En ity AssignmentNumber Number I ffective Date

Comments:


Action Code Current Entity New Entity Spud Date En Ity AssignmentNumber Number I ffective Date

Comments:


B - Add new well to existing entity (groupor unit well) N e (Plea e Print)

C - Re-assign well from one existing entity to another existing entity

D - Re-assign well from one existing entity to a new entity Signature

E - Other(Explain in'comments'sectiT4ECEIVED xÌegulatorySpecialist 9/28/2006

(5/2000)

DIV.0F0lL,GAS&

STATE OF UTAH FORM 6DEPARTMENT OF NATURALRESOURCES

DIVISIONOF OIL,GAS AND MINING

ENTITY ACTION FORM



city Oklahoma City


Well 1


Action Code Current Entity New Entity Epud Da e En Ity AssignmentNumber Number Effective Date

C 14988 14619 11/1/2005

Comments: W-« 6 CONFllENTIAL"/**

Well 2


Action Code Current Entity New Entity Spud Date En ity AssignmentNumber Number I ffective Date

Comments:


Action Code Current Entity New Entity Spud Date En Ity AssignmentNumber Number I ffective Date

Comments:


B - Add new well to existing entity (groupor unit well) N e (Plea e Print)

C - Re-assign well from one existing entity to another existing entity

D - Re-assign well from one existing entity to a new entity Signature

E - Other(Explain in'comments'sectiT4ECEIVED xÌegulatorySpecialist 9/28/2006

(5/2000)

DIV.0F0lL,GAS&

United States Department of the InteriorBUREAU OF LAND MANAGEMENT

Utah State Office TAWK PRIDE*P.O. Box 45155 *ÑgiERICA

Salt Lake City, UT 84145-0155

IN REPLY REFER TO3180UT-922

September 22, 2006

Dominion Exploration & Production, Inc.clo UnitSource incorporated11184 Huron Street, Suite 16Denver, Colorado 80234

Re: 1st Revision to the Consolidated Wasatch/Mesaverde Formation PA "A, B"2nd Revision to the Consolidated Wasatch/Mesaverde Formation PA "A, B"Little Canyon UnitUintah County, Utah

Gentlemen:

The 1st Revision to the Consolidated Wasatch/Mesaverde Formation Participating Area "A,B", LittleCanyon Unit, CRS No. UTU81878C is hereby approved effective as of November 1, 2005, pursuantto Section 11 of the Little Canyon Unit Agreement, Uintah County, Utah.

The 1st Revision of the Consolidated Wasatch/Mesaverde Formation Participating Area "A, BN

results in the addition of 459.66 acres to the participating area for a total of 1,259.02 acres and isbased upon the completionof the following wells as being capable of producing unitized substancesin paying quantities:

LCU 6-6G SENW, 6-118-21E UTU75700 4304736164LCU 2-1H NWNE, 1-118-20E UTU76274 4304736165LCU 12-36F NWSW, 36-10S-20E State 4304735613

The 2nd Revision of the Wasatch/Mesaverde Formation PA "A, B", Little Canyon Unit, CRS No.UTU81878C, is hereby approved effective December 1, 2005, pursuant to Section 11 of the LittleCanyon Unit Agreement, Uintah County, Utah.

The second Revision to the Consolidated Wasatch/Mesaverde Formation Participating Area "A, B",Little Canyon Unit, results in the addition of 120.00 acres to the participating area for a total of

i RECEIVEDSEP27 2006

DIV.0FOIL,GAS&


Utah State Office TAWK PRIDE*P.O. Box 45155 *ÑgiERICA

Salt Lake City, UT 84145-0155


September 22, 2006

Dominion Exploration & Production, Inc.clo UnitSource incorporated11184 Huron Street, Suite 16Denver, Colorado 80234

Re: 1st Revision to the Consolidated Wasatch/Mesaverde Formation PA "A, B"2nd Revision to the Consolidated Wasatch/Mesaverde Formation PA "A, B"Little Canyon UnitUintah County, Utah

Gentlemen:

The 1st Revision to the Consolidated Wasatch/Mesaverde Formation Participating Area "A,B", LittleCanyon Unit, CRS No. UTU81878C is hereby approved effective as of November 1, 2005, pursuantto Section 11 of the Little Canyon Unit Agreement, Uintah County, Utah.

The 1st Revision of the Consolidated Wasatch/Mesaverde Formation Participating Area "A, BN

results in the addition of 459.66 acres to the participating area for a total of 1,259.02 acres and isbased upon the completionof the following wells as being capable of producing unitized substancesin paying quantities:

LCU 6-6G SENW, 6-118-21E UTU75700 4304736164LCU 2-1H NWNE, 1-118-20E UTU76274 4304736165LCU 12-36F NWSW, 36-10S-20E State 4304735613

The 2nd Revision of the Wasatch/Mesaverde Formation PA "A, B", Little Canyon Unit, CRS No.UTU81878C, is hereby approved effective December 1, 2005, pursuant to Section 11 of the LittleCanyon Unit Agreement, Uintah County, Utah.

The second Revision to the Consolidated Wasatch/Mesaverde Formation Participating Area "A, B",Little Canyon Unit, results in the addition of 120.00 acres to the participating area for a total of

i RECEIVEDSEP27 2006

DIV.0FOIL,GAS&

†,379.02 acres and is base upon the completionof the following wellas being capable of producingunitized substances in paying quantities:

LCU 5-35F SWNW,35-10S-20E UTUO1470C 4304735639

Copies of the approved request are being distributed to the appropriate agencies and one copy isreturned herewith. Please advise all interested parties of the approval of the 1st and 2nd Revisionto the Consolidated Wasatch/Mesaverde Participating Area "A""B", Little Canyon Unit.

Sincerely,

/s/ Douglas F. Cook

Douglas F. CookChief, Branch ofFluid Minerals

EnclosureAs Stated

bcc: Division of Oil,Gas & MiningSITLALittle Canyon Unit w/enclosureMMS - Data Management Division (Attn: James Sykes)Oiland Gas (Attn: Judy Nordstrom)Field Manager - Vernal w/enclosureAgr. Sec. Chron.Reading FileCentral Files

CSeare:cs (09/21/06)Dominion

†,379.02 acres and is base upon the completionof the following wellas being capable of producingunitized substances in paying quantities:

LCU 5-35F SWNW,35-10S-20E UTUO1470C 4304735639

Copies of the approved request are being distributed to the appropriate agencies and one copy isreturned herewith. Please advise all interested parties of the approval of the 1st and 2nd Revisionto the Consolidated Wasatch/Mesaverde Participating Area "A""B", Little Canyon Unit.

Sincerely,

/s/ Douglas F. Cook

Douglas F. CookChief, Branch ofFluid Minerals

EnclosureAs Stated

bcc: Division of Oil,Gas & MiningSITLALittle Canyon Unit w/enclosureMMS - Data Management Division (Attn: James Sykes)Oiland Gas (Attn: Judy Nordstrom)Field Manager - Vernal w/enclosureAgr. Sec. Chron.Reading FileCentral Files

CSeare:cs (09/21/06)Dominion

Form31604 UNITED STATES FORMAPPROVED(August 1999) DEPARTMENT OF THE INTERIOR OMB NO. 1004-0137BUREAU OF LAND MANAGEMENT Expires: November30, 2000

WELL COMPLETION OR RECOMPLERON REPORT AND LOG 5. i.ease Serial No.

UTU-75700

1a. Typeof Well OilWell Gas Well Dry Other 6. If Indian, Allo#ee or TribeNameb. Typeof Completion: New Well ork Over Deepen iffResvr.

7. Unit or CA Agreement Name and No.otherLittle Canyon Unit

2. Name of Operator 8. Lease Name and Well No.Dominion Exploration & Production, Inc. LCU 6-6G

3. Address 3a. Phone No. (include area code) 9. API Well No.14000 Quail Springs Parkway - Ste. 600 - Okla. City,OK 73134 43-047-36164

4. Locationof Well (Reportlocation clearlyand in accordance with Federal requirements). ED 10. Field and Pool, or ExploratoryAtsurface 2019'FNL & 1596'FWL, SE NW JAN17 2008 v.

sT."T'ifM,noreSBlockand

At top prod. Interval reported below Surveyor Area 6-118-21EDIV.OFOIL,GAS&MINING12. Countyor Parish 13. StateAt totaldepth

Uintah UT14. Date Spudded 15. Date T.D. Reached 16. Date Completed 17. Elevations (DF, RKB, RT, GL)*

9/21/2005 11/3/20055414' GLD&A Ready to prod 11/13/2005

18. Total Depth: MD 9068' 19. Plug Back T.D.: MD 8972' 20. Depth Bridge Plug Set: MDTVD TVD TVD

21. Type Electric & Other Mechanical Logs Run (Submit copy of each) 22, Was well cored? o es (Submit analysis)Platform Express Triple Combination Log WI Was DST run? o es (Submit report)

Gamma Ray, Cement Bond Log Directional Survey? o es (Submit copy)23. Casing and Lieer Record (Report all string set in well)

Hole Size Size/Grade Wt.(#/ft) Top (MD) Bottom (MD) Stage Cementer No. of Sks & Slurry Voi Cement Top* Amount PulledDepth Type of Cement (BBL)12 114" 8 518" 32# Surface 2218' 675 Sx Circ.7 7/8" 5112" 17# Surface 9032' 910 Sx Est. TOÒ@ 2650'

24. Tubing RecordSize Depth Set (MD) Packer Depth (MD) Size Depth Set (MD) Packer Depth (MD) Size Depth Set(MD) Packer Depth (MD)

25 Producing Intervals Q 26. Perforation RecordFormation Top Bottom Perforated Interval Size No. Holes Perf.Status

A)B)cio) See AttachmentE)F)G)27. Acid, Fracture, Treatment, Cement squeeze,Etc.

Depth Interval Amount and Type of Material

See Attachment

Date First i est Hours i est Oil Gas Water Os!Gravity Gas Production MethodProduced Date Tested Production BBL MCF BBL Corr API Gravity

11/13/2005 12/29/2005 24 5 743 64 FlowingChoke Tbg.Press. Csg. 24 Hr Oil Gas Water Gas:Oil Well StatusSize Fing. Press. Rate BBL MCF BBL Ratio

48 0 81 5 743 64 1;148,600 Producing28a. Production - Interval 8Date First Test ours Test Oil Gas er Oil Gravity Gas Production MethodProduced Date sted Produc on BBL MCF BL Corr API Gravity

(See instructions and spaces for additional data on reve e

Form31604 UNITED STATES FORMAPPROVED(August 1999) DEPARTMENT OF THE INTERIOR OMB NO. 1004-0137BUREAU OF LAND MANAGEMENT Expires: November30, 2000

WELL COMPLETION OR RECOMPLERON REPORT AND LOG 5. i.ease Serial No.

UTU-75700

1a. Typeof Well OilWell Gas Well Dry Other 6. If Indian, Allo#ee or TribeNameb. Typeof Completion: New Well ork Over Deepen iffResvr.

7. Unit or CA Agreement Name and No.otherLittle Canyon Unit

2. Name of Operator 8. Lease Name and Well No.Dominion Exploration & Production, Inc. LCU 6-6G

3. Address 3a. Phone No. (include area code) 9. API Well No.14000 Quail Springs Parkway - Ste. 600 - Okla. City,OK 73134 43-047-36164

4. Locationof Well (Reportlocation clearlyand in accordance with Federal requirements). ED 10. Field and Pool, or ExploratoryAtsurface 2019'FNL & 1596'FWL, SE NW JAN17 2008 v.

sT."T'ifM,noreSBlockand

At top prod. Interval reported below Surveyor Area 6-118-21EDIV.OFOIL,GAS&MINING12. Countyor Parish 13. StateAt totaldepth

Uintah UT14. Date Spudded 15. Date T.D. Reached 16. Date Completed 17. Elevations (DF, RKB, RT, GL)*

9/21/2005 11/3/20055414' GLD&A Ready to prod 11/13/2005

18. Total Depth: MD 9068' 19. Plug Back T.D.: MD 8972' 20. Depth Bridge Plug Set: MDTVD TVD TVD

21. Type Electric & Other Mechanical Logs Run (Submit copy of each) 22, Was well cored? o es (Submit analysis)Platform Express Triple Combination Log WI Was DST run? o es (Submit report)

Gamma Ray, Cement Bond Log Directional Survey? o es (Submit copy)23. Casing and Lieer Record (Report all string set in well)

Hole Size Size/Grade Wt.(#/ft) Top (MD) Bottom (MD) Stage Cementer No. of Sks & Slurry Voi Cement Top* Amount PulledDepth Type of Cement (BBL)12 114" 8 518" 32# Surface 2218' 675 Sx Circ.7 7/8" 5112" 17# Surface 9032' 910 Sx Est. TOÒ@ 2650'

24. Tubing RecordSize Depth Set (MD) Packer Depth (MD) Size Depth Set (MD) Packer Depth (MD) Size Depth Set(MD) Packer Depth (MD)

25 Producing Intervals Q 26. Perforation RecordFormation Top Bottom Perforated Interval Size No. Holes Perf.Status

A)B)cio) See AttachmentE)F)G)27. Acid, Fracture, Treatment, Cement squeeze,Etc.

Depth Interval Amount and Type of Material

See Attachment

Date First i est Hours i est Oil Gas Water Os!Gravity Gas Production MethodProduced Date Tested Production BBL MCF BBL Corr API Gravity

11/13/2005 12/29/2005 24 5 743 64 FlowingChoke Tbg.Press. Csg. 24 Hr Oil Gas Water Gas:Oil Well StatusSize Fing. Press. Rate BBL MCF BBL Ratio

48 0 81 5 743 64 1;148,600 Producing28a. Production - Interval 8Date First Test ours Test Oil Gas er Oil Gravity Gas Production MethodProduced Date sted Produc on BBL MCF BL Corr API Gravity

(See instructions and spaces for additional data on reve e

28b Production - Interval CDate First Test Hours Test Oil Gas Water Oil Gravay Gas Production MethodProduced Date Tested Production BBL MCF BBL Corr API Gravity

Choke Tbg.Press. Csg. 24 Hr Oil Gas Water Gas:Oil Well StalusSize FIwg. Press. Rate BBL MCF BBL Ratio

Si

28c. Production - Interval DDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MelhodProduced Dale Tested Production BBL MCF BBL Corr.API Gravity

Choko Ibg.Press. Csg. 24 Hr Oil Gas Water Gas:Oil Well StatusSize Fing. Press. Rate BBL MCF BBL Ratio

Si

29. Dispostion of Gas (Sold,used ior fuel, vented, etc )Sold

30. Summary of Porous 2ones (include Aquifers): 31. Formation (Log) Markers

Show all important zones of porosity and contents thereof Cored Intervals and all drill-stemtests, including depth interval tested,cushion used, timetoolopen, flowing and shut-inpressuresand recoveries.

Formation Top Bottom Descritpion, Contents, etc. NameMeas. Depth

Wasatch Tongue 3674'Uteland Limestone 3996'Wasatach 4132'Chapita Wells 4969'Uteland Buttes 6019'Mesaverde 6851'

32. Additional remarks (include plugging procedure)

33. Circleenclosed attachments:

Electrical/Mechanical Logs (1 full set req'd) 2. GeologicReport 3. DST Report 4. Directional Survey

5 Sundry Notice for pluggingand cement verification 6. Core Analysis 7. Other:

34. I hereby certifythattheforegoing and attached information is complete and correct as determined from allavailablerecords (see attached instructions)*

Name (please pring Carla Christian Tine Regulatory Specialist

Signature A4 Date January 12, 2006

Title 18 U.S.C. Section 1001 and Title 43 U.S.C. Section 1212. make it a crime for any person knowingly and willfullyto make to any department or agency of the United Statesany false, fictitious or fradulent statements or representations as to any matter within its jurisdiction.

4 U.S. GPO:

28b Production - Interval CDate First Test Hours Test Oil Gas Water Oil Gravay Gas Production MethodProduced Date Tested Production BBL MCF BBL Corr API Gravity

Choke Tbg.Press. Csg. 24 Hr Oil Gas Water Gas:Oil Well StalusSize FIwg. Press. Rate BBL MCF BBL Ratio

Si

28c. Production - Interval DDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MelhodProduced Dale Tested Production BBL MCF BBL Corr.API Gravity

Choko Ibg.Press. Csg. 24 Hr Oil Gas Water Gas:Oil Well StatusSize Fing. Press. Rate BBL MCF BBL Ratio

Si

29. Dispostion of Gas (Sold,used ior fuel, vented, etc )Sold

30. Summary of Porous 2ones (include Aquifers): 31. Formation (Log) Markers

Show all important zones of porosity and contents thereof Cored Intervals and all drill-stemtests, including depth interval tested,cushion used, timetoolopen, flowing and shut-inpressuresand recoveries.

Formation Top Bottom Descritpion, Contents, etc. NameMeas. Depth

Wasatch Tongue 3674'Uteland Limestone 3996'Wasatach 4132'Chapita Wells 4969'Uteland Buttes 6019'Mesaverde 6851'

32. Additional remarks (include plugging procedure)

33. Circleenclosed attachments:

Electrical/Mechanical Logs (1 full set req'd) 2. GeologicReport 3. DST Report 4. Directional Survey

5 Sundry Notice for pluggingand cement verification 6. Core Analysis 7. Other:

34. I hereby certifythattheforegoing and attached information is complete and correct as determined from allavailablerecords (see attached instructions)*

Name (please pring Carla Christian Tine Regulatory Specialist

Signature A4 Date January 12, 2006

Title 18 U.S.C. Section 1001 and Title 43 U.S.C. Section 1212. make it a crime for any person knowingly and willfullyto make to any department or agency of the United Statesany false, fictitious or fradulent statements or representations as to any matter within its jurisdiction.

4 U.S. GPO:

LCU 6-6G Perforations & Frac's

Interval #1 Mesaverde 8700 - 048746 - 568782 - 848850 - 56 70 holes

Frac w/50,106# 20/40 PR6000 sd., w/313.6 mscf of N2 and 698 bb1sof YF12OST.

Interval #2 Mesaverde 8412 - 168562 - 648599 - 11 57 holes

Frac w/61,326# 20/40 PR6000 sd., w/411 mscf of N2 and 821 bb1sof YFl20ST

Interval #3 Mesaverde 8036 -45 55 holes

Frac w/42,451# 20/40 PR6000 sd., w/231.7 mscf of N2 and 554 bb1sof YF120LG

Interval #4 Mesaverde 7540 -- 49 55 holes

Frac w/30,797# 20/40 Ottawa sd., w/122.5 mscf of N2 and 398 bb1s of YFl20LG

Interval #5 Mesaverde 7140 - 447220 - 227224 - 267292 - 947313 - 15 53 holes


Interval #6 Uteland Bts. 6774 - 786832 - 37 56 holes

Frac w/59,275# 20/40 Ottawa sd., w/260.3 mscf of N2 and 500 bb1sof

LCU 6-6G Perforations & Frac's

Interval #1 Mesaverde 8700 - 048746 - 568782 - 848850 - 56 70 holes

Frac w/50,106# 20/40 PR6000 sd., w/313.6 mscf of N2 and 698 bb1sof YF12OST.

Interval #2 Mesaverde 8412 - 168562 - 648599 - 11 57 holes

Frac w/61,326# 20/40 PR6000 sd., w/411 mscf of N2 and 821 bb1sof YFl20ST

Interval #3 Mesaverde 8036 -45 55 holes

Frac w/42,451# 20/40 PR6000 sd., w/231.7 mscf of N2 and 554 bb1sof YF120LG

Interval #4 Mesaverde 7540 -- 49 55 holes


Interval #5 Mesaverde 7140 - 447220 - 227224 - 267292 - 947313 - 15 53 holes


Interval #6 Uteland Bts. 6774 - 786832 - 37 56 holes

Frac w/59,275# 20/40 Ottawa sd., w/260.3 mscf of N2 and 500 bb1sof

Division of Oil, Gas and Mining ROUTINGOPERATOR CHANGE WORKSHEET 1. DJJ

X - Change of Operator (Well Sold) Operator Name Change/MergerThe operator of the well(s) listed below has changed, effective: 7/1/2007

FROM: (Old Operator): TO: ( New Operator):N1095-Dominion Exploration & Production, Inc N2615-XTO Energy Inc

14000 QuailSprings Parkway, Suite 600 810 Houston StOklahoma City, OK 73134 Fort Worth, TX 76102

Phone: 1 (405) 749-1300 Phone: 1 (817) 870-2800

CA No. Unit: LITTLE CANYON

WELL NAME SEC TWN RNG API NO ENTITY LEASE TYPE WELL WELLNO TYPE STATUS

SEE ATTACHED LIST

OPERATOR CHANGES DOCUMENTATIONEnter date after each listed item is completed1. (R649-8-10) Sundry or legal documentation was received from the FORMER operator on: 8/6/20072. (R649-8-10) Sundry or legal documentation was received from the NEW operator on: 8/6/20073. The new company was checked on the Department of Commerce, Division of Corporations Database on: 8/6/20074a. Is the new operator registered in the State of Utah: Business Number: 5655506-0143

4b. If NO, the operator was contacted contacted on:5a. (R649-9-2)Waste Management Plan has been received on: IN PLACE5b. Inspections of LA PA state/fee well sites complete on: n/a5c. Reports current for Production/Disposition & Sundries on: ok

6. Federal and Indian Lease Wells: The BLM and or the BIA has approved the merger, name change,or operator change for all wells listed on Federal or Indian leases on: BLM BIA

7. Federal and Indian Units:The BLM or BIA has approved the successor of unit operator for wells listed on:

8. Federal and Indian Communization Agreements ("CA"):The BLM or BIA has approved the operator for all wells listed within a CA on:

9. Underground Injection Control ("UIC") The Division has approved UIC Form 5, Transfer of Authority toInject, for the enhanced/secondary recovery unit/project for the water disposal well(s) listed on:

DATA ENTRY:1. Changes entered in the Oil and Gas Database on: 9/27/20072. Changes have been entered on the Monthly Operator Change Spread Sheet on: 9/27/20073. Bond information entered in RBDMS on: 9/27/20074. Fee/State wells attached to bond in RBDMS on: 9/27/20075. Injection Projects to new operator in RBDMS on: 9/27/20076. Receipt of Acceptance of Drilling Procedures for APD/New on: 9/27/2007BOND VERIFICATION:1. Federal well(s) covered by Bond Number: UTB0001382. Indian well(s) covered by Bond Number: n/a

3a. (R649-3-1) The NEW operator of any state/fee well(s) listed covered by Bond Number 104312762

3b. The FORMER operator has requested a release of liability from their bond on: 1/23/2008The Division sent response by letter on:

LEASE INTEREST OWNER NOTIFICATION:4. (R649-2-10) The NEW operator of the feewells has been contacted and informed by a letter from the Division

of their responsibility to notify all interest owners of this change on:COMMENTS:

XTO - LITTLE CANYON (DOMINION) FORM A.xls

Division of Oil, Gas and Mining ROUTINGOPERATOR CHANGE WORKSHEET 1. DJJ

X - Change of Operator (Well Sold) Operator Name Change/MergerThe operator of the well(s) listed below has changed, effective: 7/1/2007

FROM: (Old Operator): TO: ( New Operator):N1095-Dominion Exploration & Production, Inc N2615-XTO Energy Inc

14000 QuailSprings Parkway, Suite 600 810 Houston StOklahoma City, OK 73134 Fort Worth, TX 76102

Phone: 1 (405) 749-1300 Phone: 1 (817) 870-2800

CA No. Unit: LITTLE CANYON

WELL NAME SEC TWN RNG API NO ENTITY LEASE TYPE WELL WELLNO TYPE STATUS

SEE ATTACHED LIST

OPERATOR CHANGES DOCUMENTATIONEnter date after each listed item is completed1. (R649-8-10) Sundry or legal documentation was received from the FORMER operator on: 8/6/20072. (R649-8-10) Sundry or legal documentation was received from the NEW operator on: 8/6/20073. The new company was checked on the Department of Commerce, Division of Corporations Database on: 8/6/20074a. Is the new operator registered in the State of Utah: Business Number: 5655506-0143

4b. If NO, the operator was contacted contacted on:5a. (R649-9-2)Waste Management Plan has been received on: IN PLACE

5b. Inspections of LA PA state/fee well sites complete on: n/a5c. Reports current for Production/Disposition & Sundries on: ok

6. Federal and Indian Lease Wells: The BLM and or the BIA has approved the merger, name change,or operator change for all wells listed on Federal or Indian leases on: BLM BIA

7. Federal and Indian Units:The BLM or BIA has approved the successor of unit operator for wells listed on:

8. Federal and Indian Communization Agreements ("CA"):The BLM or BIA has approved the operator for all wells listed within a CA on:

9. Underground Injection Control ("UIC") The Division has approved UIC Form 5, Transfer of Authority toInject, for the enhanced/secondary recovery unit/project for the water disposal well(s) listed on:

DATA ENTRY:1. Changes entered in the Oil and Gas Database on: 9/27/20072. Changes have been entered on the Monthly Operator Change Spread Sheet on: 9/27/20073. Bond information entered in RBDMS on: 9/27/20074. Fee/State wells attached to bond in RBDMS on: 9/27/20075. Injection Projects to new operator in RBDMS on: 9/27/20076. Receipt of Acceptance of Drilling Procedures for APD/New on: 9/27/2007BOND VERIFICATION:1. Federal well(s) covered by Bond Number: UTB0001382. Indian well(s) covered by Bond Number: n/a

3a. (R649-3-1) The NEW operator of any state/fee well(s) listed covered by Bond Number 104312762

3b. The FORMER operator has requested a release of liability from their bond on: 1/23/2008The Division sent response by letter on:

LEASE INTEREST OWNER NOTIFICATION:4. (R649-2-10) The NEW operator of the feewells has been contacted and informed by a letter from the Division

of their responsibility to notify all interest owners of this change on:COMMENTS:

XTO - LITTLE CANYON (DOMINION) FORM A.xls

STATE OF UTAH FORM 9DEPARTMENTOF NATURALRESOURCES

DIVISIONOF OlL, GAS AND MINING 5. LEASEDESIGNATIONANDSERIALNUMBER:

6. IF INDIAN,ALLOTTEEOR TRIBE NAMESUNDRY NOTICES AND REPORTS ON WELLS7. UNITorCA AGREEMENTNAME:

Do not use thisform for proposals to drill new wells, significantly deepen existing wells below current bottom-hole depth, reenter plugged wells, or todrill horizontal laterals. Use APPLICATIONFOR PERMIT TO DRILLform for such proposals.

1. TYPE OF WELL 8. WELLNAMEand NUMBER:OIL WELL Ü GAS WELL 2 OTHER

SEE ATTACHED2. NAMEOFEnPERATOR:OC. 9. A UE

TACHED3. ADDRESS OF OPERATOR: 810 Houston Street PHONE NUMBER 10. FIELDANDPOOL, OR WILDCAT:

eny Fort Worth swa TX w76102 (817) 870-2800 Natural Buttes4. LOCATIONOF WELL

FOOTAGESATSURFACE: SEE ATTACHED COUNTY: Uintah

QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:UTAH

11. CHECK APPROPRIATE BOXES TO INDICATENATUREOF NOTICE, REPORT, OR OTHER DATATYPE OF SUBMISSION TYPE OF ACTION

O ACIDIZE DEEPEN REPERFORATE CURRENT FORMATIONNOTICE OF INTENT

(Submit in Duplicate) ALTERCASING FRACTURE TREAT SIDETRACKTO REPAIR WELL

Approximate date work willstart: CASING REPAIR NEWCONSTRUCTION TEMPORARILYABANDON

CHANGETO PREVIOUS PLANS OPERATOR CHANGE TUBINGREPAIR

CHANGETUBING PLUGANDABANDON VENT OR FLARE

SUBSEQUENT REPORT CHANGEWELLNAME PLUG BACK WATERDISPOSAL(Submit Original Form Only)

CHANGEWELLSTATUS PRODUCTION(START/RESUME) WATERSHUT-OFFDate of work completion:

O COMMINGLEPRODUCING FORMATIONS RECLAMATIONOF WELLSITE OTHER:

CONVERT WELLTYPE RECOMPLETE - DIFFERENT FORMATION

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

Effective July 1, 2007, XTO Energy Inc. has purchased the wells listed on the attachment from:

Dominion Exploration & Production, Inc.14000 Quail Springs Parkway, Suite 600Oklahoma City, OK 73134

James D. AbercrombieSr. Vice President, General Manager - Western Business Unit

Please be advised that XTO Energy Inc. is considered to be the operator on the attached list and is responsibleunder the terms and conditions of the lease for the operations conducted upon the lease lands. Bond coverageis provided by Nationwide BLM Bond #104312750 and Department of Natural Resources Bond #104312762.

NAME(PLEASEPRINT) Win S. Ryan. Jr TITLE Sr. Vice President - Land Administration

SIGNATURE DATE 7/31/2007

(Thisspacefor RECEIVEDAUSO62007

(5/2000) ÛÎVÎSlon of Oil,GasandMining (See Instructionson Reverse Side) gy 0 Og MS &WNING

EarleneRussell,Engineering

STATE OF UTAH FORM 9DEPARTMENTOF NATURALRESOURCES

DIVISIONOF OlL, GAS AND MINING 5. LEASEDESIGNATIONANDSERIALNUMBER:

6. IF INDIAN,ALLOTTEEOR TRIBE NAMESUNDRY NOTICES AND REPORTS ON WELLS7. UNITorCA AGREEMENTNAME:

Do not use thisform for proposals to drill new wells, significantly deepen existing wells below current bottom-hole depth, reenter plugged wells, or todrill horizontal laterals. Use APPLICATIONFOR PERMIT TO DRILLform for such proposals.

1. TYPE OF WELL 8. WELLNAMEand NUMBER:OIL WELL Ü GAS WELL 2 OTHER

SEE ATTACHED2. NAMEOFEnPERATOR:OC. 9. A UE

TACHED3. ADDRESS OF OPERATOR: 810 Houston Street PHONE NUMBER 10. FIELDANDPOOL, OR WILDCAT:

eny Fort Worth swa TX w76102 (817) 870-2800 Natural Buttes4. LOCATIONOF WELL

FOOTAGESATSURFACE: SEE ATTACHED COUNTY: Uintah

QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:UTAH

11. CHECK APPROPRIATE BOXES TO INDICATENATUREOF NOTICE, REPORT, OR OTHER DATATYPE OF SUBMISSION TYPE OF ACTION

O ACIDIZE DEEPEN REPERFORATE CURRENT FORMATIONNOTICE OF INTENT

(Submit in Duplicate) ALTERCASING FRACTURE TREAT SIDETRACKTO REPAIR WELL

Approximate date work willstart: CASING REPAIR NEWCONSTRUCTION TEMPORARILYABANDON

CHANGETO PREVIOUS PLANS OPERATOR CHANGE TUBINGREPAIR

CHANGETUBING PLUGANDABANDON VENT OR FLARE

SUBSEQUENT REPORT CHANGEWELLNAME PLUG BACK WATERDISPOSAL(Submit Original Form Only)

CHANGEWELLSTATUS PRODUCTION(START/RESUME) WATERSHUT-OFFDate of work completion:

O COMMINGLEPRODUCING FORMATIONS RECLAMATIONOF WELLSITE OTHER:

CONVERT WELLTYPE RECOMPLETE - DIFFERENT FORMATION


Effective July 1, 2007, XTO Energy Inc. has purchased the wells listed on the attachment from:

Dominion Exploration & Production, Inc.14000 Quail Springs Parkway, Suite 600Oklahoma City, OK 73134

James D. AbercrombieSr. Vice President, General Manager - Western Business Unit

Please be advised that XTO Energy Inc. is considered to be the operator on the attached list and is responsibleunder the terms and conditions of the lease for the operations conducted upon the lease lands. Bond coverageis provided by Nationwide BLM Bond #104312750 and Department of Natural Resources Bond #104312762.

NAME(PLEASEPRINT) Win S. Ryan. Jr TITLE Sr. Vice President - Land Administration

SIGNATURE DATE 7/31/2007

(Thisspacefor RECEIVEDAUSO62007

(5/2000)ÛÎVÎSlon of Oil,GasandMining (See Instructionson Reverse Side) gy 0 Og MS &WNING

EarleneRussell,Engineering

N1095 DOMINIONE and P, INC. to N2615 XTO ENERGY, INC.

LITTLECANYONUNIT

api well_name qtr _qtr sec twp rng lease num entity Lease well stat4304731026 HILL FEDERAL 1-10 NESW 10 110S 200E U-44089 1368 Federal GW TA4304731178 LAFKAS FED 1-3 SWSW 03 110S 200E U-34350 1367 Federal GW S4304735639 LCU 5-35F SWNW 35 100S 200E U-01470-C 14619 Federal GW P4304735646 LCU 10-35F NWSE 35 100S 200E U-01470-D 14619 Federal GW P4304735729 LCU 14-lH SESW 01 110S 200E UTU-73436 14619 Federal GW P4304735730 LCU 12-lH NWSW 01 110S 200E UTU-73436 14619 Federal GW P4304735731 LCU 2-12H NWNE 12 110S 200E UTU-73436 14619 Federal GW P4304736164 LCU 6-6G SENW 06 110S 210E UTU-75700 14619 Federal GW P4304736165 LCU 2-lH NWNE 01 110S 200E UTU-76264 14619 Federal GW P4304736166 LCU 5-lH SWNW 01 110S 200E UTU-76264 14619Federal GW P4304736167 LCU 16-lH SESE 01 110S 200E UTU-73436 14619 Federal GW P4304736168 LCU ll-lH NESW 01 110S 200E UTU-73436 14619 Federal GW P4304736607 LCU 11-10H NESTV 10 110S 200E 0-44089 15361 Federed GNV P4304736774 LCU 2-10H NWNE 10 110S 200E UTU-44089 15330 Federal GW P4304736775 LCU 7-3H SWNE 03 110S 200E UTU-44090-A 15777 Federal GW P4304736776 LCU ll-3H NESW 03 110S 200E UTU-34350 16104 Federal GW DRL4304736803 LCU 7-1H SWNE 01 110S 200E UTU-76264 14619 Federal GW P4304736804 LCU 3-3H NENW 03 110S 200E UTU-44090-A 16070 Federal GW DRL4304736805 LCU 14-3H SESW 03 110S 200E UTU-34350 16106 Federal GW DRL4304736806 LCU 15-9H SWSE 09 110S 200E UTU-76265 16042 Federal GW DRL4304736807 LCU 8-12H SENE 12 110S 200E U-73436 14619 Federal GW P4304736811 LCU 14-35F SESW 35 100S 200E U-01470-D 14619 Federal GW P4304736812 LCU 13-35F STVSTV 35 100S 200E U-01470-D 14619 Federed CAWP4304736813 LCU 12-6G NWSW 06 110S 210E U-72665 15248 Federal GW P4304736891 LCU 9-3H NESE 03 110S 200E UTU-34350 16107 Federal GW DRL4304737198 LCU 6-1lH SENW 11 110S 200E UTU-73436 16009 Federal GW P4304737199 LCU 12-11H NWSW 11 110S 200E UTU-73436 16009 Federal GW P4304737200 LCU 14-llH SESTV 11 110S 200E ITTU-73436 16009 Federed GNV P4304737449 LCU 9-1lH NESE 11 110S 200E UTU-73436 16009 Federal OW P4304738380 LCU 6-3H SENW 03 110S 200E UTU-44090-A 15939 Federal GW DRL4304738381 LCU 10-3H NWSE 03 110S 200E UTU-34350 16157 Federal GW DRL4304738382 LCU 16-3H SESE 03 110S 200E UTU-34350 16105 Federal GW DRL4304738991 LCU 2-6GX (RIGSKID) NWNE 06 110S 210E UTU-075700 15912 Federal GW P4304739065 UTE TRIBAL 3-11H NENW 11 110S 200E 14-20-H62-5611 16073 Indian GW DRL4304739066 UTE TRIBAL 7-11H SWNE 11 110S 200E 14-20-H62-5611 16044 Indian GW P4304739067 UTE TRIBAL 8-11H SENE 11 110S 200E 14-20-H62-5611 16045 Indian GW DRL

1


LITTLECANYONUNIT

api well_name qtr _qtr sec twp rng lease num entity Lease well stat4304731026 HILL FEDERAL 1-10 NESW 10 110S 200E U-44089 1368 Federal GW TA4304731178 LAFKAS FED 1-3 SWSW 03 110S 200E U-34350 1367 Federal GW S4304735639 LCU 5-35F SWNW 35 100S 200E U-01470-C 14619 Federal GW P4304735646 LCU 10-35F NWSE 35 100S 200E U-01470-D 14619 Federal GW P4304735729 LCU 14-lH SESW 01 110S 200E UTU-73436 14619 Federal GW P4304735730 LCU 12-lH NWSW 01 110S 200E UTU-73436 14619 Federal GW P4304735731 LCU 2-12H NWNE 12 110S 200E UTU-73436 14619 Federal GW P4304736164 LCU 6-6G SENW 06 110S 210E UTU-75700 14619 Federal GW P4304736165 LCU 2-lH NWNE 01 110S 200E UTU-76264 14619 Federal GW P4304736166 LCU 5-lH SWNW 01 110S 200E UTU-76264 14619Federal GW P4304736167 LCU 16-lH SESE 01 110S 200E UTU-73436 14619 Federal GW P4304736168 LCU ll-lH NESW 01 110S 200E UTU-73436 14619 Federal GW P4304736607 LCU 11-10H NESTV 10 110S 200E 0-44089 15361 Federed GNV P4304736774 LCU 2-10H NWNE 10 110S 200E UTU-44089 15330 Federal GW P4304736775 LCU 7-3H SWNE 03 110S 200E UTU-44090-A 15777 Federal GW P4304736776 LCU ll-3H NESW 03 110S 200E UTU-34350 16104 Federal GW DRL4304736803 LCU 7-1H SWNE 01 110S 200E UTU-76264 14619 Federal GW P4304736804 LCU 3-3H NENW 03 110S 200E UTU-44090-A 16070 Federal GW DRL4304736805 LCU 14-3H SESW 03 110S 200E UTU-34350 16106 Federal GW DRL4304736806 LCU 15-9H SWSE 09 110S 200E UTU-76265 16042 Federal GW DRL4304736807 LCU 8-12H SENE 12 110S 200E U-73436 14619 Federal GW P4304736811 LCU 14-35F SESW 35 100S 200E U-01470-D 14619 Federal GW P4304736812 LCU 13-35F STVSTV 35 100S 200E U-01470-D 14619 Federed CAWP4304736813 LCU 12-6G NWSW 06 110S 210E U-72665 15248 Federal GW P4304736891 LCU 9-3H NESE 03 110S 200E UTU-34350 16107 Federal GW DRL4304737198 LCU 6-1lH SENW 11 110S 200E UTU-73436 16009 Federal GW P4304737199 LCU 12-11H NWSW 11 110S 200E UTU-73436 16009 Federal GW P4304737200 LCU 14-llH SESTV 11 110S 200E ITTU-73436 16009 Federed GNV P4304737449 LCU 9-1lH NESE 11 110S 200E UTU-73436 16009 Federal OW P4304738380 LCU 6-3H SENW 03 110S 200E UTU-44090-A 15939 Federal GW DRL4304738381 LCU 10-3H NWSE 03 110S 200E UTU-34350 16157 Federal GW DRL4304738382 LCU 16-3H SESE 03 110S 200E UTU-34350 16105 Federal GW DRL4304738991 LCU 2-6GX (RIGSKID) NWNE 06 110S 210E UTU-075700 15912 Federal GW P4304739065 UTE TRIBAL 3-11H NENW 11 110S 200E 14-20-H62-5611 16073 Indian GW DRL4304739066 UTE TRIBAL 7-11H SWNE 11 110S 200E 14-20-H62-5611 16044 Indian GW P4304739067 UTE TRIBAL 8-11H SENE 11 110S 200E 14-20-H62-5611 16045 Indian GW DRL

1


LITTLECANYONUNIT

api well name qtr qtr sec twp rng lease num entity Lease well stat4304735613 LAOLI12-36F 149VSTV36 100S 200E AdL,47391 14619 S.tate (39V P4304735643 LAOLI10-2H 149VSE 02 110S 200E híL,48771 14630 State (39V P4304736611 LAOLI13-2H STVSTV 02 110S 200E AdL,48771 15704 S.tate (IVV P4304736779 LCU 5-2H NESW 02 110S 200E ML-48771 99999 State GW DRL4304736780 LCU l l-2H NESW 02 110S 200E ML-48771 99999 State GW DRL4304736783 LCU 14-36F SESW 36 100S 200E ML-47391 14619 State GW P4304737986 LCU 3-36F NENW 36 100S 200E ML-47391 16071 State GW DRL4304737987 LAU 10-36F 149VSE 36 100S 200E híL-47391 15911 State (TVVS4304737988 LA LI8-36F SF14E 36 100S 200E NIL-47391 16030 S;tate (19V P4304737989 LA U 13-36F STVSTV 36 100S 200E NIL,47391 14619 State G3Arp4304737999 LA LI6-36F SElfiV 36 100S 200E AdL-47391 16059 State (IVV S4304738026 11 U 11-36F FIESTV 36 100S 200E báL,47391 14619 State (IRT P4304738256 LCU 8-2H SENE 02 110S 200E ML-48771 99999 State GW DRL4304738257 LCU 12-2H NWSW 02 110S 200E ML-48771 15750 State GW P4304738258 IJOLI7-2H STV>IE 02 110S 200E NIL,48771 15664 State (19V P4304738259 LCU 9-2H SENE 02 110S 200E ML-48771 99999 State GW DRL4304738260 LAOLI15-36F STVS.E 36 100S 200E AdLe47391 15893 State (19V P

1


LITTLECANYONUNIT

api well name qtr qtr sec twp rng lease num entity Lease well stat4304735613 LAOLI12-36F 149VSTV36 100S 200E AdL,47391 14619 S.tate (39V P4304735643 LAOLI10-2H 149VSE 02 110S 200E híL,48771 14630 State (39V P4304736611 LAOLI13-2H STVSTV 02 110S 200E AdL,48771 15704 S.tate (IVV P4304736779 LCU 5-2H NESW 02 110S 200E ML-48771 99999 State GW DRL4304736780 LCU l l-2H NESW 02 110S 200E ML-48771 99999 State GW DRL4304736783 LCU 14-36F SESW 36 100S 200E ML-47391 14619 State GW P4304737986 LCU 3-36F NENW 36 100S 200E ML-47391 16071 State GW DRL4304737987 LAU 10-36F 149VSE 36 100S 200E híL-47391 15911 State (TVVS4304737988 LA LI8-36F SF14E 36 100S 200E NIL-47391 16030 S;tate (19V P4304737989 LA U 13-36F STVSTV 36 100S 200E NIL,47391 14619 State G3Arp4304737999 LA LI6-36F SElfiV 36 100S 200E AdL-47391 16059 State (IVV S4304738026 11 U 11-36F FIESTV 36 100S 200E báL,47391 14619 State (IRT P4304738256 LCU 8-2H SENE 02 110S 200E ML-48771 99999 State GW DRL4304738257 LCU 12-2H NWSW 02 110S 200E ML-48771 15750 State GW P4304738258 IJOLI7-2H STV>IE 02 110S 200E NIL,48771 15664 State (19V P4304738259 LCU 9-2H SENE 02 110S 200E ML-48771 99999 State GW DRL4304738260 LAOLI15-36F STVS.E 36 100S 200E AdLe47391 15893 State (19V P

1


Utah State Office TAKE Palot*P.O. Box 45155 INg ERICA

Salt Lake City,UT 84145-0155


Dominion Exploration & Production, Inc.Attn: James D. Abercrombie14000 Quail Springs Parkway, #600Oklahoma City, OK 73134-2600

August 10, 2007

Re: Little Canyon UnitUintah County, Utah

Gentlemen:

On August 8, 2007, we received an indenture dated June 30, 2007, whereby Dominion Exploration& Production, Inc. resigned as Unit Operator and XTO Energy Inc. was designated as SuccessorUnit Operator for the Little Canyon Unit, Uintah County, Utah.

This indenture was executed by all required parties and the signatory parties have complied withSections 5 and 6 of the unit agreement. The instrument is hereby approved effective August 15,2007. In approving this designation, the Authorized Officer neither warrants nor certifies that thedesignated party has obtained all required approval that would entitle itto conduct operations underthe Little Canyon Unit Agreement.

Your statewide oil and gas bond No. UTBOOO138will be used to cover all operations within theRiver Bend Unit.

It is requested that you notifyall interested parties of the change in unit operator. Copies of theapproved instruments are being distributed totheappropriate federal offices, with one copy returnedherewith.

Sincerely,

/s/ Greg J. Noble

Greg J. NobleActing Chief, Branch of Fluid Minerals

EnclosureRECEIVED

AUS162007DN.0F0tL,GAS&


Utah State Office TAKE Palot*P.O. Box 45155 INg ERICA

Salt Lake City,UT 84145-0155


Dominion Exploration & Production, Inc.Attn: James D. Abercrombie14000 Quail Springs Parkway, #600Oklahoma City, OK 73134-2600

August 10, 2007

Re: Little Canyon UnitUintah County, Utah

Gentlemen:

On August 8, 2007, we received an indenture dated June 30, 2007, whereby Dominion Exploration& Production, Inc. resigned as Unit Operator and XTO Energy Inc. was designated as SuccessorUnit Operator for the Little Canyon Unit, Uintah County, Utah.

This indenture was executed by all required parties and the signatory parties have complied withSections 5 and 6 of the unit agreement. The instrument is hereby approved effective August 15,2007. In approving this designation, the Authorized Officer neither warrants nor certifies that thedesignated party has obtained all required approval that would entitle itto conduct operations underthe Little Canyon Unit Agreement.

Your statewide oil and gas bond No. UTBOOO138will be used to cover all operations within theRiver Bend Unit.

It is requested that you notifyall interested parties of the change in unit operator. Copies of theapproved instruments are being distributed totheappropriate federal offices, with one copy returnedherewith.

Sincerely,

/s/ Greg J. Noble

Greg J. NobleActing Chief, Branch of Fluid Minerals

EnclosureRECEIVED

AUS162007DN.0F0tL,GAS&

' Form 3160-5 UNITED STATES FORM APPROVED(August 2007) DEPARTMENT OF THE INTERIOR OMB NO. 1004-0137

Expires July 31, 2010BUREAU OF LAND MANAGEMENTO 5. Lease Serial No.

SUNDRY NOTICES AND REPORTS ON WELLS UTli-75700Do not use this form for proposals to dri/I or to re-enter an 6. If Indian, Allottee or Tribe Name

abandoned well. Use Form 3160-3 (APD) for such proposals.N/A

SUBMIT IN TRIPLICATE - Other instructions on page 2 7. If Unit or CA/Agreement, Name and/or No.

LITI'LE CANYONUNITl. Type of Well

Oil Well Gas Well Other 8. WellName and No.LCD #G-GG

2. Name of OperatorXTO Energy Inc• 9 APTWellNo

3a. Address 3b. Phone No. (include area code) 43-047-36164382 CR 3100 Aztec, NM 87410 \ 505-333-3100 10 Field and Poni, or FYploratory Area

4. Location of Well (Footage, Sec., T., R., M., or SurveyDescription) LOVE WASATCHMESAVERDE2019' FNL & 1596' WIL SENW SEC 6-T11S-R21E

ll. County or Parish, State

uINTAH UT

12. CHECK APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA


Notice oflntent Acidize Deepen Production (Start/Resume) Water Shut-Off

Alter Casing Fracture Treat Reclamaton WenntegrgSubsequent Report

Casing Repair New Construction Recomplete X otherRAISE CEMENT

O Final Abandonment Notice Change Plans Plug and Abandon Temporarily Abandon

O cans.s ta,,,.sts., Plug Back Water Disposal

13. Describe Proposed or Completed Operation (clearly state all pertinent details, includingestimated starting date of any proposed work and approximate duration thereof.If the proposal is to deepen directionally or recomplete horizontally, give subsurface locations and measured and true vertical depths ofall pertinent markers and zones.Attach the Bond under which the work will be performed or provide the Bond No. on file with BLM/BIA. Required subsequent reports shall be filed within 30 daysfollowing completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval, a Form 3160-4 shall be filed oncetesting has been completed. Final Abandonment Notices shall be filed only after all requirements, including reclamation, have been completed, and the operator hasdetermined that the final site is ready for final inspection.)

XTO Energy Inc. proposes to raise the cement top and put this well on pump per the attached procedure &wellbore diagram.

RECEIVEDCOPYSENTTOOPERATOR

oste:/ 24'¾ DIVOFOIL,GAS&MININGInitials:

14. I hereby certify that the foregoing is true and correctName (Printed/Typed)

LO D B Title SR. REGOIATORY COMPLIANCE TECH

Signature Date 1/12/09II

Approved by

IS SPACE FOR FEDERAL O itSTATE OFFIC EDate

Conditions of approval, any, are attached. Approval of this notice does not warrant or certify that Office FederalApprovalut I ilsthe appi cantph I al or equitable title to tehroserights in the subject lease which would ActÌ00\SNecessaryTitle 18 U.S.C. Section 1001, and Title 43 U.S.C. Section 1212, makes it a crime for any person knowinglyand willfullyto make to any department or agency ofthe United States any false,fictitious or fraudulent statements or representations as to any matter within its

' Form 3160-5 UNITED STATES FORM APPROVED(August 2007) DEPARTMENT OF THE INTERIOR OMB NO. 1004-0137

Expires July 31, 2010BUREAU OF LAND MANAGEMENTO 5. Lease Serial No.

SUNDRY NOTICES AND REPORTS ON WELLS UTli-75700

Do not use this form for proposals to dri/I or to re-enter an 6. If Indian, Allottee or Tribe Nameabandoned well. Use Form 3160-3 (APD) for such proposals.

N/A

SUBMIT IN TRIPLICATE - Other instructions on page 2 7. If Unit or CA/Agreement, Name and/or No.

LITI'LE CANYONUNITl. Type of Well

Oil Well Gas Well Other 8. WellName and No.LCD #G-GG

2. Name of Operator

XTO Energy Inc• 9 APTWellNo3a. Address 3b. Phone No. (include area code) 43-047-36164

382 CR 3100 Aztec, NM 87410 \ 505-333-3100 10 Field and Poni, or FYploratory Area4. Location of Well (Footage, Sec., T., R., M., or SurveyDescription) LOVE WASATCHMESAVERDE

2019' FNL & 1596' WIL SENW SEC 6-T11S-R21Ell. County or Parish, State

uINTAH UT

12. CHECK APPROPRIATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA


Notice oflntent Acidize Deepen Production (Start/Resume) Water Shut-Off

Alter Casing Fracture Treat Reclamaton WenntegrgSubsequent Report

Casing Repair New Construction Recomplete X otherRAISE CEMENT

O Final Abandonment Notice Change Plans Plug and Abandon Temporarily Abandon

O cans.s ta,,,.sts., Plug Back Water Disposal

13. Describe Proposed or Completed Operation (clearly state all pertinent details, includingestimated starting date of any proposed work and approximate duration thereof.If the proposal is to deepen directionally or recomplete horizontally, give subsurface locations and measured and true vertical depths ofall pertinent markers and zones.Attach the Bond under which the work will be performed or provide the Bond No. on file with BLM/BIA. Required subsequent reports shall be filed within 30 daysfollowing completion of the involved operations. If the operation results in a multiple completion or recompletion in a new interval, a Form 3160-4 shall be filed oncetesting has been completed. Final Abandonment Notices shall be filed only after all requirements, including reclamation, have been completed, and the operator hasdetermined that the final site is ready for final inspection.)

XTO Energy Inc. proposes to raise the cement top and put this well on pump per the attached procedure &wellbore diagram.

RECEIVEDCOPYSENTTOOPERATOR

oste:/ 24'¾ DIVOFOIL,GAS&MININGInitials:

14. I hereby certify that the foregoing is true and correctName (Printed/Typed)

LO D B Title SR. REGOIATORY COMPLIANCE TECH

Signature Date 1/12/09II

Approved by

IS SPACE FOR FEDERAL O itSTATE OFFIC EDate

Conditions of approval, any, are attached. Approval of this notice does not warrant or certify that Office FederalApprovalut I ilsthe appi cantph I al or equitable title to tehroserights in the subject lease which would ActÌ00\SNecessaryTitle 18 U.S.C. Section 1001, and Title 43 U.S.C. Section 1212, makes it a crime for any person knowinglyand willfullyto make to any department or agency ofthe United States any false,fictitious or fraudulent statements or representations as to any matter within its

JTBTJF

DLC

LCU 6-6GSec6,T11S,R21EUintah County, Utah

AFE # 810178

Put Well on Pump

Surf esg: 8-5/8", 32#, J-55, ST&C csg @2,218'.Prod csg: 5-1/2", 17#, N80, LT&C csg @9032'. TOC @2,650'. PBTD @8,968'.Tbg: 2-3/8" tbg, EOT @8,830'.Perfs: WA: 6774'-78', 6832'-37'

MV: 7140'-44, 7220'-22', 7224'-26', 7292'-94', 7313'-15', 7540'-49', 8036'-45',8412'-16', 8562'-64', 8599'-8611', 8700'-04', 8746'-56', 8782'-84', 8850'-56'

Purpose: Raise cement top, PWOP

PWOP Procedure

1) MI and set a Lufkin RM228-213-100 pumping unit (min ECB 15,3001bs) with a C-96engine. Set CB weights as follows:

Description Weight PositionLeft Lag 2RO + 2S 2.5" from end of crankLeft Lead 2RO+ 2D/SS 2.5" from end of crankRight Lag 2RO + 2S 2.5" from end of crankRight Lead 2RO+ 2D/SS 2.5" from end of crank

2) MIRU PU. Blow down casing to blow tank and kill well w/ 2% KCl. ND WH, NU BOP.Unseat tubing hanger and lower tubing to tag, then tally out of hole. Advise Tom Boyce offill, scale or corrosion on tubing. Clean out to PBTD with air if fill is present.

3) MIRU wireline unit and set composite BP @2820'. Pressure test to 1000 psi. Perforate 4squeeze holes @2660'. Open bradenhead valves and establish injection rate down 5 ½"casing, through squeeze holes, and up 5 ½" x 8 5/8" annulus.

4) TIH with 5 ½" cast iron cement retainer on 2-3/8" tubing. Set retainer 50' above squeezeholes at ±2610'. MIRU cementers. Establish injection rate through perfs, then close retainerand test tubing to 5000 psi. Open retainer, and pump 200 sx 50/50 poz mix containing 8%gel, 10% gypsum, ¼# sx super flake, and 1% CaCl mixed at 12.5 ppg (2.04 cuft/sx),followed by 50 sx class G containing 1% CaCl mixed at 15.8 ppg (1.15 cuft/sx). Displace to½ BBL above retainer, then close retainer and sting out. Flush remaining cement on top ofretainer, then POH with tubing.

LCU 6-6G PWOP procedure.doc Page 1 of3

JTBTJF

DLC

LCU 6-6GSec6,T11S,R21EUintah County, Utah

AFE # 810178

Put Well on Pump

Surf esg: 8-5/8", 32#, J-55, ST&C csg @2,218'.Prod csg: 5-1/2", 17#, N80, LT&C csg @9032'. TOC @2,650'. PBTD @8,968'.Tbg: 2-3/8" tbg, EOT @8,830'.Perfs: WA: 6774'-78', 6832'-37'

MV: 7140'-44, 7220'-22', 7224'-26', 7292'-94', 7313'-15', 7540'-49', 8036'-45',8412'-16', 8562'-64', 8599'-8611', 8700'-04', 8746'-56', 8782'-84', 8850'-56'

Purpose: Raise cement top, PWOP

PWOP Procedure

1) MI and set a Lufkin RM228-213-100 pumping unit (min ECB 15,3001bs) with a C-96engine. Set CB weights as follows:

Description Weight PositionLeft Lag 2RO + 2S 2.5" from end of crankLeft Lead 2RO+ 2D/SS 2.5" from end of crankRight Lag 2RO + 2S 2.5" from end of crankRight Lead 2RO+ 2D/SS 2.5" from end of crank

2) MIRU PU. Blow down casing to blow tank and kill well w/ 2% KCl. ND WH, NU BOP.Unseat tubing hanger and lower tubing to tag, then tally out of hole. Advise Tom Boyce offill, scale or corrosion on tubing. Clean out to PBTD with air if fill is present.

3) MIRU wireline unit and set composite BP @2820'. Pressure test to 1000 psi. Perforate 4squeeze holes @2660'. Open bradenhead valves and establish injection rate down 5 ½"casing, through squeeze holes, and up 5 ½" x 8 5/8" annulus.

4) TIH with 5 ½" cast iron cement retainer on 2-3/8" tubing. Set retainer 50' above squeezeholes at ±2610'. MIRU cementers. Establish injection rate through perfs, then close retainerand test tubing to 5000 psi. Open retainer, and pump 200 sx 50/50 poz mix containing 8%gel, 10% gypsum, ¼# sx super flake, and 1% CaCl mixed at 12.5 ppg (2.04 cuft/sx),followed by 50 sx class G containing 1% CaCl mixed at 15.8 ppg (1.15 cuft/sx). Displace to½ BBL above retainer, then close retainer and sting out. Flush remaining cement on top ofretainer, then POH with tubing.

LCU 6-6G PWOP procedure.doc Page 1 of3

5) PU 4-3/4" bit, bit sub, and drill collars and drill out squeeze using water. Circulate clean andpressure test squeeze to 1000 psi. If test is good, drill out CBP. POH, pick up 5-½" casingscraper and tally in hole to PBTD. If scale was encountered on scraper run or noted ontubing, spot 3000 gal 15% HCL containing 4 gal/1000 CI 100, 6 gal/1000 FE 100L,10gal/1000 FE 200, 4 gal/1000 NE 100, and 10 gal/1000 MA 844W across perforations. Pullabove acid with tubing, dump additional 100 BBL 2% KCL water down casing. Allow acidto soak overnight.

6) Lower tubing to ±8850', Swab until clean fluid is obtained. POH, LD 2 3/8" tubing.

7) RIH with tapered 2-1/16" x 2 3/8" pumping string as follows:a) 2.0625" x 12' mule shoe jointb) 1.5" S/Nc) 3300'-2.065" 3.25# J-55 tubingd) 2-3/8" x 2.0625" X-overe) 5600'-2-3/8" 4.7# L-80 EUE tubing to surface, EOT @8900'. Land tubing, then NU

wellhead.

8) RIH w/ pump and rod string as follows:a) 1 ½" x 1 1/16" x 12'x 15' RWBC pump w/ ¾" x 8' .012" inlet screenb) 5/8" x 4' Guided rod sub (mold-on guides)c) 5/8"-21,000 lb HF shear toold) 16- 1 1/4" API K Sinker Rodse) 120- 5/8" Grade D rods w/ slim hole couplingsf) 220- 3/4" Norris 96 Rods w/ "T" couplingsg) 1-6' x 3/4" Norris 96 rod ponyh) 1 ¼" x 22' Polish rod w/ 1 ½" liner

9) Space out pump as required with spacer subs. Load tubing and long stroke with rig to ensurepump action. RDMO PU.

10) Gauge tanks. Shoot FL and run dynamometer during pumping unit startup. Start wellpumping at 5 SPM and 100" SL for 24 hours. Check fluid level and tank gauges.

11) Report pre and post start up data to Tom Boyce

LCU 6-6G PWOP procedure.doc Page 2 of 3

5) PU 4-3/4" bit, bit sub, and drill collars and drill out squeeze using water. Circulate clean andpressure test squeeze to 1000 psi. If test is good, drill out CBP. POH, pick up 5-½" casingscraper and tally in hole to PBTD. If scale was encountered on scraper run or noted ontubing, spot 3000 gal 15% HCL containing 4 gal/1000 CI 100, 6 gal/1000 FE 100L,10gal/1000 FE 200, 4 gal/1000 NE 100, and 10 gal/1000 MA 844W across perforations. Pullabove acid with tubing, dump additional 100 BBL 2% KCL water down casing. Allow acidto soak overnight.

6) Lower tubing to ±8850', Swab until clean fluid is obtained. POH, LD 2 3/8" tubing.

7) RIH with tapered 2-1/16" x 2 3/8" pumping string as follows:a) 2.0625" x 12' mule shoe jointb) 1.5" S/Nc) 3300'-2.065" 3.25# J-55 tubingd) 2-3/8" x 2.0625" X-overe) 5600'-2-3/8" 4.7# L-80 EUE tubing to surface, EOT @8900'. Land tubing, then NU

wellhead.

8) RIH w/ pump and rod string as follows:a) 1 ½" x 1 1/16" x 12'x 15' RWBC pump w/ ¾" x 8' .012" inlet screenb) 5/8" x 4' Guided rod sub (mold-on guides)c) 5/8"-21,000 lb HF shear toold) 16- 1 1/4" API K Sinker Rodse) 120- 5/8" Grade D rods w/ slim hole couplingsf) 220- 3/4" Norris 96 Rods w/ "T" couplingsg) 1-6' x 3/4" Norris 96 rod ponyh) 1 ¼" x 22' Polish rod w/ 1 ½" liner

9) Space out pump as required with spacer subs. Load tubing and long stroke with rig to ensurepump action. RDMO PU.

10) Gauge tanks. Shoot FL and run dynamometer during pumping unit startup. Start wellpumping at 5 SPM and 100" SL for 24 hours. Check fluid level and tank gauges.

11) Report pre and post start up data to Tom Boyce


Regulatory• Submit NOI and subsequent report to BLM and Utah Division of Oil Gas & Mining for

raising cement top on 5 ½" casing, and for installation of pumping unit.

Services/Material• Wireline service to set CBP and per squeeze holes• Cement service to raise cement top• AFU• 4-3/4" bit & bit sub, 3-3/4" drill collars, 5-1/2" casing scraper

Equipment• Lufkin RM228-213-100 pumping unit (min ECB 15,300 lbs) with a C-96 engine

Tubing• 2-1/16" x 12' mule shoe• 1-1/2" (1.50" ID) API SN• 2-l/16"x 3.25# J-55 tubing, 3300'• 1-2 1/16" IJ x 2 3/8" EUE x-over• 2-3/8" 6.4# EUE L-80 tubing, 5600'

Rods• 1 1/2" x 1-1/16" x 12' x 15' RWBC pump, w/ ¾" x 8' inlet screen, .012" slot• 5/8" x 4' Guided Rod Sub w/mold-on guides• 5/8" - 21,000 lb HF Shear Tool• 16 - 1-1/4" x 25' API K Sinker Bars• 120 - 5/8" Norris Grade D rods w/ slimhole couplings• 220 - 3/4" Norris-96 Rods w/T-couplings• 1- 6' x 3/4" Norris-96 Spacer Sub• 1-1/4" x 22' Polished Rod w/liner


Regulatory• Submit NOI and subsequent report to BLM and Utah Division of Oil Gas & Mining for

raising cement top on 5 ½" casing, and for installation of pumping unit.

Services/Material• Wireline service to set CBP and per squeeze holes• Cement service to raise cement top• AFU• 4-3/4" bit & bit sub, 3-3/4" drill collars, 5-1/2" casing scraper

Equipment• Lufkin RM228-213-100 pumping unit (min ECB 15,300 lbs) with a C-96 engine

Tubing• 2-1/16" x 12' mule shoe• 1-1/2" (1.50" ID) API SN• 2-l/16"x 3.25# J-55 tubing, 3300'• 1-2 1/16" IJ x 2 3/8" EUE x-over• 2-3/8" 6.4# EUE L-80 tubing, 5600'

Rods• 1 1/2" x 1-1/16" x 12' x 15' RWBC pump, w/ ¾" x 8' inlet screen, .012" slot• 5/8" x 4' Guided Rod Sub w/mold-on guides• 5/8" - 21,000 lb HF Shear Tool• 16 - 1-1/4" x 25' API K Sinker Bars• 120 - 5/8" Norris Grade D rods w/ slimhole couplings• 220 - 3/4" Norris-96 Rods w/T-couplings• 1- 6' x 3/4" Norris-96 Spacer Sub• 1-1/4" x 22' Polished Rod w/liner


Downhole Well Profile (Tom) (copy 1)

ENERGY

Well Name: Little Canyon Unit 06-06GAPl/UWI ElW Dist (it) ElW Ref N/S Dist (ft) N/S Ref Cocation Field Name County State

43047361640000 1,596.0 FWL 2,019.] FNL T11S-R21E-SO6 Love Uintah UtahWell Configuration Type XTO ID B Orig KB Elev (ft) Gr Elev (ft) K5-Grd (ft) Spud Date PBTD (AII)(ftKB) Total Depth (ftKB) Method Of Production

Vertical 162378 5,414.(0 9/21/2005 Original Hole - 8968.0 9,032.0 Pigr LiftWell Config:Vertical - Original Hole, 12/16/2008 4:29:40 3M Producing Zones

ftKB ftKB Zone Top (ftKB) Btm (ftKB)Schematic-Actual Incl (TVD) (MD) Wasatch Tongue 3,674.0

Uteland Limestone 3,996.00 Wasatch 4,132.0

2,218 Chapita Wells 4,969.0

? A50 Uteland Buttes 6,019.0Mesaverde 6,851.0

3,674Casing Strings

3,996 Casing Description OD (in) Wt (Ibs/ft) String Grade Top Connection Set Depth (ftKB)

4,132 Surface 8 5/8 32.00 J-55 2,218.0Casing Description OD (in) Wt (Ibs/ft) String Grade Top Connection Set Depth (ftKB)

4,969 Production 5 1/2 17.00 N-80 9,032.0

6,019 CementDescription Top (ftKB) Btttt(ftKB) Comment

6,774 Cement Plug 8,968.0 9,032.06,778 Production Casing 2þ50.0 9,032.0

6,832 CementSurface Casing Cement 0.0 2,218.0

6,837

6,851 Perforations

7,140 ShotDens Diameter PhasingDate Top{ftKB) Btm (ftKB) (shots/ft) . (hi) (°) Zone

7,144 11/4/2005 6,774.0 6,778.0 6.0 Uteland Buttes

7,220 11/4/2005 6,832.0 6,837.0 6.0 Uteland Buttes11/4/2005 7,140.0 7,144.0 4.0 Mesaverde

7,22211/4/2005 7,220.0 7,222.0 4.0 Mesaverde

7,224 11/4/2005 7,224.0 7,226.0 4.0 Mesaverde7,226 11/4/2005 7,292.0 7,294.0 4.0 Mesaverde

7,292 11/4/2005 7,313.0 7,315.0 4.0 Mesaverde

7 , A11/4/2005 7,540.0 7,549.0 6.0 Mesaverde

' 11/4/2005 8,036.0 8,045.0 6.0 Mesaverde7,313 11/4/2005 8,412.0 8,416.0 3.0 Mesaverde7,315 11/4/2005 8,562.0 8,564.0 3.0 Mesaverde

7,540 11/4/2005 8,599.0 8,611.0 3.0 Mesaverde11/4/2005 8,700.0 8,704.0 3.0 Mesaverde

7,649 11/4/2005 8,746.0 8,756.0 3.0 Mesaverde8,036 11/4/2005 8,782.0 8,784.0 3.0 Mesaverde8,045 11/4/2005 8,850.0 8,856.0 3.0 Mesaverde

8,412 Tubing StringsTubing Description Run Date Set Depth (ftKB)

8,416 Tubing - Production 8,831.98,562 Tubing Components

Wt Top8,564 Item Description Jts Model OD (in) (Ibs/ft) Grade Thread Len (ft) Top (ftKB) Btm(ftKB)

8,599 Tubing 284 T&C 2 3/8 4.70 J-55 8,830.81 0.0 8,830.8

8,611 Upset

8,700Pump Seating Nipple 2 3/8 1.08 8,830.8 8,831.9

Rods8,704 Rod Description Run Date String Length (ft) Set Depth (ftKB)

8,746

8,756 Rod Componentsitem Description Jts Model OD (in) Grade Len (ft) Top (ftKB) Btm(ftKB)

8,782

8,784 Stimulations & TreatmentsFrac Start ... Top Perf (f... Bottom Pe... V (slurry) (... Total Add ... 15 Min (psi) ISIP (psi) AIR(bbilm... ATP (psi)

8,831 1225008,832 122500

8,850commentlHS 297 Well Import

PBTD, 8,856 Test number: 001

8,968 8,968 Measurement: bbl Ib

TD, Remarks: details: yf120Ig

9,032 9,032

www.peloton.com Page 1/2 Report Printed:


ENERGY

Well Name: Little Canyon Unit 06-06GAPI/UWI E/W Dist (ft) ElW Ref N/S Dist (ft) NIS Ref Location Field Name County State

43047361640000 1,596.0 FWL 2,019.0 FNL T11S-R21E-SO6 Love Uintah UtahWell Configuration Type XTO ID B Orig KB Elev (ft) Gr Elev (ft) KB-Grd (ft) Spud Date PBTD (AII)(ftKB) Total Depth (ftKB) Method Of Production

Vertical 162378 5,414.00 9/21/2005 Original Hole - 8968.0 9,032.0 Pigr LiftWell Confin: Vertical - Original Hole, 12/16/2008 4:29:40 PM Stimulations & Treatments

ftKB ftKB Frac Start... Top Perf (f... Bottom Pe... V (slurry) (... Total Add ... 1Š Min(psi) ISIP (psi) AIR (bbilm... ATP (psi)

Schematic - Actual inci (TVD) (MD) 7078270782

Û Comment

2,218 IHS 297 Well ImportTest number: 001

2,650 Measurement: bbl lb3,674 Remarks: details: yf1151g

3,996 Frac Start ... Top Perf (f... Bottom Pe... V (slury) (... Total Add ... 15 Min (psi) ISIP (psi) AIR(bbl/m... ATP (psi)61326

4,132 613264,969 comment

lHS 297 Well import6,019 Test number: 0016,774 Measurement: bbl Ib

L 6,778 Remarks: details: yf120st

6,832 Frac Start ... Top Perf (f... Bottom Pe... V (slurry) (... ÏotalÄëd ... 15 lÄin(psi) ISIP (psi) AIR(bbl/m... ATP (psi)42451

6,837 42451

6,851 commentlHS 297 Well import

7,140 Test number: 0017,144 Measurement: bbl Ib

Remarks: details: yf120\g7,220

Frac Start ... Top Perf (f... Bottom Pe... V (slurry) (... Total Add ... 15 Min (psi) ISIP (psi) AIR (bbl/m... ATP (psi)7,222 501067,224 50106

7,226lHS 297 Well Import

7,292 Test number: 0017,294 Measurement: bbl lb

Remarks: details: yf120st7,313

Frac Start ... Top Perf (f... Bottom Pe... V (slurry) (... Total Add ... 15 Min (psi) ISIP (psi) AIR(bb1/m... ATP (psi)7,315 59275

7,540 59275Comment

7,549 IHS 297 Well import8,036 Test number: 001

Measurement: bbl Ib8,045 Remarks: details: yfi15|g8,412

8,416

8,562

8,564

8,599

8,611

8,700

8,704

8,746

8,756

8,782

8,784

8,831

8,832

8,850

PBTD, 8,856

8,968 8,968TD' 9,032

9,032



ENERGY

Well Name: Little Canyon Unit 06-06GAPI/UWI E/W Dist (ft) ElW Ref N/S Dist (ft) NIS Ref Location Field Name County State

43047361640000 1,596.0 FWL 2,019.0 FNL T11S-R21E-SO6 Love Uintah UtahWell Configuration Type XTO ID B Orig KB Elev (ft) Gr Elev (ft) KB-Grd (ft) Spud Date PBTD (AII)(ftKB) Total Depth (ftKB) Method Of Production

Vertical 162378 5,414.00 9/21/2005 Original Hole - 8968.0 9,032.0 Pigr LiftWell Confin: Vertical - Original Hole, 12/16/2008 4:29:40 PM Stimulations & Treatments

ftKB ftKB Frac Start... Top Perf (f... Bottom Pe... V (slurry) (... Total Add ... 1Š Min(psi) ISIP (psi) AIR (bbilm... ATP (psi)

Schematic - Actual inci (TVD) (MD) 7078270782

Û Comment

2,218 IHS 297 Well ImportTest number: 001

2,650 Measurement: bbl lb3,674 Remarks: details: yf1151g

3,996 Frac Start ... Top Perf (f... Bottom Pe... V (slury) (... Total Add ... 15 Min (psi) ISIP (psi) AIR(bbl/m... ATP (psi)61326

4,132 613264,969 comment

lHS 297 Well import6,019 Test number: 0016,774 Measurement: bbl Ib

L 6,778 Remarks: details: yf120st

6,832 Frac Start ... Top Perf (f... Bottom Pe... V (slurry) (... ÏotalÄëd ... 15 lÄin(psi) ISIP (psi) AIR(bbl/m... ATP (psi)42451

6,837 42451

6,851 commentlHS 297 Well import

7,140 Test number: 0017,144 Measurement: bbl Ib

Remarks: details: yf120\g7,220

Frac Start ... Top Perf (f... Bottom Pe... V (slurry) (... Total Add ... 15 Min (psi) ISIP (psi) AIR (bbl/m... ATP (psi)7,222 501067,224 50106

7,226lHS 297 Well Import

7,292 Test number: 001

7,294 Measurement: bbl lbRemarks: details: yf120st

7,313Frac Start ... Top Perf (f... Bottom Pe... V (slurry) (... Total Add ... 15 Min (psi) ISIP (psi) AIR(bb1/m... ATP (psi)

7,315 59275

7,540 59275Comment

7,549 IHS 297 Well import8,036 Test number: 001

Measurement: bbl Ib8,045 Remarks: details: yfi15|g8,412

8,416

8,562

8,564

8,599

8,611

8,700

8,704

8,746

8,756

8,782

8,784

8,831

8,832

8,850

PBTD, 8,856

8,968 8,968TD' 9,032

9,032


Form3J60-5 UNITEDSTATES DOGMCOPY FORMAPPROVED(August2007) DEPARTMENT OF THE INTERIOR OMBNO. 1004-0137

ExpiresJuly31, 2010BUREAUOF LANDMANAGEMENT

O $, LeaseSerialNo.SUNDRY NOTICES AND REPORTS ON WELLS UTlF75700

Do not use this form for proposals to drIll or to re-enter an 6. If Indian, Allottee or Tribe Nameabandoned welL Use Form 3160-3 (APD) for such proposals.

N/A

SUSMIT IN TRIPLICATE- Other instructions on page 2 7. If Unitor CA/Agreement,Nameand/orNo.LITTLE CAtWORUNIT

1. Type of Well

O onwo O Gas Well Otlu 8. Well Natne and No.LCU C-CG

2. Name of Operator

9 API WellNo.3a. Address 3b. Phone No. (include area code) gy

382 CR 3100 Aztec, NM 87410 505-333-3100 10. Field and Pool or Exnlaratorv Area4. Location of Well (Footage. Sec.. T. R., &Lor SurveyDescription) L(NE VBBEFOR NE!SAVERDE:

2019' FNL & 1596' BWL SEtW SEC 6-T118-R21E11. County or Parish, State

UnlTAH UTAH12. CHECK APPROPRÏATE BOX(ES) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA

TYPE OF SUBMISSlON TYPE OF ACTION

O ~~ O - O O ~~a= 6 s-a-o O --o«

Subsequent ReportCasing Repair New Construction Recomple e X Other RAISE CEMENTesseauss Plugand Abandon T A MUT WEMaW

O c-ma r.cs, Plug Back

13. Describe Proposed or CompletedOperation (clearly state all pertinent details, including estimated starting date of any proposed work and approximate duration thereofIfthe proposal is to deepen directionally or recomplete horizontally, give subsurface locations and measured and true vertical depths ofall pertinent markers and zones.Attach the Bond under which the work will be perfortried or provide the Bond No, on file with 13LM/BIA. Required subsequent reports shall be liled within 30 daysfollowing completionofthe involved operations, Ifthe operation results in a multiple completion or recompletion in a new interval, a Form 3160-4 shall be filedoncetesting has been completed. Final Abandonment Notices shall be filed only aller all requirements, includingreclamation, have been completed, and the operator hasdetermined that the final site is ready for final inspection.)

XTO Einergy Inc. raised the cement top and put this well on purip per the attached Morning Report. Seealso attached current Wellbore Diagram.

RECEIVEDJUNf 82003

AS&MWING

14. I herebycertify that the foregoing istrue and correctName (Printed/Typed)

. RIG)L Title REGUIATORYCGi BKSignatur Date 6/8/2009

THIS SPACEPOR FEDERAL OR STATEOFFlcE USEApproved by Title Date

Conditionsofapproval ifany, are attached. Approval ofthis notice does not warrantor certify that (NTWthe applicantholdslegalor equitable title to those rights in thesubpet leasewhich wouldentitjethy appüdaptto Rondge;operations thereon.

Title i lis.Crécetion Ï001, and Title43 U.S.C. Section 1211 makesit a crimefor any person knowinglyand willibily to make to any depan ein oi a sency of the Umted States any false,fictitpys og linadalent statementsor representations as to any matiefwithin itsJarisdiction. Û .JA

Wellname: Little Canyon Unit 06-06GT-R-8: T11S-R21E-SO6 State: Utah2'ones: MesaverdeWasatchCounty: Uintah Lat: 39*S3'27.07"N Long: 109*36'42.940"W

Objective: PWOP (RP) Proposed TD:

Daily Operations Data From: 3/10/2009 7:00:00AM to 3/10/2009 5:00:00PMOperation Summary: First rptfor AFE#810178 to PWOP. Bd well. MIRUKey #6013. NDWH. NU bop. Unland hngr. TlH w/ 2 Jt's2-3/8" tbg.Tg 68' of fill@8920'. TOH w/ 284 jt's, 4.7#, J-55,eue 2-3/8" tbg, SN, 1/2 BRS. Found perf wash hole @6837' ( JT #217 ).MU&TlH w/ 4.75"bit, 5.5"scr &286 jt's 2-3/8" tbg. Tg 68' of fill@8920'. TOH w/ 66 jt's tbg. EOT @6800'. SWIFN

Daily Operations Data From: 3/11/2009 7:00:00AM to 3/11/2009 7:00:00PMOperation Summary: Bd tbg. TlH w/4.75" bit, 5.5" csg scr &66 jts 2-3/8" tbg. Tgd 68' offill@8920'. RU pwr swivel &AFU. Estab circ. CO fr18920' - 8968' ( suspect BRS). TOH & LDscr& bit. TlH w/4.75" WO shoe &286 jts tbg. Tgd BRS @8968', RU pwr swivel &AFU, Estab circ &WO BRS &CO to PBTD @8988'. RD swivel &AFU. TOH w/289 jts tbg. LD shoe, reed BRS & bit.SWI & SDFN.

Daily Operations Data From: 3/12/2009 7:00:00AM to 3/12/2009 4:00:00PMOperation Summary: Bd well. On 3/11/2009 Notified SLM rep Mike Lee, Vernal UT, office with phoneconversation. Verbal okay given. MIRUPerf O Log WLU. Held safety mtg. RIH & set 6K CBP @2750'. PT pig to 1,000 psig, gd tst. RlH & perf sqz holes w/3-1/8" ceg guns loaded w/TitanEXP-3323-361T, 22.7 gm chrgs, fr/2650' - 2653' w/1 JSPF (120 deg phasing, 0.36" EHD, 35.63"pene., 4 holes ttl.)Estb circ up srfc csg @3 bpm, 600 psig. RD WL. TlH w/5.5" CICR & 85 jts2.375", 4,7#, J-55 EUE tbg. Set CICR @2750'. PT tbg to 2,000 psig. Tstd gd. Estb circ to surffr/BHviv. Sqz'd csg ik @2650' w/200 sks Class B cmt w/ 1% CaCl2 ( mixed @ 12.5 ppg & 2.06 yld) then 50 sks Class G cmt w/ 2% CaCL2 ( mixed @ 15.8 ppg & 1.15 yld ).Fishd dwn tbg w/10 BFW.5 bbls cmt to surf. Unsting & RC out w/30 bbis 2%. TOH &LD stinger tl. PU &TlH w/ 4.75" bit, 4 -

3-1/2" DC &70 Jtstbg. EOT @2400'. SWI &SDFN

Daily Operations Data From: 3/13/2009 7:00:00AM to 3/13/2009 4:00:00PMOperation Summary: TlH w/6 jts tbg.Tg 6' of cmt @2569'. RU pwr swivel. Estb circ& DO cmtto CICR @2575'. DO CICR @2575' ( 5 hrs). Contd DO 90' cmt fr/2579' - 2665' ( BOC ). PT sqz@2650' - 53'. PT failed. Press bled of fr/1000 - 200 psig, 2". PT 8.625" surf csg to 500 psig. 2 bisto fill.Tstd gd. BD squeeze @2500 psig. EIR of 3 BPM @ 1800 psig. TOH wltbg & BHA.Prep toresqueeze. SWI SDFWE.

Daily Operations Data From: 3/16/2009 7:00:00AM to 3/16/2009 3:00:00PMOperation Summary: Bd well. TIH w/ 5.5" pkr & 85 jts 2.375" 4.7#, J-56 EUE tbg. Set pkr @2675'. Fill &PT tbg &CFP @2750' to 1,000 psig. Gd tst. Risd press &tis. Set Pkr @2600', EIR thru squeezeholes @2650' - 53' of 2 BPM @ 1800 psig. PT TCA to 1500 psig. Tstd Gd. Rlsd tls &reset pkr @2570'. RU cmt equip. PTsurf ins to 4,000 psig. Tstd gd. Sqz'd csg leak @2650' w/ 50 sks Class Gcmt wl2% CaCL2 {mixed @15.8 ppg & 1.15 yld ). Fishd dwn tbg w/9 BFW. Risd pkr & pull 120'tbg. RC out w/30 bbis 2%. Rest Pkr @2450'. Press up tbg to 1000 psig. WOC time4.5 hrs. Risdtls &TOH w/ tbg, LD 5.5" Pkr. PU &TlH wl4.75" bit, 4 - 3-1/2" DC & 70 jts tbg. EOT @2400'. SWl& SDFN

Daily Operations Data From: 3/17/2009 7:00:00AM to 3/17/2009 2:00:00PMOperation Summary: TIH w/6 jts tbg. Tgd omt @2550'. RU pwr swivel. Esto elrc & DO emtfr/2550' - 2665' ( BOC ). PT sqz @2660' - 53'. Tstd Gd @1250 psig. 30". PT 8.625" surf cog to500 psig. Obis to fill.Tstd gd. Contd TíH & CO cmtstringers to CBP @2750'. DO CBP @2750'.Bd ceg on 48/48" ck 4 hrs 1850 - 250 pelg. TlH w/120 ' thg, No pig remains. TOHwitbgto DC's @surf. OWU to tot tnk48/48" ok.FCP 250 psig.

Dany Operations Data From: 3/18/2009 7:00:00AM to 3/18/2009 12:00:00PMOperation Summary: Bd well. LD DC & BHA.TlH w/4.75" bit, SN & 289 jts tbg, Tgd PBTD @8988'. LD4 jts. W/ EOT @8860'. RU ac equip. Pmp 34 bis trtd2% dwn tbg. Then 60 bis Chem pill( 110 gis Naleo DVE40-005 SI, 5 gals EC 6106 BC, 100 gals IPA 2000 & 55 bbis2% KCiwtr),followed w/20 bbis 2% KCIwtr& 2000 gals 15% HGiac dwn TCA. SD 1 hr for ao soak. Displ aswl160 bble trtd2% KCtwtr@2 bpm & 1000 psig. SWI &

Wellname: Little Canyon Unit 06-06GT-R-8: T11S-R21E-SO6 State: Utah2'ones: MesaverdeWasatchCounty: Uintah Lat: 39*S3'27.07"N Long: 109*36'42.940"W

Objective: PWOP (RP) Proposed TD:

Daily Operations Data From: 3/10/2009 7:00:00AM to 3/10/2009 5:00:00PMOperation Summary: First rptfor AFE#810178 to PWOP. Bd well. MIRUKey #6013. NDWH. NU bop. Unland hngr. TlH w/ 2 Jt's2-3/8" tbg.Tg 68' of fill@8920'. TOH w/ 284 jt's, 4.7#, J-55,eue 2-3/8" tbg, SN, 1/2 BRS. Found perf wash hole @6837' ( JT #217 ).MU&TlH w/ 4.75"bit, 5.5"scr &286 jt's 2-3/8" tbg. Tg 68' of fill@8920'. TOH w/ 66 jt's tbg. EOT @6800'. SWIFN

Daily Operations Data From: 3/11/2009 7:00:00AM to 3/11/2009 7:00:00PMOperation Summary: Bd tbg. TlH w/4.75" bit, 5.5" csg scr &66 jts 2-3/8" tbg. Tgd 68' offill@8920'. RU pwr swivel &AFU. Estab circ. CO fr18920' - 8968' ( suspect BRS). TOH & LDscr& bit. TlH w/4.75" WO shoe &286 jts tbg. Tgd BRS @8968', RU pwr swivel &AFU, Estab circ &WO BRS &CO to PBTD @8988'. RD swivel &AFU. TOH w/289 jts tbg. LD shoe, reed BRS & bit.SWI & SDFN.

Daily Operations Data From: 3/12/2009 7:00:00AM to 3/12/2009 4:00:00PMOperation Summary: Bd well. On 3/11/2009 Notified SLM rep Mike Lee, Vernal UT, office with phoneconversation. Verbal okay given. MIRUPerf O Log WLU. Held safety mtg. RIH & set 6K CBP @2750'. PT pig to 1,000 psig, gd tst. RlH & perf sqz holes w/3-1/8" ceg guns loaded w/TitanEXP-3323-361T, 22.7 gm chrgs, fr/2650' - 2653' w/1 JSPF (120 deg phasing, 0.36" EHD, 35.63"pene., 4 holes ttl.)Estb circ up srfc csg @3 bpm, 600 psig. RD WL. TlH w/5.5" CICR & 85 jts2.375", 4,7#, J-55 EUE tbg. Set CICR @2750'. PT tbg to 2,000 psig. Tstd gd. Estb circ to surffr/BHviv. Sqz'd csg ik @2650' w/200 sks Class B cmt w/ 1% CaCl2 ( mixed @ 12.5 ppg & 2.06 yld) then 50 sks Class G cmt w/ 2% CaCL2 ( mixed @ 15.8 ppg & 1.15 yld ).Fishd dwn tbg w/10 BFW.5 bbls cmt to surf. Unsting & RC out w/30 bbis 2%. TOH &LD stinger tl. PU &TlH w/ 4.75" bit, 4 -

3-1/2" DC &70 Jtstbg. EOT @2400'. SWI &SDFN

Daily Operations Data From: 3/13/2009 7:00:00AM to 3/13/2009 4:00:00PMOperation Summary: TlH w/6 jts tbg.Tg 6' of cmt @2569'. RU pwr swivel. Estb circ& DO cmtto CICR @2575'. DO CICR @2575' ( 5 hrs). Contd DO 90' cmt fr/2579' - 2665' ( BOC ). PT sqz@2650' - 53'. PT failed. Press bled of fr/1000 - 200 psig, 2". PT 8.625" surf csg to 500 psig. 2 bisto fill.Tstd gd. BD squeeze @2500 psig. EIR of 3 BPM @ 1800 psig. TOH wltbg & BHA.Prep toresqueeze. SWI SDFWE.

Daily Operations Data From: 3/16/2009 7:00:00AM to 3/16/2009 3:00:00PMOperation Summary: Bd well. TIH w/ 5.5" pkr & 85 jts 2.375" 4.7#, J-56 EUE tbg. Set pkr @2675'. Fill &PT tbg &CFP @2750' to 1,000 psig. Gd tst. Risd press &tis. Set Pkr @2600', EIR thru squeezeholes @2650' - 53' of 2 BPM @ 1800 psig. PT TCA to 1500 psig. Tstd Gd. Rlsd tls &reset pkr @2570'. RU cmt equip. PTsurf ins to 4,000 psig. Tstd gd. Sqz'd csg leak @2650' w/ 50 sks Class Gcmt wl2% CaCL2 {mixed @15.8 ppg & 1.15 yld ). Fishd dwn tbg w/9 BFW. Risd pkr & pull 120'tbg. RC out w/30 bbis 2%. Rest Pkr @2450'. Press up tbg to 1000 psig. WOC time4.5 hrs. Risdtls &TOH w/ tbg, LD 5.5" Pkr. PU &TlH wl4.75" bit, 4 - 3-1/2" DC & 70 jts tbg. EOT @2400'. SWl& SDFN

Daily Operations Data From: 3/17/2009 7:00:00AM to 3/17/2009 2:00:00PMOperation Summary: TIH w/6 jts tbg. Tgd omt @2550'. RU pwr swivel. Esto elrc & DO emtfr/2550' - 2665' ( BOC ). PT sqz @2660' - 53'. Tstd Gd @1250 psig. 30". PT 8.625" surf cog to500 psig. Obis to fill.Tstd gd. Contd TíH & CO cmtstringers to CBP @2750'. DO CBP @2750'.Bd ceg on 48/48" ck 4 hrs 1850 - 250 pelg. TlH w/120 ' thg, No pig remains. TOHwitbgto DC's @surf. OWU to tot tnk48/48" ok.FCP 250 psig.

Dany Operations Data From: 3/18/2009 7:00:00AM to 3/18/2009 12:00:00PMOperation Summary: Bd well. LD DC & BHA.TlH w/4.75" bit, SN & 289 jts tbg, Tgd PBTD @8988'. LD4 jts. W/ EOT @8860'. RU ac equip. Pmp 34 bis trtd2% dwn tbg. Then 60 bis Chem pill( 110 gis Naleo DVE40-005 SI, 5 gals EC 6106 BC, 100 gals IPA 2000 & 55 bbis2% KCiwtr),followed w/20 bbis 2% KCIwtr& 2000 gals 15% HGiac dwn TCA. SD 1 hr for ao soak. Displ aswl160 bble trtd2% KCtwtr@2 bpm & 1000 psig. SWI &

Daily Operations Data From: 3/19/2009 7:00:00AM to 3/19/2009 6:00:00PMOperation Summary: Bd well. TOH w/180jts 2.375"tbg.LD 102 Jt's2.375" tbg & bit TIHwl2-1/16" X 6' MSMAJ, SN( 1.5" LD.), 101 jts 2.0625", 3.25#, J-55, IJ tbg, 2-1/16 x 2-3/8 XO,1 jt2.375" tbg, 5.5" x 2-3/8" TAC&179 jts2.375",4.7#, J.55, EUE, Srd tbg.NDBOP,set TACw/12Ktens. Ld tbg on hgr &NU WH. SN @8,891', TAC @5575',EOT @8,898'. WA/MVperfs fr/6774' -

8856'. RU &RIHw/swbtls, BFL@3500' FS, S. OBO,15 BLW,2 hrs, FFL @4150' FS. Drty fidsmpis w/tr solids. SWI &SDFN.

Daily Operations Data From: 3/20/2009 7:00:00AMto 3/20/2009 2:00:00PMOperation Summary: RU &RTHw/swb tis,BFL @2,700' FS, S. O BO, 55 BLW,7hrs, FFL @5,560'. Drtyfld smpls w/tr solids. SWI &SDFN.

Daily Operations Data From: 3/23/2009 7:00:00AM to 3/23/2000 2:00:00PMOperation Summary: PU & load new 1.25 x 1.0625" x 1T RWBC pmp (XTO #162) w/3/4" x4' screened GAC. TlH w/pmp, 16- 1.25" sbs, 120 - 5/8 gr 'D'plain skr d, 218 - 3/4" gr 'D' plain skr d,1- 3/4" x 2' rod sub &26' x 1.25" PR w/1.5" x 16' Inr. Seated pmp & SWO. PT tbg to 500 psig w/8BW. LS pmp to 1000 psig, Gd PA. Clamped off rods for PU installation. RDMO Key Energy#6013. Rpts suspended. TURN WELLOVER TO FACILITIES.

======================LittleCanyon Unit 06-06G=============================

End of

Daily Operations Data From: 3/19/2009 7:00:00AM to 3/19/2009 6:00:00PMOperation Summary: Bd well. TOH w/180jts 2.375"tbg.LD 102 Jt's2.375" tbg & bit TIHwl2-1/16" X 6' MSMAJ, SN( 1.5" LD.), 101 jts 2.0625", 3.25#, J-55, IJ tbg, 2-1/16 x 2-3/8 XO,1 jt2.375" tbg, 5.5" x 2-3/8" TAC&179 jts2.375",4.7#, J.55, EUE, Srd tbg.NDBOP,set TACw/12Ktens. Ld tbg on hgr &NU WH. SN @8,891', TAC @5575',EOT @8,898'. WA/MVperfs fr/6774' -

8856'. RU &RIHw/swbtls, BFL@3500' FS, S. OBO,15 BLW,2 hrs, FFL @4150' FS. Drty fidsmpis w/tr solids. SWI &SDFN.

Daily Operations Data From: 3/20/2009 7:00:00AMto 3/20/2009 2:00:00PMOperation Summary: RU &RTHw/swb tis,BFL @2,700' FS, S. O BO, 55 BLW,7hrs, FFL @5,560'. Drtyfld smpls w/tr solids. SWI &SDFN.

Daily Operations Data From: 3/23/2009 7:00:00AM to 3/23/2000 2:00:00PMOperation Summary: PU & load new 1.25 x 1.0625" x 1T RWBC pmp (XTO #162) w/3/4" x4' screened GAC. TlH w/pmp, 16- 1.25" sbs, 120 - 5/8 gr 'D'plain skr d, 218 - 3/4" gr 'D' plain skr d,1- 3/4" x 2' rod sub &26' x 1.25" PR w/1.5" x 16' Inr. Seated pmp & SWO. PT tbg to 500 psig w/8BW. LS pmp to 1000 psig, Gd PA. Clamped off rods for PU installation. RDMO Key Energy#6013. Rpts suspended. TURN WELLOVER TO FACILITIES.

======================LittleCanyon Unit 06-06G=============================

End of

ENERGY

We11Name: Little Canyon Unit 06416GÃPIIUWI EfW Dist ift) ENWRef NIS Di t (It) NISRef Location Field Name County State43047361640000 1,596.0 FWL 2,019.0 FNL T118-R21E-SO6 Love Uintah UtahWellConfiguration Type XTO IDB Orig KB Elev (ft) Gr Ele" (ft) KB-Gi{ft) SpudDate PBTD (All)(ftKB) TotatDepth (flKB} Method OfFŸodu ÏÍn¯Vertical 162378 5,432.00 5,414.00 18.00 9/21/2005 OriginalHole - 8988.0 9,032.0 PIgr LiftWell Config: Vertical. OriginalHole, 6/8/20Ns 11:27:20 AM Zones

ftKB ftKB Zone Top(ftKB) Stm(flKB)Schematic - Actual inct (TVD) (MD) Wasatch 6,774.0 6,837-7

Mesaverde 7,140.0 8,8360 Casinq Strings17 CasingDescription OD (in) Wt (ibs/ft) String Grade Top Connection Set Depth (flK18 Surface _ 8 5/8 32.00 J-55 2,218.019 Casing Description OD (in) WI (Ibs/ft) StringGrade Top Connection Set Depth (RK21 Production 5 1/2 17.00 N-80 eue 9,032.0150 Cement

2,218 Description Type string2,650 Surface Casing Cement casing Surface, 2,218.0ftKB2,653 comment3.6743,996 Description Type string4,132 Production Casing Cement casing Production, 9,032.0ftKB4,96g comment5,4715,675 Perforations5,578

HoleS,610 Shot Dens Diameter Phasing6,610 Date TopfftKB) sim(flKB) (shots/ft) (in) (•) gy6,019 3/12/2009 2,650.0 2,653.0 1.0 0.360 120 Wasatch6,//4 11/4/2005 6,774.0 6,778.0 6.0 0.360 60 Wasatch6,778 11/4/2005 6,632.0' 6,837.0 6.0 0.360 60 Wasatch0,032 11/4/2005 7,140.0 7,144,0 4.0 0.360 90 Mesaverde6,837 -6,851 11/4/2005 7,220.0 7,222.0 4.0 0,360 90 Mesaverde7,140 11/4/2005 7,224.0 7,226.0 4.0 0.360 90 Mesaverde7,144 11/4/20D5 7,292.0 7,294.0[ 4.0 0.360 90 Mesaverde7,220 11/4/2005 7,313.0 7,315.0 4.0 0.380 90 Mesaverde/,222 Ï1/4/2005 7,540.0 7,549.0 8,0 0.360 60 Mesaverde7,224 11/4/2005 8,036.0 8,045.0 6.0 0.360 60 Mesaverde

11/4/2005 8,412.0 8,416.0 3.0 0.360 120 Mesaverde7,294 11/4/2005 8,562.0 8,564.0 3.0 0.360 120 Mesaverde7,313 11/4/2005 8,599.0 8,611.0 3.0 0.360 120 Mesaverde7,315 11/4/2005 8,700.0 8,704.0 3.0 0.360 120 Mesaverde7,540 11/4/2005 8,746.0 8,Ï56.0 3.0 0,360 120 Mesaverde

(MD):7,140 7,549 11/4/2005 8,782 0 8,784.0 3.0 0.360 120 Mesaverdees:Mesaverde 11/4/2005 8,850 0 8,856.0 3.0 0.360 120 Mesaverde

8 412 Tubing Strings8 416 Tubing Description Run Dato Set Depth (ftKB)- 8,471 Tubing - Production 3/19/2009 8,898.08,562 Tubing Components8,564 | Wt i Top

item Description Jts Model OD(in) (lbsl... Grade Thread Len (it) Top{ftKB) Sim (ItKB8.61 Tubing Hanger 6 N-... EUE 0.72 16.8 178 700 Tubing 179 T&C 2 3/8 4.70|J-55 EUE 5,557.33\ 17.6 5,5748.704 Upset8,746 Anchor/catcher 4 3/4 J-55 EUE 3.54 5,574.9 5,5788,756 Tubing 1 T&C 2 3/8 4.70 J-55 EUE 31.17 5,578.4 5,Š00- 8,782 Upset8 Cross Over ž 3/8 J-55 EUE 0.50 5,609.6 5.6108,832 Tubing 101 Integral 2 3.25 J-55 EUE 3,280.79 5,610.1 8,8908,836 Jt. 1/168,850 Seat Nipple 2 N-... EUE 1.10 8,890.9 6,8928,856 t/168,871 Mule Shoe Pup Joini 2 3,25 J-55 EUE 6.00 8,892.0 8,8988,888 1/168,8918,892 Rods8,898 Rod Description Run Date String Length(ft) Set Depth (ftKB)PBTD 8,ggs Rod String 3/23/2009 8,899.00 8 892.08,988 h F 8,990 Rod Components

TO 9,031 ItemOoscription | Jts Model OD (in) Grade Len (ft) Top(ftKB) Stm(ftKB)9,032 Polished Rod 1 1 1/4 26.00 -7.0 19


ENERGY

We11Name: Little Canyon Unit 06416GÃPIIUWI EfW Dist ift) ENWRef NIS Di t (It) NISRef Location Field Name County State43047361640000 1,596.0 FWL 2,019.0 FNL T118-R21E-SO6 Love Uintah UtahWellConfiguration Type XTO IDB Orig KB Elev (ft) Gr Ele" (ft) KB-Gi{ft) SpudDate PBTD (All)(ftKB) TotatDepth (flKB} Method OfFŸodu ÏÍn¯Vertical 162378 5,432.00 5,414.00 18.00 9/21/2005 OriginalHole - 8988.0 9,032.0 PIgr LiftWell Config: Vertical. OriginalHole, 6/8/20Ns 11:27:20 AM Zones

ftKB ftKB Zone Top(ftKB) Stm(flKB)Schematic - Actual inct (TVD) (MD) Wasatch 6,774.0 6,837-7

Mesaverde 7,140.0 8,8360 Casinq Strings17 CasingDescription OD (in) Wt (ibs/ft) String Grade Top Connection Set Depth (flK18 Surface _ 8 5/8 32.00 J-55 2,218.019 Casing Description OD (in) WI (Ibs/ft) StringGrade Top Connection Set Depth (RK21 Production 5 1/2 17.00 N-80 eue 9,032.0150 Cement

2,218 Description Type string2,650 Surface Casing Cement casing Surface, 2,218.0ftKB2,653 comment3.6743,996 Description Type string4,132 Production Casing Cement casing Production, 9,032.0ftKB4,96g comment5,4715,675 Perforations5,578

HoleS,610 Shot Dens Diameter Phasing6,610 Date TopfftKB) sim(flKB) (shots/ft) (in) (•) gy6,019 3/12/2009 2,650.0 2,653.0 1.0 0.360 120 Wasatch6,//4 11/4/2005 6,774.0 6,778.0 6.0 0.360 60 Wasatch6,778 11/4/2005 6,632.0' 6,837.0 6.0 0.360 60 Wasatch0,032 11/4/2005 7,140.0 7,144,0 4.0 0.360 90 Mesaverde6,837 -6,851 11/4/2005 7,220.0 7,222.0 4.0 0,360 90 Mesaverde7,140 11/4/2005 7,224.0 7,226.0 4.0 0.360 90 Mesaverde7,144 11/4/20D5 7,292.0 7,294.0[ 4.0 0.360 90 Mesaverde7,220 11/4/2005 7,313.0 7,315.0 4.0 0.380 90 Mesaverde/,222 Ï1/4/2005 7,540.0 7,549.0 8,0 0.360 60 Mesaverde7,224 11/4/2005 8,036.0 8,045.0 6.0 0.360 60 Mesaverde

11/4/2005 8,412.0 8,416.0 3.0 0.360 120 Mesaverde7,294 11/4/2005 8,562.0 8,564.0 3.0 0.360 120 Mesaverde7,313 11/4/2005 8,599.0 8,611.0 3.0 0.360 120 Mesaverde7,315 11/4/2005 8,700.0 8,704.0 3.0 0.360 120 Mesaverde7,540 11/4/2005 8,746.0 8,Ï56.0 3.0 0,360 120 Mesaverde

(MD):7,140 7,549 11/4/2005 8,782 0 8,784.0 3.0 0.360 120 Mesaverdees:Mesaverde 11/4/2005 8,850 0 8,856.0 3.0 0.360 120 Mesaverde

8 412 Tubing Strings8 416 Tubing Description Run Dato Set Depth (ftKB)- 8,471 Tubing - Production 3/19/2009 8,898.08,562 Tubing Components8,564 | Wt i Top

item Description Jts Model OD(in) (lbsl... Grade Thread Len (it) Top{ftKB) Sim (ItKB8.61 Tubing Hanger 6 N-... EUE 0.72 16.8 178 700 Tubing 179 T&C 2 3/8 4.70|J-55 EUE 5,557.33\ 17.6 5,5748.704 Upset8,746 Anchor/catcher 4 3/4 J-55 EUE 3.54 5,574.9 5,5788,756 Tubing 1 T&C 2 3/8 4.70 J-55 EUE 31.17 5,578.4 5,Š00- 8,782 Upset8 Cross Over ž 3/8 J-55 EUE 0.50 5,609.6 5.6108,832 Tubing 101 Integral 2 3.25 J-55 EUE 3,280.79 5,610.1 8,8908,836 Jt. 1/168,850 Seat Nipple 2 N-... EUE 1.10 8,890.9 6,8928,856 t/168,871 Mule Shoe Pup Joini 2 3,25 J-55 EUE 6.00 8,892.0 8,8988,888 1/168,8918,892 Rods8,898 Rod Description Run Date String Length(ft) Set Depth (ftKB)PBTD 8,ggs Rod String 3/23/2009 8,899.00 8 892.08,988 h F 8,990 Rod Components

TO 9,031 ItemOoscription | Jts Model OD (in) Grade Len (ft) Top(ftKB) Stm(ftKB)9,032 Polished Rod 1 1 1/4 26.00 -7.0 19


XTO - Wellbore Diagram

ENERGY

Well Name: Little Canyon Unit 06-ti6GAPIIUWI ElW Dist (ft) ElWRef NIS Di t (it) NIS Ref Location Field Name County State43047361640000 1,596.0 FWL 2 019.0 FNL T118--R21E-SO6 Love Uintah UtahWell Configuration Type XTOIDB Orig KB Elev (ft) Gr Ele (ft) KB-Gr1{ft) Spud Date PSTD(AII)(ftKB) Total Depth (ftKB) Method Of ProductionVertical 162378 5,432 00 5,414.00 18.00 9/21/2005 OriginalHole - 8988.0 9,032.0 PIgr Lift

Well Config: Vertical-OriginalHole 6/8/2000 11:27:20 AM Rod ComponentsftKB ftKB Item Description Jts Model OO (ing Grade Len (it) Top (ftKB) Stm (ftKB}

Schematic - Actual incl (TVD) (MD} Pony Rod 96 3/4 2.00 19.0 21-7

Sucker Rod 218 WCN-96 3/4 96 5,450.00 21.0 5,471-- 0 Sucker Rod 120 D 5/8 D 3,000.00 5,471.0 8,471

17 SinkerBar 16 K 1 1/4 K 400.00 8,471.0 8,87118 Rod insert Pump i 17.00 8,871.0 8,88819 1/1621 Sand Screen .025 3/4 4.00 8,688.0 8,892

2 8 Stimulations &TreatmentsFrac Start Date Top Perf {ft... Bottom Pe... V (slurry)(... Ìotil Prop... AIR (b . ATP (psi) MTP {psi) ISlP (psi)2,650 11/14/2005 8700 88562,653 comment3,674 lHS 297 Well import3,996 Test number:0014,132 Measurement: bbi lbRemarks: details: yfí15Ig

5,575 Frac startDate Top Port (ft.. Bottom Pe... V(sluivy}(... Total Prop... AIR(b .. ATP (psi) MTP {psi) ISIP (psi)5,578 11/14/2005 8412 86115,610 comment ¯5,610 IHS 297 Well Import6,019 Test number: 0016,774 Measurement: bbl Ib6,778 Remarks: details: yf120st

: G,032 Frac Start Date Top Part (ft.. Bottom Pe. . V (slurry}(... Total Prop... AIR (b .. ATP(psi) MTP (psi) iSIP (psi)6,837 11/14/2005 8036 80450,051 comment7,140 IHS297 Well Import7,144 Test number: 0017,220 Measurement: bblib7,222 Remarks: details: yf120lg7,2247,226 Frac Start Date Top Perf (ft.. Bottom Pe... V (slurry)(... Total Prop... AIR (b .. JATP (psi) MTP (pai) ISIP (psi)

7,292 11/14/2005 7540 75497,294 comment7,313 lHS 297 Well import7,315 Test number: 0017,540 Measurement: bbi Ib7 549 Remarks: details; yf120st

Top (MD):7,140,Des:Mesaverde 8,036 (ac Start Date |Top Perf (ft.. Bottom Pe... V (slurry) (... Total Prop... AIR (b .. ATP (psi) MTP (psi) ISIP (pei)

8,045 11/14/2005 7140 73158,412 comment8,416 IHS 297 Well 1mport8,471 Test number 0018,562 Measurement: bblib8,564 Remarks: details: yfi15fg8,5998,61i Frac Start Date Top Perf (ft .. Bottom Pe... V (slurry) (... Total Prop... AIR (b .. ATP (psl} MTP (psi) lŠlP (psi)

8,700 11/14/2005 6774 6837

S 7 Well ImportMeesasnuremm

nt:b I Ib8,784 Remarks: details: yfl20lg8,831 Frao Start Date Top Perf (ft Bottom Pe... V (slurry) (... Total Ñrop...AIR (b... ATP (psi) MTP (psi) ISIP(psi)8,8328,836 comment8,8508,8568,8718,8888,8918,092

PBTD 8,898

0,032 9,032

www.peloton.com Page 212 Report Printed:

XTO - Wellbore Diagram

ENERGY

Well Name: Little Canyon Unit 06-ti6GAPIIUWI ElW Dist (ft) ElWRef NIS Di t (it) NIS Ref Location Field Name County State43047361640000 1,596.0 FWL 2 019.0 FNL T118--R21E-SO6 Love Uintah UtahWell Configuration Type XTOIDB Orig KB Elev (ft) Gr Ele (ft) KB-Gr1{ft) Spud Date PSTD(AII)(ftKB) Total Depth (ftKB) Method Of ProductionVertical 162378 5,432 00 5,414.00 18.00 9/21/2005 OriginalHole - 8988.0 9,032.0 PIgr Lift

Well Config: Vertical-OriginalHole 6/8/2000 11:27:20 AM Rod ComponentsftKB ftKB Item Description Jts Model OO (ing Grade Len (it) Top (ftKB) Stm (ftKB}

Schematic - Actual incl (TVD) (MD} Pony Rod 96 3/4 2.00 19.0 21-7

Sucker Rod 218 WCN-96 3/4 96 5,450.00 21.0 5,471-- 0 Sucker Rod 120 D 5/8 D 3,000.00 5,471.0 8,471

17 SinkerBar 16 K 1 1/4 K 400.00 8,471.0 8,87118 Rod insert Pump i 17.00 8,871.0 8,88819 1/1621 Sand Screen .025 3/4 4.00 8,688.0 8,892

2 8 Stimulations &TreatmentsFrac Start Date Top Perf {ft... Bottom Pe... V (slurry)(... Ìotil Prop... AIR (b . ATP (psi) MTP {psi) ISlP (psi)2,650 11/14/2005 8700 88562,653 comment

3,674 lHS 297 Well import3,996 Test number:0014,132 Measurement: bbi lbRemarks: details: yfí15Ig

5,575 Frac startDate Top Port (ft.. Bottom Pe... V(sluivy}(... Total Prop... AIR(b .. ATP (psi) MTP {psi) ISIP (psi)5,578 11/14/2005 8412 86115,610 comment ¯5,610 IHS 297 Well Import6,019 Test number: 0016,774 Measurement: bbl Ib6,778 Remarks: details: yf120st

: G,032 Frac Start Date Top Part (ft.. Bottom Pe. . V (slurry}(... Total Prop... AIR (b .. ATP(psi) MTP (psi) iSIP (psi)6,837 11/14/2005 8036 80450,051 comment7,140 IHS297 Well Import7,144 Test number: 0017,220 Measurement: bblib7,222 Remarks: details: yf120lg7,2247,226 Frac Start Date Top Perf (ft.. Bottom Pe... V (slurry)(... Total Prop... AIR (b .. JATP (psi) MTP (pai) ISIP (psi)

7,292 11/14/2005 7540 75497,294 comment7,313 lHS 297 Well import7,315 Test number: 0017,540 Measurement: bbi Ib7 549 Remarks: details; yf120st

Top (MD):7,140,Des:Mesaverde 8,036 (ac Start Date |Top Perf (ft.. Bottom Pe... V (slurry) (... Total Prop... AIR (b .. ATP (psi) MTP (psi) ISIP (pei)

8,045 11/14/2005 7140 73158,412 comment8,416 IHS 297 Well 1mport8,471 Test number 0018,562 Measurement: bblib8,564 Remarks: details: yfi15fg8,5998,61i Frac Start Date Top Perf (ft .. Bottom Pe... V (slurry) (... Total Prop... AIR (b .. ATP (psl} MTP (psi) lŠlP (psi)

8,700 11/14/2005 6774 6837

S 7 Well ImportMeesasnuremm

nt:b I Ib8,784 Remarks: details: yfl20lg8,831 Frao Start Date Top Perf (ft Bottom Pe... V (slurry) (... Total Ñrop...AIR (b... ATP (psi) MTP (psi) ISIP(psi)8,8328,836 comment8,8508,8568,8718,8888,8918,092

PBTD 8,898

0,032 9,032

www.peloton.com Page 212 Report Printed:

API Well No: 43047361640000

STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS, AND MINING

FORM 9

5.LEASE DESIGNATION AND SERIAL NUMBER: UTU-75700

SUNDRY NOTICES AND REPORTS ON WELLSDo not use this form for proposals to drill new wells, significantly deepen existing wells below currentbottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION FOR PERMIT TODRILL form for such proposals.

6. IF INDIAN, ALLOTTEE OR TRIBE NAME:

7.UNIT or CA AGREEMENT NAME: LITTLE CANYON

1. TYPE OF WELL Gas Well

8. WELL NAME and NUMBER: LCU 6-6G

2. NAME OF OPERATOR: XTO ENERGY INC

9. API NUMBER: 43047361640000

3. ADDRESS OF OPERATOR: 382 Road 3100 , Aztec, NM, 87410

9. FIELD and POOL or WILDCAT: LOVE

4. LOCATION OF WELL FOOTAGES AT SURFACE: 2019 FNL 1596 FWL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: SENW Section: 06 Township: 11.0S Range: 21.0E Meridian: S

COUNTY: UINTAH

STATE: UTAH

11.

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


NOTICE OF INTENTApproximate date work will start:

SUBSEQUENT REPORTDate of Work Completion:

3/23/2010

SPUD REPORTDate of Spud:

DRILLING REPORTReport Date:

ACIDIZE ALTER CASING CASING REPAIR

CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME

CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

DEEPEN FRACTURE TREAT NEW CONSTRUCTION

OPERATOR CHANGE PLUG AND ABANDON PLUG BACK

PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION

REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON

TUBING REPAIR VENT OR FLARE WATER DISPOSAL

WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION

WILDCAT WELL DETERMINATION OTHER OTHER:


XTO Energy Inc. performed an acid treatment on this well per the attachedsummary report.

NAME (PLEASE PRINT) Barbara Nicol

TITLE Regulatory Compliance Tech

SIGNATURE N/A

DATE 4/13/2010

PHONE NUMBER:505 333-3159 Ext

ACID TREATMENT

PHONE NUMBER505 333-3642

April 13, 2010

April 15, 2010

iPI Well No: 43047361640000

FORM 9


DIVISION OF OIL, GAS, AND MINING EAS7E57DOEOSIGNATIONAND SERIAL NUMBER:

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

Do not use this form for proposals to drill new wells, significantly deepen e×isting wells below currentbottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION FOR PERMIT TO 7.UNIT or CA AGREEMENT NAME:

DRILL form for such proposals. LITTLE CANYON

1. TYPE OF WELL 8. WELL NAME and NUMBER:Gas Well LCU 6-6G

2. NAME OF OPERATOR: 9. API NUMBER:XTO ENERGY INC 43047361640000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:382 Road 3100 , Aztec, NM, 87410 505 333-3159 Ext LOVE

4.LOCATIONOFWELL COUNTY:FOOTAGESATSURFACE: UINTAH

2019 FNL 1596 FWLQTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:

Qtr/Qtr; SENW Section: 06 Township: 11.05 Range: 21.0E Meridian: S UTAH

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



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


SDUato

UWENrkRCEPmOpReTtion: DEEPEN FRACTURE TREAT NEW CONSTRUCTION

3/23/2010 OPERATOR CHANGE PLUG AND ABANDON PLUG BACK

SPUD REPORTPRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION

Date of Spud:REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


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

WILDCAT WELL DETERMINATION OTHER OTHER: ACID TREATMENT

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

XTO Energy Inc. performed an acid treatment on this well per the attachedsummary report. Accepted by the

Utah Division ofOil, Gas and Mining

FOR RECggig2 LY

NAME (PLEASE PRINT) PHONE NUMBER TITLEBarbara Nicol 505 333-3642 Regulatory Compliance Tech

SIGNATURE DATEN/A 4/13/2010

RECEIVED April 13,

iPI Well No: 43047361640000

FORM 9


DIVISION OF OIL, GAS, AND MINING EAS7E57DOEOSIGNATIONAND SERIAL NUMBER:







4.LOCATIONOFWELL COUNTY:FOOTAGESATSURFACE: UINTAH


Qtr/Qtr; SENW Section: 06 Township: 11.05 Range: 21.0E Meridian: S UTAH






SDUato

UWENrkRCEPmOpReTtion: DEEPEN FRACTURE TREAT NEW CONSTRUCTION


SPUD REPORTPRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION




WILDCAT WELL DETERMINATION OTHER OTHER: ACID TREATMENT


XTO Energy Inc. performed an acid treatment on this well per the attachedsummary report. Accepted by the

Utah Division ofOil, Gas and Mining

FOR RECggig2 LY



RECEIVED April 13,

EXECUTIVE SUMMARY REPORT 3/9/2010 - 4/13/2010

Report run on 4/13/2010 at 11:12 AM

1

Little Canyon Unit 06-06G Section 06-11S-21E, Uintah, Utah, Roosevelt

3/9/2010 MIRU Key Energy #6013. Bd well. PT tbg to 1500 psig w/22 bbl TFW @ 140 deg

w/success. Rlsd press & unseat pmp. LD 1-1/4" x 26' PR w/1.5 x 14' lnr. TOH w/1 - 3/4" rod sub, 3 - 3/4'' Norris 96 slick. NU & ppd 25 bls TFW @ 140*F dwn tbg due to heavy paraffin BU. Contd TOH w/215 - 3/4" Norris 96 slick skr d, LD 120 - 5/8'' Norris slick skr d, 16- 1-1/4" sbs & pmp. Pmp was stuck opn @ surf. ND WH, NU BOP. Unlnd tbg hngr @ 60k. Rlsd TAC. TOH & LD 179 jts 2-3/8'', 4.7#, J-55 EUE tbg, TAC, 1 jt 2-3/8'', 4.7#, J-55 EUE tbg. Prep equip to pl 2-1/16" tbg. SWI & SDFN.

================================= Little Canyon Unit 06-06G =================================

3/10/2010 Bd well. TOH & LD 101 jts 2-1/16'', 3.25#, J-55 EUE tbg, SN & OEMAJ w/mule shoe. Tbg showed hvy ext sc BU fr/6840 - 7200' FS. TIH w/4.75'' bit, 5.5'' csg scr & 229 jts 2-3/8'' tbg, 4.7#, L-80 tbg. Tgd sc BU @ 7340'. TOH w/ 29 jts tbg. EOT @ 6500'. Ppd 20 bbls TFW dwn tbg. SWI & SDFN.


3/11/2010 Bd well. TIH w/29 jts 2-3/8" tbg. Tgd fill @ 7340'. MIRU pwr swivel & AFU. Estb circion. CO sc BU fr/7340'- 7370' & fell thru. Circ cln & KW w/12 BW. TIH & tgd fill @ 8930'. Estb circion. CO 50' of fill to PBTD @ 8980' (tbg measurement). Circ cln & KW w/20 BW. RDMO pwr swivel & AFU. TOH w/tbg. LD bit & csg scr. SWI & SDFN.


3/12/2010 Bd well. TIH w/BHA & prod tbg strg. Set 5-1/2" TAC @ 8905' w/15K tens. Ld prod tbg on hgr as follows: 269 jts, 2-3/8", L-80, 4.7#, EUE 8rd tbg, 2-3/8" SN, 4' x 2-3/8" perf sub, 8' x 2-3/8" tbg sub, 5-1/2" Tech SH TAC & mule shoe col. SN @ 8888', TAC/EOT @ 8905', WA/MV perfs fr/6774'- 8836' & PBTD @ 8988'. ND BOP. NU B-1 adpt. RU swb tls. RIH w/XTO's 1.90" tbg broach to SN, no ti spts. POH & LD broach. Prep for A. trtmnt. SWI & SDFWE.


3/15/2010 MIRU Frac Tech ac equip. PT surf lines to 3000 psig. Pmp 1500 gals 15% HCl ac w/adds dwn tbg. Flshd w/36 bbls TFW @ 0 psig. Let ac soak 1 hr. RU & RIH w/swb tls. BFL @ 2,500' FS. S. 0 BO, Parted sandline 60' from rope socket on first run. Bd well. ND WH. NU BOP. Rlsd TAC. TOH w/BHA & prod tbg strg. Recd swb tls @ SN. TIH w/prod tbg strg as pld. Set 5-1/2" TAC @ 8905' w/15K tens. Ld prod tbg on hgr as follows: 269 jts, 2-3/8", L-80, 4.7#, EUE 8rd tbg, 2-3/8" SN, 4'x 2-3/8" perf sub, 8'x 2-3/8" tbg sub, 5-1/2" Tech- SH TAC & mule shoe col. SWI & SDFN.


3/16/2010 RU & RIH w/swb tls. BFL @ 4,500' FS. S. 0 BO, 95 BLW, 16 runs, 10 hrs. FFL @ 6,000'FS, FCP 500 - 150 psig. Fld smpls of blk & dirty wtr. Sample taken for analysis. SWI & SDFN.


3/17/2010 RU & RIH w/swb tls. BFL @ 5,500' FS. S. 0 BO, 9 BLW, 3 runs, 2 hrs. FFL 6,000'FS, FCP 500-150 psig. Fluid was clean w/ no solids. PU & loaded 2" x 1-1/4" x 19' RXBC pmp (XTO #265) w/3/4" x 8' .025 mesh screen GAC. TIH w/pmp, 3' Stablizer, shear tl pinned to 26K,3' Stablizer, 16 - 1-1/4" sbs, 60 -3/4'' Norris 96 w/ molded guides, 277- 3/4" Norris 96 skr d , 14' subs. New 1.5'' polish rod. Seated pmp. PT tbg to 1000 psig w/25 bbls TFW. Tstd ok. Rlsd press. LS pmp w/rig to 1000 psig. Gd PA. SWO & HWO. MIRU Nalco pmp trk, Pmp 30 bls chem pill w/ 165 gls Nalco EC 6652A SI, 5 gls Nalco EC 6106 Bio,5 gls/1000MA 844, then 200 bls TFW dwn TCA, 0-500 psig @ 4BPM. Unable to RWTP surf equip not ready. Turn well over to facilities.

3/24/2010 Prep PU for st up. Std C-96 PU (SN#210023C). Ppg @ 4 x 120” SPM. Std PU @ 3:00 p.m., 3/23/10 & RTP.

April 13, 2010

EXECUTIVE SUMMARY REPORT3/9/2010 - 4/13/2010


Little Canyon Unit 06-06G

Section 06-118-21E, Uintah, Utah, Roosevelt

3/9/2010 MIRU Key Energy #6013. Bd well. PT tbg to 1500 psig w/22 bbl TFW @ 140 degw/success. Rlsd press & unseat pmp. LD 1-1/4" x 26' PR w/1.5 x 14' lnr.TOH w/1 - 3/4" rod sub, 3 - 3/4'' Norris 96 slick. NU & ppd 25 bls TFW @140*F dwn tbg due to heavy paraffin BU. Contd TOH w/215 - 3/4" Norris 96slick skr d, LD 120 - 5/8'' Norris slick skr d, 16- 1-1/4" sbs & pmp. Pmpwas stuck opn @ surf. ND WH, NU BOP. Unlnd tbg hngr @ 60k. Rlsd TAC. TOH &LD 179 jts 2-3/8'', 4.7#, J-55 EUE tbg, TAC, 1 jt 2-3/8'', 4.7#, J-55 EUEtbg. Prep equip to pl 2-1/16" tbg. SWI & SDFN.


3/10/2010 Bd well. TOH & LD 101 jts 2-1/16'', 3.25#, J-55 EUE tbg, SN & OEMAJ w/muleshoe. Tbg showed hvy ext sc BU fr/6840 - 7200' FS. TIH w/4.75'' bit, 5.5''csg scr & 229 jts 2-3/8'' tbg, 4.7#, L-80 tbg. Tgd sc BU @ 7340'. TOH w/ 29jts tbg. EOT @ 6500'. Ppd 20 bbls TFW dwn tbg. SWI & SDFN.


3/11/2010 Bd well. TIH w/29 jts 2-3/8" tbg. Tgd fill @ 7340'. MIRU pwr swivel & AFU.Estb circion. CO sc BU fr/7340'- 7370' & fell thru. Circ cln & KW w/12 BW.TIH & tgd fill @ 8930'. Estb circion. CO 50' of fill to PBTD @ 8980' (tbgmeasurement). Circ cln & KW w/20 BW. RDMO pwr swivel & AFU. TOH w/tbg. LDbit & csg scr. SWI & SDFN.


3/12/2010 Bd well. TIH w/BHA & prod tbg strg. Set 5-1/2" TAC @ 8905' w/15K tens. Ldprod tbg on hgr as follows: 269 jts, 2-3/8", L-80, 4.7#, EUE 8rd tbg, 2-3/8"SN, 4' x 2-3/8" perf sub, 8' x 2-3/8" tbg sub, 5-1/2" Tech SH TAC & mule shoecol. SN @ 8888', TAC/EOT @ 8905', WA/MV perfs fr/6774'- 8836' & PBTD @8988'. ND BOP. NU B-1 adpt. RU swb tls. RIH w/XTO's 1.90" tbg broach toSN, no ti spts. POH & LD broach. Prep for A. trtmnt. SWI & SDFWE.


3/15/2010 MIRU Frac Tech ac equip. PT surf lines to 3000 psig. Pmp 1500 gals 15% HClac w/adds dwn tbg. Flshd w/36 bbls TFW @ 0 psig. Let ac soak 1 hr. RU &

RIH w/swb tls. BFL @ 2,500' FS. S. O BO, Parted sandline 60' from ropesocket on first run. Bd well. ND WH. NU BOP. Rlsd TAC. TOH w/BHA & prod tbgstrg. Recd swb tls @ SN. TIH w/prod tbg strg as pld. Set 5-1/2" TAC @8905' w/15K tens. Ld prod tbg on hgr as follows: 269 jts, 2-3/8", L-80,

4.7#, EUE 8rd tbg, 2-3/8" SN, 4'x 2-3/8" perf sub, 8'x 2-3/8" tbg sub, 5-1/2"Tech- SH TAC & mule shoe col. SWI & SDFN.


3/16/2010 RU & RIH w/swb tls. BFL @ 4,500' FS. S. O BO, 95 BLW, 16 runs, 10 hrs. FFL@ 6,000'FS, FCP 500 - 150 psig. Fld smpls of blk & dirty wtr. Sample takenfor analysis. SWI & SDFN.


3/17/2010 RU & RIH w/swb tls. BFL @ 5,500' FS. S. O BO, 9 BLW, 3 runs, 2 hrs. FFL6,000'FS, FCP 500-150 psig. Fluid was clean w/ no solids. PU & loaded 2" x1-1/4" x 19' RXBC pmp (XTO #265) w/3/4" x 8' .025 mesh screen GAC. TIHw/pmp, 3' Stablizer, shear tl pinned to 26K,3' Stablizer, 16 - 1-1/4" sbs,60 -3/4'' Norris 96 w/ molded guides, 277- 3/4" Norris 96 skr d , 14' subs.New 1.5'' polish rod. Seated pmp. PT tbg to 1000 psig w/25 bbls TFW. Tstdok. Rlsd press. LS pmp w/rig to 1000 psig. Gd PA. SWO & HWO. MIRU Nalcopmp trk, Pmp 30 bls chem pill w/ 165 gls Nalco EC 6652A SI, 5 gls Nalco EC6106 Bio,5 gls/1000MA 844, then 200 bls TFW dwn TCA, 0-500 psig @ 4BPM.Unable to RWTP surf equip not ready. Turn well over to facilities.

3/24/2010 Prep PU for st up. Std C-96 PU (SN#210023C). Ppg @ 4 x 120" SPM. Std PU @ 3:00p.m., 3/23/10 & RTP.

1

RECEIVED April 13,

EXECUTIVE SUMMARY REPORT3/9/2010 - 4/13/2010


Little Canyon Unit 06-06G

Section 06-118-21E, Uintah, Utah, Roosevelt

3/9/2010 MIRU Key Energy #6013. Bd well. PT tbg to 1500 psig w/22 bbl TFW @ 140 degw/success. Rlsd press & unseat pmp. LD 1-1/4" x 26' PR w/1.5 x 14' lnr.TOH w/1 - 3/4" rod sub, 3 - 3/4'' Norris 96 slick. NU & ppd 25 bls TFW @140*F dwn tbg due to heavy paraffin BU. Contd TOH w/215 - 3/4" Norris 96slick skr d, LD 120 - 5/8'' Norris slick skr d, 16- 1-1/4" sbs & pmp. Pmpwas stuck opn @ surf. ND WH, NU BOP. Unlnd tbg hngr @ 60k. Rlsd TAC. TOH &LD 179 jts 2-3/8'', 4.7#, J-55 EUE tbg, TAC, 1 jt 2-3/8'', 4.7#, J-55 EUEtbg. Prep equip to pl 2-1/16" tbg. SWI & SDFN.


3/10/2010 Bd well. TOH & LD 101 jts 2-1/16'', 3.25#, J-55 EUE tbg, SN & OEMAJ w/muleshoe. Tbg showed hvy ext sc BU fr/6840 - 7200' FS. TIH w/4.75'' bit, 5.5''csg scr & 229 jts 2-3/8'' tbg, 4.7#, L-80 tbg. Tgd sc BU @ 7340'. TOH w/ 29jts tbg. EOT @ 6500'. Ppd 20 bbls TFW dwn tbg. SWI & SDFN.


3/11/2010 Bd well. TIH w/29 jts 2-3/8" tbg. Tgd fill @ 7340'. MIRU pwr swivel & AFU.Estb circion. CO sc BU fr/7340'- 7370' & fell thru. Circ cln & KW w/12 BW.TIH & tgd fill @ 8930'. Estb circion. CO 50' of fill to PBTD @ 8980' (tbgmeasurement). Circ cln & KW w/20 BW. RDMO pwr swivel & AFU. TOH w/tbg. LDbit & csg scr. SWI & SDFN.


3/12/2010 Bd well. TIH w/BHA & prod tbg strg. Set 5-1/2" TAC @ 8905' w/15K tens. Ldprod tbg on hgr as follows: 269 jts, 2-3/8", L-80, 4.7#, EUE 8rd tbg, 2-3/8"SN, 4' x 2-3/8" perf sub, 8' x 2-3/8" tbg sub, 5-1/2" Tech SH TAC & mule shoecol. SN @ 8888', TAC/EOT @ 8905', WA/MV perfs fr/6774'- 8836' & PBTD @8988'. ND BOP. NU B-1 adpt. RU swb tls. RIH w/XTO's 1.90" tbg broach toSN, no ti spts. POH & LD broach. Prep for A. trtmnt. SWI & SDFWE.


3/15/2010 MIRU Frac Tech ac equip. PT surf lines to 3000 psig. Pmp 1500 gals 15% HClac w/adds dwn tbg. Flshd w/36 bbls TFW @ 0 psig. Let ac soak 1 hr. RU &

RIH w/swb tls. BFL @ 2,500' FS. S. O BO, Parted sandline 60' from ropesocket on first run. Bd well. ND WH. NU BOP. Rlsd TAC. TOH w/BHA & prod tbgstrg. Recd swb tls @ SN. TIH w/prod tbg strg as pld. Set 5-1/2" TAC @8905' w/15K tens. Ld prod tbg on hgr as follows: 269 jts, 2-3/8", L-80,

4.7#, EUE 8rd tbg, 2-3/8" SN, 4'x 2-3/8" perf sub, 8'x 2-3/8" tbg sub, 5-1/2"Tech- SH TAC & mule shoe col. SWI & SDFN.


3/16/2010 RU & RIH w/swb tls. BFL @ 4,500' FS. S. O BO, 95 BLW, 16 runs, 10 hrs. FFL@ 6,000'FS, FCP 500 - 150 psig. Fld smpls of blk & dirty wtr. Sample takenfor analysis. SWI & SDFN.


3/17/2010 RU & RIH w/swb tls. BFL @ 5,500' FS. S. O BO, 9 BLW, 3 runs, 2 hrs. FFL6,000'FS, FCP 500-150 psig. Fluid was clean w/ no solids. PU & loaded 2" x1-1/4" x 19' RXBC pmp (XTO #265) w/3/4" x 8' .025 mesh screen GAC. TIHw/pmp, 3' Stablizer, shear tl pinned to 26K,3' Stablizer, 16 - 1-1/4" sbs,60 -3/4'' Norris 96 w/ molded guides, 277- 3/4" Norris 96 skr d , 14' subs.New 1.5'' polish rod. Seated pmp. PT tbg to 1000 psig w/25 bbls TFW. Tstdok. Rlsd press. LS pmp w/rig to 1000 psig. Gd PA. SWO & HWO. MIRU Nalcopmp trk, Pmp 30 bls chem pill w/ 165 gls Nalco EC 6652A SI, 5 gls Nalco EC6106 Bio,5 gls/1000MA 844, then 200 bls TFW dwn TCA, 0-500 psig @ 4BPM.Unable to RWTP surf equip not ready. Turn well over to facilities.

3/24/2010 Prep PU for st up. Std C-96 PU (SN#210023C). Ppg @ 4 x 120" SPM. Std PU @ 3:00p.m., 3/23/10 & RTP.

1

RECEIVED April 13,

API Well No: 43047361640000



FORM 9


SUNDRY NOTICES AND REPORTS ON WELLSDo not use this form for proposals to drill new wells, significantly deepen existing wells below currentbottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION FOR PERMIT TODRILL form for such proposals.






9. API NUMBER: 43047361640000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 382 Road 3100 , Aztec, NM, 87410 505 333-3159 Ext



COUNTY: UINTAH

STATE: UTAH

11.





12/20/2010












WILDCAT WELL DETERMINATION OTHER OTHER: CHEMICAL TRTMT


XTO Energy Inc. performed a chemical treatment on this well per thefollowing: 12/20/2010: MIRU Nalco. Trtd TCA w/110 gal sc inhib, 10 gal

biocide mixed w/20 bbls trtd wtr & follow w/200 bbls 2% KCl wtr. SWI & letsoak overnight. RDMO Nalco. SDFN.

NAME (PLEASE PRINT) PHONE NUMBER Barbara Nicol 505 333-3642

TITLE Regulatory Compliance Tech

SIGNATURE N/A

DATE 1/11/2011

January 11, 2011

01/11/2011

iPI Well No: 43047361640000

FORM 9


DIVISION OF OIL, GAS, AND MINING LEAS7E57DOEOSIGNATIONAND SERIAL NUMBER:







4.LOCATIONOFWELL COUNTY:FOOTAGES AT SURFACE: UINTAH


Qtr/Qtr: SENW Section: 06 Township: 11.05 Range: 21.0E Meridian: S UTAH






SDat ofUWENrkRCEPmOption: DEEPEN FRACTURE TREAT NEW CONSTRUCTION


sPuD REPORTPRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION






XTO Energy Inc. performed a chemical treatment on this well per thefollowing: 12/20/2010: MIRU Nalco. Trtd TCA w/110 gal sc inhib, 10 gal Accepted by the

biocide mixed w/20 bbls trtd wtr & follow w/200 bbls 2% KCI wtr. SWI & lebtah Division ofsoak overnight. RDMO Nalco. SDFN· Oil, Gas and Mining

FOR REGORROINLY



RECEIVED January 11,

iPI Well No: 43047361640000

FORM 9


DIVISION OF OIL, GAS, AND MINING LEAS7E57DOEOSIGNATIONAND SERIAL NUMBER:







4.LOCATIONOFWELL COUNTY:FOOTAGES AT SURFACE: UINTAH


Qtr/Qtr: SENW Section: 06 Township: 11.05 Range: 21.0E Meridian: S UTAH






SDat ofUWENrkRCEPmOption: DEEPEN FRACTURE TREAT NEW CONSTRUCTION


sPuD REPORTPRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION






XTO Energy Inc. performed a chemical treatment on this well per thefollowing: 12/20/2010: MIRU Nalco. Trtd TCA w/110 gal sc inhib, 10 gal Accepted by the

biocide mixed w/20 bbls trtd wtr & follow w/200 bbls 2% KCI wtr. SWI & lebtah Division ofsoak overnight. RDMO Nalco. SDFN· Oil, Gas and Mining

FOR REGORROINLY



RECEIVED January 11,

RECEIVED: Apr. 01, 2016



FORM 9


SUNDRY NOTICES AND REPORTS ON WELLS

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






9. API NUMBER: 43047361640000

3. ADDRESS OF OPERATOR: PHONE NUMBER: PO Box 6501 , Englewood, CO, 80155 303 397-3727 Ext



COUNTY: UINTAH

STATE: UTAH

11.





3 /3 /2016












WILDCAT WELL DETERMINATION OTHER OTHER:


XTO Energy Inc. Performed an Acid Treatment on this well per thefollowing: 02/26/16: MIRU SLU. TOH w/plunger & BHBS. Fill @ 8,906'(no perfs covered). RDMO SLU. 02/29/16: MIRU pump truck. Pump1000 gal 15% HCL w/3 gal T scav. dn csg and flush w/25 bbls TFW.Pump 250 gal 15% HCL w/2 gal T scav. dn tbg. and flush w/32 bbls

TFW. RDMO. 03/02/16: MIRU SWU. RIH w/swb tl's. SWIFPBU. 03/03/16:RIH w/swb tl's. Inspect & dropd Viton plunger. Cycle plunger to surf &

RWTP 03/03/16. RDMO SWU.

NAME (PLEASE PRINT) PHONE NUMBER Rhonda Smith 505 333-3215

TITLE Regulatory Clerk

SIGNATURE N/A

DATE 4 /1 /2016

April 05, 2016

Sundry Number: 70766 API Well Number: 43047361640000Sundry Number: 70766 API Well Number: 43047361640000

FORM 9STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING UTU-75700


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

FOR PERMIT TO DRILL form for such proposals. LITTLECANYON



3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:PO Box 6501 , Englewood, CO, 80155 303 397-3727 Ext LOVE

4. LOCATION OF WELL COUNTY:FOOTAGESATSURFACE: UINTAH

2019 FNL 1596 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:

QtrlQtr: SENW Section: 06 Township: 11.0S Range: 21.0E Meridian: S UTAH

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


ACI DIZE ALTER CASING CASING REPAIR



SUBSEQUENT REPORTDate of Work Completion: DEEPEN FRACTURE TREAT NEW CONSTRUCTION

3/3/20 16OPERATOR CHANGE PLUG AND ABANDON PLUG BACK

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



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

WILDCATWELLDETERMINATION OTHER OTHER:


XTO Energy Inc. Performed an Acid Treatment on this well per the Accepted by thefollowing: 02/26/16: MIRU SLU. TOH w/plunger & BHBS. Fill @ 8,906' Utah Division of

(no perfs covered). RDMO SLU. 02/29/16: MIRU pump truck. Pump Oil, Gas and Mining

1000 gal 15% HCL w/3 gal T scav. dn csg and flush w/25 bbls TFW. FOR RECORD ONLYPump 250 gal 15% HCL w/2 gal T scav. dn tbg. and flush w/32 bbls April 05, 2016

TFW. RDMO. 03/02/16: MIRU SWU. RIH w/swb tl's. SWIFPBU. 03/03/16:RIH w/swb tl's. Inspect & dropd Viton plunger. Cycle plunger to surf &

RWTP 03/03/16. RDMO SWU.

NAME (PLEASE PRINT) PHONE NUMBER TITLERhonda Smith 505 333-3215 Regulatory Clerk


RECEIVED: Apr. 01,

Division of Oil, Gas and Mining

Operator Change/Name Change Worksheet-for State use only

Effective Date' 7/112020 FORMER OPERATOR: NEW OPERA TOR: XTO Energy, Inc. Utah Gas Op Ltd

Groups: "

Hill Creek River Bend Little .Canyon Big Pack

.' , "

WELL INFORMATION:

WeUName Range

See Attached List -

Total Well Count: 600 Pre-Notice Completed: 812612020 OPERATOR CHANGES DOCUMENTATION: I . Sundry or legal documentation was received from the FORM ER operator on:

2. Sundry or legal documentation was received from the NEW operator on: 3. New operator Division of Corporations Business Number:

REVIEW: Receipt of Acceptance of Drilling Procedures for APD on: Reports current for ProductionlDisposition & Sundries: OPS/SlrrA well(s) reviewed for full cost bonding: Approved by Dustin UIC5 on all disposaVinjectionlstorage weU(s) Approved on: Approved by Dayne Surface Facility(s) included in operator change:

NEW OPERA TOR BOND VERIFICATION:

Statelfee well(s) covered by Bond Number(s):

DATA ENTRY: Well(s) update in the RBDMS on: Group(s) update in ROBMS on :

Surface Facilities update in RBDMS on:

Entities Updated in RBDMS on:

RLBOOI5799

IOn12020 IOn12020 IOn12020 IOnt2020

COMMENTS: Need SI plan and plugging estimate for the LCU 7-2H

Dir

10636157-0161

IOn12020 10/512020 91212020 Hill Creek Kings Canyon little canyon RBU 1l-18F RBU 9-17E

River Bend SWD 1 Tap 1 Tap2 Tap 3 TapS West Willow Creek

NA

Entity Number

7/112020 7/112020

LCU 7-2H well had plugging operations started on 10/512020, revived approval from Dustin to make the operator change.

Status

10/9/2020

STATE OF UTAH DEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING

SUNDRY NOTICES AND REPORTS ON WELLS

00 not use 1/1,. fo<m for proPosals to drjl new wells. sign,ficantly deepen e .. stong we!!s below current bottom·hole depth. reenter plugge<l wells. or to drill honzon.ol lo.e",t • . Use APPUCATtON FOR PERMIT TO DRILL form for svch prOllosals.

1. TYPE OF WELL OIL WELL 0 GAS WELL IZI OTHER __________ _

2. NAME OF OPERATOR:

XTO Ener~lY Inc

STAI~ TX ll" 77389 I PHONE NUMBER:

(800) 299-2800 3. ADDRESS OF OPERATOR:

22777 Springwoods Villagtj CITY Spring

4. LOCATION OF WELL

FOOTAGES AT SURFACE: Multiple (See Attached List)

OTRIOTR, SECTION. TOWNSHIP. RANGE. MERIDIAN'

FORM 9

5. LEASE DESIGNATION AND SERIAL NUMBER:

Multiple (See Attached List) 6. IF INDIAN. AlLOTIEE OR TRIBE NAME:

NIA 7. UNIT or CA AGREH4ENT NAME:

Multiple (See Attached list) 8. WELL NAME and NUMBER:

Multiple (See Attached list) 9. API NUMBER:

Multiple 10. FIELD AND POOL OR WILDCAT:

Multiple (See Attached List)

COUNTY: Multiple

STATE.

UTAH

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


!2l 0 ACIDIZE 0 DEEPEN 0 REPERFORATE CURRENT FORMATION NOTICE OF INTENT

(Sobmil in Duplicate) 0 AlTER CASING 0 FRACTURE TREAT 0 SIDETRACK TO REPAIR WELL

Appro.imate dale work will start 0 CASING REPAIR 0 NEW CONSTRUCTION 0 TEMPORARILY ABANDON

7/112020 0 CHANGE TO PREVIOUS PLANS 121 OPERATOR CHANGE 0 TUBING REPAIR

0 CHANGE TUBING 0 PLUG AND ABANDON 0 VENT OR FLARE

0 SUBSEQUENT R EPORT 0 CHANGE WELL NAME 0 PLUG BACK 0 WATER DISPOSAL (Submit Original Form Only)

0 CffANGE WELL STATUS 0 PRODUCTION (STARTIRESUME) 0 WATER SHUT·OFF Date of .. VQfk comp{eboo:

0 COMMINGLE PRODUCING FORMATIONS 0 RECLAMATION OF WELL SITE 0 OTHER:

0 CONVERT WELL TYPE 0 RECOMPLETE • DIFFERENT FORMATION

12. D E SC RIBE PROPOSED OR COMPLETED OPERATIONS. Clearly show all pertin ent details in~lud ing d ates. depths. v olumes. etc.

Seller / From: XTO Energy Inc 22777 Springwoods Village Parkway Spring, TX 77389-1425 817.378.5572

Buyer 1 To: Utah Gas Op Ltd 8310 South Valley Highway, Suite 300 Englewood, CO 80112 402.206.7756

Effective July 1, 2020 interest assigned or transferred from XTO Energy Inc. (XTO) to Utah Gas Op Ltd (UGC) hereby certifies that it is authorized by the proper lease interest owner to conduct lease operations and is responsible under the terms and conditions of the leases associated with the attached list of wells. Bond coverage pursuant to 43 CFR 3104 for lease activities is provided by Utah Gas Op Ltd with their BLM Bond No. RLB0015799.

TITLE

DATE

(This space for St~t. VIO only)

. 512000) (See Instructions on Reverse Side)

Land Mgr A&D, as Agent and Attorney in Fact

7/1/2020

APPROVED OCT 07 2020

~ Of!- GAS & MININ~ .

By:~gJLt{)..9d fi..oO ....



TRANSFER OF AUTHORITY TO INJECT Well Name and Number River Bend Unit 13-11 F

Location of Well

Footage : 96FSL and 315 FWL

QQ, Section, Township, Range: SWSW 11 10S 20E

I EFFECTIVE DATE OF TRANSFER: _7_1_1/_20_2_0 ___ _

CURRENT OPERA TOR

Company: XTO Energy Inc

Address : 22777 Springswoods V illage Parkway

city Spring state TX zi~ 77389

Phone: (817) 870-2800

Comments'

NEW OPERA TOR

Company: Utah Gas Op L TO

Address: 8310 S Valley Hwy, Ste 300

cit~ Englewood state CO ziQ 801 12

Phone: (402) 206-7756

Comments

(This space for State use only) Accepted by the

, 12/2019)

Utah Division of Oil, Gas and Mining

Sep 02,2020

t?~ Permit Manager

County : Uintah

State : UTAH

Name:

Signature :

Title:

Date:

Name:

Signature:

Title:

Date:

API Number 4304730973

Field or Unit Name Natural Buttes

Lease Designation and Number UTU7206

Phyllis Hinze

p~~*=,¥ Agent and Attorney-in-Fact

J J I JUJZO

Aaron Martinsen

~ Chief Executive Officer

7-J-2v

~ EPA approval required

Max Inj. Press. ~I ax Inj. Ra te Perm. Inj. Interva l Packer Depth Next MIT Due

UIC FORM 5


DIVISION OF OIL , GAS AND MINING

TRANSFER OF AUTHORITY TO INJECT Well Name and Number

River Bend Unit 4-22F INJ Location of Well

Footage . 891 FNL and 1164 FWL

QQ. Section, Township. Range: NWNW 22 10S 20E

I EFFECTIVE DATE OF TRANSFER: _7_/1_/2_0_2_0 __ _

CURRENT OPERATOR

Company: XTO Energy Inc

Address : 22777 Springswoods Village Parkway

city Spring state TX zip 77389

Phone: (817) 870-2800

Comments:

NEW OPERATOR

Company: Utah Gas Op LTD

Address: 8310 S Valley Hwy, Ste 300

cit~ Englewood state CO zip 80112

Phone: (402) 206-7756

Comments:

(This space for State use only) Accepted by the Utah Division of

Oil, Gas and Mining Sep 02,2020

FOR RECORD ONLY

Q~ Permit Manager

( 1212019)

County : Uintah

State : UTAH

Name:

Signature:

Title:

Date:

Name:

Signature:

Title:

Date:

API Number

4304731615 Field or Unit Name

Natural Buttes Lease Designation and Number

UTU0143521A

Phyllis Hinze

Aaron Martinsen

~~ Chief Executive Officer

7-1--;LD

~ EPA approval required

Nlax Illj . Pres. Max Inj. Rate Perm. Inj. Interval Packer Deplh Next M IT Due

UIC FORM 5



TRANSFER OF AUTHORITY TO INJECT Well Name and Number HILL CREEK UNIT 01-28F INJ

Location of Well

Footage : 767' FNL & 628' FEL

QQ, Section, Township, Range: NENE 28 10S 20E

I EFFECTIVE DATE OF TRANSFER: _7_/1_/2_0_2_0 __ _

CURRENT OPERATOR

Company: XTO ENERGY INC,

Address : 22777 SPRINGSWOOD VILLAGE PARKWAY

cit~ SPRING state TX ziQ 77389-1425

Phone: (817) 870-2800

Comments:

NEW OPERATOR

Company: UTAH GAS OP LTD

Address: 8310 SOUTH VALLEY HIGHWAY, SUITE 300

cit~ ENGLEWOOD state CO zip 80112

Phone: (402) 206-7756

Comments:

(This space for State use only)

Transfer approved by:

Accepted by the Utah Division of

Oil. Gas and Mining

Title: Sep 02,2020 FOR RECORD ONLY

Q~ Permit Manager

Comments:

(612018)

County : UINTAH

State : UTAH

Name:

Signature:

Title:

Date:

API Number 4304733671

Field or Unit Name HILL CREEK

Lease Designation and Number 1420H624783

Phyllis Hinze

PWj,eMdz±-:y Agent and Attorney-in-Fact

7/1/2020

Name: Aaron Martinsen

Signature: ~ Title: Chief Executive Officer

Date: 7/1/2020

Approval Date:

@ EPA approval required

UIC FORM 5

Documents

oo O O B Wellington, Utah P.O. Box12-1/4" 8-5/8" ST&C 32# 2,000' Lead, 219 sks, tail, 100 sks top attached Drilling Plan 5-1/2" 17# 9,200' Lead, 435 sks Tai see attached Drilling is