api well number: 43013526290000 api well number

RECEIVED: January 29, 2014

STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER

Ute Tribal 31-06

2. TYPE OF WORK

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

ANTELOPE CREEK

4. TYPE OF WELLOil Well Coalbed Methane Well: NO

5. UNIT or COMMUNITIZATION AGREEMENT NAMEANTELOPE CREEK

6. NAME OF OPERATORPETROGLYPH OPERATING CO

7. OPERATOR PHONE208 685-7685

8. ADDRESS OF OPERATOR960 Broadway Avenue, Ste 500, Boise, ID, 83703

9. OPERATOR [email protected]

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

1420H623520

11. MINERAL OWNERSHIP

FEDERAL INDIAN STATE FEE 12. SURFACE OWNERSHIP

FEDERAL INDIAN STATE FEE

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

14. SURFACE OWNER PHONE (if box 12 = 'fee')

15. ADDRESS OF SURFACE OWNER (if box 12 = 'fee')

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

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

Ute Indian Tribe

18. INTEND TO COMMINGLE PRODUCTION FROMMULTIPLE FORMATIONS

YES (Submit Commingling Application) NO

19. SLANT

VERTICAL DIRECTIONAL HORIZONTAL

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

LOCATION AT SURFACE 1989 FNL 2150 FEL SWNE 31 5.0 S 3.0 W U

Top of Uppermost Producing Zone 1980 FNL 1980 FWL SENW 31 5.0 S 3.0 W U

At Total Depth 1980 FNL 1980 FWL SENW 31 5.0 S 3.0 W U

21. COUNTYDUCHESNE

22. DISTANCE TO NEAREST LEASE LINE (Feet)1989

23. NUMBER OF ACRES IN DRILLING UNIT640

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

19

26. PROPOSED DEPTHMD: 6348 TVD: 67181

27. ELEVATION - GROUND LEVEL

6798

28. BOND NUMBER

LPM4138336

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

43-8342

Hole, Casing, and Cement Information

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

COND 20 14 0 - 53 5.0 Unknown 10.0 Class G 25 1.17 15.8

SURF 12.25 8.625 0 - 493 24.0 J-55 ST&C 10.0 Class G 226 1.17 15.8

PROD 7.875 5.5 0 - 6348 15.5 J-55 LT&C 10.0 Class G 484 1.92 12.5

Class G 343 1.46 13.4

ATTACHMENTS

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

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

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

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

NAME Ed Trotter TITLE Agent PHONE 435 789-4120

SIGNATURE DATE 10/31/2013 EMAIL [email protected]

API NUMBER ASSIGNED

43013526290000

Permit Manager

APPROVAL

FORM 3

AMENDED REPORT

API Well Number: 43013526290000

CONFIDE

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FORM 3STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUM Ribal31-06

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

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

6. NAME OF OPERATOR 7. OPERATOR PHONEPETROGLYPH OPERATING CO 208 685-7685

8. ADDRESS OF OPERATOR 9. OPERATOR E-MAIL960 Broadway Avenue, Ste 500, Boise, ID, 83703 [email protected]

10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL,INDIAN,ORS14A20EH623520

FEDERAL INDIANISTATE FEE FEDERAL INDIAN STATE FEEI

13. NAME OF SURFACE OWNER (if box 12 = 'fee') 14. SURFACE OWNER PHONE (if box 12 = 'fee')

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

18. INTEND TO COMMINGLE PRODUCTION FROM 19. SLANT17. INDIAN ALLOTTEE OR TRIBE NAME

MULTIPLE FORMATIONS(if box 12 = 'INDIAN')Ute Indian Tribe YES (Submit Commingling Application) NO VERTICAL DIRECTIONAL HORIZONTAL





21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITDUCHESNE 1989 640

25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 6348 TVD: 67181

19

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

6798 LPM4138336 43-8342




SURF 12.25 8.625 0 - 493 24.0 J-55 ST&C 10.0 Class G 226 1.17 15.8

PROD 7.875 5.5 0 - 6348 15.5 J-55 LT&C 10.0 Class G 484 1.92 12.5

Class G 343 1.46 13.4

ATTACHMENTS


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

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

DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLYOR HORIZONTALLY DRILLED) TOPOGRAPHICAL MAP



API NUMBER ASSIGNED APPROVAL43013526290000

Permit Manager

RECEIVED: January 29,


FORM 3STATE OF UTAH



















19


6798 LPM4138336 43-8342




SURF 12.25 8.625 0 - 493 24.0 J-55 ST&C 10.0 Class G 226 1.17 15.8

PROD 7.875 5.5 0 - 6348 15.5 J-55 LT&C 10.0 Class G 484 1.92 12.5

Class G 343 1.46 13.4

ATTACHMENTS








Permit Manager



FORM 3STATE OF UTAH



















19


6798 LPM4138336 43-8342




SURF 12.25 8.625 0 - 493 24.0 J-55 ST&C 10.0 Class G 226 1.17 15.8

PROD 7.875 5.5 0 - 6348 15.5 J-55 LT&C 10.0 Class G 484 1.92 12.5

Class G 343 1.46 13.4

ATTACHMENTS








Permit Manager



FORM 3STATE OF UTAH



















19


6798 LPM4138336 43-8342




SURF 12.25 8.625 0 - 493 24.0 J-55 ST&C 10.0 Class G 226 1.17 15.8

PROD 7.875 5.5 0 - 6348 15.5 J-55 LT&C 10.0 Class G 484 1.92 12.5

Class G 343 1.46 13.4

ATTACHMENTS








Permit Manager


RECEIVED: October 31, 2013

CONFIDENTIAL NINE POINT DRILLING PLAN

PETROGLYPH OPERATING COMPANY, INC

UTE TRIBAL 31-06

SW NE, SEC 31, T5S, R3W

DUCHESNE COUNTY, UTAH

BLM 9 point drilling plan--POCI 1 of 7

1. ESTIMATED TOPS OF IMPORTANT GEOLOGICAL MARKERS:

Formation Subsea TVD MD

Rig KB=~13’ above GGL 6811 0 0

Surface Formation = Uinta

Uinta 6798 13 13

Green River 5302 1509 1515

Trona 4052 2759 2831

Mahogany Shale 3895 2916 3002

“B” Marker

Waterflood

Unit In

terval 2835 3976 4127

“X” Marker 2357 4454 4616

Douglas Creek Marker 2219 4592 4757

“B” Limestone 1846 4965 5132

Base Castle Peak Limestone 1310 5501 5668

BSCARB 878 5933 6100

Wasatch 612 NDE NDE Formation at TD: Green River Rig TD 630 6181 6348

2. ESTIMATED DEPTHS OF ANTICIPATED WATER, OIL, GAS OR MINERAL

FORMATIONS:

Substance Formation Subsea TVD MD

Base of moderately saline ground water*

Uinta 5500 1311 1314

Oil/Gas Douglas Creek 2219 4592 4757

Oil/Gas Castle Peak 1310 5501 5668

Any water encountered during drilling shall be sampled, analyzed and reported to BLM, Vernal office

using State of Utah DOGM Form 7 Report of Water Encountered during Drilling. The following

analyses shall be performed on any water encountered:

Flow rate (or blowtest) Temperature pH TDS

Dissolved Iron Dissolved Magnesium Dissolved Bicarb. Dissolved Sulfate

Dissolved Calcium Dissolved Sodium Dissolved Carbonate Dissolved Chloride

All depths through the “Base of moderately saline ground water”*, along with any water encountered

below that depth which is less than 10,000 TDS, shall be protected by the surface casing or by lifting the

cement of the production casing into the surface casing.

*Base of Moderately Saline Groundwater from Howells, Longson and Hunt, 1981, Utah State Technical

Publication 92: The Base of the Moderately Saline Water in the Uinta Basin, Utah


CONFIDE

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CONFIDENTIALNINE POINT DRILLING PLAN

PETROGLYPH OPERATING COMPANY, INCUTE TRIBAL 31-06

SW NE, SEC 31, T5S, R3WDUCHESNE COUNTY, UTAH


Formation Subsea TVD MDRigKB=~13'above GGL 6811 0 0SurfaceFormation = UintaUinta 6798 13 13Green River 5302 1509 1515Trona 4052 2759 2831MahoganyShale 3895 2916 3002"B"Marker - 2835 3976 4127"X"Marker g 2 2357 4454 4616Douglas CreekMarker

i¯T 2219 4592 4757

"B"Limestone N = 1846 4965 5132Base CastlePeak Limestone 1310 5501 5668BSCARB 878 5933 6100Wasatch 612 NDE NDEFormationat TD:Green River RigTD 630 6181 6348

2. ESTIMATED DEPTHS OF ANTICIPATED WATER, OIL, GAS OR MINERALFORMATIONS:

Substance Formation Subsea TVD MDBaseof moderatelysalineground Uinta 5500 1311 1314water*

Oil/Gas DouglasCreek 2219 4592 4757Oil/Gas CastlePeak 1310 5501 5668

Any water encountered during drilling shall be sampled, analyzed and reported to BLM, Vernal officeusing State of Utah DOGM Form 7 Report of Water Encountered during Drilling. The followinganalyses shall be performed on any water encountered:

Flow rate (or blowtest) Temperature pH TDSDissolved Iron Dissolved Magnesium Dissolved Bicarb. Dissolved SulfateDissolved Calcium Dissolved Sodium Dissolved Carbonate Dissolved Chloride

All depths through the "Base of moderately saline ground water"*, along with any water encounteredbelow that depth which is less than 10,000 TDS, shall be protected by the surface casing or by lifting thecement of the production casing into the surface casing.

*Base of Moderately Saline Groundwater from Howells, Longson and Hunt, 1981, Utah State TechnicalPublication 92: The Base of the Moderately Saline Water in the Uinta Basin, Utah

BLM9 point drilling plan--POCI 1 of 7

RECEIVED: October 31,







i¯T 2219 4592 4757

















i¯T 2219 4592 4757

















i¯T 2219 4592 4757














UTE TRIBAL 31-06




3. PROPOSED CASING PROGRAM:

String Hole Casing Top - MD Bottom - MD Weight lb/ft Grade Thread

Conductor 20" 14" surface 53' steel Cond’r none

Surface 12-1/4" 8-5/8" surface 493’ 24 J-55 STC

Production 7-7/8" 5-1/2" surface 6348’ 15.5 J-55 LTC

String Hole Casing Collapse Burst Tensile

Surface 12-1/4" 8-5/8" 1,370 psi 2,950 psi 244,000 lb

Production 7-7/8" 5-1/2" 4,040 psi 4,810 psi 248,000 lb

• All casing will be new or inspected.

• The surface and production strings shall have a minimum of one (1) centralizer on each of the

bottom three (3) joints.

• The production string shall have a minimum of one (1) centralizer for every three (3) joints from TD

to the top of the “B” marker at 4127’MD.

4. PROPOSED CEMENTING PROGRAM:

String Top

Cement Description Sacks

Excess Weight Yield

Bottom Vol (ft3) (ppg) (ft3/sk)

Conductor 0

Construction Grade Cement Sufficient volumes to grout Conductor 53

Surface 0 Class G +2% CaCl2

+0.25 lb/sk Cello Flake 226

30% 15.8 1.17 493 264

Production Lead

0 EXPANDACEM (Class G +additives) + 1 lb/sk Granulite TR¼ (LCM)

484 30% 12.5 1.92

4127 930

Production Tail

4127 EXPANDACEM (Class G +additives) + 1 lb/sk Granulite TR¼ (LCM)

343 30% 13.4 1.46

6348 500

• The 8-5/8” surface casing shall be cemented back to surface. In the event that during the primary

surface cementing operation the cement does not circulate to surface, or if the cement level should

fall back more than 8 feet from surface, then a remedial surface cementing operation shall be

performed to insure adequate isolation and stabilization of the surface casing.

• The 5-1/2” production casing shall be cemented back to surface. In the event that during the primary

cementing operation the cement does not circulate to surface, a remedial cementing operation shall

be performed only if necessary to lift cement above the Surface Casing Shoe at 493’MD.


CONFIDE

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String Hole Casing Top - MD Bottom - MD Weight Ib/ft Grade ThreadConductor 20" 14" surface 53' steel Cond'r noneSurface 12-1/4" 8-5/8" surface 493' 24 J-55 STC

Production 7-7/8" 5-1/2" surface 6348' 15.5 J-55 LTC

String Hole Casing Collapse Burst TensileSurface 12-1/4" 8-5/8" 1,370 psi 2,950 psi 244,000 lb

Production 7-7/8" 5-1/2" 4,040psi 4,810psi 248,000lb


• The surface and production strings shall have a minimum of one (1) centralizer on each of thebottom three (3) joints.

• The production string shall have a minimum of one (1) centralizer for every three (3) joints from TDto the top of the "B" marker at 4127'MD.


Top . Sacks Weight YieldString CementDescription ExcessBottom Vol(ft3) (ppg) (ft3/sk)OConductor --- ---- ConstructionGradeCement SufficientvolumestogroutConductor530 Class G +2% CaCl2 226Surface -- -- 30% 15.8 1.17493 +0.25 lb/sk CelloFlake 264

Production 0 EXPANDACEM(ClassG +additives) 484 -- 30% 12.5 1.92Lead 4127 + 1 lb/skGranuliteTR¼ (LCM) 930Production 4127 EXPANDACEM(ClassG +additives) 343 -- 30% 13.4 1.46Tail 6348 + 1 lb/skGranuliteTR¼ (LCM) 500

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

• The 5-1/2" production casing shall be cemented back to surface. In the event that during the primarycementing operation the cement does not circulate to surface, a remedial cementing operation shallbe performed only if necessary to lift cement above the Surface Casing Shoe at 493'MD.

BLM9 point drilling plan--POci 2 of 7






























































UTE TRIBAL 31-06




5. MINIMUM PRESSURE CONTROL AND SAFETY EQUIPMENT:

• An 8”, 2000 PSI, Double Ram BOPE with Hydraulic Closing Unit shall be used.

• A 2000 PSI Working Pressure Annular shall be used.

• The flowline shall have a minimum diameter of 10”.

• Auxiliary equipment shall be a Kelly Cock, Bit Float, and a TIW valve with drill pipe threads.

• Spark arrestors shall be equipped on all engine exhausts within 100 feet of the wellbore.

• See attached 2,000 psi BOP schematic diagram.

BOPE TESTING PROCEDURE:

• The BOPE shall be tested by a professional tester to conform to Onshore Order #2.

6. MUD PROGRAM:

A. SURFACE HOLE

• The surface hole will be drilled with an air/mist system from 0’ to 493’. All cutting shall be

directed to pit.

• A trailer-mounted compressor with a capacity of 2000 CFM will be used. Compressor will have

a safety shut-off valve located less than 15 feet from the driller’s controls of the rig.

• The rat and mouse holes will be drilled with the air rig after surface casing is cemented.

• The 140 barrel water truck used with the deduster will be the source of kill fluid in the highly

unlikely event of pressure being encountered during drilling of the surface hole.

• Operator requests the following variances from Onshore Order 2 part E during drilling of the

surface hole. Operator will use air drilling techniques only on surface hole:

o Operator requests a variance to regulations requiring the blooie line discharge to be 100’

from the wellbore. Due to reduced location size, the blooie line discharge will be

approximately 75’ from the wellbore and securely anchored.

o Operator requests a variance to regulations requiring an automatic igniter or continuous pilot

light on the blooie line. A mister shall be on the end of the blooie line.

o Operator requests a variance to regulations requiring compressors be located in the opposite

direction from the blooie line; a minimum of 100’ from the wellbore. Due to the reduced

location size, the compressors shall be located as close as is reasonable to the opposite

direction from the blooie line and 75’ from the wellbore.

o Operator requests a variance to regulations requiring a BOPE on the hole when drilling the

surface hole. An air bowl shall be utilized on the diverter system in place of a BOPE.


CONFIDE

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• An 8", 2000 PSI, Double Ram BOPE with Hydraulic Closing Unit shall be used.• A 2000 PSI Working Pressure Annular shall be used.• The flowline shall have a minimum diameter of 10".• Auxiliary equipment shall be a Kelly Cock, Bit Float, and a TIW valve with drill pipe threads.• Spark arrestors shall be equipped on all engine exhausts within 100 feet of the wellbore.• See attached 2,000 psi BOP schematic diagram.

BOPE TESTING PROCEDURE:• The BOPE shall be tested by a professional tester to conform to Onshore Order #2.

6. MUD PROGRAM:

A. SURFACE HOLE

• The surface hole will be drilled with an air/mist system from O' to 493'. All cutting shall bedirected to pit.

• A trailer-mounted compressor with a capacity of 2000 CFM will be used. Compressor will havea safety shut-off valve located less than 15 feet from the driller's controls of the rig.


• The 140 barrel water truck used with the deduster will be the source of kill fluid in the highlyunlikely event of pressure being encountered during drilling of the surface hole.

• Operator requests the following variances from Onshore Order 2 part E during drilling of thesurface hole. Operator will use air drilling techniques only on surface hole:o Operator requests a variance to regulations requiring the blooie line discharge to be 100'

from the wellbore. Due to reduced location size, the blooie line discharge will beapproximately 75' from the wellbore and securely anchored.

o Operator requests a variance to regulations requiring an automatic igniter or continuous pilotlight on the blooie line. A mister shall be on the end of the blooie line.

o Operator requests a variance to regulations requiring compressors be located in the oppositedirection from the blooie line; a minimum of 100' from the wellbore. Due to the reducedlocation size, the compressors shall be located as close as is reasonable to the oppositedirection from the blooie line and 75' from the wellbore.

o Operator requests a variance to regulations requiring a BOPE on the hole when drilling thesurface hole. An air bowl shall be utilized on the diverter system in place of a BOPE.










6. MUD PROGRAM:

A. SURFACE HOLE



















6. MUD PROGRAM:

A. SURFACE HOLE



















6. MUD PROGRAM:

A. SURFACE HOLE















UTE TRIBAL 31-06




B. PRODUCTION HOLE

• The production hole shall be drilled with a freshwater polymer system from 493’ to 6348’.

LSND mud if conditions warrant.

• Clay inhibition and hole stability shall be achieved with a Diammonium Phosphate (DAP)

additive or similar source of clay-stabilizing ions. Anticipated mud weight is 8.3-8.8 lbs/gal.

although mud weight up to 10lbs/gal may be used if necessary to prevent wellbore wall

instability due to the planned inclination of the well.

• All cuttings and circulating medium shall be directed into the reserve pit. Total Dissolved Solids

(TDS) are anticipated to be less than 3000 PPM.

• Sufficient mud inventory will be maintained on location in either tanks or the reserve pit during

the drilling of the production hole to handle any adverse conditions that may arise.

• If necessary to control formation fluids or pressure, the system will be weighted with the addition

of bentonite gel, and if pressure conditions warrant, with barite. Enough material shall be

maintained on location to allow for the mudweight to be raised to 10.5 lbs/gal should need arise.

• During drilling operations, pit levels and flow from the well shall be monitored by instrumenta-

tion to include at least: a pit volume totalizer (PVT), a stroke counter, and a mud-flow indicator.

• A mud-gas separator shall be available on location.

C. HAZARDOUS MATERIALS AND POLLUTANTS

• Chromate additives shall NOT be used in the mud system on Indian lands without prior DOGM

approval to ensure adequate protection of freshwater aquifers.

• Chemicals subject to reporting under SARA Title III in an amounts equal to or greater than

10,000 pounds annually shall NOT be used, produced, stored, transported, or disposed of in

association with the drilling, testing, or completion of this well.

• Extremely hazardous substances, as defined in 40 CFR 355, in threshold planning quantities

shall NOT be used, produced, stored, transported, or disposed of in association with the drilling,

testing, or completion of this well.

• Hazardous substances specifically listed by the EPA as a hazardous waste, as defined in 40 CFR

261 (D), or any substances that through their use would lead to the generation of a hazardous

waste, shall NOT be used in association with the drilling, testing, or completion of this well.


CONFIDE

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B. PRODUCTION HOLE• The production hole shall be drilled with a freshwater polymer system from 493' to 6348'.


• Clay inhibition and hole stability shall be achieved with a Diammonium Phosphate (DAP)additive or similar source of clay-stabilizing ions. Anticipated mud weight is 8.3-8.8 lbs/gal.although mud weight up to 101bs/gal may be used if necessary to prevent wellbore wallinstability due to the planned inclination of the well.

• All cuttings and circulating medium shall be directed into the reserve pit. Total Dissolved Solids(TDS) are anticipated to be less than 3000 PPM.

• Sufficient mud inventory will be maintained on location in either tanks or the reserve pit duringthe drilling of the production hole to handle any adverse conditions that may arise.

• If necessary to control formation fluids or pressure, the system will be weighted with the additionof bentonite gel, and if pressure conditions warrant, with barite. Enough material shall bemaintained on location to allow for the mudweight to be raised to 10.5 lbs/gal should need arise.

• During drilling operations, pit levels and flow from the well shall be monitored by instrumenta-tion to include at least: a pit volume totalizer (PVT), a stroke counter, and a mud-flow indicator.


C. HAZARDOUS MATERIALS AND POLLUTANTS• Chromate additives shall NOT be used in the mud system on Indian lands without prior DOGM


• Chemicals subject to reporting under SARA Title III in an amounts equal to or greater than10,000 pounds annually shall NOT be used, produced, stored, transported, or disposed of inassociation with the drilling, testing, or completion of this well.

• Extremely hazardous substances, as defined in 40 CFR 355, in threshold planning quantitiesshall NOT be used, produced, stored, transported, or disposed of in association with the drilling,testing, or completion of this well.

• Hazardous substances specifically listed by the EPA as a hazardous waste, as defined in 40 CFR261 (D), or any substances that through their use would lead to the generation of a hazardouswaste, shall NOT be used in association with the drilling, testing, or completion of this well.































































UTE TRIBAL 31-06




7. EVALUATION PROGRAM:

Logs: Triple Combo TD to base of surface casing (AIT, DSN, CDL)

Base of surface casing to surface (GR only)

Cores: None planned

DST: None planned

Testing: Operator plans no testing until the completion phase of the well.

8. ANTICIPATED ABNORMAL PRESSURE OR TEMPERATURE:

• Operator anticipates Bottom Hole Temperatures below 150°F, the maximum temperature for

DAP drilling fluids.

• No H2S has been encountered or is known to exist from previous drilling in the area at this depth.

• Maximum pressure for hydrocarbon bearing zones at native conditions in this area is

approximately 1587 PSI (0.25 PSI/ft gradient).

• This well is NOT in the vicinity of active injection wells. Nearby active injection can cause

pressures up to a 0.433 PSI/ft gradient .

9. DIRECTIONAL WELL PLAN:

• Well shall be drilled directionally in order to limit surface disturbance.

• A Positive Displacement Motor with a bent sub of 1.25° to 1.75° will be used to control well

path.

• A directional survey shall be taken at least one (1) time per 100’ of drilling.

• Anti-collision equipment will not be used as there are no existing wells in the vicinity of the

proposed well path.

• While cutting the Waterflood Unit Interval from 4127’ to 6100’, the actual well path may be

allowed to vary up to 100’ horizontally from plan in order to prevent excessive slide drilling.

Above and below the Waterflood Unit Interval, variances in excess 100’ horizontally from plan

may be allowed.

• Directional drilling plan is attached.


CONFIDE

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Logs: Triple Combo TD to base of surface casing (AIT, DSN, CDL)Base of surface casing to surface (GR only)

Cores: None planned

DST: None planned


8. ANTICIPATED ABNORMAL PRESSURE OR TEMPERATURE:• Operator anticipates Bottom Hole Temperatures below 150°F, the maximum temperature for



• Maximum pressure for hydrocarbon bearing zones at native conditions in this area isapproximately 1587 PSI (0.25PSI/ft gradient).

• This well is NOT in the vicinity of active injection wells. Nearby active injection can causepressures up to a 0.433 PSI/ft gradient .

9. DIRECTIONAL WELL PLAN:• Well shall be drilled directionally in order to limit surface disturbance.

• A Positive Displacement Motor with a bent sub of 1.25° to 1.75° will be used to control wellpath.

• A directional survey shall be taken at least one (1) time per 100' of drilling.

• Anti-collision equipment will not be used as there are no existing wells in the vicinity of theproposed well path.

• While cutting the Waterflood Unit Interval from 4127' to 6100', the actual well path may beallowed to vary up to 100' horizontally from plan in order to prevent excessive slide drilling.Above and below the Waterflood Unit Interval, variances in excess 100' horizontally from planmay be allowed.










Cores: None planned

DST: None planned





















Cores: None planned

DST: None planned





















Cores: None planned

DST: None planned


















UTE TRIBAL 31-06




TYPICAL 2,000 p.s.i. BLOWOUT PREVENTER

KILL LINE - Minimum 2" To Choke Manifold - Minimum 2"

PIPE RAMS

BLIND RAMS

FILL UP LINE

DRILLING NIPPLE

FLOW LINE

ANNULAR PREVENTER

CASING HEAD

DRILLING SPOOL


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TYPICAL2,000 p.s.i. BLOWOUT PREVENTERRILLING NIPPLE

FILLEUPFLOW LINE

ANNULARPREVENTER

BLIND RAMS

O DRILLING SPOOL

CASING HEAD

To Choke Manifold -KILLLINE - Minimum 2" Minimum 2"








FILLEUPFLOW LINE

ANNULARPREVENTER

BLIND RAMS

O DRILLING SPOOL

CASING HEAD









FILLEUPFLOW LINE

ANNULARPREVENTER

BLIND RAMS

O DRILLING SPOOL

CASING HEAD

To Choke Manifold -KILLLINE - Minimum 2"

Minimum 2"








FILLEUPFLOW LINE

ANNULARPREVENTER

BLIND RAMS

O DRILLING SPOOL

CASING HEAD







UTE TRIBAL 31-06




TYPICAL 2,000 p.s.i. CHOKE MANIFOLD

BOP STACK OUTLET (3" Nominal)

TO PIT (2 IN. MIN.) TO MUD/GAS SEPARATOR AND/OR PIT (2 IN. MIN.)

2" 2"

2"

ADJUSTABLE CHOKE ADJUSTABLE CHOKE


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TYPICAL2,000 p.s.i. CHOKE MANIFOLD

ADJUSTABLE CHOKEADJUSTABLE CHOKE

TO PIT (2 IN. MIN.) TO MUD/GAS SEPARATORBOP STACK OUTLET AND/OR PIT (2 IN. MIN.)(3" Nominal)































RKB

KOP

End Build

Start Drop

End Drop

RTD

6,500

6,000

5,500

5,000

4,500

4,000

3,500

3,000

2,500

2,000

1,500

1,000

500

0

0 500 1,000 1,500

TR

UE

VE

RT

ICA

L D

EP

TH

VERTICAL SECTION ON AZIMUTH 269.7 DEGREES

Ute Tribal 31-06

# Reference Type MD Inc Azi TVD N E DLS

0 RKB Tie Point 0.00 0.00 0.00 0.00 0.00 0.00

1 KOP Vertical 600.00 0.00 0.00 600.00 0.00 0.00 0.00

2 End Build Build 2280.00 21.00 269.70 2242.64 -1.59 -304.44 1.25

3 Start Drop Tangent 3525.00 21.00 269.70 3404.95 -3.93 -750.60 0.00

4 End Drop Drop 5625.00 0.00 0.00 5458.24 -5.92 -1131.15 1.00

Vert S

0.00

0.00

304.44

750.61

1131.17

5 RTD Vertical 6348.00 0.00 0.00 6181.24 -5.92 -1131.15 0.00 1131.17

RKB

KOP

End BuildStart DropEnd DropRTD

-900

-800

-700

-600

-500

-400

-300

-200

-100

0

-1,200 -1,100 -1,000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0

NO

RT

HIN

G

EASTING


CONFIDE

NTIAL


0 nKD 0 RTO ¯ c ap tarï rop - I Elid Duild ŒgKOP

-100

500 KOP-200

1,000-300

-400

I--1,500

-500

2,000-600

\\End Build

-700

2,500-800

I-

3,000 -1,200 -1,100 -1,000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0

EASTING

Start Drop

w 3,500

I--4,000

4,500

5,000

5,500EndDrop Ute Tribal 31-06

6,000 PETROGLYPHRTD

6,500

0 500 1,000 1,500VERTICAL SECTION ON AZIMUTH269.7 DEGREES

# Reference Type MD Inc Azi TVD N E DLS Vert S

0 RKB Tie Point 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1 KOP Vertical 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00

2 End Build Build 2280.00 21.00 269.70 2242.64 -1.59 -304.44 1.25 304.44

3 Start Drop Tangent 3525.00 21.00 269.70 3404.95 -3.93 -750.60 0.00 750.61

4 End Drop Drop 5625.00 0.00 0.00 5458.24 -5.92 -1131.15 1.00 1131.17

5 RTD Vertical 6348.00 0.00 0.00 6181.24 -5.92 -1131.15 0.00 1131.17




-100

500 KOP-200

1,000-300

-400

I--1,500

-500

2,000-600

\\End Build

-700

2,500-800

I-

3,000 -1,200 -1,100 -1,000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0

EASTING

Start Drop

w 3,500

I--4,000

4,500

5,000


6,000 PETROGLYPHRTD

6,500



0 RKB Tie Point 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1 KOP Vertical 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00

2 End Build Build 2280.00 21.00 269.70 2242.64 -1.59 -304.44 1.25 304.44


4 End Drop Drop 5625.00 0.00 0.00 5458.24 -5.92 -1131.15 1.00 1131.17

5 RTD Vertical 6348.00 0.00 0.00 6181.24 -5.92 -1131.15 0.00 1131.17




-100

500 KOP-200

1,000-300

-400

I--1,500

-500

2,000-600

\\End Build

-700

2,500-800

I-

3,000 -1,200 -1,100 -1,000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0

EASTING

Start Drop

w 3,500

I--4,000

4,500

5,000


6,000 PETROGLYPHRTD

6,500



0 RKB Tie Point 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1 KOP Vertical 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00

2 End Build Build 2280.00 21.00 269.70 2242.64 -1.59 -304.44 1.25 304.44


4 End Drop Drop 5625.00 0.00 0.00 5458.24 -5.92 -1131.15 1.00 1131.17

5 RTD Vertical 6348.00 0.00 0.00 6181.24 -5.92 -1131.15 0.00 1131.17




-100

500 KOP-200

1,000-300

-400

I--1,500

-500

2,000-600

\\End Build

-700

2,500-800

I-

3,000 -1,200 -1,100 -1,000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0

EASTING

Start Drop

w 3,500

I--4,000

4,500

5,000


6,000 PETROGLYPHRTD

6,500



0 RKB Tie Point 0.00 0.00 0.00 0.00 0.00 0.00 0.00

1 KOP Vertical 600.00 0.00 0.00 600.00 0.00 0.00 0.00 0.00

2 End Build Build 2280.00 21.00 269.70 2242.64 -1.59 -304.44 1.25 304.44


4 End Drop Drop 5625.00 0.00 0.00 5458.24 -5.92 -1131.15 1.00 1131.17

5 RTD Vertical 6348.00 0.00 0.00 6181.24 -5.92 -1131.15 0.00 1131.17



MD* INC* AZI* TVD* N* E* DLS* V. S.*

DIRECTIONAL WELL PLAN

SES - Stoner Engineering Software

31-06, Plan 1

Units feet, °/100ft

SurfaceX

SurfaceY

Surface Z

Surface Long

Surface Lat

Ground Level

Plan 1

Vertical Section Azimuth 269.7

14:14 Monday, October 28, 2013 Page 1 of 4

Survey Calculation Method Minimum Curvature

Database Access

Location SHL: 1989' FNL & 2150' FEL BHL: 1980' FNL & 3293' FEL

Well Name 31-06

Field

Operator

County Duchesne

State UT

Country USA

Site

Slot Name

Well Number

Lat Long Ref

Z Datum

UWI

API

MapZone

Project

MapE* MapN* SysTVD*ft ft ft ft ft ft ft ftdeg deg °/100ft

0.00 0.00 0.0 0.00 0.00 0.00 0.00

*** RKB (at MD = 0.00)

50.00 0.00 0.0 50.00 0.00 0.00 0.00 0.00

100.00 0.00 0.0 100.00 0.00 0.00 0.00 0.00

150.00 0.00 0.0 150.00 0.00 0.00 0.00 0.00

200.00 0.00 0.0 200.00 0.00 0.00 0.00 0.00

250.00 0.00 0.0 250.00 0.00 0.00 0.00 0.00

300.00 0.00 0.0 300.00 0.00 0.00 0.00 0.00

350.00 0.00 0.0 350.00 0.00 0.00 0.00 0.00

400.00 0.00 0.0 400.00 0.00 0.00 0.00 0.00

450.00 0.00 0.0 450.00 0.00 0.00 0.00 0.00

500.00 0.00 0.0 500.00 0.00 0.00 0.00 0.00

550.00 0.00 0.0 550.00 0.00 0.00 0.00 0.00

600.00 0.00 0.0 600.00 0.00 0.00 0.00 0.00

*** KOP (at MD = 600.00)

650.00 0.63 269.7 650.00 0.00 -0.27 1.25 0.27

700.00 1.25 269.7 699.99 -0.01 -1.09 1.25 1.09

750.00 1.88 269.7 749.97 -0.01 -2.45 1.25 2.45

800.00 2.50 269.7 799.94 -0.02 -4.36 1.25 4.36

850.00 3.13 269.7 849.88 -0.04 -6.82 1.25 6.82

900.00 3.75 269.7 899.79 -0.05 -9.81 1.25 9.81

950.00 4.38 269.7 949.66 -0.07 -13.36 1.25 13.36

1000.00 5.00 269.7 999.49 -0.09 -17.44 1.25 17.44

1050.00 5.63 269.7 1049.28 -0.12 -22.07 1.25 22.07

1100.00 6.25 269.7 1099.01 -0.14 -27.24 1.25 27.24

1150.00 6.88 269.7 1148.68 -0.17 -32.96 1.25 32.96

1200.00 7.50 269.7 1198.29 -0.21 -39.21 1.25 39.21

1250.00 8.13 269.7 1247.82 -0.24 -46.01 1.25 46.01

1300.00 8.75 269.7 1297.28 -0.28 -53.35 1.25 53.35

1350.00 9.38 269.7 1346.66 -0.32 -61.22 1.25 61.22

1400.00 10.00 269.7 1395.94 -0.36 -69.64 1.25 69.64

1450.00 10.63 269.7 1445.14 -0.41 -78.59 1.25 78.59

1500.00 11.25 269.7 1494.23 -0.46 -88.07 1.25 88.07

1550.00 11.88 269.7 1543.21 -0.51 -98.09 1.25 98.10

1600.00 12.50 269.7 1592.09 -0.57 -108.65 1.25 108.65

1650.00 13.13 269.7 1640.84 -0.63 -119.74 1.25 119.74

www.makinhole.comPage 1 of 4 1999-2013 Stoner Engineering LLC


CONFIDE

NTIAL



31-06, Plan 1Operator Units feet, °/100ft 14:14 Monday, October 28, 2013 Page 1 of 4

Field County Duchesne Vertical Section Azimuth 269.7Well Name 31-06 State UT Survey Calculation Method Minimum Curvature

Plan 1 Country USA Database Access

Location SHL: 1989' FNL & 2150' FEL BHL: 1980' FNL & 3293' MapZone Lat Long RefFEL

Site SurfaceX Surface LongSlot Name UWI SurfaceY Surface Lat

Well Number API Z DatumProject Surface Z Ground Level

DIRECTIOrlAL WELL PLMI

MD* INC* AZI* TVD* N* E* DLS* V. S.* MapE* MapN* SysTVD*

*** RKB (at MD = 0.00)0.00 0.00 0.0 0.00 0.00 0.00 0.00

50.00 0.00 0.0 50.00 0.00 0.00 0.00 0.00100.00 0.00 0.0 100.00 0.00 0.00 0.00 0.00150.00 0.00 0.0 150.00 0.00 0.00 0.00 0.00200.00 0.00 0.0 200.00 0.00 0.00 0.00 0.00

250.00 0.00 0.0 250.00 0.00 0.00 0.00 0.00300.00 0.00 0.0 300.00 0.00 0.00 0.00 0.00350.00 0.00 0.0 350.00 0.00 0.00 0.00 0.00400.00 0.00 0.0 400.00 0.00 0.00 0.00 0.00450.00 0.00 0.0 450.00 0.00 0.00 0.00 0.00

500.00 0.00 0.0 500.00 0.00 0.00 0.00 0.00550.00 0.00 0.0 550.00 0.00 0.00 0.00 0.00

*** KOP (at MD = 600.00)600.00 0.00 0.0 600.00 0.00 0.00 0.00 0.00650.00 0.63 269.7 650.00 0.00 -0.27 1.25 0.27700.00 1.25 269.7 699.99 -0.01 -1.09 1.25 1.09

750.00 1.88 269.7 749.97 -0.01 -2.45 1.25 2.45800.00 2.50 269.7 799.94 -0.02 -4.36 1.25 4.36850.00 3.13 269.7 849.88 -0.04 -6.82 1.25 6.82900.00 3.75 269.7 899.79 -0.05 -9.81 1.25 9.81950.00 4.38 269.7 949.66 -0.07 -13.36 1.25 13.36

1000.00 5.00 269.7 999.49 -0.09 -17.44 1.25 17.441050.00 5.63 269.7 1049.28 -0.12 -22.07 1.25 22.071100.00 6.25 269.7 1099.01 -0.14 -27.24 1.25 27.241150.00 6.88 269.7 1148.68 -0.17 -32.96 1.25 32.961200.00 7.50 269.7 1198.29 -0.21 -39.21 1.25 39.21

1250.00 8.13 269.7 1247.82 -0.24 -46.01 1.25 46.011300.00 8.75 269.7 1297.28 -0.28 -53.35 1.25 53.351350.00 9.38 269.7 1346.66 -0.32 -61.22 1.25 61.221400.00 10.00 269.7 1395.94 -0.36 -69.64 1.25 69.641450.00 10.63 269.7 1445.14 -0.41 -78.59 1.25 78.59

1500.00 11.25 269.7 1494.23 -0.46 -88.07 1.25 88.071550.00 11.88 269.7 1543.21 -0.51 -98.09 1.25 98.101600.00 12.50 269.7 1592.09 -0.57 -108.65 1.25 108.651650.00 13.13 269.7 1640.84 -0.63 -119.74 1.25 119.74

Page 1 of 4 www.makinhole.com












*** RKB (at MD = 0.00)0.00 0.00 0.0 0.00 0.00 0.00 0.00

50.00 0.00 0.0 50.00 0.00 0.00 0.00 0.00100.00 0.00 0.0 100.00 0.00 0.00 0.00 0.00150.00 0.00 0.0 150.00 0.00 0.00 0.00 0.00200.00 0.00 0.0 200.00 0.00 0.00 0.00 0.00

250.00 0.00 0.0 250.00 0.00 0.00 0.00 0.00300.00 0.00 0.0 300.00 0.00 0.00 0.00 0.00350.00 0.00 0.0 350.00 0.00 0.00 0.00 0.00400.00 0.00 0.0 400.00 0.00 0.00 0.00 0.00450.00 0.00 0.0 450.00 0.00 0.00 0.00 0.00

500.00 0.00 0.0 500.00 0.00 0.00 0.00 0.00550.00 0.00 0.0 550.00 0.00 0.00 0.00 0.00

*** KOP (at MD = 600.00)600.00 0.00 0.0 600.00 0.00 0.00 0.00 0.00650.00 0.63 269.7 650.00 0.00 -0.27 1.25 0.27700.00 1.25 269.7 699.99 -0.01 -1.09 1.25 1.09

750.00 1.88 269.7 749.97 -0.01 -2.45 1.25 2.45800.00 2.50 269.7 799.94 -0.02 -4.36 1.25 4.36850.00 3.13 269.7 849.88 -0.04 -6.82 1.25 6.82900.00 3.75 269.7 899.79 -0.05 -9.81 1.25 9.81950.00 4.38 269.7 949.66 -0.07 -13.36 1.25 13.36

1000.00 5.00 269.7 999.49 -0.09 -17.44 1.25 17.441050.00 5.63 269.7 1049.28 -0.12 -22.07 1.25 22.071100.00 6.25 269.7 1099.01 -0.14 -27.24 1.25 27.241150.00 6.88 269.7 1148.68 -0.17 -32.96 1.25 32.961200.00 7.50 269.7 1198.29 -0.21 -39.21 1.25 39.21

1250.00 8.13 269.7 1247.82 -0.24 -46.01 1.25 46.011300.00 8.75 269.7 1297.28 -0.28 -53.35 1.25 53.351350.00 9.38 269.7 1346.66 -0.32 -61.22 1.25 61.221400.00 10.00 269.7 1395.94 -0.36 -69.64 1.25 69.641450.00 10.63 269.7 1445.14 -0.41 -78.59 1.25 78.59

1500.00 11.25 269.7 1494.23 -0.46 -88.07 1.25 88.071550.00 11.88 269.7 1543.21 -0.51 -98.09 1.25 98.101600.00 12.50 269.7 1592.09 -0.57 -108.65 1.25 108.651650.00 13.13 269.7 1640.84 -0.63 -119.74 1.25 119.74













*** RKB (at MD = 0.00)0.00 0.00 0.0 0.00 0.00 0.00 0.00

50.00 0.00 0.0 50.00 0.00 0.00 0.00 0.00100.00 0.00 0.0 100.00 0.00 0.00 0.00 0.00150.00 0.00 0.0 150.00 0.00 0.00 0.00 0.00200.00 0.00 0.0 200.00 0.00 0.00 0.00 0.00

250.00 0.00 0.0 250.00 0.00 0.00 0.00 0.00300.00 0.00 0.0 300.00 0.00 0.00 0.00 0.00350.00 0.00 0.0 350.00 0.00 0.00 0.00 0.00400.00 0.00 0.0 400.00 0.00 0.00 0.00 0.00450.00 0.00 0.0 450.00 0.00 0.00 0.00 0.00

500.00 0.00 0.0 500.00 0.00 0.00 0.00 0.00550.00 0.00 0.0 550.00 0.00 0.00 0.00 0.00

*** KOP (at MD = 600.00)600.00 0.00 0.0 600.00 0.00 0.00 0.00 0.00650.00 0.63 269.7 650.00 0.00 -0.27 1.25 0.27700.00 1.25 269.7 699.99 -0.01 -1.09 1.25 1.09

750.00 1.88 269.7 749.97 -0.01 -2.45 1.25 2.45800.00 2.50 269.7 799.94 -0.02 -4.36 1.25 4.36850.00 3.13 269.7 849.88 -0.04 -6.82 1.25 6.82900.00 3.75 269.7 899.79 -0.05 -9.81 1.25 9.81950.00 4.38 269.7 949.66 -0.07 -13.36 1.25 13.36

1000.00 5.00 269.7 999.49 -0.09 -17.44 1.25 17.441050.00 5.63 269.7 1049.28 -0.12 -22.07 1.25 22.071100.00 6.25 269.7 1099.01 -0.14 -27.24 1.25 27.241150.00 6.88 269.7 1148.68 -0.17 -32.96 1.25 32.961200.00 7.50 269.7 1198.29 -0.21 -39.21 1.25 39.21

1250.00 8.13 269.7 1247.82 -0.24 -46.01 1.25 46.011300.00 8.75 269.7 1297.28 -0.28 -53.35 1.25 53.351350.00 9.38 269.7 1346.66 -0.32 -61.22 1.25 61.221400.00 10.00 269.7 1395.94 -0.36 -69.64 1.25 69.641450.00 10.63 269.7 1445.14 -0.41 -78.59 1.25 78.59

1500.00 11.25 269.7 1494.23 -0.46 -88.07 1.25 88.071550.00 11.88 269.7 1543.21 -0.51 -98.09 1.25 98.101600.00 12.50 269.7 1592.09 -0.57 -108.65 1.25 108.651650.00 13.13 269.7 1640.84 -0.63 -119.74 1.25 119.74













*** RKB (at MD = 0.00)0.00 0.00 0.0 0.00 0.00 0.00 0.00

50.00 0.00 0.0 50.00 0.00 0.00 0.00 0.00100.00 0.00 0.0 100.00 0.00 0.00 0.00 0.00150.00 0.00 0.0 150.00 0.00 0.00 0.00 0.00200.00 0.00 0.0 200.00 0.00 0.00 0.00 0.00

250.00 0.00 0.0 250.00 0.00 0.00 0.00 0.00300.00 0.00 0.0 300.00 0.00 0.00 0.00 0.00350.00 0.00 0.0 350.00 0.00 0.00 0.00 0.00400.00 0.00 0.0 400.00 0.00 0.00 0.00 0.00450.00 0.00 0.0 450.00 0.00 0.00 0.00 0.00

500.00 0.00 0.0 500.00 0.00 0.00 0.00 0.00550.00 0.00 0.0 550.00 0.00 0.00 0.00 0.00

*** KOP (at MD = 600.00)600.00 0.00 0.0 600.00 0.00 0.00 0.00 0.00650.00 0.63 269.7 650.00 0.00 -0.27 1.25 0.27700.00 1.25 269.7 699.99 -0.01 -1.09 1.25 1.09

750.00 1.88 269.7 749.97 -0.01 -2.45 1.25 2.45800.00 2.50 269.7 799.94 -0.02 -4.36 1.25 4.36850.00 3.13 269.7 849.88 -0.04 -6.82 1.25 6.82900.00 3.75 269.7 899.79 -0.05 -9.81 1.25 9.81950.00 4.38 269.7 949.66 -0.07 -13.36 1.25 13.36

1000.00 5.00 269.7 999.49 -0.09 -17.44 1.25 17.441050.00 5.63 269.7 1049.28 -0.12 -22.07 1.25 22.071100.00 6.25 269.7 1099.01 -0.14 -27.24 1.25 27.241150.00 6.88 269.7 1148.68 -0.17 -32.96 1.25 32.961200.00 7.50 269.7 1198.29 -0.21 -39.21 1.25 39.21

1250.00 8.13 269.7 1247.82 -0.24 -46.01 1.25 46.011300.00 8.75 269.7 1297.28 -0.28 -53.35 1.25 53.351350.00 9.38 269.7 1346.66 -0.32 -61.22 1.25 61.221400.00 10.00 269.7 1395.94 -0.36 -69.64 1.25 69.641450.00 10.63 269.7 1445.14 -0.41 -78.59 1.25 78.59

1500.00 11.25 269.7 1494.23 -0.46 -88.07 1.25 88.071550.00 11.88 269.7 1543.21 -0.51 -98.09 1.25 98.101600.00 12.50 269.7 1592.09 -0.57 -108.65 1.25 108.651650.00 13.13 269.7 1640.84 -0.63 -119.74 1.25 119.74







31-06, Plan 1


SurfaceX

SurfaceY

Surface Z

Surface Long

Surface Lat

Ground Level

Plan 1




Database Access


Well Name 31-06

Field

Operator

County Duchesne

State UT

Country USA

Site

Slot Name

Well Number

Lat Long Ref

Z Datum

UWI

API

MapZone

Project


1700.00 13.75 269.7 1689.47 -0.69 -131.36 1.25 131.36

1750.00 14.38 269.7 1737.97 -0.75 -143.51 1.25 143.51

1800.00 15.00 269.7 1786.34 -0.82 -156.18 1.25 156.18

1850.00 15.63 269.7 1834.56 -0.89 -169.39 1.25 169.39

1900.00 16.25 269.7 1882.64 -0.96 -183.12 1.25 183.12

1950.00 16.88 269.7 1930.57 -1.03 -197.37 1.25 197.37

2000.00 17.50 269.7 1978.33 -1.11 -212.14 1.25 212.15

2050.00 18.13 269.7 2025.94 -1.19 -227.44 1.25 227.44

2100.00 18.75 269.7 2073.37 -1.27 -243.25 1.25 243.25

2150.00 19.38 269.7 2120.63 -1.36 -259.58 1.25 259.58

2200.00 20.00 269.7 2167.70 -1.45 -276.42 1.25 276.43

2250.00 20.63 269.7 2214.60 -1.54 -293.78 1.25 293.79

2280.00 21.00 269.7 2242.64 -1.59 -304.44 1.25 304.44

*** END BUILD (at MD = 2280.00)

2300.00 21.00 269.7 2261.31 -1.63 -311.61 0.00 311.61

2350.00 21.00 269.7 2307.99 -1.73 -329.53 0.00 329.53

2400.00 21.00 269.7 2354.67 -1.82 -347.44 0.00 347.45

2450.00 21.00 269.7 2401.35 -1.91 -365.36 0.00 365.37

2500.00 21.00 269.7 2448.03 -2.01 -383.28 0.00 383.29

2550.00 21.00 269.7 2494.70 -2.10 -401.20 0.00 401.20

2600.00 21.00 269.7 2541.38 -2.19 -419.12 0.00 419.12

2650.00 21.00 269.7 2588.06 -2.29 -437.04 0.00 437.04

2700.00 21.00 269.7 2634.74 -2.38 -454.95 0.00 454.96

2750.00 21.00 269.7 2681.42 -2.48 -472.87 0.00 472.88

2800.00 21.00 269.7 2728.10 -2.57 -490.79 0.00 490.80

2850.00 21.00 269.7 2774.78 -2.66 -508.71 0.00 508.71

2900.00 21.00 269.7 2821.46 -2.76 -526.63 0.00 526.63

2950.00 21.00 269.7 2868.14 -2.85 -544.54 0.00 544.55

3000.00 21.00 269.7 2914.82 -2.95 -562.46 0.00 562.47

3050.00 21.00 269.7 2961.49 -3.04 -580.38 0.00 580.39

3100.00 21.00 269.7 3008.17 -3.13 -598.30 0.00 598.31

3150.00 21.00 269.7 3054.85 -3.23 -616.22 0.00 616.23

3200.00 21.00 269.7 3101.53 -3.32 -634.13 0.00 634.14

3250.00 21.00 269.7 3148.21 -3.41 -652.05 0.00 652.06

3300.00 21.00 269.7 3194.89 -3.51 -669.97 0.00 669.98



CONFIDE

NTIAL











1700.00 13.75 269.7 1689.47 -0.69 -131.36 1.25 131.36

1750.00 14.38 269.7 1737.97 -0.75 -143.51 1.25 143.511800.00 15.00 269.7 1786.34 -0.82 -156.18 1.25 156.181850.00 15.63 269.7 1834.56 -0.89 -169.39 1.25 169.391900.00 16.25 269.7 1882.64 -0.96 -183.12 1.25 183.121950.00 16.88 269.7 1930.57 -1.03 -197.37 1.25 197.37

2000.00 17.50 269.7 1978.33 -1.11 -212.14 1.25 212.152050.00 18.13 269.7 2025.94 -1.19 -227.44 1.25 227.442100.00 18.75 269.7 2073.37 -1.27 -243.25 1.25 243.252150.00 19.38 269.7 2120.63 -1.36 -259.58 1.25 259.582200.00 20.00 269.7 2167.70 -1.45 -276.42 1.25 276.43

2250.00 20.63 269.7 2214.60 -1.54 -293.78 1.25 293.79*** END BUILD (at MD = 2280.00)

2280.00 21.00 269.7 2242.64 -1.59 -304.44 1.25 304.442300.00 21.00 269.7 2261.31 -1.63 -311.61 0.00 311.612350.00 21.00 269.7 2307.99 -1.73 -329.53 0.00 329.532400.00 21.00 269.7 2354.67 -1.82 -347.44 0.00 347.45

2450.00 21.00 269.7 2401.35 -1.91 -365.36 0.00 365.372500.00 21.00 269.7 2448.03 -2.01 -383.28 0.00 383.292550.00 21.00 269.7 2494.70 -2.10 -401.20 0.00 401.202600.00 21.00 269.7 2541.38 -2.19 -419.12 0.00 419.122650.00 21.00 269.7 2588.06 -2.29 -437.04 0.00 437.04

2700.00 21.00 269.7 2634.74 -2.38 -454.95 0.00 454.962750.00 21.00 269.7 2681.42 -2.48 -472.87 0.00 472.882800.00 21.00 269.7 2728.10 -2.57 -490.79 0.00 490.802850.00 21.00 269.7 2774.78 -2.66 -508.71 0.00 508.712900.00 21.00 269.7 2821.46 -2.76 -526.63 0.00 526.63

2950.00 21.00 269.7 2868.14 -2.85 -544.54 0.00 544.553000.00 21.00 269.7 2914.82 -2.95 -562.46 0.00 562.473050.00 21.00 269.7 2961.49 -3.04 -580.38 0.00 580.393100.00 21.00 269.7 3008.17 -3.13 -598.30 0.00 598.313150.00 21.00 269.7 3054.85 -3.23 -616.22 0.00 616.23

3200.00 21.00 269.7 3101.53 -3.32 -634.13 0.00 634.143250.00 21.00 269.7 3148.21 -3.41 -652.05 0.00 652.063300.00 21.00 269.7 3194.89 -3.51 -669.97 0.00 669.98













1700.00 13.75 269.7 1689.47 -0.69 -131.36 1.25 131.36

1750.00 14.38 269.7 1737.97 -0.75 -143.51 1.25 143.511800.00 15.00 269.7 1786.34 -0.82 -156.18 1.25 156.181850.00 15.63 269.7 1834.56 -0.89 -169.39 1.25 169.391900.00 16.25 269.7 1882.64 -0.96 -183.12 1.25 183.121950.00 16.88 269.7 1930.57 -1.03 -197.37 1.25 197.37

2000.00 17.50 269.7 1978.33 -1.11 -212.14 1.25 212.152050.00 18.13 269.7 2025.94 -1.19 -227.44 1.25 227.442100.00 18.75 269.7 2073.37 -1.27 -243.25 1.25 243.252150.00 19.38 269.7 2120.63 -1.36 -259.58 1.25 259.582200.00 20.00 269.7 2167.70 -1.45 -276.42 1.25 276.43

2250.00 20.63 269.7 2214.60 -1.54 -293.78 1.25 293.79*** END BUILD (at MD = 2280.00)

2280.00 21.00 269.7 2242.64 -1.59 -304.44 1.25 304.442300.00 21.00 269.7 2261.31 -1.63 -311.61 0.00 311.612350.00 21.00 269.7 2307.99 -1.73 -329.53 0.00 329.532400.00 21.00 269.7 2354.67 -1.82 -347.44 0.00 347.45

2450.00 21.00 269.7 2401.35 -1.91 -365.36 0.00 365.372500.00 21.00 269.7 2448.03 -2.01 -383.28 0.00 383.292550.00 21.00 269.7 2494.70 -2.10 -401.20 0.00 401.202600.00 21.00 269.7 2541.38 -2.19 -419.12 0.00 419.122650.00 21.00 269.7 2588.06 -2.29 -437.04 0.00 437.04

2700.00 21.00 269.7 2634.74 -2.38 -454.95 0.00 454.962750.00 21.00 269.7 2681.42 -2.48 -472.87 0.00 472.882800.00 21.00 269.7 2728.10 -2.57 -490.79 0.00 490.802850.00 21.00 269.7 2774.78 -2.66 -508.71 0.00 508.712900.00 21.00 269.7 2821.46 -2.76 -526.63 0.00 526.63

2950.00 21.00 269.7 2868.14 -2.85 -544.54 0.00 544.553000.00 21.00 269.7 2914.82 -2.95 -562.46 0.00 562.473050.00 21.00 269.7 2961.49 -3.04 -580.38 0.00 580.393100.00 21.00 269.7 3008.17 -3.13 -598.30 0.00 598.313150.00 21.00 269.7 3054.85 -3.23 -616.22 0.00 616.23

3200.00 21.00 269.7 3101.53 -3.32 -634.13 0.00 634.143250.00 21.00 269.7 3148.21 -3.41 -652.05 0.00 652.063300.00 21.00 269.7 3194.89 -3.51 -669.97 0.00 669.98













1700.00 13.75 269.7 1689.47 -0.69 -131.36 1.25 131.36

1750.00 14.38 269.7 1737.97 -0.75 -143.51 1.25 143.511800.00 15.00 269.7 1786.34 -0.82 -156.18 1.25 156.181850.00 15.63 269.7 1834.56 -0.89 -169.39 1.25 169.391900.00 16.25 269.7 1882.64 -0.96 -183.12 1.25 183.121950.00 16.88 269.7 1930.57 -1.03 -197.37 1.25 197.37

2000.00 17.50 269.7 1978.33 -1.11 -212.14 1.25 212.152050.00 18.13 269.7 2025.94 -1.19 -227.44 1.25 227.442100.00 18.75 269.7 2073.37 -1.27 -243.25 1.25 243.252150.00 19.38 269.7 2120.63 -1.36 -259.58 1.25 259.582200.00 20.00 269.7 2167.70 -1.45 -276.42 1.25 276.43

2250.00 20.63 269.7 2214.60 -1.54 -293.78 1.25 293.79*** END BUILD (at MD = 2280.00)

2280.00 21.00 269.7 2242.64 -1.59 -304.44 1.25 304.442300.00 21.00 269.7 2261.31 -1.63 -311.61 0.00 311.612350.00 21.00 269.7 2307.99 -1.73 -329.53 0.00 329.532400.00 21.00 269.7 2354.67 -1.82 -347.44 0.00 347.45

2450.00 21.00 269.7 2401.35 -1.91 -365.36 0.00 365.372500.00 21.00 269.7 2448.03 -2.01 -383.28 0.00 383.292550.00 21.00 269.7 2494.70 -2.10 -401.20 0.00 401.202600.00 21.00 269.7 2541.38 -2.19 -419.12 0.00 419.122650.00 21.00 269.7 2588.06 -2.29 -437.04 0.00 437.04

2700.00 21.00 269.7 2634.74 -2.38 -454.95 0.00 454.962750.00 21.00 269.7 2681.42 -2.48 -472.87 0.00 472.882800.00 21.00 269.7 2728.10 -2.57 -490.79 0.00 490.802850.00 21.00 269.7 2774.78 -2.66 -508.71 0.00 508.712900.00 21.00 269.7 2821.46 -2.76 -526.63 0.00 526.63

2950.00 21.00 269.7 2868.14 -2.85 -544.54 0.00 544.553000.00 21.00 269.7 2914.82 -2.95 -562.46 0.00 562.473050.00 21.00 269.7 2961.49 -3.04 -580.38 0.00 580.393100.00 21.00 269.7 3008.17 -3.13 -598.30 0.00 598.313150.00 21.00 269.7 3054.85 -3.23 -616.22 0.00 616.23

3200.00 21.00 269.7 3101.53 -3.32 -634.13 0.00 634.143250.00 21.00 269.7 3148.21 -3.41 -652.05 0.00 652.063300.00 21.00 269.7 3194.89 -3.51 -669.97 0.00 669.98













1700.00 13.75 269.7 1689.47 -0.69 -131.36 1.25 131.36

1750.00 14.38 269.7 1737.97 -0.75 -143.51 1.25 143.511800.00 15.00 269.7 1786.34 -0.82 -156.18 1.25 156.181850.00 15.63 269.7 1834.56 -0.89 -169.39 1.25 169.391900.00 16.25 269.7 1882.64 -0.96 -183.12 1.25 183.121950.00 16.88 269.7 1930.57 -1.03 -197.37 1.25 197.37

2000.00 17.50 269.7 1978.33 -1.11 -212.14 1.25 212.152050.00 18.13 269.7 2025.94 -1.19 -227.44 1.25 227.442100.00 18.75 269.7 2073.37 -1.27 -243.25 1.25 243.252150.00 19.38 269.7 2120.63 -1.36 -259.58 1.25 259.582200.00 20.00 269.7 2167.70 -1.45 -276.42 1.25 276.43

2250.00 20.63 269.7 2214.60 -1.54 -293.78 1.25 293.79*** END BUILD (at MD = 2280.00)

2280.00 21.00 269.7 2242.64 -1.59 -304.44 1.25 304.442300.00 21.00 269.7 2261.31 -1.63 -311.61 0.00 311.612350.00 21.00 269.7 2307.99 -1.73 -329.53 0.00 329.532400.00 21.00 269.7 2354.67 -1.82 -347.44 0.00 347.45

2450.00 21.00 269.7 2401.35 -1.91 -365.36 0.00 365.372500.00 21.00 269.7 2448.03 -2.01 -383.28 0.00 383.292550.00 21.00 269.7 2494.70 -2.10 -401.20 0.00 401.202600.00 21.00 269.7 2541.38 -2.19 -419.12 0.00 419.122650.00 21.00 269.7 2588.06 -2.29 -437.04 0.00 437.04

2700.00 21.00 269.7 2634.74 -2.38 -454.95 0.00 454.962750.00 21.00 269.7 2681.42 -2.48 -472.87 0.00 472.882800.00 21.00 269.7 2728.10 -2.57 -490.79 0.00 490.802850.00 21.00 269.7 2774.78 -2.66 -508.71 0.00 508.712900.00 21.00 269.7 2821.46 -2.76 -526.63 0.00 526.63

2950.00 21.00 269.7 2868.14 -2.85 -544.54 0.00 544.553000.00 21.00 269.7 2914.82 -2.95 -562.46 0.00 562.473050.00 21.00 269.7 2961.49 -3.04 -580.38 0.00 580.393100.00 21.00 269.7 3008.17 -3.13 -598.30 0.00 598.313150.00 21.00 269.7 3054.85 -3.23 -616.22 0.00 616.23

3200.00 21.00 269.7 3101.53 -3.32 -634.13 0.00 634.143250.00 21.00 269.7 3148.21 -3.41 -652.05 0.00 652.063300.00 21.00 269.7 3194.89 -3.51 -669.97 0.00 669.98







31-06, Plan 1


SurfaceX

SurfaceY

Surface Z

Surface Long

Surface Lat

Ground Level

Plan 1




Database Access


Well Name 31-06

Field

Operator

County Duchesne

State UT

Country USA

Site

Slot Name

Well Number

Lat Long Ref

Z Datum

UWI

API

MapZone

Project


3350.00 21.00 269.7 3241.57 -3.60 -687.89 0.00 687.90

3400.00 21.00 269.7 3288.25 -3.70 -705.81 0.00 705.82

3450.00 21.00 269.7 3334.93 -3.79 -723.73 0.00 723.74

3500.00 21.00 269.7 3381.61 -3.88 -741.64 0.00 741.65

3525.00 21.00 269.7 3404.95 -3.93 -750.60 0.00 750.61

*** START DROP (at MD = 3525.00)

3550.00 20.75 269.7 3428.30 -3.98 -759.51 1.00 759.52

3600.00 20.25 269.7 3475.14 -4.07 -777.02 1.00 777.03

3650.00 19.75 269.7 3522.12 -4.16 -794.12 1.00 794.13

3700.00 19.25 269.7 3569.25 -4.25 -810.81 1.00 810.82

3750.00 18.75 269.7 3616.53 -4.33 -827.09 1.00 827.10

3800.00 18.25 269.7 3663.95 -4.41 -842.95 1.00 842.97

3850.00 17.75 269.7 3711.50 -4.49 -858.41 1.00 858.42

3900.00 17.25 269.7 3759.18 -4.57 -873.44 1.00 873.45

3950.00 16.75 269.7 3807.00 -4.65 -888.06 1.00 888.07

4000.00 16.25 269.7 3854.94 -4.72 -902.26 1.00 902.27

4050.00 15.75 269.7 3903.00 -4.80 -916.04 1.00 916.05

4100.00 15.25 269.7 3951.18 -4.87 -929.40 1.00 929.42

4150.00 14.75 269.7 3999.48 -4.93 -942.34 1.00 942.36

4200.00 14.25 269.7 4047.89 -5.00 -954.86 1.00 954.88

4250.00 13.75 269.7 4096.40 -5.06 -966.96 1.00 966.97

4300.00 13.25 269.7 4145.02 -5.12 -978.63 1.00 978.64

4350.00 12.75 269.7 4193.74 -5.18 -989.88 1.00 989.89

4400.00 12.25 269.7 4242.55 -5.24 -1000.70 1.00 1000.71

4450.00 11.75 269.7 4291.46 -5.29 -1011.09 1.00 1011.11

4500.00 11.25 269.7 4340.46 -5.35 -1021.06 1.00 1021.08

4550.00 10.75 269.7 4389.54 -5.40 -1030.60 1.00 1030.62

4600.00 10.25 269.7 4438.70 -5.44 -1039.71 1.00 1039.73

4650.00 9.75 269.7 4487.94 -5.49 -1048.40 1.00 1048.41

4700.00 9.25 269.7 4537.26 -5.53 -1056.65 1.00 1056.66

4750.00 8.75 269.7 4586.64 -5.57 -1064.47 1.00 1064.49

4800.00 8.25 269.7 4636.09 -5.61 -1071.86 1.00 1071.88

4850.00 7.75 269.7 4685.60 -5.65 -1078.82 1.00 1078.83

4900.00 7.25 269.7 4735.18 -5.68 -1085.35 1.00 1085.36

4950.00 6.75 269.7 4784.80 -5.71 -1091.44 1.00 1091.45



CONFIDE

NTIAL











3350.00 21.00 269.7 3241.57 -3.60 -687.89 0.00 687.903400.00 21.00 269.7 3288.25 -3.70 -705.81 0.00 705.82

3450.00 21.00 269.7 3334.93 -3.79 -723.73 0.00 723.743500.00 21.00 269.7 3381.61 -3.88 -741.64 0.00 741.65

*** START DROP (at MD = 3525.00)3525.00 21.00 269.7 3404.95 -3.93 -750.60 0.00 750.613550.00 20.75 269.7 3428.30 -3.98 -759.51 1.00 759.523600.00 20.25 269.7 3475.14 -4.07 -777.02 1.00 777.03

3650.00 19.75 269.7 3522.12 -4.16 -794.12 1.00 794.133700.00 19.25 269.7 3569.25 -4.25 -810.81 1.00 810.823750.00 18.75 269.7 3616.53 -4.33 -827.09 1.00 827.103800.00 18.25 269.7 3663.95 -4.41 -842.95 1.00 842.973850.00 17.75 269.7 3711.50 -4.49 -858.41 1.00 858.42

3900.00 17.25 269.7 3759.18 -4.57 -873.44 1.00 873.453950.00 16.75 269.7 3807.00 -4.65 -888.06 1.00 888.074000.00 16.25 269.7 3854.94 -4.72 -902.26 1.00 902.274050.00 15.75 269.7 3903.00 -4.80 -916.04 1.00 916.054100.00 15.25 269.7 3951.18 -4.87 -929.40 1.00 929.42

4150.00 14.75 269.7 3999.48 -4.93 -942.34 1.00 942.364200.00 14.25 269.7 4047.89 -5.00 -954.86 1.00 954.884250.00 13.75 269.7 4096.40 -5.06 -966.96 1.00 966.974300.00 13.25 269.7 4145.02 -5.12 -978.63 1.00 978.644350.00 12.75 269.7 4193.74 -5.18 -989.88 1.00 989.89

4400.00 12.25 269.7 4242.55 -5.24 -1000.70 1.00 1000.714450.00 11.75 269.7 4291.46 -5.29 -1011.09 1.00 1011.114500.00 11.25 269.7 4340.46 -5.35 -1021.06 1.00 1021.084550.00 10.75 269.7 4389.54 -5.40 -1030.60 1.00 1030.624600.00 10.25 269.7 4438.70 -5.44 -1039.71 1.00 1039.73

4650.00 9.75 269.7 4487.94 -5.49 -1048.40 1.00 1048.414700.00 9.25 269.7 4537.26 -5.53 -1056.65 1.00 1056.664750.00 8.75 269.7 4586.64 -5.57 -1064.47 1.00 1064.494800.00 8.25 269.7 4636.09 -5.61 -1071.86 1.00 1071.884850.00 7.75 269.7 4685.60 -5.65 -1078.82 1.00 1078.83

4900.00 7.25 269.7 4735.18 -5.68 -1085.35 1.00 1085.364950.00 6.75 269.7 4784.80 -5.71 -1091.44 1.00 1091.45













3350.00 21.00 269.7 3241.57 -3.60 -687.89 0.00 687.903400.00 21.00 269.7 3288.25 -3.70 -705.81 0.00 705.82

3450.00 21.00 269.7 3334.93 -3.79 -723.73 0.00 723.743500.00 21.00 269.7 3381.61 -3.88 -741.64 0.00 741.65

*** START DROP (at MD = 3525.00)3525.00 21.00 269.7 3404.95 -3.93 -750.60 0.00 750.613550.00 20.75 269.7 3428.30 -3.98 -759.51 1.00 759.523600.00 20.25 269.7 3475.14 -4.07 -777.02 1.00 777.03

3650.00 19.75 269.7 3522.12 -4.16 -794.12 1.00 794.133700.00 19.25 269.7 3569.25 -4.25 -810.81 1.00 810.823750.00 18.75 269.7 3616.53 -4.33 -827.09 1.00 827.103800.00 18.25 269.7 3663.95 -4.41 -842.95 1.00 842.973850.00 17.75 269.7 3711.50 -4.49 -858.41 1.00 858.42

3900.00 17.25 269.7 3759.18 -4.57 -873.44 1.00 873.453950.00 16.75 269.7 3807.00 -4.65 -888.06 1.00 888.074000.00 16.25 269.7 3854.94 -4.72 -902.26 1.00 902.274050.00 15.75 269.7 3903.00 -4.80 -916.04 1.00 916.054100.00 15.25 269.7 3951.18 -4.87 -929.40 1.00 929.42

4150.00 14.75 269.7 3999.48 -4.93 -942.34 1.00 942.364200.00 14.25 269.7 4047.89 -5.00 -954.86 1.00 954.884250.00 13.75 269.7 4096.40 -5.06 -966.96 1.00 966.974300.00 13.25 269.7 4145.02 -5.12 -978.63 1.00 978.644350.00 12.75 269.7 4193.74 -5.18 -989.88 1.00 989.89

4400.00 12.25 269.7 4242.55 -5.24 -1000.70 1.00 1000.714450.00 11.75 269.7 4291.46 -5.29 -1011.09 1.00 1011.114500.00 11.25 269.7 4340.46 -5.35 -1021.06 1.00 1021.084550.00 10.75 269.7 4389.54 -5.40 -1030.60 1.00 1030.624600.00 10.25 269.7 4438.70 -5.44 -1039.71 1.00 1039.73

4650.00 9.75 269.7 4487.94 -5.49 -1048.40 1.00 1048.414700.00 9.25 269.7 4537.26 -5.53 -1056.65 1.00 1056.664750.00 8.75 269.7 4586.64 -5.57 -1064.47 1.00 1064.494800.00 8.25 269.7 4636.09 -5.61 -1071.86 1.00 1071.884850.00 7.75 269.7 4685.60 -5.65 -1078.82 1.00 1078.83

4900.00 7.25 269.7 4735.18 -5.68 -1085.35 1.00 1085.364950.00 6.75 269.7 4784.80 -5.71 -1091.44 1.00 1091.45













3350.00 21.00 269.7 3241.57 -3.60 -687.89 0.00 687.903400.00 21.00 269.7 3288.25 -3.70 -705.81 0.00 705.82

3450.00 21.00 269.7 3334.93 -3.79 -723.73 0.00 723.743500.00 21.00 269.7 3381.61 -3.88 -741.64 0.00 741.65

*** START DROP (at MD = 3525.00)3525.00 21.00 269.7 3404.95 -3.93 -750.60 0.00 750.613550.00 20.75 269.7 3428.30 -3.98 -759.51 1.00 759.523600.00 20.25 269.7 3475.14 -4.07 -777.02 1.00 777.03

3650.00 19.75 269.7 3522.12 -4.16 -794.12 1.00 794.133700.00 19.25 269.7 3569.25 -4.25 -810.81 1.00 810.823750.00 18.75 269.7 3616.53 -4.33 -827.09 1.00 827.103800.00 18.25 269.7 3663.95 -4.41 -842.95 1.00 842.973850.00 17.75 269.7 3711.50 -4.49 -858.41 1.00 858.42

3900.00 17.25 269.7 3759.18 -4.57 -873.44 1.00 873.453950.00 16.75 269.7 3807.00 -4.65 -888.06 1.00 888.074000.00 16.25 269.7 3854.94 -4.72 -902.26 1.00 902.274050.00 15.75 269.7 3903.00 -4.80 -916.04 1.00 916.054100.00 15.25 269.7 3951.18 -4.87 -929.40 1.00 929.42

4150.00 14.75 269.7 3999.48 -4.93 -942.34 1.00 942.364200.00 14.25 269.7 4047.89 -5.00 -954.86 1.00 954.884250.00 13.75 269.7 4096.40 -5.06 -966.96 1.00 966.974300.00 13.25 269.7 4145.02 -5.12 -978.63 1.00 978.644350.00 12.75 269.7 4193.74 -5.18 -989.88 1.00 989.89

4400.00 12.25 269.7 4242.55 -5.24 -1000.70 1.00 1000.714450.00 11.75 269.7 4291.46 -5.29 -1011.09 1.00 1011.114500.00 11.25 269.7 4340.46 -5.35 -1021.06 1.00 1021.084550.00 10.75 269.7 4389.54 -5.40 -1030.60 1.00 1030.624600.00 10.25 269.7 4438.70 -5.44 -1039.71 1.00 1039.73

4650.00 9.75 269.7 4487.94 -5.49 -1048.40 1.00 1048.414700.00 9.25 269.7 4537.26 -5.53 -1056.65 1.00 1056.664750.00 8.75 269.7 4586.64 -5.57 -1064.47 1.00 1064.494800.00 8.25 269.7 4636.09 -5.61 -1071.86 1.00 1071.884850.00 7.75 269.7 4685.60 -5.65 -1078.82 1.00 1078.83

4900.00 7.25 269.7 4735.18 -5.68 -1085.35 1.00 1085.364950.00 6.75 269.7 4784.80 -5.71 -1091.44 1.00 1091.45













3350.00 21.00 269.7 3241.57 -3.60 -687.89 0.00 687.903400.00 21.00 269.7 3288.25 -3.70 -705.81 0.00 705.82

3450.00 21.00 269.7 3334.93 -3.79 -723.73 0.00 723.743500.00 21.00 269.7 3381.61 -3.88 -741.64 0.00 741.65

*** START DROP (at MD = 3525.00)3525.00 21.00 269.7 3404.95 -3.93 -750.60 0.00 750.613550.00 20.75 269.7 3428.30 -3.98 -759.51 1.00 759.523600.00 20.25 269.7 3475.14 -4.07 -777.02 1.00 777.03

3650.00 19.75 269.7 3522.12 -4.16 -794.12 1.00 794.133700.00 19.25 269.7 3569.25 -4.25 -810.81 1.00 810.823750.00 18.75 269.7 3616.53 -4.33 -827.09 1.00 827.103800.00 18.25 269.7 3663.95 -4.41 -842.95 1.00 842.973850.00 17.75 269.7 3711.50 -4.49 -858.41 1.00 858.42

3900.00 17.25 269.7 3759.18 -4.57 -873.44 1.00 873.453950.00 16.75 269.7 3807.00 -4.65 -888.06 1.00 888.074000.00 16.25 269.7 3854.94 -4.72 -902.26 1.00 902.274050.00 15.75 269.7 3903.00 -4.80 -916.04 1.00 916.054100.00 15.25 269.7 3951.18 -4.87 -929.40 1.00 929.42

4150.00 14.75 269.7 3999.48 -4.93 -942.34 1.00 942.364200.00 14.25 269.7 4047.89 -5.00 -954.86 1.00 954.884250.00 13.75 269.7 4096.40 -5.06 -966.96 1.00 966.974300.00 13.25 269.7 4145.02 -5.12 -978.63 1.00 978.644350.00 12.75 269.7 4193.74 -5.18 -989.88 1.00 989.89

4400.00 12.25 269.7 4242.55 -5.24 -1000.70 1.00 1000.714450.00 11.75 269.7 4291.46 -5.29 -1011.09 1.00 1011.114500.00 11.25 269.7 4340.46 -5.35 -1021.06 1.00 1021.084550.00 10.75 269.7 4389.54 -5.40 -1030.60 1.00 1030.624600.00 10.25 269.7 4438.70 -5.44 -1039.71 1.00 1039.73

4650.00 9.75 269.7 4487.94 -5.49 -1048.40 1.00 1048.414700.00 9.25 269.7 4537.26 -5.53 -1056.65 1.00 1056.664750.00 8.75 269.7 4586.64 -5.57 -1064.47 1.00 1064.494800.00 8.25 269.7 4636.09 -5.61 -1071.86 1.00 1071.884850.00 7.75 269.7 4685.60 -5.65 -1078.82 1.00 1078.83

4900.00 7.25 269.7 4735.18 -5.68 -1085.35 1.00 1085.364950.00 6.75 269.7 4784.80 -5.71 -1091.44 1.00 1091.45







31-06, Plan 1


SurfaceX

SurfaceY

Surface Z

Surface Long

Surface Lat

Ground Level

Plan 1




Database Access


Well Name 31-06

Field

Operator

County Duchesne

State UT

Country USA

Site

Slot Name

Well Number

Lat Long Ref

Z Datum

UWI

API

MapZone

Project


5000.00 6.25 269.7 4834.48 -5.74 -1097.10 1.00 1097.11

5050.00 5.75 269.7 4884.21 -5.77 -1102.33 1.00 1102.34

5100.00 5.25 269.7 4933.98 -5.80 -1107.12 1.00 1107.13

5150.00 4.75 269.7 4983.79 -5.82 -1111.48 1.00 1111.49

5200.00 4.25 269.7 5033.63 -5.84 -1115.40 1.00 1115.41

5250.00 3.75 269.7 5083.51 -5.86 -1118.89 1.00 1118.90

5300.00 3.25 269.7 5133.42 -5.87 -1121.94 1.00 1121.95

5350.00 2.75 269.7 5183.35 -5.89 -1124.56 1.00 1124.57

5400.00 2.25 269.7 5233.30 -5.90 -1126.74 1.00 1126.75

5450.00 1.75 269.7 5283.27 -5.91 -1128.48 1.00 1128.50

5500.00 1.25 269.7 5333.25 -5.92 -1129.79 1.00 1129.81

5550.00 0.75 269.7 5383.24 -5.92 -1130.66 1.00 1130.68

5600.00 0.25 269.7 5433.24 -5.92 -1131.10 1.00 1131.11

5625.00 0.00 0.0 5458.24 -5.92 -1131.15 1.00 1131.17

*** END DROP (at MD = 5625.00)

5650.00 0.00 0.0 5483.24 -5.92 -1131.15 0.00 1131.17

5700.00 0.00 0.0 5533.24 -5.92 -1131.15 0.00 1131.17

5750.00 0.00 0.0 5583.24 -5.92 -1131.15 0.00 1131.17

5800.00 0.00 0.0 5633.24 -5.92 -1131.15 0.00 1131.17

5850.00 0.00 0.0 5683.24 -5.92 -1131.15 0.00 1131.17

5900.00 0.00 0.0 5733.24 -5.92 -1131.15 0.00 1131.17

5950.00 0.00 0.0 5783.24 -5.92 -1131.15 0.00 1131.17

6000.00 0.00 0.0 5833.24 -5.92 -1131.15 0.00 1131.17

6050.00 0.00 0.0 5883.24 -5.92 -1131.15 0.00 1131.17

6100.00 0.00 0.0 5933.24 -5.92 -1131.15 0.00 1131.17

6150.00 0.00 0.0 5983.24 -5.92 -1131.15 0.00 1131.17

6200.00 0.00 0.0 6033.24 -5.92 -1131.15 0.00 1131.17

6250.00 0.00 0.0 6083.24 -5.92 -1131.15 0.00 1131.17

6300.00 0.00 0.0 6133.24 -5.92 -1131.15 0.00 1131.17

6348.00 0.00 0.0 6181.24 -5.92 -1131.15 0.00 1131.17

*** RTD (at MD = 6348.00)



CONFIDE

NTIAL











5000.00 6.25 269.7 4834.48 -5.74 -1097.10 1.00 1097.115050.00 5.75 269.7 4884.21 -5.77 -1102.33 1.00 1102.345100.00 5.25 269.7 4933.98 -5.80 -1107.12 1.00 1107.13

5150.00 4.75 269.7 4983.79 -5.82 -1111.48 1.00 1111.495200.00 4.25 269.7 5033.63 -5.84 -1115.40 1.00 1115.415250.00 3.75 269.7 5083.51 -5.86 -1118.89 1.00 1118.905300.00 3.25 269.7 5133.42 -5.87 -1121.94 1.00 1121.955350.00 2.75 269.7 5183.35 -5.89 -1124.56 1.00 1124.57

5400.00 2.25 269.7 5233.30 -5.90 -1126.74 1.00 1126.755450.00 1.75 269.7 5283.27 -5.91 -1128.48 1.00 1128.505500.00 1.25 269.7 5333.25 -5.92 -1129.79 1.00 1129.815550.00 0.75 269.7 5383.24 -5.92 -1130.66 1.00 1130.685600.00 0.25 269.7 5433.24 -5.92 -1131.10 1.00 1131.11

*** END DROP (at MD = 5625.00)5625.00 0.00 0.0 5458.24 -5.92 -1131.15 1.00 1131.175650.00 0.00 0.0 5483.24 -5.92 -1131.15 0.00 1131.175700.00 0.00 0.0 5533.24 -5.92 -1131.15 0.00 1131.175750.00 0.00 0.0 5583.24 -5.92 -1131.15 0.00 1131.175800.00 0.00 0.0 5633.24 -5.92 -1131.15 0.00 1131.17

5850.00 0.00 0.0 5683.24 -5.92 -1131.15 0.00 1131.175900.00 0.00 0.0 5733.24 -5.92 -1131.15 0.00 1131.175950.00 0.00 0.0 5783.24 -5.92 -1131.15 0.00 1131.176000.00 0.00 0.0 5833.24 -5.92 -1131.15 0.00 1131.176050.00 0.00 0.0 5883.24 -5.92 -1131.15 0.00 1131.17

6100.00 0.00 0.0 5933.24 -5.92 -1131.15 0.00 1131.176150.00 0.00 0.0 5983.24 -5.92 -1131.15 0.00 1131.176200.00 0.00 0.0 6033.24 -5.92 -1131.15 0.00 1131.176250.00 0.00 0.0 6083.24 -5.92 -1131.15 0.00 1131.176300.00 0.00 0.0 6133.24 -5.92 -1131.15 0.00 1131.17

*** RTD (at MD = 6348.00)6348.00 0.00 0.0 6181.24 -5.92 -1131.15 0.00 1131.17













5000.00 6.25 269.7 4834.48 -5.74 -1097.10 1.00 1097.115050.00 5.75 269.7 4884.21 -5.77 -1102.33 1.00 1102.345100.00 5.25 269.7 4933.98 -5.80 -1107.12 1.00 1107.13

5150.00 4.75 269.7 4983.79 -5.82 -1111.48 1.00 1111.495200.00 4.25 269.7 5033.63 -5.84 -1115.40 1.00 1115.415250.00 3.75 269.7 5083.51 -5.86 -1118.89 1.00 1118.905300.00 3.25 269.7 5133.42 -5.87 -1121.94 1.00 1121.955350.00 2.75 269.7 5183.35 -5.89 -1124.56 1.00 1124.57

5400.00 2.25 269.7 5233.30 -5.90 -1126.74 1.00 1126.755450.00 1.75 269.7 5283.27 -5.91 -1128.48 1.00 1128.505500.00 1.25 269.7 5333.25 -5.92 -1129.79 1.00 1129.815550.00 0.75 269.7 5383.24 -5.92 -1130.66 1.00 1130.685600.00 0.25 269.7 5433.24 -5.92 -1131.10 1.00 1131.11

*** END DROP (at MD = 5625.00)5625.00 0.00 0.0 5458.24 -5.92 -1131.15 1.00 1131.175650.00 0.00 0.0 5483.24 -5.92 -1131.15 0.00 1131.175700.00 0.00 0.0 5533.24 -5.92 -1131.15 0.00 1131.175750.00 0.00 0.0 5583.24 -5.92 -1131.15 0.00 1131.175800.00 0.00 0.0 5633.24 -5.92 -1131.15 0.00 1131.17

5850.00 0.00 0.0 5683.24 -5.92 -1131.15 0.00 1131.175900.00 0.00 0.0 5733.24 -5.92 -1131.15 0.00 1131.175950.00 0.00 0.0 5783.24 -5.92 -1131.15 0.00 1131.176000.00 0.00 0.0 5833.24 -5.92 -1131.15 0.00 1131.176050.00 0.00 0.0 5883.24 -5.92 -1131.15 0.00 1131.17

6100.00 0.00 0.0 5933.24 -5.92 -1131.15 0.00 1131.176150.00 0.00 0.0 5983.24 -5.92 -1131.15 0.00 1131.176200.00 0.00 0.0 6033.24 -5.92 -1131.15 0.00 1131.176250.00 0.00 0.0 6083.24 -5.92 -1131.15 0.00 1131.176300.00 0.00 0.0 6133.24 -5.92 -1131.15 0.00 1131.17

*** RTD (at MD = 6348.00)6348.00 0.00 0.0 6181.24 -5.92 -1131.15 0.00 1131.17













5000.00 6.25 269.7 4834.48 -5.74 -1097.10 1.00 1097.115050.00 5.75 269.7 4884.21 -5.77 -1102.33 1.00 1102.345100.00 5.25 269.7 4933.98 -5.80 -1107.12 1.00 1107.13

5150.00 4.75 269.7 4983.79 -5.82 -1111.48 1.00 1111.495200.00 4.25 269.7 5033.63 -5.84 -1115.40 1.00 1115.415250.00 3.75 269.7 5083.51 -5.86 -1118.89 1.00 1118.905300.00 3.25 269.7 5133.42 -5.87 -1121.94 1.00 1121.955350.00 2.75 269.7 5183.35 -5.89 -1124.56 1.00 1124.57

5400.00 2.25 269.7 5233.30 -5.90 -1126.74 1.00 1126.755450.00 1.75 269.7 5283.27 -5.91 -1128.48 1.00 1128.505500.00 1.25 269.7 5333.25 -5.92 -1129.79 1.00 1129.815550.00 0.75 269.7 5383.24 -5.92 -1130.66 1.00 1130.685600.00 0.25 269.7 5433.24 -5.92 -1131.10 1.00 1131.11

*** END DROP (at MD = 5625.00)5625.00 0.00 0.0 5458.24 -5.92 -1131.15 1.00 1131.175650.00 0.00 0.0 5483.24 -5.92 -1131.15 0.00 1131.175700.00 0.00 0.0 5533.24 -5.92 -1131.15 0.00 1131.175750.00 0.00 0.0 5583.24 -5.92 -1131.15 0.00 1131.175800.00 0.00 0.0 5633.24 -5.92 -1131.15 0.00 1131.17

5850.00 0.00 0.0 5683.24 -5.92 -1131.15 0.00 1131.175900.00 0.00 0.0 5733.24 -5.92 -1131.15 0.00 1131.175950.00 0.00 0.0 5783.24 -5.92 -1131.15 0.00 1131.176000.00 0.00 0.0 5833.24 -5.92 -1131.15 0.00 1131.176050.00 0.00 0.0 5883.24 -5.92 -1131.15 0.00 1131.17

6100.00 0.00 0.0 5933.24 -5.92 -1131.15 0.00 1131.176150.00 0.00 0.0 5983.24 -5.92 -1131.15 0.00 1131.176200.00 0.00 0.0 6033.24 -5.92 -1131.15 0.00 1131.176250.00 0.00 0.0 6083.24 -5.92 -1131.15 0.00 1131.176300.00 0.00 0.0 6133.24 -5.92 -1131.15 0.00 1131.17

*** RTD (at MD = 6348.00)6348.00 0.00 0.0 6181.24 -5.92 -1131.15 0.00 1131.17













5000.00 6.25 269.7 4834.48 -5.74 -1097.10 1.00 1097.115050.00 5.75 269.7 4884.21 -5.77 -1102.33 1.00 1102.345100.00 5.25 269.7 4933.98 -5.80 -1107.12 1.00 1107.13

5150.00 4.75 269.7 4983.79 -5.82 -1111.48 1.00 1111.495200.00 4.25 269.7 5033.63 -5.84 -1115.40 1.00 1115.415250.00 3.75 269.7 5083.51 -5.86 -1118.89 1.00 1118.905300.00 3.25 269.7 5133.42 -5.87 -1121.94 1.00 1121.955350.00 2.75 269.7 5183.35 -5.89 -1124.56 1.00 1124.57

5400.00 2.25 269.7 5233.30 -5.90 -1126.74 1.00 1126.755450.00 1.75 269.7 5283.27 -5.91 -1128.48 1.00 1128.505500.00 1.25 269.7 5333.25 -5.92 -1129.79 1.00 1129.815550.00 0.75 269.7 5383.24 -5.92 -1130.66 1.00 1130.685600.00 0.25 269.7 5433.24 -5.92 -1131.10 1.00 1131.11

*** END DROP (at MD = 5625.00)5625.00 0.00 0.0 5458.24 -5.92 -1131.15 1.00 1131.175650.00 0.00 0.0 5483.24 -5.92 -1131.15 0.00 1131.175700.00 0.00 0.0 5533.24 -5.92 -1131.15 0.00 1131.175750.00 0.00 0.0 5583.24 -5.92 -1131.15 0.00 1131.175800.00 0.00 0.0 5633.24 -5.92 -1131.15 0.00 1131.17

5850.00 0.00 0.0 5683.24 -5.92 -1131.15 0.00 1131.175900.00 0.00 0.0 5733.24 -5.92 -1131.15 0.00 1131.175950.00 0.00 0.0 5783.24 -5.92 -1131.15 0.00 1131.176000.00 0.00 0.0 5833.24 -5.92 -1131.15 0.00 1131.176050.00 0.00 0.0 5883.24 -5.92 -1131.15 0.00 1131.17

6100.00 0.00 0.0 5933.24 -5.92 -1131.15 0.00 1131.176150.00 0.00 0.0 5983.24 -5.92 -1131.15 0.00 1131.176200.00 0.00 0.0 6033.24 -5.92 -1131.15 0.00 1131.176250.00 0.00 0.0 6083.24 -5.92 -1131.15 0.00 1131.176300.00 0.00 0.0 6133.24 -5.92 -1131.15 0.00 1131.17

*** RTD (at MD = 6348.00)6348.00 0.00 0.0 6181.24 -5.92 -1131.15 0.00 1131.17





CONFIDE

NTIAL


TSS R3W, US.R&M 131ißROGLYPHOPERATING CO., INC.Well loca¯ion, JTE TWllAL 4.51-05, loca¯cd as

s.r we . ro ve shown iri the SW 1/4 NE 1/4 et 5eccion 31, TSS5381f - 2 9 9tco 59 / 2 Ucc R3W, J.S.B.&M., Duchesre County, Jtah.

I II BAsis 'F ELEVATlCN

UNSS CAP UET It CJAG ETE LIY UJrsialsE EM IkEE-cis:

L CA lE] IS THE SE OF SECTION B, T:U, ... s i ) &-L

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BASl5 OF BEARINGS

9.;SI OF BE INGS I . .5. BLERVATlC .

TR/BAL f31-06

C A LE- CER [lFI ATE

lir=E elI¥T THoT THE LA E A

EST s|F HY KNEWLE:)::E shi: REL

REW J- H- '. 8 F. STATE

. 27 i¥ - 2523. 9 - 142 I EV: 09-2¯-li S.F

UINTAH ENGINICE1HNG LANJ3 SURVEYING,

-85 SOUTH 200 EAST - VERKAT, UTAEI 84098

(4¾) 189-1017

LEGEN sir-ET.. alEsio= 0 )d-¿ -11 01-2N-13

= 90 YYROL N TA y rioTY WH F1 m,E 5LIRF ,-=Tr ¯EFEREsfE

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BASl5 OF BEARINGS


TR/BAL f31-06





. 27 i¥ - 2523. 9 - 142 I EV: 09-2¯-li S.F



(4¾) 189-1017















BASl5 OF BEARINGS


TR/BAL f31-06





. 27 i¥ - 2523. 9 - 142 I EV: 09-2¯-li S.F



(4¾) 189-1017















BASl5 OF BEARINGS


TR/BAL f31-06





. 27 i¥ - 2523. 9 - 142 I EV: 09-2¯-li S.F



(4¾) 189-1017










CONFIDE

NTIAL


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---------- PROPOSID ACCESS ROAD I. TE TRIBAL di31-06 ON EXISTING ii31-07

SECTION 3L T55, R3W, I .S.B.&31.

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PETROGLYPH OPERATING CO., INC. P.O. BOX 607 ROOSEVELT, UTAH 84066

October 30, 2013

Ms. Diana Mason

State of Utah

Division of Oil, Gas & Mining

1594 West North Temple, Suite 1210

P.O. Box 145801

Salt Lake City, UT 84114-5801

Re: Directional Drilling R649-3-11

Ute Tribal 31-06 : 1989‘ FNL & 2150‘ FEL, SW/NE, (Surface Hole) 1980‘ FNL & 1980‘ FWL, SE/NW, (Bottom Hole)

Sec. 31, T5S, R3W, U.S.B.&M., Duchesne County, Utah

Dear Ms. Mason,

Pursuant to the filing of Petroglyph Operating Co., Inc.’s Application for Permit to Drill

regarding the above referenced well on October 30, 2013, we are hereby submitting this letter in

accordance with Oil & Gas Conservation Rule R649-3-11 pertaining to the Exception to

Location and Siting of Wells.

The Ute Tribal 30-02O is located within the Antelope Creek Unit Area.

Petroglyph Operating Co., Inc. is permitting this well as a directional well in order to

minimize surface disturbance. Locating the well at the surface location and drilling

directionally from this location, Petroglyph Operating Co., Inc. will be able to utilize the

existing road and pipelines in the area.

Furthermore, Petroglyph Operating Co., Inc. hereby certifies that it is the sole working

interest owner within 460 feet of the entire directional well bore.

Therefore, based on the above stated information, Petroglyph Operating Co., Inc. requests the

permit be granted pursuant to R649-3-11.

Respectfully Submitted,

Ed Trotter,

Agent

P.O. Box 1910

Vernal, UT 84078

Phone: (435)789-4120

Fax: (435)789-1420


CONFIDE

NTIAL


PETROGLYPH OPERATING CO., INC.P.O. BOX 607ROOSEVELT, UTAH 84066

October 30, 2013

Ms. Diana MasonState of UtahDivision of Oil, Gas & Mining1594 West North Temple, Suite 1210P.O. Box 145801Salt Lake City, UT 84114-5801


Ute Tribal 31-06 : 1980' FNL & 2150' FEL, SW/NE, (Surface Hole)1980' FNL & 1980' FWL, SE/NW, (Bottom Hole)Sec· 31, TsS, R3W, U.S.B.&M.,Duchesne County, Utah

Dear Ms. Mason,Pursuant to the filing of Petroglyph Operating Co., Inc.'s Application for Permit to Drill

regarding the above referenced well on October 30, 2013, we are hereby submitting this letter inaccordance with Oil & Gas Conservation Rule R649-3-11 pertaining to the Exception toLocation and Siting of Wells.

• The Ute Tribal 30-020 is located within the Antelope Creek Unit Area.• Petroglyph Operating Co., Inc. is permitting this well as a directional well in order to

minimize surface disturbance. Locating the well at the surface location and drillingdirectionally from this location, Petroglyph Operating Co., Inc. will be able to utilize theexisting road and pipelines in the area.

• Furthermore, Petroglyph Operating Co., Inc. hereby certifies that it is the sole workinginterest owner within 460 feet of the entire directional well bore.

Therefore, based on the above stated information, Petroglyph Operating Co., Inc. requests thepermit be granted pursuant to R649-3-11.


Ed Trotter,AgentP.O. Box 1910Vernal, UT 84078Phone: (435)789-4120Fax: (435)789-1420




October 30, 2013



Ute Tribal 31-06 : 1989' FNL & 2150' FEL, SW/NE, (Surface Hole)1980' FNL & 1980' FWL, SE/NW, (Bottom Hole)Sec- 31, TsS, R3W, U.S.B.&M.,Duchesne County, Utah












October 30, 2013















October 30, 2013














E-mail: [email protected]


CONFIDE

NTIAL














Document1 Page 1 of 1

Certification I hereby certify that I, or persons under my direct supervision, have inspected the proposed drillsite and access route; that I am familiar with the conditions that presently exist; that the statements made in the Plan are, to the best of my knowledge, true and correct; and that the work associated with the operations proposed herein will be performed by Petroglyph Operating Co., Inc. and its contractors and subcontractors in conformity with this Plan and the terms and conditions under which it is approved. Please be advised that Petroglyph Operating Co., Inc. is considered to be the operator of the UTE TRIBAL 31-06 Well, located in the SW/NE of Section 31, T5S, R3W, Duchesne County, Utah; Lease #14-20-H62-3520; and is responsible under the terms and conditions of the lease for the operations conducted upon the leased lands. Bond Coverage is provided under Bond #LPM4138335. _________________________ ________________________ Date Ed Trotter, as Agent for Petroglyph Operating Co., Inc.


CONFIDE

NTIAL


Certification

I hereby certify that I, or persons under my direct supervision, have inspected theproposed drillsite and access route; that I am familiar with the conditions thatpresently exist; that the statements made in the Plan are, to the best of myknowledge, true and correct; and that the work associated with the operationsproposed herein will be performed by Petroglyph Operating Co., Inc. and itscontractors and subcontractors in conformity with this Plan and the terms andconditions under which it is approved.

Please be advised that Petroglyph Operating Co., Inc. is considered to be theoperator of the UTE TRIBAL 31-06 Well, located in the SW/NE ofSection 31, T5S, R3W, Duchesne County, Utah; Lease #14-20-H62-3520; and is responsible under the terms and conditions of the lease for theoperations conducted upon the leased lands. Bond Coverage is provided underBond #LPM4138335·

Date Ed Trotter, as Agent forPetroglyph Operating Co., Inc.

Documentl Page 1 of 1



Certification







Certification







Certification








CONFIDE

NTIAL


PETROGLYPH OPERATING CO., INC. FICURE #1LOCATIONLAYOUT FOR SCALE: 1" = 50

Prevoliing N winds UTE TRIBAL $31-06 ON EXISTING#31-07 DArE: 08-26-13DRAWN BY: J.JSECTION 31, T5S, R3W, U.S.B.&M' REV: 09-26-13 5.F.

Previously Approved 1983' FNL 2150' FEL REV: 10-18-13 S.F.Surface Use Area - -- --

or the Utc Triboi /31-07

1 p Stock //e - "4 4'

F-2 - 10El 795 145

L ANo- -Il -

- aransliion Line

131

El 799.2'C-9.4' C-0.7 Existin 17-Strn, R/t) Ute Tribal /J/-Q7

20E-1.2

. Iri. 796.6

60' c es' Slo. 1+94

F-24ç_Q El 795 4

a zaao

Existing -

ExistingRoad

F-1. JRESER P/7 O 796

El 798 7' (d' Deep) | |C-8.9'

cutAtoHim. Pit) Transition Line i Appro×.

Tee of ITotal Pit Capocky Fill SlopeW/2' of Freehoord

- 19ÛO Bb/s + y¡yTotal R// Jo/urne

¯Pad

= ?,250 C12. d 6800

Round Corneros Needed I |

C-6 84 ---..

3ß 6.6

Approx. - ExistingTop of Pipeline i

Elev ungraded creand At Loc Stoke = 6796.6' cut siopUixtair ENCINEERING ¿c LAND S(IRV£YING

FIN/SHED GRADE ELEV AT LOC STAKE = 679Z8 as sa 29, a... - v...se ca.>.asava - <<sea res-rory







1 p Stock //e - "4 4'

F-2 - 10El 795 145

L ANo- -Il -

- aransliion Line

131


20E-1.2

. Iri. 796.6

60' c es' Slo. 1+94

F-24ç_Q El 795 4

a zaao

Existing -

ExistingRoad


El 798 7' (d' Deep) | |C-8.9'




¯Pad

= ?,250 C12. d 6800


C-6 84 ---..

3ß 6.6










1 p Stock //e - "4 4'

F-2 - 10El 795 145

L ANo- -Il -

- aransliion Line

131


20E-1.2

. Iri. 796.6

60' c es' Slo. 1+94

F-24ç_Q El 795 4

a zaao

Existing -

ExistingRoad


El 798 7' (d' Deep) | |C-8.9'




¯Pad

= ?,250 C12. d 6800


C-6 84 ---..

3ß 6.6










1 p Stock //e - "4 4'

F-2 - 10El 795 145

L ANo- -Il -

- aransliion Line

131


20E-1.2

. Iri. 796.6

60' c es' Slo. 1+94

F-24ç_Q El 795 4

a zaao

Existing -

ExistingRoad


El 798 7' (d' Deep) | |C-8.9'




¯Pad

= ?,250 C12. d 6800


C-6 84 ---..

3ß 6.6





RECEIVED: November 29, 2013

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UTE TRIBAL29-16

4301330849

UTE TRIBAL 29-064301330850

UTE TRIBAL29-044301330851

UTE TRIBAL30-07

4301330852

UTE TRIBAL32-084301330853

UTE TRIBAL29-074301330939

UTE TRIBAL25-54301330944

UTE TRIBAL31-034301331188

UTE TRIBAL25-64301331202

UTE TRIBAL25-24301331213

UTE TRIBAL29-08A

4301331305

UTE TRIBAL29-08B

4301331339

UTE TRIBAL29-10

4301331475

UTE TRIBAL28-12

4301331529

UTE TRIBAL29-154301331530

UTETRIBAL 28-13

4301331576

UTE TRIBAL32-014301331577

UTE TRIBAL29-08

4301331693

UTE TRIBAL30-014301331707

UTE TRIBAL28-05A

4301331709

UTE TRIBAL29-114301331714

UTE TRIBAL30-08

4301331734

UTETRIBAL 29-054301331796

UTE TRIBAL29-124301331797

UTE TRIBAL30-094301331798

UTE TRIBAL36-08-E4W4301331815

UTE TRIBAL29-034301331842

UTE TRIBAL30-104301331895

UTE TRIBAL30-154301331896

UTE TRIBAL30-11

4301331907

UTE TRIBAL30-14

4301331908

UTE TRIBAL30-06

4301331970

UTE TRIBAL31-044301332034

UTE TRIBAL31-054301332035

UTE TRIBAL31-074301332036

UTE TRIBAL31-124301332038

UTE TRIBAL31-134301332039

UTE TRIBAL29-01

4301332198UTE TRIBAL

29-024301332199

UT 29-144301332201

UTE TRIBAL29-05F4301332497

UTE TRIBAL30-01A

4301332498

UTE TRIBAL29-06F

4301332534

UTETRIBAL 29-06E4301332535

UTETRIBAL 29-09J

4301332548

UTE TRIBAL29-16P

4301332556

UTE TRIBAL14-25-544301332776

UTE TRIBAL16-25-544301332779

UTE TRIBAL8-25-544301332780

UTE TRIBAL11-25-544301332856

UTE TRIBAL30-134301334054

UTE TRIBAL30-044301334055

UTE TRIBAL29-11G

4301334292

UTE TRIBAL30-124301334294

FEDERAL1-1D-64

4301350524FEDERAL2-1D-644301350765

FEDERAL7-1D-64

4301350766

FEDERAL 9-1D-644301350767

UTE TRIBAL30-14N4301350805

UTE TRIBAL30-14M

4301350809

UTETRIBAL 30-16K

4301350811

GDU 63-6-234301350905

UTE TRIBAL30-054301350935UTE TRIBAL30-05E4301350936

UTETRIBAL 30-05F

4301350944

UTE TRIBAL36-05-E44301351555

UTE TRIBAL36-13-E44301351603

UTE TRIBAL36-02-E44301351931

UTE Tribal1-25D-54

4301352173UTE Tribal

9-25D-544301352177

Ute Tribal28-04A

4301352197

Ute Tribal29-11L4301352201

Ute Tribal 29-07C4301352203

Ute Tribal30-02O

4301352205

Ute Tribal30-034301352206

Ute Tribal29-07B4301352207

UteTribal 29-11M4301352209

GDU 63-6-144301352228

GDU 63-6-224301352229

UTE Tribal12-25D-54

4301352308

UTE Tribal13-25D-54

4301352322

GDU 63-5-124301352562

Ute Tribal31-014301352598

Ute Tribal32-09I

4301352599

Ute Tribal32-044301352600

Ute Tribal32-09

4301352601

Ute Tribal32-144301352602

Ute Tribal29-10H4301352618

Ute Tribal30-07H4301352621

Ute Tribal30-07G

4301352622

Ute Tribal32-154301352623

Ute Tribal29-13Q4301352624

Ute Tribal29-13J

4301352625

Ute Tribal31-06

4301352629

Ute Tribal32-024301352636

Ute Tribal32-03

4301352637

G I L S O N I T EG I L S O N I T ED R A W U N I TD R A W U N I T

A N T E L O P EA N T E L O P EC R E E K U N I TC R E E K U N I T

Map Produced by Diana Mason

F1,700 0 1,700850 Feet

1:16,807

Wells QueryStatus

APD - Aproved Permit

H DRL - Spuded (Drilling Commenced)

4 GIW - Gas Injection

!) GS - Gas Storage

! LOC - New Location

7 OPS - Operation Suspended

ª PA - Plugged Abandoned

* PGW - Producing Gas Well

' POW - Producing Oil Well

¸ SGW - Shut-in Gas Well

· SOW - Shut-in Oil Well

6 TA - Temp. Abandoned

" TW - Test Well

¸ WDW - Water Disposal

¸ WIW - Water Injection Well

=) WSW - Water Supply Well

UnitsSTATUS

ACTIVE

EXPLORATORY

GAS STORAGE

NF PP OIL

NF SECONDARY

PI OIL

PP GAS

PP GEOTHERML

PP OIL

SECONDARY

TERMINATED

FieldsSTATUS

Unknown

ABANDONED

ACTIVE

COMBINED

INACTIVE

STORAGE

TERMINATED

TOOELE

SAN JUAN

MILLARD

KANE

JUAB

IRON

EMERY

UINTAH

BOX ELDER

GARFIELD

GRAND

UTAH

WAYNEBEAVER

DUCHESNE

SEVIER

SUMMIT

RICH

WASHINGTON

CARBON

SANPETE

CACHE

PIUTE

DAVIS

WASATCH

WEBER

SALT LAKE

DAGGETT

MORGAN

Location Map

API Number: 4301352629Well Name: Ute Tribal 31-06 Township: T05.0S Range: R03.0W Section: 31 Meridian: U

Operator: PETROGLYPH OPERATING CO

Map Prepared: 11/29/2013


CONFIDE

NTIAL


UTE TRIBAL UTE TRIBAL UTE TRIBAL |25-2 UTETRIBAL 30-020

3ribalUTETRI L UTETRIBAL 29-03 UTETRIBAL 29-01/ Ut API Number: 43013526294301331213 30-04 4301352205 430135220630-01 29-04 UTE 4301331842 29-02 4301332198

4301 9725TETRIBAL 4301334055 43013317 4301330851TRIBAL29-0 4301332199 Well Name: Ute Tribal 31-06

UTE TRIBAL4301331202

UTE Tribal E TRIBAL 3UTET AL 03OLTE30TRIBAL

3

8L

TR BAL 29-0

0E41335209 2

3 939

430E

3

3L

UTE TRIBATownship: TO5.0S Range: RO3.0W Section: 31 Meridian: U

051330944 1-25D-54 3205135342780 31350935Ute

Trib43013308524301331796

3b0 325 2703Ute Tribal 28-05A Operator: PETROGLYPH OPERATING CO

4301352173 JTE RIBAL 30- Tribal UTE TRIBAL UTE TRIBAL UTE TRIBAL UTE TRIBAL 29-07B UTE TRIBAL 4331331709UTE Tribal TRIBAL 3C 05F 30-08 29-05F 29-06F 29-11G 4301352207 29-08B

UTE Tribal UTE TRIBAL 25 9-25D-54 430135 944 43013509430135

43013 21 4301331734 4301332497 4301332534 4301334292 4301331339 28 Map Prepared: 11/29/201312-25D-54 11-25-54 4301352177 30 UTE TRIBAL UTE TRI AL UTE TRIBAL UTE T L UTE TfBAL Map Produced by Diana Mason

4301352308 4301332856 UTE TRIBAL UTE TRIBAL 29-11 29-08A UTE RIBAL0112334294 UTE30T BAL

0110331895 001331798 0112331797U

4301331714 432 310475

43013313054301

4321 92

4301331907 Tribal 29-11 Tribal Ute Tribal I JTE Welle Query Units430135 L 29-10H TRIBAL29-09J status sTAyus

2201 4301352618 4301332548 * APo AproveaPermit AcTivE

UTE Tribal UTE TRIBAL UTE TRIBAL UTE TRI Tribal UTE TRIBAL DRL spudea<oriiiingcommenceci ExPtosAvoav

13-25D-54 14-25-54UTETR 3AL

30-14 30-153J

UT29-14 29-15 UTETRIBAL Giw Gasinjection GAssTOR^oE

4301332776 021533/79

UTE TRI3013319

BL301R334

0

63350-0181E 43tl1352

Ute Tribal

4301332201

UT

43RO133153043013 0 L928

c NoAR

UËlBAL 430 09 01143N50805A N LOP 29-13Q 4301323 56564301331576 °FS opersionsuspended

30-13 iiTcToimai / 4301352624 PA iuggeaAbandoned

4301334054 31-03 K MT4301331188 UTE TRIBAL Ute Tribal Ute Tribal UTE T IBAL DIL

L 434L 0012330827 0011352538

0015b2

0052636

001131577

O Tw TestweliUnknown

UTE TRIBAL UTETRII.AL wow waerosposai36-05-E4 36-08-E4 Y UTE TRIBAL Ute Tribal4301351555 4301331; 15 31-05 31-06 UTE TRIBAL UTE TI:lBAL

4301332035 43031135262 0017332036

32

0018330853 e usw watersuppiyweii coMe Eo

Ute fribal svosAoE

4303 5029L393 TERMiNATED

36UTE TRIBAL Ute Trib31-12 34301332038 4301 601

sox ELDERic

Location Map

UTE TRIBAL36-13-E4

UTE TRIBAL Ute Tribal4301351603 31-13 32-14 Ute Tribal TooEu

4301332039 43013526022623 uvAH

oucHE NuiNTAH

PINON FED 1 "^"ANPE

Eueny eaAND

4301311008 sevisa

U 63-5-124301352562

e vER PiuTE wAvNE

FED AL06 G4DO16335284

G I LSON I TE01 4301131D- F3E0D1E37L6-1D-64

DR A WUN I T 04 *^3 1°N "N

O 430E7DE0D F3EDE3RA7LG 53

00 850 0 1.700Feet

1:16,807

RECEIVED: November 29,


2U TRIBALUTETRIBAL 3

3ribalTETRI L UTETRIBAL 2

3TRIB L UTETR29 LUt API Number: 43013526294301331213 30-04 4301352205 4301352206

30-01 29-04 UTE 4301331842 29-02 43013321984301 9725TETRIBAL 4301334055 43013317 4301330851TRIBAL29-0 4301332199 Well Name: Ute Tribal 31-06



3

8L

TR BAL 29-0

0E41335209 2

3 939

430E

3

3L


051330944 1-25D-54 3205135342780 350935Ute

Trib43013308524301331796




43013 21 4301331734 4301332497 4301332534 4301334292 4301331339 28 Map Prepared: 11/29/201312-25D-54 11-25-54 4301352177 30 UTE TRIBAL UTE TRIDAL UTE TRIBAL UTE T L UTE TËBAL Map Produced by Diana Mason


0110331895 0019331/980112331797U 4301331714

432 310475 430133130543014321 92

4301331907 Tribal 29-11 Tribal te Tribal I JTE Welle Query Units430135 L 29-10H TRIB/L29-09J status sTAyus


UTE Tribal UTE TRIBAL UTE TRIBAL UTE TRI Tribal UTE TRI L DRL spudea<oriiiingcommenceci ExPtosAvoav

13-25D-54 14-25-54UTE TR 3AL

30-14 30-153J UT 29-14 29-15 UTE TRIB \L Giw Gas injection GAs sTOR^oE

4301332776 021533/79

UTE TRI301331

301R3340

63350-0181E 43 11

Ute Tribal

4301332201

UT

3RO133153043013 0 L928

c NoAR

UËlBAL 430 09 01143N50805A N LO 29-13Q 4301323 56564301331576 °FS opersionsuspended


4301334054 31-03 KT1 NT4301331188 UTE TRIBAL Ute Tribal Ute Tribal UTE T IBAL DIL

L 434L 0012330827 0011352538

0015b2

0052636

001131577

O Tw Testwell unknownUTE TRIBAL UTETRII.AL wow waerosposai36-05-E4 36-08-E4 Y UTE TRIBAL Ute Tribal4301351555 4301331; 15 31-05 31-06 UTE TRIBAL UTE TI:lBAL

4301332035 4301352629 0017332036 32-08 watersuppiyweii coMeiNED

31 32 4301330853Ute fribal svosAoE



sox ELDERic

Location Map

UTE TRIBAL36-13-E4


4301332039 43013526022623 uvAH

oucHE NuiNTAH

PINON FED 1 "^"ANPE

Eueny eaAND

4301311008 sevisa

U 63-5-124301352562

vER PiuTE wAvNE

FED AL06 G4DO16335284

G I LSON I TE01 4301131D- F3E0D1E37L6-1D-64

DR A WUN I T 04 *^3 1°N "N

C 430E7DE0D F3EDE3RA7LG 53

oo eso o uooFeet

1:16,807



UTE TRIBAL UTE TRIBAL UTE TRIBAL |25-2 UTETRIBAL 30-020 3





3

8L

TR BAL 29-0

0E41335209 2

3 939

430E

3

3L


051330944 1-25D-54 3205135342780 31350935Ute

Trib43013308524301331796






0110331895 001331798 0112331797U

4301331714 432 310475

43013313054301

4321 92



UTE Tribal UTE TRIBAL UTE TRIBAL UTE TRI Tribal UTE TRIBAL o ORL spudea<oriiiingcommenceci ExPtosAvoav

13-25D-54 14-25-54UTETR 3AL

30-14 30-153J


4301332776 021533/79

UTE TRI3013319

BL301R334

0

63350-0181E 43tl1352

Ute Tribal

4301332201

UT

43RO133153043013 0 L928

cNoAR




L 434L 0012330827 0011352538

0015b2

0052636

001131577







sox ELDERic

Location Map

UTE TRIBAL36-13-E4


4301332039 43013526022623 uvAH

oucHE NuiNTAH

PINON FED 1 "I"^"ANPE

Eueny eaAND

4301311008 sevisa

U 63-5-124301352562

BEAvER PiuTE wAvNE

06 GDU 63-6-1405

IRON GARFiELD

FED AL 4301352228 G I LSON I TE01 4301131D- F3E0D1E37L6-1D-64

DR A WUN I T 04 *^3""°1°N "NE

C 430E7DE0D F3EDE3RA7LœG G 53

00 850 0 1700Feet

1:16,807



UTE TRIBAL UTE TRIBAL UTE TRIBAL |25-2 UTETRIBAL 30-020 3





3

8L

TR BAL 29-0

0E41335209 2

3 939

430E

3

3L


051330944 1-25D-54 3205135342780 31350935Ute

Trib43013308524301331796






0110331895 001331798 0112331797U

4301331714 432 310475

43013313054301

4321 92



UTE Tribal UTE TRIBAL UTE TRIBAL UTE TRI Tribal UTE TRIBAL o ORL spudea<oriiiingcommenceci ExPtosAvoav

13-25D-54 14-25-54UTETR 3AL

30-14 30-153J


4301332776 021533/79

UTE TRI3013319

BL301R334

0

63350-0181E 43tl1352

Ute Tribal

4301332201

UT

43RO133153043013 0 L928

c NoAR




L 434L 0012330827 0011352538

0015b2

0052636

001131577







sox ELDERic

Location Map

UTE TRIBAL36-13-E4


4301332039 43013526022623 uvAH

oucHE NuiNTAH

PINON FED 1 "I"^"ANPE

Eueny eaAND

4301311008 sevisa

U 63-5-124301352562

BEAvER PiuTE wAvNE

06 GDU 63-6-1405

IRON GARFiELD

FED AL 4301352228 G I LSON I TE01 4301131D- F3E0D1E37L6-1D-64

DR A WUN I T 04 *^3""°1°N "NE

C 430E7DE0D F3EDE3RA7LœG G 53

00 850 0 1700Feet

1:16,807



WORKSHEETAPPLICATION FOR PERMIT TO DRILL

APD RECEIVED: 10/31 /2013 API NO. ASSIGNED: 43013526290000

WELL NAME: Ute Tribal 31-06

OPERATOR: PETROGLYPH OPERATING CO (N3800) PHONE NUMBER: 435 789-4120

CONTACT: Ed Trotter

PROPOSED LOCATION: SWNE 31 050S 030W Permit Tech Review:

SURFACE: 1989 FNL 2150 FEL Engineering Review:

BOTTOM: 1980 FNL 1980 FWL Geology Review:

COUNTY: DUCHESNE

LATITUDE: 40.00486 LONGITUDE: -110.26390

UTM SURF EASTINGS: 562829.00 NORTHINGS: 4428556.00

FIELD NAME: ANTELOPE CREEK

LEASE TYPE: 2 - Indian

LEASE NUMBER: 1420H623520 PROPOSED PRODUCING FORMATION(S): GREEN RIVER

SURFACE OWNER: 2 - Indian COALBED METHANE: NO

RECEIVED AND/OR REVIEWED: LOCATION AND SITING:

PLAT R649-2 -3 .

Bond: INDIAN - LPM4138336 Unit: ANTELOPE CREEK

Potash R649-3-2. General

Oil Shale 190-5

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

Oil Shale 190-13 Drilling Unit

Water Permit: 43-8342 Board Cause No: Cause 214-2

RDCC Review: Effective Date: 6 /9 /2000

Fee Surface Agreement Siting: Suspends General Siting

Intent to Commingle R649-3-11. Directional Drill

Commingling Approved

Comments: Presite Completed

Stipulations: 4 - Federal Approval - dmason 15 - Directional - dmason


CONFIDE

NTIAL



I

I

APD RECEIVED: 10/31/2013 API NO. ASSIGNED: 43013526290000



CONTACT: Ed Trotter




COUNTY: DUCHESNE



FIELD NAME: ANTELOPECREEK




I

RECEIVED ANDIOR REVIEWED: LOCATION AND SITING:

PLAT R649-2-3.



Oil Shale 190-5




RDCC Review: Effective Date: 6/9/2000




I


Stipulations: 4 - Federal Approval - dmason15 - Directional - dmason




I

I




CONTACT: Ed Trotter




COUNTY: DUCHESNE







I


PLAT R649-2-3.



Oil Shale 190-5








I






I

I




CONTACT: Ed Trotter




COUNTY: DUCHESNE







I


PLAT R649-2-3.



Oil Shale 190-5








I






I

I




CONTACT: Ed Trotter




COUNTY: DUCHESNE







I


PLAT R649-2-3.



Oil Shale 190-5








I




Permit To Drill******************Well Name: Ute Tribal 31-06

API Well Number: 43013526290000Lease Number: 1420H623520Surface Owner: INDIAN Approval Date: 1 / 2 9 / 2 0 1 4

Issued to:PETROGLYPH OPERATING CO, 960 Broadway Avenue, Ste 500, Boise, ID 83703

Authority:Pursuant to Utah Code Ann. 40-6-1 et seq. , and Utah Administrat ive CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of Cause 214-2. The expected producing formation or poolis the GREEN RIVER Formation(s), completion into any other zones will requirefiling a Sundry Notice (Form 9). Completion and commingling of more than onepool will require approval in accordance with R649-3-22.

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

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

Conditions of Approval:State approval of this well does not supercede the required federal approval, whichmust be obtained prior to dri l l ing.

In accordance with Utah Admin. R.649-3-11, Directional Drilling, the operator shallsubmit a complete angular deviation and directional survey report to the Divisionwithin 30 days following completion of the well.

Notification Requirements:The operator is required to notify the Division of Oil, Gas and Mining of thefollowing actions during drilling of this well: • Within 24 hours following the spudding of the well - contact Carol Daniels at8 0 1 - 5 3 8 - 5 2 8 4 (please leave a voicemail message if not available) OR submit an electronic sundry notice (pre-registration required) via the Utah Oil &

State of Utaha DEPARTMENT OF NATURAL RESOURCES

-

.,5., MICHAEL R. STYLER

GARY R HERBERT E wcunw Drector

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

Permit To Drillkkkkkkkkkkkkkkkkkk

Well Name: Ute Tribal 31-06API Well Number: 43013526290000

Lease Number: 1420H623520Surface Owner: INDIANApproval Date: 1/29/20 14


Authority:Pursuant to Utah Code Ann. 40-6-1 et seq., and Utah Administrative CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of Cause 214-2. The expected producing formation or poolis the GREEN RIVER Formation(s), completion into any other zones will requirefiling a Sundry Notice (Form 9). Completion and commingling of more than onepool will require approval in accordance with R649-3-22.

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

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

Conditions of Approval:State approval of this well does not supercede the required federal approval, whichmust be obtained prior to drilling.


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

• Within 24 hours following the spudding of the well - contact Carol Daniels at801-538-5284

(please leave a voicemail message if not available)ORsubmit an electronic sundry notice (pre-registration required) via the Utah Oil


-

















-

















-
















Gas website at ht tp:/ /oi lgas.ogm.utah.gov

Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas ConservationGeneral Rules will be promptly filed with the Division of Oil, Gas and Mining,including but not l imited to: • Entity Action Form (Form 6) - due within 5 days of spudding the well • Monthly Status Report (Form 9) - due by 5th day of the following calendarm o n t h • Requests to Change Plans (Form 9) - due prior to implementation • Written Notice of Emergency Changes (Form 9) - due within 5 days • Notice of Operations Suspension or Resumption (Form 9) - due prior toimplementa t ion • Report of Water Encountered (Form 7) - due within 30 days after completion • Well Completion Report (Form 8) - due within 30 days after completion orplugging

Approved By:

For John RogersAssociate Director, Oil & Gas

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

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

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

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

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

plugging

Approved By:

For John RogersAssociate Director, Oil &






plugging

Approved By:







plugging

Approved By:







plugging

Approved By:


Fbnn 3160~y~«; RECEIVE~ t FORM APPROVED (August ,-" , OMB No. 1004-0136

~~. '\ ,~~ UNITED STATES Expires July 31, 2010

'oj' \ ~PARTMENT OF THE INTERIOR NOV 0 6 2013 \,)V s 'b-~ UREAU OF LAND MANAGEMENT 5. Lease Serial No.

.' G'f- 1420H623520

0« o"APPLICATION FOR PERMIT TO DRILL OR REEN~LM 6. If Indian, Allottee or Tribe Name

la. Tw.'bfWork: • DRILL o REENTER

CONFIDENTIAL 7. If Unit or CA Agreement, Name and No.

1420H624650

8. Lease Name and Well No.

lb. Type of Well: • Oil Well o Gas Well o Other • Single Zone o Multiple Zone UTE TRIBAL 31-06

2. Name ofOpcrator Contact: ED H TROTTER 9.t;I3e~NDI ~ -6~'f PETROGLYPH OPERATING CO., tell: [email protected]

3a. Address 3b. Phone No. (include area code) 10. Field and Pool, or Exploratory P.O. BOX 607 Ph: 435-789-4120 ANTELOPE CREEK ROOSEVELT, UT 84066 Fx: 435-789-1420

4. Location of Well (Report location clearly and in accordance with any State requirements. *) II. Sec., T., R., M., or Blk. and Survey or Area

At surface SWNE 1989FNL 2150FEL Sec 31 T5S R3W Mer UBM

At proposed prod. zone SENW 1980FNL 1980FWL

14. Distance in miles and direction from nearest town or post office* 12. County or Parish I 13. State 21.3 MILES SOUTHWEST OF MYTON, UTAH DUCHESNE UT

15. Distance from proposed location to nearest property or lease line, ft. (Also to nearest drig. unit line, if any)

16. No. of Acres in Lease 17. Spacing Unit dedicated to this well

1989 640.00

18. Distance from proposed location to nearest well, drilling, 19. Proposed Depth 20. BLMlBIA Bond No. on file completed, applied for, on this lease, ft.

19 6348MD LPM4138335 6181 TVD

21. Elevations (Show whether DF, KB, RT, GL, etc. 22. Approximate date work will stait 23. Estimated duration 6798 GL 12115/2013 45 DAYS

24. Attachments

The following, completed in accordance with the requirements of Onshore Oil and Gas Order No. I, shall be attached to this fonn:

I. Well plat certified by a registered surveyor. 2. A Drilling Plan.

4. Bond to cover the operations unless covered by an existing bond on file (see Item 20 above).

5. Operator certification 3. A Surface Use Plan (if the location is on National Forest System Lands, the SUPO shall be filed with the appropriate Forest Service Office). 6. Such other site specific information and/or plans as may be required by the

authorized officer.

25. Signature (Electronic Submission)

Title DISTRICT MANAGER

Title

Name (printedffyped) LESTER FARNSWORTH Ph: 435-722-2531

Name (PrintedtTyped) Jerry Kenczka Office

Date 10/31/2013

jCJt4 3 0 2014

Application approval does not warrant or certify the applicant holds legal or equitable title to those rights in the subject lease which would entitle the applicant to conduct operations thereon. Conditions of approval, if any, are attached.

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

Additional Operator Remarks (see next page)

Electronic Submission 1225113 verified by the BLM Well Infonnatlon System For PETROGLYPH OPERATING CO., INC., sent to the Vernal

Committed to AFMSS for processing by LESLIE BUHLER on 11/12/2013 ()

~ OPERA-';OR-8UBMITrED ~ OPERATOR-8UBMITTED ~ OPERATOR-8

UDOOM

rm3160 RECEIVEEt FORMAPPROVED(Augu OMB No. 1004-0136

UNITED STATES Expires July 31, 2010

\ PARTMENT OF THE INTERIORUREAU OF LAND MANAGEMENT 5. Lease Serial No.SS 1420H623520

\\APPLICATION FOR PERMIT TO DRILL OR REENSLM 6. If Indian, Allottee or Tribe Name

la. TyÑf Work: g DRILL O REENTER 7. If Unit or CA Agreement, Name and No.CONFIDENTIAL 1420H6246508. Lease Name and Well No.

lb. Type of Well: g Oil Well O Gas Well O Other g Single Zone O Multiple Zone UTE TRIBAL31-06

2. Name of Operator Contact: ED H TROTTER 9. API Well No.PETROGLYPH OPERATING CO., INOsil:[email protected]

3a. Addoss 3b. Phone No. (includearea code) 10. Field and Pool, or ExploratoryP.O. BOX 607 Ph: 435-789-4120 ANTELOPE CREEKROOSEVELT, UT 84066 Fx: 435-789-1420

4. Location of Well (Report location clearly and in accordance with any State requirements.*) 11. Sec., T., R., M., or Blk. and Surveyor Area

At surface SWNE 1989FNL 2150FEL Sec 31 T5S R3W Mer UBMAt proposed prod. zone SENW 1980FNL 1980FWL

14. Distance in miles and direction from nearest town or post office* 12. County or Parish 13. State21.3 MILES SOUTHWEST OF MYTON, UTAH DUCHESNE UT

15. Distance from proposed locationto nearest property or 16. No. of Acres in Lease 17. SpacingUnit dedicated to this welllease line, ft. (Also to nearest drig. unit line, if any)

1989 640.00

18. Distance from proposed location to nearest well, drilling, 19. Proposed Depth 20. BLM/BIA Bond No. on filecompleted, applied for, on this lease, ft.

19 6348 MD LPM41383356181 TVD

21. Elevations (Show whether DF, KB, RT, GL, etc. 22. Approximatedate work will start 23. Estimatedduration6798 GL 12/15/2013 45 DAYS

24. Attachments

The following, completed in accordance with the requirements of Onshore Oil and Gas Order No. 1, shall be attached to this form:

1. Well plat certified by a registered surveyor. 4. Bond to cover the operations unless covered by an existing bond on file (see2. A Drilling Plan. Item 20 above).3. A Surface Use Plan (if the location is on National Forest System Lands, the 5. Operator certification

SUPO shall be filed with the appropriate Forest Service Office). 6. Such other site specific informationand/or plans as may be required by theauthorized officer.

25. Signature Name (Printed/Typed) Date(Electronic Submission) LESTER FARNSWORTH Ph: 435-722-2531 10/31/2013

Title

Appr e Name (Printed/Typed) Jerry Kenczka ][ÏN3O20¾

Application approval does not warrant or certify the applicant holds legal or equitable title to those rights in the subject lease which would entitle the applicant to conductoperationsthereon.Conditionsof approval, if any, are attached.

Title 18 U.S.C. Section 1001 and Title 43 U.S.C. Section 1212,make it a crime for any person knowingly and willfully to make to any departmentor agency of the UnitedStates any false, fictitious or fraudulent statements or representations as to any matter within itsjurisdiction.


Electronic Submission #225113 verlfled by the BLM Well Information SystemFor PETROGLYPH OPERATING CO., INC., sent to the Vernal


" OPERATOR-SUBMITTED " OPERATOR-SUBMITTED " OPERATOR-SUBMITTED "













1989 640.00


19 6348 MD LPM41383356181 TVD


24. Attachments





Title




















1989 640.00


19 6348 MD LPM41383356181 TVD


24. Attachments





Title




















1989 640.00


19 6348 MD LPM41383356181 TVD


24. Attachments





Title








UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT

VERNAL FIELD OFFICE 170 South 500 East VERNAL, UT 84078 (435) 781-4400

CONDITIONS OF APPROVAL FOR APPLICATION FOR PERMIT TO DRILL

Company: Well No:

PETROGLYPH OPERATING CO UTE TRIBAL 31-06

Location: Lease No:

SWNE SEC 31 TOSS R03W 1420H623520 1420H624650 API No: 43-013-52629 Agreement:

OFFICE NUMBER: (435) 781-4400

OFFICE FAX NUMBER: (435) 781-3420

A COpy OF THESE CONDITIONS SHALL BE FURNISHED TO YOUR FIELD REPRESENTATIVE TO INSURE COMPLIANCE

All lease and/or unit operations are to be conducted in such a manner that full compliance is made with the applicable laws, regulations (43 CFR Part 3160), and this approved Application for Permit to Drill including Surface and Downhole Conditions of Approval. The operator is considered fully responsible for the actions of his subcontractors. A copy of the approved APD must be on location during construction, drilling, and completion operations. This permit is approved for a two (2) year period, or until lease expiration, whichever occurs first. An additional extension, up to two (2) years, may be applied for by sundry notice prior to expiration.

NOTIFICATION REQUIREMENTS

Construction Activity (Notify Ute Tribe Energy & Minerals Dept. and BlM Environmental Scientist)

Construction Completion (Notify Ute Tribe Energy & Minerals Dept. and BlM Environmental Scientist)

Spud Notice (Notify BLM Petroleum Engineer)

Casing String & Cementing (Notify BLM Supv. Petroleum Tech.)

BOP & Related Equipment Tests (Notify BLM Supv. Petroleum Tech.)

First Production Notice (Notify BLM Petroleum Engineer)

- The Ute Tribe Energy & Minerals Dept. and BLM Environmental Scientist shall be notified at least 48 hours in advance of any construction activity. The Ute Tribal office is open Monday through Thursday.

- Upon completion of the pertinent APD/ROW construction, notify the Ute Tribe Energy & Minerals Dept. for a Tribal Technician to verify the Affidavit of Completion. Notify the BLM Environmental Scientist prior to moving on the drilling rig.

- Twenty-Four (24) hours prior to spudding the well.

- Twenty-Four (24) hours prior to running casing and cementing all casing strings to:blm ut vn [email protected].

- Twenty-Four (24) hours prior to initiating pressure tests.

- Within Five (5) business days after new well begins or production resumes after well has been off production for more than ninety (90) days.

UNITED STATES DEPARTMENT OF THE INTERIORBUREAU OF LAND MANAGEMENT

VERNAL FIELD OFFICE170 South 500 East VERNAL, UT 84078 (435) 781-4400


Company: PETROGLYPH OPERATING CO Location: SWNE SEC 31 TOSS RO3WWell No: UTE TRIBAL 31-06 Lease No: 1420H623520API No: 43-013-52629 Agreement: 1420H624650



A COPY OF THESE CONDITIONS SHALL BE FURNISHED TO YOURFIELD REPRESENTATIVE TO INSURE COMPLIANCE

All lease and/or unit operations are to be conducted in such a manner that full compliance is made with theapplicable laws, regulations (43 CFR Part 3160), and this approved Application for Permit to Drill includingSurface and Downhole Conditions of Approval. The operator is considered fully responsible for the actions of hissubcontractors. A copy of the approved APD must be on location during construction, drilling, and completionoperations. This permit is approved for a two (2) year period, or until lease expiration, whichever occursfirst. An additional extension, up to two (2) years, may be applied for by sundry notice prior to expiration.


Construction Activity - The Ute Tribe Energy & Minerals Dept. and BLM Environmental(Notify Ute Tribe Energy & Minerals Scientist shall be notified at least 48 hours in advance of anyDept. and BLM Environmental construction activity. The Ute Tribal office is open MondayScientist) throughThursday.

Construction Completion - Upon completion of the pertinent APDIROW construction, notify(Notify Ute Tribe Energy & Minerals the Ute Tribe Energy & Minerals Dept. for a Tribal Technician toDept. and BLM Environmental verify the Affidavit of Completion. Notify the BLM EnvironmentalScientist) Scientist priorto moving on the drilling rig.

Spud Notice - Twenty-Four (24) hours prior to spudding the well.(Notify BLM Petroleum Engineer)

Casing String & Cementing - Twenty-Four (24) hours prior to running casing and cementing(Notify BLM Supv. Petroleum Tech.) all casing strings to:blm ut vn [email protected].

BOP & Related Equipment Tests - Twenty-Four (24) hours prior to initiating pressure tests.(Notify BLM Supv. Petroleum Tech.)

First Production Notice - Within Five (5) business days after new well begins or(Notify BLM Petroleum Engineer) production resumes after well has been off production for more

than ninety (90)
















than ninety (90)
















than ninety (90)
















than ninety (90)

SURFACE USE PROGRAM CONDITIONS OF APPROVAL (COAs)

Page 2 of6 Well: UTE TRIBAL 31-06

6/23/2014

• All areas of disturbance (including surface pipelines) must have appropriate surface use agreements or approvals in place with the proper owner and/or agency before such action is started.

• The conditions of approval, as set forth by those owners and/or agencies, shall be adhered to.

Page 2 of 6Well: UTE TRIBAL 31-06

6/23/2014

SURFACE USE PROGRAMCONDITIONS OF APPROVAL (COAs)

• All areas of disturbance (including surface pipelines) must have appropriate surface useagreements or approvals in place with the proper owner and/or agency before such action isstarted.

• The conditions of approval, as set forth by those owners and/or agencies, shall be adhered


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DOWNHOLE PROGRAM CONDITIONS OF APPROVAL (COAs)

SITE SPECIFIC DOWNHOLE COAs:

1. Gamma Ray Log shall be run from Total Depth to Surface.

2. CBL will be run from TD to TOC.

3. Cement for the surface casing will be circulated to the surface.

4. Cement for long-string shall be circulated 200' above surface casing shoe.

5. Variance Granted, variance for Air-drilling is granted per APD

Page 3 of6 Well: UTE TRIBAL 31-06

6/23/2014

All provisions outlined in Onshore Oil & Gas Order #2 Drilling Operations shall be strictly adhered to. The following items are emphasized:

DRILLING/COMPLETION/PRODUCING OPERATING STANDARDS

• The spud date and time shall be reported orally to Vernal Field Office within 24 hours of spudding.

• Notify Vernal Field Office Supervisory Petroleum Engineering Technician at least 24 hours in advance of casing cementing operations and BOPE & casing pressure tests.

• All requirements listed in Onshore Order #2 III. E. Special Drilling Operations are applicable for air drilling of surface hole.

• Blowout prevention equipment (BOPE) shall remain in use until the well is completed or abandoned. Closing unit controls shall remain unobstructed and readily accessible at all times. Choke manifolds shall be located outside of the rig substructure.

• All BOPE components shall be inspected daily and those inspections shall be recorded in the daily drilling report. Components shall be operated and tested as required by Onshore Oil & Gas Order No. 2 to insure good mechanical working order. All BOPE pressure tests shall be performed by a test pump with a chart recorder and NOT by the rig pumps. Test shall be reported in the driller's log.

• BOP drills shall be initially conducted by each drilling crew within 24 hours of drilling out from under the surface casing and weekly thereafter as specified in Onshore Oil & Gas Order NO.2.

• Casing pressure tests are required before drilling out from under all casing strings set and cemented in place.

• No aggressive/fresh hard-banded drill pipe shall be used within casing.

• Cement baskets shall not be run on surface casing.


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DOWNHOLE PROGRAMCONDITIONS OF APPROVAL (COAs)







AII provisions outlined in Onshore Oil & Gas Order #2 Drilling Operations shall be strictlyadhered to. The following items are emphasized:

DRILLINGICOMPLETIONIPRODUCING OPERATING STANDARDS

• The spud date and timeshall be reported orallyto Vernal Field Office within24 hours ofspudding.

• Notify Vernal Field Office Supervisory Petroleum Engineerinq Technician at least 24 hours inadvance of casinq cementing operations and BOPE & casing pressure tests.

• All requirements listed in Onshore Order #2 III. E. Special Drilling Operations are applicable forair drilling of surface hole.

• Blowout prevention equipment (BOPE) shall remain in use untilthe well is completed orabandoned. Closing unit controls shall remain unobstructed and readily accessible at all times.Choke manifolds shall be located outside of the rig substructure.

• All BOPE components shall be inspected daily and those inspections shall be recorded in thedaily drilling report. Components shall be operated and tested as required by Onshore Oil&Gas Order No. 2 to insure good mechanical workingorder. All BOPE pressure tests shall beperformed by a test pump with a chart recorder and _NOTby the rig pumps. Test shall bereported in the driller's log.

• BOP drills shall be initially conducted by each drilling crew within 24 hours of drilling out fromunder the surface casing and weekly thereafteras specified in Onshore Oil& Gas Order No. 2.

• Casing pressure tests are required before drilling out from under all casing strings set andcemented in place.

• No aggressivelfresh hard-banded drill pipe shall be used within casing.

• Cement baskets shall not be run on surface


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of6 Well: UTE TRIBAL 31-06

6/23/2014

• The operator must report all shows of water or water-bearing sands to the BlM. If flowing water is encountered it must be sampled, analyzed, and a copy of the analyses submitted to the BlM Vernal Field Office.

• The operator must report encounters of all non oil & gas mineral resources (such as Gilsonite, tar sands, oil shale, trona, etc.) to the Vernal Field Office, in writing, within 5 working days of each encounter. Each report shall include the well name/number, well location, date and depth (from KB or Gl) of encounter, vertical footage of the encounter and, the name of the person making the report (along with a telephone number) should the BlM need to obtain additional information.

• A complete set of angular deviation and directional surveys of a directional well will be submitted to the Vernal BlM office engineer within 30 days of the completion of the well.

• While actively drilling, chronologic drilling progress reports shall be filed directly with the BlM, Vernal Field Office on a weekly basis in sundry, letter format or e-mail to the Petroleum Engineers until the well is completed.

• A cement bond log (CBl) will be run from the production casing shoe to the top of cement and shall be utilized to determine the bond quality for the production casing. Submit a field copy of the CBl to this office.

• Please submit an electronic copy of all other logs run on this well in CD (compact disc) format to the Vernal BlM Field Office. This submission will supersede the requirement for submittal of paper logs to the BlM.

• There shall be no deviation from the proposed drilling, completion, and/or workover program as approved. Safe drilling and operating practices must be observed. Any changes in operation must have prior approval from the BlM Vernal Field Office.

OPERATING REQUIREMENT REMINDERS:

• All wells, whether drilling, producing, suspended, or abandoned, shall be identified in accordance with 43 CFR 3162.6. There shall be a sign or marker with the name of the operator, lease serial number, well number, and surveyed description of the well.

• For information regarding production reporting, contact the Office of Natural Resources Revenue (ONRR) at www.ONRR.gov.

• Should the well be successfully completed for production, the BlM Vernal Field office must be notified when it is placed in a producing status. Such notification will be by written communication and must be received in this office by not later than the fifth business day following the date on which the well is placed on production. The notification shall provide, as a minimum, the following informational items:

o Operator name, address, and telephone number.

o Well name and number.

o Well location (XX, Sec., Twn, Rng, and P.M.).


6/23/2014

• The operator must report all shows of water or water-bearing sands to the BLM. Ifflowing wateris encountered it must be sampled, analyzed, and a copy of the analyses submitted to the BLMVernal Field Office.

• The operator must report encounters of all non oil& gas mineral resources (such as Gilsonite,tar sands, oil shale, trona, etc.) to the Vernal Field Office, in writing, within 5 working days ofeach encounter. Each report shall include the well namelnumber, well location, date and depth(from KB or GL) of encounter, vertical footage of the encounter and, the name of the personmaking the report (along with a telephone number) should the BLM need to obtain additionalinformation.

• A complete set of angular deviation and directional surveys of a directional well will besubmitted to the Vernal BLMoffice engineer within 30 days of the completion of the well.

• While actively drilling, chronologic drilling progress reports shall be filed directly with the BLM,Vernal Field Office on a weekly basis in sundry, letter format or e-mail to the PetroleumEngineers untilthewell is completed.

• A cement bond log (CBL) will be run from the production casing shoe to the top of cement andshall be utilizedto determine the bond quality for the production casing. Submit a field copy ofthe CBL to this office.

• Please submit an electronic copy of all other logs run on this well in CD (compact disc)format to the Vernal BLM Field Office. This submission will supersede the requirementfor submittal of paper logs to the BLM.

• There shall be no deviation from the proposed drilling, completion, and/or workover program asapproved. Safe drilling and operating practices must be observed. Any changes in operationmust have prior approval from the BLMVernal Field Office.


• All wells, whether drilling, producing, suspended, or abandoned, shall be identified inaccordance with 43 CFR 3162.6. There shall be a sign or marker with the name of the operator,lease serial number, well number, and surveyed description of the well.

• For information regarding production reporting, contact the Office of Natural ResourcesRevenue (ONRR) at www.ONRR.gov.

• Should the well be successfully completed for production, the BLMVernal Field office must benotified when it is placed in a producing status. Such notification will be by writtencommunication and must be received in this office by not later than the fifth business dayfollowing the date on which the well is placed on production. The notificationshall provide, as aminimum, the following informational items:

o Operator name, address, and telephonenumber.


o Well location (¼¼,Sec., Twn, Rng, and


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o Date well was placed in a producing status (date of first production for which royalty will be paid).

o The nature of the well's production, (i.e., crude oil, or crude oil and casing head gas, or natural gas and entrained liquid hydrocarbons).

o The Federal or Indian lease prefix and number on which the well is located; otherwise the non-Federal or non-Indian land category, i.e., State or private.

o Unit agreement and/or participating area name and number, if applicable.

o Communitization agreement number, if applicable.

• Any venting or flaring of gas shall be done in accordance with Notice to Lessees (NTL) 4A and needs prior approval from the BLM Vernal Field Office.

• All undesirable events (fires, accidents, blowouts, spills, discharges) as specified in NTL 3A will be reported to the BLM, Vernal Field Office. Major events, as defined in NTL3A, shall be reported verbally within 24 hours, followed by a written report within 15 days. "Other than Major Events" will be reported in writing within 15 days. "Minor Events" will be reported on the Monthly Report of Operations and Production.

• Whether the well is completed as a dry hole or as a producer, "Well Completion and Recompletion Report and Log" (BLM Form 3160-4) shall be submitted not later than 30 days after completion of the well or after completion of operations being performed, in accordance with 43 CFR 3162.4-1. Two copies of all logs run, core descriptions, and all other surveys or data obtained and compiled during the drilling, workover, and/or completion operations, shall be filed on BLM Form 3160-4. Submit with the well completion report a geologic report including, at a minimum, formation tops, and a summary and conclusions. Also include deviation surveys, sample descriptions, strip logs, core data, drill stem test data, and results of production tests if performed. Samples (cuttings, fluid, and/or gas) shall be submitted only when requested by the BLM, Vernal Field Office.

• All off-lease storage, off-lease measurement, or commingling on-lease or off-lease, shall have prior written approval from the BLM Vernal Field Office.

• Oil and gas meters shall be calibrated in place prior to any deliveries. The BLM Vernal Field Office Petroleum Engineers will be provided with a date and time for the initial meter calibration and all future meter proving schedules. A copy of the meter calibration reports shall be submitted to the BLM Vernal Field Office. All measurement facilities will conform to the API standards for liquid hydrocarbons and the AGA standards for natural gas measurement. All measurement points shall be identified as the point of sale or allocation for royalty purposes.

• A schematic facilities diagram as required by Onshore Oil & Gas Order No. 3 shall be submitted to the BLM Vernal Field Office within 30 days of installation or first production, whichever occurs first. All site security regulations as specified in Onshore Oil & Gas Order No.3 shall be adhered to. All product lines entering and leaving hydrocarbon storage tanks will be effectively sealed in accordance with Onshore Oil & Gas Order No.3.


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o Date well was placed in a producing status (date of first production for which royaltywillbe paid).

o The nature of the well's production, (i.e., crude oil,or crude oil and casing head gas, ornatural gas and entrained liquid hydrocarbons).

o The Federal or Indian lease prefix and number on which the well is located; otherwisethe non-Federal or non-Indian land category, i.e., State or private.



• Any venting or flaring of gas shall be done in accordance with Notice to Lessees (NTL) 4A andneeds prior approval from the BLMVernal Field Office.

• All undesirable events (fires, accidents, blowouts, spills, discharges) as specified in NTL 3A willbe reported to the BLM, Vernal Field Office. Major events, as defined in NTL3A, shall bereported verbally within 24 hours, followed by a written report within 15 days. "Other than MajorEvents" willbe reported in writingwithin 15 days. "Minor Events" will be reported on theMonthly Report of Operations and Production.

• Whether the well is completed as a dry hole or as a producer, "Well Completion andRecompletion Report and Log" (BLM Form 3160-4) shall be submitted not later than 30 daysafter completion of the well or after completion of operations being performed, in accordancewith 43 CFR 3162.4-1. Two copies of all logs run, core descriptions, and all other surveys ordata obtained and compiled during the drilling, workover, and/or completion operations, shall befiled on BLM Form 3160-4. Submit with the well completion report a geologic report including,at a minimum, formation tops, and a summary and conclusions. Also include deviation surveys,sample descriptions, strip logs, core data, drill stem test data, and results of production tests ifperformed. Samples (cuttings, fluid, and/or gas) shall be submitted only when requested by theBLM, Vernal Field Office.

• All off-lease storage, off-lease measurement, or comminglingon-lease or off-lease, shall haveprior written approval from the BLMVernal Field Office.

• Oiland gas meters shall be calibrated in place prior to any deliveries. The BLMVernal FieldOffice Petroleum Engineers will be provided with a date and timefor the initial meter calibrationand all future meter proving schedules. A copy of the meter calibration reports shall besubmitted to the BLMVernal Field Office. All measurement facilities will conform to the APIstandards for liquid hydrocarbons and the AGAstandards for natural gas measurement. Allmeasurement points shall be identified as the point of sale or allocation for royalty purposes.

• A schematic facilities diagram as required by Onshore Oil & Gas Order No. 3 shall be submittedto the BLMVernal Field Office within 30 days of installation or first production, whichever occursfirst. All site security regulations as specified in Onshore Oil & Gas Order No. 3 shall beadhered to. All product lines entering and leaving hydrocarbon storage tanks will be effectivelysealed in accordance with Onshore Oil & Gas Order No.


6/23/2014













6/23/2014













6/23/2014













6/23/2014

• Any additional construction, reconstruction, or alterations of facilities, including roads, gathering lines, batteries, etc., which will result in the disturbance of new ground, shall require the filing of a suitable plan and need prior approval of the BLM Vernal Field Office. Emergency approval may be obtained orally, but such approval does not waive the written report requirement.

• No location shall be constructed or moved, no well shall be plugged, and no drilling or workover equipment shall be removed from a well to be placed in a suspended status without prior approval of the BLM Vernal Field Office. If operations are to be suspended for more than 30 days, prior approval of the BLM Vernal Field Office shall be obtained and notification given before resumption of operations.

• Pursuant to Onshore Oil & Gas Order No.7, this is authorization for pit disposal of water produced from this well for a period of gO days from the date of initial production. A permanent disposal method must be approved by this office and in operation prior to the end of this gO-day period. In order to meet this deadline, an application for the proposed permanent disposal method shall be submitted along with any necessary water analyses, as soon as possible, but no later than 45 days after the date of first production. Any method of disposal which has not been approved prior to the end of the authorized gO-day period will be considered as an Incident of Noncompliance and will be grounds for issuing a shut-in order until an acceptable manner for disposing of said water is provided and approved by this office.

• Unless the plugging is to take place immediately upon receipt of oral approval, the Field Office Petroleum Engineers must be notified at least 24 hours in advance of the plugging of the well, in order that a representative may witness plugging operations. If a well is suspended or abandoned, all pits must be fenced immediately until they are backfilled. The "Subsequent Report of Abandonment" (Form BLM 3160-5) must be submitted within 30 days after the actual plugging of the well bore, showing location of plugs, amount of cement in each, and amount of casing left in hole, and the current status of the surface restoration.


6/23/2014

• Any additional construction, reconstruction, or alterations of facilities, including roads, gatheringlines, batteries, etc., which will result in the disturbance of new ground, shall require the filing ofa suitable plan and need prior approval of the BLMVernal Field Office. Emergency approvalmay be obtained orally, but such approval does not waive the written report requirement.

• No location shall be constructed or moved, no well shall be plugged, and no drilling or workoverequipment shall be removed from a well to be placed in a suspended status without priorapproval of the BLMVernal Field Office. Ifoperations are to be suspended for more than 30days, prior approval of the BLMVernal Field Office shall be obtained and notificationgivenbefore resumption of operations.

• Pursuant to Onshore Oil & Gas Order No. 7, this is authorization for pit disposal of waterproduced from this well for a period of 90 days from the date of initial production. A permanentdisposal method must be approved by this officeand in operation prior to the end of this 90-dayperiod. In order to meet this deadline, an application for the proposed permanent disposalmethod shall be submitted along with any necessary water analyses, as soon as possible, butno later than 45 days after the date of first production. Any method of disposal which has notbeen approved prior to the end of the authorized 90-day period will be considered as an Incidentof Noncompliance and will be grounds for issuing a shut-in order untilan acceptable manner fordisposing of said water is provided and approved by this office.

• Unless the plugging is to take place immediately upon receipt of oral approval, the Field OfficePetroleum Engineers must be notified at least 24 hours in advance of the plugging of the well, inorder that a representative may witness plugging operations. If a well is suspended orabandoned, all pits must be fenced immediately until they are backfilled. The "SubsequentReport of Abandonment" (Form BLM 3160-5) must be submitted within 30 days after the actualplugging of the well bore, showing location of plugs, amount of cement in each, and amount ofcasing left in hole, and the current status of the surface


6/23/2014






6/23/2014






6/23/2014





RECEIVED: Aug. 19, 2014


DIVISION OF OIL, GAS, AND MINING

FORM 9

5.LEASE DESIGNATION AND SERIAL NUMBER: 1420H623520

SUNDRY NOTICES AND REPORTS ON WELLS

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

6. IF INDIAN, ALLOTTEE OR TRIBE NAME: UTE

7.UNIT or CA AGREEMENT NAME: ANTELOPE CREEK

1. TYPE OF WELL Oil Well

8. WELL NAME and NUMBER: Ute Tribal 31-06

2. NAME OF OPERATOR: PETROGLYPH OPERATING CO

9. API NUMBER: 43013526290000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 960 Broadway Avenue, Ste 500 , Boise, ID, 83703 208 685-7685 Ext

9. FIELD and POOL or WILDCAT: ANTELOPE CREEK

4. LOCATION OF WELL FOOTAGES AT SURFACE: 1989 FNL 2150 FEL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: SWNE Section: 31 Township: 05.0S Range: 03.0W Meridian: U

COUNTY: DUCHESNE

STATE: UTAH

11.

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

TYPE OF SUBMISSION TYPE OF ACTION

NOTICE OF INTENTApproximate date work will start:

SUBSEQUENT REPORTDate of Work Completion:

SPUD REPORTDate of Spud:

8 /19 /2014

DRILLING REPORTReport Date:

ACIDIZE ALTER CASING CASING REPAIR

CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME

CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

DEEPEN FRACTURE TREAT NEW CONSTRUCTION

OPERATOR CHANGE PLUG AND ABANDON PLUG BACK

PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION

REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON

TUBING REPAIR VENT OR FLARE WATER DISPOSAL

WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION

WILDCAT WELL DETERMINATION OTHER OTHER:

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

This well was spud on 8/19/2014 at approximately 7:00 A.M. Using aBucket rig provided by Craig's Roustabout Service, Vernal Utah, we set60' of 16" Conductor. For additional information please contact our

staff at 435-722-2531.

NAME (PLEASE PRINT) PHONE NUMBER Rodrigo Jurado 435 722-5302

TITLE Regulatory & Compliance Spc

SIGNATURE N/A

DATE 8 /19 /2014

August 20, 2014

Sundry Number: 54670 API Well Number: 43013526290000Sundry Number: 54670 API Well Number: 43013526290000

FORM 9STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING 1420H623520

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

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

FOR PERMIT TO DRILL form for such proposals. ANTELOPE CREEK

1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well Ute Tribal 31-06

2. NAME OF OPERATOR: 9. API NUMBER:PETROGLYPH OPERATING CO 4301 3526290000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:960 Broadway Avenue, Ste 500 , Boise, ID, 83703 208 685-7685 Ext ANTELOPE CREEK

4. LOCATION OF WELL COUNTY:FOOTAGES AT SURFACE: DUCHESNE

1989 FNL 2150 FELQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:

QtrlQtr: SWNE Section: 31 Township: 05.0S Range: 03.0W Meridian: U UTAH

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


ACI DIZE ALTER CASING CASING REPAIR

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


SUBSEQUENT REPORTDate of Work Completion: DEEPEN FRACTURE TREAT NEW CONSTRUCTION


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

8/ 19 /2 0 14 REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


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

WILDCATWELLDETERMINATION OTHER OTHER:


This well was spud on 8/19/2014 at approximately 7:00 A.M. Using a Accepted by theBucket rig provided by Craig's Roustabout Service, Vernal Utah, we set Utah Division of

60' of 16" Conductor. For additional information please contact our Oil, Gas and Mining

staff at 435-722-2531. FOR RECORD ONLYAugust 20, 2014

NAME (PLEASE PRINT) PHONE NUMBER TITLERodrigo Jurado 435 722-5302 Regulatory & Compliance Spc

SIGNATURE DATEN/A 8/19/2014

RECEIVED: Aug. 19,

Sundry Number: 54670 API Well Number: 43013526290000

FORM 9STATE OF UTAH





























RECEIVED: Aug. 19,


FORM 9STATE OF UTAH





























RECEIVED: Aug. 19,


FORM 9STATE OF UTAH





























RECEIVED: Aug. 19,

STATE OF UTAH DEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL. GAS AND MINING

ENTITY ACTION FORM

FORM6

Operator: Petroglyph Operating Company Operator Account Number: N 3800

Address: P.O. Box 607

city Roosevelt

state UT zip 84066 Phone Number: (435) 722-2531

Well 1

API Number Well Name QQ Sec Twp Rng County

4301352598 Ute Tribal 31-01 NENE 31 5S 3W Duchesne

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

B 99999 12216 8/15/2014 C6l9.-11111 Comments:

Please add well to exiting Ute Tribal 30-15 Tank Battery. elf' i1 H"'ii" ,., .; ,: ~I· Ij ,,,,,,. , f C'").QAv lt1.u)· ; '1,

...... r....-, •. t

Well 2


4301352629 Ute Tribal 31-06 SWNE 31 5S 3W Duchesne

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

B 99999 12216 8/19/2014 C() I c;2 \ I P-I Comments: Please add well to existing Ute Tribal 30-15 Tank Battery,

GQiD./ !'l?'1f;"'Jl-, 6/' I :J!., ... ''t \,r:

'c' " :

W 113 e ~. 'III


4301352624 Ute Tribal 29-130 SWSW 29 5S 3W Duchesne

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

B 99999 12216 8/20/2014 .PJ .. -;2(LL4 Comments: P d II ., T 'b 15 T B lease ad we to eXisting Ute n al 30- ank attery. ((i'. ~V

ACTION CODeS: A - Establish new entity for new well (Single well only)

B - Add new well to eXisting entity (group or unit well)

C - Re-asslgn well from one eXisting entity to another eXisting entity

D - Re-asslgn well from one eXlstAEeEtVEBtlty E - Other (Explain In 'comments' section)

AUG 2 1 2014 (S/20uO}

Div. of Oil. ~~g ~ ~4jnin~

j(~ '~'~~I'~' , • " • ,J l~ .. . J,

Rodrigo Jurado

?~'~~~-----------------8120/2014

Date

STATEOFUTAH FORM6DEPARTMENT OF NATURAL RESOURCES


ENTITY ACTION FORM



city Roosevelt


Well 1

API Number Well Name QQ Sec Twp Rng County4301352598 Ute Tribal 31-01 NENE 31 SS 3W Duchesne

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

B 99999 12216 8/15/2014

Comments Please add well to exiting Ute Tribal 30-15 Tank Battery. pg3

Well 2


4301352629 Ute Tribal 31-06 SWNE 31 SS 3W Duchesne


B 99999 12216 8/19/2014

Comments e add well to existing Ute Tribal 30-15 Tank Battery.

Well 3

API Number Wet! Name QQ Sec Twp Rng County4301352624 Ute Tribal 29-13Q SWSW 29 5S 3W Duchesne


B 99999 12216 8/20/2014Comments:

Please add well to existing Ute Tribal 30-15 Tank Battery.

ACTION CODES:A - Establish new entity for new well (single well only) Rodrigo Jurado

B - Add new well to existing entity (groupor unit well) NameC - Re-assign well from one existing entity to another existing entityD - Re-assign well from one exist tity |E - Other (Explain in comments' section) latory Compliance Spc. 8/20/2014

AUS2 1 2014 ""' °•**

(5/2000)

Div.ofOil,Gas &



ENTITY ACTION FORM



city Roosevelt


Well 1



B 99999 12216 8/15/2014


Well 2




B 99999 12216 8/19/2014


Well 3



B 99999 12216 8/20/2014

Comments:Please add well to existing Ute Tribal 30-15 Tank Battery.



AUS2 1 2014 ""' °•**

(5/2000)

Div.ofOil,Gas &



ENTITY ACTION FORM



city Roosevelt


Well 1



B 99999 12216 8/15/2014


Well 2




B 99999 12216 8/19/2014


Well 3



B 99999 12216 8/20/2014Comments:

Please add well to existing Ute Tribal 30-15 Tank Battery.



AUS2 1 2014 ""' °•**

(5/2000)

Div.ofOil,Gas &

CONFIDENTIAL

BLM - Vernal Field Office - Notification Form

Operator Petroglyph Operating Rig Name/# Craig's IPro Petro Submitted By Rodrigo Jurado Phone Number 435-722-5302 Well Name/Number Ute Tribal 31-06 Qtr/Qtr SWINE Section 31 Township 5S Range _3W_ Lease Serial Number 14-20-H62-3520 API Number _43-013-52629 _____ _

Spud Notice - Spud is the initial spudding of the well, not drilling out below a casing string.

Date/Time __ _ __ AMD PMD

Casing - Please report time casing run starts, not cementing times. ~ Surface Casing D Intermediate Casing D Production Casing D Liner D Other

Date/Time 08/20/2014

BOPE

07:00 AM D PM ~

D Initial BOPE test at surface casing pOint D BOPE test at intermediate casing point D 30 day BOPE test D Other

Date/Time __ _ ___ AMD PMD

Remarks We plan to run +1- 500' of 8-5/8" J-55 Sfc Casing at the time indicated. (Sent 8/19/2014 @ 4:00 P.M.)

CONFilENR


Operator Petroglyph Operatina Rig Name/# Craiq's /Pro PetroSubmitted By Rodriqo Jurado Phone Number 435-722-5302Well Name/Number Ute Tribal 31-06Qtr/Qtr SW/NE Section _3_1 Township 5S Range _3WLease Serial Number 14-20-H62-3520API Number _43-013-52629

Spud Notice - Spud is the initial spudding of the well, not drillingout below a casing string.

Date/Time AM PM

Casina - Please report time casing run starts, not cementingtimes.

Surface CasingIntermediate CasingProduction CasingLinerotherDate/Time 08/20/2014 07:00 AM PM

BOPEInitial BOPE test at surface casing pointBOPEtest at intermediate casing point30 day BOPEtestOther

Date/Time AM PM

Remarks We plan to run +/- 500' of 8-5/8" J-55 Sfc Casinq at thetime indicated. (Sent 8/19/2014 @4:00

CONFilENR




Date/Time AM PM




Date/Time AM PM


CONFilENR




Date/Time AM PM




Date/Time AM PM


CONFIDENTlAL


Operator Petroglyph Operating Co. Rig Name/ # Capstar 334 Submitted By Geno Rowland Phone Number 970-361-3271 Well Name/Number U~tll.¥.e....LT..!..!.ri~bad.LI..x.3.L.1-..x.06x--_________ _ Qtr/Qtr SWINE Section 31 Township 5S Range3"'-1w~_ Lease Serial Number ..L...14.1...o-2=.:=0"--I..I.H6X.t2_-3~5~2LX.0 _________ _ APINumber4~3_-~01~3~-5_2~6~29~ __________________ __

SQud Notice - Spud is the initial spudding of the well, not drilling out below a casing string.

Date/Time ____ _ ___ AMD PMD

Casing - Please report time casing run starts, not cementing times.

Surface Casing Intermediate Casing Production Casing Liner Other

Date/Time 09/07/2014

BOPE

02:00 AM [Z] PM D

§ Initial BOPE test at surface casing point ~OPE test at intermediate casing point 30 day BOPE test

o Other

Date/Time ____ _ ___ AMD PMD

Remarks Intensions are to run a 5-1/2" J-55 15.50 #/ft. Production String to a Shoe depth of 6377' MD (.(8). d

Print Form CONFllENTIAL

BLM- Vernal Field Office - Notification Form

Operator Petroglyph Operating Co- Rig Name/# Capstar 334Submitted By Geno Rowland Phone Number 970-361-3271Well Name/Number UteTribal31-06Qtr/QtrSWINE Section 31 Township ss Range 3WLease Serial Number 14-20-H62-3520API Number 43-013-526?9


Date/Time AM PM


Surface CasingIntermediate CasingProduction CasingLinerOther

Date/Time 09/07/2014 02:00 AM PM

BOPEInitial BOPEtest at surface casing pointBOPE test at intermediate casing point30 day BOPE testOther

Date/Time AM PM

Intensions are to run a 5-1/2" J-55 15.50 #lft. Production

CONFllENTIAL

BLM- Vernal Field Office - Notification Form

Operator Petroglyph Operating Co- Rig Name/# Capstar 334Submitted By Geno Rowland Phone Number 970-361-3271Well Name/Number UteTribal31-06Qtr/QtrSWINE Section 31 Township ss Range 3WLease Serial Number 14-20-H62-3520API Number 43-013-526?9


Date/Time AM PM


Surface CasingIntermediate CasingProduction CasingLinerOther

Date/Time 09/07/2014 02:00 AM PM

BOPEInitial BOPEtest at surface casing pointBOPE test at intermediate casing point30 day BOPE testOther

Date/Time AM PM

Intensions are to run a 5-1/2" J-55 15.50 #lft. Production

RECEIVED: Sep. 29, 2014

FEDERAL APPROVAL OF THIS ACTION IS NECESSARY



FORM 9









9. API NUMBER: 43013526290000




COUNTY: DUCHESNE

STATE: UTAH

11.




10 /6 /2014















Please see attached.



SIGNATURE N/A

DATE 9 /29 /2014

September 29, 2014

Sundry Number: 56025 API Well Number: 43013526290000Sundry Number: 56025 API Well Number: 43013526290000FEDERAL APPROVAL OF THIS ACTION IS NECESSARY

FORM 9STATE OF UTAH






2. NAME OF OPERATOR: 9. API NUMBER:PETROGLYPH OPERATING CO 43013526290000







ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT

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

10/6/2014CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate of Work Completion:


PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONSPUD REPORT

Date of Spud: REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


DRILLING REPORT WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSIONReport Date:



Please see attached. Accepted by theUtah Division of

Oil, Gas and Mining

Date:



RECEIVED: Sep. 29,

Sundry Number: 56025 API Well Number: 43013526290000FEDERAL APPROVAL OF THIS ACTION IS NECESSARY

FORM 9STATE OF UTAH













ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT

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

10/6/2014CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate of Work Completion:


PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATIONSPUD REPORT

Date of Spud: REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


DRILLING REPORT WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSIONReport Date:



Please see attached. Accepted by theUtah Division of

Oil, Gas and Mining

Date:



RECEIVED: Sep. 29,

RECEIVED: Sep. 29, 2014


STATE OF UTAH FORM 9DEPARTMENTOFNATURALRESOURCES

DIVISION OF OIL, GAS AND MINING 5 LEASEDEStGNATIONANÒSERIALNUMBER:

1420H6235206 iF INDIAN. ALLOTTEE OR TRIBE NAMESUNDRY NOTICES AND REPORTS ON WELLS Ute Indian Tribe7 UNITor CA ÀGREEMENT NÁMEDo not use this form for proposals to drìîl new wells, significantly deepen existing wells below current bottom-hole depth, reenter plugged wells, or t° 1420H624650drill horizontal laterais. Use APPLICATION FOR PERMIT TO DRILL form for such proposals,

1. TYPE OF WELLOIL WELL GAS WELL OTHER

8 WEÉ AbMEa NUOM68ER

2 NAMEOF OPERATOR: 9 API NUMBER:Petroglyph Operating Company Inc. 4301352629

3 ADDRESS OF OPERATOR: PHONE NUMBER 10. FIELD AND POOL, OR WILDCATP.O. Box 607 Roosevelt UT 84066 (435) 722-2531 Antelope Creek

4 LOCATION OF WELL

FOOTAGESATSURFACE 1989' FNL, 2150' FEL COUNTY Duchesne

QTRIOTR, SECTION, TOWNSHiP. RANGE. MERIDIAN: SWNE 31 SS 3W U STATE

UTAH

CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE. REPORT, OR OTHER DATATYPE OF SUBMISSION TYPE OF ACTION

O ACIDiZE DEEPEN REPERFORATE CURRENT FORMATIONNOTICE OF INTENT(Submit in Duphcate) ALTER CASING FRACTURE TREAT SIDETRACK TO REPAIR WELL

Approximate date work will start: CASING REPAIR NEW CONSTRUCTION TEMPORARILY ABANDON

10/6/2014 CHANGE TO PREVIOUS PLANS OPERATOR CHANGE TUBING REPAIR

CHANGE TUBING PLUG AND ABANDON VENT OR FLARE

O SUBSEQUENT REPORT CHANGE WELL NAME PLUG BACK WATER DISPOSAL(Submit Original Form Only)

CHANGE WELL STATUS PRODUCTION (START/RESUME) WATER SHUT-OFFDate of work completion:

O COMMINGLEPRODUCING FORMATIONS RECLAMATIONOF WELL SITE OTHER:

O CONVERT WELL TYPE RECOMPLETE -OlFFERENT FORMATION

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

On or around 10/6/2014, depending on equipment availability, Petroglyph Operating intends to perforate and fracture treat thefollowing: 4165-77, 4777-79, 4806-09, 4836-40, 4907-09, 4912-14, 4931-40, 5049-55, 5060-62, 5065-71, 5180-83, 5205-09,5273-75, 5286-89, 5332-44, 5347-56, 5384-86, 5394-96, 5398-5400, 5406-08, 5420-22, 5424-26, 5573-76, 5582-86, 5610-15,5660-64, 5680-86, 5693-5703, 5706-13 & 5744-46. We will perforate at 4 shot per foot and isolate zones using Halliburton 8KComposite Plugs. We plan complete the following stages:5,573-5,746: 39,200 Gals of fluid containing 70,000#'s of sand,5,273-5,426: 47,600 Gals of fluid containing 85,000#'s of sand,5,180-5,209: 14,000 Gals of fluid containing 25,000#'s of sand,5,049-5,071: 28,000 Gals of fluid containing 50,000#'s of sand,4,907-4,940: 19,600 Gals of fluid containing 35,000#'s of sand,4,777-4,840: 16,800 Gals of fluid containing 30,000#'s of sand,4,1654,177: 16,800 Gals of fluid containing 30,000#'s of sand.This plan is tentative and willbe adjusted as needed during completion operations. Volumes and amounts of sand are onlyestimates, actual figures will be reported at a later date, All plugs will be drilled out and and the well swabbed if necessary.

NAME (PLEASE PRINT) Rodr go Jurado Regulatory Compliance Specialist

SIGNATURE 9:29/2014


STATE OF UTAH FORM 9DEPARTMENTOFNATURALRESOURCES

DIVISION OF OIL, GAS AND MINING 5 LEASEDEStGNATIONANÒSERIALNUMBER:

1420H6235206 iF INDIAN. ALLOTTEE OR TRIBE NAMESUNDRY NOTICES AND REPORTS ON WELLS Ute Indian Tribe7 UNITor CA ÀGREEMENT NÁMEDo not use this form for proposals to drìîl new wells, significantly deepen existing wells below current bottom-hole depth, reenter plugged wells, or t° 1420H624650drill horizontal laterais. Use APPLICATION FOR PERMIT TO DRILL form for such proposals,

1. TYPE OF WELLOIL WELL GAS WELL OTHER 8 WEÉ AbMEa NUOM68ER

2 NAMEOF OPERATOR: 9 API NUMBER:Petroglyph Operating Company Inc. 4301352629

3 ADDRESS OF OPERATOR: PHONE NUMBER 10. FIELD AND POOL, OR WILDCATP.O. Box 607 Roosevelt UT 84066 (435) 722-2531 Antelope Creek

4 LOCATION OF WELL


QTRIOTR, SECTION, TOWNSHiP. RANGE. MERIDIAN: SWNE 31 SS 3W U STATE

UTAH

CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE. REPORT, OR OTHER DATATYPE OF SUBMISSION TYPE OF ACTION

O ACIDiZE DEEPEN REPERFORATE CURRENT FORMATIONNOTICE OF INTENT(Submit in Duphcate) ALTER CASING FRACTURE TREAT SIDETRACK TO REPAIR WELL


10/6/2014 CHANGE TO PREVIOUS PLANS OPERATOR CHANGE TUBING REPAIR

CHANGE TUBING PLUG AND ABANDON VENT OR FLARE

O SUBSEQUENT REPORT CHANGE WELL NAME PLUG BACK WATER DISPOSAL(Submit Original Form Only)

CHANGE WELL STATUS PRODUCTION (START/RESUME) WATER SHUT-OFFDate of work completion:

O COMMINGLEPRODUCING FORMATIONS RECLAMATIONOF WELL SITE OTHER:

O CONVERT WELL TYPE RECOMPLETE -OlFFERENT FORMATION

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

On or around 10/6/2014, depending on equipment availability, Petroglyph Operating intends to perforate and fracture treat thefollowing: 4165-77, 4777-79, 4806-09, 4836-40, 4907-09, 4912-14, 4931-40, 5049-55, 5060-62, 5065-71, 5180-83, 5205-09,5273-75, 5286-89, 5332-44, 5347-56, 5384-86, 5394-96, 5398-5400, 5406-08, 5420-22, 5424-26, 5573-76, 5582-86, 5610-15,5660-64, 5680-86, 5693-5703, 5706-13 & 5744-46. We will perforate at 4 shot per foot and isolate zones using Halliburton 8KComposite Plugs. We plan complete the following stages:5,573-5,746: 39,200 Gals of fluid containing 70,000#'s of sand,5,273-5,426: 47,600 Gals of fluid containing 85,000#'s of sand,5,180-5,209: 14,000 Gals of fluid containing 25,000#'s of sand,5,049-5,071: 28,000 Gals of fluid containing 50,000#'s of sand,4,907-4,940: 19,600 Gals of fluid containing 35,000#'s of sand,4,777-4,840: 16,800 Gals of fluid containing 30,000#'s of sand,4,1654,177: 16,800 Gals of fluid containing 30,000#'s of sand.This plan is tentative and willbe adjusted as needed during completion operations. Volumes and amounts of sand are onlyestimates, actual figures will be reported at a later date, All plugs will be drilled out and and the well swabbed if necessary.

NAME (PLEASE PRINT) Rodr go Jurado Regulatory Compliance Specialist

SIGNATURE 9:29/2014

RECEIVED: Nov. 03, 2014



FORM 9









9. API NUMBER: 43013526290000




COUNTY: DUCHESNE

STATE: UTAH

11.





10/31 /2014














The date of first production for this well was 10/31/2014.



SIGNATURE N/A

DATE 11 /3 /2014

November 06, 2014


FORM 9STATE OF UTAH

















10/31/2014OPERATOR CHANGE PLUG AND ABANDON PLUG BACK







The date of first production for this well was 10/31/2014. Accepted by theutah Division of

Oil, Gas and Mining

FOR RECORD ONLYNovember 06, 2014



RECEIVED: Nov. 03,

RECEIVED: Feb. 18, 2015



FORM 9









9. API NUMBER: 43013526290000




COUNTY: DUCHESNE

STATE: UTAH

11.





10/31 /2014














Please see attached.



SIGNATURE N/A

DATE 2 /18 /2015

February 20, 2015


FORM 9STATE OF UTAH
















/ SUBSEQUENTREPORTDate of Work Completion: DEEPEN FRACTURE TREAT NEW CONSTRUCTION

10/31/2014OPERATOR CHANGE PLUG AND ABANDON PLUG BACK







Please see attached. Accepted by theutah Division of

Oil, Gas and Mining

FOR RECORD ONLYFebruary 20, 2015



RECEIVED: Feb. 18,

RECEIVED: Feb. 18, 2015


STATE OF UTAH FORM 9DEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING 5 LEASE DESIGNATION AND SERIAL NUMBER

14-20-H62-3520

SUNDRY NOTICES AND REPORTS ON WELLS ALALLOT EbEeORTRIBENAME

7 UNIT or CA AGREEMENT NAMEDo not use this form for proposals to drill new wells. significantly deepen existing wells below current bottom-hole depth, reenter plugged wells, or t° 14-20-H62-4650

drill horizontal laterais. Use APPLICATION FOR PERMIT TO DRiLL form for such proposais.

1 TYPE OF WELLOIL WELL GAS WELL OTHER

S VeEL AbMEa NUOM68ER:

2 NAME OF OPERATOR: 9 API NUMBER:

Petroglyph Operating Company Inc. 43013525293 ADDRESS OF OPERATOR PHONE NUMBER: 10. FIELD AND POOL, OR WILDCAT:

P.O. Box 607 Rooseveit UT , 84066 (435) 722-2531 Antelope Creek4 LOCATiON OF WELL


QTR/QTR, SECTION, TOWNSHIP, RANGE MERIDIAN: SWNE 31 5S 3W U STATE

UTAH

CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE, REPORT, OR OTHER DATATYPE OF SUBMISSION TYPE OF ACTION

O ACIDíZE DEEPEN REPERFORATE CURRENT FORMATIONNOTICE OF INTENT

(Submit in Dupucate) ALTER CASING FRACTURE TREAT SIDETRACK TO REPAIR WELL


O CHANGE TO PREVIOUS PLANS OPERATOR CHANGE TUBiNG REPAIR

O CHANGE TUBING PLUG AND ABANDON VENT OR FLARE

SUBSEQUENT REPORT CHANGE WELL NAME PLUG BACK WATER DISPOSAL(Submit Originai Form Only)

CHANGE WELL STATUS PRODUCTION (START/RESUME) WATER SHUT-OFF

Date of work completion:

O COMMINGLEPRODUCING FORMATIONS RECLAMATIONOF WELL SITE OTHER

10/31/2014CONVERT WELL TYPE RECOMPLETE -DIFFERENT FORMATION

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

On 9/18/2014 Petroglyph Operating ran GR/CBL and found ETOC @ 110'. On 10/10/2014 we then perforated the following:4165-77, 4777-79, 4806-09, 4836-40, 4907-09, 4912-14, 4931-40, 5049-55, 5060-62, 5065-71, 5180-83, 5205-09, 5273-755286-89, 5332-34, 5347-56, 5384-86, 5394-96, 5398-5400, 5406-08, 5420-22, 5424-26, 5573-76, 5582-86, 5610-15, 56605680-86, 5693-5703, 5706-13 & 5744-46, We isolated and fracture treated the following intervals:5,57365,746': 784 Bbis of fluid containing 70,000#'s of sand,5,273'-5,426': 911 Bbis of fluid containing 85,300#'s of sand,5,18065,209': 479 Bbis of fluid containing 25,300#'s of sand,5,04955,071': 540 Bb\s of fluid containing 50,300#'s of sand,4,907'-4,940': 511 Bbis of fluid containing 60,200#'s of sand,4,77764,840': 407 Bbis of fluid containing 44,700#'s of sand,4,165'-4,17T: 437 Bble of fluid containing 29,380#'s of sand.Isolation plugs used were Halliburton 8K Composite Plugs, fluid used was Delta 140 18#gelled fluid, sand used was 20/40Mesh Premium White Sand and guns used were Titan 3-1/8", containing 22.7 gram charges, 0.42" EHD, 23.54" TTP @4 SPF

@ 120* Phased. All plugs were drilled out and cleaned out to PBTD, 6,288'. The well was swabbed until a good oli cut wassee, then ran a pump on 10/31/2014 and put to pump.

Rodngo Joado Regulatolv Coophance Spet ialst

2 18 201 i

(This space for State use only)

RECEIVED: Mar. 04, 2015


STATE OF UTAH AMENDED REPORT FORM 8DEPARTMENT OF NATURALRESOURCES (highlight changes)

DIVISIONOF OIL, GAS AND MINING S LEASEDESIGNATIONANDSERIALNUMBER:

14-20-H62-35206. IF INDIAN,ALLOTTEEOR TRíBE NAME

WELL COMPLETION OR RECOMPLETION REPORT AND LOG Ute Indian Tribeis B i Me

r Li L7. UNITor CÁAGREEMEÑT NÀME

14-20-H62-4650TV i F / FK 8. WELL NAMEand NUMBÈR

M 2 U" O LP O eO U"sO OTHER Ute Tribal 31-06NrMf F Ffat < 9,APINUMBER

Petroglyph Operating Company, Inc 4301352529to of "rRa i PHONE NUMBER 10 FIELD AND POOL, OR WILDCAT

PO Box 607 Roosevelt UT = 84066 (435) 722-2531 Antelope Creek1 l ( ATIuN V i ll (f - TAL Em 11, QTR/QTR. SECTlON TOWNSHIP, RANGE,

MERIDIANU IRF cr 1989' FNL 2150' FEL SWNE 31 SS 3W U

T ffRl I IN INIFP al <fPR EDer a 1994' FNL 309T FEL SENW Sec 31 TSS R3W12. COUNTY

vttu 2022' FNL 3320' FEL SENW Sec 31 T5S R3È Duchesne UTAH

1 At H E V fulf ID hi «HF 4 LATFU (1PLEHD RE A i N D RPts MT.GL)

8/19/2014 9/6/2014 11/1/2014 ABANDONED READYTO PRODUCE 2 6 811' RKB"i "" "" 6 393 ' " " as sto , 6 288 20. 1FMULTIPLECOMPLETIONS HOW MANY? * I r i b ID at 10

- 6 217 i 6 112TvFEELE TR ANl JTHEP*1ErPANI"All F JN ibnittopefei 23.

WAS WELL COREDO NO YES (Submit analysis)ACTR SDDSN Borehole Volume Plot Cement Bond Log

WAS DST RUN? NO YES (San og

DIRECTIONAL SURVEY? NO YES (Submit copy)

24 CASING AND LINER RECORD (Report all strmgs set m well)

H t i 6 1't /i tt ALL * f I H I * * TOP (MD) Bul M Hi E iNl H CMFN F

VOL E BBL)CEMENT TOP ** AMOUNT PULLED

26 la J-55 75 0 73 0 Conductor

12 25 8 625 J-55 24 0 538 G 360 74

7 875 ES J-55 15 5 0 6,377 G 840 267 110 CBL

2& TUBING RO.:ORD

SlZE

2 875 5,7666 PRODUCING INTERVAL:> 27 PERFORATION RECORD

TE M r ,l P

(,reen River 4 105 5 746 4 008 5 570 4,165 5 746 0 42 492

2" ACID FRA-TJRE EATHEN' 'F-MENTRQsEbZL M

4 165'-5 746' 4,069 Bbis of Delta 140 18# Gelled Fluid conta ning 365 180#'s of 20/40 Mesh Sand

29. ENCLOSEDATTACHMENTS: We STATUS

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

5/2000) CONTINUED ON



3L INITIAL PRODUCTION INTERVAL A (As shown in item #26)

DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION OIL - BBL: GAS - MCF: WATER - BBL PROD METHOD

10/31/2014 12/3/2014 24 RATES: 76 73 22 Rod PumpCHOKE SIZE: BG. PRESS CSG, PRESS. API GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OlL - BBL: GAS - MCF: WATER - BBL INTERVAL STATUS

32/64 55 55 40.90 1 961 RATES: 76 73 22 OpenINTERVAL B (As shown in item #26)

DATE FIRST PRODUCED: TEST DATE: TEST PRODUCTION OtL - BBL: GAS- MCF: WATER - BBL PROD. METHOD:RATES

CHOKE SíZE TBG. PRESS CSG, PRESS API GRAVITY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTlON OIL - BBL: GAS - MCF: WATER - BBL INTERVAL STATUS

RATES

INTERVAL C (As shown In item #26)

HOURS TESTED TEST PRODUCTION OíL - BBL: GAS - MCF WATER - BBLRATES: -÷

CHOKE SIZE CSG. PRESS API GRAVITY BTU -GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL GAS - MCF WATER - BBL INTERVAL STATUSRATES

INTERVAL D (As shown in item #20)

TEST PRODUCTION .OIL - BBL: GAS - MCF: WATER - BBL

RATES -+

CHOKE SIZE CSG. PRESS API GRAVlTY BTU - GAS GAS/OIL RATIO 24 HR PRODUCTION OIL - BBL WATER - BBL:

RATES

32. DISPOSITION OF GAS (Sold, Used for Fuel, Vented, Etc.)

Used for Fuel33. SUMMARYOF POROUS ZONES (include Aqulfers): 34. FORMATION (Log) MARKERS:

Show alHmportant zones of porosity and contents thereof: Cored intervals and all drill-stem tests, including depth intervaltested, cushion used, time tool open, flowing and shutan pressures and recoveries.

Formation Descriptions, Contents, etc Name (MeasuedpDepth)

Mahogany Shale 2,984Lower Parachute Creek 3,310Garden Gulch 3,700Middle Garden Gulch 4,117Lower Garden Gulch 4,609Douglas Creek 4,748Lower Douglas Creek 5 118Castle Peak 5 660Basal CarbonateWasatch 6 360

Rodogo Jtuado Royulatoly Lomplianco Special st

3 2 2015

Utah Division of Oil, Gas and Mining1594 West North Temple, Suite 1210Box 145801 : : 801-359-3940Salt Lake City, Utah 84114-5801



STATE OF UTAH FORM 7DEPARTMENT OF NATURAL RESOURCES


REPORT OF WATER ENCOUNTERED DURING DRILLING

Well name and number: Ute Tribal 31-06

API number: 4301352629

Well Location: QQ SWNE Section 31 Township 5S Range 3W County Duchesne

Well operator: Petroglyph Operating Cornpany, Inc.


city Roosevelt state UT ip 84066 Phone: (435) 722-2531

Drilling contractor: Pro Petro

Address: 1422 East 1500 South

city Vernal state UT zip 84078 Phone: (435) 789-1735

Water encountered (attach additional pages as needed):

DEPTH VOLUME QUALITY

FROM TO (FLOW RATE OR HEAD) (FRESH OR SALTY)

0 532 0 No Water Encountered

Formation tops:(Top to Bottom)

4 6

NAMEfPLEASEPRINTIRodrigo Jurado Regulator, Ce avha « Spe a si

SIGNA



Job Number: UT141438 State/Country: UT / USA

Company: Petroglyph Energy Declination: 10.98

Lease/Well: Ute Tribal 31-06 Grid: True

Location: Section 31 T5S, R3W File name: C:\WINSERVE\UT141438.SVY

Rig Name: Capstar 334 Date/Time: 06-Sep-14 / 11:55

RKB: Curve Name: As DrilledG.L. or M.S.L.:

WINSERVE SURVEY CALCULATIONSMinimum Curvature Method

Vertical Section Plane 269.70VerticalSection Referenced to Wellhead

Rectangular Coordinates Referenced to Wellhead

Measured IncI Drift True Vertical CLOSURE DoglegDepth Angle Direction Vertical N-S E-W Section Distance Direction Severity

FT Dog Deg Depth FT FT FT FT Deg Deg/100

.00 .00 .00 .00 .00 .00 .00 .00 .00.00

593.00 .53 22.93 592.99 2.53 1.07 -1.08 2.74 22.93 .09

685.00 .26 210.45 684.99 2.74 1.13 -1.14 2.96 22.40 .86

778.00 1.80 245.47 777.97 1.95 -.31

.30 1.97 351.04 1,71Transition from HWDP to Drill pipe893.00 3.52 244.55 892.84 -.32 -5.14 5.14 5.15 266.46 1.50

978.00 4.35 257.34 977.65 -2.15-10.64 10.65 10.85 258.60 1.42

1062.00 5.63 262.70 1061.33 -3.37 -17.84 17.85 18.15 259.31 1.621146.00 6.77 266.87 1144.83 -4.16 -26.87 26.89 27.19 261.20 1.461230.00 7.97 270.21 1228.14 -4.41 -37.63 37.66 37.89 263.32 1.521315.00 8.79 274.61 1312.23 -3.87 -50.00 50.02 50.15 265.58 1.22

1399.00 9.18 271.62 1395.20 -3.16-63.10 63.11 63.18 267.13 .72

1484.00 10.11 276.32 1479.00 -2.15 -77.29 77.30 77.32 268.41 1.431568.00 12.26 280.32 1561.40 .26

-93.39 93.39 93.39 270.16 2.721652.00 12.52 278.34 1643.44 3.18 -111.18 111.16 111.22 271.64 .59

1736.00 13.05 274.30 1725.36 5.21 -129.64 129.61 129.75 272.30 1.24

1821.00 13.49 272.10 1808.09 6.29 -149.12 149.08 149.25 272.42 .79

1905.00 15.56 270.35 1889.41 6.72 -170.18 170.14 170.31 272.26 2.521989.00 16.30 268.85 1970.18 6.55 -193.23 193.19 193.34 271.94 1.012074.00 16.88 269.77 2051.64 6.27 -217.50 217.46 217.59 271.65

.75

2158.00 18.63 268.85 2131.64 5.95 -243.11 243.08 243.18 271.40 2.11

2242.00 20.52 268.10 2210.78 5.19 -271.24 271.21 271.29 271.10 2.272327.00 21.53 270.70 2290.12 4.89 -301.73 301.70 301.77 270.93 1.622411.00 22.50 272.72 2368.00 5.84 -333.20 333.16 333.25 271.00 1.462496.00 22.54 268.76 2446.52 6.26 -365.73 365.69 365.79 270.98 1.782587.00 20.80 266.30 2531.09 4.84 -399.30 399.27 399.33 270.69 2.16

Page



Measured incl Dritt True Vertical CLOSURE DoglegDepth Angle Direction Vertical N-S E-W Section Distance Direction Severity

FT _ Deg__

Dog Depth FT FT FT FT Dog Deg/1002678 00 19 61 264 12 2616 49 2 23 430 61 430 59 430 62 270 30 1.552770 00 20 83 267 97 2702 82 07 462 32 462 31 462 32 270 01 1.962861 00 22 54 267 71 2787 37 1 20 495 92 495 92 495 92 269 86 1.88295200 2228 26749 287150 265 53058 53059 53059 26971

.30

3043 00 22 76 267 66 2955 56 4 13 565 40 565 42 565 42 269 58 .53

3135 00 21.75 270.13 3040.71 -4.82 600 23 600.25 600.25 269.54 1.503226 00 22 28 270.21 3125 07 -4.72 634 34 634.36 634.36 269.57 .58

3317 00 22 90 271.40 3209.09 -4.22 -669 29 669.31 669.31 269.64 .85

3409 00 23 38 273.11 3293 69 -2.79 705 41 705.42 705.42 269.77.90

3500 00 22 50 272.23 3377.49 -1.13 740 84 740.84 740.84 269.91 1.04

3592 00 21 58 271 44 3462 77 -.02 775 35 775 34 775 35 270 00 1.053683.00 20 52 270 52 3547 70

.54 808 03 808 01 808 03 270 04 1.223774.00 19 16 268 72 3633 29

.35 838 91 838 89 838 91 270 02 1.643866.00 17 58 266 39 3720 60 -.86 867 87 867 86 867 87 269 94 1.893957.00 17 35 265 98 3807 41 -2.68 895 12 895 12 895 12 269 83 .29

4048 00 16 35 267 53 3894 50 -4.18 -921.45 921 46 921.46 269.74 1.204139 00 15 82 269 82 3981 94 -4.77 -946.65 946.67 946.67 269.71 .91

4231 00 15 29 271 88 4070 57 -4.41-971.32 971.33 971.33 269.74 .83

4322 00 14 15 270 04 4158 58 -4.01 -994.43 994.44 994.44 269.77 1.354413 00 12 66 267 18 4247 10 -4.49 -1015.52 1015.53 1015.53 269.75 1.79

4504 00 10.99 264 11 4336 17 -5.87 1034 11 1034.12 1034.12 269.67 1.964595 00 10.50 268 50 4425 57 -6.98 1051 03 105005 1051.05 269.62 1 054687 00 9.14 265 29 4516 23 -7.80 1066 69 1066,71 1066.72 269.58 L594778 00 9.01 272 15 4606 09 -8-13 1081 01 1081.04 1081.04 269.57 1.204869 OG 8.00 27û 78 4696 09 -7.77 1UB44| 1094.49 1094.49 269.59 1.13

NGH 00 7.48 ora T 1 -7.71-1106.72 1106.75 1106.75

.59

b2 00 6.45 264 05 18 -8.18 -1117.86 1117.88 1117.89 69 58 L29141 00 5.76 i 6 968 -8.50

-1127.51 1127.54 1127.54 9 5 1.09: i I 4,88 8 -7.80 -1135.90 1135.93 1135.93 6 1 20

in 00 3.78 6 -7.32 -1142.81 1142.83 1142.83 69 63 1.47

M 1 3.47 256.19 -8.08-1148.48 1148.50 1148.51 69 St

.88

2.15 257,28 -9.12 -1152.82 1152.85 1152.85 9 L45L74 232.99 -10.34 -1155.62 1155.65 1155.66 9

.99

1.41 221.92 -12.00 -1157.47 1157.51 1157.53.49

163 215.02 -13.90 -1158.96 1159.01 1159.04.31

1.71 213.26 -16.09-1160.45 1160,51 1160.56

.10

LSO 212.56 -18.46-1161.98 1162.06 1162.12

210

1.93 209.88 -20.99-1163.51 1163.60 1163.70

.17

2.29 209.83 -23 90 -1165.18 1165.29 1165.42 68 m .40

2.25 209.20 27.03 -1166.95 1167.08 1167.27 de.05

Final Survey99 Y . W 207.55 6152.66 -30.32 -1168.73 1168.87 1169.12 268.51 .24

Projection to Bit6393 00 3 46 207.55 6216.60 -32.76

-1170.00 1170.15 1170.46 268.40.00

Page 2As Drilled File:



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0750

1585

50

Division of Oil, Gas and Mining Operator Change/Name Change Worksheet-for State use only

Effective Date ' 9/ 1120 19

FORMER OPERA TOR: NEW OPERATOR: Crescent Point Energy U.S. Corporation CH4-Finley Operating, LLC

Groups: Ouray Valley-Unit

Horseshoe Bend (GR)-EOR Randlett-EOR Antelope Creek-EOR

Antelope-Unit -

Range Dir

Total Well Count: 1405

OPERATOR C HANGES DOC UMENTATION:

1. Sundry or legal documentation was received fTom the FORME R operator on: 2. Sundry or legal documentation was received fTom the NEW operator on: 3. New operator Division of Corporations Business Number: I 1468999-0161

REVIEW: Receipt of Acceptance of Drilling Procedures for APD on: Reports current for ProductionlDisposition & undries: OPS/SlrrA well(s) reviewed for full cost bonding: Approved by Dustin

12/3112019 12/ 18120 19

12/ 1812019 UIC5 on all disposal/injection/storage well(s) Approved on : Approved by Dayne Surface Facil ity(s) included in operator change:

NEW OPERATOR BOND VERIFICATION: State/fee well(s) covered by Bond Number(s):

DATA ENTRY: Well(s) update in the RBDMS on: Group(s) update in ROBMS on: Surface Facilities update in RBDMS on :

Entities Updated in RBDMS on :

COMMENTS:

None

LPM9282986-Blanket

LPM9282991-lndividual

LPM 9336805-Shut-In Bond

12/31 /20 19 12/3112019

NA 12/3 1/2019

10125/20 19

10125120 19 10/25/20 19

Shut-Ln well have until 6/1 /2020 to get into comliance or they will need to be plugged, if the well bore is need for furture use full cost bonding will be required.

Status

1/7/2020

FORM 9 STATE OF UTAH DEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING 5. LEASE DESIGNATION AND SERIAL NUMBER: see attached well list


Do not use this form for proposals to drill new wells, significantly deepen existing wells below current bottom·hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION FOR PERMIT TO DRILL form for such proposals.

1. TYPE OF WELL OIL WELL IZI GAS WELL 0 OTHER injection wells

2. NAME OF OPERATOR: Crescent Point Energy U,S, Corp,

STATE CO ZIp 80228 I PHONE NUMBER: (720) 880-3610

3. ADDRESS OF OPERATOR: 555 17th Street, Suite 1800 CITY Denver

4. LOCATION OF WELL

FOOTAGES AT SURFACE:

OTRIOTR, SECTION, TOWNSHIP, RANGE, MERIDIAN:

6. IF INDIAN, ALlOTIEE OR TRIBE NAME: see attached

7. UNIT or CA AGREEMENT NAME:

8. WELL NAME and NUMBER: see attached

9. API NUMBER: attached

10. FIELD AND POOL, OR WILDCAT: attached

COUNTY:

STATE: UTAH

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


[l] 0 ACIDIZE 0 DEEPEN 0 REPERFORATE CURRENT FORMATION NOTICE OF INTENT

(Submit in Duplicate) 0 ALTER CASING 0 FRACTURE TREAT 0 SIDETRACK TO REPAIR WELL Approximate date wort< will start 0 CASING REPAIR 0 NEW CONSTRUCTION 0 TEMPORAflIL Y ABANDON

9/1/2019 0 CHANGE TO PREVIOUS PLANS III OPERATOR CHANGE 0 TUBING REPAIR

0 CHANGE TUBING 0 PLUG AND ABANDON 0 VENT OR FLARE

0 SUBSEQUENT REPORT 0 CHANGE WEll NAME 0 PLUG BACK 0 WATER DISPOSAL (Submit Original Form Only)

0 0 0 CHANGE WELL STATUS PRODUCTION (STARTIRESUME) WATER SHUT -OFF Date of work completion:

0 COMMINGLE PRODUCING FORMATIONS 0 RECLAMATION OF WELL SITE 0 OTHER:

0 CONVERT WELL TYPE 0 RECOMPLETE -DIFFERENT FORMATION


Please consider this sundry as notification of the transfer of operatorship of the wells listed on the attached exhibit from Crescent Point Energy U,S, Corp, to CH4-Finley Operating , LLC effective September 1, 2019.

PREVIOUS OPERATOR: Crescent Point Energy US Corp 555 17th Street, Suite 1800 Denver, CO 80202

Signature - 0 aldwin, President State/Fee ond #LPM9080271 BLM Bond #LPM9080275 BIA Bond #LPM9247918

r

NAME (PLEASE PRINT) ____________________ _

SIGNATURE ______________________ _

. .. (This space for State use 0

t ' . -DEC 3 t 2019

(

\

NEW OPERATOR: CH4-Finley Operating, LLC 5128 Apache Plume Road, Suite 300 Fort Worth, TX 76109

Signature - a hew E, Cooper, VP-Land State/Fee Bond #LPM9282986 BLM Bond #LPM9282988 BIA Bond #LPM9282987

TITLE

DATE 10/17/2019

RECEIVED

OCT 2 5 2019 (512000) (See Instructions on Reverse Side)

DIV OF Oil , GAS & MINING

api well number: 43013526290000 api well number

Documents