threerivers yes commingling application) no · location at surface 1475€fsl€€€1237€fwl€...

RECEIVED: August 21, 2013

STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER

Three Rivers Federal 3-23-820

2. TYPE OF WORK

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

THREE RIVERS

4. TYPE OF WELLOil Well Coalbed Methane Well: NO

5. UNIT or COMMUNITIZATION AGREEMENT NAME

6. NAME OF OPERATORAXIA ENERGY LLC

7. OPERATOR PHONE720 746-5200

8. ADDRESS OF OPERATOR1430 Larimer Ste 400, Denver, CO, 80202

9. OPERATOR [email protected]

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

UTU85994

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')

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 1475 FSL 1237 FWL NWSW 3 8.0 S 20.0 E S

Top of Uppermost Producing Zone 1980 FSL 1980 FWL NESW 3 8.0 S 20.0 E S

At Total Depth 1980 FSL 1980 FWL NESW 3 8.0 S 20.0 E S

21. COUNTYUINTAH

22. DISTANCE TO NEAREST LEASE LINE (Feet)1237

23. NUMBER OF ACRES IN DRILLING UNIT40

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

40

26. PROPOSED DEPTHMD: 7111 TVD: 6955

27. ELEVATION - GROUND LEVEL

4745

28. BOND NUMBER

UTB000464

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

43-10988

Hole, Casing, and Cement Information

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

Surf 11 8.625 0 - 1000 24.0 J-55 LT&C 8.7 Premium Lite High Strength 120 2.97 11.5

Class G 115 1.16 15.8

Prod 7.875 5.5 0 - 7111 17.0 J-55 LT&C 9.2 Light (Hibond) 165 3.78 10.5

Premium Lite High Strength 330 2.31 12.0

ATTACHMENTS

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

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

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

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

NAME Don Hamilton TITLE Permitting Agent (Buys & Associates, Inc) PHONE 435 719-2018

SIGNATURE DATE 08/12/2013 EMAIL [email protected]

API NUMBER ASSIGNED

43047539530000

Permit Manager

APPROVAL

FORM 3

AMENDED REPORT

API Well Number: 43047539530000

CONFIDE

NTIAL


FORM 3STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES AMENDEDREPORTDIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME ae R

veEsRFederal3-23-820

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

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

6. NAME OF OPERATOR 7. OPERATOR PHONEAXIAENERGY LLC 720 746-5200

8. ADDRESS OF OPERATOR 9. OPERATOR E-MAIL1430 Larimer Ste 400, Denver, CO, 80202 [email protected]

10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL,INDIAN,ORSTE)85994 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')

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

(if box 12 = 'INDIAN')MULTIPLE FORMATIONS

YES (Submit Commingling Application) NO VERTICAL DIRECTIONAL HORIZONTAL


LOCATION ATSURFACE 1475 FSL 1237 FWL NWSW 3 8.0 S 20.0 E S



21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITUINTAH 1237 40

25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 7111 TVD: 6955

40

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

4745 UTBOOO464 43-10988


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

11 8.625 0 - 1000 24.0 J-55 LT&C 8.7 Premium Lite High Strength 120 2.97 11.5

Class G 115 1.16 15.8

7.875 5.5 0 - 7111 17.0 J-55 LT&C 9.2 Light (Hibond) 165 3.78 10.5


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 APPROVAL43047539530000

Permit Manager

RECEIVED: August 21,


FORM 3STATE OF UTAH




















40


4745 UTBOOO464 43-10988




Class G 115 1.16 15.8



ATTACHMENTS








Permit Manager



FORM 3STATE OF UTAH




















40


4745 UTBOOO464 43-10988




Class G 115 1.16 15.8



ATTACHMENTS








Permit Manager



FORM 3STATE OF UTAH




















40


4745 UTBOOO464 43-10988




Class G 115 1.16 15.8



ATTACHMENTS








Permit Manager



DRILLING PLAN

Axia Energy, LLC Three Rivers Project Three Rivers Federal #3-23-820

NWSW Sec 3 T8S R20E Uintah County, Utah

1. ESTIMATED FORMATION TOPS FORMATION TOP (TVD) COMMENTS

Uinta Surface Gas & Degraded Oil; Possible Brackish H2O

Green River* 2,820’ Oil & Associated Gas

Lower Green River* 4,768’ Oil & Associated Gas

Wasatch* 6,655’ Oil & Associated Gas

TD 7,111’ (MD) 6,955’ (TVD)

NOTE: Datum, Ground Level (GL) Elevation: 4,745’; Asterisks (*) denotes target pay intervals

A) The Bureau of Land Management (BLM) will be notified within 24 hours of spudding the well. The State of Utah, Division of Oil, Gas and Mining will be notified within 24 hours of spudding the well.

2. CASING PROGRAM

CASING HOLE SIZE

DEPTH SET (MD)

CSG SIZE WGHT GRD THRD

CAPACITY (bbl/ft)

CONDUCTOR 50-75 13 3/8

SURFACE 11 1000 ± 8 ⅝ 24.0 J-55 LTC 0.0636

PRODUCTION 7 ⅞ 7,111’ 5 ½ 17.0 J-55 LTC 0.0232 NOTE: All casing depth intervals are to surface unless otherwise noted.

Casing Specs

SIZE ID DRIFT DIA

COLLAPSE RESISTANCE

INTERNAL YIELD

TENSILE YIELD

JOINT STRENGTH

(in) (in) (in) (psi) (psi) (lbs) (lbs)

8 ⅝ 8.097 7.972 1,370 2,950 381,000 244,000

5 ½ 4.892 4.767 4,910 5,320 273,000 229,000

A) The Bureau of Land Management will be notified 24 hours prior to running casing, cementing, and BOPE testing

B) As per 43 CFR 3160, Onshore Oil and Gas Order No. 2, Drilling Operations, Part B.1 h:

a) Prior to drilling out cement, all casing strings will be pressure tested to 0.22 psi/ft of casing length or 1500 psi, whichever is greater, but not to exceed 70% of minimum internal yield. Pressure decline must not be greater than 10% in 30 minutes.


CONFIDE

NTIAL


DRILLING PLAN

Axia Energy, LLCThree Rivers ProjectThree Rivers Fecleral #3-23-820

NWSW Sec 3 TSS R20EUintah County, Utah

1. ESTIMATED FORMATION TOPSFORMATION TOP (TVD) COMMENTS

Uinta Surface Gas & Degraded Oil; Possible Brackish H2OGreen River* 2,820' Oil&Associated GasLower Green River* 4,768' Oil&Associated GasWasatch* 6,655' Oil&Associated GasTD 7,111' (MD) 6,955' (TVD)

NOTE: Datum, Ground Level (GL) Elevation: 4,745'; Asterisks (*)denotes target pay intervals

A) The Bureau of Land Management (BLM)will be notified within 24 hours of spudding the well. The Stateof Utah, Division of Oil,Gas and Mining will be notifiedwithin 24 hours of spudding the well.

2. CASING PROGRAMHOLE DEFTH CSG CAPACITY

CASING SIZE SET (MD) SIZE WGHT GRD THRD (bbl/ft)

CONDUCTOR 50-75 13 3/8SURFACE 11 1000 ± 8 ¾ 24.0 J-55 LTC 0.0636

PRODUCTION 7 ½ 7,111' 5 ½ 17.0 J-55 LTC 0.0232NOTE: Allcasing depth intervals are to surface unless otherwise noted.

Casing SpecsDRIFT COLLAPSE INTERNAL TENSILE JOINT

SIZE ID DIA RESISTANCE YIELD YIELD STRENGTH(in) (in) (in) (psi) (psi) (Ibs) (Ibs)

8 ¾ 8.097 7.972 1,370 2,950 381,000 244,000

5 ½ 4.892 4.767 4,910 5,320 273,000 229,000

A) The Bureau of Land Management will be notified 24 hours prior to running casing, cementing, andBOPE testing

B) As per 43 CFR 3160, Onshore Oiland Gas Order No. 2, Drilling Operations, Part B.1 h:

a) Prior to drillingout cement, all casing strings will be pressure tested to 0.22 psi/ft of casing lengthor 1500 psi, whichever is greater, but not to exceed 70% of minimum internal yield. Pressuredecline must not be greater than 10% in 30 minutes.



DRILLING PLAN









CONDUCTOR 50-75 13 3/8SURFACE 11 1000 ± 8 ½ 24.0 J-55 LTC 0.0636




8 ½ 8.097 7.972 1,370 2,950 381,000 244,000

5 ½ 4.892 4.767 4,910 5,320 273,000 229,000






DRILLING PLAN













8 ½ 8.097 7.972 1,370 2,950 381,000 244,000

5 ½ 4.892 4.767 4,910 5,320 273,000 229,000






DRILLING PLAN













8 ½ 8.097 7.972 1,370 2,950 381,000 244,000

5 ½ 4.892 4.767 4,910 5,320 273,000 229,000






FLOAT EQUIPMENT

SURFACE (8 ⅝): Float Shoe, 1 JNT Casing, Float Collar

Centralizers: 1st 4 Joints: every joint Remainder: every third joint

PRODUCTION (5 ½): Float Shoe, 1 JNT Casing, Float Collar

Centralizers: 1st 4 Joints: every joint Remainder: every third joint to Green River top

NOTE: 5 ½” 17# N-80 or equivalent marker collar or casing joints will be placed at the top of the Green River and approximately 400’ above the Wasatch.

3. CEMENT PROGRAM

CONDUCTOR (13 ⅜): Ready Mix – Cement to surface

SURFACE (8 ⅝):

Surface - 500’ 500’ - MD

Cement Top: Surface

Lead: 120 sks, Premium Lightweight Cmt w/ additives, 11.50 ppg, 2.97 cf/sk, 50% excess

Tail: 115 sks Class G Cement w/ additives, 15.80 ppg, 1.16 cf/sk, 50% excess

NOTE: The above volumes are based on a gauge-hole + 50% excess.

PRODUCTION (5 ½):

700’ - 3500’ 3500’ - MD

Cement Top – 700’

Lead: Tail:

165 sacks – Light Cement w/ additives – 10.5 ppg, 3.78 ft3/sk – 20% excess 330 sacks – Light Premium Cement w/ additives – 12.0 ppg, 2.31 ft3/sk – 20% excess NOTE: The above volumes are based on gauge hole + 20% excess. Adjustments will be made and volumes will be caliper + 10%.

NOTE: The above volumes are based on a gauged-hole. Adjustments will be made based on caliper.

A) For Surface casing, if cement falls or does not circulate to surface, cement will be topped off.

B) Cement will not be placed down annulus with a 1” pipe unless BLM is contacted.

C) The Bureau of Land Management will be notified 24 hours prior to running casing and cementing.

D) As per 43 CFR 3160, Onshore Oil and Gas Order No.2, Drilling Operations, Part B:

a) All waiting on cement times shall be adequate to achieve a minimum of 500 psi compressive strength at the casing shoe (minimum of 8 hours) prior to drilling out.

b) Prior to drilling out cement, casing will be pressure tested to 1500 psi. Pressure decline must not be greater than 10% (150 psi) in 30 minutes.


CONFIDE

NTIAL


FLOAT EQUIPMENT

SURFACE (8 ¾): Float Shoe, 1 JNT Casing, Float Collar.

1* 4 Joints: every jointCentralizers:Remainder: every thirdjoint

PRODUCTION (5 ½): Float Shoe, 1 JNT Casing, Float Collar.

1* 4 Joints: every jointCentralizers: . .Remainder: every thirdjoint to Green River topNOTE: 5 ½" 17# N-80 or equivalent marker collaror casing joints will be placed at the top of the Green

River and approximately 400' above the Wasatch.

3. CEMENT PROGRAM

CONDUCTOR (13 ¾): Ready Mix - Cement to surface

SURFACE (8 ¾): Cement Top: Surface

Surface -

500, Lead: 120 sks, Premium Lightweight Cmt w/ additives, 11.50 ppg, 2.97cf/sk, 50% excess

500' - MD Tail: 115 sks Class G Cement w/ additives, 15.80 ppg, 1.16 cf/sk, 50%excess


PRODUCTION (5 ½): Cement Top - 700'

700' -

3500, Lead: 165 sacks - Light Cement w/ additives - 10.5 ppg, 3.78 ft3/sk -

20% excess

3500' - MD Tail: 330 sacks - Light Premium Cement w/ additives - 12.0 ppg, 2.31ft3/sk - 20% excess

NOTE: The above volumes are based on gauge hole + 20%excess. Adjustments will be made and volumes will be caliper +

10%.

NOTE: The above volumes are based on a gauged-hole. Adjustments will be made based on caliper.A) For Surface casing, if cement falls or does not circulate to surface, cement will be toppedoff.

B) Cement will not be placed down annulus with a 1" pipe unless BLMis contacted.C) The Bureau of Land Management will be notified 24 hours prior to running casing and cementing.D) As per 43 CFR 3160, Onshore Oiland Gas Order No.2, Drilling Operations, Part B:

a) Allwaiting on cement timesshall be adequate to achieve a minimumof 500 psi compressivestrength at the casing shoe (minimumof 8 hours) prior to drillingout.

b) Prior to drillingout cement, casing will be pressure tested to 1500 psi. Pressure decline must not begreater than 10% (150 psi) in 30 minutes.



FLOAT EQUIPMENT






3. CEMENT PROGRAM



Surface -





700' -


20% excess



10%.







FLOAT EQUIPMENT






3. CEMENT PROGRAM



Surface -





700' -


20% excess



10%.







FLOAT EQUIPMENT






3. CEMENT PROGRAM



Surface -





700' -


20% excess



10%.







4. PRESSURE CONTROL EQUIPMENT A) The Bureau of Land Management will be notified 24 hours prior to all BOPE pressure tests. The State of

Utah, Division of Oil, Gas and Mining will be notified 24 hours prior to all BOPE pressure tests.

B) The BOPE shall be closed whenever the well is unattended.

C) As per 43 CFR 3160, Onshore Oil and Gas Order No. 2, Drilling Operations, Part A:

a) All BOPE connections subjected to well pressure will be flanged, welded, or clamped.

b) Choke Manifold:

i) Tee blocks or targeted ‘T’s will be used and anchored to prevent slip and reduce vibration.

ii) Two adjustable chokes will be used in the choke manifold.

iii) All valves (except chokes) in kill line choke manifold and choke line will not restrict the flow.

iv) Pressure gauges in the well control system will be designed for drilling fluid.

D) BOPE Testing:

a) BOPE shall be pressure tested when initially installed, whenever any seal subject to pressure testing is broken, or after repairs.

b) All BOP tests will be performed with a test plug in place.

c) BOP will be tested to full stack working pressure and annular preventer to 50% stack working pressure.

INTERVAL BOP EQUIPMENT

0 – 1000 ± 11” Diverter with Rotating Head

1000 ± – TD 3,000# Ram Double BOP & Annular with Diverter & Rotating Head NOTE: Drilling spool to accommodate choke and kill lines.

5. MUD PROGRAM A) Mud test will be performed at least every 24 hours and after mudding up to determine density,

viscosity, gel strength, filtration, and pH.

B) Gas-detecting equipment will be installed and operated in the mud-return system from top of Green River Formation to TD.

a) Flare line discharge will be located no less than 100 feet from the wellhead using straight or targeted ‘T’s and anchors.

INTERVAL MUD WGHT VISC FLUID LOSS COMMENTS

SURF – 1000 ± 8.4 – 8.7 ppg 32 NC Spud Mud

1000 ± – TD 8.6 – 9.2 ppg 40 NC DAP/Gel NOTE: Mud weight increases will be directed by hole conditions.

6. ABNORMAL CONDITIONS A) No abnormal pressures or temperatures are anticipated.

a) Estimated bottom hole pressure at TD will be approximately 3,012 psi (normal pressure gradient: 0.433 psi/ft).

b) Estimated maximum surface pressure will be approximately 1,530 psi (estimated bottom hole minus pressure of partially evacuated hole (gradient: 0.220 psi/ft)).

B) No hydrogen sulfide is anticipated.


CONFIDE

NTIAL


4. PRESSURE CONTROL EQUIPMENTA) The Bureau of Land Management will be notified 24 hours prior to all BOPE pressure tests. The State of

Utah, Division of Oil,Gas and Mining will be notified 24 hours prior to all BOPE pressure tests.B) The BOPE shall be closed whenever the well is unattended.C) As per 43 CFR 3160, Onshore Oiland Gas Order No. 2, Drilling Operations, Part A:


b) Choke Manifold:

i) Tee blocksor targeted 'T's will be used and anchored to prevent slip and reduce vibration.

ii) Two adjustable chokes will be used in the choke manifold.iii) Allvalves (except chokes) in kill line choke manifoldand choke line will not restrict the flow.

iv) Pressure gauges in the well control system will be designed for drillingfluid.

D) BOPETesting:

a) BOPEshall be pressure tested when initially installed, whenever any seal subject to pressuretesting is broken, or after repairs.


c) BOP will be tested to full stack working pressure and annular preventer to 50% stack workingpressure.


0 - 1000 ± 11" Diverter with Rotating Head

1000 ± - TD 3,000# Ram Double BOP &Annular with Diverter & Rotating HeadNOTE: Drilling spool to accommodate choke and kill lines.

5. MUD PROGRAMA) Mud test will be performed at least every 24 hours and after mudding up to determine density,


B) Gas-detecting equipment will be installed and operated in the mud-return system from top of GreenRiver Formation to TD.

a) Flare line discharge will be located no less than 100 feet from the wellhead using straight ortargeted 'T's and anchors.


SURF - 1000 ± 8.4 - 8.7 ppg 32 NC Spud Mud

1000 ± - TD 8.6 - 9.2 ppg 40 NC DAP/GelNOTE: Mud weight increases will be directed by hole conditions.

6. ABNORMAL CONDITIONSA) No abnormal pressures or temperaturesare anticipated.

a) Estimated bottom hole pressure at TD will be approximately 3,012 psi (normal pressure gradient:0.433 psi/ft).

b) Estimated maximumsurface pressure will be approximately 1,530 psi (estimated bottom holeminus pressure of partially evacuated hole (gradient:0.220 psi/ft)).







b) Choke Manifold:




D) BOPETesting:























b) Choke Manifold:




D) BOPETesting:























b) Choke Manifold:




D) BOPETesting:




















INTERVAL CONDITION

SURF – 1000 ± Lost Circulation Possible

1000 ± – TD Lost Circulation Possible

7. AUXILIARY EQUIPMENT A) Choke Manifold

B) Upper and lower kelly cock with handle available

C) Stabbing valve

D) Safety valve and subs to fit all string connections in use

8. SURVEY & LOGGING PROGRAMS A) Cores: None anticipated.

B) Testing: None anticipated.

C) Directional Drilling: Directional tools will be used to locate the bottom hole per the attached directional plan +/-.

D) Open Hole Logs: TD to surface casing: resistivity, neutron density, gamma ray and caliper.

E) Mud Logs: None

9. HAZARDOUS MATERIALS

In accordance with Superfund Amendments and Reauthorization Act of 1986 (SARA) Title III, no chemicals subject to reporting in an amount equal to or greater than 10,000 pounds will be used, produced, stored, transported, or disposed of annually in association with the drilling of this well. Furthermore, no extremely hazardous substances, as defined in 40 CFR 355, in threshold planning quantities (TPQ), will be used, produced, stored, transported, or disposed of in association with the drilling of this well.


CONFIDE

NTIAL


INTERVAL CONDITION

SURF - 1000 ± Lost CirculationPossible

1000 ± - TD Lost CirculationPossible

7. AUXILIARY EQUIPMENTA) Choke Manifold

B) Upper and lower kelly cock with handle availableC) Stabbing valve


8. SURVEY & LOGGING PROGRAMSA) Cores: None anticipated.B) Testing: None anticipated.

C) Directional Drilling: Directional toolswill be used to locate the bottom hole per the attached directionalplan +/-.

D) Open Hole Logs: TD to surface casing: resistivity, neutron density, gamma ray and caliper.E) Mud Logs: None


In accordance with Superfund Amendments and Reauthorization Act of 1986 (SARA)Title III, no chemicalssubject to reporting in an amount equal to or greater than 10,000 pounds will be used, produced, stored,transported,or disposed of annually in association with the drillingof this well. Furthermore, no extremelyhazardous substances, as defined in 40 CFR 355, in thresholdplanning quantities (TPQ),will be used,produced, stored, transported,or disposed of in association with the drillingof this well.



INTERVAL CONDITION













INTERVAL CONDITION













INTERVAL CONDITION













ROBERT L.KAY

No. 161319

A


CONFIDE

NTIAL


TBS, R20E, S.L.B.&M. AXIA ENERGYWell location, THREE RIVERS FEDERAL #3-23-820,located as shown in the NW 1/4 SW 1/4 of

SB9°49'J4"W- 2631.48' (Meas.) SB9°17'56"W

- 2661.97' (Meas.) T7S Section 3, T8s, R20E, S.L.B.&M., Uintah County,

roun, reeserass cap, TBS 'BASIS OF ELEVATION

Rebar 0.5' HighE-W Fence

BENCH MARK (38EAM) LOCATED IN THE SW 1/4 OF SECTION9, T7S, R20E, S.L.B.&M. TAKEN FROM THE PELICAN LAKE,

LOT 4 LOT 3 LOT 2 LOT 1 QUADRANGLE,UTAH, UINTAH COUNTY, 7.5 MINUTE QUAD(TOPOGRAPHIC MAP) PUBLISHED BY THE UNITED STATESDEPARTMENTOF THE INTERIOR, GEOLOGICALSURVEY. SAIDELEVATIONIS MARKED AS BEING 4942 FEET.

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

1998 Priv. N

3 Alum. Cap,

Eound8' High

Nail

1980', Target Bottorn HO/e 9 $ b 2

1HREE R/VERS EEDERAL1237' /3-23-820

CERTIFICATEElev. Un ded Ground =

4745> g LANDI THIS IS TO CERTIFYTHAT THE ABOVE D

FIELD NOTES OF ACTUALSURVEYS M OR UNDESUPERVISIONAND THAT THE SAME U g I l g OBEST OF MY KNOWLEDGEAND BELIE

REGIS D LA DS ORREGISTR . 131STATE O 7g g

SB9;7'29"W - 5341.90' (Meas.) p,iv UINTAH ENGINEERING & LAND SURVEYINGA/u n. Cap Alum. Cap

85 SOUTH 200 EAST - VERNAL, UTAH 84078

(435) 789-1017LEGEND: SCALE DATE SURVEYED: DATE DRAWN:

1" = 1000' 06-24-13 06-28-13=

90° SYMBOL NAD 83 (TARGET BOTTOMHOLE) NAD 83 (SURFACE LOCATION) FARTY REFERENCESLATITUDE =40°08°59.82" (40.149950) LATITUDE =

40°08'54.74" (40.148539)= PROPOSED WELL HEAD. LONGITUDE=

109°39'25.46" (109.657072) LONGITUDE= 109'39'34.97" (109.659714) B.H. C.A. K.O. G.L.O. PLATNAD 27 (TARCET BOTTOMHOLE) NAD 27 (SURFACE LOCATION) WFATHFP FILE

A = SECTION CORNERS LOCATED LATITUDE = 40'08'59.95" (40.149986) LATITUDE = 40'08'54.87" (40.148575) HOT AXIA ENERGYLONGITUDE=109°39'22.96" (109.656378) LONGITUDE= 109'39'32.47" (109.659019)




SB9°49'J4"W- 2631.48' (Meas.) SB9°17'56"W







1998 Priv. N

3 Alum. Cap,

Eound8' High

Nail










1" = 1000' 06-24-13 06-28-13=








SB9°49'J4"W- 2631.48' (Meas.) SB9°17'56"W







1998 Priv. N

3 Alum. Cap,

Eound8' High

Nail










1" = 1000' 06-24-13 06-28-13=








SB9°49'J4"W- 2631.48' (Meas.) SB9°17'56"W







1998 Priv. N

3 Alum. Cap,

Eound8' High

Nail





FIELD NOTES OF ACTUALSURVEYS M OR UNDESUPERVISIONAND THAT THE SAME U g Ig OBEST OF MY KNOWLEDGEAND BELIE





1" = 1000' 06-24-13 06-28-13=







Uintah Engineering & Land Survey ing85 South 200 East Vernal, Utah 84078(435) 789-1017 * FAX (435) 789-1813

R21E

R20E

LEGEND:

130907MONTH DAY YEAR A

TOPO

PROPOSED LOCATION

³ ACCESS ROADMAPUELS

AXIA ENERGY

Uintah Engineering & Land Surveying85 South 200 East Vernal, Utah 84078(435) 789-1017 * FAX (435) 789-1813 DRAWN BY: S.O. REVISION: 00-00-00SCALE: 1:100,000

STATE

HIGH

WAY 8

8

SEE TOPO "B" T8S T7S

¥

¥

U.S. H

IGHWA

Y 40 1

2.1 MI

. +/-

VERN

AL 26

.1 MI. +

/-

%

PROPOSED LOCATION: THREE RIVERS FEDERAL #3-13-820, #3-14-820, #3-23-820 & #3-24-820

THREE RIVERS FEDERAL#3-13-820, #3-14-820, #3-23-820 & #3-24-820

SECTION 3, T8S, R20E, S.L.B.&M.NW 1/4 SW 1/4


CONFIDE

NTIAL


PROPOSED LOCATION:THREE RIVERS FEDERAL

'A #3-13-820, #3-14-820,3-2 2

LEGEND: AXIA ENERGYPROPOSED LOCATION N THREE RIVERS FEDERAL

#3-13-820, #3-14-820, #3-23-820 & #3-24-820SECTION 3, T8S, R20E, S.L.B.&M.

NW 1/4 SW 1/4

- Uintah Engineering & Land Surveying ACCESS ROAD 07 09 1385 South 200 East Vernal, Utah 84078 M A P MONTH DAY YEAR

(435) 789-1017 * FAX (435) 789-1813 SCALE:1:100,000 DRAWNBY:S.O. REVISION:00-00-00




'A #3-13-820, #3-14-820,3-2 2



NW 1/4 SW 1/4






'A #3-13-820, #3-14-820,3-2 2



NW 1/4 SW 1/4






'A #3-13-820, #3-14-820,3-2 2



NW 1/4 SW 1/4






BLM

130907MONTH DAY YEAR B

TOPO³ ACCESS ROADMAPUELS

R20E

AXIA ENERGY

T8S

Uintah Engineering & Land Surveying85 South 200 East Vernal, Utah 84078(435) 789-1017 * FAX (435) 789-1813 DRAWN BY: S.O. REVISION: 00-00-00SCALE: 1"= 2000'

EXISTING ROADSLEGEND:

%


%

T7S

PROPOSED ACCESS ROAD

PROPOSED ACCESS 232' +/-

¥

¥

U.S. H

IGHWA

Y 40 1

2.1 MI

. +/-

VERN

AL 26

.1 MI. +

/-STA

TE HI

GHWA

Y 88



%

THREE RIVERS FEDERAL#10-41-820 & #10-42-820

EXISTING PIPELINE%

PROPOSED ACCESS FOR THETHREE RIVERS FEDERAL#10-41-820 & #10-42-820 1,444' MI. +/-


CONFIDE

NTIAL


R20E

33 34

T7SWell

PR POSED ACCESS FOR THE- - -«4762 765

THREE RIVERS FEDERAL#10-41-820 & #10-42-820 1,444' MI. +/-

EXISTING PIPELINE

BLM


-- +-- -- --

#3-13-820, #3-14-820,3-23- 0 & #3-24-820

,

THREE RIVERS FEDERAL#10-41-820 & #10 42-820 I c

10

LEGEND: AXIA ENERGYEXISTING ROADS N THREE RIVERS FEDERAL

------- PROPOSED ACCESS ROAD #3-13-820, #3-14-820, #3-23-820 & #3-24-820SECTION 3, T8S, R20E, S.L.B.&M.

NW 1/4 SW 1/4

- Uintah Engineering & Land Surveying ACCESS ROAD 07 09 13 |85 South 200 East Vernal, Utah 84078 M A P MONTH DAY YEAR g(435) 789-1017 * FAX (435) 789-1813 SCALE:1"=2000' DRAWNBY:S.O. REVISION:00-00-00



R20E

33 34

T7SWell



EXISTING PIPELINE

BLM


-- + #3-13-820, #3-14-820,3-23- 0 & #3-24-820

,


10



NW 1/4 SW 1/4




R20E

33 34

T7SWell



EXISTING PIPELINE

BLM


-- + #3-13-820, #3-14-820,3-23- 0 & #3-24-820

,


10



NW 1/4 SW 1/4




R20E

33 34

T7SWell



EXISTING PIPELINE

BLM


-- + #3-13-820, #3-14-820,3-23- 0 & #3-24-820

,


10



NW 1/4 SW 1/4





MM

NORTH OURAY UNIT 3

NORTH OURAY UNIT 2

THREE RIVERS 2-15-820

THREE RIVERS 2-23-820THREE RIVERS 2-13-820

THREE RIVERS FED 34-15-720

THREE RIVERS FEDERAL 3-32-820

130907MONTH DAY YEAR C

TOPO³ TOPOGRAPHICMAPUELS

R20E

AXIA ENERGY

T8S


LEGEND:

T7S

DISPOSAL WELLSPRODUCING WELLSSHUT IN WELLS

ABANDONED WELLSTEMPORARILY ABANDONED

(

!\M

··

%





CONFIDE

NTIAL


20E

33 34 35

NORTH OU UNIT•3

T7S- - so THREE RIVERS FED 34-15-720 Gas

We T8SI ,I

NORTH OURAY UNI 2

-- THREE RIVERS FEDEI L 3-32-820


THREE RIVERS 2 1 820

PROPOSED LOCATION:THREE RIVERS FEDERAL THREE RIVERS 2-15-820

. #3-13-820, #3-14-820,‡3-23-8 & #3-24-820

- --4 /

15 14

LEGEND: AXIA ENERGYDISPOSAL WELLS N THREE RIVERS FEDERAL

® PRODUCING WELLS ABANDONED WELLS #3-13-820, #3-14-820, #3-23-820 & #3-24-820SECTION 3, T8S, R20E, S.L.B.&M.

-®--SHUT IN WELLS TEMPORARILY ABANDONED NW 1/4 SW 1/4

- Uintah Engineering & Land Surveying TOPOGRAPHIC 07 09 1385 South 200 East Vernal, Utah 84078 M A P MONTH DAY YEAR

(435) 789-1017 * FAX (435) 789-1813 SCALE:1"=2000' DRAWNBY:S.O. REVISION:00-00-00



20E

33 34 35

NORTH OU UNIT•3


We T8SI ,I

NORTH OURAY UNI 2





. #3-13-820, #3-14-820,‡3-23-8 & #3-24-820

- --4 /

15 14



-® -SHUT IN WELLS TEMPORARILY ABANDONED NW 1/4 SW 1/4





20E

33 34 35

NORTH OU UNIT•3


We T8SI ,I

NORTH OURAY UNI 2





. #3-13-820, #3-14-820,‡3-23-8 & #3-24-820

- --4 /

15 14








20E

33 34 35

NORTH OU UNIT•3


We T8SI ,I

NORTH OURAY UNI 2





. #3-13-820, #3-14-820,‡3-23-8 & #3-24-820

- --4 /

15 14









BLM

130907MONTH DAY YEAR D


R20E

AXIA ENERGY

T8S


LEGEND:

T7S%

PROPOSED PIPELINE FOR THE THREE RIVERS FEDERAL#10-41-820 & #10-42-820

PROPOSED ACCESS ROADEXISTING ROADSEXISTING PIPELINEPROPOSED PIPELINEPROPOSED PIPELINE (SERVICING OTHER WELLS)

APPROXIMATE TOTAL PIPELINE DISTANCE = 256' +/-

%

EXISTING PIPELINE

SEE DETAIL "A"

DETAIL "A"

%

PROPOSED PIPELINE

%

PROPOSED ACCESS ROAD%

TIE-IN POINT




%



CONFIDE

NTIAL


I e•e i e a

I

33 en|4811

I

IDETAIL "A"

T7ST8S

I trI

EXISTING PIPELINE4 2

SEE DE AIL A

PROPOSED LOCATION:THREE RIVERS FEDERAL#3-13-820, #3-14-820,#3-23-820 & #3-24-820

,

THREE RIVERS FEDERAL¯ #10-41-820 & #10-42-820

10


LEGEND: AXIA ENERGYEXISTING ROADS N THREE RIVERS FEDERALPROPOSED ACCESS ROAD

------- EXISTING PIPELINE #3-13-820, #3-14-820, #3-23-820 & #3-24-820----------- PROPOSED PIPELINE SECTION 3, T8S, R20E, S.L.B.&M.----------- PROPOSED PIPELINE NW 1/4 SW 1/4

(SERVICING OTHER WELLS)

- Uintah Engineering & Land Surveying TOPOGRAPHIC 07 09 13 |85 South 200 East Vernal, Utah 84078 M A P AIONTH DAY YEAR |(435) 789-1017 * FAX (435) 789-1813 SCALE:1"=2000' DRAWNBY:S.O. REVISION:00-00-00



I e•e i e a

I

33 en|4811

I

IDETAIL "A"

T7ST8S

I trI


SEE DE AIL A


,


10








I e•e i e a

I

33 en|4811

I

IDETAIL "A"

T7ST8S

I trI


SEE DE AIL A


,


10








I e•e i e a

I

33 en|4811

I

IDETAIL "A"

T7ST8S

I trI


SEE DE AIL A


,


10









BLM

130907MONTH DAY YEAR E


R20E

AXIA ENERGY

T8S


LEGEND:

T7S

%

PROPOSED ACCESS ROADPROPOSED POWER LINEPROPOSED POWER LINE(SERVICING OTHER WELLS)

APPROXIMATE TOTAL POWER LINE DISTANCE 190' +/-

PROPOSED POWER LINE FOR THE THREE RIVERS FEDERAL #10-41-820 & #10-42-820SEE DETAIL "A"

DETAIL "A"

%

TIE-IN POINT

%

PROPOSED 30' POWERLINE RIGHT OF WAY

%

PROPOSED

ACCESS ROAD


%





CONFIDE

NTIAL


..

R20E

334811

i r-

- --

DETAIL "A"

T8 S

SEE DE AIL " BLM

PROPOSED LOCATION:THREE RIVERS FEDERAL#3-13-820, #3-14-820,

3-23-820 & #3-24-820,

THREE RIVERS EDERAL-- - -- - #10-41-820 & #10-42-820


LEGEND: AXIA ENERGYPROPOSED ACCESS ROAD N THREE RIVERS FEDERALPROPOSED POWER LINE #3-13-820, #3-14-820, #3-23-820 & #3-24-820

PROPOSED POWER LINE SECTION 3, T8S, R20E, S.L.B.&M.(SERVICING OTHER WELLS) NW 1/4 SW 1/4

- Uintah Engineering & Land Surveying TOPOGRAPHIC 07 09 13 |85 South 200 East Vernal, Utah 84078 M A P MONTH DAY YEAR g(435) 789-1017 * FAX (435) 789-1813 SCALE:1"=2000' DRAWNBY:S.O. REVISION:00-00-00



..

R20E

334811

i r-

- --

DETAIL "A"

T8 S

SEE DE AIL " BLM


3-23-820 & #3-24-820,








..

R20E

334811

i r-

- --

DETAIL "A"

T8 S

SEE DE AIL " BLM


3-23-820 & #3-24-820,








..

R20E

334811

i r-

- --

DETAIL "A"

T8 S

SEE DE AIL " BLM


3-23-820 & #3-24-820,








07-22-2013

1000

2000

3000

4000

5000

6000

7000

0 1000

1300 0° 1300 M.D. KOP/ Start Build

2477 24.25° 2513 M.D. End Build

2820 24.25° 2889 M.D. Top Green River

3160 24.25° 3262 M.D. Top Birds Nest

3351 24.25° 3472 M.D. Start Drop

3585 19.22° 3724 M.D. Base Birds Nest

3962 11.4° 4115 M.D. Temperature 120

4528 900' 0° 4684 M.D. Vertical Point

4768 0° 4924 M.D. Garden Gulch 4928 0° 5084 M.D. TGR3

6505 0° 6661 M.D. Top Uteland Butte 6655 0° 6811 M.D. Top Wasatch

6955 900' 0° 7111 M.D. TD

0 250

0

250

500

750

250 250 500 750 1000

Top Green RiverTop Birds NestBase Birds NestTemperature 120Garden GulchTGR3Top Uteland ButteTop Wasatch

2820’ TVD3160’ TVD3585’ TVD3962’ TVD4768’ TVD4928’ TVD6505’ TVD6655’ TVD

Vertical Point899.70' Displacement from S/L@ 53.98° Azimuth from S/LNorth-529.11' East-727.67' of S/LTVD-4528' MD-4684' Y=7228651', X=2155524.9'TDTVD-6955’ MD-7111’

Rate of Build2°/100'MD

Rate of Drop2°/100'MD

Vertical Section1” =1000’

Plane of Proposal53.98° Azimuth

Average Angle24.25°

Surface LocationY=7228121.84'X=2154797.21'NAD83

Horizontal Plan1” =500’

N

Axia EnergyThree Rivers 3-23-820

Uintah County, UT

BighornDirectional

Incorporated

Denver, Colorado303-463-1919


CONFIDE

NTIAL


Axia EnergyThree Rivers 3-23-820 Horizon5tal0Plan

Uintah County, UTN verticalpoint

899.70' Displacement from SIL@ 53.98° Azimuth from SILNorth-529.11' East-727.67' of SILTVD-4528' MD-4684'Y=7228651',X=2155524.9'TDWD-6955' MD-7111'

Plane of Proposal 750 -53.98° AzimuthVertical Section

1" =1000'

500 -1000

1300 0° 1300 M.D. KOP/ Start Build250 -

Rate of Build

O

2°/100'MD 02000

2477 24.25° 2513 M.D. End Build 250250 0 \ 250 500 750 1000

282024.25° 2889 M.D. Top Green River .

Average AnqIe Surface Location24.25° Y=7228121.84'

3000 X=2154797.21'3160 24.25° 3262 M.D. Top Birds Nest NAD83

3351 24.25° 3472 M.D. Start Drop

358519.22° 3724 M.D. Base Birds Nest Rate of Drop2°/100'MD

3962 400011.4° 4115 M.D. Temperature 120

4528 900',

0° 4684 M.D. Vertical PointTop Green River 2820' TVD4768 ,

0° 4924 M.D. Garden Gulch Top Birds Nest 3160' TVD4928 ,

0° 5084 M.D. TGR3 Base Birds Nest 3585' TVD5000 Temperature 120 3962' TVDGarden Gulch 4768' TVDTGR3 4928' TVDTop Uteland Butte 6505' TVDTop Wasatch 6655' TVD

6000

6505 c,0° 6661 M.D. Top Uteland Butte

6655 c,0° 6811 M.D. Top Wasatch

69557000

900',

0°7111 M.D. TD

BighornDirection

incorpor ed

10000 Denver, Colorado

303-463-1919

07-22-2013







1" =1000'

500 -1000


Rate of Build

O

2°/100'MD 02000

2477 24.25° 2513 M.D. End Build 250250 0 \ 250 500 750 1000




3351 24.25° 3472 M.D. Start Drop


3962 400011.4° 4115 M.D. Temperature 120

4528 900',




6000



69557000

900',

0°7111 M.D. TD

BighornDirection

incorpor ed


303-463-1919

07-22-2013







1" =1000'

500 -1000


Rate of Build

O

2°/100'MD 02000

2477 24.25° 2513 M.D. End Build 250250 0 \ 250 500 750 1000




3351 24.25° 3472 M.D. Start Drop


3962 400011.4° 4115 M.D. Temperature 120

4528 900',




6000



69557000

900',

0°7111 M.D. TD

BighornDirection

incorpor ed


303-463-1919

07-22-2013







1" =1000'

500 -1000


Rate of Build

O

2°/100'MD 02000

2477 24.25° 2513 M.D. End Build 250250 0 \ 250 500 750 1000




3351 24.25° 3472 M.D. Start Drop


3962 400011.4° 4115 M.D. Temperature 120

4528 900',




6000



69557000

900',

0°7111 M.D. TD

BighornDirection

incorpor ed


303-463-1919

07-22-2013



BighornDirectional

Incorporated


Bighorn Directional, Inc.Axia EnergyThree Rivers 3-23-820Uintah County, UT

Plane of Vertical Section: 53.98°Slot Location: 7228121.84', 2154797.21'

Minimum of Curvature

MeasuredDepthFeet

B O R EInc

Degrees

H O L EDirectionDegrees

TrueVerticalDepthFeet

R E C T A N G U L A RC O O R D I N A T E S

North(-South) East(-West)Feet Feet

L A M B E R TC O O R D I N A T E S

Y XFeet Feet

C L O S U R E SDistance Direction

Feet Deg

VerticalSection

Feet

DoglegSeverityDeg/100'

Page: 1

1300.00 0.00 0.00 1300.00 0.00 0.00 7228121.8 2154797.2 0.00 0.000.00 0.00KOP/ Start Build

1400.00 2.00 53.98 1399.98 1.03 1.41 7228122.9 2154798.6 1.75 53.981.75 2.001500.00 4.00 53.98 1499.84 4.10 5.64 7228125.9 2154802.9 6.98 53.986.98 2.001600.00 6.00 53.98 1599.45 9.23 12.69 7228131.1 2154809.9 15.69 53.9815.69 2.001700.00 8.00 53.98 1698.70 16.40 22.55 7228138.2 2154819.8 27.88 53.9827.88 2.00

1800.00 10.00 53.98 1797.47 25.60 35.20 7228147.4 2154832.4 43.52 53.9843.52 2.001900.00 12.00 53.98 1895.62 36.82 50.63 7228158.7 2154847.8 62.60 53.9862.60 2.002000.00 14.00 53.98 1993.06 50.04 68.83 7228171.9 2154866.0 85.10 53.9885.10 2.002100.00 16.00 53.98 2089.64 65.27 89.76 7228187.1 2154887.0 110.98 53.98110.98 2.002200.00 18.00 53.98 2185.27 82.46 113.40 7228204.3 2154910.6 140.21 53.98140.21 2.00

2300.00 20.00 53.98 2279.82 101.60 139.73 7228223.4 2154936.9 172.77 53.98172.77 2.002400.00 22.00 53.98 2373.17 122.68 168.72 7228244.5 2154965.9 208.60 53.98208.60 2.002500.00 24.00 53.98 2465.21 145.66 200.32 7228267.5 2154997.5 247.67 53.98247.67 2.002512.76 24.25 53.98 2476.86 148.72 204.54 7228270.6 2155001.7 252.89 53.98252.89 2.00

End Build2889.12 24.25 53.98 2820.00 239.65 329.58 7228361.5 2155126.8 407.50 53.98407.50 0.00

Top Green River

3262.04 24.25 53.98 3160.00 329.74 453.48 7228451.6 2155250.7 560.69 53.98560.69 0.00Top Birds Nest

3471.69 24.25 53.98 3351.14 380.39 523.14 7228502.2 2155320.4 646.82 53.98646.82 0.00Start Drop

3571.69 22.25 53.98 3443.01 403.61 555.07 7228525.5 2155352.3 686.30 53.98686.30 2.003671.69 20.25 53.98 3536.21 424.93 584.39 7228546.8 2155381.6 722.55 53.98722.55 2.003723.53 19.22 53.98 3585.00 435.22 598.55 7228557.1 2155395.8 740.05 53.98740.05 2.00

Base Birds Nest

3823.53 17.22 53.98 3679.98 453.61 623.83 7228575.5 2155421.0 771.32 53.98771.32 2.003923.53 15.22 53.98 3776.00 470.03 646.42 7228591.9 2155443.6 799.24 53.98799.24 2.00


CONFIDE

NTIAL


Bighorn Directional, Inc.Page: 1Axia Energy

Three Rivers 3-23-820Bighorn Minimum of Curvature

Uintah County, UT Slot Location: 7228121.84', 2154797.21'wam Plane of Vertical Section: 53.98°

True RECTANGULAR LAMBERTMeasured BORE HOLE Vertical COORDINATES COORDINATES Vertical CLOSURES Dogleg

Depth Inc Direction Depth North(-South) East(-West) Y X Section Distance Direction SeverityFeet Degrees Degrees Feet Feet Feet Feet Feet Feet Feet Deg Deg/100'

1300.00 0.00 0.00 1300.00 0.00 0.00 7228121.8 2154797.2 0.00 0.00 0.00 0.00KOP/ Start Build

1400.00 2.00 53.98 1399.98 1.03 1.41 7228122.9 2154798.6 1.75 1.75 53.98 2.001500.00 4.00 53.98 1499.84 4.10 5.64 7228125.9 2154802.9 6.98 6.98 53.98 2.001600.00 6.00 53.98 1599.45 9.23 12.69 7228131.1 2154809.9 15.69 15.69 53.98 2.001700.00 8.00 53.98 1698.70 16.40 22.55 7228138.2 2154819.8 27.88 27.88 53.98 2.00

1800.00 10.00 53.98 1797.47 25.60 35.20 7228147.4 2154832.4 43.52 43.52 53.98 2.001900.00 12.00 53.98 1895.62 36.82 50.63 7228158.7 2154847.8 62.60 62.60 53.98 2.002000.00 14.00 53.98 1993.06 50.04 68.83 7228171.9 2154866.0 85.10 85.10 53.98 2.002100.00 16.00 53.98 2089.64 65.27 89.76 7228187.1 2154887.0 110.98 110.98 53.98 2.002200.00 18.00 53.98 2185.27 82.46 113.40 7228204.3 2154910.6 140.21 140.21 53.98 2.00

2300.00 20.00 53.98 2279.82 101.60 139.73 7228223.4 2154936.9 172.77 172.77 53.98 2.002400.00 22.00 53.98 2373.17 122.68 168.72 7228244.5 2154965.9 208.60 208.60 53.98 2.002500.00 24.00 53.98 2465.21 145.66 200.32 7228267.5 2154997.5 247.67 247.67 53.98 2.002512.76 24.25 53.98 2476.86 148.72 204.54 7228270.6 2155001.7 252.89 252.89 53.98 2.00

End Build2889.12 24.25 53.98 2820.00 239.65 329.58 7228361.5 2155126.8 407.50 407.50 53.98 0.00

Top Green River

3262.04 24.25 53.98 3160.00 329.74 453.48 7228451.6 2155250.7 560.69 560.69 53.98 0.00Top Birds Nest

3471.69 24.25 53.98 3351.14 380.39 523.14 7228502.2 2155320.4 646.82 646.82 53.98 0.00Start Drop

3571.69 22.25 53.98 3443.01 403.61 555.07 7228525.5 2155352.3 686.30 686.30 53.98 2.003671.69 20.25 53.98 3536.21 424.93 584.39 7228546.8 2155381.6 722.55 722.55 53.98 2.003723.53 19.22 53.98 3585.00 435.22 598.55 7228557.1 2155395.8 740.05 740.05 53.98 2.00

Base Birds Nest

3823.53 17.22 53.98 3679.98 453.61 623.83 7228575.5 2155421.0 771.32 771.32 53.98 2.003923.53 15.22 53.98 3776.00 470.03 646.42 7228591.9 2155443.6 799.24 799.24 53.98 2.00





Uintah County, UT Slot Location: 7228121.84', 2154797.21'Plane of Vertical Section: 53.98°



1300.00 0.00 0.00 1300.00 0.00 0.00 7228121.8 2154797.2 0.00 0.00 0.00 0.00KOP/ Start Build

1400.00 2.00 53.98 1399.98 1.03 1.41 7228122.9 2154798.6 1.75 1.75 53.98 2.001500.00 4.00 53.98 1499.84 4.10 5.64 7228125.9 2154802.9 6.98 6.98 53.98 2.001600.00 6.00 53.98 1599.45 9.23 12.69 7228131.1 2154809.9 15.69 15.69 53.98 2.001700.00 8.00 53.98 1698.70 16.40 22.55 7228138.2 2154819.8 27.88 27.88 53.98 2.00

1800.00 10.00 53.98 1797.47 25.60 35.20 7228147.4 2154832.4 43.52 43.52 53.98 2.001900.00 12.00 53.98 1895.62 36.82 50.63 7228158.7 2154847.8 62.60 62.60 53.98 2.002000.00 14.00 53.98 1993.06 50.04 68.83 7228171.9 2154866.0 85.10 85.10 53.98 2.002100.00 16.00 53.98 2089.64 65.27 89.76 7228187.1 2154887.0 110.98 110.98 53.98 2.002200.00 18.00 53.98 2185.27 82.46 113.40 7228204.3 2154910.6 140.21 140.21 53.98 2.00

2300.00 20.00 53.98 2279.82 101.60 139.73 7228223.4 2154936.9 172.77 172.77 53.98 2.002400.00 22.00 53.98 2373.17 122.68 168.72 7228244.5 2154965.9 208.60 208.60 53.98 2.002500.00 24.00 53.98 2465.21 145.66 200.32 7228267.5 2154997.5 247.67 247.67 53.98 2.002512.76 24.25 53.98 2476.86 148.72 204.54 7228270.6 2155001.7 252.89 252.89 53.98 2.00

End Build2889.12 24.25 53.98 2820.00 239.65 329.58 7228361.5 2155126.8 407.50 407.50 53.98 0.00

Top Green River

3262.04 24.25 53.98 3160.00 329.74 453.48 7228451.6 2155250.7 560.69 560.69 53.98 0.00Top Birds Nest

3471.69 24.25 53.98 3351.14 380.39 523.14 7228502.2 2155320.4 646.82 646.82 53.98 0.00Start Drop

3571.69 22.25 53.98 3443.01 403.61 555.07 7228525.5 2155352.3 686.30 686.30 53.98 2.003671.69 20.25 53.98 3536.21 424.93 584.39 7228546.8 2155381.6 722.55 722.55 53.98 2.003723.53 19.22 53.98 3585.00 435.22 598.55 7228557.1 2155395.8 740.05 740.05 53.98 2.00

Base Birds Nest

3823.53 17.22 53.98 3679.98 453.61 623.83 7228575.5 2155421.0 771.32 771.32 53.98 2.003923.53 15.22 53.98 3776.00 470.03 646.42 7228591.9 2155443.6 799.24 799.24 53.98 2.00








1300.00 0.00 0.00 1300.00 0.00 0.00 7228121.8 2154797.2 0.00 0.00 0.00 0.00KOP/ Start Build

1400.00 2.00 53.98 1399.98 1.03 1.41 7228122.9 2154798.6 1.75 1.75 53.98 2.001500.00 4.00 53.98 1499.84 4.10 5.64 7228125.9 2154802.9 6.98 6.98 53.98 2.001600.00 6.00 53.98 1599.45 9.23 12.69 7228131.1 2154809.9 15.69 15.69 53.98 2.001700.00 8.00 53.98 1698.70 16.40 22.55 7228138.2 2154819.8 27.88 27.88 53.98 2.00

1800.00 10.00 53.98 1797.47 25.60 35.20 7228147.4 2154832.4 43.52 43.52 53.98 2.001900.00 12.00 53.98 1895.62 36.82 50.63 7228158.7 2154847.8 62.60 62.60 53.98 2.002000.00 14.00 53.98 1993.06 50.04 68.83 7228171.9 2154866.0 85.10 85.10 53.98 2.002100.00 16.00 53.98 2089.64 65.27 89.76 7228187.1 2154887.0 110.98 110.98 53.98 2.002200.00 18.00 53.98 2185.27 82.46 113.40 7228204.3 2154910.6 140.21 140.21 53.98 2.00

2300.00 20.00 53.98 2279.82 101.60 139.73 7228223.4 2154936.9 172.77 172.77 53.98 2.002400.00 22.00 53.98 2373.17 122.68 168.72 7228244.5 2154965.9 208.60 208.60 53.98 2.002500.00 24.00 53.98 2465.21 145.66 200.32 7228267.5 2154997.5 247.67 247.67 53.98 2.002512.76 24.25 53.98 2476.86 148.72 204.54 7228270.6 2155001.7 252.89 252.89 53.98 2.00

End Build2889.12 24.25 53.98 2820.00 239.65 329.58 7228361.5 2155126.8 407.50 407.50 53.98 0.00

Top Green River

3262.04 24.25 53.98 3160.00 329.74 453.48 7228451.6 2155250.7 560.69 560.69 53.98 0.00Top Birds Nest

3471.69 24.25 53.98 3351.14 380.39 523.14 7228502.2 2155320.4 646.82 646.82 53.98 0.00Start Drop

3571.69 22.25 53.98 3443.01 403.61 555.07 7228525.5 2155352.3 686.30 686.30 53.98 2.003671.69 20.25 53.98 3536.21 424.93 584.39 7228546.8 2155381.6 722.55 722.55 53.98 2.003723.53 19.22 53.98 3585.00 435.22 598.55 7228557.1 2155395.8 740.05 740.05 53.98 2.00

Base Birds Nest

3823.53 17.22 53.98 3679.98 453.61 623.83 7228575.5 2155421.0 771.32 771.32 53.98 2.003923.53 15.22 53.98 3776.00 470.03 646.42 7228591.9 2155443.6 799.24 799.24 53.98 2.00








1300.00 0.00 0.00 1300.00 0.00 0.00 7228121.8 2154797.2 0.00 0.00 0.00 0.00KOP/ Start Build

1400.00 2.00 53.98 1399.98 1.03 1.41 7228122.9 2154798.6 1.75 1.75 53.98 2.001500.00 4.00 53.98 1499.84 4.10 5.64 7228125.9 2154802.9 6.98 6.98 53.98 2.001600.00 6.00 53.98 1599.45 9.23 12.69 7228131.1 2154809.9 15.69 15.69 53.98 2.001700.00 8.00 53.98 1698.70 16.40 22.55 7228138.2 2154819.8 27.88 27.88 53.98 2.00

1800.00 10.00 53.98 1797.47 25.60 35.20 7228147.4 2154832.4 43.52 43.52 53.98 2.001900.00 12.00 53.98 1895.62 36.82 50.63 7228158.7 2154847.8 62.60 62.60 53.98 2.002000.00 14.00 53.98 1993.06 50.04 68.83 7228171.9 2154866.0 85.10 85.10 53.98 2.002100.00 16.00 53.98 2089.64 65.27 89.76 7228187.1 2154887.0 110.98 110.98 53.98 2.002200.00 18.00 53.98 2185.27 82.46 113.40 7228204.3 2154910.6 140.21 140.21 53.98 2.00

2300.00 20.00 53.98 2279.82 101.60 139.73 7228223.4 2154936.9 172.77 172.77 53.98 2.002400.00 22.00 53.98 2373.17 122.68 168.72 7228244.5 2154965.9 208.60 208.60 53.98 2.002500.00 24.00 53.98 2465.21 145.66 200.32 7228267.5 2154997.5 247.67 247.67 53.98 2.002512.76 24.25 53.98 2476.86 148.72 204.54 7228270.6 2155001.7 252.89 252.89 53.98 2.00

End Build2889.12 24.25 53.98 2820.00 239.65 329.58 7228361.5 2155126.8 407.50 407.50 53.98 0.00

Top Green River

3262.04 24.25 53.98 3160.00 329.74 453.48 7228451.6 2155250.7 560.69 560.69 53.98 0.00Top Birds Nest

3471.69 24.25 53.98 3351.14 380.39 523.14 7228502.2 2155320.4 646.82 646.82 53.98 0.00Start Drop

3571.69 22.25 53.98 3443.01 403.61 555.07 7228525.5 2155352.3 686.30 686.30 53.98 2.003671.69 20.25 53.98 3536.21 424.93 584.39 7228546.8 2155381.6 722.55 722.55 53.98 2.003723.53 19.22 53.98 3585.00 435.22 598.55 7228557.1 2155395.8 740.05 740.05 53.98 2.00

Base Birds Nest

3823.53 17.22 53.98 3679.98 453.61 623.83 7228575.5 2155421.0 771.32 771.32 53.98 2.003923.53 15.22 53.98 3776.00 470.03 646.42 7228591.9 2155443.6 799.24 799.24 53.98 2.00



BighornDirectional

Incorporated


Bighorn Directional, Inc.Axia EnergyThree Rivers 3-23-820Uintah County, UT

Plane of Vertical Section: 53.98°Slot Location: 7228121.84', 2154797.21'

Minimum of Curvature

MeasuredDepthFeet

B O R EInc

Degrees

H O L EDirectionDegrees

TrueVerticalDepthFeet

R E C T A N G U L A RC O O R D I N A T E S

North(-South) East(-West)Feet Feet

L A M B E R TC O O R D I N A T E S

Y XFeet Feet

C L O S U R E SDistance Direction

Feet Deg

VerticalSection

Feet

DoglegSeverityDeg/100'

Page: 2

4023.53 13.22 53.98 3872.93 484.48 666.29 7228606.3 2155463.5 823.80 53.98823.80 2.004114.70 11.40 53.98 3962.00 495.90 682.00 7228617.7 2155479.2 843.24 53.98843.24 2.00

Temperature 1204214.70 9.40 53.98 4060.36 506.51 696.59 7228628.4 2155493.8 861.28 53.98861.28 2.004314.70 7.39 53.98 4159.28 515.10 708.40 7228636.9 2155505.6 875.88 53.98875.88 2.004414.70 5.39 53.98 4258.65 521.65 717.41 7228643.5 2155514.6 887.01 53.98887.01 2.00

4514.70 3.39 53.98 4358.35 526.16 723.61 7228648.0 2155520.8 894.68 53.98894.68 2.004614.70 1.39 53.98 4458.26 528.61 726.99 7228650.5 2155524.2 898.86 53.98898.86 2.004684.45 0.00 53.98 4528.00 529.11 727.67 7228651.0 2155524.9 899.70 53.98899.70 2.00

Vertical Point4924.45 0.00 53.98 4768.00 529.11 727.67 7228651.0 2155524.9 899.70 53.98899.70 0.00

Garden Gulch5084.45 0.00 53.98 4928.00 529.11 727.67 7228651.0 2155524.9 899.70 53.98899.70 0.00

TGR3

6661.45 0.00 53.98 6505.00 529.11 727.67 7228651.0 2155524.9 899.70 53.98899.70 0.00Top Uteland Butte

6811.45 0.00 53.98 6655.00 529.11 727.67 7228651.0 2155524.9 899.70 53.98899.70 0.00Top Wasatch

7111.45 0.00 53.98 6955.00 529.11 727.67 7228651.0 2155524.9 899.70 53.98899.70 0.00TDFinal Station Closure Distance: 899.70' Direction: 53.98°


CONFIDE

NTIAL




Uintah County, UT Slot Location: 7228121.84', 2154797.21'wam Plane of Vertical Section: 53.98°



4023.53 13.22 53.98 3872.93 484.48 666.29 7228606.3 2155463.5 823.80 823.80 53.98 2.004114.70 11.40 53.98 3962.00 495.90 682.00 7228617.7 2155479.2 843.24 843.24 53.98 2.00

Temperature 1204214.70 9.40 53.98 4060.36 506.51 696.59 7228628.4 2155493.8 861.28 861.28 53.98 2.004314.70 7.39 53.98 4159.28 515.10 708.40 7228636.9 2155505.6 875.88 875.88 53.98 2.004414.70 5.39 53.98 4258.65 521.65 717.41 7228643.5 2155514.6 887.01 887.01 53.98 2.00

4514.70 3.39 53.98 4358.35 526.16 723.61 7228648.0 2155520.8 894.68 894.68 53.98 2.004614.70 1.39 53.98 4458.26 528.61 726.99 7228650.5 2155524.2 898.86 898.86 53.98 2.004684.45 0.00 53.98 4528.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 2.00

Vertical Point4924.45 0.00 53.98 4768.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00

Garden Gulch5084.45 0.00 53.98 4928.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00

TGR3

6661.45 0.00 53.98 6505.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00Top Uteland Butte

6811.45 0.00 53.98 6655.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00Top Wasatch

7111.45 0.00 53.98 6955.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00TDFinal Station Closure Distance: 899.70' Direction: 53.98°








4023.53 13.22 53.98 3872.93 484.48 666.29 7228606.3 2155463.5 823.80 823.80 53.98 2.004114.70 11.40 53.98 3962.00 495.90 682.00 7228617.7 2155479.2 843.24 843.24 53.98 2.00

Temperature 1204214.70 9.40 53.98 4060.36 506.51 696.59 7228628.4 2155493.8 861.28 861.28 53.98 2.004314.70 7.39 53.98 4159.28 515.10 708.40 7228636.9 2155505.6 875.88 875.88 53.98 2.004414.70 5.39 53.98 4258.65 521.65 717.41 7228643.5 2155514.6 887.01 887.01 53.98 2.00

4514.70 3.39 53.98 4358.35 526.16 723.61 7228648.0 2155520.8 894.68 894.68 53.98 2.004614.70 1.39 53.98 4458.26 528.61 726.99 7228650.5 2155524.2 898.86 898.86 53.98 2.004684.45 0.00 53.98 4528.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 2.00

Vertical Point4924.45 0.00 53.98 4768.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00

Garden Gulch5084.45 0.00 53.98 4928.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00

TGR3


6811.45 0.00 53.98 6655.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00Top Wasatch









4023.53 13.22 53.98 3872.93 484.48 666.29 7228606.3 2155463.5 823.80 823.80 53.98 2.004114.70 11.40 53.98 3962.00 495.90 682.00 7228617.7 2155479.2 843.24 843.24 53.98 2.00

Temperature 1204214.70 9.40 53.98 4060.36 506.51 696.59 7228628.4 2155493.8 861.28 861.28 53.98 2.004314.70 7.39 53.98 4159.28 515.10 708.40 7228636.9 2155505.6 875.88 875.88 53.98 2.004414.70 5.39 53.98 4258.65 521.65 717.41 7228643.5 2155514.6 887.01 887.01 53.98 2.00

4514.70 3.39 53.98 4358.35 526.16 723.61 7228648.0 2155520.8 894.68 894.68 53.98 2.004614.70 1.39 53.98 4458.26 528.61 726.99 7228650.5 2155524.2 898.86 898.86 53.98 2.004684.45 0.00 53.98 4528.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 2.00

Vertical Point4924.45 0.00 53.98 4768.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00

Garden Gulch5084.45 0.00 53.98 4928.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00

TGR3


6811.45 0.00 53.98 6655.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00Top Wasatch









4023.53 13.22 53.98 3872.93 484.48 666.29 7228606.3 2155463.5 823.80 823.80 53.98 2.004114.70 11.40 53.98 3962.00 495.90 682.00 7228617.7 2155479.2 843.24 843.24 53.98 2.00

Temperature 1204214.70 9.40 53.98 4060.36 506.51 696.59 7228628.4 2155493.8 861.28 861.28 53.98 2.004314.70 7.39 53.98 4159.28 515.10 708.40 7228636.9 2155505.6 875.88 875.88 53.98 2.004414.70 5.39 53.98 4258.65 521.65 717.41 7228643.5 2155514.6 887.01 887.01 53.98 2.00

4514.70 3.39 53.98 4358.35 526.16 723.61 7228648.0 2155520.8 894.68 894.68 53.98 2.004614.70 1.39 53.98 4458.26 528.61 726.99 7228650.5 2155524.2 898.86 898.86 53.98 2.004684.45 0.00 53.98 4528.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 2.00

Vertical Point4924.45 0.00 53.98 4768.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00

Garden Gulch5084.45 0.00 53.98 4928.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00

TGR3


6811.45 0.00 53.98 6655.00 529.11 727.67 7228651.0 2155524.9 899.70 899.70 53.98 0.00Top Wasatch





CONFIDE

NTIAL


3000 psi

B0P Equipment"°"'ANG

3000psi WPANNUI.AR

PREVENTOR

CHOKEMANIFOLD2° MIN. ADJUSTABLE 3000 psiCHOKE BLINDRAMS

TOMUD/GASSEPARATORORPlT ° O 3000 psio o o PIPERAMS

O3" MIN. MANUAL MANUAL

RATEDTO VALVE VALVE---- 3000 PSIG

0MANUAL REMOTEVALVE VALVE

¯2" LINE

LINEPlT 3" LINETOCHOKE ,,,,,,,aaaaapoooooopapaçoaço 3 0 pL

MANIFOLDCHECK

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CASINGHEADWITHTHD'O

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3000 psi


3000psi WPANNUI.AR

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MANIFOLDCHECK

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QUTLETSAND0 VALVES

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3000 psi


3000psi WPANNUI.AR

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2580 Creekview Road Moab, Utah 84532 435/719-2018

August 12, 2013 Mrs. Diana Mason State of Utah Division of Oil Gas and Mining P.O. Box 145801 Salt Lake City, Utah 84114-5801 RE: Request for Exception to Spacing – Axia Energy, LLC – Three Rivers Federal 3-23-820 Surface Location: 1475’ FSL & 1237’ FWL, NW/4 SW/4, Section 3, T8S, R20E, Target Location: 1980’ FSL & 1980’ FWL, NE/4 SW/4, Section 3, T8S, R20E, SLB&M, Uintah County, Utah Dear Diana: Axia Energy, LLC respectfully submits this request for exception to spacing (R649-3-11) based on geology since the well is located less than 460 feet to the drilling unit boundary. Axia Energy, LLC is the only owner and operator within 460 feet of the surface and target location, as well as all points along the intended well bore path, and neither the surface nor target locations are within 460 feet of any uncommitted tracts or a unit boundary. Thank you very much for your timely consideration of this application. Please feel free to contact Jess A. Peonio of Axia Energy, LLC at 720-746-5212 or myself should you have any questions or need additional information. Sincerely,

Don Hamilton Agent for Axia Energy, LLC cc: Jess A. Peonio, Axia Energy, LLC


CONFIDE

NTIAL


2580 Creekview RoadMoab, Utah 84532435/719-2018

August 12, 2013

Mrs. Diana MasonState of UtahDivision of Oil Gas and MiningP.O. Box 145801Salt Lake City, Utah 84114-5801

RE: Request for Exception to Spacing - Axia Energy, LLC -

Three Rivers Federal 3-23-820Surface Location: 1475' FSL & 1237' FWL, NW/4 SW/4, Section 3, T8S, R20E,Target Location: 1980' FSL & 1980' FWL, NE/4 SW/4, Section 3, T8S, R20E,

SLB&M, Uintah County, Utah

Dear Diana:

Axia Energy, LLC respectfully submits this request for exception to spacing (R649-3-11) based ongeology since the well is located less than 460 feet to the drilling unit boundary. Axia Energy,LLC is the only owner and operator within 460 feet of the surface and target location, as well asall points along the intended well bore path, and neither the surface nor target locations arewithin 460 feet of any uncommitted tracts or a unit boundary.

Thank you very much for your timely consideration of this application. Please feel free tocontact Jess A. Peonio of Axia Energy, LLC at 720-746-5212 or myself should you have anyquestions or need additional information.

Sincerely,

Don HamiltonAgent for Axia Energy, LLC

cc: Jess A. Peonio, Axia Energy, LLC




August 12, 20 13



Three Rivers Federal 3-23-820Surface Location: 1475' FSL & 123T FWL, NW/4 SW/4, Section 3, TSS, R20E,Target Location: 1980' FSL & 1980' FWL, NE/4 SW/4, Section 3, TSS, R20E,


Dear Diana:



Sincerely,






August 12, 20 13





Dear Diana:



Sincerely,






August 12, 20 13





Dear Diana:



Sincerely,





ROBERT L.KAY

No. 161319

A


CONFIDE

NTIAL


AXIA ENERGY FIGURE #1LOCATION LAYOUT FOR SCALE: 1" = 60'

THREE RIVERS FEDERAL #3-13-820, DATE: 06-28-13

#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.


Topsoil Stockpi/e E-16.O'C-8.9 E/. 2 O'

1d

C ner

OCut Slope E/. 42.5'I N_ Nolll

Flare Pit is to belocated a min. of 100from/the WeHHead

C-7.8' C-6.1 C-2.25508 49.1' E/ 5.2'

/ 0 E/. 32.2'(Strn. Pit) 45' 35 35 ' 5 T05' Sta. 1+70

SER VE P/ TS10' De p) C-5.5

r"an n LineNOTE:Earthwork Calculations Require a

- - Fill of 2.7' @ #3-24-820 Location \-'¯- N - Stake For Balance. All Fill is total Pit C acity 5- be Compacted to a Minimum of-

re boa--- 95% of the Maximum Dry Density 0+70

cv '¯ Obtained by AASHTO Method t-99.

C-4.2 C-2.8'E/. 47.2' E/. 45.8'

-1

¯

\ \ 210' Sta. 0+00(Btrn. Pit)

-4.6

E/. 38.4'Reserve Pit Backfill

Existing Proposed2- Track¯ Access Road

E/ev. Ungraded Ground At /J-14-820 Loc. Stoke = 4745.2' UINTAH ENGINEERING & LAND SURVEYINGE/N/SHED GRADE ELEV A T /3-14-820 LOC. STAKE = 474 J. O' 85 So. 200 East * Vernal, Utah 84078 * (435) 789-1017





#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.



1d

C ner



C-7.8' C-6.1 C-2.25508 49.1' E/ 5.2'

/ 0 E/. 32.2'(Strn. Pit) 45' 35 35 ' 5 T05' Sta. 1+70






C-4.2 C-2.8'E/. 47.2' E/. 45.8'

-1

¯

\ \ 210' Sta. 0+00(Btrn. Pit)

-4.6








#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.



1d

C ner



C-7.8' C-6.1 C-2.25508 49.1' E/ 5.2'

/ 0 E/. 32.2'(Strn. Pit) 45' 35 35 ' 5 T05' Sta. 1+70






C-4.2 C-2.8'E/. 47.2' E/. 45.8'

-1

¯

\ \ 210' Sta. 0+00(Btrn. Pit)

-4.6








#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.



1d

C ner

OCut Slope E/. 42.5'I N_ No . 1 1

Elare Pit is to belocated a min. of 100from/the WeHHead

C-7.8' C-6.1 C-2.25508 49.1' E/ 5.2'

/ 0 E/. 32.2'(Strn. Pit) 45' 35 35 ' 5 T05' Sta. 1+70






C-4.2 C-2.8'E/. 47.2' E/. 45.8'

-1

¯

\ \ 210' Sta. 0+00(Btrn. Pit)

-4.6






ROBERT L.KAY

No. 161319

A


CONFIDE

NTIAL


AXIA ENERGY FIGURE #2×-section TYPICAL CROSS SECTIONS FOR '

ScaleTHREE RIVERS FEDERAL #3-13-820,

1" = 100 #3-14-820, #3-23-820 & #3-24-820g LAND

DATE: 06-28-13 SECTION 3, T8S, R20E, S.L.B.&M.DRAWN BY: K.O. ce

NW 1/4 SW 1/4 No. 16131

RO ..

SM. J+50

10' 100' 45' 35' 70' 105'

/J-14-82OLOCAT/ON STAKE

10' 100' 45' 210'I IIII I

155' 210'I II I

/LL Preconstruction

SM. 0+00

NOTE: APPROX/MATE ACREAGE

ITopsoil should not be WELLS/TE D/STURBANCE = ± J.634 ACRESSGrridpepedn

S bstrnctshreed

AreaACCESS ROAD D/STURBANCE = ± 0.159 ACRES

NOLUANT/TYINCLUDES

P/PELINE D/STURBANCE = ± 0.176 ACRES 5% FOR COMPACTIONTOTAL = ± J.969 ACRES

EXCESS MATERIAL = 5,430 Cu. Yds.APPROXIMATE YARDAGES Topsoil & Pit Backfill = 5,4JO Cu. Yds.

(1/2 Pit Vol.)(6") Topsoil Stripping = 2,580 Cu. Yds.

EXCESS UNBALANCE = 0 Cu. Yds.Remaining Location = 18,010 Cu. Yds.(After Interim Rehabilitation)

TOTAL CUT = 20,590 CU. YDS UINTAH ENGINEERING & LAND SURVEYINGFILL = 15, 160 CU. YDS- 85 So. 200 East * Vernal, Utah 84078 * (435) 789-1017





1" = 100 #3-14-820, #3-23-820 & #3-24-820g LAND


NW 1/4 SW 1/4 No. 16131

RO ..

SM. J+50

10' 100' 45' 35' 70' 105'


10' 100' 45' 210'I IIII I

155' 210'I II I

/LL Preconstruction

SM. 0+00



S bstrnctshreed


NOLUANT/TYINCLUDES










1" = 100 #3-14-820, #3-23-820 & #3-24-820g LAND


NW 1/4 SW 1/4 No. 16131

RO ..

SM. J+50

10' 100' 45' 35' 70' 105'


10' 100' 45' 210'I IIII I

155' 210'I II I

/LL Preconstruction

SM. 0+00



S bstrnctshreed


NOLUANT/TYINCLUDES










1" = 100 #3-14-820, #3-23-820 & #3-24-820g LAND


NW 1/4 SW 1/4 No.16131

RO ..

SM. J+50

10' 100' 45' 35' 70' 105'


10' 100' 45' 210'I IIII I

155' 210'I II I

/LL Preconstruction

SM. 0+00



S bstrnctshreed


NOLUANT/TYINCLUDES








ROBERT L.KAY

No. 161319

A


CONFIDE

NTIAL


AXIA ENERGY FIGURE #3TYPICAL RIG LAYOUT FOR ,, ,

THREE RIVERS FEDERAL #3-13-820, DSACAELEO6-28-6103

#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.


opsoil Stockpile

O'

Slope

Nt is to be

located a min. of 100from the Well Head

PIPE RACKS

5

I/ 00 DOGI I I I I - HOUSE O

45' 35' 35' N 5 05

/ L,RIG ¯

PUMP TOIL TO

MUD SHED

2a acPO

RHOPPER

20, 750 ±- total Pit e TOOLS

- 5, 690 Yds

FUEL

1 1 210'

S RAGE

S/o

Reserve Pit Backfill& Spoi/s Stockp//e

<o \ \__------ ' / / Proposed¯~~¯---- Access Road

UINTAH ENGINEERING & LAND SURVEYING85 So. 200 East * Vernal, Utah 84078 * (435) 789-1017





#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.


opsoil Stockpile

O'

Slope

Nt is to be


PIPE RACKS

5


45' 35' 35' N 5 05

/ L,RIG ¯

PUMP TOIL TO

MUD SHED

2a acPO

RHOPPER


- 5, 690 Yds

FUEL

1 1 210'

S RAGE

S/o








#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.


opsoil Stockpile

O'

Slope

Nt is to be


PIPE RACKS

5


45' 35' 35' N 5 05

/ L,RIG ¯

PUMP TOIL TO

MUD SHED

2a acPO

RHOPPER


- 5, 690 Yds

FUEL

1 1 210'

S RAGE

S/o








#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.


opsoil Stockpile -


PIPE RACKS

5


45' 35' 35' N 5 05

/ L,RIG ¯

PUMP TOIL TO

MUD SHED

2a acPO

RHOPPER

20, 750 ±- total Pit e TOOLSII - 5,690 Yds

FUEL

1 1 210'

S RAGE

S/o






ROBERT L.KAY

No. 161319

A


CONFIDE

NTIAL


AXIA ENERGY FIGURE #4INTERIM RECLAMATIONPLAN FOR SCALE: 1" = 60'


#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.


Approx.L $ Toe ofe o Fill Slope

Approx.Top ofCut Slope

#3-24-820 o

#3-23-820 o \

#3-14-820 o

o #3-13-820

M er

ansition Line

ooooCombuster

Water

Treaters

Access Road

INTERIMRECLAMATION APPROX/MA1E ACREAGE UINTAH ENGINEERING & LAND SURVEYINGUN-RECLAIMED = ± 0.911 ACRES 85 So. 200 East * Vernal, UtaA 84078 * (435) 789-1017





#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.




#3-24-820 o

#3-23-820 o \

#3-14-820 o

o #3-13-820

M er

ansition Line

ooooCombuster

Water

Treaters

Access Road






#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.




#3-24-820 o

#3-23-820 o \

#3-14-820 o

o #3-13-820

M er

ansition Line

ooooCombuster

Water

Treaters

Access Road






#3-14-820, #3-23-820 & #3-24-820 DRAWN BY: K.O.




#3-24-820 o

#3-23-820 o \

#3-14-820 o

o #3-13-820

M er

ansition Line

ooooCombuster

Water

Treaters

Access Road




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NORTH OURAYUNIT 34304710605

FEDERAL 14304720450

PELICANLAKE 11-3-8-204304738445

PELICANLAKE 8-4-8-204304738446

THREERIVERS 2-11-820

4304751936

THREE RIVERS2-13-820

4304752687


4304752688


4304752689THREE

RIVERS 2-25-8204304752690

THREERIVERS FEDERAL 3-53-8204304752820THREE RIVERS FEDERAL3-54-8204304752860

THREE RIVERSFEDERAL 3-32-8204304752861

THREE RIVERS FEDERAL5-56-8204304752862


THREERIVERS FEDERAL 3-33-820

4304752864

THREE RIVERSFED 4-31-8204304752874

THREERIVERS 4-21-820

4304752875


THREE RIVERS FED10-42-8204304752949


4304752950THREE RIVERSFED 34-15-7204304752965


4304753008

ThreeRivers Federal 34-35-720

4304753282Three Rivers Federal34-25-7204304753283

Three Rivers Federal10-32-820

4304753415


4304753437

Three Rivers4-33-820

4304753528


4304753551


Three RiversFederal 35-14-720

4304753553Three Rivers

Federal 35-13-7204304753554


4304753555


4304753556




4304753913


4304753914


4304753945

Three Rivers2-223-8204304753946

Three Rivers2-21-8204304753947


4304753948


4304753952


4304753953ThreeRivers Federal 3-24-8204304753954

Map Produced by Diana MasonMap Prepared:

F1,500 0 1,500750 Feet

1:14,255

UnitsSTATUS

ACTIVE

EXPLORATORY

GAS STORAGE

NF PP OIL

NF SECONDARY

PI OIL

PP GAS

PP GEOTHERML

PP OIL

SECONDARY

TERMINATED

TOOELE

SAN JUAN

MILLARD

KANE

JUAB

IRON

EMERY

UINTAH

BOX ELDER

GARFIELD

GRAND

UTAH

WAYNEBEAVER

DUCHESNE

SEVIER

SUMMIT

RICH

WASHINGTON

CARBON

SANPETE

CACHE

PIUTE

DAVIS

WASATCH

WEBER

SALT LAKE

DAGGETT

MORGAN

Location Map

Operator: AXIA ENERGY LLC

Well Name: Three Rivers Federal 3-23-820API Number: 4304753953

Township T08.0S Section 03Range R20.0EMeridian: SLBM


CONFIDE

NTIAL


Federr3e5e1R47e2

THREERI API Number: 4304753953

Tre0e47Re5r55 4330547454 0 Well Name: Three Rivers Federal 3-23-820

Federa 35-13-7204 04753554 35 Township TO8.0S Range R20.0E Section 03

34 Meridian: SLBMT ee Rivers ederal THRE RIVER D

RiveedThraee

720IRTHOURAY

F3EDEROA4L1 Operator: AXIA ENERGY LLC

4304753551 4304753557 4 4 50 82 43047106053 HREE RIVERS Three Rivers Federal NOPTW ni ipov

_

Map Prepared:

U 34-15-/20 >---MU UNIT2 Map Produced by Diana Mason

4 4752965 4304753283 4304710604

THREE

Three Riv sRI OR4S 11 820 Three Rivers

RIVERSO447251 THREE VEORS Federal 3-12-82 03 43024725234 < Three Rivers

43047528744304753914 hr Rivers Federal 2-21-820

Thre 4- 820 4304753947Rivers Federal 4-42-8 0 430 11 THREE

4304753 E1L3CAN RIVERS4FEDERAL643-33-820 G 0230K4E738844--20

HREE RIVERS TH E R820ERS s04 EDERAL 3-32-820 AcTivE

05Three Rivers Federal

04752861 43047 8ERIVERS

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4-32-820 THREE 2-13-820 oAssrosAGE

4304753552 RIVERSFEDERAL3-53-820 4304752687Thre Rivers 4304752820 NF sEcoNDARY

4- 3-820 THREE RIVERS FED. RAL '43 4753528

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43047539 ers Federal 3-24-820 4304753946 PP at

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3-14- 02-24-820

TERMiNarED

430475 952 THREERIV43ROS4753945

2-15-8204304752689

REE RIVERS HREE3D4ERAL653-55-820 ' ""

icHLocation Map

THRF

43 4752862 10-20-82043047 i3555 Three EE RIVERS FED I oucHEsN

hre ivers Federal 10-31-820 -42-820 UT^H T^H

Rivers Federal 9- 1-820 4304753437 304752949auAs

43047->3556 Three Rivers F: deral HREE RIVERS cAasoN

10-32-820 ED 10-41-820430475341 304752948

MiLLARDEMERy GRAND

09

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08 R°N G^RFIELD

mNauAN

WASHINGTON KANE

00 750 0 1.500Feet

1:14,255



Federr3e5e1R47e2


Te0e47Re5r55 4330547454 0 Well Name: Three Rivers Federal 3-23-820

Federal 5-13-7204 04753554 35 Township TO8.0S Range R20.0E Section 03


RiveedThraee

720RTH OURAY 44F3E0D4

0A4 Operator: AXIA ENERGY LLC

4304753551 4304753557 4 4 50 82 +43047106053 HREE RIVERS hree Rivers Federal NOPTW ni ipov Map Prepared:


4 4752965 4304753283 4304710604

THREE

Three Riv sRI OR4S 11 820 Three2R2iver0si

RIVERSO447251 THREE VEORS Federal3-12-82 03 4304753948AThreeRivers



4304753 13 RIVERS FEDERAL 3-33-820 G 02

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43047539 ers Federal 3-24-820 304753946 at

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TERMiNarED4304753945430475 952 THREE RIVERS

2-15-82043047e52689

REE RIVERS HREE3HDR

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5R

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Location Map

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43047 i3555 Three EE RIVERS FED oucHEsN

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43047->3556 Three Rivers Fe deral HREE RIVERS cAasoN

10-32-820 ED 10-41-820430475341 , 304752948

MiLLARDEMERY GRAND

09

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08 "°N ^RFIE'O

mNauAN

WASHINGTON KANE

00 750 0 1.500Feet

1:14,255



Federr3e5e1R47e2





RiveedThraee





4 4752965 4304753283 4304710604

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4304753 13 RIVERS FEDERAL 3-33-820 G 02

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304752861 i4304 E8E




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REE RIVERS HREE3HDR

R

5R

F DERAL

' ""icH

Location Map






10-32-820 ED 10-41-820430475341 , 304752948

MiLLARDEMERY GRAND

09

10BEAvER PiuT wAvNE

08 "°N ^RFIE'O

mNauAN

WASHINGTON KANE

00 750 0 1.500Feet

1:14,255



Federr3e5e1R47e2





RiveedThraee





4 4752965 4304753283 4304710604

THREE





4304753 13 RIVERS FEDERAL 3-33-820 G 02

E N44p-20 430 86H4REE



304752861 i4304 E8E




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4LAK4E 4358-20 4304752860 2-h2r2e3e-8Riv0ers

43047539 ers Federal 3-24-820 304753946 at


3-14- 02-24-820


2-15-82043047e52689

REE RIVERS HREE3HDR

R

5R

F DERAL

' ""icH

Location Map






10-32-820 ED 10-41-820430475341 , 304752948

MiLLARDEMERY GRAND

09

10BEAvER PiuT wAvNE

08 "°N ^RFIE'O

mNauAN

WASHINGTON KANE

00 750 0 1.500Feet

1:14,255



WORKSHEETAPPLICATION FOR PERMIT TO DRILL

APD RECEIVED: 8 /12 /2013 API NO. ASSIGNED: 43047539530000

WELL NAME: Three Rivers Federal 3-23-820

OPERATOR: AXIA ENERGY LLC (N3765) PHONE NUMBER: 435 719-2018

CONTACT: Don Hamilton

PROPOSED LOCATION: NWSW 03 080S 200E Permit Tech Review:

SURFACE: 1475 FSL 1237 FWL Engineering Review:

BOTTOM: 1980 FSL 1980 FWL Geology Review:

COUNTY: UINTAH

LATITUDE: 40.14850 LONGITUDE: -109.65958

UTM SURF EASTINGS: 614171.00 NORTHINGS: 4445101.00

FIELD NAME: THREE RIVERS

LEASE TYPE: 1 - Federal

LEASE NUMBER: UTU85994 PROPOSED PRODUCING FORMATION(S): WASATCH

SURFACE OWNER: 1 - Federal COALBED METHANE: NO

RECEIVED AND/OR REVIEWED: LOCATION AND SITING:

PLAT R649-2 -3 .

Bond: FEDERAL - UTB000464 Unit:

Potash R649-3-2. General

Oil Shale 190-5

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

Oil Shale 190-13 Drilling Unit

Water Permit: 43-10988 Board Cause No: R649-3-11

RDCC Review: Effective Date:

Fee Surface Agreement Siting:

Intent to Commingle R649-3-11. Directional Drill

Commingling Approved

Comments: Presite Completed

Stipulations: 1 - Exception Location - bhill 4 - Federal Approval - dmason 15 - Directional - dmason 23 - Spacing - dmason


CONFIDE

NTIAL



I

I

APD RECEIVED: 8/12/2013 API NO. ASSIGNED: 43047539530000


OPERATOR: AXIAENERGY LLC (N3765) PHONE NUMBER: 435 719-2018





COUNTY: UINTAH







I

RECEIVED ANDIOR REVIEWED: LOCATION AND SITING:

PLAT R649-2-3.

Bond: FEDERAL - UTBOOO464 Unit:


Oil Shale 190-5








I


Stipulations: 1 - Exception Location - bhill4 - Federal Approval - dmason15 - Directional - dmason23 - Spacing - dmason




I

I








COUNTY: UINTAH







I


PLAT R649-2-3.



Oil Shale 190-5








I






I

I








COUNTY: UINTAH







I


PLAT R649-2-3.



Oil Shale 190-5








I






I

I








COUNTY: UINTAH







I


PLAT R649-2-3.



Oil Shale 190-5








I




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

Well Name: Three Rivers Federal 3-23-820API Well Number: 43047539530000

Lease Number: UTU85994Surface Owner: FEDERAL Approval Date: 8 / 2 1 / 2 0 1 3

Issued to:AXIA ENERGY LLC, 1430 Larimer Ste 400, Denver, CO 80202

Authority:Pursuant to Utah Code Ann. 40-6-1 et seq. , and Utah Administrat ive CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-11. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.

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

Exception Location:Appropriate information has been submitted to DOGM and administrat ive approvalof the requested exception location is hereby granted.

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

Conditions of Approval: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.

This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil , Gas andMining (the “Board”). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been drilled,

State of UtahDEPARTMENT OF NATURAL RESOURCES

- -/ MICHAELR.STYLER

GAR'R H BERTExoutimDrotor

comrmr Division of Oil, Gas and MiningGREGORY S. BELL JOHN R. BAZALieuterant Gowrær Busion Director

Permit To Drillkkkkkkkkkkkkkkkkkk


Lease Number: UTU85994Surface Owner: FEDERALApproval Date: 8/21/2013


Authority:Pursuant to Utah Code Ann. 40-6-1 et seq., and Utah Administrative CodeR649-3-1 et seq., the Utah Division of Oil, Gas and Mining issues conditions ofapproval, and permit to drill the listed well. This permit is issued in accordancewith the requirements of R649-3-11. The expected producing formation or pool isthe WASATCH Formation(s), completion into any other zones will require filing aSundry Notice (Form 9). Completion and commingling of more than one pool willrequire approval in accordance with R649-3-22.

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

Exception Location:Appropriate information has been submitted to DOGM and administrative approvalof the requested exception location is hereby granted.

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

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


This proposed well is located in an area for which drilling units (well spacingpatterns) have not been established through an order of the Board of Oil, Gas andMining (the "Board"). In order to avoid the possibility of waste or injury tocorrelative rights, the operator is requested, once the well has been































completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of i ts analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drill ing and spacing units in conformance with such analysis by fil inga Request for Agency Action with the Board.

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 &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

completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soonas is practicable after completion of its analysis, and if the analysis suggests anarea larger than the quarter-quarter section upon which the well is located is beingdrained, the operator is requested to seek an appropriate order from the Boardestablishing drilling and spacing units in conformance with such analysis by filinga Request for Agency Action with the Board.

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 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:


STATEOFUTAHDEPARTMENT OF NATURALRESOURCES

DIVISIONOF OIL, GAS AND MINING

Request to Transfer Application or Permit to Drill

(This form should accompany a Sundry Notice, Form 9, requesting APD transfer)

Well name: See Attached List

API number:Location: Qtr-Qtr: Section: Township: Range:

Company that filed original application: Don Hamilton - Star Point Enterprises for Axia Energy, LLC

Date original permit was issued:Company that permit was issued to: Axia Energy

Check Desired Action:

/ Transfer pending (unapproved) Application for Permit to Drill to new operatorThe undersigned as owner with legal rights to drillon the property, hereby verifies thatthe information assubmitted in the pending Application for Permit to Drill,remains valid and does not require revision. The newowner of the applicationaccepts and agrees to the information and procedures as stated in the application.

Transfer approved Application for Permit to Drill to new operator

The undersigned as owner with legal rights to drillon the property as permitted, hereby verifies that theinformation as submitted in the previously approved application to drill, remains valid and does not requirerevision.

Following is a checklist of some items related to the application, which should be verified. Yes No

lf located on private land, has the ownership changed?

Ifso, has the surface agreement been updated?Have any wells been drilled in the vicinityof the proposed wellwhich would affect the spacing or sitingrequirements for thislocation?Have there been any unit or other agreements put in place that could affect the permitting or operationof thisproposed well?Have there been any changes to the access route including ownership or right-of-way, which couldaffect theproposed location?Has the approved source of water for drillingchanged?Have there been any physical changes to the surface location or access route which will require a change inplans from what was discussed at the onsite evaluation?Is bonding still in place, which covers this proposed well? Bond No.

Any desired or necessary changes to either a pending or approvedApplication for Permit to Drillthat is being transferred,should be filed on a Sundry Notice, Form 9, or amended Application for Permit to Drill,Form 3, as appropriate, withnecessary supporting information as required.

Name (please print) Mary Sharon Balakas Title Attomey in Fact

Representing (company name) Ultra Resources

The person signing this form must have legal authorityto represent the companyor individual(s) to be listed as the new operator on the Application forPermit to Drill.


























































Division of Oil, Gas and Mining ROUTINGOPERATOR CHANGE WORKSHEET (for state use only) CDW

X - Change of Operator (Well Sold) Operator Name Change/MergerThe operator of the well(s) listed below has changed, effective: 10/1/2013

FROM: (oldOperator): TO: ( New Operator):N3765-Axia Energy, LLC N4045-Ultra Resources, Inc.1430 Larimer Street, Suite 400 304 Inverness Way South, Suite 295Denver, CO 80202 Englewood, CO 80112

Phone: 1 (720) 746-5200 Phone: 1 (303) 645-9810

CA No. Unit: N/AWELL NAME SEC TWN RNG API NO ENTITY LEASE WELL WELL

NO TYPE TYPE STATUSSee Attached List

OPERATOR CHANGES DOCUMENTATIONEnter date after each listed item is completed1. (R649-8-10) Sundry or legal documentation was received from the FORMER operator on: 12/16/20132. (R649-8-10) Sundry or legal documentation was received from the NEW operator on: 12/16/20133. The new company was checked on the Department of Commerce, Division of Corporations Database on: 1/14/20144a. Is the new operator registered in the State of Utah: Business Number: 8861713-01435a. (R649-9-2)Waste Management Plan has been received on: N/A5b. Inspections of LA PA state/fee well sites complete on: N/A5c. Reports current for Production/Disposition & Sundries on: 1/14/20146. Federal and Indian Lease Wells: The BLM and or the BIA has approved the merger, name change,

or operator change for all wells listed on Federal or Indian leases on: BLM Not Yet BIA7. Federal and Indian Units:

The BLM or BIA has approved the successor of unit operator for wells listed on: N/A8. Federal and Indian Communization Agreements ("CA"):

The BLM or BIA has approved the operator for all wells listed within a CA on: N/A9. Underground Injection Control ("UIC") Division has approved UIC Form 5 Transfer of Authority to

Inject, for the enhanced/secondary recovery unit/project for the water disposal well(s) listed on: N/ADATA ENTRY:1. Changes entered in the Oil and Gas Database on: 1/14/20142. Changes have been entered on the Monthly Operator Change Spread Sheet on: 1/14/20143. Bond information entered in RBDMS on: 1/14/20144. Fee/State wells attached to bond in RBDMS on: 1/14/20145. Injection Projects to new operator in RBDMS on: N/A6. Receipt of Acceptance of Drilling Procedures for APD/New on: 1/14/20147. Surface Agreement Sundry from NEW operator on Fee Surface wells received on: YesBOND VERIFICATION:1. Federal well(s) covered by Bond Number: 220464002. Indian well(s) covered by Bond Number: 220464003a. (R649-3-1) The NEW operator of any state/fee well(s) listed covered by Bond Number 220463983b. The FORMER operator has requested a release of liability from their bond on: Not Yet

LEASE INTEREST OWNER NOTIFICATION:4. (R649-2-10) The NEW operator of the fee wells has been contacted and informed by a letter from the Division

of their responsibility to notify all interest owners of this change on: 1/14/2014COMMENTS:

Ultra Resources, Inc.xls




Phone: 1 (720) 746-5200 Phone: 1 (303) 645-9810














Phone: 1 (720) 746-5200 Phone: 1 (303) 645-9810














Phone: 1 (720) 746-5200 Phone: 1 (303) 645-9810











Axia Energy, LLC (N3765) to Ultra Resources, Inc. (N4045) Effective 10/1/2013

Well Name Sec TWN RNG API Number Entity Mineral Lease Well Type Well StatusTHREE RIVERS 2-41-820 2 080S 200E 4304752686 State OW APDTHREE RIVERS 2-25-820 2 080S 20S304752690 State OW APDTHREE RIVERS 36-21-720 36 070S 200E 4304752698 State OW APDTHREE RIVERS 36-13-720 36 070S 200E 4304752699 State OW APDTHREE RIVERS FEDERAL 3-54-82(3 080S 200E 4304752860 Federal OW APDTHREE RIVERS FEDERAL 3-33-82(3 080S 200E 4304752864 Federal OW APDTHREE RIVERS FED 35-34-720 35 070S 200E 4304753006 ederal OW APDTHREE RIVERS FED 35-42-720 35 070S 200E 4304753007 Federal OW APDTHREE RIVERS FED 35-44-720 35 070S 200E 4304753008 Federal OW APDThree Rivers 2-32-820 2 080S 200E 4304753274 State OW APDThree Rivers 18-21-821 18 080S 210E 4304753276 Fee OW APDThree Rivers 18-31-821 18 080S 210E 4304753277 Fee OW APDThree Rivers 27-34-720 34 070S 200E 4304753278 Fee OW APDThree Rivers 34-31T-720 4 070S 200E 4304753281 Fee OW APDThree Rivers Federal 35-14-720 35 070S 200E 4304753553 Federal OW APDThree Rivers Federal 35-13-720 35 070S 200E 4304753554 Federal OW APDThree Rivers 7-34-821 7 080S 210E 4304753558 Fee OW APDThree Rivers 7-23-821 7 080S 210E 4304753559 Fee OW APDThree Rivers 7-21-821 7 080S 210E 4304753560 Fee OW APDThree Rivers 7-22-821 7 080S 210E 304753561 Fee OW APDThree Rivers 7-12-821 7 080S 210E 4304753562 Fee OW APDThree Rivers 18-22-821 18 080S 210E 4304753620 Fee OW APDThree Rivers 18-32-821 18 080S 210E 4304753621 Fee OW APDThree Rivers D 16 080S 200E 4304753702 State WD APDThree Rivers Federal 4-41-820 4 080S 200E 4304753911 Federal OW APDThree Rivers Federal 4-42-820 4 080S 200E 4304753913 Federal OW APDThree Rivers Federal 3-12-820 4 080S 200E 4304753914 Federal OW APDThree Rivers Federal 34-42-720 35 070S 200E 4304753915 Federal OW APDThree Rivers Federal 34-43-720 35 070S 200E 4304753916 Federal OW APDThree Rivers Federal 35-12-720 35 070S 200E 4304753917 Federal OW APDThree Rivers Federal 35-43-720 70S 200E 4304753918 Federal OW APDThree Rivers Federal 35-442-720 35 070S 200E 4304753919 Federal OW APDThree Rivers Federal 35-21-720 35 070S 200E 4304753943 Federal OW APDThree Rivers Federal 35-11-720 35 070S 200E 4304753944 Federal OW APDThree Rivers 2-24-820 2 080S 200E 04753945 State OW APDThree Rivers 2-223-820 2 080S 200E 4304753946 State OW APDThree Rivers 2-21-820 2 080S 200E 304753947 State OW APDThree Rivers 2-22-820 2 080S 200E 4304753948 State OW APDThree Rivers 32-42-720 32 070S 200E 4304753949 Fee OW APDThree Rivers Federal 3-13-820 3 080S 200E 4304753951 Federal OW APDThree Rivers Federal 3-14-820 080S 200E 4304753952 Federal OW APDThree Rivers Federal 3-23-820 3 200E 4304753953 Federal OW APDThree Rivers Federal 3-24-820 3 080S 200E 4304753954 Federal OW APDThree Rivers 4-13-820 5 080S 200E 4304753956 Federal OW APDThree Rivers Federal 5-43-820 5 080S 200E 4304753957 Federal OW APDThree Rivers Federal 5-42-820 5 080S 200E 4304753958 Federal OW APDThree Rivers Federal 5-11-820 5 080S 200E 4304754204 Federal OW APDThree Rivers Federal 5-21-820 5 080S 20N04754205 Federal COW APDThree Rivers Federal 8-31-820 080S 200E 4304754211 Federal OW APDThree Rivers Federal 8-41-820 8 080S 200E 4304754212 Federal OW APDThree Rivers Federal 3-34-820 3 080S 200E 4304754213 Federal OW APDThree Rivers Federal 3-44-820 3 080S 200E 4304754214 Federal OW APDTHREE RIVERS 32-34-720 32 070S 200E 4304752735 19249 Fee OW DRLTHREE RIVERS FEDERAL 8-52-82 8 080S 200E 4304752770 19156 Federal OW DRLTHREE RIVERS 4-14-820 5 080S 200E 4304752863 19183 Fee OW DRLTHREE RIVERS FED 10-42-820 10 080S 200E 4304752949 19310 Federal OW DRLTHREE RIVERS FED 3-11-820 4 070S 200E 4304752950 19184 Federal OW DRLThree Rivers 16-21-820 16 080S 200E 4304753229 19024 State OW DRLThree Rivers 16-22-820 16 080S 200E 4304753230 18961 State OW DRL

1



1



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1


Three Rivers Federal 34-35-720 34 070S 200E 4304753282 19287 Federal OW DRLThree Rivers Federal 34-25-720 34 070S 200E 4304753283 19288 Federal OW DRLThree Rivers Federal 10-32-820 10 080S 200E 4304753415 19275 Federal OW DRLThree Rivers Federal 10-31-820 10 080S 200E 4304753437 19276 Federal OW DRLThree Rivers 16-34-820 16 080S 200E 4304753472 19278 State OW DRLThree Rivers 16-44-820 16 080S 200E 4304753473 19268 State OW DRLThree Rivers 16-11-820 16 080S 200E 4304753474 19262 State OW DRLThree Rivers 16-12-820 16 080S 200E 4304753475 19263 State OW DRLThree Rivers 16-32-820 16 080S 200E 4304753494 19185 State OW DRLThree Rivers 16-31-820 16 080S 200E 4304753495 19269 State OW DRLThree Rivers 16-33-820 16 080S 200E 4304753496 19161 State OW DRLTHREE RIVERS FED 10-30-820 10 080S 200E 4304753555 19169 Federal OW DRLThree Rivers Federal 9-41-820 10 080S 200E 4304753556 19170 Federal OW DRLThree Rivers Federal 33-13-720 33 070S 200E 4304753723 19222 Federal OW DRLThree Rivers Federal 33-12-720 33 070S 200E 4304753724 19250 Federal OW DRLThree Rivers 32-3333-720 32 070S 200E 4304753950 19251 Fee OW DRLTHREE RIVERS 36-11-720 36 070S 200E 4304751915 18355 State OW PTHREE RIVERS 2-l l-820 2 080S 200E 4304751936 18354 State OW PTHREE RIVERS 34-31-720 34 070S 200E 4304752012 18326 Fee OW PTHREE RIVERS 16-42-820 16 080S 200E 4304752056 18682 State OW PTHREE RIVERS 16-43-820 16 080S 200E 4304752057 18683 State OW PTHREE RIVERS 16-41-820 16 080S 200E 4304752110 18356 State OW PTHREE RIVERS 2-51-820 2 080S 200E 4304752685 18941 State OW PTHREE RIVERS 2-13-820 2 080S 200E 4304752687 19014 State OW PTHREE RIVERS 2-23-820 2 080S 200E 4304752688 19015 State OW PTHREE RIVERS 2-15-820 2 080S 200E 4304752689 18770 State OW PTHREE RIVERS 36-31-720 36 070S 200E 4304752697 19086 State OW PTHREE RIVERS 32-25-720 32 070S 200E 4304752718 19033 Fee OW PTHREE RIVERS 36-23-720 36 070S 200E 4304752733 18769 State OW PTHREE RIVERS 32-33-720 32 070S 200E 4304752734 19016 Fee OW PTHREE RIVERS 32-15-720 32 070S 200E 4304752736 18767 Fee OW PTHREE RIVERS 32-35-720 32 070S 200E 4304752737 18766 Fee OW PTHREE RIVERS FEDERAL 8-53-82(8 080S 200E 4304752771 18992 Federal OW PTHREE RIVERS FEDERAL 3-53-82(3 080S 200E 4304752820 19104 Federal OW PTHREE RIVERS FEDERAL 3-32-82{ 3 080S 200E 4304752861 18942 Federal OW PTHREE RIVERS FEDERAL 5-56-82{ 5 080S 200E 4304752862 18993 Federal OW PTHREE RIVERS FED 4-31-820 4 080S 200E 4304752874 19023 Federal OW PTHREE RIVERS 4-21-820 4 080S 200E 4304752875 19048 Federal OW PTHREE RIVERS FED 34-23-720 34 070S 200E 4304752945 19049 Federal OW PTHREE RIVERS FED 34-33-720 34 070S 200E 4304752947 19050 Federal OW PTHREE RIVERS FED 10-41-820 10 080S 200E 4304752948 19137 Federal OW PTHREE RIVERS FED 34-15-720 34 070S 200E 4304752965 18960 Federal OW PTHREE RIVERS FED 35-32-720 35 070S 200E 4304753005 19138 Federal OW PThree Rivers 16-23-820 16 080S 200E 4304753231 19037 State OW PThree Rivers 16-24-820 16 080S 200E 4304753232 19038 State OW PThree Rivers 2-33-820 2 080S 200E 4304753273 18943 State OW PThree Rivers 4-33-820 4 080S 200E 4304753528 19167 Fee OW PThree Rivers Federal 33-14-720 33 070S 200E 4304753551 19107 Federal OW PThree Rivers Federal 4-32-820 4 080S 200E 4304753552 19168 Federal OW PThree Rivers Federal 33-24-720 33 070S 200E 4304753557 19108 Federal OW PThree Rivers 32-334-720 32 070S 200E 4304753710 19067 Fee OW PThree Rivers 5-31-820 32 070S 200E 4304753711 19068 Fee OW PThree Rivers Federal 33-11-720 32 070S 200E 4304753733 19109 Federal OW PThree Rivers 32-32-720 32 070S 200E 4304753734 19087 Fee OW PThree Rivers 32-333-720 32 070S 200E 4304753735 19088 Fee OW P

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· Ultra Resources, Inc.

PETROLEUM

December 13, 2013

RECEiVED

DEC1 6 2013

DIV.OFOIL,GAS&MINING

Division of Oil, Gas, and Mining1594 West North TempleSalt Lake City, UT 84116Attn: Rachel Medina

Re: Transfer of OperatorThree Rivers Project AreaUintah County, Utah

Dear Ms. Medina:

Pursuant to Purchase and Sale Agreement dated effective October 1, 2013 Ultra Resources, Inc. ("Ultra") assumedthe operations of Axia Energy, LLC ("Axia") in the Three Rivers Area, Uintah County, Utah.

Accordingly, Ultra is submitting the following documents for your review and approval:

1) Request to Transfer Application or Permit to Drill for New, APD Approved & Drilled Wells2) Request to Transfer Application or Permit to Drill - APD Pending3) Two Completed Sundry Notice and Reports on Wells Form 9 regarding Change of Operator executed by

Ultra Resources, Inc. and Axia Energy, LLC4) Statewide Surety Bond in the amount of $120,000

As to all wells located on Fee Surface there are surface agreements in place. Ultra presently does not anticipatemaking any change in the drilling plans submitted by Axia.

Ultra has also submitted a Statewide Bond to the Bureau of Land Management. As soon as we receive theacknowledgement and approval by the BLM we will forward same to you for your files. A copy of our transferletter and bond is attached for your reference.

Should you need any further information at this time, please call me direct at (303) 645-9865 or emailmsbalakas ultrapetroleum.com.

incerely

Mary S on Balakas, CPLDirector of Land

cc: Cindy Turner, Axia Energy, LLC

304 Inverness Way South, Suite 295, Englewood, CO 80112Telephone 303-708-9740 Facsimile


PETROLEUM

December 13, 2013

RECEiVED

DEC1 6 2013




Dear Ms. Medina:








incerely





PETROLEUM

December 13, 2013

RECEiVED

DEC1 6 2013




Dear Ms. Medina:








incerely





PETROLEUM

December 13, 2013

RECEiVED

DEC1 6 2013




Dear Ms. Medina:








incerely




STATE OF UTAH FORM 9DEPARTMENT OF NATURALRESOURCES

DIVISIONOF OIL, GAS AND MINING 5. LEASEDESIGNATIONANDSERIALNUMBER:

See Attached Well List6. IF INDIAN.ALLOTTEEOR TRIBE NAMESUNDRY NOTICES AND REPORTS ON WELLST UNITor CA AGREEMENT NAME:Do not use this form for proposals to drill new wells, significantlydeepen existing wells below current bottom-hole depth, reenter plugged wells, or to

drillhorizontal laterals. Use APPLICATION FOR PERMIT TO DRILLform for such proposals.1 TYPE OF WELL 8. WELLNAMEand NUMBER:OIL WELL GAS WELL Q OTHER

See Attached Well List2 NAMEOFOPERATOR: 9.APINUMBER:Ultra Resources, Inc. Ñ 645

3 ADDRESS OF OPERATOR: PHONE NUMBER: 10. FIELDAND POOL, OR WILDCAT:304 Inverness Way South cn Englewood

STATE CO ZIP 80112 (303) 645-98104 LOCATION OF WELL

FOOTAGES ATSURFACE: See Attached COUNTY: Uintah

QTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:UTAH

9t CHECK APPROPRIATE BOXES TO INDICATENATURE OF NOTICE, REPORT, OR OTHER DATATYPE OF SUBMISSION TYPE OF ACTION

ACIDIZE DEEPEN REPERFORATE CURRENT FORMATIONNOTICE OF INTENT(Submit in Duplicate) ALTER CASING FRACTURE TREAT SIDETRACKTOREPAIR WELL

Approximate date woß willstart: CASING REPAIR NEW CONSTRUCTION TEMPORARILYABANDON

10/1/2013 CHANGE TO PREVIOUS PLANS OPERATOR CHANGE TUBINGREPAIR

O CHANGE TUBING PLUG ANDABANDON VENTOR FLARE

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

O CHANGE WELL STATUS PRODUCTION (START/RESUME) WATER SHUT-OFFDate ofwork completion:O COMMINGLEPRODUCING FORMATIONS RECLAMATIONOF WELL SITE OTHER:

O CONVERT WELL TYPE RECOMPLETE - DIFFERENT FORMATION

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

EFFECTIVE DATE: October 1, 2013FROM:Axia Energy, LLC1430 Larimer StreetSDe ve4r

CO 80202Bond Number: Blanket Statewide UT State/Fee Bond LPM9046682TO: DEC16 1033Ultra Resources, Inc.304 Inverness Way South

y OF L GASEnglewood, CO 80119Bond Number:

_0

Ultra Resources, c e dp s n r ms and conditions of the leases/wells for the operations conducted on theleased lands.

NAME(PLEASE PRINT) Mary Sharon BalakasTITLE Attorney in Fact

(This space for State use only)

JAN16 2013DIV.OIL GAS &MINING

(5/2000) (See Instructions on Reverse






















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_0



























_0






i.TTACHMENTTO FORM 9 CHANGEOF OPERATORI.XIA ENERGYTO ULTRARESOURCEI EFFECTIVE10-01-2013

Axia Well Name State Actual DateState Well Name (for database sort Mineral Surface Well Well Status @ Apprvd

Listdownloaded 12-10-13 and consistency) Sec TWN RNG API Number Entity Lease Lease Type Status 12/12/13 Submitted DOGMTHREERIVERS2-11-820 Three Rivers 02-11-820 2 0805 200E 4304751936 18354 State State OW P PTHREERIVERS2-13-820 Three Rivers 02-13-820 2 0805 200E 4304752687 19014 State State OW DRL P 08/27/12THREERIVERS2-15-820 Three Rivers 02-15-820 2 0805 200E 4304752689 18770 State State OW P PThree Rivers 2-21-820 Three Rivers 02-21-820 210805 200E 4304753947 State State OW APD APRVD 10/15/13Three Rivers 2-223-820 Three Rivers 02-223-820 2 0805 200E 4304753946 State B OW APD APRVD 10/15/13Three Rivers 2-22-820 Three Rivers 02-22-820 2 080s 200E 4304753948 State State OW APD APRVD 10/15/13THREERIVERS2-23-820 Three Rivers 02-23-820 2 0805 200E 4304752688 19015 State State OW DRL P 08/27/12Three Rivers 2-24-820 Three Rivers 02-24-820 2 0805 200E 4304753945 State State OW APD APRVD 10/15/13THREERIVERS2-25-820 Three Rivers 02-25-820 2 0805 200E 4304752690 State State OW APD APRVD 08/27/12Three Rivers 2-32-820 Three Rivers 02-32-820 2 0805 200E 4304753274 State State OW APD APRVD 12/11/12Three Rivers 2-33-820 Three Rivers 02-33-820 2 080S 200E 4304753273 18943 State State OW P PTHREERIVERS2-41-820 Three Rivers 02-41-820 2 0805 200E 4304752686 State State OW APD APRVD 08/27/12!THREERIVERS2-51-820 Three Rivers 02-51-820 2 0805 200E 4304752685 18941 State State OW P PThree Rivers 4-13-820 Three Rivers 04-13-820 5 0805 200E 4304753956 Fee Federal OW APD PERPEND 08/19/13THREERIVERS4-14-820 Three Rivers 04-14-820 5 0805 200E 4304752863 19183 Fee Federal OW DRL PThree Rivers 4-33-820 Three Rivers 04-33-820 4 0805 200E 4304753528 19167 Fee Fee OW DRL PThree Rivers 5-31-820 Three Rivers 05-31-820 32 0705 200E 4304753711 19068 Fee Fee OW DRL PThree Rivers 7-12-821 Three Rivers 07-12-821 7 0805 210E 4304753562 Fee Fee OW APD PERPEND 04/15/13Three Rivers 7-21-821 Three Rivers 07-21-821 7 0805 210E 4304753560 Fee Fee OW APD PERPEND 04/15/13Three Rivers 7-22-821 Three Rivers 07-22-821 7 0805 210E 4304753561 Fee Fee OW APD PERPEND 04/15/13Three Rivers 7-23-821 Three Rivers 07-23-821 7 0805 210E 4304753559 Fee Fee OW APD PERPEND 04/15/13Three Rivers 7-34-821 Three Rivers 07-34-821 7 0805 210E 4304753558 Fee Fee OW APD PERPEND 04/15/13Three Rivers 16-11-820 Three Rivers 16-11-820 16 0805 200E 4304753474 19262 State State OW DRL SCS 03/12/13Three Rivers 16-12-820 Three Rivers 16-12-820 16 0805 200E 4304753475 19263 State State OW DRL SCS 03/12/13Three Rivers 16-21-820 Three Rivers 16-21-820 16 0805 200E 4304753229 19024 State State OW DRL P 12/11/12Three Rivers 16-22-820 Three Rivers 16-22-820 16 0805 200E 4304753230 18961 State State OW DRL P 12/11/12Three Rivers 16-23-820 Three Rivers 16-23-820 16 0805 200E 4304753231 19037 State State OW DRL P 12/11/12Three Rivers 16-24-820 Three Rivers 16-24-820 16 0805 200E 4304753232 19038 State State OW P PThree Rivers 16-31-820 Three Rivers 16-31-820 16 0805 200E 4304753495 State State OW APD CCS 03/12/13Three Rivers 16-32-820 Three Rivers 16-32-820 16 0805 200E 4304753494 19185 State State OW DRL WOC 03/12/13Three Rivers 16-33-820 Three Rivers 16-33-820 16 0805 200E 4304753496 19161 State State OW DRL WOC 03/12/13Three Rivers 16-34-820 Three Rivers 16-34-820 16 0805 200E 4304753472 State State OW APD CCS 03/12/13THREERIVER516-41-820 Three Rivers 16-41-820 16 0805 200E 4304752110 18356 State State OW P PTHREERIVERS16-42-820 Three Rivers 16-42-820 16 0805 200E 4304752056 18682 State State OW P PTHREERIVERS16-43-820 Three Rivers 16-43-820 16 0805 200E 4304752057 18683 State State OW P PThree Rivers 16-44-820 Three Rivers 16-44-820 16 0805 200E 4304753473 State State OW APD CCS 03/12/13Three Rivers 18-21-821 Three Rivers 18-21-821 18 0805 210E 4304753276 Fee Fee OW APD PERPEND 12/17/12Three Rivers 18-22-821 Three Rivers 18-22-821 18 0805 210E 4304753620 Fee Fee OW APD PERPEND 04/15/13Three Rivers 18-31-821 Three Rivers 18-31-821 18 0805 210E 4304753277 Fee Fee OW APD PERPEND 12/19/12Three Rivers 18-32-821 Three Rivers 18-32-821 18 0805 210E 4304753621 Fee Fee OW APD PERPEND 04/15/13Three Rivers 27-34-720 Three Rivers 27-34-720 34 0705 200E 4304753278 Fee Fee OW APD PERPEND 12/19/12THREERIVERS32-15-720 Three Rivers 32-15-720 32 070S 200E 4304752736 18767 Fee Fee OW P PTHREERIVERS32-25-720 Three Rivers 32-25-720 32 0705 200E 4304752718 19033 Fee Fee OW P PThree Rivers 32-32-720 Three Rivers 32-32-720 32 0705 200E 4304753734 19087 Fee Fee OW DRL P 06/12/13Three Rivers 32-3333-720 Three Rivers 32-3333-720 32 0705 200E 4304753950 19251 Fee Fee OW DRL SCS 10/15/13Three Rivers 32-333-720 Three Rivers 32-333-720 32 0705 200E 4304753735 19088 Fee Fee OW DRL P 06/12/13Three Rivers 32-334-720 Three Rivers 32-334-720 32 0705 200E 4304753710 19067 Fee Fee OW DRL P 05/22/13THREERIVERS32-33-720 Three Rivers 32-33-720 32 0705 200E 4304752734 19016 Fee Fee OW DRL P 08/29/12THREERIVERS32-34-720 Three Rivers 32-34-720 32 0705 200E 4304752735 19249 Fee Fee OW DRL DRLG 08/29/12THREERIVERS32-35-720 Three Rivers 32-35-720 32 0705 200E 4304752737 18766 Fee Fee OW P PThree Rivers 32-42-720 Three Rivers 32-42-720 32 070S 200E 4304753949 Fee Fee OW APD APRVD 10/15/13THREERIVERS34-31-720 Three Rivers 34-31-720 34 0705 200E 4304752012 18326 Fee Fee OW P PThree Rivers 34-31T-720 Three Rivers 34-31T-720 34 0705 200E 4304753281 Fee Fee OW APD APRVD 12/11/12THREERIVERS36-11-720 Three Rivers 36-11-720 36 070S 200E 4304751915 18355 State State OW P PTHREERIVERS36-13-720 Three Rivers 36-13-720 36 070S 200E 4304752699 State State OW APD APRVD 08/29/12THREERIVERS36-21-720 Three Rivers 36-21-720 36 070s 200E 4304752698 State State OW APD APRVD 08/29/12THREERIVERS36-23-720 Three Rivers 36-23-720 36 0705 200E 4304752733 18769 State State OW P PTHREERIVERS36-31-720 Three Rivers 36-31-720 36 0705 200E 4304752697 19086 State State OW DRL P 08/29/12Three Rivers D Three Rivers D 16 0805 200E 4304753702 State State WD APD APRVD 07/15/13THREERIVERSFED3-11-820 Three Rivers Fed 03-11-820 34 0705 200E 4304752950 19184 Federal Fee OW DRL WOC 02/22/13Three Rivers Federal 3-12-820 Three Rivers Fed 03-12-820 4 080S 200E 4304753914 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 3-13-820 Three Rivers Fed 03-13-820 3 0805 200E 4304753951 Federal Federal OW APD PERPEND 08/12/13Three Rivers Federal 3-14-820 Three Rivers Fed 03-14-820 3 0805 200E 4304753952 Federal Federal OW APD PERPEND 08/12/13Three Rivers Federal 3-23-820 Three Rivers Fed 03-23-820 3 0805 200E 4304753953 Federal Federal OW APD PERPEND 08/12/13 .Three Rivers Federal 3-24-820 Three Rivers Fed 03-24-820 3 0805 200E 4304753954 Federal Federal OW APD PERPEND 08/12/13THREERIVERSFEDERAL3-32-820 Three Rivers Fed 03-32-820 3 0805 200E 4304752861 18942 Federal Federal OW P PTHREERIVERSFEDERAL3-33-820 Three Rivers Fed 03-33-820 3 0805 200E 4304752864 Federal Federal OW APD APRVD 12/24/12THREERIVERSFEDERAL3-53-820 Three Rivers Fed 03-53-820 3 0805 200E 4304752820 19104 Federal Federal OW DRL P 12/24/12THREERIVERSFEDERAL3-54-820 Three Rivers Fed 03-54-820 3 080S 200E 4304752860 Federal Federal OW APD APRVD 12/24/12

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ATTACHMENTTO FORM 9 CHANGEOF OPERATORAXIAENERGYTOULTRARESOURCESEFFECTIVE10-01-2013


List downloaded 12-10-13 and consistency) Sec TWN RNG API Number Entity Lease Lease Type Status 12/12/13 Submitted DOGMTHREE RIVERS4-21-820 Three Rivers Fed 04-21-820 4 0805 200E 4304752875 19048 Federal Fee OW DRL P 02/22/13THREERIVERSFED4-31-820 Three Rivers Fed 04-31-820 4 0805 200E 4304752874 19023 Federal Fee OW DRL P 02/22/13Three Rivers Federal4-32-820 Three Rivers Fed 04-32-820 4 0805 200E 4304753552 19168 Federal Fee OW DRL P 08/26/13Three Rivers Federal 4-41-820 Three Rivers Fed 04-41-820 4 0805 200E 4304753911 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal4-42-820 Three Rivers Fed 04-42-820 4 0805 200E 4304753913 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 5-11-820 Three Rivers Fed 05-11-820 5 0805 200E 4304754204 Federal Federal Ow NEW PERPEND 12/03/13Three Rivers Federal 5-21-820 Three Rivers Fed 05-21-820 5 0805 200E 4304754205 Federal Federal OW NEW PERPEND 12/03/13Three Rivers Federal 5-42-820 Three Rivers Fed 05-42-820 5 0805 200E 4304753958 Federal Federal OW APD PERPEND 08/19/13Three Rivers Federal 5-43-820 Three Rivers Fed 05-43-820 5 0805 200E 4304753957 Federal Federal OW APD PERPEND 08/19/13THREE RIVERSFEDERAL5-56-820 Three Rivers Fed 05-56-820 5 080S 200E 4304752862 18993 Federal Federal OW P PTHREE RIVERSFEDERAL8-52-820 Three Rivers Fed 08-52-820 8 080S 200E 4304752770 19156 Federal Federal OW DRL P 02/22/13THREE RIVERSFEDERAL8-53-820 Three Rivers Fed 08-53-820 8 0805 200E 4304752771 18992 Federal Federal OW P PThree Rivers Federal9-41-820 Three Rivers Fed 09-41-820 10 OSOS 200E 4304753556 19170 Federal Federal OW DRL P 08/20/13THREERIVERSFED10-30-820 Three Rivers Fed 10-30-820 10 0805 200E 4304753555 19169 Federal Federal OW DRL P 08/20/13Three Rivers Federal 10-31-820 Three Rivers Fed 10-31-820 10 0805 200E 4304753437 Federal Federal OW APD CCS 08/21/13Three Rivers Federal 10-32-820 Three Rivers Fed 10-32-820 10 0805 200E 4304753415 Federal Federal OW APD CCS 08/21/13THREE RIVERSFED10-41-820 Three Rivers Fed 10-41-820 10 0805 200E 4304752948 19137 Federal Federal OW DRL P 02/22/13THREERIVERSFED10-42-820 Three Rivers Fed 10-42-820 10 OSOS 200E 4304752949 Federal Federal OW APD APRVD 02/22/13Three Rivers Federal 33-11-720 Three Rivers Fed 33-11-720 32 0705 200E 4304753733 19109 Federal Fee OW DRL P 07/17/13Three Rivers Federal 33-12-720 Three Rivers Fed 33-12-720 33 0705 200E 4304753724 19250 Federal Fee OW DRL WOC 09/16/13Three Rivers Federal 33-13-720 Three Rivers Fed 33-13-720 33 0705 200E 4304753723 19222 Federal Fee OW DRL WOC 09/16/13Three Rivers Federal 33-14-720 Three Rivers Fed 33-14-720 33 0705 200E 4304753551 19107 Federal Fee OW DRL P 09/16/13Three Rivers Federal 33-24-720 Three Rivers Fed 33-24-720 33 0705 200E 4304753557 19108 Federal Fee OW DRL P 07/09/13THREE RIVERSFED34-15-720 Three Rivers Fed 34-15-720 34 0705 200E 4304752965 18960 Federal Fee OW P PTHREERIVERSFED34-23-720 Three Rivers Fed 34-23-720 34 070S 200E 4304752945 19049 Federal Fee OW DRL P 02/12/13Three Rivers Federal 34-25-720 Three Rivers Fed 34-25-720 34 070S 200E 4304753283 Federal Fee OW APD APRVD 06/10/13THREE RIVERSFED34-33-720 Three Rivers Fed 34-33-720 34 0705 200E 4304752947 19050 Federal Fee OW DRL P 02/22/13Three Rivers Federal 34-35-720 Three Rivers Fed 34-35-720 34 0705 200E 4304753282 Federal Fee OW APD APRVD 06/10/13Three Rivers Federal 34-42-720 Three Rivers Fed 34-42-720 35 0705 200E 4304753915 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 34-43-720 Three Rivers Fed 34-43-720 35 0705 200E 4304753916 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 35-11-720 Three Rivers Fed 35-11-720 35 0705 200E 4304753944 Federal Federal OW APD PERPEND 07/25/13Three Rivers Federal 35-12-720 Three Rivers Fed 35-12-720 35 0705 200E 4304753917 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 35-13-720 Three Rivers Fed 35-13-720 35 0705 200E 4304753554 Federal Federal OW APD APRVD 08/20/13Three Rivers Federal 35-14-720 Three Rivers Fed 35-14-720 35 0705 200E 4304753553 Federal Federal OW APD APRVD 08/22/13Three Rivers Federal 35-21-720 Three Rivers Fed 35-21-720 35 0705 200E 4304753943 Federal Federal OW APD PERPEND 07/25/13THREE RIVERSFED35-32-720 Three Rivers Fed 35-32-720 35 070S 200E 4304753005 19138 Federal Federal OW DRL APRVD 02/22/13THREERIVERSFED35-34-720 Three Rivers Fed 35-34-720 35 0705 200E 4304753006 Federal Federal OW APD APRVD 02/22/13THREE RIVERSFED35-42-720 Three Rivers Fed 35-42-720 35 0705 200E 4304753007 Federal Federal OW APD APRVD 02/22/13Three Rivers Federal 35-43-720 Three Rivers Fed 35-43-720 35 0705 200E 4304753918 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 35-442-720 Three Rivers Fed 35-442-720 35 0705 200E 4304753919 Federal Federal OW APD APRVD 08/01/13THREERIVERSFED35-44-720 Three Rivers Fed 35-44-720 35 0705 200E 4304753008 Federal Federal OW APD APRVD 02/22/13Three Rivers Fed 03-34-820 Three Rivers Fed 03-34-820 3 0805 200E Federal NA SUB 12/10/13Three Rivers Fed 03-44-820 Three Rivers Fed 03-44-820 3 0805 200E Federal NA SUB 12/10/13Three Rivers Fed 08-31-820 Three Rivers Fed 08-31-820 8 0805 200E Federal NA SUB 12/07/13Three Rivers Fed 08-41-820 Three Rivers Fed 08-41-820 9 0805 200E Federal NA SUB 12/07/13

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STATEOFUTAH FORM9DEPARTMENT OF NATURALRESOURCES

DIVISIONOF OlL, GAS AND MINING 5 LEASE DESIGNATIONAND SERIAL NUMBER:

See Attached Well List6 IF INDIAN,ALLOTTEEOR TRIBE NAMESUNDRY NOTICES AND REPORTS ON WELLS7 UNITor CA AGREEMENT NAME:Do not use this form for proposals to drillnew wells, significantly deepen existing wells below current bottom-hole depth, reenter plugged wells, or to

drillhorizontal laterals. Use APPLICATION FOR PERMIT TO DRILLform forsuch proposals1 TYPE OF WELL 8 WELL NAMEand NUMBER:OIL WELL GAS WELL OTHER See Attached Well List2 NAMEOF OPERATOR: 9. API NUMBER:Axia Energy, LLC

3. ADDRESS OF OPERATOR: PHONE NUMBER: 10 FIELD AND POOL OR WILDCAT:1430 Larimer Street, Ste 400 CITY Denver STATE CO z,p 80202 (720) 746-5200

4. LOCATIONOF WELL

FOOTAGES AT SURFACE: See Attached COUNTY: Uintah

QTRIQTR, SECTION, TOWNSHIP, RANGE, MERID1AN: STATE:UTAH

n. CHECK APPROPRIATE BOXES TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATATYPE OF SUBMISSION TYPE OF ACTION

O ^CIDIZE DEEPEN REPERFORATE CURRENT FORMATIONNOTICE OF INTENT(Submit in Duplicate) ALTER CASING FRACTURE TREAT SIDETRACK TO REPAIR WELL

Approximate date work willstart: CASING REPAIR NEW CONSTRUCTION. TEMPORARILYABANDON

10/1/2013 CHANGE TO PREVIOUS Pl.ANS OPERATOR CHANGE TUBINGREPAIR

O CHANGE TUBING PLUG AND ABANDON VENT OR FLARE

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

O CHANGE WELLSTATUS PRODUCTION (STARTIRESUME) WATER SHUT-OFFDate ofwork completion:

O COMMINGLEPRODUCING FORMATIONS RECLAMATIONOF WELL SITE OTHER:


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

EFFECTIVE DATE: October 1, 2013FROM:Axia Energy, LLC1430 Larimer StreetSuite 400

g ODenver, CO 80202 'B d Number: Blanket Statewide UT State/Fee Bond LPM9046682 DEC16 100Ultra Resources, Inc.304 Inverness Way South gy y OL GAS&Englewood, CO 80112Bond Number: \ (( \

Ultra Resources, Inc. willbe responsible under the terms and conditions of the leases/wells for the operations conducted on theleased lands.

NAME(PLEASEP ) Daniel G. BlpnchardTITLE Pf6Sident

SIGNATURE DATE

(ThisspaceforStateuseonly APPROVEDJAN16 2013

(5/2000) (SeelnstructionsonReverseSide) V.OIL GAS &






4. LOCATIONOF WELL

















SIGNATURE DATE








4. LOCATIONOF WELL

















SIGNATURE DATE








4. LOCATIONOF WELL

















SIGNATURE DATE



ATTACHMENTTO FORM 9 CHANGEOF OPERATORAXIAENERGYTO ULTRARESOURCE'-EFFECTIVE10-01-2013


List downloaded 12-10-13 and consistency) Sec TWN RNG API Number Entity Lease Lease Type Status 12/12/13 Submitted DOGMTHREERIVERS2-11-820 Three Rivers 02-11-820 2 0805 200E 4304751936 18354 State State OW P P \THREERIVERS2-13-820 Three Rivers 02-13-820 2 0805 200E 4304752687 19014 State State OW DRL P $ 08/27/12THREERIVERS2-15-820 Three Rivers 02-15-820 2 0805 200E 4304752689 18770 State State OW P PThree Rivers 2-21-820 Three Rivers 02-21-820 2 0805 200E 4304753947 State State OW APD APRVD 10/15/13Three Rivers 2-223-820 Three Rivers 02-223-820 2 0805 200E 4304753946 State & OW APD APRVD 10/15/13Three Rivers 2-22-820 Three Rivers 02-22-820 2 OSOS 200E 4304753948 State State OW APD APRVD Âg 10/15/13THREERIVERS2-23-820 Three Rivers 02-23-820 2 080S 200E 4304752688 19015 State State OW DRL P 08/27/12Three Rivers 2-24-820 Three Rivers 02-24-820 2 0805 200E 4304753945 State State OW APD APRVD 10/15/13THREERIVERS2-25-820 Three Rivers 02-25-820 2 0805 200E 4304752690 5tate State OW APD APRVD 08/27/12Three Rivers 2-32-820 Three Rivers 02-32-820 2 0805 200E 4304753274 State State OW APD APRVD 12/11/12Three Rivers 2-33-820 Three Rivers 02-33-820 2 080s 200E 4304753273 18943 State State OW P PTHREERIVERS2-41-820 Three Rivers 02-41-820 2 0805 200E 4304752686 State State OW APD APRVD 08/27/12THREERIVERS2-51-820 Three Rivers 02-51-820 2 OSOS 200E 4304752685 18941 State State OW P PThree Rivers 4-13-820 Three Rivers 04-13-820 5 080S 200E 4304753956 Fee Federal OW APD PERPEND 08/19/13THREERIVERS4-14-820 Three Rivers 04-14-820 5 0805 200E 4304752863 19183 Fee Federal OW DRL PThree Rivers 4-33-820 Three Rivers 04-33-820 4 0805 200E 4304753528 19167 Fee Fee OW DRL PThree Rivers 5-31-820 Three Rivers 05-31-820 32 0705 200E 4304753711 19068 Fee Fee OW DRL PThree Rivers 7-12-821 Three Rivers 07-12-821 7 0805 210E 4304753562 Fee Fee OW APD PERPEND 04/15/13 yThree Rivers 7-21-821 Three Rivers 07-21-821 7 0805 210E 4304753560 Fee Fee OW APD PERPEND 04/15/13Three Rivers 7-22-821 Three Rivers 07-22-821 7 080S 210E 4304753561 Fee Fee OW APD PERPEND 04/15/13Three Rivers 7-23-821 Three Rivers 07-23-821 7 080S 210E 4304753559 Fee Fee OW APD PERPEND 04/15/13Three Rivers 7-34-821 Three Rivers 07-34-821 7 0805 210E 4304753558 Fee Fee OW APD PERPEND 04/15/13Three Rivers 16-11-820 Three Rivers 16-11-820 16 0805 200E 4304753474 19262 State State OW DRL SCS 03/12/13Three Rivers 16-12-820 Three Rivers 16-12-820 16 0805 200E 4304753475 19263 State State OW DRL SCS 03/12/13Three Rivers 16-21-820 Three Rivers 16-21-820 16 0805 200E 4304753229 19024 State State OW DRL P 12/11/12Three Rivers 16-22-820 Three Rivers 16-22-820 16 0805 200E 4304753230 18961 State State OW DRL P 12/11/12Three Rivers 16-23-820 Three Rivers 16-23-820 16 0805 Z00E 4304753231 19037 State State OW DRL P 12/11/12Three Rivers 16-24-820 Three Rivers 16-24-820 16 080s 200E 4304753232 19038 State State OW P PThree Rivers 16-31-820 Three Rivers 16-31-820 16 0805 200E 4304753495 State State OW APD CCS 03/12/13Three Rivers 16-32-820 Three Rivers 16-32-820 16 0805 200E 4304753494 19185 State State OW DRL WOC 03/12/13Three Rivers 16-33-820 Three Rivers 16-33-820 16 0805 200E 4304753496 19161 State State OW DRL WOC 03/12/13Three Rivers 16-34-820 Three Rivers 16-34-820 16 OSOS 200E 4304753472 State State OW APD CCS 03/12/13THREERIVERS16-41-820 Three Rivers 16-41-820 16 0805 200E 4304752110 18356 State State OW P PTHREERIVERS16-42-820 Three Rivers 16-42-820 16 0805 200E 4304752056 18682 State State OW P PTHREERIVERS16-43-820 Three Rivers 16-43-820 16 080S 200E 4304752057 18683 State State OW P PThree Rivers 16-44-820 Three Rivers 16-44-820 16 0805 200E 4304753473 State State OW APD CCS 03/12/13Three Rivers 18-21-821 Three Rivers 18-21-821 18 0805 210E 4304753276 Fee Fee OW APD PERPEND 12/17/12 *g

Three Rivers 18-22-821 Three Rivers 18-22-821 18 0805 210E 4304753620 Fee Fee OW APD PERPEND 04/15/13Three Rivers 18-31-821 Three Rivers 18-31-821 18 0805 210E 4304753277 Fee Fee OW APD PERPEND 12/19/12Three Rivers 18-32-821 Three Rivers 18-32-821 18 0805 210E 4304753621 Fee Fee OW APD PERPEND 04/15/13Three Rivers 27-34-720 Three Rivers 27-34-720 34 0705 200E 4304753278 Fee Fee OW APD PERPEND 12/19/12THREERIVERS32-15-720 Three Rivers 32-15-720 32 0705 200E 4304752736 18767 Fee Fee OW P PTHREERIVERS32-25-720 Three Rivers 32-25-720 32 0705 200E 4304752718 19033 Fee Fee OW P PThree Rivers 32-32-720 Three Rivers 32-32-720 32 0705 200E 4304753734 19087 Fee Fee OW DRL P 06/12/13Three Rivers 32-3333-720 Three Rivers 32-3333-720 32 0705 200E 4304753950 19251 Fee Fee OW DRL SCS 10/15/13Three Rivers 32-333-720 Three Rivers 32-333-720 32 0705 200E 4304753735 19088 Fee Fee OW DRL P 06/12/13Three Rivers 32-334-720 Three Rivers 32-334-720 32 070S 200E 4304753710 19067 Fee Fee OW DRL P 05/22/13THREERIVERS32-33-720 Three Rivers 32-33-720 32 0705 200E 4304752734 19016 Fee Fee OW DRL P 08/29/12THREERIVERS32-34-720 Three Rivers 32-34-720 32 0705 200E 4304752735 19249 Fee Fee OW DRL DRLG 08/29/12THREERIVERS32-35-720 Three Rivers 32-35-720 32 0705 200E 4304752737 18766 Fee Fee OW P PThree Rivers 32-42-720 Three Rivers 32-42-720 32 0705 200E 4304753949 Fee Fee OW APD APRVD 10/15/13THREERIVERS34-31-720 Three Rivers 34-31-720 34 0705 200E 4304752012 18326 Fee Fee OW P PThree Rivers 34-31T-720 Three Rivers 34-31T-720 34 0705 200E 4304753281 Fee Fee OW APD APRVD 12/11/12THREERIVERS36-11-720 Three Rivers 36-11-720 36 0705 200E 4304751915 18355 State State OW P PTHREERIVERS36-13-720 Three Rivers 36-13-720 36 0705 200E 4304752699 State State OW APD APRVD 08/29/12THREERIVERS36-21-720 Three Rivers 36-21-720 36 0705 200E 4304752698 5tate State OW APD APRVD 08/29/12THREERIVERS36-23-720 Three Rivers 36-23-720 36 0705 200E 4304752733 18769 State State OW P PTHREERIVERS36-31-720 Three Rivers 36-31-720 36 070S 200E 4304752697 19086 State State OW DRL P 08/29/12Three Rivers D Three Rivers D 16 OSOS 200E 4304753702 State State WD APD APRVD 07/15/13THREERIVERSFED3-11-820 Three Rivers Fed 03-11-820 34 0705 200E 4304752950 19184 Federal Fee OW DRL WOC 02/22/13Three Rivers Federal 3-12-820 Three Rivers Fed 03-12-820 4 0805 200E 4304753914 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 3-13-820 Three Rivers Fed 03-13-820 3 0805 200E 4304753951 Federal Federal OW APD PERPEND 08/12/13Three Rivers Federal 3-14-820 Three Rivers Fed 03-14-820 3 0805 200E 4304753952 Federal Federal OW APD PERPEND 08/12/13Three Rivers Federal 3-23-820 Three Rivers Fed 03-23-820 3 0805 200E 4304753953 Federal Federal OW APD PERPEND 08/12/13Three Rivers Federal 3-24-820 Three Rivers Fed 03-24-820 3 0805 200E 4304753954 Federal Federal OW APD PERPEND 08/12/13THREERIVERSFEDERAL3-32-820 Three Rivers Fed 03-32-820 3 0805 200E 4304752861 18942 Federal Federal OW P PTHREERIVERSFEDERAL3-33-820 Three Rivers Fed 03-33-820 3 0805 200E 4304752864 Federal Federal OW APD APRVD 12/24/12THREERIVERSFEDERAL3-53-820 Three Rivers Fed 03-53-820 3 0805 200E 4304752820 19104 Federal Federal OW DRL P 12/24/12THREERIVERSFEDERAL3-54-820 Three Rivers Fed 03-54-820 3 0805 200E 4304752860 Federal Federal OW APD APRVD 12/24/12

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ATTACHMENTTO FORM 9 CHANGEOF OPERATORAXIAENERGYTO ULTRARESOURCESEFFECTIVE10-01-2013


List downloaded 12-10-13 and consistency) Sec TWN RNG API Number Entity Lease Lease Type Status 12/12/13 Submitted DOGMTHREERIVERS4-21-820 Three Rivers Fed 04-21-820 4 0805 200E 4304752875 19048 Federal Fee OW DRL P 02/22/13THREERIVERSFED4-31-820 Three Rivers Fed 04-31-820 4 0805 200E 4304752874 19023 Federal Fee OW DRL P 02/22/13Three Rivers Federal4-32-820 Three Rivers Fed 04-32-820 4 0805 200E 4304753552 19168 Federal Fee OW DRL P 08/26/13Three Rivers Federal 4-41-820 Three Rivers Fed 04-41-820 4 0805 200E 4304753911 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 4-42-820 Three Rivers Fed 04-42-820 4 0805 200E 4304753913 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 5-11-820 Three Rivers Fed 05-11-820 5 0805 200E 4304754204 Federal Federal OW NEW PERPEND 12/03 3Three Rivers Federal 5-21-820 Three Rivers Fed 05-21-820 5 0805 200E 4304754205 Federal Federal OW NEW PERPEND 12/03/13Three Rivers Federal 5-42-820 Three Rivers Fed 05-42-820 5 0805 200E 4304753958 Federal Federal OW APD PERPEND 08/19/13Three Rivers Federal 5-43-820 Three Rivers Fed 05-43-820 5 0805 200E 4304753957 Federal Federal OW APD PERPEND 08/19/13THREERIVERSFEDERALS-56-820 Three Rivers Fed 05-56-820 5 0805 200E 4304752862 18993 Federal Federal OW P PTHREERIVERSFEDERAL8-52-820 Three Rivers Fed 08-52-820 8 0805 200E 4304752770 19156 Federal Federal OW DRL P 02/22/13THREERIVERSFEDERAL8-53-820 Three Rivers Fed 08-53-820 8 OSOS 200E 4304752771 18992 Federal Federal OW P PThree Rivers Federal9-41-820 Three Rivers Fed 09-41-820 10 0805 200E 4304753556 19170 Federal Federal OW DRL P 08/20/13THREERIVERSFED 10-30-820 Three Rivers Fed 10-30-820 10 080S 200E 4304753555 19169 Federal Federal OW DRL P 08/20/13Three Rivers Federal 10-31-820 Three Rivers Fed 10-31-820 10 0805 200E 4304753437 Federal Federal OW APD CCS 08/21/13Three Rivers Federal 10-32-820 Three Rivers Fed 10-32-820 10 0805 200E 4304753415 Federal Federal OW APD CCS 08/21/13THREERIVERSFED 10-41-820 Three Rivers Fed 10-41-820 10 0805 200E 4304752948 19137 Federal Federal Ow DRL P 02/22/13THREERIVERSFED 10-42-820 Three Rivers Fed 10-42-820 10 0805 200E 4304752949 Federal Federal OW APD APRVD 02/22/13Three Rivers Federal 33-11-720 Three Rivers Fed 33-11-720 32 0705 200E 4304753733 19109 Federal Fee OW DRL P 07/17/13Three Rivers Federal 33-12-720 Three Rivers Fed 33-12-720 33 0705 200E 4304753724 19250 Federal Fee OW DRL WOC 09/16/13Three Rivers Federal 33-13-720 Three Rivers Fed 33-13-720 33 0705 200E 4304753723 19222 Federal Fee OW DRL WOC 09/16/13Three Rivers Federal33-14-720 Three Rivers Fed 33-14-720 33 0705 200E 4304753551 19107 Federal Fee OW DRL P 09/16/13Three Rivers Federal 33-24-720 Three Rivers Fed 33-24-720 33 0705 200E 4304753557 19108 Federal Fee OW DRL P 07/09/13THREERIVERSFED34-15-720 Three Rivers Fed 34-15-720 34 0705 200E 4304752965 18960 Federal Fee OW P PTHREERIVERSFED34-23-720 Three Rivers Fed 34-23-720 34 0705 200E 4304752945 19049 Federal Fee OW DRL P 02/12/13Three Rivers Federal 34-25-720 Three Rivers Fed 34-25-720 34 0705 200E 4304753283 Federal Fee OW APD APRVD 06/10/13THREERIVERSFED34-33-720 Three Rivers Fed 34-33-720 34 0705 200E 4304752947 19050 Federal Fee OW DRL P 02/22/13Three Rivers Federal 34-35-720 Three Rivers Fed 34-35-720 34 0705 200E 4304753282 Federal Fee OW APD APRVD 06/10/13Three Rivers Federal 34-42-720 Three Rivers Fed 34-42-720 35 070S 200E 4304753915 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 34-43-720 Three Rivers Fed 34-43-720 35 0705 200E 4304753916 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 35-11-720 Three Rivers Fed 35-11-720 35 0705 200E 4304753944 Federal Federal OW APD PERPEND 07/25/13 QQThree Rivers Federal 35-12-720 Three Rivers Fed 35-12-720 35 0705 200E 4304753917 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 35-13-720 Three Rivers Fed 35-13-720 35 0705 200E 4304753554 Federal Federal OW APD APRVD 08/20/13Three Rivers Federal 35-14-720 Three Rivers Fed 35-14-720 35 0705 200E 4304753553 Federal Federal OW APD APRVD 08/22/13Three Rivers Federal 35-21-720 Three Rivers Fed 35-21-720 35 0705 200E 4304753943 Federal Federal OW APD PERPEND 07/25/13THREERIVERSFED35-32-720 Three Rivers Fed 35-32-720 35 0705 200E 4304753005 19138 Federal Federal OW DRL APRVD 02/22/13THREERIVERSFED35-34-720 Three Rivers Fed 35-34-720 35 0705 200E 4304753006 Federal Federal OW APD APRVD 02/22/13THREERIVERSFED35-42-720 Three Rivers Fed 35-42-720 35 0703 200E 4304753007 Federal Federal OW APD APRVD 02/22/13Three Rivers Federal 35-43-720 Three Rivers Fed 35-43-720 35 0705 200E 4304753918 Federal Federal OW APD APRVD 08/01/13Three Rivers Federal 35-442-720 Three Rivers Fed 35-442-720 35 0705 200E 4304753919 Federal Federal OW APD APRVD 08/01/13THREERIVERSFED35-44-720 Three Rivers Fed 35-44-720 35 0705 200E 4304753008 Federal Federal OW APD APRVD 02/22/13Three Rivers Fed 03-34-820 Three Rivers Fed 03-34-820 3 0805 200E Federal NA SUB 12/10/13Three Rivers Fed 03-44-820 Three Rivers Fed 03-44-820 3 0805 200E Federal NA SUB 12/10/13Three Rivers Fed 08-31-820 Three Rivers Fed 08-31-820 8 0803 200E Federal NA SUB 12/07/13Three Rivers Fed 08-41-820 Three Rivers Fed 08-41-820 9 080S 200E Federal NA SUB 12/07/13

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RECEIVEDForm 3160-3 FORMAPPROVED(August2007) OMB No. 1004-0136UNITED STATES Expires July 31, 2010

DEPARTMENT OF THE INTERIOR ABUREAU OF LAND MANAGEMENT 5. Lease Serial No.

UTU85994APPLICATION FOR PERMIT TO DRILL OR REENTELM 6. IfIndian, Allottee or Tribe Name

l a. Type of Work: O DRILL O REENTER C NFIDENTIAL 7. If Unit or CA Agreement, Name and No.

8. Lease Name and We11No.lb. Type of Well: O Oil Well O Gas Well O Other O Multiple Zone g Single Zone THREE RIVERS FED 3-23-8202. Name of Operator Contact: DON S HAMILTON 9. API Well No.Ultra Resources, Inc. E-Mail: [email protected]

3a. Address 3b. Phone No. (include area code) 10. Field and Pool, or Exploratory304 Inverness Way South, Suite 295 Ph: 435-719-2018 UNDESIGNATEDEnglewood, CO 80112 Fx: 435-719-2019

4. Location of Well (Report location clearly and in accordance with any State requirements.*) 11. Sec., T., R., M., or Blk. and Survey or AreaAt surface NWSW 1475FSL 1237FWL 40.148539 N Lat, 109.659714 W Lon Sec 3 T8S R20E Mer SLBAtproposedprod. zone NESW 1980FSL 1980FWL 40.149950 N Lat, 109.657072 W Lon

14. Distance in miles and direction from nearest town or post office* 12. County or Parish 13. State26.4 MILES SOUTHWEST OF VERNAL, UTAH UINTAH UT15. Distance from proposed location to nearest property or 16. No. of Acres in Lease 17. Spacing Unit dedicated to this welllease line, ft. (Also to nearest drig. unit line, if any)

1237 1818.00 40.0018. Distance from proposed location to nearest well, drilling, 19. Proposed Depth 20. BLM/BIA Bond No. on filecompleted, applied for, on this lease, ft.

40 7111 MD UTBOOO5936955 TVD RECEIVED

21. Elevations (Show whether DF, KB, RT, GL, etc. 22. Approximate date work will start 23. Estimated duration4745 GL 08/25/2013 60 DAYS

24. AttachmentsThe following, completed in accordance with the requirements of Onshore Oil and Gas Order No. 1, shall be attached to this form: DIV.Ul-CIL,GAS&MININC1. 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 certificationSUPO shall be filed with the appropriate Forest Service Office). 6. Such other site specific informationand/or plans as may be required by the

authorized of5cer.

25. Signature Name (Printed/Typed) Date(Electronic Submission) DON S HAMILTON Ph: 435-719-2018 08/12/2013Title

PERMITTINGAGENTApproved by (Signatur Name (Printed/Typed)

Title ngMgidManage; Omce VERNALFIELDOFFICE&MineralResourcesApplication approval does not warrant or certify the applicant holds legal or equitable title to those rights in the subject leasewhich would entitle the applicant to conductoperations thereon.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 department or agency of the UnitedStates any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction.

Additional Operator Remarks (see next page)

Electronic Submission #216769 verified by the BLM Well Information System

NOTICEOFAPPROVALCONDITIONSOFAPPROVALATTACHED

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













authorized of5cer.





















authorized of5cer.





















authorized of5cer.









UNITED STATES DEPARTMENT OF THE INTERIORBUREAU OF LAND MANAGEMENT

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

CONDITIONS OF APPROVAL FOR APPLICATION FOR PERMIT TO DRILL

Company: Ultra Resources, Inc. Location: NWSW, Sec. 3, T8S, R20EWell No: Three Rivers Fed 3-23-820 Lease No: UTU-85994API No: 43-047-53953 Agreement: NIA

OFFICE NUMBER: (435) 781-4400

OFFICE FAX NUMBER: (435) 781-3420

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 the applicablelaws, regulations (43 CFR Part 3160), and this approved Application for Permit to Drill including Surface andDownhole 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. Thispermit is approved for a two (2) year period, or until lease expiration, whichever occurs first. An additionalextension, up to two (2) years, may be applied for by sundry notice prior to expiration.

NOTIFICATION REQUIREMENTS

Location Construction - Forty-Eight (48) hours prior to construction of location and |(Notify Environmental Scientist) access roads.

Location Completion - Prior to moving on the drilling rig.(Notify Environmental Scientist)

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

Casing String & Cementing - Twenty-Four (24) hours prior to running casing and(Notify Supv. Petroleum Tech.) cementing all casing strings to:

blm ut vn [email protected] & Related Equipment Tests - Twenty-Four (24) hours prior to initiating pressure tests.(Notify Supv. Petroleum Tech.)

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

more than ninety (90)

















































of 6Well: Three Rivers Fed. 3-23-820

3/20/2014

SURFACE USE PROGRAMCONDITIONSOF APPROVAL (COAs)

• All new and replacement internal combustion gas field engines of less than or equal to 300 design-rated horsepower must not emit more than 2 gms of NOxper horsepower-hour. This requirementdoes not apply to gas field engines of less than or equal to 40 design-rated horsepower.

• All and replacement internal combustion gas field engines of greater than 300 design ratedhorsepower must not emit more than 1.0 gms of NOx per horsepower-hour.

• Ifthere is an active Gilsonite mining operation within 2 miles of the well location, operator shallnotify the Gilsonite operator at least 48 hours prior to any blasting during construction.

• If paleontological materials are uncovered during construction, the operator is to immediately stopwork and contact the Authorized Officer (AO). A determination willbe made by the AO as to whatmitigation may be necessary for the discovered paleontologic material before construction cancontinue.

SITE SPECIFIC COAs:

• 300 design-rated horse power must not emit more than 2 grams of NOx per horsepower-hour. This requirement does not apply to gas field engines of less than or equal to 40design-rated horsepower-hour.

• AIIvehicles and equipment shall be cleaned either through power-washing, or otherapproved method, if the vehicles or equipment were brought in from areas outside theUinta Basin, to prevent AII new and replacement internal combustion gas field engines ofless than or equal to weed seed introduction.

• Project activities are not allowed from March 1 - August 31 to minimize impacts duringburrowing owl nesting season. This Condition of Approval only applies to the following welllocations:

• Three Rivers # 5-42-820, 5-43-820, and 4-13-820;• Three Rivers # 3-13-820, 3-14-820, 3-23-820,and 3-24-820;• Three Rivers # 35-11-720 and

Page 2 of 6Well: Three Rivers Fed. 3-23-820

3/20/2014






SITE SPECIFIC COAs:






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SITE SPECIFIC COAs:






3/20/2014






SITE SPECIFIC COAs:






3/20/2014

DOWNHOLE PROGRAMCONDITIONS OF APPROVAL (COAs)

SITE SPECIFIC DOWNHOLE COAs:

• Cement for the surface casing shall be circulated to the surface. Cement for the production casingshall be brought up to a minimum of 200 feet above the surface casing shoe.

• A CBL shall be run from TD to TOC in the Production Casing.

• Cement sample shall be caught and tested for compressibility for the lead and tailcement for thesurface and production casing. The results shall be reported with the completion report.

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

DRILLINGICOMPLETIONIPRODUCING OPERATINGSTANDARDS

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

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

• All requirements listed in Onshore Order #2 III. E. Special Drilling Operations are applicable for airdrilling 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 the dailydrilling report. Components shall be operated and tested as required by Onshore Oil & Gas OrderNo. 2 to insure good mechanical working order. All BOPE pressure tests shall be performed by atest pump with a chart recorder and by the rig pumps. Test shall be reported in the driller'slog.

• BOP drills shall be initially conducted by each drilling crew within 24 hours of drillingout from underthe 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 withincasing.

• Cement baskets shall not be run on surface casing.

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


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3/20/2014

• The operator must report encounters of all non oil & gas mineral resources (such as Gilsonite, tarsands, oilshale, trona, etc.) to the Vernal Field Office, in writing,within 5 working days of eachencounter. Each report shall include the well namelnumber, well location, date and depth (from KBor GL) of encounter, vertical footage of the encounter and, the name of the person making thereport (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 wellwillbe submitted tothe 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 Engineersuntilthe well is completed.

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

• Please submit an electronic copy of all other logs run on this well in LAS format [email protected]. This submission will supersede the requirement for submittalof 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 operation musthave prior approval from the BLM Vernal Field


3/20/2014








3/20/2014








3/20/2014








3/20/2014

OPERATING REQUIREMENT REMINDERS:

• All wells, whether drilling, producing, suspended, or abandoned, shall be identified in accordancewith43 CFR 3162.6. There shall be a sign or marker with the name of the operator, lease serialnumber, well number, and surveyed description of the well.

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

• Should the well be successfully completed for production, the BLMVernal Field office must benotifiedwhen it is placed in a producing status. Such notificationwillbe by written communicationand must be received in this officeby not later than the fifth business day following the date onwhich the well is placed on production. The notificationshall provide, as a minimum,the followinginformational items:

o Operator name, address, and telephone number.

o Well name and number.

o Well location (¼¼,Sec., Twn, Rng, and P.M.).

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

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; otherwise thenort-Federal or non-Indian land category, i.e., State or private.

o Unitagreement 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 andneeds prior approval from the BLMVernal Field Office.

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

• Whether the well is completed as a dry hole or as a producer, "WellCompletion and RecompletionReport and Log" (BLM Form 3160-4) shall be submitted not later than 30 days after completion ofthe 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 compiledduring 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


3/20/2014

















3/20/2014

















3/20/2014

















3/20/2014

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 comminglingon-lease or off-lease, shall have priorwritten approval from the BLMVernal Field Office.

• Oiland gas meters shall be calibrated in place prior to any deliveries. The BLMVernal Field OfficePetroleum Engineers will be provided with a date and timefor the initial meter calibration and allfuture meter proving schedules. A copy of the meter calibration reports shall be submitted to theBLMVernal Field Office. All measurement facilities will conform to the API standards for liquidhydrocarbons and the AGA standards for natural gas measurement. AIImeasurement points shallbe 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 tothe BLMVernal Field Office within 30 days of installation or first production, whichever occurs first.AIIsite security regulations as specified in Onshore Oil & Gas Order No. 3 shall be adhered to. AIIproduct lines entering and leaving hydrocarbon storage tanks will be effectivelysealed inaccordance with Onshore Oil & Gas Order No. 3.

• 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 of asuitable plan and need prior approval of the BLM Vernal Field Office. Emergency approval may beobtained 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 prior approvalof the BLMVernal Field Office. Ifoperations are to be suspended for more than 30 days, priorapproval of the BLMVernal Field Office shall be obtained and notificationgiven before resumptionof operations.

• Pursuant to Onshore Oil & Gas Order No. 7, this is authorization for pit disposal of water producedfrom thiswell for a period of 90 days from the date of initial production. A permanent disposalmethod must be approved by this office and in operation prior to the end of this 90-day period. Inorder to meet this deadline, an application for the proposed permanent disposal method shall besubmitted along with any necessary water analyses, as soon as possible, but no later than 45 daysafter the date of first production. Any method of disposal which has not been approved prior to theend of the authorized 90-day period willbe considered as an Incident of Noncompliance and will begrounds for issuing a shut-in order untilan acceptable manner for disposing of said water isprovided and approved by this office.

• Unless the plugging is to take place immediately upon receipt of oral approval, the Field OfficePetroleum Engineers must be notifiedat least 24 hours in advance of the plugging of the well, inorder that a representative may witness plugging operations. If a well is suspended or abandoned,all pits must be fenced immediately untilthey are backfilled. The "Subsequent Report ofAbandonment" (Form BLM 3160-5) must be submitted within30 days after the actual plugging ofthe well bore, showing location of plugs, amount of cement in each, and amount of casing left inhole, and the current status of the surface


3/20/2014










3/20/2014










3/20/2014









RECEIVED: Apr. 15, 2014

FEDERAL APPROVAL OF THIS ACTION IS NECESSARY


DIVISION OF OIL, GAS, AND MINING

FORM 9

5.LEASE DESIGNATION AND SERIAL NUMBER: UTU85994

SUNDRY NOTICES AND REPORTS ON WELLS

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

6. IF INDIAN, ALLOTTEE OR TRIBE NAME:

7.UNIT or CA AGREEMENT NAME:

1. TYPE OF WELL Oil Well

8. WELL NAME and NUMBER: Three Rivers Federal 3-23-820

2. NAME OF OPERATOR: ULTRA RESOURCES INC

9. API NUMBER: 43047539530000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 304 Inverness Way South #245 , Englewood, CO, 80112 303 645-9810 Ext

9. FIELD and POOL or WILDCAT: THREE RIVERS

4. LOCATION OF WELL FOOTAGES AT SURFACE: 1536 FSL 1296 FWL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: NWSW Section: 03 Township: 08.0S Range: 20.0E Meridian: S

COUNTY: UINTAH

STATE: UTAH

11.

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

TYPE OF SUBMISSION TYPE OF ACTION

NOTICE OF INTENTApproximate date work will start:

7 /1 /2014

SUBSEQUENT REPORTDate of Work Completion:

SPUD REPORTDate of Spud:

DRILLING REPORTReport Date:

ACIDIZE ALTER CASING CASING REPAIR

CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME

CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

DEEPEN FRACTURE TREAT NEW CONSTRUCTION

OPERATOR CHANGE PLUG AND ABANDON PLUG BACK

PRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION

REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON

TUBING REPAIR VENT OR FLARE WATER DISPOSAL

WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION

WILDCAT WELL DETERMINATION OTHER OTHER:

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

Ultra requests to change TD from 7,111 MD/6,955 TVD to 6,901MD/6,791 TVD and to update the SHL per attached Plat, Drilling Planand Directional Plan and Exception Location Letter to the previously

approved APD.

NAME (PLEASE PRINT) PHONE NUMBER Jenna Anderson 303 645-9804

TITLE Permitting Assistant

SIGNATURE N/A

DATE 4 /15 /2014

May 27, 2014

Sundry Number: 50132 API Well Number: 43047539530000Sundry Number: 50132 API Well Number: 43047539530000FEDERAL APPROVAL OF THIS ACTION IS NECESSARY

FORM 9STATE OF UTAH

DEPARTMENTOF NATURALRESOURCES5.LEASE DESIGNATION AND SERIAL NUMBER:DIVISION OF OIL, GAS, AND MINING UTU85994

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

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

FOR PERMIT TO DRILL form for such proposals.

1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well Three Rivers Federal 3-23-820

2. NAME OF OPERATOR: 9. API NUMBER:ULTRARESOURCES INC 43047539530000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:304 Inverness Way South #245 , Englewood, CO, 80112 303 645-9810 Ext THREE RIVERS

4. LOCATION OF WELL COUNTY:FOOTAGESATSURFACE: UINTAH

1536 FSL 1296 FWLQTRIQTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:

QtrlQtr: NWSW Section: 03 Township: 08.0S Range: 20.0E Meridian: S UTAH

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


ACI DIZE ALTER CASING CASING REPAIRNOTICE OF INTENT

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

7/1/2014CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

SUBSEQUENT REPORT DEEPEN FRACTURE TREAT NEW CONSTRUCTIONDate of Work Completion:


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

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


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

WILDCATWELLDETERMINATION OTHER OTHER:


Ultra requests to change TD from 7,111 MD/6,955 TVD to 6,901 Approved by theMD/6,791 TVD and to update the SHL per attached Plat, Drilling Plan utah Division ofand Directional Plan and Exception Location Letter to the previously aas2and OM14ning

approved APD. Date:

By:

NAME (PLEASE PRINT) PHONE NUMBER TITLEJenna Anderson 303 645-9804 Permitting Assistant

SIGNATURE DATEN/A 4/15/2014

RECEIVED: Apr. 15,

Sundry Number: 50132 API Well Number: 43047539530000FEDERAL APPROVAL OF THIS ACTION IS NECESSARY

FORM 9STATE OF UTAH

























approved APD. Date:

By:



RECEIVED: Apr. 15,


FORM 9STATE OF UTAH

























approved APD. Date:

By:



RECEIVED: Apr. 15,


FORM 9STATE OF UTAH

























approved APD. Date:

By:



RECEIVED: Apr. 15,

RECEIVED: May. 15, 2014

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Map Produced by Diana Mason

F1,400 0 1,400700 Feet

1:13,814

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

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Location Map

API Number: 4304753953Well Name: Three Rivers Federal 3-23-820 Township: T08.0S Range: R20.0E Section: 03 Meridian: S

Operator: ULTRA RESOURCES INC

Map Prepared: 5/15/2014

Sundry Number: 50132 API Well Number: 43047539530000Sundry Number: 50132 API Well Number: 43047539530000

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WASHINGTON KANE

1.400 Feet

I i 1:13,814

RECEIVED: May. 15,


ROBERT L.KAY

No. 161319

A


TBS, R20 E, S. L. B. &M. ULTRA RESOURCES, INC.Well location, THREE RIVERS FED #3-23-820,located as shown in the NW 1/4 SW 1/4 of

sne .49'J4"W- 2631.48' (Meas.) SB9°17'56"W

- 2661.97' (Meas.) - T7S Section 3, T8s, R20E, S.L.B.&M., Uintah County,



LOT 2 BENCH MARK (38EAM) LOCATED IN THE SW 1/4 OF SECTIONLOT 1 9, T7S, R20E, S.L.B.&M. TAKEN FROM THE PELICAN LAKE,

LOT 4 LOT 3 / QUADRANGLE,UTAH, UINTAH COUNTY, 7.5 MINUTE QUAD/ I , 1' (TOPOGRAPHIC MAP) PUBLISHED BY THE UNITED STATES

DEPARTMENTOF THE INTERIOR, GEOLOGICALSURVEY. SAIDELEVATIONIS MARKED AS BEING 4942 FEET.

1296 BASIS OF BEARINGSBASIS OF BEARINGS IS A G.P.S. OBSERVATION.

1/16 SectionLine

Detal/ "A"No Sca/e 1998 Priv. N

3 Alum. Cap,

Found0.8' High

Nail

Torget Bottom Ho/e o

1296' r SCALECERTIFICATE LAND

I THIS IS TO CERTIFYTHAT THE ABOVE Di See Detal/ "A THREE R/ VERS EED /3-23-820

y FIELD NOTES OF ACTUALSURVEYS M OR UNDE@ Above Right E/ev. Ungraded Ground = 4748' sPEROSIMONYKANNODDATETHAENDBMELEIE U Ig O

REGIS D LA DS ORREGISTR . 131STATE O 7g g3

REVISED: 03-17-14 S.S. ggSB9;7'29"W - 5341.90' (Meas.) p,iv UINTAH ENGINEERING & LAND SURVEYING

Alu,n. Cap Alum. Cap



1" = 1000' 06-24-13 06-28-13=

90° SYMBOL PARTY REFERENCES= PROPOSED WELL HEAD. B.H. C.A. K.O. G.L.O. PLAT

NAD 83 (TARGET BOTTOMHOLE) NAD 83 (SURFACE LOCATION) WFATHFP FILEA = SECTION CORNERS LOCATED LATITUDE =

40°08°59.82" (40.149950) LATITUDE =40°08'55.35" (40.148708) HOT ULTRA RESOURCES, INCLONGITUDE=

109°39'25.46" (109.657072) LONGITUDE= 109'39'34.21" (109.659503)

RECEIVED: May. 15,



sne .49'J4"W- 2631.48' (Meas.) SB9°17'56"W








1/16 SectionLine


3 Alum. Cap,

Found0.8' High

Nail










1" = 1000' 06-24-13 06-28-13=




109°39'25.46" (109.657072) LONGITUDE= 109'39'34.21" (109.659503)

RECEIVED: May. 15,



sne .49'J4"W- 2631.48' (Meas.) SB9°17'56"W








1/16 SectionLine


3 Alum. Cap,

Found0.8' High

Nail










1" = 1000' 06-24-13 06-28-13=




109°39'25.46" (109.657072) LONGITUDE= 109'39'34.21" (109.659503)

RECEIVED: May. 15,



sne .49'J4"W- 2631.48' (Meas.) SB9°17'56"W








1/16 SectionLine


3 Alum. Cap,

Found0.8' High

Nail










1" = 1000' 06-24-13 06-28-13=




109°39'25.46" (109.657072) LONGITUDE= 109'39'34.21" (109.659503)

RECEIVED: May. 15,


ULTRA RESOURCES, INC.

MASTER 8 - POINT DRILLING PROGRAM

Slim Hole Design

8 5/8” Surface & 5 ½” Production Casing Design

DATED: 04-15-14

Directional Wells located on Ultra leases in Three Rivers Project:

Three Rivers Fed 3-23-820

SHL: Sec 3 (NWSW) T8S R20E

Uintah, Utah

ONSHORE OIL & GAS ORDER NO. 1 Approval of Operations on Onshore

Federal and Indian Oil and Gas Leases

All lease and/or unit operations are to be conducted in such a manner that full compliance is made with the applicable laws, regulations (CFR 43, Part 3160) and the approved Application for Permit to Drill. 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.



MASTER8 - POINT DRILLING PROGRAM

Slim Hole Design8 5/8" Surface & 5 ½" Production Casing Design

DATED: 04-15-14

Directional Wells located on Ultra leases inThree Rivers Project:



Uintah, Utah

ONSHORE OIL & GAS ORDER NO. 1Approval of Operations on Onshore


All lease and/or unit operations are to be conducted in such a manner that full compliance is made with the applicable laws,regulations (CFR 43, Part 3160) and the approved Application for Permit to Drill. The operator is considered fully responsiblefor the actions of his subcontractors. A copy of the approved APD must be on location during construction, drilling, andcompletion operations.

RECEIVED: May. 15,





DATED: 04-15-14




Uintah, Utah




RECEIVED: May. 15,





DATED: 04-15-14




Uintah, Utah




RECEIVED: May. 15,





DATED: 04-15-14




Uintah, Utah




RECEIVED: May. 15,


Three Rivers Fed 3-23-820 Page 2 of 5 1. Formation Tops

The estimated tops of important geologic markers are as follows:

Formation Top Top (TVD) Comments Uinta Surface BMSW 1,601’ MD / 1,600’ TVD

Garden Gulch 4,826’ MD / 4,716’ TVD Oil & Associated Gas Lower Green River* 4,996’ MD / 4,886’ TVD Oil & Associated Gas Wasatch 6,701’ MD / 6,591’ TVD Oil & Associated Gas TD 6,901’ MD / 6,791’ TVD

Asterisks (*) denotes target pay intervals All shows of fresh water and minerals will be reported and protected. A sample will be taken of any water flows and a water analysis furnished to the BLM. Oil and gas shows will be adequately tested for commercial possibilities, reported and protected by casing and cement.

2. BOP Equipment

A) The BOPE shall be closed whenever the well is unattended The Bureau of Land Management will be notified 24

hours prior to all BOPE pressure tests. The State of Utah, Division of Oil, Gas and Mining will be notified 24 hours prior to all BOPE pressure tests.

B) The BOPE shall be closed whenever the well is unattended. C) As per 43 CFR 3160, Onshore Oil and Gas Order No. 2, Drilling Operations, Part A:

1) All BOPE connections subjected to well pressure will be flanged, welded, or clamped. 2) Choke Manifold 3) Tee blocks or targeted ‘T’s will be used and anchored to prevent slip and reduce vibration. 4) Two adjustable chokes will be used in the choke manifold. 5) All valves (except chokes) in kill line choke manifold and choke line will not restrict the

flow. 6) Pressure gauges in the well control system will be designed for drilling fluid.

D) BOPE Testing: 1) BOPE shall be pressure tested when initially installed, whenever any seal subject to pressure testing is broken,

or after repairs. 2) All BOP tests will be performed with a test plug in place. 3) BOP will be tested to full stack working pressure and annular preventer to 50% stack working pressure.

INTERVAL BOP EQUIPMENT 0 - 1,000’ MD / 1, 000’ TVD 11” Diverter with Rotating Head 1,000’ MD / 1, 000’ TVD – 6,901’ MD / 6,791’ TVD 3,000# Ram Double BOP & Annular with

Diverter & Rotating Head NOTE: Drilling spool to accommodate choke and kill lines.

3. Casing and Float Equipment Program

CASING:

Directional

Well Hole Size OD Depth MD/TVD Wt. Grade &

Connection Cond.

Surface 11” 8 5/8” 1,000’ MD / 1, 000’ TVD 24.0 ppf J-55, LTC New Production 7 7/8” 5 ½” 6,901’ MD / 6,791’ TVD 17.0 ppf J-55, LTC New


Three Rivers Fed 3-23-820 Page 2 of 5

1. Formation TopsThe estimated tops of important geologic markers are as follows:

Formation Top Top (TVD) CommentsUinta SurfaceBMSW 1,601' MD / 1,600' TVDGarden Gulch 4,826' MD / 4,716' TVD Oil & Associated GasLower Green River* 4,996' MD / 4,886' TVD Oil & Associated GasWasatch 6,701' MD / 6,591' TVD Oil & Associated GasTD 6,901' MD / 6,791' TVD

Asterisks (*)denotes target pay intervalsAll shows of fresh water and minerals will be reported and protected. A sample will be taken of any water flows and awater analysis furnished to the BLM. Oil and gas shows will be adequately tested for commercial possibilities, reportedand protected by casing and cement.

2. BOP Equipment

A) The BOPE shall be closed whenever the well is unattended The Bureau of Land Management will be notified 24hours prior to all BOPE pressure tests. The State of Utah, Division of Oil, Gas and Mining will be notified 24 hoursprior to all BOPE pressure tests.



1) All BOPE connections subjected to well pressure will be flanged, welded, or clamped.2) Choke Manifold3) Tee blocks or targeted 'T's will be used and anchored to prevent slip and reduce vibration.4) Two adjustable chokes will be used in the choke manifold.5) All valves (except chokes) in kill line choke manifold and choke line will not restrict the

flow.6) Pressure gauges in the well control system will be designed for drilling fluid.

D) BOPE Testing:1) BOPE shall be pressure tested when initially installed, whenever any seal subject to pressure testing is broken,

or after repairs.2) All BOP tests will be performed with a test plug in place.3) BOP will be tested to full stack working pressure and annular preventer to 50% stack working pressure.

INTERVAL BOP EQUIPMENT0 - 1,000' MD / 1, 000' TVD 11" Diverter with Rotating Head1,000' MD / 1, 000' TVD - 6,901' MD / 6,791' TVD 3,000# Ram Double BOP & Annular with

Diverter & Rotating HeadNOTE: Drilling spool to accommodate choke and kill lines.


CASING:

Hole Grade &Directional OD Depth MD/TVD Wt. Cond.Size ConnectionWellSurface 11" 8 5/8" 1,000' MD / 1, 000' TVD 24.0 ppf J-55, LTC NewProduction 7 7/8" 5 ½" 6,901' MD / 6,791' TVD 17.0 ppf J-55, LTC New

RECEIVED: May. 15,






2. BOP Equipment











CASING:


RECEIVED: May. 15,






2. BOP Equipment











CASING:


RECEIVED: May. 15,






2. BOP Equipment











CASING:


RECEIVED: May. 15,



CASING SPECIFICATIONS:

FLOAT EQUIPMENT:

SURFACE (8 5/8”) Float Shoe, 1 joint casing, float collar Centralizers: 1 each 1st 4 Joints then every 4th joint to surface PRODUCTION (5 ½”) Float Shoe, 1 joint casing, float collar Centralizers: 1 each 1st 4 Joints then every 3rd joint to 500’ into surface casing

4. Cementing Programs

CONDUCTOR (13 ⅜”) Ready Mix – Cement to surface

SURFACE (8 5/8”) Cement Top - Surface

Surface – 500’ Lead: 80 sks, Premium Lightweight Cmt w/ additives, 11.5 ppg, 2,97 cf/sk 50% excess

500’ – 1,000’ MD / 1, 000’ TVD± Tail: 115 sks Glass G Cement w/ additives, 15.8 ppg, 1.16 cf/sx, 50% excess

Note: The above volumes are based on a gauge-hole + 50% excess. PRODUCTION (5 ½”) Cement Top – 500’ 500’ - 4,000’ TVD ± Lead: 225 sks – Econocem Cement w/ 0.25 lbm Poly-E-Flake, 1%

Granulite TR ¼, 5 lbm Kol-Seal; 11.0 ppg; 3.54 cf/sx; 15% excess 4,000’ – 6,901’ MD / 6,791’ TVD Tail: 450 sks, Expandacem Cement w/ 0.25 lbm Poly-E-Flake, 1 lbm

Granulite TR ¼, 2 lbm Kol-Seal; 14.0 pp; 1.349 cf/sk; 15% excess Note: Lead Cement will be brought to 4,000’ which will give a minimum of 500’ above Lower Green River. A) For Surface casing, if cement falls or does not circulate to surface, cement will be topped off. B) Cement will not be placed down annulus with a 1” pipe unless BLM is contacted. C) The Bureau of Land Management will be notified 24 hours prior to running casing and cementing. D) As per 43 CFR 3160, Onshore Oil and Gas Order No.2, Drilling Operations, Part B:

1) All waiting on cement times shall be adequate to achieve a minimum of 500 psi compressive

strength at the casing shoe (minimum of 8 hours) prior to drilling out. 2) Prior to drilling out cement, casing will be pressure tested to 1500 psi. Pressure decline must not

be greater than 10% (150 psi) in 30 minutes. 3) Progress reports, Form 3160-5 “Sundry Notices and Reports on Wells”, shall be filed with the

Field Manager within 30 days after the work in completed. 4) Setting of each string of casing, size, grade, weight of casing set, hole size, setting depth, amounts

and type of cement used, whether cement circulated or the top of the cement behind the casing, depth of cementing tools used, casing test method and results, and the date work was done. Show the spud date on the first reports submitted.

5) Temperature or bond logs must be submitted for each well where the casing cement was not circulated to the surface.

6) A pressure integrity test of each casing shoe shall be performed. Formation at the shoe shall be tested to a minimum of the mud weight equivalent anticipated to control the formation pressure to

Directional Well Casing OD Casing

ID / Drift ID Collapse

(psi) Int. Yield

(psi) Ten. Yield

(lb) Jt. Strength

(lb) Surface 8 5/8” 8.097” / 7.972” 1,370 2,950 381,000 244,000

Production 5 ½” 4.492” / 4.767” 4,910 5,320’ 273,000 229,000




Directional Casing Collapse Int. Yield Ten. Yield Jt. StrengthWell Casing OD ID / Drift ID (psi) (psi) (lb) (lb)

Surface 8 5/8" 8.097" / 7.972" 1,370 2,950 38 1,000 244,000

Production 5 ½" 4.492" / 4.767" 4,910 5,320' 273,000 229,000

FLOAT EQUIPMENT:SURFACE (8 5/8") Float Shoe, 1 joint casing, float collar

Centralizers: 1 each 16'4 Joints then every 4thjOinÍÍO SUTface

PRODUCTION (5 ½") Float Shoe, 1 joint casing, float collarCentralizers: 1 each 16'4 Joints then every 3rdjOint to 500' into surface casing


CONDUCTOR (13 ¾") Ready Mix - Cement to surface

SURFACE (8 5/8") Cement Top - SurfaceSurface - 500' Lead: 80 sks, Premium Lightweight Cmt w/ additives, l1.5 ppg, 2,97 cf/sk 50%

excess500' - 1,000' MD / 1, 000' TVD± Tail: 115 sks Glass G Cement w/ additives, 15.8 ppg, 1.16 cf/sx, 50% excess

Note: The above volumes are based on a gauge-hole + 50% excess.

PRODUCTION (5 ½") Cement Top - 500'500' - 4,000' TVD ± Lead: 225 sks - Econocem Cement w/ 0.25 lbm Poly-E-Flake, 1%

Granulite TR ¼, 5 lbm Kol-Seal; 11.0 ppg; 3.54 cf/sx; 15% excess4,000' - 6,901' MD / 6,791' TVD Tail: 450 sks, Expandacem Cement w/ 0.25 lbm Poly-E-Flake, l lbm

Granulite TR ¼, 2 lbm Kol-Seal; 14.0 pp; 1.349 cf/sk; 15% excess

Note: Lead Cement will be brought to 4,000' which will give a minimum of 500' above Lower GreenRiver.

A) For Surface casing, if cement falls or does not circulate to surface, cement will be topped off.B) Cement will not be placed down annulus with a 1" pipe unless BLM is contacted.C) The Bureau of Land Management will be notified 24 hours prior to running casing and cementing.D) As per 43 CFR 3160, Onshore Oil and Gas Order No.2, Drilling Operations, Part B:

1) All waiting on cement times shall be adequate to achieve a minimum of 500 psi compressivestrength at the casing shoe (minimum of 8 hours) prior to drilling out.

2) Prior to drilling out cement, casing will be pressure tested to 1500 psi. Pressure decline must notbe greater than 10% (150 psi) in 30 minutes.

3) Progress reports, Form 3160-5 "Sundry Notices and Reports on Wells", shall be filed with theField Manager within 30 days after the work in completed.

4) Setting of each string of casing, size, grade, weight of casing set, hole size, setting depth, amountsand type of cement used, whether cement circulated or the top of the cement behind the casing,depth of cementing tools used, casing test method and results, and the date work was done. Showthe spud date on the first reports submitted.

5) Temperature or bond logs must be submitted for each well where the casing cement was notcirculated to the surface.

6) A pressure integrity test of each casing shoe shall be performed. Formation at the shoe shall betested to a minimum of the mud weight equivalent anticipated to control the formation pressure to

RECEIVED: May. 15,





Surface 8 5/8" 8.097" / 7.972" 1,370 2,950 38 1,000 244,000

Production 5 ½" 4.492" / 4.767" 4,910 5,320' 273,000 229,000




















RECEIVED: May. 15,





Surface 8 5/8" 8.097" / 7.972" 1,370 2,950 38 1,000 244,000

Production 5 ½" 4.492" / 4.767" 4,910 5,320' 273,000 229,000




















RECEIVED: May. 15,





Surface 8 5/8" 8.097" / 7.972" 1,370 2,950 38 1,000 244,000

Production 5 ½" 4.492" / 4.767" 4,910 5,320' 273,000 229,000




















RECEIVED: May. 15,



the next casing depth or at total depth of the well. This test shall be performed after drilling 5-10 feet of new hole.

5. Mud Program The proposed circulating mediums to be employed in drilling are as follows:

Interval Mud Type Viscosity Fluid Loss pH Mud Wt. (ppg)

0 – 1,000’ MD / 1, 000’ TVD Water/Spud Mud 32 No Control (NC) 7.0 -8.2 <8.8 1,000’ MD / 1, 000’ TVD - 6,901’ MD / 6,791’ TVD DAP System 40 - 60 10 - 18 7.0-8.2 <10.0

A) For Surface Sufficient quantities of mud materials will be maintained or readily accessible for the

purpose of assuring well control during the course of drilling operations. A mud test shall be performed every 24 hours after mudding up to determine, as applicable: density, viscosity, gel strength, filtration, and pH.

B) The mud monitoring equipment on location will be installed by top of Green River and will be able to monitor at a minimum the pit volume totalizer (PVT), stroke counter, and flow sensor

C) Flare line discharge will be located no less than 100 feet from the wellhead using straight or targeted

‘T’ and anchors.

6. Evaluation Program - Testing, Logging, and Coring A) Cores: None anticipated. B) Testing: None anticipated. C) Directional Drilling: Directional tools will be used to locate the bottom hole per the attached

directional plan +/-. D) Open Hole Logs: TD to surface casing: resistivity, neutron density, gamma ray and caliper. E) Mud Logs: None anticipated. F) Formation to TD; record and monitor gas shows and record drill times (normal mud logging duties).

7. Anticipated Pressures and H.S.

A) The expected bottom hole pressure is 3,500 – 3,650 psig. Normal pressures are anticipated from

surface to approximately TD. These pressures will be controlled by a blowout preventer stack, annular BOP, choke manifold, mud/gas separator, surface equipment and drilling mud. A supply of barite to weight the mud to a balancing specific gravity, if necessary, will be on location.

B) Maximum expected surface pressure will be based on the frac gradient of the casing shoe. The design of the casing assumes that the MASP will be the fracture pressure at the shoe less a column of gas.

C) No hydrogen sulfide gas is anticipated, however if H2S is encountered, the guidelines in Onshore Oil and Gas Order No. 6 will be complied with.

8. Other Information and Notification Requirements

A) There shall be no deviation from the proposed drilling and/or workover program as approved. Any

changes in operation must have prior approval from the Utah Division of Oil, Gas and Mining, and the BLM Vernal (when drilling on Federal leases). 1) Anticipated starting date will be upon approval. It is anticipated that completion operations will

begin within 15 days after the well has been drilled. 2) It is anticipated that the drilling and completion of this well will take approximately 90 days.



the next casing depth or at total depth of the well. This test shall be performed after drilling 5-10feet of new hole.

5. Mud Program

The proposed circulating mediums to be employed in drilling are as follows:

Mud WtInterval Mud Type Viscosity Fluid Loss pH °

(ppg)0 - 1,000' MD / 1, 000' Water/Spud MudTVD 32 No Control (NC) 7.0 -8.2 <8.8

1,000' MD / 1, 000' TVD -

DAP System 40 - 60 10 - 18 7.0-8.2 <10.06,901' MD / 6,791' TVD

A) For Surface Sufficient quantities of mud materials will be maintained or readily accessible for thepurpose of assuring well control during the course of drilling operations. A mud test shall beperformed every 24 hours after mudding up to determine, as applicable: density, viscosity, gel strength,filtration, and pH.

B) The mud monitoring equipment on location will be installed by top of Green River and will be able tomonitor at a minimum the pit volume totalizer (PVT), stroke counter, and flow sensor

C) Flare line discharge will be located no less than 100 feet from the wellhead using straight or targeted'T' and anchors.

6. Evaluation Program - Testing, Logging, and Coring

A) Cores: None anticipated.B) Testing: None anticipated.C) Directional Drilling: Directional tools will be used to locate the bottom hole per the attached

directional plan +/-.

D) Open Hole Logs: TD to surface casing: resistivity, neutron density, gamma ray and caliper.E) Mud Logs: None anticipated.F) Formation to TD; record and monitor gas shows and record drill times (normal mud logging duties).


A) The expected bottom hole pressure is 3,500 - 3,650 psig. Normal pressures are anticipated fromsurface to approximately TD. These pressures will be controlled by a blowout preventer stack, annularBOP, choke manifold, mud/gas separator, surface equipment and drilling mud. A supply of barite toweight the mud to a balancing specific gravity, if necessary, will be on location.

B) Maximum expected surface pressure will be based on the frac gradient of the casing shoe. The designof the casing assumes that the MASP will be the fracture pressure at the shoe less a column of gas.

C) No hydrogen sulfide gas is anticipated, however if H2S is encountered, the guidelines in Onshore Oiland Gas Order No. 6 will be complied with.


A) There shall be no deviation from the proposed drilling and/or workover program as approved. Anychanges in operation must have prior approval from the Utah Division of Oil, Gas and Mining,and the BLM Vernal (when drilling on Federal leases).1) Anticipated starting date will be upon approval. It is anticipated that completion operations will

begin within 15 days after the well has been drilled.2) It is anticipated that the drilling and completion of this well will take approximately 90 days.

RECEIVED: May. 15,




5. Mud Program




1,000' MD / 1, 000' TVD -

DAP System 40 - 60 10 - 18 7.0-8.2 <10.06,901' MD / 6,791' TVD















RECEIVED: May. 15,




5. Mud Program




1,000' MD / 1, 000' TVD -

DAP System 40 - 60 10 - 18 7.0-8.2 <10.06,901' MD / 6,791' TVD















RECEIVED: May. 15,




5. Mud Program




1,000' MD / 1, 000' TVD -

DAP System 40 - 60 10 - 18 7.0-8.2 <10.06,901' MD / 6,791' TVD















RECEIVED: May. 15,


Three Rivers Fed 3-23-820 Page 5 of 5 B) Notification Requirements for Utah Division of Oil, Gas and Mining:

• Within 24 hrs. of spud (Carol Daniels at 801/538-5284) • 24 hrs. prior to testing BOP equipment (Dan Jarvis 801/538-5338 or 231-8956) • 24 hrs. prior to cementing or testing casing (Dan Jarvis) • Within 24 hrs. of making any emergency changes to APD (Dustin Doucet 801/538-

5281 or 733-0983) C) Notification Requirements BLM Vernal when drilling on Federal leases as follows: (Cade T Taylor @ [email protected] and [email protected]:

• Within 24 hrs. of spud (Carol Daniels at 801/538-5284) • 24 hrs. prior to testing BOP equipment (Dan Jarvis 801/538-5338 or 231-8956) • 24 hrs. prior to cementing or testing casing (Dan Jarvis) • Within 24 hrs. of making any emergency changes to APD (Dustin Doucet 801/538-

5281 or 733-0983) D) Any changes in the program must be approved by the Utah Division of Oil, Gas and Mining and

or the BLM Vernal Office. “Sundry Notices and Reports on Wells” (form 3160-5) must be filed for all changes of plans. Emergency approval may be obtained orally, but such approval does not waive the written report requirement. 1) Should the well be successfully completed for production, the BLM Pinedale Field Office must be

notified when it is placed in a producing status. The notification shall provide, as a minimum, the following information items: . Operator name, address, and telephone number. . Well name and number. . Well location (1/4 1/4, Section, Township, Range and P.M.) . Date well was placed in a producing status (date of first production for which royalty will

be paid). . 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). . The Federal or Indian lease prefix and number on which the well is located. As

appropriate, the unit agreement name, number and participating area name. As appropriate, the communitization agreement number.



B) Notification Requirements for Utah Division of Oil, Gas and Mining:• Within 24 hrs. of spud (Carol Daniels at 801/538-5284)• 24 hrs. prior to testing BOP equipment (Dan Jarvis 801/538-5338 or 231-8956)• 24 hrs. prior to cementing or testing casing (Dan Jarvis)• Within 24 hrs. of making any emergency changes to APD (Dustin Doucet 801/538-

5281 or 733-0983)

C) Notification Requirements BLM Vernal when drilling on Federal leases as follows:(Cade TTaylor @[email protected] and [email protected]:• Within 24 hrs. of spud (Carol Daniels at 801/538-5284)• 24 hrs. prior to testing BOP equipment (Dan Jarvis 801/538-5338 or 231-8956)• 24 hrs. prior to cementing or testing casing (Dan Jarvis)• Within 24 hrs. of making any emergency changes to APD (Dustin Doucet 801/538-

5281 or 733-0983)

D) Any changes in the program must be approved by the Utah Division of Oil, Gas and Mining andor the BLM Vernal Office. "Sundry Notices and Reports on Wells" (form 3160-5) must be filed for allchanges of plans. Emergency approval may be obtained orally, but such approval does not waive thewritten report requirement.1) Should the well be successfully completed for production, the BLM Pinedale Field Office must be

notified when it is placed in a producing status. The notification shall provide, as a minimum, thefollowing information items:

. Operator name, address, and telephone number.

. Well name and number.

. Well location (1/4 1/4, Section, Township, Range and P.M.)

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

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

. The Federal or Indian lease prefix and number on which the well is located. Asappropriate, the unit agreement name, number and participating area name. Asappropriate, the communitization agreement number.

RECEIVED: May. 15,




5281 or 733-0983)


5281 or 733-0983)









RECEIVED: May. 15,




5281 or 733-0983)


5281 or 733-0983)









RECEIVED: May. 15,




5281 or 733-0983)


5281 or 733-0983)









RECEIVED: May. 15,

mailto:[email protected]

mailto:[email protected]



a. Ma · a aW I § A coa o

II



II



II



II


16in Conductor : 0.00° Inc, 120.00ft MD, 120.00ft TVD, 0.00ft VSBase Gravel : 0.00° Inc, 120.00ft MD, 120.00ft TVD, 0.00ft VSTie On : 0.00° Inc, 13.00ft MD, 13.00ft TVD, 0.00ft VS

8.625in Casing Surface : 0.00° Inc, 1000.00ft MD, 1000.00ft TVD, 0.00ft VS

2.00°/100ftBMSW : 8.03° Inc, 1601.31ft MD, 1600.00ft TVD, 28.06ft VS

End of Tangent : 0.00° Inc, 1200.00ft MD, 1200.00ft TVD, 0.00ft VS

End of Build (S) : 17.09° Inc, 2054.43ft MD, 2041.82ft TVD, 126.48ft VS

End of Tangent (S) : 17.09° Inc, 3971.43ft MD, 3874.18ft TVD, 689.79ft VS

2.00°/100ft

Mahogany : 11.89° Inc, 4231.60ft MD, 4126.00ft TVD, 754.85ft VS

Garden Gulch : 0.00° Inc, 4825.86ft MD, 4716.00ft TVD, 816.26ft VSDrop (S) : 0.00° Inc, 4825.86ft MD, 4716.00ft TVD, 816.26ft VS

Lower Green River : 0.00° Inc, 4995.86ft MD, 4886.00ft TVD, 816.26ft VS

5.5in Casing Production : 0.00° Inc, 6900.86ft MD, 6791.00ft TVD, 816.26ft VSWasatch : 0.00° Inc, 6700.86ft MD, 6591.00ft TVD, 816.26ft VS

TD : 0.00° Inc, 6900.86ft MD, 6791.00ft TVD, 816.26ft VSEnd of Tangent : 0.00° Inc, 6900.86ft MD, 6791.00ft TVD, 816.26ft VS

True

Ver

tical

Dep

th (f

t)

Vertical Section (ft)Azimuth 56.35° with reference 0.00 N, 0.00 E

Scale 1 inch = 1000 ft

Scal

e 1

inch

= 1

000

ft

Coordinates are in feet referenced to Slot

Mean Sea Level to Mud line (At Slot: Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)): 0 feet

Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Mean Sea Level: 4761 feet

Measured depths are referenced to Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT)

True vertical depths are referenced to Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT)

Plot reference wellpath is Three Rivers Fed 3-23-820 PWP

Created by: ewilliams on 4/14/2014

Depths are in feet

Scale: True distance

North Reference: True north

Grid System: NAD83 / Lambert Utah SP, Central Zone (4302), US feet

Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Mean Sea Level

Mean Sea Level to Mud line (At Slot: Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL))

Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Mud line (At Slot: Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL))

Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)

Slot

Sec.03-T8S-R20E

Facility Name

-1672.71

Local N (ft)

Location Information

-871.28

Local E (ft) Grid East (US ft)

Grid East (US ft)

2154854.943

2155691.488

7228184.769

Grid North (US ft)

7229874.935

Grid North (US ft)

4761ft

0ft

4761ft

40°08'55.350"N

Latitude

40°09'11.880"N

Latitude

109°39'34.210"W

Longitude

109°39'22.990"W

Longitude

End of TangentDrop (S)

End of Tangent (S)End of Build (S)End of Tangent

Tie OnDesign Comment

6900.864825.863971.432054.431200.0013.00MD (ft)

0.000 56.3470.000 56.34717.089 56.34717.089 56.3470.000 56.3470.000 56.347Inc (°) Az (°)

6791.004716.003874.182041.821200.0013.00

TVD (ft)Well Profile Data

452.34452.34382.2670.090.000.00

Local N (ft)

679.46679.46574.18105.28

Local E (ft)

0.000.00

0.002.000.002.000.000.00

DLS (°/100ft)

816.26816.26689.79126.480.000.00

VS (ft)

Facility:

Field:

Location:

ULTRA RESOURCES, INCSec.03-T8S-R20E

UINTAH COUNTY

Three Rivers

Wellbore:

Well:

Slot:

Three Rivers Fed 3-23-820 PWB


Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)

Three Rivers Fed 3-23-820 Target On Plat 1980' FSL & 1980' FWL

Name

4500.00

MD (ft) TVD (ft) Local N (ft)

Targets

452.34 679.46

Local E (ft)

2155524.89

Grid East (US ft)

7228650.96

Grid North (US ft)

40°08'59.820"N

Latitude

109°39'25.460"W

Longitude

Three Rivers Fed 3-23-820Target On Plat

1980' FSL & 1980' FWL

Three Rivers Fed 3-23-820SHL:

(1536' FSL & 1296' FWL)

Northing (ft)

Easting (ft)Scale 1 inch = 400


ULTRA RESOURCES, INCLocation Three Rivers Slot Three Rivers Fed 3-23-820 (1536 FSL & 1296 FWL)

Field UINTAH COUNTY Well Three Rivers Fed 3-23-820

Facility Sec.03-T8S-R20E Wellbore Three Rivers Fed 3-23-820 PWB

Targets

PETROLEUM Design Comment MD (ft) Inc P) Az (Well Profile Datcaal

N (ft) Local E (ft) DLS (/100ft) VS (ft)Tie On 13.00 0.000 56 347 13 00

End of Tangent 1200 00 0.000 56 347 1200.00 0.0End of Build (S) 2054 43 17.089 56 347 2041.82 70.09 105 28 2 00 126.48

End of Tangent (S) 3971 43 17.089 56 347 3874.18 382.26 574 18 0 00 689.79Drap (S) 4825 86 0 000 56 347 4716.00 452.34 679 46 2 00 816.26

End of Tangent 6900 86 0 000 56 347 6791.00 452.34 679 46 0 00 816.26


-500 -

iotomrencemiipathisThreeRiversFeda2>s2oPwP

noeRiveraFeas2>s20eise Fsta129sFwt)(RT) endsymem NR>sattembeautansP centreizone(43o2;usset

essumadepthsammarencedtoRigonThreeRiversFeas2>s20eisseFsta129sFwt)(RT

nree Rivers Fed >2>s20 91536 Fst a 129s Fwt)(RT)to r,9

eveitor,9udiine(«siotThreeRiversFeas2>s2o(1saeFsta129sFut);omet

0 - Tie On : 0.00° Inc, 13.00ft MD, 13.00ft TVD, 0.00ft VSBase Gravel : 0.00° Inc, 120.00ft MD, 120.00ft TVD, 0.00ft VS16in Conductor : 0.00° Inc, 120.00ft MD, 120.00ft TVD, 0.00ft VS

600 -

1000 - 8.625in Casing Surface : 0.00° Inc, 1000.00ft MD, 1000.00ft TVD, 0.00ft VS

End of Tangent : 0.00° Inc, 1200.00ft MD, 1200.00ft TVD, 0.00ft VSScale 1 inch = 400 Easting (ft)

O 200 400 600 8001500- lilligggp3° Inc, 1601.31ft MD, 1600.00ft TVD, 28.06ft VS

- 600


2000 -

End of Build (S) : 17.09° Inc, 2054.43ft MD, 2041.82ft TVD, 126.48ft VS 1980' FSL & 1980' FWL -- 400

O2500 -

- 200

3000 -

Three Rivers Fed 3-23-820SHL: - 0

(1536' FSL & 1296' FWL)

3500 -

2 - -200

I-

End of Tangent (S) : 17.09° Inc, 3971.43ft MD, 3874.18ft TVD, 689.79ft VS4000 -

Mahogany : 11.89° Inc, 4231.60ft MD, 4126.00ft TVD, 754.85ft VS2.00°/100ft

4500 -


Lower Green River : 0.00° Inc, 4995.86ft MD, 4886.00ft TVD, 816.26ft VS5000 -

5500 -

6000 -

6500 -

Wasatch : 0.00° Inc, 6700.86ft MD, 6591.00ft TVD, 816.26ft VS5.5in Casing Production : 0.00° Inc, 6900.86ft MD, 6791.00ft TVD, 816.26ft VSEnd of Tangent : 0.00° Inc, 6900.86ft MD, 6791.00ft TVD, 816.26ft VSTD : 0.00° Inc, 6900.86ft MD, 6791.00ft TVD, 816.26ft VS

7000 -

IIIIIIIIO 500 1000 1500 2000 2500 3000 3500

Vertical Section (ft) Scale1inch=1000ft

Azimuth 56.35° with reference 0.00 N, 0.00 E

RECEIVED: May. 15,





Targets





End of Tangent 6900 86 0 000 56 347 6791.00 452.34 679 46 0 00 816.26


-500 -







600 -




- 600


2000 -


O2500 -

- 200

3000 -


(1536' FSL & 1296' FWL)

3500 -

2 - -200

I-



4500 -



5500 -

6000 -

6500 -


7000 -

IIIIIIIIO 500 1000 1500 2000 2500 3000 3500



RECEIVED: May. 15,





Targets





End of Tangent 6900 86 0 000 56 347 6791.00 452.34 679 46 0 00 816.26


-500 -







600 -




- 600


2000 -


O2500 -

- 200

3000 -


(1536' FSL & 1296' FWL)

3500 -

2 - -200

I-



4500 -



5500 -

6000 -

6500 -


7000 -

IIIIIIIIO 500 1000 1500 2000 2500 3000 3500



RECEIVED: May. 15,





Targets





End of Tangent 6900 86 0 000 56 347 6791.00 452.34 679 46 0 00 816.26


-500 -







600 -




- 600


2000 -


O2500 -

- 200

3000 -


(1536' FSL & 1296' FWL)

3500 -

2 - -200

I-



4500 -



5500 -

6000 -

6500 -


7000 -

IIIIIIIIO 500 1000 1500 2000 2500 3000 3500



RECEIVED: May. 15,


REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area Three Rivers Well Three Rivers Fed 3-23-820Field UINTAH COUNTY Wellbore Three Rivers Fed 3-23-820 PWBFacility Sec.03-T8S-R20E

REPORT SETUP INFORMATIONProjection System NAD83 / Lambert Utah SP, Central Zone (4302), US feet Software System WellArchitect® 3.0.0North Reference True User EwilliamsScale 0.999914 Report Generated 4/14/2014 at 2:33:11 PMConvergence at slot n/a Database/Source file WellArchitectDB/Three_Rivers_Fed_3-23-820_PWB.xml

WELLPATH LOCATIONLocal coordinates Grid coordinates Geographic coordinates

North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude LongitudeSlot Location -1672.71 -871.28 2154854.94 7228184.77 40°08'55.350"N 109°39'34.210"WFacility Reference Pt 2155691.49 7229874.94 40°09'11.880"N 109°39'22.990"WField Reference Pt 2156630.96 7236613.42 40°10'18.270"N 109°39'09.100"W

WELLPATH DATUMCalculation method Minimum curvature Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Facility Vertical DatumHorizontal Reference Pt Slot Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Mean Sea LevelVertical Reference Pt Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Mud Line at Slot (Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWMD Reference Pt Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) Section OriginField Vertical Reference Mean Sea Level Section Azimuth

Planned Wellpath ReportThree Rivers Fed 3-23-820 PWP

Page 1 of 5

Page 1 of 5

4/14/2014

Sundry Number: 50132 API Well Number: 43047539530000Sundry Number: 50132 API Well Number: 43047539530000 Page1of5

Planned Wellpath Report DYNAMICThree Rivers Fed 3-23-820 PWP GRAPHICS,INC.

Page 1 of 5PETROLELT1

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Arca Three Rivers Well Three Rivers Fed 3-23-820

Field UINTAH COUNTY Wellbore Three Rivers Fed 3-23-820 PWB

Facility Sec.03-TSS-R20E

REPORT SETUP INFORMATIONProjection System NAD83 / Lambert Utah SP, Central Zone (4302), US feet Software System WellArchitect® 3.0.0North Reference Truc User Ewilliams

Scale 0.999914 Report Generated 4/14/2014 at 2:33:11 PM

Convergence at slot n/a Database/Source file WellArchitectDB/Three_Rivers_Fed_3-23-820_PWB.xml


North[ft] East[ft] Easting[US ft] Northing[US ft] Latitude Longitude

SlotLocation -1672.71 -871.28 2154854.94 7228184.77 40°08'55.350"N 109°39'34.210"W

Facility Reference Pt 2155691.49 7229874.94 40°09'11.880"N 109°39'22.990"W

Field Reference Pt 2156630.96 7236613.42 40°10'18.270"N 109°39'09.100"W

WELLPATH DATUMCalculation method Minimum curvature Rig on Three Rivers Fed 3-23-820 91536'FSL & 1296' FWL) (RT) to Facility Vertical DatumIlorizontal Reference Pt Slot Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Mean Sea Level

Vertical Reference Pt Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) Rig on Three Rivers Fod 3-23-820 91536' FSL & 1296' FWL) (RT) to Mud Line at Slot (Three Rivers Fed 3-23-820 (1536' FSL & 1296' F3

MD Reference Pt Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) Section OriginField Vertical Reference Mean Sca Level Section Azimuth

Sundry Number: 50132 API Well Number: 43047539530000 Page1of5

Planned Wellpath Report DYNAMICThree Rivers Fed 3-23-820 PWP GRAPHICS,INC,

Page1of5PETROLELT1

REFERENCE MILLPATH IDENTIHCATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)

Area Three Rivers Well Three Rivers Fed 3-23-820


Facility Sec.03-T8S-R20E

REPORT SETUP INFORMATIONProjection System NAD83 / Lambert Utah SP, Central Zone (4302), US feet Software System WellArchitect® 3.0.0

North Reference True User Ewilliams

Scale 0.999914 Report Generated 4/14/2014 at 2:33:11 PMConvergence at slot n/a Database/Source file WellArchitectDB/Three_Rivers_Fed_3-23-820_PWB.xml

MILLPATH LOCATIONLocal coordinates Grid coordinates Geographic coordinates


SlotLocation -1672.71 -871.28 2154854.94 7228184.77 40°08'55.350"N 109°39'34.210"W

FacilityReferencePt 2155691.49 7229874.94 40°09'11.880"N 109°39'22.990"W

FieldReferencePt 2156630.96 7236613.42 40°10'18.270"N 109°39'09.100"W

MILLPATH DATUMCalculation method Minimum curvature Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Facility Vertical Datum

Horizontal Reference Pt Slot Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Mean Sea Level

Vertical Reference Pt Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) to Mud Line at Slot (Three Rivers Fed 3-23-820 (1536' FSL & 1296' F3

MD Reference Pt Rig on Three Rivers Fed 3-23-820 91536' FSL & 1296' FWL) (RT) Section Origin

Field Vertical Reference Mean Sea Level Section Azimuth



Page1of5PETROLELT1










SlotLocation -1672.71 -871.28 2154854.94 7228184.77 40°08'55.350"N 109°39'34.210"W










Page1of5PETROLELT1










SlotLocation -1672.71 -871.28 2154854.94 7228184.77 40°08'55.350"N 109°39'34.210"W











Page 2 of 5

WELLPATH DATA (80 stations) † = interpolated/extrapolated stationMD[ft]

Inclination[°]

Azimuth[°]

TVD[ft]

Vert Sect[ft]

North[ft]

East[ft]

Latitude Longitude DLS[°/100ft]

Comments

0.00† 0.000 56.347 0.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 13.00 0.000 56.347 13.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

113.00† 0.000 56.347 113.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 120.00† 0.000 56.347 120.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 Base Gravel213.00† 0.000 56.347 213.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 313.00† 0.000 56.347 313.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 413.00† 0.000 56.347 413.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 513.00† 0.000 56.347 513.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 613.00† 0.000 56.347 613.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 713.00† 0.000 56.347 713.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 813.00† 0.000 56.347 813.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 913.00† 0.000 56.347 913.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

1013.00† 0.000 56.347 1013.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 1113.00† 0.000 56.347 1113.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 1200.00 0.000 56.347 1200.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 1213.00† 0.260 56.347 1213.00 0.03 0.02 0.02 40°08'55.350"N 109°39'34.210"W 2.00 1313.00† 2.260 56.347 1312.97 2.23 1.23 1.85 40°08'55.362"N 109°39'34.186"W 2.00 1413.00† 4.260 56.347 1412.80 7.91 4.39 6.59 40°08'55.393"N 109°39'34.125"W 2.00 1513.00† 6.260 56.347 1512.38 17.08 9.47 14.22 40°08'55.444"N 109°39'34.027"W 2.00 1601.31† 8.026 56.347 1600.00 28.06 15.55 23.36 40°08'55.504"N 109°39'33.909"W 2.00 BMSW1613.00† 8.260 56.347 1611.57 29.72 16.47 24.74 40°08'55.513"N 109°39'33.891"W 2.00 1713.00† 10.260 56.347 1710.26 45.81 25.39 38.13 40°08'55.601"N 109°39'33.719"W 2.00 1813.00† 12.260 56.347 1808.33 65.33 36.21 54.38 40°08'55.708"N 109°39'33.510"W 2.00 1913.00† 14.260 56.347 1905.66 88.27 48.92 73.48 40°08'55.833"N 109°39'33.264"W 2.00 2013.00† 16.260 56.347 2002.13 114.59 63.50 95.38 40°08'55.978"N 109°39'32.982"W 2.00 2054.43 17.089 56.347 2041.82 126.48 70.09 105.28 40°08'56.043"N 109°39'32.854"W 2.00 2113.00† 17.089 56.347 2097.80 143.69 79.63 119.61 40°08'56.137"N 109°39'32.670"W 0.00 2213.00† 17.089 56.347 2193.39 173.07 95.91 144.07 40°08'56.298"N 109°39'32.355"W 0.00 2313.00† 17.089 56.347 2288.97 202.46 112.19 168.53 40°08'56.459"N 109°39'32.040"W 0.00 2413.00† 17.089 56.347 2384.56 231.84 128.48 192.99 40°08'56.620"N 109°39'31.725"W 0.00 2513.00† 17.089 56.347 2480.14 261.23 144.76 217.45 40°08'56.781"N 109°39'31.410"W 0.00 2613.00† 17.089 56.347 2575.73 290.61 161.05 241.91 40°08'56.941"N 109°39'31.095"W 0.00 2713.00† 17.089 56.347 2671.31 320.00 177.33 266.37 40°08'57.102"N 109°39'30.780"W 0.00 2813.00† 17.089 56.347 2766.90 349.38 193.62 290.83 40°08'57.263"N 109°39'30.465"W 0.00 2913.00† 17.089 56.347 2862.48 378.77 209.90 315.29 40°08'57.424"N 109°39'30.150"W 0.00 3013.00† 17.089 56.347 2958.07 408.15 226.18 339.75 40°08'57.585"N 109°39'29.835"W 0.00 3113.00† 17.089 56.347 3053.65 437.54 242.47 364.21 40°08'57.746"N 109°39'29.520"W 0.00 3213.00† 17.089 56.347 3149.24 466.92 258.75 388.67 40°08'57.907"N 109°39'29.205"W 0.00 3313.00† 17.089 56.347 3244.82 496.31 275.04 413.13 40°08'58.068"N 109°39'28.890"W 0.00 3413.00† 17.089 56.347 3340.41 525.69 291.32 437.59 40°08'58.229"N 109°39'28.575"W 0.00 3513.00† 17.089 56.347 3436.00 555.08 307.60 462.05 40°08'58.390"N 109°39'28.260"W 0.00 3613.00† 17.089 56.347 3531.58 584.46 323.89 486.51 40°08'58.551"N 109°39'27.945"W 0.00 3713.00† 17.089 56.347 3627.17 613.85 340.17 510.97 40°08'58.712"N 109°39'27.630"W 0.00 3813.00† 17.089 56.347 3722.75 643.23 356.46 535.43 40°08'58.872"N 109°39'27.315"W 0.00 3913.00† 17.089 56.347 3818.34 672.62 372.74 559.89 40°08'59.033"N 109°39'27.000"W 0.00

Page 2 of 5

4/14/2014



Page 2 of 5PETKOLEEN




WELLPATH D ATA (80 stations) † = interpola edlextrapolate I stationMD Tuclination Azimuth TVD VertSect North East Latitude Longitude DTS Comments[ft) [°1 í°j [ft1 fft1 fft1 fft1 [°/100ft1

0.001 0.000 56.347 0.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.0013.00 0.000 56.347 13.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

113.001 0.000 56.347 113.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00120.001 0.000 56.347 120.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 Base Gravel

213.001 0.000 56.347 213.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00313.001 0.000 56.347 313.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00413.001 0.000 56.347 413.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00513.001 0.000 56.347 513.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00613.001 0.00( 56.347 613.00 0.00 0.00 000 40°08'55.350"N 109°39'34.210"W (713.001 0.00( 56.347 713.00 0.00 0.00 000 40°08'55.350"N 109°39'34.210"W (813.001 0.00( 56.347 813.00 0.00 0.00 000 40°08'55.350"N 109°39'34.210"W (913.001 0.00( 56.347 913.00 0.00 0.00 000 40°08'55.350"N 109°39'34.210"W (

1013.001 0.000 56.347 1013.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001113.001 0.000 56.347 1113.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001200.00 0.000 56.347 1200.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001213.001 0.26( 56.347 1213.00 0.03 0.02 0.02 40°08'55.350"N 109°39'34.210"W 2.001313.001 2.26( 56.347 1312.97 2.23 1.23 1.85 40°08'55.362"N 109°39'34.186"W 2.001413.001 4.26( 56.347 1412.80 7.91 4.39 6.59 40°08'55.393"N 109°39'34.125"W 2.001513.001 6.26( 56.347 1512.38 17.08 9.47 14.22 40°08'55.444"N 109°39'34.027"W 2.001601.311 8.02( 56.347 1600.00 28.06 15.55 23.36 40°08'55.504"N 109°39'33.909"W 2.00 BMSW

1613.001 8.26( 56.347 1611.57 29.72 16.47 24.74 40°08'55.513"N 109°39'33.891"W 2.001713.001 10.26( 56.347 1710.26 45.81 25.39 38.13 40°08'55.601"N 109°39'33.719"W 2.001813.001 12.26( 56.347 1808.33 65.33 36.21 54.38 40°08'55.708"N 109°39'33.510"W 2.001913.001 14.26( 56.347 1905.66 88.27 48.92 73.48 40°08'55.833"N 109°39'33.264"W 2.002013.001 16.26( 56.347 2002.13 114.59 63.50 95.38 40°08'55.978"N 109°39'32.982"W 2.002054.43 17.085 56.347 2041.82 126.48 70.09 105.28 40°08'56.043"N 109°39'32.854"W 2.002113.001 17.085 56.347 2097.80 143.69 79.63 119.61 40°08'56.137"N 109°39'32.670"W 0.002213.001 17.085 56.347 2193.39 173.07 95.91 144.07 40°08'56.298"N 109°39'32.355"W 0.002313.001 17.085 56.347 2288.97 202.46 112.19 168.53 40°08'56.459"N 109°39'32.040"W 0.002413.001 17.085 56.347 2384.56 231.84 128.48 192.99 40°08'56.620"N 109°39'31.725"W 0.002513.001 17.086 56.347 2480.14 261.23 144.76 217.45 40°08'56.781"N 109°39'31.410"W 0.002613.001 17.086 56.347 2575.73 290.61 161.05 241.91 40°08'56.941"N 109°39'31.095"W 0.002713.001 17.086 56.347 2671.31 320.00 177.33 266.37 40°08'57.102"N 109°39'30.780"W 0.002813.001 17.085 56.347 2766.90 349.38 193.62 290.83 40°08'57.263"N 109°39'30.465"W 0.002913.001 17.085 56.347 2862.48 378.77 209.90 315.29 40°08'57.424"N 109°39'30.150"W 0.003013.001 17.085 56.347 2958.07 408.15 226.18 339.75 40°08'57.585"N 109°39'29.835"W 0.003113.001 17.085 56.347 3053.65 437.54 242.47 364.21 40°08'57.746"N 109°39'29.520"W 0.003213.001 17.085 56.347 3149.24 466.92 258.75 388.67 40°08'57.907"N 109°39'29.205"W (3313.001 17.085 56.347 3244.82 496.31 275.04 413.13 40°08'58.068"N 109°39'28.890"W (3413.001 17.085 56.347 3340.41 525.69 291.32 437.59 40°08'58.229"N 109°39'28.575"W (3513.001 17.085 56.347 3436.00 555.08 307.60 462.05 40°08'58.390"N 109°39'28.260"W 0.003613.001 17.085 56.347 3531.58 584.46 323.89 486.51 40°08'58.551"N 109°39'27.945"W 0.003713.001 17.085 56.347 3627.17 613.85 340.17 510.97 40°08'58.712"N 109°39'27.630"W 0.003813.001 17.085 56.347 3722.75 643.23 356.46 535.43 40°08'58.872"N 109°39'27.315"W 0.003913.001 17.086 56.347 3818.34 672.62 372.74 559.89 40°08'59.033"N 109°39'27.000"W 0.00



Page2of5PETROLEEP1

REFERENCE MILLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)




WELLPATH D tTA (80 stations) † = interpola ed/extrapolate I stationMD Inclination Azimuth TVD VertSect North East Latitude Longitude DLS Commentsfft1 [°1 f°1 fft1 fal fal fal f°/100R1

0.001 0.000 56.347 0.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.0013.00 0.000 56.347 13.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

113.001 0.000 56.347 113.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00120.001 0.000 56.347 120.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 Base Gravel

213.001 0.000 56.347 213.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00313.001 0.000 56.347 313.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00413.001 0.000 56.347 413.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00513.001 0.000 56.347 513.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00613.001 0.000 56.347 613.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00713.001 0.000 56.347 713.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00813.001 0.000 56.347 813.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00913.001 0.000 56.347 913.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

1013.001 0.000 56.347 1013.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001113.001 0.000 56.347 1113.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001200.00 0.000 56.347 1200.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001213.001 0.260 56.347 1213.00 0.03 0.02 0.02 40°08'55.350"N 109°39'34.210"W 2.001313.001 2.260 56.347 1312.97 2.23 1.23 1.85 40°08'55.362"N 109°39'34.186"W 2.001413.001 4.260 56.347 1412.80 7.91 4.39 6.59 40°08'55.393"N 109°39'34.125"W 2.001513.001 6.260 56.347 1512.38 17.08 9.47 14.22 40°08'55.444"N 109°39'34.027"W 2.001601.311 8.02( 56.347 1600.00 28.06 15.55 23.36 40°08'55.504"N 109°39'33.909"W 2.00 BMSW

1613.001 8.260 56.347 1611.57 29.72 16.47 24.74 40°08'55.513"N 109°39'33.891"W 2.001713.001 10.260 56.347 1710.26 45.81 25.39 38.13 40°08'55.601"N 109°39'33.719"W 2.001813.001 12.260 56.347 1808.33 65.33 36.21 54.38 40°08'55.708"N 109°39'33.510"W 2.001913.001 14.260 56.347 1905.66 88.27 48.92 73.48 40°08'55.833"N 109°39'33.264"W 2.002013.001 16.260 56.347 2002.13 114.59 63.50 95.38 40°08'55.978"N 109°39'32.982"W 2.002054.43 17.085 56.347 2041.82 126.48 70.09 105.28 40°08'56.043"N 109°39'32.854"W 2.002113.001 17.085 56.347 2097.80 143.69 79.63 119.61 40°08'56.137"N 109°39'32.670"W 0.002213.001 17.085 56.347 2193.39 173.07 95.91 144.07 40°08'56.298"N 109°39'32.355"W 0.002313.001 17.085 56.347 2288.97 202.46 112.19 168.53 40°08'56.459"N 109°39'32.040"W 0.002413.001 17.085 56.347 2384.56 231.84 128.48 192.99 40°08'56.620"N 109°39'31.725"W 0.002513.001 17.085 56.347 2480.14 261.23 144.76 217.45 40°08'56.781"N 109°39'31.410"W 0.002613.001 17.085 56.347 2575.73 290.61 161.05 241.91 40°08'56.941"N 109°39'31.095"W 0.002713.001 17.085 56.347 2671.31 320.00 177.33 266.37 40°08'57.102"N 109°39'30.780"W 0.002813.001 17.085 56.347 2766.90 349.38 193.62 290.83 40°08'57.263"N 109°39'30.465"W 0.002913.001 17.085 56.347 2862.48 378.77 209.90 315.29 40°08'57.424"N 109°39'30.150"W 0.003013.001 17.085 56.347 2958.07 408.15 226.18 339.75 40°08'57.585"N 109°39'29.835"W 0.003113.001 17.085 56.347 3053.65 437.54 242.47 364.21 40°08'57.746"N 109°39'29.520"W 0.003213.001 17.085 56.347 3149.24 466.92 258.75 388.67 40°08'57.907"N 109°39'29.205"W 0.003313.001 17.085 56.347 3244.82 496.31 275.04 413.13 40°08'58.068"N 109°39'28.890"W 0.003413.001 17.085 56.347 3340.41 525.69 291.32 437.59 40°08'58.229"N 109°39'28.575"W 0.003513.001 17.085 56.347 3436.00 555.08 307.60 462.05 40°08'58.390"N 109°39'28.260"W 0.003613.001 17.085 56.347 3531.58 584.46 323.89 486.51 40°08'58.551"N 109°39'27.945"W 0.003713.001 17.085 56.347 3627.17 613.85 340.17 510.97 40°08'58.712"N 109°39'27.630"W 0.003813.001 17.085 56.347 3722.75 643.23 356.46 535.43 40°08'58.872"N 109°39'27.315"W 0.003913.001 17.085 56.347 3818.34 672.62 372.74 559.89 40°08'59.033"N 109°39'27.000"W 0.00



Page2of5PETROLEEP1






0.001 0.000 56.347 0.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.0013.00 0.000 56.347 13.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

113.001 0.000 56.347 113.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00120.001 0.000 56.347 120.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 Base Gravel






Page2of5PETROLEEP1






0.001 0.000 56.347 0.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.0013.00 0.000 56.347 13.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

113.001 0.000 56.347 113.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00120.001 0.000 56.347 120.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00 Base Gravel







Page 3 of 5

WELLPATH DATA (80 stations) † = interpolated/extrapolated stationMD[ft]

Inclination[°]

Azimuth[°]

TVD[ft]

Vert Sect[ft]

North[ft]

East[ft]

Latitude Longitude DLS[°/100ft]

Comments

3971.43 17.089 56.347 3874.18 689.79 382.26 574.18 40°08'59.127"N 109°39'26.816"W 0.00 4013.00† 16.257 56.347 3914.01 701.71 388.87 584.11 40°08'59.193"N 109°39'26.688"W 2.00 4113.00† 14.257 56.347 4010.48 728.03 403.45 606.01 40°08'59.337"N 109°39'26.406"W 2.00 4213.00† 12.257 56.347 4107.81 750.96 416.15 625.10 40°08'59.462"N 109°39'26.160"W 2.00 4231.60† 11.885 56.347 4126.00 754.85 418.31 628.34 40°08'59.484"N 109°39'26.118"W 2.00 Mahogany4313.00† 10.257 56.347 4205.88 770.48 426.97 641.35 40°08'59.569"N 109°39'25.951"W 2.00 4413.00† 8.257 56.347 4304.57 786.56 435.89 654.74 40°08'59.657"N 109°39'25.778"W 2.00 4513.00† 6.257 56.347 4403.77 799.20 442.89 665.26 40°08'59.727"N 109°39'25.643"W 2.00 4613.00† 4.257 56.347 4503.34 808.36 447.96 672.88 40°08'59.777"N 109°39'25.545"W 2.00 4713.00† 2.257 56.347 4603.17 814.04 451.11 677.61 40°08'59.808"N 109°39'25.484"W 2.00 4813.00† 0.257 56.347 4703.14 816.23 452.33 679.44 40°08'59.820"N 109°39'25.460"W 2.00 4825.86 0.000 56.347 4716.001 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 2.00 Garden Gulch4913.00† 0.000 56.347 4803.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 4995.86† 0.000 56.347 4886.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 Lower Green River5013.00† 0.000 56.347 4903.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5113.00† 0.000 56.347 5003.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5213.00† 0.000 56.347 5103.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5313.00† 0.000 56.347 5203.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5413.00† 0.000 56.347 5303.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5513.00† 0.000 56.347 5403.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5613.00† 0.000 56.347 5503.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5713.00† 0.000 56.347 5603.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5813.00† 0.000 56.347 5703.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 5913.00† 0.000 56.347 5803.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6013.00† 0.000 56.347 5903.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6113.00† 0.000 56.347 6003.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6213.00† 0.000 56.347 6103.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6313.00† 0.000 56.347 6203.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6413.00† 0.000 56.347 6303.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6513.00† 0.000 56.347 6403.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6613.00† 0.000 56.347 6503.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6700.86† 0.000 56.347 6591.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 Wasatch6713.00† 0.000 56.347 6603.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6813.00† 0.000 56.347 6703.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 6900.86 0.000 56.347 6791.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 TD

Page 3 of 5

4/14/2014



Page 3 of 5PETKOLEEN




WELLPATH I ATA (80 station::) † = interp ilatedlextrapolited stationMD Inclination Azimuth TVT) VertSect North East Latitude Longitude DLS Comments[ft1 [°1 [°j fft1 [ft] fft1 [ft1 Í°ilA0ft]

3971.43 17.089 56.349 3874.18 689.79 382.26 574.18 40°08'59.127"N 109°39'26.816"W 0.004013.001 16.25 56.34; 3914.01 701.71 388.87 584.11 40°08'59.193"N 109°39'26.688"W 2.004113.001 14.25 56.34; 4010.48 728.03 403.45 606.01 40°08'59.337"N 109°39'26.406"W 2.004213.001 12.25 56.34; 4107.81 750.96 416.15 625.10 40°08'59.462"N 109°39'26.160"W 2.004231.601 11.88 56.34; 4126.00 754.85 418.31 628.34 40°08'59.484"N 109°39'26.ll8"W 2.00 Mahoaany

4313.001 10.25 56.34; 4205.88 770.48 426.97 641.35 40°08'59.569"N 109°39'25.951"W 2.004413.001 8.25 56.34; 4304.57 786.56 435.89 654.74 40°08'59.657"N 109°39'25.778"W 2.004513.001 6.25 56.34; 4403.77 799.20 442.89 665.26 40°08'59.727"N 109°39'25.643"W 2.004613.001 4.25 56.349 4503.34 808.36 447.96 672.88 40°08'59.777"N 109°39'25.545"W 2.004713.001 2.25 56.349 4603.17 814.04 451.11 677.61 40°08'59.808"N 109°39'25.484"W 2.004813.001 0.25 56.349 4703.14 816.23 452.33 679.44 40°08'59.820"N 109°39'25.460"W 2.004825.86 0.00( 56.349 4716.00' 816.26 452.34 679.4( 40°08'59.820"N 109°39'25.460"W 2.00 GardenGulch

4913.001 0.00( 56.349 4803.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.004995.861 0.00( 56.349 4886.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 LowerGreenRiver

5013.001 0.00( 56.349 4903.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005113.001 0.000 56.349 5003.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005213.001 0.000 56.349 5103.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005313.001 0.000 56.349 5203.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005413.001 0.000 56.349 5303.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005513.001 0.000 56.34; 5403.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005613.001 0.000 56.34; 5503.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005713.001 0.000 56.34; 5603.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005813.001 0.000 56.34; 5703.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005913.001 0.000 56.34; 5803.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006013.001 0.000 56.34; 5903.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006113.001 0.000 56.34; 6003.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006213.001 0.00( 56.34; 6103.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006313.001 0.00( 56.34; 6203.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006413.001 0.00( 56.34; 6303.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006513.001 0.000 56.34; 6403.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006613.001 0.000 56.34; 6503.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006700.861 0.000 56.34; 6591.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 wasatch6713.001 0.00( _ 56.34; 6603.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006813.001 0.000 56.34; 6703.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006900.86 0.000 56.34; 6791.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 TD

Sundry Number: 50132 API Well Number: 43047539530000 Page 3 of 5


Page3of5PETROLELE





WILLPATH l ATA (80 station::) † = interp slated/extrapolsted stationMD Inclination Azimuth TVD VertSect North East Latitude Longitude DLS Commentsfft1 f°1 f°1 fft1 fft1 fft1 fft1 f°/100ft1

3971.43 17.08f 56.349 3874.18 689.79 382.26 574.18 40°08'59.127"N 109°39'26.816"W 0.004013.001 16.25 56.349 3914.01 701.71 388.87 584.11 40°08'59.193"N 109°39'26.688"W 2.004113.001 14.25 56.349 4010.48 728.03 403.45 606.01 40°08'59.337"N 109°39'26.406"W 2.004213.001 12.25 56.349 4107.81 750.96 416.15 625.10 40°08'59.462"N 109°39'26.160"W 2.004231.601 11.88 56.349 4126.00 754.85 418.31 628.34 40°08'59.484"N 109°39'26.118"W 2.00 Mahogany

4313.001 10.25 56.349 4205.88 770.48 426.97 641.35 40°08'59.569"N 109°39'25.951"W 2.004413.001 8.25 56.349 4304.57 786.56 435.89 654.74 40°08'59.657"N 109°39'25.778"W 2.004513.001 6.25 56.349 4403.77 799.20 442.89 665.26 40°08'59.727"N 109°39'25.643"W 2.004613.001 4.25 56.349 4503.34 808.36 447.96 672.88 40°08'59.777"N 109°39'25.545"W 2.004713.001 2.25 56.349 4603.17 814.04 451.11 677.61 40°08'59.808"N 109°39'25.484"W 2.004813.001 0.25 56.349 4703.14 816.23 452.33 679.44 40°08'59.820"N 109°39'25.460"W 2.004825.86 0.000 56.349 4716.001 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 2.00 GardenGulch

4913.001 0.000 56.349 4803.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.004995.861 0.000 56.349 4886.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 LowerGreenRiver

5013.001 0.000 56.349 4903.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005113.001 0.000 56.349 5003.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005213.001 0.000 56.349 5103.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005313.001 0.000 56.349 5203.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005413.001 0.000 56.349 5303.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005513.001 0.000 56.349 5403.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005613.001 0.000 56.34; 5503.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005713.001 0.000 56.34; 5603.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005813.001 0.000 56.34; 5703.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.005913.001 0.000 56.34; 5803.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006013.001 0.000 56.34; 5903.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006113.001 0.000 56.34; 6003.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006213.001 0.000 56.34; 6103.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006313.001 0.000 56.34; 6203.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006413.001 0.000 56.34; 6303.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006513.001 0.000 56.34; 6403.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006613.001 0.000 56.34; 6503.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006700.861 0.000 56.34; 6591.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 Wasatch

6713.001 0.000 56.34; 6603.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006813.001 0.000 56.34; 6703.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006900.86 0.000 56.34; 6791.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 TD



Page3of5PETROLELE










6713.001 0.000 56.34; 6603.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006813.001 0.000 56.34; 6703.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006900.86 0.000 56.34; 6791.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 TD



Page3of5PETROLELE










6713.001 0.000 56.34; 6603.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006813.001 0.000 56.34; 6703.14 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.006900.86 0.000 56.34; 6791.00 816.26 452.34 679.46 40°08'59.820"N 109°39'25.460"W 0.00 TD




Page 4 of 5

HOLE & CASING SECTIONS - Ref Wellbore: Three Rivers Fed 3-23-820 PWB Ref Wellpath: Three Rivers Fed 3-23-820 PWPString/Diameter Start MD

[ft]End MD

[ft]Interval

[ft]Start TVD

[ft]End TVD

[ft]Start N/S

[ft]Start E/W

[ft]End N/S

[ft]End E/W

[ft]16in Conductor 13.00 120.00 107.00 13.00 120.00 0.00 0.00 0.00 0.0012.25in Open Hole 120.00 1000.00 880.00 120.00 1000.00 0.00 0.00 0.00 0.008.625in Casing Surface 13.00 1000.00 987.00 13.00 1000.00 0.00 0.00 0.00 0.007.875in Open Hole 1000.00 6900.86 5900.86 1000.00 6791.00 0.00 0.00 452.34 679.465.5in Casing Production 13.00 6900.86 6887.86 13.00 6791.00 0.00 0.00 452.34 679.46

TARGETSName MD

[ft] TVD[ft]

North[ft]

East[ft]

Grid East[US ft]

Grid North[US ft]

Latitude Longitude Shape

1) Three Rivers Fed 3-23-820 Target On Plat 1980' FSL & 1980' FWL

4500.00 452.34 679.46 2155524.89 7228650.96 40°08'59.820"N 109°39'25.460"W point

Page 4 of 5

4/14/2014



Page 4 of 5PETKOLELTI




HOLE & CASING SECTIONS - Ref Wellbore: Three Rivers Fed 3-23-820 PWB Ref Wellpath: Three Rivers Fed 3-23-820 PWP

String/Diameter Start MD End MD Interval Start TVD End TVD Start N/S Start E/W End N/S End E/WÍTil [ftl ÍTil [ftl [ftl [ftl [ftl ÍTil ÍTil

16in Conductor 13.00 120.00 107.00 13.0C 120.00 0.00 0.00 0.00 0.0012.25in Open Hole 120.00 1000.00 880.00 120.00 1000.00 0.00 0.00 0.00 0.00

8.625in Casing Surface 13.00 1000.00 987.00 13.00 1000.00 0.00 0.00 0.00 0.007.875in Open Ilole 1000.00 6900.86 5900.86 1000.0C 6791.00 0.00 0.00 452.34 679.46

5.Sin Casing Production 13.00 6900.86 6887.86 13.0C 6791.00 0.00 0.00 452.34 679.46

TARGETSName MD TVD North East Grid East Grid North Latitudc Longitudc Shape

[ftl Íftl Ïftl Ïftl [US ftl [US ft

1) Three Rivers Fed 3-23-820 Target On Plat 1980' 4500.00 452.34 679.46 2155524.89 7228650.96 40°08'59.820"N 109°39'25.460"W pointFSL & 1980' FWL



Page4of5PETROLELT1





HOLE & CASING SECTIONS -RefWellbore: Three Rivers Fed 3-23-820 PWB RefWelipath: Three Rivers Fed 3-23-820 PWPString/Diameter Start MD End MD Interval Start TVD End TVD StartN/S StartE/W End N/S End E/W

[ft [ft [ft [ft [ft [ft [ft [ft [ft16in Conductor 13.00 120.00 107.00 13.00 120.00 0.00 0.00 0.0C 0.00

12.25inOpenHole 120.00 1000.00 880.00 120.00 1000.00 0.00 0.00 0.0C 0.008.625in Casing Surface 13.00 1000.00 987.00 13.00 1000.00 0.00 0.00 0.0C 0.00

7.875inOpenHole 1000.00 6900.86 5900.86 1000.00 6791.00 0.00 0.00 452.34 679.46

5.5inCasingProduction 13.00 6900.86 6887.86 13.00 6791.00 0.00 0.00 452.34 679.46

TARGETSName MD TVD North East GridEast GridNorth Latitude Longitude Shape

[ft] [ft] [ft] [ft] [US It [US It]




Page4of5PETROLELT1








7.875inOpenHole 1000.00 6900.86 5900.86 1000.00 6791.00 0.00 0.00 452.34 679.46







Page4of5PETROLELT1








7.875inOpenHole 1000.00 6900.86 5900.86 1000.00 6791.00 0.00 0.00 452.34 679.46








Page 5 of 5

WELLPATH COMMENTSMD[ft]

Inclination[°]

Azimuth[°]

TVD[ft]

Comment

120.00 0.000 56.347 120.00 Base Gravel1601.31 8.026 56.347 1600.00 BMSW4231.60 11.885 56.347 4126.00 Mahogany4825.86 0.000 56.347 4716.00 Garden Gulch4995.86 0.000 56.347 4886.00 Lower Green River6700.86 0.000 56.347 6591.00 Wasatch6900.86 0.000 56.347 6791.00 TD

Page 5 of 5

4/14/2014



Page 5 of 5PETKOLELT1




WELLPATH COMMENTSMD Inclination Azimuth Til) CommentÍTil Í°l Í°l ÍTil

120.00 0.000 56.347 120.00 Base Gravel1601.31 8.026 56.347 1600.00 BMSW4231.60 11.885 56.347 4126.00 Mahogany

4825.86 0.000 56.347 4716.00 Garden Gulch4995.86 0.000 56.347 4886.00 Lower Green River6700.86 0.000 56.347 6591.00 Wasatch6900.86 0.000 56.347 6791.00 TD



Page5of5PETROLEEP1





WELLPATH COMMENTSMD Inclination Azimuth TVD Comment[ftl 1°l 1°l [ftl




Page5of5PETROLEEP1









Page5of5PETROLEEP1








May 15, 2014

Mr. Dustin Doucet Utah Division of Oil, Gas & Mining 1594 West North Temple Salt Lake City, Utah 84116

RE: Request for Exception to Spacing Three Rivers Fed 3-23-820 Surface Location: 1536’ FSL & 1296’ FWL, NWSW, Sec. 3, T8S, R20E Target Location: 1980’ FSL & 1980’ FWL, NESW, Sec. 3, T8S, R20E SLB&M, Uintah County, Utah Dear Mr. Doucet: Ultra Resources, Inc. (“Ultra”) respectfully submits this request for exception to spacing (Docket No. 2013-030 / Cause No. 270-02) based on geology since the well is located less than 100 feet to the drilling unit boundary. The adjacent drilling unit boundary is covered by the same lease and has the identical production interest owners in it. Ultra owns 100% of the leasehold within 460 feet of the surface and target location as well as all points along the intended well bore path. Thank you very much for your timely consideration of this application. Please feel free to contact me at 303-645-9810 should you have any questions or need additional information. Sincerely, Debbie Ghani Sr. Permitting Specialist /dg


Ultra Resources, Inc.

PETROLEUM

May 15, 2014

Mr. Dustin DoucetUtah Division of Oil, Gas & Mining1594 West North TempleSalt Lake City, Utah 84116

RE: Request for Exception to SpacingThree Rivers Fed 3-23-820

Surface Location: 1536' FSL & 1296' FWL, NWSW, Sec. 3, T85, R20ETarget Location: 1980' FSL & 1980' FWL, NESW, Sec. 3, T8S, R20ESLB&M, Uintah County, Utah

Dear Mr. Doucet:

Ultra Resources, Inc. ("Ultra") respectfully submits this request for exception to spacing (DocketNo. 2013-030 / Cause No. 270-02) based on geology since the well is located less than 100 feet tothe drilling unit boundary.

The adjacent drilling unit boundary is covered by the same lease and has the identical productioninterest owners in it.

Ultra owns 100% of the leasehold within 460 feet of the surface and target location as well as allpoints along the intended well bore path.

Thank you very much for your timely consideration of this application. Please feel free to contactme at 303-645-9810 should you have any questions or need additional information.

Sincerely,

Debbie GhaniSr. Permitting Specialist

/dg

304 Inverness Way South, Suite 295, Englewood, CO 80112Telephone 303-708-9740 Facsimile 303-708-9748

RECEIVED: May. 15,



PETROLEUM

May 15, 2014



Surface Location: 1536' FSL & 1296' FWL, NWSW, Sec. 3, T8S, R20ETarget Location: 1980' FSL & 1980' FWL, NESW, Sec. 3, T8S, R20ESLB&M, Uintah County, Utah

Dear Mr. Doucet:





Sincerely,


/dg


RECEIVED: May. 15,



PETROLEUM

May 15, 2014




Dear Mr. Doucet:





Sincerely,


/dg


RECEIVED: May. 15,



PETROLEUM

May 15, 2014




Dear Mr. Doucet:





Sincerely,


/dg


RECEIVED: May. 15,

RECEIVED: Jul. 16, 2014



FORM 9









9. API NUMBER: 43047539530000




COUNTY: UINTAH

STATE: UTAH

11.




8 /16 /2014















Ultra respectfully requests a one year extension of the state permit forthe referenced well. This is the first extension that has been requested.



SIGNATURE N/A

DATE 7 /16 /2014

July 17, 2014


FORM 9STATE OF UTAH








4. LOCATION OF WELL COUNTY:FOOTAGESAT SURFACE: UINTAH








SUBSEQUENTREPORT DEEPEN FRACTURETREAT NEWCONSTRUCTIONDate of Work Completion:








Ultra respectfully requests a one year extension of the state permit for Approved by thethe referenced well. This is the first extension that has been requested. Ukd1; ib7yiRiikh‡of

OFI, Gas and Mining

Date:



RECEIVED: Jul. 16,


FORM 9STATE OF UTAH

























OFI, Gas and Mining

Date:



RECEIVED: Jul. 16,


FORM 9STATE OF UTAH

























OFI, Gas and Mining

Date:



RECEIVED: Jul. 16,


FORM 9STATE OF UTAH

























OFI, Gas and Mining

Date:



RECEIVED: Jul. 16,

RECEIVED: Jul. 16, 2014

The Utah Division of Oil, Gas, and Mining

- State of Utah- Department of Natural Resources

Electronic Permitting System - Sundry Notices

Request for Permit Extension Validation Well Number 43047539530000

API: 43047539530000Well Name: Three Rivers Federal 3-23-820

Location: 1536 FSL 1296 FWL QTR NWSW SEC 03 TWNP 080S RNG 200E MER SCompany Permit Issued to: ULTRA RESOURCES INC

Date Original Permit Issued: 8 /21 /2013

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

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

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

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

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

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

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

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

Signature: Jenna Anderson Date: 7 /16 /2014

Title: Permitting Specialist Representing: ULTRA RESOURCES INC


UTAH

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

- State of Utah- Department of Natural ResourcesElectronic Permitting System - Sundry Notices

OTI. EMI Pr N1NTrie



Location: 1536 FSL 1296 FWL QTR NWSW SEC 03 TWNP 080S RNG 200E MER SCompany Permit Issued to: ULTRARESOURCES INC

Date Original Permit Issued: 8/21/2013


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

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

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

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

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

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

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

Signature: Jenna Anderson Date: 7/16/2014Title: Permitting Specialist Representing: ULTRARESOURCES INC

RECEIVED: Jul. 16,


UTAH



OTI. EMI Pr N1NTrie














RECEIVED: Jul. 16,


UTAH



OTI. EMI Pr N1NTrie














RECEIVED: Jul. 16,


UTAH



OTI. EMI Pr N1NTrie














RECEIVED: Jul. 16,

RECEIVED: Aug. 07, 2014



FORM 9









9. API NUMBER: 43047539530000




COUNTY: UINTAH

STATE: UTAH

11.






8 /7 /2014













Ultra Resources will be moving ProPetro to spud the Three Rivers Fed3-23-820 (API#43-047-53953) on 8/7/2014.



SIGNATURE N/A

DATE 8 /7 /2014

August 07, 2014


FORM 9STATE OF UTAH













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 / 7 / 2 0 14 REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


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



Ultra Resources will be moving ProPetro to spud the Three Rivers Fed Accepted by the3-23-820 (APl#43-047-53953) on 8/7/2014. Utah Division ofOil, Gas and Mining

FOR RECORD ONLYAugust 07, 2014



RECEIVED: Aug. 07,


FORM 9STATE OF UTAH




























RECEIVED: Aug. 07,


FORM 9STATE OF UTAH




























RECEIVED: Aug. 07,


FORM 9STATE OF UTAH




























RECEIVED: Aug. 07,

RECEIVED: Sep. 08, 2014



FORM 9









9. API NUMBER: 43047539530000




COUNTY: UINTAH

STATE: UTAH

11.







9 /8 /2014












Monthly status report of drilling and completion attached.



SIGNATURE N/A

DATE 9 /8 /2014

September 09, 2014


FORM 9STATE OF UTAH






















9/8/2014WILDCAT WELL DETERMINATION OTHER OTHER:


Monthly status report of drilling and completion attached. Accepted by theutah Division of

Oil, Gas and Mining

FOR RECORD ONLYSeptember 09, 2014



RECEIVED: Sep. 08,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Sep. 08,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Sep. 08,


FORM 9STATE OF UTAH

























Oil, Gas and Mining




RECEIVED: Sep. 08,


9/8/2014 1:30 PM Page 1THREE RIVERS FED 3-23-820

ULTRA RESOURCES, INC.DAILY DRILLING REPORT DATE: 08/11/2014

WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR OtherTD AT REPORT 1,035' FOOTAGE 955' PRATE CUM. DRLG. HRS DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS Drilling at 1,035' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,800 SSE SSED

AFE Days vs Depth: AFE Cost Vs Depth:DWOP Days vs Depth: # LL/BP Received Today:

RECENT CASINGS RUN: Date Set Size Grade Weight Depth FIT Depth FIT ppgConductor 08/07/2014 16 ARJ-55 45 100

RECENT BITS:BIT SIZE MANUF TYPE SERIAL NO. JETS TFA DEPTH IN DEPTH OUT I-O-D-L-B-G-O-R

BIT OPERATIONS:BIT WOB RPM GPM PRESS HHP HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP

RECENT MUD MOTORS:# SIZE MANUF TYPE SERIAL NO. LOBES DEPTH IN DEPTH OUT DATE IN DATE OUT

MUD MOTOR OPERATIONS:# WOB REV/GAL HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP

SURVEYSDate TMD Incl Azimuth TVD VS NS EW DLS Tool Type

SURFACE PUMP/BHA INFORMATIONPump 1 Liner Stroke Len SPM PSI GPM SPR Slow PSIPump 2 Liner Stroke Len SPM PSI GPM SPR Slow PSI

Pump 32 Liner Stroke Len SPM PSI GPM SPR Slow PSIBHA Makeup Length Hours on BHA 0

Up Weight 0 Dn Weight 0 RT Weight 0 Torque 0 Hours on Motor

DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 10,0008100..320: Mud & Chemicals 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 4,0008100..510: Testing/Inspection/ 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 10,000 8100..535: Directional Drillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 17,272 17,272 35,0008100..605: Cementing Work 25,000 8100..610: P & A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 17,272 26,395 675,000



WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR OtherTD AT REPORT 1,035' FOOTAGE 955' PRATE CUM. DRLG. HRS DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS Drillingat 1,035' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,800 SSE SSED

AFE Days vs Depth: AFE Cost Vs Depth:DWOP Days vs Depth: # LLIBP Received Today:





MUD MOTOR OPERATIONS:# WOB REVIGAL HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP


SURFACE PUMPIBHA INFORMATIONPump 1 Liner Stroke Len SPM PSI GPM SPR Slow PSIPump 2 Liner Stroke Len SPM PSI GPM SPR Slow PSI

Pump 32 Liner Stroke Len SPM PSI GPM SPR Slow PSIBHA Makeup Length Hours on BHA O


DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 10,0008100..320: Mud & Chemicals 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: MoblDemob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 4,0008100..510: Testing/Inspection/ 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 10,000 8100..535: Directional Drillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 17,272 17,272 35,0008100..605: Cementing Work 25,000 8100..610: P &A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 8100..950: Administrative OlH8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 17,272 26,395 675,000

9/8/2014 1:30 PM THREE RIVERS FED 3-23-820 Page 1

RECEIVED: Sep. 08,
















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RECEIVED: Sep. 08,
















RECEIVED: Sep. 08,




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR OtherTD AT REPORT 1,035' FOOTAGE 955' PRATE 112.4 CUM. DRLG. HRS 8.5 DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS Drilling at 1,035' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,800 SSE SSED

TIME BREAKDOWNDRILLING 8.50

DETAILSStart End Hrs21:30 06:00 08:30 DRILL F/ 80' T/ 1035'


FUEL AND WATER USAGEFluid Used Received Transferred On Hand Cum.UsedFuel 1,500.0 1,500.0 0.0 1,500.0GasFresh Well WaterNano WaterFrac WaterReserve Pit WaterBoiler HoursAir Heater HoursUrea 0.0Urea Sys 1 HrsUrea Sys 2 HrsUrea Sys 3 Hrs

RECENT CASINGS RUN: Date Set Size Grade Weight Depth FIT Depth FIT ppgSurface 08/12/2014 8 5/8 ARJ-55 24 1,015Conductor 08/07/2014 16 ARJ-55 45 100









DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 10,0008100..320: Mud & Chemicals 788 788 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 30,560 30,560 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 1,458 4,0008100..510: Testing/Inspection/ 1,246 1,246 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 10,000 8100..535: Directional Drillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 1,557 18,829 35,0008100..605: Cementing Work 35,197 35,197 25,000 8100..610: P & A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 2,750 2,750 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 7,491 7,491 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 95,485 121,880 675,000



WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR OtherTD AT REPORT 1,035' FOOTAGE 955' PRATE 112.4 CUM. DRLG. HRS 8.5 DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS Drillingat 1,035' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,800 SSE SSED


DETAILSStart End Hrs21:30 06:00 08:30 DRILL Fl80' TI 1035'












DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 10,0008100..320: Mud & Chemicals 788 788 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 30,560 30,560 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: MoblDemob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 1,458 4,0008100..510: Testing/Inspection/ 1,246 1,246 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 10,000 8100..535: Directional Drillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 1,557 18,829 35,0008100..605: Cementing Work 35,197 35,197 25,000 8100..610: P &A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 2,750 2,750 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 7,491 7,491 8100..950: Administrative OlH8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 95,485 121,880 675,000


RECEIVED: Sep. 08,



















RECEIVED: Sep. 08,



















RECEIVED: Sep. 08,



















RECEIVED: Sep. 08,




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR OtherTD AT REPORT (no data) FOOTAGE PRATE CUM. DRLG. HRS 8.5 DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS (nothing recorded) GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST NEXT CASING SIZE NEXT CASING DEPTH SSE SSED











DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 10,0008100..320: Mud & Chemicals 788 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 30,560 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 1,246 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 10,000 8100..535: Directional Drillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P & A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 2,750 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 7,491 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 121,880 675,000














DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 10,0008100..320: Mud & Chemicals 788 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 30,560 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: MoblDemob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 1,246 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 10,000 8100..535: Directional Drillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P &A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 2,750 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 7,491 8100..950: Administrative OlH8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 121,880 675,000


RECEIVED: Sep. 08,
















RECEIVED: Sep. 08,
















RECEIVED: Sep. 08,
















RECEIVED: Sep. 08,




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR OtherTD AT REPORT 1,027' FOOTAGE 0' PRATE CUM. DRLG. HRS 8.5 DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS Pressure Test BOP at 1,027' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,866 SSE 0 SSED 0

TIME BREAKDOWN

DETAILSStart End Hrs05:55 05:55 00:00 SAFETY MEETING DAYS: PINCH POINTS, WORKING AROUND THIRD PARTY TRUCKS, FORKLIFT SAFETY.

SAFETY MEETING NIGHTS: PINCH POINTS, WORKING AROUND THIRD PARTY TRUCKS.REGULATORY NOTICES: SENT NOTICE FOR BOP TEST ON THE 3-23-820.REGULATORY VISITS: NONE.INCIDENTS: NONE.SAFETY DRILLS: NONE.











DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 10,0008100..320: Mud & Chemicals 788 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 30,560 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 1,246 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 10,000 8100..535: Directional Drillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P & A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 2,750 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 7,491 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 121,880 675,000



WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR OtherTD AT REPORT 1,027' FOOTAGE O' PRATE CUM. DRLG. HRS 8.5 DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS Pressure Test BOP at 1,027' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,866 SSE O SSED 0

TIME BREAKDOWN















RECEIVED: Sep. 08,




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RECEIVED: Sep. 08,




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RECEIVED: Sep. 08,




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RECEIVED: Sep. 08,




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR Ensign 122TD AT REPORT 1,027' FOOTAGE 0' PRATE CUM. DRLG. HRS 8.5 DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS Pressure Test BOP at 1,027' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST 08/23/2014 NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,866 SSE 0 SSED 0

TIME BREAKDOWNNIPPLE UP B.O.P. 1.00 PRESSURE TEST B.O.P. 2.00 RIG REPAIRS 6.00

DETAILSStart End Hrs21:00 00:00 03:00 FIX PUMP MOTOR, CHANGE OUT DERRICK LIGHTS TO LED.00:00 01:00 01:00 NIPPLE UP ON THE THREE RIVERS FED 3-23-82001:00 04:00 03:00 REPLACE LIGHTS IN DERRICK, FIX PUMP IT WAS STILL NOT GETTING FULL BOOST OUT OF THE TURBO.04:00 06:00 02:00 PJSM, RIG UP TESTERS AND START TO TEST BOP.05:55 05:55 00:00 SAFETY MEETING DAYS: PINCH POINTS, WORKING AROUND THIRD PARTY TRUCKS, FORKLIFT SAFETY.



FUEL AND WATER USAGEFluid Used Received Transferred On Hand Cum.UsedFuel 40.0 3,100.0 3,060.0 1,540.0GasFresh Well WaterNano WaterFrac WaterReserve Pit WaterBoiler HoursAir Heater HoursUrea 0.0Urea Sys 1 HrsUrea Sys 2 HrsUrea Sys 3 Hrs







08/23/2014 2,039 12.3 51.50 2,034 76.2 37.04 67.26 1.9 MWD Survey Tool08/23/2014 1,948 10.6 51.70 1,945 58.1 25.82 53.11 2.6 MWD Survey Tool08/23/2014 1,858 8.6 59.30 1,856 43.2 17.25 40.82 2.7 MWD Survey Tool

SURFACE PUMP/BHA INFORMATIONPump 1 Liner 6.5 Stroke Len 9.0 SPM 126 PSI 2,100 GPM 440 SPR Slow PSIPump 2 Liner Stroke Len SPM PSI GPM SPR Slow PSI

Pump 32 Liner Stroke Len SPM PSI GPM SPR Slow PSIBHA Makeup STEARABLE Length Hours on BHA 0

Up Weight 17,000 Dn Weight RT Weight Torque Hours on Motor 0

BHA MAKEUP:# Component OD ID Length Weight (ft/lb) Serial Number Description1 DRILL BIT 7.875 0.00 0 SMITH MDSI516 5X 12 .552

TFA2 7/8 5.7STG .28 1.5 7.000 3.250 0.00 0 1.5 DEG FBH 7/8 5.7 STG. .28

REV3 NON MAG MONEL 6.500 3.250 0.00 EN122-1 4.5 XH P x B4 EM GAP SUB 6.400 3.250 0.00 650-0053 4.5 XH P x B5 NON MAG FLEX MONEL 6.500 2.813 0.00 EN0815-12 4.5 XH P x B6 NON MAG FLEX MONEL 6.500 2.813 0.00 EN0814-12 4.5 XH P x B7 DRILL COLLAR 6.500 2.250 0.00 RIG 4.5 XH P x B8 18JTS HWDP 4.500 2.313 0.00 RIG 4.5 XH P x B9 DRILLING JARS 6.550 2.625 0.00 09190D 4.5 XH P x B(SMITH)HE JARS

10 6JTS HWDP 4.500 2.313 0.00 RIG 4.5 XH P x B



WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR Ension 122TD AT REPORT 1,027' FOOTAGE O' PRATE CUM. DRLG. HRS 8.5 DRLG DAYS SINCE SPUD 0ANTICIPATED TD 6,866' PRESENT OPS Pressure Test BOP at 1,027' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: MUD ENGINEER:LAST BOP TEST 08/23/2014 NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,866 SSE O SSED 0













SURFACE PUMPIBHA INFORMATIONPump 1 Liner 6.5 Stroke Len 9.0 SPM 126 PSI 2_1)0 GPM 440 SPR Slow PSIPump 2 Liner Stroke Len SPM PSI GPM SPR Slow PSI

Pump 32 Liner Stroke Len SPM PSI GPM SPR Slow PSIBHA Makeup STEARABLE Length Hours on BHA O

Up Weight 1LOOO Dn Weight RT Weight Torque Hours on Motor 0

BHA MAKEUP:# Component OD ID Length Weight (ft/Ib) Serial Number Description1 DRILL BIT 7.875 0.00 0 SMITH MDSl516 5X 12 .552


REV3 NON MAG MONEL 6.500 3.250 0.00 EN122-1 4.5 XH PxB4 EM GAP SUB 6.400 3.250 0.00 650-0053 4.5 XH PxB5 NON MAG FLEX MONEL 6.500 2.813 0.00 ENO815-12 4.5 XH PxB6 NON MAG FLEX MONEL 6.500 2.813 0.00 ENO814-12 4.5 XH PxB7 DRILL COLLAR 6.500 2.250 0.00 RIG 4.5 XH PxB8 18JTS HWDP 4.500 2.313 0.00 RIG 4.5 XH PxB9 DRILLINGJARS 6.550 2.625 0.00 09190D 4.5 XH Px B(SMITH)HE JARS10 6JTS HWDP 4.500 2.313 0.00 RIG 4.5 XH PxB


RECEIVED: Sep. 08,























RECEIVED: Sep. 08,























RECEIVED: Sep. 08,























RECEIVED: Sep. 08,



DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 10,0008100..320: Mud & Chemicals 725 1,513 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 6,857 37,417 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 1,246 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 816 816 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 88 88 10,000 8100..535: Directional Drillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P & A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 1,875 4,625 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 919 8,410 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 11,280 133,160 675,000


DAJLYCOSTS DAJLY CUM AFE DAJLY CUM AFE8100..100:Permits& Fees 9,123 4,500 8100..105:Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200:Location Roads 14,439 30,000 8100..210:Reclarnation8100..220:Secondary Reclamati 8100..230:PitSolidifcation 5,0008100..300:VVaterVVell 8100..310:Ø/ater/VVaterDisposa 10,0008100..320: Mud & Chemicals 725 1,513 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 6,857 37,417 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: MoblDemob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510:Testing/Inspection/ 1,246 1,000 8100..520:Trucking & Hauling 23,0008100..530: Equipment Rental 816 816 17,000 8100..531: Down Hole Motor Ren 1,5008100..532:Solids Control Equi 88 88 10,000 8100..535:DirectionalDrillin 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P &A8100..700:Logging-Openhole 14,000 8100..705:Logging-Mud8100..800: Supervision/Consult 1,875 4,625 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 919 8,410 8100..950: Administrative OlH8100..999:Non Operated IDC 8200..510:Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605:Cernenting VVork 25,000 8210..600:Production Casing 50,0008210..620:VVellhead/Casing Hea 15,000 Total cost 11,280 133,160 675,000


RECEIVED: Sep. 08,




RECEIVED: Sep. 08,




RECEIVED: Sep. 08,




RECEIVED: Sep. 08,




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR Ensign 122TD AT REPORT 3,090' FOOTAGE 2,063' PRATE 187.5 CUM. DRLG. HRS 19.5 DRLG DAYS SINCE SPUD 1ANTICIPATED TD 6,866' PRESENT OPS Directional Drilling at 3,090' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: ANCHOR MUD ENGINEER: DAN KASTELLAST BOP TEST 08/24/2014 NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,866 SSE 0 SSED 0

TIME BREAKDOWNDIRECTIONAL DRILLING 11.00 PRESSURE TEST B.O.P. 4.00 RIG REPAIRS 5.00

RIG SERVICE 0.50 TRIPPING 3.00 WIRELINE 0.50

DETAILSStart End Hrs06:00 10:00 04:00 TEST BOP-(WALKER)PIPE RAMS, BLIND RAMS, CHOKE LINE & CHOKE VALVES, FOSV, INSIDE BOP, KILL

LINE AND VALVES, CHOKE MANIFOLD, HCR & MANUAL VALVE ALL @ 10 MIN 250 PSI LOW 10 MIN 3000 PSIHIGH - ANNULAR @ 10 MIN 1500 PSI HIGH 10 MIN 250 PSI LOW - CASING @ 30 MIN 1500 PSI -ACCUMULATOR FUNCTION TEST, RIG DOWN TESTER.

NOTE:THE RIG WAS STILL WORKING ON THE PUMPS WHILE WE TESTED BOP.

10:00 15:00 05:00 RIG REPAIR- WORK ON MUD PUMP # 2, REPAIR HPU, REPAIR PIPE ON GAS BUSTER.15:00 15:30 00:30 PICK UP DIR TOOLS.15:30 18:30 03:00 TRIP IN THE HOLE, TAG CEMENT AT 978', DRILL OUT CEMENT, FLOAT, CEMENT, SHOE.18:30 01:00 06:30 DIR DRILL F/ 1027' T/ 2315' 1288' @ 198.1 FT/HR - W/ 2-15K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -

7-10K TORQUE - 1600 PSI SPP.01:00 01:30 00:30 RIG SERVICE- LUBRICATE RIG (GREASE PIPEARMS, ROUGHNECK, WASH PIPE AND SHOCK SUB)

SERVICE AND INSPECT PUMP # 1 PUMP #2 AND HPU MOTORS.01:30 06:00 04:30 DIR DRILL F/ 2315' T/ 3090' 775' @ 172.2 FT/HR - W/ 6-15K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -

7-10K TORQUE - 1800 PSI SPP.ON BOTTOM ROP 282.605:55 05:55 00:00 SAFETY MEETING DAYS: PINCH POINTS, WORKING AROUND BOOM, FORKLIFT SAFETY, HOUSE

KEEPING.SAFETY MEETING NIGHTS: PINCH POINTS, WORKING AROUND BOOM, HOUSE KEEPING.REGULATORY NOTICES: NONE.REGULATORY VISITS: NONE.INCIDENTS: NONE.SAFETY DRILLS: BOP DRILL NIGHT CREW.


FUEL AND WATER USAGEFluid Used Received Transferred On Hand Cum.UsedFuel 820.0 2,240.0 2,360.0GasFresh Well WaterNano WaterFrac WaterReserve Pit WaterBoiler HoursAir Heater HoursUrea 0.0Urea Sys 1 HrsUrea Sys 2 HrsUrea Sys 3 Hrs


RECENT BITS:BIT SIZE MANUF TYPE SERIAL NO. JETS TFA DEPTH IN DEPTH OUT I-O-D-L-B-G-O-R1 7.875 SMITH MDSI516 JJ6088 12/12/12/12/12 0.552 1,027 -------

BIT OPERATIONS:BIT WOB RPM GPM PRESS HHP HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 65/123 440 1,600 2.93 11.00 2,063 187.55 11.00 2,063 187.55

RECENT MUD MOTORS:# SIZE MANUF TYPE SERIAL NO. LOBES DEPTH IN DEPTH OUT DATE IN DATE OUT1 6.500 DYNA-DRILL FIXED 650-106 7/8 5 1,027 08/23/2014

MUD MOTOR OPERATIONS:# WOB REV/GAL HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 24 0.28 11.00 2,063 187.55 11.00 2,063 187.55



MUD PROPERTIESType LSND Mud Wt 9.3 Alk. Sand % XS Lime lb/bbl

Temp. 100 Gels 10sec 2 Cl ppm 2,300 Solids % 4.0 Salt bblsVisc 36 Gels 10min 5 Ca ppm 20 LGS % 1.0 LCM ppb

PV 7 pH 9.1 pF 1.5 Oil % API WL cc 9.6YP 5 Filter Cake/32 2 Mf 4.5 Water % 96.0 HTHP WL cc

O/W Ratio ES WPSComments: SODIUM BICARBONATE 6,TRAILER RENTAL 1,ENGINEERING 1.

Flaring: Flare Foot-Minutes 0 Flared MCF 0.0 Cum. Flared MCF 0.0

SURFACE PUMP/BHA INFORMATIONPump 1 Liner 6.5 Stroke Len 9.0 SPM 126 PSI 2,100 GPM 440 SPR 43 Slow PSI 285Pump 2 Liner Stroke Len SPM PSI GPM SPR Slow PSI

Pump 32 Liner Stroke Len SPM PSI GPM SPR Slow PSIBHA Makeup STEARABLE Length 912.1 Hours on BHA 11

Up Weight 90,000 Dn Weight 65,000 RT Weight 78,000 Torque 8,000 Hours on Motor 11



WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANT JOHN FREITAS PHONE# 435-219-4933 CONTRACTOR Ension 122TD AT REPORT 3,090' FOOTAGE 2,063' PRATE 187.5 CUM. DRLG. HRS 19.5 DRLG DAYS SINCE SPUD 1ANTICIPATED TD 6,866' PRESENT OPS Directional Drillingat 3,090' GEOLOGIC SECT.DAILY MUD LOSS SURF: DH: CUM. MUD LOSS SURF: DH:MUD COMPANY: ANCHOR MUD ENGINEER: DAN KASTELLAST BOP TEST 08/24/2014 NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,866 SSE O SSED 0




LINEAND VALVES, CHOKE MANIFOLD, HCR & MANUALVALVEALL @ 10 MIN 250 PSI LOW 10 MIN 3000 PSIHIGH -ANNULAR @ 10 MIN 1500 PSI HIGH 10 MIN 250 PSI LOW- CASING @30 MIN 1500 PSI -

ACCUMULATOR FUNCTION TEST, RIG DOWN TESTER.


10:00 15:00 05:00 RIG REPAIR- WORK ON MUD PUMP #2, REPAIR HPU, REPAIR PIPE ON GAS BUSTER.15:00 15:30 00:30 PICK UP DIR TOOLS.15:30 18:30 03:00 TRIP IN THE HOLE, TAG CEMENT AT 978', DRILL OUT CEMENT, FLOAT, CEMENT, SHOE.18:30 01:00 06:30 DIR DRILL FI 1027' TI2315' 1288' @ 198.1 FTlHR - WI 2-15K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -


SERVICE AND INSPECT PUMP #1 PUMP #2 AND HPU MOTORS.01:30 06:00 04:30 DIR DRILL FI 2315' TI 3090' 775' @ 172.2 FTlHR - WI 6-15K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -







1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027


1 65/123 440 1,600 2.93 11.00 2,063 187.55 11.00 2,063 187.55


MUD MOTOR OPERATIONS:# WOB REVIGAL HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 24 0.28 11.00 2,063 187.55 11.00 2,063 187.55



MUD PROPERTIESType LSND Mud Wt 9.3 Alk. Sand % XS Lime Ib/bbl

Temp. 100 Gels 10sec 2 CI ppm 2,300 Solids % 4.0 Salt bblsVisc 36 Gels 10min 5 Ca ppm 20 LGS % 1.0 LCM ppb


OlW Ratio ES WPSComments: SODIUM BICARBONATE 6,TRAILER RENTAL 1,ENGINEERING 1.


SURFACE PUMPIBHA INFORMATIONPump 1 Liner 6.5 Stroke Len 9.0 SPM 126 PSI 2_S)0 GPM 440 SPR 43 Slow PSI 285Pump 2 Liner Stroke Len SPM PSI GPM SPR Slow PSI


Up Weight 90 000 Dn Weight 65,000 RT Weight 785)0 Torque 8 )00 Hours on Motor 11


RECEIVED: Sep. 08,



















1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027


1 65/123 440 1,600 2.93 11.00 2,063 187.55 11.00 2,063 187.55














RECEIVED: Sep. 08,



















1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027


1 65/123 440 1,600 2.93 11.00 2,063 187.55 11.00 2,063 187.55














RECEIVED: Sep. 08,



















1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027


1 65/123 440 1,600 2.93 11.00 2,063 187.55 11.00 2,063 187.55














RECEIVED: Sep. 08,



BHA MAKEUP:# Component OD ID Length Weight (ft/lb) Serial Number Description1 DRILL BIT 7.875 1.00 JJ6088 SMITH MDSI516 5X 12 .552

TFA2 7/8 5.7STG .28 1.5 7.000 3.250 26.69 650-106 1.5 DEG FBH 7/8 5.7 STG. .28

REV3 NON MAG MONEL 6.500 3.250 30.61 EN122-1 4.5 XH P x B4 EM GAP SUB 6.400 3.250 5.49 650-0053 4.5 XH P x B5 NON MAG FLEX MONEL 6.500 2.813 28.40 EN0815-12 4.5 XH P x B6 NON MAG FLEX MONEL 6.500 2.813 30.22 EN0814-12 4.5 XH P x B7 DRILL COLLAR 6.500 2.250 31.06 RIG 4.5 XH P x B8 18JTS HWDP 4.500 2.313 545.17 RIG 4.5 XH P x B9 DRILLING JARS 6.550 2.625 31.34 71617G 4.5 XH P x B(SMITH)HE JARS


DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 525 525 10,0008100..320: Mud & Chemicals 809 2,322 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 16,275 53,692 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 2,300 3,546 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 3,260 4,076 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 350 438 10,000 8100..535: Directional Drillin 14,425 14,425 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P & A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 5,000 9,625 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 4,730 13,140 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 47,674 180,834 675,000


BHA MAKEUP:# Component OD ID Length Weight (ft/Ib) Serial Number Description1 DRILL BIT 7.875 1.00 JJ6088 SMITH MDSl516 5X 12 .552


REV3 NON MAG MONEL 6.500 3.250 30.61 EN122-1 4.5 XH PxB4 EM GAP SUB 6.400 3.250 5.49 650-0053 4.5 XH PxB5 NON MAG FLEX MONEL 6.500 2.813 28.40 ENO815-12 4.5 XH PxB6 NON MAG FLEX MONEL 6.500 2.813 30.22 ENO814-12 4.5 XH PxB7 DRILL COLLAR 6.500 2.250 31.06 RIG 4.5 XH PxB8 18JTS HWDP 4.500 2.313 545.17 RIG 4.5 XH PxB9 DRILLINGJARS 6.550 2.625 31.34 71617G 4.5 XH Px B(SMITH)HE JARS10 6JTS HWDP 4.500 2.313 182.16 RIG 4.5 XH PxB

DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 525 525 10,0008100..320: Mud & Chemicals 809 2,322 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 16,275 53,692 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 20,000 8100..410: MoblDemob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 2,300 3,546 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 3,260 4,076 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 350 438 10,000 8100..535: Directional Drillin 14,425 14,425 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P &A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 5,000 9,625 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 4,730 13,140 8100..950: Administrative OlH8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 47,674 180,834 675,000


RECEIVED: Sep. 08,







RECEIVED: Sep. 08,







RECEIVED: Sep. 08,







RECEIVED: Sep. 08,




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANTJOHN FREITAS/JARED MEJORADOPHONE# 435-219-4933 CONTRACTOR Ensign 122TD AT REPORT 6,074' FOOTAGE 2,984' PRATE 127.0 CUM. DRLG. HRS 43.0 DRLG DAYS SINCE SPUD 2ANTICIPATED TD 6,866' PRESENT OPS Directional Drilling at 6,074' GEOLOGIC SECT.DAILY MUD LOSS SURF: 0 DH: 20 CUM. MUD LOSS SURF: 0 DH: 20MUD COMPANY: ANCHOR MUD ENGINEER: DAN KASTELLAST BOP TEST 08/24/2014 NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,866 SSE 0 SSED 0

TIME BREAKDOWNDIRECTIONAL DRILLING 23.50 RIG SERVICE 0.50

DETAILSStart End Hrs06:00 12:30 06:30 DIR DRILL F/ 3090' T/ 4036' 946' @ 145.5 FT/HR - W/ 6-15K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -


SERVICE AND INSPECT PUMP # 1 PUMP #2 AND HPU MOTORS.13:00 18:00 05:00 DIR DRILL F/ 4036' T/ 4625' 589' @ 117.8 FT/HR - W/ 6-15K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -

7-10K TORQUE - 1800 PSI SPP.18:00 00:00 06:00 DIR DRILL F/ 4625' T/ 5472' 847' @ 141.1 FT/HR - W/ 20-25K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -


7-10K TORQUE - 2425 PSI SPP. ON BOTTOM ROP 208.5505:55 05:55 00:00 SAFETY MEETING DAYS: DIGGING DITCHES, FORKLIFT SAFETY, HOUSE KEEPING.

SAFETY MEETING NIGHTS: LIGHTNING, HOUSE KEEPING.REGULATORY NOTICES: PRODUCTION CASING, STATE AND BLM.REGULATORY VISITS: NONE.INCIDENTS: NONE.SAFETY DRILLS: BOP DRILL DAY CREW.


FUEL AND WATER USAGEFluid Used Received Transferred On Hand Cum.UsedFuel 1,600.0 3,000.0 3,640.0 3,960.0GasFresh Well WaterNano WaterFrac WaterReserve Pit WaterBoiler HoursAir Heater HoursUrea 0.0Urea Sys 1 HrsUrea Sys 2 HrsUrea Sys 3 Hrs


RECENT BITS:BIT SIZE MANUF TYPE SERIAL NO. JETS TFA DEPTH IN DEPTH OUT I-O-D-L-B-G-O-R1 7.875 SMITH MDSI516 JJ6088 12/12/12/12/12 0.552 1,027 -------

BIT OPERATIONS:BIT WOB RPM GPM PRESS HHP HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 65/123 440 2,250 3.08 23.50 2,984 126.98 34.50 5,047 146.29


MUD MOTOR OPERATIONS:# WOB REV/GAL HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 24 0.28 23.50 2,984 126.98 34.50 5,047 146.29


08/25/2014 6,840 1.6 166.40 6,721 826.7 452.49 693.13 0.0 Projected Survey Station08/25/2014 6,790 1.6 166.40 6,671 827.2 453.85 692.80 0.8 MWD Survey Tool08/25/2014 6,748 1.6 154.60 6,629 827.5 454.94 692.41 0.4 MWD Survey Tool




O/W Ratio ES WPSComments: ANCO BAR 48, SODA ASH 13, CEDAR FIBER 3, DRISPAC REG 6, HI-YIELD GEL 11, LIGNITE 2, LIME 7, PHPA 6, SAWDUST 20,

FLOWZAN 3, MYA-CIDE 4, TRAILER RENTAL 1,ENGINEERING 1.


SURFACE PUMP/BHA INFORMATIONPump 1 Liner 6.5 Stroke Len 9.0 SPM 126 PSI 2,150 GPM 440 SPR Slow PSIPump 2 Liner Stroke Len SPM PSI GPM SPR 43 Slow PSI 289


Up Weight 135 Dn Weight 105 RT Weight 117 Torque 11,300 Hours on Motor 35



WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANTOHN FREITAS/JARED MEJORADOPHONE# 435-219-4933 CONTRACTOR Ension 122TD AT REPORT 6,074' FOOTAGE 2,984' PRATE 127.0 CUM. DRLG. HRS 43.0 DRLG DAYS SINCE SPUD 2ANTICIPATED TD 6,866' PRESENT OPS Directional Drillingat 6,074' GEOLOGIC SECT.DAILY MUD LOSS SURF: 0 DH: 20 CUM. MUD LOSS SURF: 0 DH: 20MUD COMPANY: ANCHOR MUD ENGINEER: DAN KASTELLAST BOP TEST 08/24/2014 NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,866 SSE O SSED 0


DETAILSStart End Hrs06:00 12:30 06:30 DIR DRILL FI 3090' TI 4036' 946' @ 145.5 FTlHR - WI 6-15K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -



7-10K TORQUE - 1800 PSI SPP.18:00 00:00 06:00 DIR DRILL FI 4625' TI 5472' 847' @ 141.1 FTlHR - WI20-25K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -



SAFETY MEETING NIGHTS: LIGHTNING, HOUSE KEEPING.REGULATORY NOTICES: PRODUCTION CASING, STATE AND BLM.REGULATORY VISITS: NONE.INCIDENTS: NONE.SAFETY DRILLS: BOP DRILL DAYCREW.





1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027


1 65/123 440 2,250 3.08 23.50 2,984 126.98 34.50 5,047 146.29








OlW Ratio ES WPSComments: ANCO BAR 48, SODA ASH 13, CEDAR FIBER 3, DRISPAC REG 6, HI-YlELD GEL 11, LIGNITE 2, LIME 7, PHPA 6, SAWDUST 20,



SURFACE PUMPIBHA INFORMATIONPump 1 Liner 6.5 Stroke Len 9.0 SPM 126 PSI 2 0 GPM 440 SPR Slow PSIPump 2 Liner Stroke Len SPM PSI GPM SPR 43 Slow PSI 289




RECEIVED: Sep. 08,
















1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027


1 65/123 440 2,250 3.08 23.50 2,984 126.98 34.50 5,047 146.29















RECEIVED: Sep. 08,
















1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027


1 65/123 440 2,250 3.08 23.50 2,984 126.98 34.50 5,047 146.29















RECEIVED: Sep. 08,
















1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027


1 65/123 440 2,250 3.08 23.50 2,984 126.98 34.50 5,047 146.29















RECEIVED: Sep. 08,







DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 525 10,0008100..320: Mud & Chemicals 5,370 7,691 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 19,425 73,117 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 10,031 10,031 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 3,546 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 3,260 7,336 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 350 788 10,000 8100..535: Directional Drillin 8,725 23,150 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P & A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 5,000 14,625 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 5,737 18,877 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 57,898 238,732 675,000





DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 525 10,0008100..320: Mud & Chemicals 5,370 7,691 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 19,425 73,117 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 10,031 10,031 20,000 8100..410: MoblDemob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 3,546 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 3,260 7,336 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 350 788 10,000 8100..535: Directional Drillin 8,725 23,150 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P &A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 5,000 14,625 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 5,737 18,877 8100..950: Administrative OlH8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 57,898 238,732 675,000


RECEIVED: Sep. 08,







RECEIVED: Sep. 08,







RECEIVED: Sep. 08,







RECEIVED: Sep. 08,




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANTJOHN FREITAS/JERAD MEJORADOPHONE# 435-219-4933 CONTRACTOR Ensign 122TD AT REPORT 6,840' FOOTAGE 766' PRATE 56.7 CUM. DRLG. HRS 56.5 DRLG DAYS SINCE SPUD 3ANTICIPATED TD 6,866' PRESENT OPS Logging at 6,840' GEOLOGIC SECT.DAILY MUD LOSS SURF: 0 DH: 30 CUM. MUD LOSS SURF: 0 DH: 50MUD COMPANY: ANCHOR MUD ENGINEER: DAN KASTELLAST BOP TEST 08/24/2014 NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,824 SSE 0 SSED 0

TIME BREAKDOWNCOND MUD & CIRCULATE 1.00 DIRECTIONAL DRILLING 13.50 TRIPPING 6.50

WIRELINE 3.00

DETAILSStart End Hrs06:00 12:00 06:00 DIR DRILL F/ 6074' T/ 6546' 472' @ 78.6 FT/HR - W/ 20-25K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -


7-10K TORQUE - 2500 PSI SPP.18:00 19:30 01:30 DIR DRILL F/ 6753' T/ 6840'(TD) 87' @ 58 FT/HR - W/ 20-25K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF

- 7-10K TORQUE - 2500 PSI SPP.ON BOTTOM ROP 167.52.19:30 20:30 01:00 CIRC HOLE CLEAN.20:30 00:00 03:30 PUMP & ROTATE OUT OF HOLE F/6840' T/ 6111' - PUMP DRY JOB - T.O.O.H. F/ 6111' T/ 2958'00:00 02:30 02:30 CONT. T.O.O.H. F/ 2958' T/ DIR TOOLS02:30 03:00 00:30 PULL MWD TOOL - L/D DIR TOOLS - DRAIN M/M - BREAK BIT - FUNCTION ALL B.O.P. COMPONENTS - FILL

HOLE W/ ACTIVE MUD SYSTEM CONTINUOUSLY 44BBLS03:00 06:00 03:00 RIG UP HALLIBURTON LOGGERS, HOLD A PJSM WITH HALLIBURTON, RUN IN WIRELINE TOOLS, LINE

SPEED DOWN 200 FPM, LINE SPEED UP 60 FPM / LOGGERS DEPTH 6333',TOOLS- RELEASABLE WIRELINECABLE HEAD,GAMMA TELEMTRY, DUEL SPACE NEUTRON, DNS DECENTRALIZER, SPECTRAL DENSITYTOOL,DENSITY INSITE PAD, ARRAY COMPENSATED TRUE RESISTIVITY INSTRUMENT SECTION, ARRAYCOMPENSATED RESISTIVITY SONDE SECTION, SP RING AND BULL NOSE.

05:55 05:55 00:00 SAFETY MEETING DAYS: INSPECTING EQUIPMENT, HOUSE KEEPING.SAFETY MEETING NIGHTS: LAYING DOWN DRILL PIPE, HOUSE KEEPING.REGULATORY NOTICES: NONE.REGULATORY VISITS: NONE.INCIDENTS: NONE.SAFETY DRILLS: NONE.


FUEL AND WATER USAGEFluid Used Received Transferred On Hand Cum.UsedFuel 1,300.0 2,340.0 5,260.0GasFresh Well WaterNano WaterFrac WaterReserve Pit WaterBoiler HoursAir Heater HoursUrea 0.0Urea Sys 1 HrsUrea Sys 2 HrsUrea Sys 3 Hrs

RECENT CASINGS RUN: Date Set Size Grade Weight Depth FIT Depth FIT ppgProduction 08/26/2014 5 1/2 J-55 17 6,824Surface 08/12/2014 8 5/8 ARJ-55 24 1,015Conductor 08/07/2014 16 ARJ-55 45 100

RECENT BITS:BIT SIZE MANUF TYPE SERIAL NO. JETS TFA DEPTH IN DEPTH OUT I-O-D-L-B-G-O-R1 7.875 SMITH MDSI516 JJ6088 12/12/12/12/12 0.552 1,027 6,840 3-3-BT-S-X-X-CT-TD

BIT OPERATIONS:BIT WOB RPM GPM PRESS HHP HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10

RECENT MUD MOTORS:# SIZE MANUF TYPE SERIAL NO. LOBES DEPTH IN DEPTH OUT DATE IN DATE OUT1 6.500 DYNA-DRILL FIXED 650-106 7/8 5 1,027 6,840 08/23/2014 08/26/2014

MUD MOTOR OPERATIONS:# WOB REV/GAL HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 24 0.28 13.50 766 56.74 48.00 5,813 121.10






O/W Ratio ES WPSComments: ANCO DD 2,DRISPAC REG 9,LIGNITE 8, LIME 12, PHPA 1, SAWDUST 70, FLOWZAN 2, SOLTEX 20,WALNUT 90,MYA-CIDE 3,

TRAILER RENTAL 1,ENGINEERING 1.







WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANTOHN FREITAS/JERAD MEJORADOPHONE# 435-219-4933 CONTRACTOR Ension 122TD AT REPORT 6,840' FOOTAGE 766' PRATE 56.7 CUM. DRLG. HRS 56.5 DRLG DAYS SINCE SPUD 3ANTICIPATED TD 6,866' PRESENT OPS Loaqina at 6,840' GEOLOGIC SECT.DAILY MUD LOSS SURF: 0 DH: 30 CUM. MUD LOSS SURF: 0 DH: 50MUD COMPANY: ANCHOR MUD ENGINEER: DAN KASTELLAST BOP TEST 08/24/2014 NEXT CASING SIZE 5 1/2 NEXT CASING DEPTH 6,824 SSE O SSED 0


WIRELINE 3.00

DETAILSStart End Hrs06:00 12:00 06:00 DIR DRILL FI 6074' TI 6546' 472' @78.6 FTlHR - WI 20-25K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -

7-10K TORQUE - 2500 PSI SPP.12:00 18:00 06:00 DIR DRILL FI 6546' TI 6753' 207' @34.5 FTlHR - WI 20-25K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF -

7-10K TORQUE - 2500 PSI SPP.18:00 19:30 01:30 DIR DRILL FI 6753' TI 6840'(TD) 87' @58 FTlHR - WI20-25K WT ON BIT - 440GPM - 55-65RPM - 400-600 DIFF

-7-10K TORQUE -2500 PSI SPP.ON BOTTOM ROP 167.52.19:30 20:30 01:00 CIRC HOLE CLEAN.20:30 00:00 03:30 PUMP & ROTATE OUT OF HOLE Fl6840' TI 6111'- PUMP DRY JOB - T.O.O.H. FI6111' TI2958'00:00 02:30 02:30 CONT. T.O.O.H. FI 2958' TI DIR TOOLS02:30 03:00 00:30 PULL MWD TOOL - L/D DIR TOOLS - DRAIN MIM - BREAK BIT - FUNCTION ALL B.O.P. COMPONENTS - FILL

HOLE WlACTIVE MUD SYSTEM CONTINUOUSLY 44BBLS03:00 06:00 03:00 RIG UP HALLIBURTON LOGGERS, HOLD A PJSM WITH HALLIBURTON, RUN IN WIRELINE TOOLS, LINE

SPEED DOWN 200 FPM, LINE SPEED UP 60 FPM / LOGGERS DEPTH 6333',TOOLS- RELEASABLE WIRELINECABLE HEAD,GAMMATELEMTRY, DUEL SPACE NEUTRON, DNS DECENTRALIZER, SPECTRAL DENSITYTOOL,DENSITY INSITE PAD, ARRAY COMPENSATED TRUE RESISTIVITY INSTRUMENT SECTION, ARRAYCOMPENSATED RESISTIVITY SONDE SECTION, SP RING AND BULL NOSE.

05:55 05:55 00:00 SAFETY MEETING DAYS: INSPECTING EQUIPMENT, HOUSE KEEPING.SAFETY MEETING NIGHTS: LAYINGDOWN DRILL PIPE, HOUSE KEEPING.REGULATORY NOTICES: NONE.REGULATORY VISITS: NONE.INCIDENTS: NONE.SAFETY DRILLS: NONE.





1 7.875 SMITH MDSl516 JJ6088 12/12/12/12/12 0.552 1,027 6,840 3-3-BT-S-X-X-CT-TD


1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10


MUD MOTOR OPERATIONS:# WOB REVIGAL HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 24 0.28 13.50 766 56.74 48.00 5,813 121.10






OlW Ratio ES WPSComments: ANCO DD 2,DRISPAC REG 9,LIGNITE 8, LIME 12, PHPA 1, SAWDUST 70, FLOWZAN 2, SOLTEX 20,WALNUT90,MYA-CIDE 3,



SURFACE PUMPIBHA INFORMATIONPump 1 Liner 6.5 Stroke Len 9.0 SPM 126 PSI 2 0 GPM 440 SPR 43 Slow PSI 390Pump 2 Liner Stroke Len SPM PSI GPM SPR Slow PSI




RECEIVED: Sep. 08,





WIRELINE 3.00














1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10















RECEIVED: Sep. 08,





WIRELINE 3.00














1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10















RECEIVED: Sep. 08,





WIRELINE 3.00














1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10















RECEIVED: Sep. 08,







DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 420 945 10,0008100..320: Mud & Chemicals 7,838 15,529 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 19,425 92,542 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 10,031 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 3,546 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 3,260 10,596 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 350 1,138 10,000 8100..535: Directional Drillin 7,725 30,875 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P & A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 5,000 19,625 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 4,162 23,039 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 82,370 82,370 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 130,549 369,281 675,000





DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 420 945 10,0008100..320: Mud & Chemicals 7,838 15,529 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 19,425 92,542 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 10,031 20,000 8100..410: MoblDemob8100..420: Bits & Reamers 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 3,546 1,000 8100..520: Trucking & Hauling 23,0008100..530: Equipment Rental 3,260 10,596 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 350 1,138 10,000 8100..535: Directional Drillin 7,725 30,875 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P &A8100..700: Logging - Openhole 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 5,000 19,625 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 4,162 23,039 8100..950: Administrative OlH8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 25,000 8210..600: Production Casing 82,370 82,370 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 130,549 369,281 675,000


RECEIVED: Sep. 08,







RECEIVED: Sep. 08,







RECEIVED: Sep. 08,







RECEIVED: Sep. 08,




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANTJOHN FREITAS/JARED MEJORADOPHONE# 435-219-4933 CONTRACTOR Ensign 122TD AT REPORT 6,840' FOOTAGE 0' PRATE CUM. DRLG. HRS 56.5 DRLG DAYS SINCE SPUD 3ANTICIPATED TD 6,866' PRESENT OPS Rig release at 6,840' GEOLOGIC SECT.DAILY MUD LOSS SURF: 0 DH: 0 CUM. MUD LOSS SURF: 0 DH: 50MUD COMPANY: ANCHOR MUD ENGINEER: DAN KASTELLAST BOP TEST 08/24/2014 NEXT CASING SIZE 2 7/8 NEXT CASING DEPTH 6,821 SSE SSED

TIME BREAKDOWNCASING & CEMENT 8.50 COND MUD & CIRCULATE 1.50 RIG UP / TEAR DOWN 2.00

WIRELINE 1.50

DETAILSStart End Hrs06:00 07:30 01:30 RIG DOWN LOGGING EQUIPMENT07:30 13:30 06:00 RIG UP AND RUN CASING. SHOE, FLOAT, THREAD LOCK SAME, 155 JOINTS OF 5.5" J-55 17# AND 2

MARKERS SET AT 5976', 5082' WITH CENTRALIZERS THE FIRST 4 JTS AND EVERY THIRD JT UP TO 500'13:30 15:00 01:30 CONDITION MUD BACK TO 40VIS FOR CEMENT JOB WHILE HALLIBURTON RIGGED UP EQUIPMENT ON

THE GROUND15:00 17:30 02:30 R/U HES TO FLOOR-CHECK HEAD: LOAD PLUG WITNESED BY CO-MAN. R/U HEAD & IRON.PUMP 3bbls

WTR & TEST LINES T/5,000psi. PUMP 50bbl TUNED SPACER III. MIX & PUMP 146bbls [email protected]/YIELD OF 3.5ft3/SK/20.92gal WTR/SK(235SKS),MIX & PUMP 107bbls [email protected]/1.35ft3/SK/5.82gal/SK=445 SKS. WASH UP. DROP PLUG & DISP/158.2bbls WTR.BUMPPLUG/2231=500psi OVER FCP OF 1731psi. BLED BACK 1.5bbls T/TRUCK. FLOATS HELD.***FULLRETURNS***20 BARRELS CEMENT TO SURFACE***

17:30 19:30 02:00 RIG DOWN FOR RIG SKID & CLEAN MUD TANKS - RIG RELEASED @ 19:30HRS 8/26/2014 FROM TR3-23-820 SKIDDING TO TR 3-14-820

05:55 05:55 00:00 SAFETY MEETING DAYS: RUNNING CASING & CEMENTING, HOUSE KEEPING.SAFETY MEETING NIGHTS: SKIDDING RIG, NIPPLE UP B.O.P. & TESTING B.O.P., HOUSE KEEPING.REGULATORY NOTICES: NONE.REGULATORY VISITS: NONE.INCIDENTS: NONE.SAFETY DRILLS: NONE.


FUEL AND WATER USAGEFluid Used Received Transferred On Hand Cum.UsedFuel 100.0 2,240.0 0.0 5,360.0GasFresh Well WaterNano WaterFrac WaterReserve Pit WaterBoiler HoursAir Heater HoursUrea 0.0Urea Sys 1 HrsUrea Sys 2 HrsUrea Sys 3 Hrs

CASING EQUIPMENTRIG UP AND RUN CASING. SHOE, FLOAT, THREAD LOCK SAME, 155 JOINTS OF 5.5" J-55 17# AND 2 MARKERS SET AT 5976', 5082' WITHCENTRALIZERS THE FIRST 4 JTS AND EVERY THIRD JT UP TO 500'

CEMENT JOB SUMMARYR/U HES TO FLOOR-CHECK HEAD: LOAD PLUG WITNESED BY CO-MAN. R/U HEAD & IRON.PUMP 3bbls WTR & TEST LINES T/5,000psi.PUMP 50bbl TUNED SPACER III. MIX & PUMP 146bbls LEAD [email protected]/YIELD OF 3.5ft3/SK/20.92gal WTR/SK(235SKS),MIX & PUMP 107bblsTAIL [email protected]/1.35ft3/SK/5.82gal/SK=445 SKS. WASH UP. DROP PLUG & DISP/158.2bbls WTR.BUMP PLUG/2231=500psi OVER FCP OF1731psi. BLED BACK 1.5bbls T/TRUCK. FLOATS HELD.***FULL RETURNS***20BBLS CEMENT TO SURFACE***


RECENT BITS:BIT SIZE MANUF TYPE SERIAL NO. JETS TFA DEPTH IN DEPTH OUT I-O-D-L-B-G-O-R1 7.875 SMITH MDSI516 JJ6088 12/12/12/12/12 0.552 1,027 6,840 3-3-BT-S-X-X-CT-TD

BIT OPERATIONS:BIT WOB RPM GPM PRESS HHP HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10


MUD MOTOR OPERATIONS:# WOB REV/GAL HRS 24hr DIST 24HR ROP CUM HRS CUM DIST CUM ROP1 24 0.28 13.50 766 56.74 48.00 5,813 121.10






O/W Ratio ES WPSComments: ANCO BAR 40, LIME 3, SAWDUST 75, TRAILER RENTAL 1,ENGINEERING 1.




WELL NAME THREE RIVERS FED 3-23-820 AFE# 140627 SPUD DATE 08/23/2014WELL SITE CONSULTANTOHN FREITAS/JARED MEJORADOPHONE# 435-219-4933 CONTRACTOR Ension 122TD AT REPORT 6,840' FOOTAGE O' PRATE CUM. DRLG. HRS 56.5 DRLG DAYS SINCE SPUD 3ANTICIPATED TD 6,866' PRESENT OPS Rio release at 6,840' GEOLOGIC SECT.DAILY MUD LOSS SURF: 0 DH: O CUM. MUD LOSS SURF: 0 DH: 50MUD COMPANY: ANCHOR MUD ENGINEER: DAN KASTELLAST BOP TEST 08/24/2014 NEXT CASING SIZE 2 7/8 NEXT CASING DEPTH 6,821 SSE SSED

TIME BREAKDOWNCASING & CEMENT 8.50 COND MUD & CIRCULATE 1.50 RIG UP ITEAR DOWN 2.00

WIRELINE 1.50

DETAILSStart End Hrs06:00 07:30 01:30 RIG DOWN LOGGING EQUIPMENT07:30 13:30 06:00 RIG UP AND RUN CASING. SHOE, FLOAT, THREAD LOCK SAME, 155 JOINTS OF 5.5" J-55 17#AND 2


THE GROUND15:00 17:30 02:30 RIU HES TO FLOOR-CHECK HEAD: LOAD PLUG WITNESED BY CO-MAN. RIU HEAD & IRON.PUMP 3bbls

WTR &TEST LINES Tl5,000psi. PUMP 50bbl TUNED SPACER III.MIX & PUMP 146bbls [email protected] OF 3.5ft3/SKl20.92gal WTR/SK(235SKS),MIX & PUMP 107bbls [email protected]/1.35ft3/SKl5.82gallŠK=445 SKS. WASH UP. DROP PLUG & DISP/158.2bbls WTR.BUMPPLUGl2231=500psi OVER FCP OF 1731psi. BLED BACK 1.5bbls TITRUCK. FLOATS HELD.***FULLRETURNS***20 BARRELS CEMENT TO SURFACE***


05:55 05:55 00:00 SAFETY MEETING DAYS: RUNNING CASING & CEMENTING, HOUSE KEEPING.SAFETY MEETING NIGHTS: SKIDDING RIG, NIPPLE UP B.O.P. &TESTING B.O.P., HOUSE KEEPING.REGULATORY NOTICES: NONE.REGULATORY VISITS: NONE.INCIDENTS: NONE.SAFETY DRILLS: NONE.




CEMENT JOB SUMMARYRIU HES TO FLOOR-CHECK HEAD: LOAD PLUG WITNESED BY CO-MAN. RIU HEAD & IRON.PUMP 3bbls WTR &TEST LINES Tl5,000psi.PUMP 50bbl TUNED SPACER III.MIX & PUMP 146bbls LEAD [email protected] OF 3.5ft3/SKl20.92gal WTR/SK(235SKS),MIX & PUMP [email protected]/1.35ft3/SKl5.82gallŠK=445 SKS. WASH UP. DROP PLUG & DISP/158.2bbls WTR.BUMP PLUGl2231=500psi OVER FCP OF1731psi. BLED BACK 1.5bbls TITRUCK. FLOATS HELD.***FULLRETURNS***20BBLS CEMENT TO SURFACE***





1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10








OlW Ratio ES WPSComments: ANCO BAR 40, LIME 3, SAWDUST 75, TRAILER RENTAL 1,ENGINEERING 1.



RECEIVED: Sep. 08,





WIRELINE 1.50















1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10











RECEIVED: Sep. 08,





WIRELINE 1.50















1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10











RECEIVED: Sep. 08,





WIRELINE 1.50















1 65/123 440 2,250 3.12 13.50 766 56.74 48.00 5,813 121.10











RECEIVED: Sep. 08,










DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 945 10,0008100..320: Mud & Chemicals 1,736 17,266 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 10,631 103,173 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 10,031 20,000 8100..410: Mob/Demob8100..420: Bits & Reamers 13,095 13,095 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 3,546 1,000 8100..520: Trucking & Hauling 6,665 6,665 23,0008100..530: Equipment Rental 1,851 12,447 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 197 1,335 10,000 8100..535: Directional Drillin 7,725 38,600 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P & A8100..700: Logging - Openhole 12,121 12,121 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 2,500 22,125 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 8,362 31,401 8100..950: Administrative O/H8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 38,751 38,751 25,000 8210..600: Production Casing 3,010 85,380 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 106,645 475,926 675,000








DAILY COSTS DAILY CUM AFE DAILY CUM AFE8100..100: Permits & Fees 9,123 4,500 8100..105: Insurance 2,5008100..110: Staking & Surveying 1,500 8100..120: Surface Damages & R8100..200: Location Roads 14,439 30,000 8100..210: Reclamation8100..220: Secondary Reclamati 8100..230: Pit Solidification 5,0008100..300: Water Well 8100..310: Water/Water Disposa 945 10,0008100..320: Mud & Chemicals 1,736 17,266 55,000 8100..325: Oil Base Mud Diesel 35,0008100..400: Drilling Rig 10,631 103,173 135,000 8100..402: Drilling Rig Cleani 5,0008100..405: Rig Fuel 10,031 20,000 8100..410: MoblDemob8100..420: Bits & Reamers 13,095 13,095 17,500 8100..500: Roustabout Services 1,458 4,0008100..510: Testing/Inspection/ 3,546 1,000 8100..520: Trucking & Hauling 6,665 6,665 23,0008100..530: Equipment Rental 1,851 12,447 17,000 8100..531: Down Hole Motor Ren 1,5008100..532: Solids Control Equi 197 1,335 10,000 8100..535: Directional Drillin 7,725 38,600 65,0008100..540: Fishing 8100..600: Surface Casing/Inte 18,829 35,0008100..605: Cementing Work 35,197 25,000 8100..610: P &A8100..700: Logging - Openhole 12,121 12,121 14,000 8100..705: Logging - Mud8100..800: Supervision/Consult 2,500 22,125 35,000 8100..810: Engineering/Evaluat8100..900: Contingencies 8,362 31,401 8100..950: Administrative OlH8100..999: Non Operated IDC 8200..510: Testing/Inspection/ 2,0008200..520: Trucking & Hauling 11,500 8200..530: Equipment Rental 20,0008200..605: Cementing Work 38,751 38,751 25,000 8210..600: Production Casing 3,010 85,380 50,0008210..620: Wellhead/Casing Hea 15,000 Total Cost 106,645 475,926 675,000


RECEIVED: Sep. 08,










RECEIVED: Sep. 08,










RECEIVED: Sep. 08,










RECEIVED: Sep. 08,

ECEIVED EP 022014

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ACCUMULATOR FUNrnON TEST WEU:-r£" F~;::' :1 -~L3 .t?2.('

TO CK::CK THE lJSA8LE FLUiD STORED IN THE NiTROGEN BOTT'l.ES ON TK~

.ACCUMULATOR tOO #:2 Hi .A.2~cj~ or j: or iii)

1. Moke sure all rams and annular are open and if applic:oble HCR is dosed

Z. Ensure occumulalor is pumped up to. working pressure! (Shut off all pumps)

3. Open HCR \/IJM. (If apJJIicable)

4. CJase annular.

5. Close all pipe roms.. 5. Open one set of pipe roms to simulote dosing eM blind roms.

7. If you have a 3 Ram srock open the annular to adljeve the 50 +/. % SDfety

Joctor for SAlt and greatl!r systerr.s.

8. Accumulator pressure should be 200 psi O'IIer prer:harge pressure

{Accumulator working pressure (J.5(JO psi = 750 desired psi)

(2,000 and 3j}(J() psi '" 1,000 desired psi}).

!l. RECORD JHE REMAINING PfI:ESSURE~_....:/....:' ..:::;_L::.'.;:..C_·· ______ ,PSJ

If annular is dosed, open it at this time and clase HCR.

',J GiECK THE CAP,6..CiE OF THE ACCUMULATOR PUMPS (00 #2 'il.A.:2.;.)

Shut the accumulator bottles or spherical (Iwlate rMm {rom the pumps &

manifold) Opetl the bleed off valve to the tonk (Manifold psi should

go. to zero psi) r:lase bleed valve.

1. Open tM HCR valve. (1/ applicable)

2. Close annular. •

3. With pumps only, time how lang it tokes to reo gain manifold presssure to

200 psi over desired prer:horge pressure! (Acr:umulotor working

pressure (l.5OO psi = 750 psi desired psi) (2.000 and 3.000 psi = 1.000

desired psi)}.

c:::: -; 4. RECORD ELAPSED TINIE~_-----,::J::..!......!..._",::;....:·O.:::_:..:<:"-=-______ PSI (2 minutes orless)

TO CHECK THE ?RECHARGE ON THE BOTTLES OR SPHERICAL {GO #Z iil.A.2.ci.i

1.. Open bOtttes bade up to the monifold (pressure should be above the desired prechorge

pressure (:1,500 psi = 750 psi desired psi) (2.000 and 3,000 psi = 1.000 desired

psi )) may need to use pumps to pressure bode up.

Z. With power to pumps shut off open bleed line to tank.

3. Watch and record where the pressure drops (Accumulator psi).

4. RECORD THE PRESSURE DROP 4Of.{) PSI

1/ pn!5SUre drops below MINIMUM precharge (ACcumulator worldng pressure (1.500 psi = 700 psi

minimum) (2.000 and 3,000 psi = 900 psi minimum)) eHr:h bottle sholl be independently checked

with a guage.

OATE :' ACCUMULATOR FUNCTION 7EST

WEU.. Ê, Fíh 9 Î ·'èFTO CHiiCKTHEUSABLEFLUIDSTORED INTHE NITROGEN BOTTLili ON TRE

ACCUMULATOR (OO #2 ULA,2-c.i. or n or iii)

1 Make sure a/I rams and annuhrore open and if applicable HQt is closedz. Ensure accumueroris pumped up to working pressure! (Shut off all pumps)3. OpenfiCRuofwe.(ifoppliccole)

4. <bse annular.5. Gose oli pipe roms.6. Open one set of pipe rams to simulate closing the blind rums.7. If you have a 3 Ram stuck open the annular to achieve the 50 +/- % safety

JoctorforSM ond greater systems.8. Accumulatorpressure should be 200 psi over precharge pressure

(Accumuistor working pressure (1,500 psi = 750 desired psi)

(2,000 and 3,000 psi=1,000 desiredpsi))

R RECORD UfE AmfAN-G PRESSURE Ü PSI

If annular is closed, open it at this time and close HCR.

CHECKTHE CAPACITY OF THE ACCUMULATOR PUMPS (OO #2 NLA.2.¾-}

Shut the accumulator bottles orspherical Ilsolutethem from the pumps &manifokf} open the bleed off wolve to the tank (Manifold psi Should

go to zero psi) dose bleed volve.

1. Open the HCRvolve. (If applicoble)2 Cose annular. .÷

3. With pumps ong time how long it takes to re- gain manifold presssure to200 psi over desired precharge pmssure! (Accumulator working

pressure (1,500 psi = 750 psi desired psi) {2,000 and 3,000 psi = 1,000

desired psi)).

A RKORD W5m HME PSI (2 nunutes orless)

TO CHECK THE PRECHARGE ON THEBOTTLESORSPHERICAL(OC #2 ill.A.2.d.)

1. Open botties back up to the manifold {pressure should be above the desired prechargepressure ( psi= 750 psi desired psi) (2,000 and 3,000 psi = 1,000 desired

psi)) may need to use pumps to pressure back up.

2 With power to pumps shut off open bleed line to tank.3. Watch and record where the pressure drops {Accumulator psi).

RECORDHiEPRESSUREDROP ) ) PSI

If pressure drops below MINIMUM precharge (Accumulator working pressure (1,500psi= 700 psi

minimum) {2,000 and 3,000 psi= 900 psi minimum)) each bottle shall be independently checked

















desired psi)).

























desired psi)).

























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WALKER INSPECTION.LLC. 676 REBEL TESTING· EAGER BEAVER TESTERS

WYOMING· COLORADO· NORTH DAKOTA

Daily JSAlObservation Report OPERATOR: ____ ~£j~/A~r_~_~~ ______________ __ LOCATION: IE: F¢1> :I~ 'Z.J - Pz.o EMPLOYEE NAME: J)v ,-fin ~'?,rj,,,,oQ4

I !lSI High Pressure Testing

I ~ I Working Below Platform

I ~ Requires PPE

I~ Overhead Work is Occurring

I Fill in if: Confined Spaces are Involved

I Fill in if: Set up of Containment

I §!IiIiIk1 Using Rig Hoist to Lift Tools

I Fill in if: I Other: __ ----:,----",, __ ---,~_._-------SIGNATURE: cV/f"/;,:.>;/jj

2" WALKER INSPECTION, LLC. AND AFFILIATES

AmN,QANCE: L /#

DATE: ____ g>_-_-_~~3~-__ ~_O~/~¥ ________________ __

DATE: ~-2..'3- Lv f'i .

Observation Reportf ./ /--' EMPLOYEE REPORTING: 1>..t 5i!t.. vSgQ;IY'i).x4 SIGNATURE: T]-?S /j:!/ <j .

)'

Was job set up and performed correctly and to best of companies ability? IV N

Was all safety equipment used correctly by all involved? @I N

Any incidents or near misses to report about WI? Y I@

Any incidents or near misses to report in general? V I~

Any spills or environemental issues to report? Y I~

Basic Comments; ______________________________________________________________ __

WALKER INSPECTION,LLC.676 REBEL TESTING • EAGER BEAVERTESTERS

WYOMING• COLORADO • NORTH DAKOTA

Daily JSA/Observation ReportOPERATOR: DATE: $¯ L / ŸLOCATION: TX y-21- Ÿ10 CONTRACTOR: 67 y (:r-L

EMPLOYEENAME: u TAn Ä¾Ánon<j.

High Pressure Testing COMMENTS: Üoaci »,men C< r

Working Below Platform

Requires PPE

Overhead Work is Occurring

Fillin if: Confined Spaces are involved

Fillin if: Set up of Containment

Using Rig Hoist to Lift Tools

Fill in if: Other:

SIGNATURE: DATE:

WALKERINSPECTION LLC.AND AFFILIATESATTENDANÇE:

Observation ReportEMPLOYEEREPORTING: 'e Å«fw,ad SIGNATURE:

Was job set up and performed correctly and to best of companies ability? (9 N

Was all safety equipment used correctly by all involved? / N

Any incidents or near misses to report about WI? Y /

Any incidents or near missesto report in general7 Y/

Any spills or environemental issues to report? Y /

Basic







Requires PPE





Fill in if: Other:

SIGNATURE: DATE:








Basic







Requires PPE





Fill in if: Other:

SIGNATURE: DATE:








Basic







Requires PPE





Fill in if: Other:

SIGNATURE: DATE:








Basic




FORM 9









9. API NUMBER: 43047539530000




COUNTY: UINTAH

STATE: UTAH

11.





9 /28 /2014














First Production occurred on the TR3-23-820 on 09/28/2014.



SIGNATURE N/A

DATE 9 /29 /2014

October 01, 2014


FORM 9STATE OF UTAH

















9/28/2014OPERATOR CHANGE PLUG AND ABANDON PLUG BACK







First Production occurred on the TR3-23-820 on 09/28/2014. Accepted by theutah Division of

Oil, Gas and Mining

FOR RECORD ONLYOctober 01, 2014



RECEIVED: Sep. 29,


FORM 9STATE OF UTAH
























First Production occurred on the TR3-23-820 on 09/28/2014. Accepted by theutah Division of

Oil, Gas and Mining

FOR RECORD ONLYOctober 01, 2014



RECEIVED: Sep. 29,

RECEIVED: Oct. 29, 2014

Form 3160-4 UNITED STATES FORM APPROVED(August 2007) DEPARTMENT OF THE INTERIOR OMB No. 1004-0137

BUREAU OF LAND MANAGEMENT Expires: July 31, 2010

WELL COMPLETION OR RECOMPLETION REPORT AND LOG 5. Lease Serial No.UTU85994

1a. Type of Well Oil Well Gas Well Dry Other

b. Type of Completion New Well Work Over Deepen Plug Back Diff. Resvr.

Other _________________________________

6. If Indian, Allottee or Tribe Name

7. Unit or CA Agreement Name and No.

2. Name of OperatorULTRA RESOURCES, INC.

Contact: JENNA ANDERSONE-Mail: [email protected]

8. Lease Name and Well No.THREE RIVERS FED 3-23-820

3. Address 304 INVERNESS WAY SOUTH SUITE 295ENGLEWOOD, CO 80112

3a. Phone No. (include area code)Ph: 303-645-9804

9. API Well No.43-047-53953

4. Location of Well (Report location clearly and in accordance with Federal requirements)*

At surface NWSW 1536FSL 1296FWL 40.148708 N Lat, 109.659503 W Lon

At top prod interval reported below NESW 2022FSL 1987FWL 40.150066 N Lat, 109.657046 W Lon

At total depth NESW 1980FSL 1994FWL 40.149950 N Lat, 109.657023 W Lon

10. Field and Pool, or ExploratoryTHREE RIVERS

11. Sec., T., R., M., or Block and Surveyor Area Sec 3 T8S R20E Mer SLB

12. County or ParishUINTAH

13. StateUT

14. Date Spudded08/07/2014

15. Date T.D. Reached08/25/2014

16. Date CompletedD & A Ready to Prod.09/27/2014

17. Elevations (DF, KB, RT, GL)*4745 GL

18. Total Depth: MD 6840TVD 6721

19. Plug Back T.D.: MD 6821TVD 6702

20. Depth Bridge Plug Set: MDTVD

21. Type Electric & Other Mechanical Logs Run (Submit copy of each)TRIPLE COMBO, CBL

22. Was well cored? No Yes (Submit analysis)Was DST run? No Yes (Submit analysis)Directional Survey? No Yes (Submit analysis)

23. Casing and Liner Record (Report all strings set in well)

Top Bottom Stage Cementer No. of Sks. & Slurry Vol.Hole Size Size/Grade Wt. (#/ft.) Cement Top* Amount Pulled

(MD) (MD) Depth Type of Cement (BBL)

24.000 16.000 ARJ-55 45.0 0 100 450 0

12.250 8.625 ARJ-55 24.0 0 1015 675 0

7.875 5.500 J-55 17.0 0 6824 680 0

24. Tubing Record

Size Depth Set (MD) Packer Depth (MD) Size Depth Set (MD) Packer Depth (MD) Size Depth Set (MD) Packer Depth (MD)

2.875 486025. Producing Intervals 26. Perforation Record

Formation Top Bottom Perforated Interval Size No. Holes Perf. Status

A) LOWER GR 5006 6706 5006 TO 6706 261 OPEN

B)

C)

D)27. Acid, Fracture, Treatment, Cement Squeeze, Etc.

Depth Interval Amount and Type of Material

5006 TO 6706 FRATURE/STIMULATE 7 STAGES

28. Production - Interval ADate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MethodProduced Date Tested Production BBL MCF BBL Corr. API Gravity

09/27/2014 10/10/2014 24 32.0 37.0 407.0 GAS PUMPING UNIT

Choke Tbg. Press. Csg. 24 Hr. Oil Gas Water Gas:Oil Well StatusSize Flwg. Press. Rate BBL MCF BBL Ratio

SI POW

28a. Production - Interval BDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MethodProduced Date Tested Production BBL MCF BBL Corr. API Gravity


SI

(See Instructions and spaces for additional data on reverse side)ELECTRONIC SUBMISSION #274440 VERIFIED BY THE BLM WELL INFORMATION SYSTEM

** OPERATOR-SUBMITTED ** OPERATOR-SUBMITTED ** OPERATOR-SUBMITTED **


Fonn 3160-4 UNITED STATES FORM APPROVED(August 2007) DEPARTMENT OF THE INTERIOR OMB No. 1004-0137



la. Type of Well Oil Well O Gas Well O Dry O other 6. If Indian, Allottee or Tribe Name

b. Type of Completion New Well O Work Over O Deepen O Plug Back O Diff. Resvr.

Other 7. Unit or CA Agreement Name and No.

2. Name of Operator Contact: JENNA ANDERSON 8. Lease Name and Well No.ULTRA RESOURCES, INC. E-Mail: [email protected] THREE RIVERS FED 3-23-820

3. Address 304 INVERNESS WAY SOUTH SUITE 295 3a. Phone No. (include area code) 9. API Well No.ENGLEWOOD, CO 80112 Ph: 303-645-9804 43-047-53953

4. Location of Well (Report location clearly and in accordance with Federal requirements)* 10. Field and Pool, or ExploratoryTHREE RIVERS

At surface NWSW 1536FSL 1296FWL 40.148708 N Lat, 109.659503 W Lon 11. Sec., T., R., M., or Block and Survey

At top prod interval reported below NESW 2022FSL 1987FWL 40.150066 N Lat, 109.657046 W Lon or Area Sec 3 T8S R20E Mer SLB12. County or Parish 13. State

At total depth NESW 1980FSL 1994FWL 40.149950 N Lat, 109.657023 W Lon UINTAH UT14. Date Spudded 15. Date T.D. Reached 16. Date Completed 17. Elevations (DF, KB, RT, GL)*

08/07/2014 08/25/2014 OD & A Ready to Prod. 4745 GL09/27/2014

18. Total Depth: MD 6840 19. Plug Back T.D.: MD 6821 20. Depth Bridge Plug Set: MDTVD 6721 TVD 6702 TVD

21. Type Electric & Other Mechanical Logs Run (Submit copy of each) 22. Was well cored? No O Yes (Submit analysis)TRIPLE COMBO, CBL Was DST run? No O Yes (Submit analysis)

Directional Survey? O No Yes (Submit analysis)


. Top Bottom Stage Cementer No. of Sks. & Slurry Vol.Hole Size Size/Grade Wt. (#/ft.) Cement Top* Amount Pulled


24.000 16.000 ARJ-55 45.0 0 100 450 012.250 8.625 ARJ-55 24.0 0 1015 675 0

7.875 5.500 J-55 17.0 0 6824 680 0

24. Tubing Record




A) LOWER GR 5006 6706 5006 TO 6706 261 OPENB)C)D)27. Acid, Fracture, Treatment, Cement Squeeze, Etc.




09/27/2014 10/10/2014 24 32.0 37.0 407.0 GAS PUMPING UNITChoke Tbg. Press. Csg. 24 Hr. Oil Gas Water Gas:Oil Well Statussize Flwg. Press. Rate BBL MCF BBL Ratio

SI POW

28a. Production - Interval BDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MethodProduced Date Tested Product on BBL MCF BBL Corr. API Gravity

Choke Tbg. Press. Csg. 24 Hr. Oil Gas Water Gas:Oil Well Statussize Flwg. Press. Rate BBL MCF BBL Ratio

SI



RECEIVED: Oct. 29,


Fonn 3160-4 UNITED STATES FORM APPROVED(August 2007) DEPARTMENT OF THE INTERIOR OMB No. 1004-0137



la. Type of Well Oil Well O Gas Well O Dry O other 6. If Indian, Allottee or Tribe Name

b. Type of Completion New Well O Work Over O Deepen O Plug Back O Diff. Resvr.

Other 7. Unit or CA Agreement Name and No.

2. Name of Operator Contact: JENNA ANDERSON 8. Lease Name and Well No.ULTRA RESOURCES, INC. E-Mail: [email protected] THREE RIVERS FED 3-23-820

3. Address 304 INVERNESS WAY SOUTH SUITE 295 3a. Phone No. (include area code) 9. API Well No.ENGLEWOOD, CO 80112 Ph: 303-645-9804 43-047-53953

4. Location of Well (Report location clearly and in accordance with Federal requirements)* 10. Field and Pool, or ExploratoryTHREE RIVERS

At surface NWSW 1536FSL 1296FWL 40.148708 N Lat, 109.659503 W Lon 11. Sec., T., R., M., or Block and Survey

At top prod interval reported below NESW 2022FSL 1987FWL 40.150066 N Lat, 109.657046 W Lon or Area Sec 3 T8S R20E Mer SLB12. County or Parish 13. State

At total depth NESW 1980FSL 1994FWL 40.149950 N Lat, 109.657023 W Lon UINTAH UT14. Date Spudded 15. Date T.D. Reached 16. Date Completed 17. Elevations (DF, KB, RT, GL)*

08/07/2014 08/25/2014 OD & A Ready to Prod. 4745 GL09/27/2014

18. Total Depth: MD 6840 19. Plug Back T.D.: MD 6821 20. Depth Bridge Plug Set: MDTVD 6721 TVD 6702 TVD

21. Type Electric & Other Mechanical Logs Run (Submit copy of each) 22. Was well cored? No O Yes (Submit analysis)TRIPLE COMBO, CBL Was DST run? No O Yes (Submit analysis)

Directional Survey? O No Yes (Submit analysis)


. Top Bottom Stage Cementer No. of Sks. & Slurry Vol.Hole Size Size/Grade Wt. (#/ft.) Cement Top* Amount Pulled


24.000 16.000 ARJ-55 45.0 0 100 450 012.250 8.625 ARJ-55 24.0 0 1015 675 0

7.875 5.500 J-55 17.0 0 6824 680 0

24. Tubing Record




A) LOWER GR 5006 6706 5006 TO 6706 261 OPENB)C)D)27. Acid, Fracture, Treatment, Cement Squeeze, Etc.




09/27/2014 10/10/2014 24 32.0 37.0 407.0 GAS PUMPING UNITChoke Tbg. Press. Csg. 24 Hr. Oil Gas Water Gas:Oil Well Statussize Flwg. Press. Rate BBL MCF BBL Ratio

SI POW

28a. Production - Interval BDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MethodProduced Date Tested Product on BBL MCF BBL Corr. API Gravity


SI



RECEIVED: Oct. 29,


28b. Production - Interval CDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MethodProduced Date Tested Production BBL MCF BBL Corr. API Gravity


SI

28c. Production - Interval DDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MethodProduced Date Tested Production BBL MCF BBL Corr. API Gravity


SI

29. Disposition of Gas(Sold, used for fuel, vented, etc.)USED ON LEASE

30. Summary of Porous Zones (Include Aquifers): 31. Formation (Log) Markers

Show all important zones of porosity and contents thereof: Cored intervals and all drill-stemtests, including depth interval tested, cushion used, time tool open, flowing and shut-in pressuresand recoveries.

Top

Meas. DepthFormation Top Bottom Descriptions, Contents, etc. Name

UPPER GREEN RIVER 2800MAHOGANY 4212LOWER GREEN RIVER 4989WASATCH 6722

32. Additional remarks (include plugging procedure):Frac material used: 10000 gal HCI Acid, 848343 gal Fr-66 Water, 299088 gal DeltaFracFluid, 844688 lbs White Sand

33. Circle enclosed attachments:

1. Electrical/Mechanical Logs (1 full set req'd.) 2. Geologic Report 3. DST Report 4. Directional Survey

5. Sundry Notice for plugging and cement verification 6. Core Analysis 7 Other:

34. I hereby certify that the foregoing and attached information is complete and correct as determined from all available records (see attached instructions):

Electronic Submission #274440 Verified by the BLM Well Information System.For ULTRA RESOURCES, INC., sent to the Vernal

Name Title(please print) JENNA ANDERSON PERMITTING SPECIALIST

Signature (Electronic Submission) Date 10/28/2014

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 agencyof the United States any false, fictitious or fradulent statements or representations as to any matter within its jurisdiction.

** ORIGINAL ** ORIGINAL ** ORIGINAL ** ORIGINAL ** ORIGINAL ** ORIGINAL ** ORIGINAL **




SI

28c. Production - Interval DDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MethodProduced Date Tested Product on BBL MCF BBL Corr. API Gravity


SI

29. Disposition of Gas(Sold, used forfuel,vented, etc.)USED ON LEASE



TopFormation Top Bottom Descriptions, Contents, etc. Name

Meas. Depth








Name(please print) JENNA ANDERSON Title PERMITTING SPECIALIST




RECEIVED: Oct. 29,




SI

28c. Production - Interval DDate First Test Hours Test Oil Gas Water Oil Gravity Gas Production MethodProduced Date Tested Product on BBL MCF BBL Corr. API Gravity


SI

29. Disposition of Gas(Sold, used forfuel,vented, etc.)USED ON LEASE



TopFormation Top Bottom Descriptions, Contents, etc. Name

Meas. Depth








Name(please print) JENNA ANDERSON Title PERMITTING SPECIALIST




RECEIVED: Oct. 29,


THREE RIVERS FED 3-23-820 GL: 4,744.5, KB: 4,757.0Sec 3, 8S, 20E Uintah County, Utah

Size Weight Grade Depth Sks/CmtConductor 16 45 ARJ-55 100 450

Surface 8 5/8 24 ARJ-55 1015 675Production 5 1/2 17 J-55 6824 680Cement Top 0

ProposedAs IsX

100'

1,015'

6,824'

6,821'PBTD

CBL Top960'

STAGE ZONE 1 ZONE 2 ZONE 3 ZONE 4 ZONE 5 ZONE 6 ZONE 71 6704-6706 6684-6685 6657-6658 6639-6640 6625-6626 6616-6617 6598-65992 6497-6499 6483-6484 6474-6475 6466-6467 6460-6461 6449-6450 6438-64393 6366-6367 6361-6362 6348-6349 6328-6330 6286-6287 6271-6272 6263-62644 6162-6163 6125-6126 6118-6119 6095-6096 6085-6086 6062-6063 6049-60505 5855-5856 5836-5837 5827-5828 5814-5815 5808-5809 5784-5785 5768-57696 5445-5447 5437-5438 5433-5434 5429-5430 5307-5308 5270-5271 5251-52527 5147-5148 5136-5138 5109-5111 5097-5098 5079-5080 5067-5068 5048-5049

Stage Date Av.Rate Av.Press Proppant CleanFluid Tracer Screenout1 09/24/2014 50.0 2,355 138,678 4,297 N2 09/24/2014 22.0 2,501 24,958 4,206 N3 09/24/2014 40.0 2,328 148,768 4,080 N4 09/24/2014 45.0 3,176 188,202 5,128 N5 09/24/2014 49.0 2,590 144,985 3,976 N6 09/25/2014 49.0 3,002 82,599 2,348 N7 09/25/2014 48.0 2,075 116,498 3,688 N

Totals: 844,688 27,723

Actual Formation or Depth Top Sand Type AmountGross Sand DrilledGross Sand Logged

Net SandNet Pay

Move In Spud Date TD Date Rig Release 1st Prod Full Sales08/11/2014 08/23/2014 08/25/2014 08/26/2014 09/27/2014


Proposed THREE RIVERS FED 3-23-820 GL: 4,744.5, KB: 4,757.0x As is Sec 3, 8S, 20E Uintah County, Utah



STAGE ZONE 1 ZONE 2 ZONE 3 ZONE 4 ZONE 5 ZONE 6 ZONE 7

k 2404 40

49 0 5 6

4100. 3 6366-6367 6361-6362 6348-6349 6328-6330 6286-6287 6271-6272 6263-6264

4 6162-6163 6125-6126 6118-6119 6095-6096 6085-6086 6062-6063 6049-60505 5855-5856 5836-5837 5827-5828 5814-5815 5808-5809 5784-5785 5768-57696 5445-5447 5437-5438 5433-5434 5429-5430 5307-5308 5270-5271 5251-52527 5147-5148 5136-5138 5109-5111 5097-5098 5079-5080 5067-5068 5048-5049

Stage Date Av.Rate Av.Press Proppant CleanFluid Tracer Screenout1 09/24/2014 50.0 2,355 138,678 4,297 N

1,015' 2 09/24/2014 22.0 2,501 24,958 4,206 N3 09/24/2014 40.0 2,328 148,768 4,080 N4 09/24/2014 45.0 3,176 188,202 5,128 N5 09/24/2014 49.0 2,590 144,985 3,976 N6 09/25/2014 49.0 3,002 82,599 2,348 N7 09/25/2014 48.0 2,075 116,498 3,688 N

Totals: 844,688 27,723


Net SandNet Pay

Move In Spud Date TD Date Rio Release 1st Prod Full Sales08/11/2014 08/23/2014 08/25/2014 08/26/2014 09/27/2014

CBL Top960'

PBTD 6,6828124'

RECEIVED: Oct. 29,


Proposed THREE RIVERS FED 3-23-820 GL: 4,744.5, KB: 4,757.0x As is Sec 3, 8S, 20E Uintah County, Utah



STAGE ZONE 1 ZONE 2 ZONE 3 ZONE 4 ZONE 5 ZONE 6 ZONE 7

k 2404 40

49 0 5 6

4100. 3 6366-6367 6361-6362 6348-6349 6328-6330 6286-6287 6271-6272 6263-6264

4 6162-6163 6125-6126 6118-6119 6095-6096 6085-6086 6062-6063 6049-60505 5855-5856 5836-5837 5827-5828 5814-5815 5808-5809 5784-5785 5768-57696 5445-5447 5437-5438 5433-5434 5429-5430 5307-5308 5270-5271 5251-52527 5147-5148 5136-5138 5109-5111 5097-5098 5079-5080 5067-5068 5048-5049

Stage Date Av.Rate Av.Press Proppant CleanFluid Tracer Screenout1 09/24/2014 50.0 2,355 138,678 4,297 N

1,015' 2 09/24/2014 22.0 2,501 24,958 4,206 N3 09/24/2014 40.0 2,328 148,768 4,080 N4 09/24/2014 45.0 3,176 188,202 5,128 N5 09/24/2014 49.0 2,590 144,985 3,976 N6 09/25/2014 49.0 3,002 82,599 2,348 N7 09/25/2014 48.0 2,075 116,498 3,688 N

Totals: 844,688 27,723


Net SandNet Pay

Move In Spud Date TD Date Rio Release 1st Prod Full Sales08/11/2014 08/23/2014 08/25/2014 08/26/2014 09/27/2014

CBL Top960'

PBTD 6,6828124'

RECEIVED: Oct. 29,



ULTRA RESOURCES, INCLocat>on Three Rivers Siel Three Rivers Fed 3 23 820 (1536 FSL & 129Œ FWL)

Feld UINTAMCOUNTY Well Three Rrvers Fed 3 23 820Feedily Sec 03 TSS R20E Wetbare Three Rivers Fed 323820 PWS

PETROLEUM-

500 -

1000 •

so--a Easting (ft)O 200 400 600I I I I1500 -

• 600Three Rivers Fed 3-23420

Top of Production2022' FSL & 1987 FWL2000 -

Three Rivers Fed 3-23-820BHL

1980' FSL & 1994' FWL

2500 -

2ooTop Green River: 18 86" inc.2800.00ft MD.2758 32ft TVD, 307.81ft VS

hree Rivers Fed 3-23-820SHL:

(1536' FSL & 1296' FWL) • ©

2 3500 -

J-

-200

4000 -

ahogany 13.79° Inc, 4212 00ft MD,4103 40ft TVD, 733.71ft VS

4500 -

Lower Green River 3.14' Inc. 4898 00ft MD,4779.71ft TVD.84303ft VSTop ofProducton 0 64' Inc. 5006 00ft MD.4887 64ft TVD, 846 40ft VS5000 -

5500 -

6000 •

lill11t!O 500 1000 1500 2000 2500 3000 3500Vertical Section (ft) '**·""°"

Mmuth 53 95· wathreference0 00 N, 0.00


ULTRA RESOURCES, INCLocat>on Three Rivers Siel Three Rivers Fed 3 23 820 (1536 FSL & 129Œ FWL)

Feld UINTAMCOUNTY Well Three Rrvers Fed 3 23 820Feedily Sec 03 TSS R20E Wetbare Three Rivers Fed 323820 PWS

PETROLEUM-

500 -

1000 •

so--a Easting (ft)O 200 400 600I I I I1500 -

• 600Three Rivers Fed 3-23420

Top of Production2022' FSL & 1987 FWL2000 -

Three Rivers Fed 3-23-820BHL

1980' FSL & 1994' FWL

2500 -

2ooTop Green River: 18 86" inc.2800.00ft MD.2758 32ft TVD, 307.81ft VS

hree Rivers Fed 3-23-820SHL:

(1536' FSL & 1296' FWL) • ©

2 3500 -

J-

-200

4000 -

ahogany 13.79° Inc, 4212 00ft MD,4103 40ft TVD, 733.71ft VS

4500 -

Lower Green River 3.14' Inc. 4898 00ft MD,4779.71ft TVD.84303ft VSTop ofProducton 0 64' Inc. 5006 00ft MD.4887 64ft TVD, 846 40ft VS5000 -

5500 -

6000 •

lill11t!O 500 1000 1500 2000 2500 3000 3500Vertical Section (ft) '**·""°"

Mmuth 53 95· wathreference0 00 N, 0.00



Page l of 5

Actual Wellpath Report DYNAMICThree Rivers Fed 3-23-820 AWP GRAPHICS,INC.Page 1of 5

PETROLEUM

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area hree Rivers Well hree Rivers Fed 3-23-820Field UINTAH COUNTY Wellbore Three Rivers Fed 3-23-820 AWBFacility ec.03-T8S-R20E

REPORT SETUP INFORMATIONProjection System NAD83 / Lambert Utah SP, Central Zone (4302), Sofhvare System WellArchitect®3.0.0

US feetNorth Reference True User EwilliamsScale 0.999914 Report Generated 10/26/2014 at 8:27:13 PMConvergence at slot 1.18 East Database/Source file WellArchitectDBffhree Rivers Fed 3-23-820 AWB.xml


Northlft! Eastjft! Easting|US ft| Northing|US ft! Latitude LongitudeSlotLocation -1672.71 -871.28 2154854.94 7228184.77 40°08'55.350"N 109°39'34.210"WFacility Reference Pt 2\55691.49 7229874.94 40°09'11.880"N 109°39'22.990"WField Reference Pt 2156630.96 7236613.42 40°10'l8.270"N 109°39'09.100"W

WELLPATH DATUMCalculation method Minimum curvature Ensign 122 (RT) to Facility Vertical Datum 4756.00ftHorizontal Reference Pt Slot Ensign 122 (RT) to Mean Sea Level 4756.00ftVertical Reference Pt Ensign 122 (RT) Ensign I22 (RT) to Mud Line at Slot (Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)) 4756.00ftMD Reference Pt Ensign 122 (RT) Section Origin N 0.00, E 0.00 ftField Vertical Reference Mean Sea Level Section Azimuth 53.95*


Page l of 5

Actual Wellpath Report DYNAMICThree Rivers Fed 3-23-820 AWP GRAPHICS,INC.Page 1of 5

PETROLEUM

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area hree Rivers Well hree Rivers Fed 3-23-820Field UINTAH COUNTY Wellbore Three Rivers Fed 3-23-820 AWBFacility ec.03-T8S-R20E

REPORT SETUP INFORMATIONProjection System NAD83 / Lambert Utah SP, Central Zone (4302), Sofhvare System WellArchitect®3.0.0

US feetNorth Reference True User EwilliamsScale 0.999914 Report Generated 10/26/2014 at 8:27:13 PMConvergence at slot 1.18 East Database/Source file WellArchitectDBffhree Rivers Fed 3-23-820 AWB.xml


Northlft! Eastjft! Easting|US ft| Northing|US ft! Latitude LongitudeSlotLocation -1672.71 -871.28 2154854.94 7228184.77 40°08'55.350"N 109°39'34.210"WFacility Reference Pt 2\55691.49 7229874.94 40°09'11.880"N 109°39'22.990"WField Reference Pt 2156630.96 7236613.42 40°10'l8.270"N 109°39'09.100"W

WELLPATH DATUMCalculation method Minimum curvature Ensign 122 (RT) to Facility Vertical Datum 4756.00ftHorizontal Reference Pt Slot Ensign 122 (RT) to Mean Sea Level 4756.00ftVertical Reference Pt Ensign 122 (RT) Ensign I22 (RT) to Mud Line at Slot (Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)) 4756.00ftMD Reference Pt Ensign 122 (RT) Section Origin N 0.00, E 0.00 ftField Vertical Reference Mean Sea Level Section Azimuth 53.95*


Sundry Number: 57148 API Well Number: 43047539530000Sundry Number: 57148 API Well Number: 43047539530000Page 2 of 5

Actual Wellpath Report DYNAMICThree Rivers Fed 3-23-820 AWP GRAPHICS,INC.Page 2 of 5

PETROLEUPI

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area Three Rivers Well hree Rivers Fed 3-23-820'ield UINTAH COUNTY Wellbore hree Rivers Fed 3-23-820 AWBacility Sec.03-T8S-R20E

WELLPATH DATA (75 stations) † = interpolatedlextrapolated stationMD inclination Azimuth TVD Vert Sect North East Latitude Longitude DLS .ommentse o o

0. 0.0 104,50 0.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.0013.00 0.00 104.50 13.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

100.00 0.00 0.00 100.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001015.00 0.00 0. 1015.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001042.00 0.70 104.50 1042.00 0.10 -0.04 0.16 40°08'55.350"N 109°39'34.208"W 2.591133.00 0.7 115. 1132.99 0.72 -0.42 1.20 40°08'55.346"N 109°39'34.195"W 0.151223.00 0.7 109.5 1222.99 1.29 -0.85 2.21 40°08'55.342"N 109°39'34.182"W 0.091314.00 1.60 90. 1313.97 2.62 -1.05 4.00 40°08'55.340"N 109°39'34.158"W 1.061405.00 1.8 74.50 1404.93 4.97 -0.69 6.65 40°08'55.343"N 109°39'34.124"W 0.581495.00 3.4 64.50 1494.83 8 92 0.84 10.42 40°08'55.358"N 109°39'34.076"W 1.841586.00 4.70 58.2 1585.60 15.29 3.96 16.03 40°08'55.389"N 109°39'34.004"W l.511676.00 5.00 63.30 1675.28 22.84 7.67 22.67 40°08'55.426"N 109°39'33.918"W 0.581767.00 6.2 64.00 1765.85 31.59 11.60 30 63 40°08'55.465"N 109°39'33.816"W 1.321858.00 8.6 59.30 1856.08 43.20 17.23 40.89 40°08'55.520"N 109°39'33.683"W 2.721948.00 10.60 51.70 1944.82 58.18 25 80 53 18 40°08'55.605"N 109°39'33.525"W 2.632039.00 12.30 51.50 2034.01 76.23 37.02 67.33 40°08'55.716"N 109°39'33.343"W 1.872129.00 14.40 50.0 2121.57 96.97 50 18 83.41 40°08'55.846"N 109°39'33.136"W 2.362220.00 16.40 51.3 2209.30 121.09 65.49 102.11 40°08'55.997"N 109°39'32.895"W 2.232310.00 18.30 50.70 2295.20 147.90 82 39 122.96 40°08'56.164"N 109°39'32.627"W 2.122401.00 18.7 50.50 2381.50 176.72 100.71 145.27 40°08'56.345"N 109°39'32.339"W 0.452491.00 19.3 50.8 2466.59 205.97 119.29 167.93 40°08'56.529"N 109°39'32.047"W 0.682582.00 19.30 52.90 2552.48 236.03 137.87 191.58 40°08'56.712"N 109°39'31.743"W 0.762673.00 19.50 55.00 2638.31 266.25 155.65 216.01 40°08'56.888"N 109°39'31.428"W 0.802763.00 18. 55.2 2723.31 295.84 172.59 240.29 40°08'57.056"N 109°3931.116"W 0.672800.0 18.85 54.87 2758.32 307.81 179.45 250.10 40°08'57.123"N 109°39'30.989"W 0.30 o Green River2854.00 18.80 54.40 2809.43 325.24 189.53 264.31 40°08'57.223"N 109°39'30.806"W 0.302944.00 17.80 52.40 2894.88 353.49 206.37 287.00 40°08'57.389"N 109°39'30.514"W L313035.00 17.8 52.90 2981.52 381.30 223.25 309.12 40°08'57.556"N 109°39'30.229"W 0.173126.00 18.20 54. 3068.07 409.42 239.99 331.71 40°08'57.722"N 109°39'29.938"W 0.583216.00 19.90 54.30 3153.13 438.79 257.19 355.52 40°08'57.892"N 109°39'29.632"W 1.893307.00 20.3 54.60 3238.59 470.07 275.37 380.96 40°08'58.07]"N 109°39'29.304"W 0.453397.00 19.7 53.7 3323.16 500.85 293.40 405.92 40°08'58.249"N 109°39'28.983"W 0.753488.00 19.00 52.80 3409.02 530.99 311.43 430.08 40°08'58.428"N 109°39'28.672"W 0.843578.00 19.60 54.10 3493.96 560.74 329.14 453.97 40°08'58.603"N 109°39'28.364"W 0.823669.00 19.3 53.1 3579.77 591.04 347.12 478.36 40°08'58.780"N 109°39'28.050"W 0.493760.00 17.2 51.2 3666.19 619.52 364.58 500.88 40°08'58.953"N 109°39'27.760"W 2.403850.00 15.30 50.50 3752.59 644.66 380.48 520.41 40°08'59.110"N 109°39'27.508"W 2.123941.00 15.40 50.60 3840.34 668.71 395.78 539.01 40°08'59.261"N 109°39'27.269"W 0.114031.00 14.10 52.2 3927.38 691.60 410.09 556.91 40°08'59.402"N 109°39'27.038"W 1.514122.00 13. 57. 4015.85 712.90 422.46 574.26 40°08'59.525"N 109°39'26.815"W I.734212.00 13.791 57.69 4103.40 733.71 433.70 591.81 40°08'59.636"N 109°39'26.589"W 0.90 ahogany4213.00 13.80 57.70 4104.37 733.95 433 83 592.01 40°08'59.637"N 109°39'26.586"W 0.904303.00 12.50 59.5 4192.01 754.36 444.51 609.48 40°08'59.743"N 109°39'26.361"W l.514394.00 11.30 60.20 4281.05 773.02 453.94 625.70 40°08'59.836"N 109°39'26.152"W 1.334484.00 9.80 60.80 4369.52 789.39 462.06 640.04 40°08'59.916"N 109°39'25.968"W 1.67

Sundry Number: 57148 API Well Number: 43047539530000Page 2 of 5

Actual Wellpath Report DYNAMICThree Rivers Fed 3-23-820 AWP GRAPHICS,INC.Page 2 of 5

PETROLEUPI

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area Three Rivers Well hree Rivers Fed 3-23-820'ield UINTAH COUNTY Wellbore hree Rivers Fed 3-23-820 AWBacility Sec.03-T8S-R20E

WELLPATH DATA (75 stations) † = interpolatedlextrapolated stationMD inclination Azimuth TVD Vert Sect North East Latitude Longitude DLS .ommentse o o

0. 0.0 104,50 0.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.0013.00 0.00 104.50 13.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.00

100.00 0.00 0.00 100.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001015.00 0.00 0. 1015.00 0.00 0.00 0.00 40°08'55.350"N 109°39'34.210"W 0.001042.00 0.70 104.50 1042.00 0.10 -0.04 0.16 40°08'55.350"N 109°39'34.208"W 2.591133.00 0.7 115. 1132.99 0.72 -0.42 1.20 40°08'55.346"N 109°39'34.195"W 0.151223.00 0.7 109.5 1222.99 1.29 -0.85 2.21 40°08'55.342"N 109°39'34.182"W 0.091314.00 1.60 90. 1313.97 2.62 -1.05 4.00 40°08'55.340"N 109°39'34.158"W 1.061405.00 1.8 74.50 1404.93 4.97 -0.69 6.65 40°08'55.343"N 109°39'34.124"W 0.581495.00 3.4 64.50 1494.83 8 92 0.84 10.42 40°08'55.358"N 109°39'34.076"W 1.841586.00 4.70 58.2 1585.60 15.29 3.96 16.03 40°08'55.389"N 109°39'34.004"W l.511676.00 5.00 63.30 1675.28 22.84 7.67 22.67 40°08'55.426"N 109°39'33.918"W 0.581767.00 6.2 64.00 1765.85 31.59 11.60 30 63 40°08'55.465"N 109°39'33.816"W 1.321858.00 8.6 59.30 1856.08 43.20 17.23 40.89 40°08'55.520"N 109°39'33.683"W 2.721948.00 10.60 51.70 1944.82 58.18 25 80 53 18 40°08'55.605"N 109°39'33.525"W 2.632039.00 12.30 51.50 2034.01 76.23 37.02 67.33 40°08'55.716"N 109°39'33.343"W 1.872129.00 14.40 50.0 2121.57 96.97 50 18 83.41 40°08'55.846"N 109°39'33.136"W 2.362220.00 16.40 51.3 2209.30 121.09 65.49 102.11 40°08'55.997"N 109°39'32.895"W 2.232310.00 18.30 50.70 2295.20 147.90 82 39 122.96 40°08'56.164"N 109°39'32.627"W 2.122401.00 18.7 50.50 2381.50 176.72 100.71 145.27 40°08'56.345"N 109°39'32.339"W 0.452491.00 19.3 50.8 2466.59 205.97 119.29 167.93 40°08'56.529"N 109°39'32.047"W 0.682582.00 19.30 52.90 2552.48 236.03 137.87 191.58 40°08'56.712"N 109°39'31.743"W 0.762673.00 19.50 55.00 2638.31 266.25 155.65 216.01 40°08'56.888"N 109°39'31.428"W 0.802763.00 18. 55.2 2723.31 295.84 172.59 240.29 40°08'57.056"N 109°3931.116"W 0.672800.0 18.85 54.87 2758.32 307.81 179.45 250.10 40°08'57.123"N 109°39'30.989"W 0.30 o Green River2854.00 18.80 54.40 2809.43 325.24 189.53 264.31 40°08'57.223"N 109°39'30.806"W 0.302944.00 17.80 52.40 2894.88 353.49 206.37 287.00 40°08'57.389"N 109°39'30.514"W L313035.00 17.8 52.90 2981.52 381.30 223.25 309.12 40°08'57.556"N 109°39'30.229"W 0.173126.00 18.20 54. 3068.07 409.42 239.99 331.71 40°08'57.722"N 109°39'29.938"W 0.583216.00 19.90 54.30 3153.13 438.79 257.19 355.52 40°08'57.892"N 109°39'29.632"W 1.893307.00 20.3 54.60 3238.59 470.07 275.37 380.96 40°08'58.07]"N 109°39'29.304"W 0.453397.00 19.7 53.7 3323.16 500.85 293.40 405.92 40°08'58.249"N 109°39'28.983"W 0.753488.00 19.00 52.80 3409.02 530.99 311.43 430.08 40°08'58.428"N 109°39'28.672"W 0.843578.00 19.60 54.10 3493.96 560.74 329.14 453.97 40°08'58.603"N 109°39'28.364"W 0.823669.00 19.3 53.1 3579.77 591.04 347.12 478.36 40°08'58.780"N 109°39'28.050"W 0.493760.00 17.2 51.2 3666.19 619.52 364.58 500.88 40°08'58.953"N 109°39'27.760"W 2.403850.00 15.30 50.50 3752.59 644.66 380.48 520.41 40°08'59.110"N 109°39'27.508"W 2.123941.00 15.40 50.60 3840.34 668.71 395.78 539.01 40°08'59.261"N 109°39'27.269"W 0.114031.00 14.10 52.2 3927.38 691.60 410.09 556.91 40°08'59.402"N 109°39'27.038"W 1.514122.00 13. 57. 4015.85 712.90 422.46 574.26 40°08'59.525"N 109°39'26.815"W I.734212.00 13.791 57.69 4103.40 733.71 433.70 591.81 40°08'59.636"N 109°39'26.589"W 0.90 ahogany4213.00 13.80 57.70 4104.37 733.95 433 83 592.01 40°08'59.637"N 109°39'26.586"W 0.904303.00 12.50 59.5 4192.01 754.36 444.51 609.48 40°08'59.743"N 109°39'26.361"W l.514394.00 11.30 60.20 4281.05 773.02 453.94 625.70 40°08'59.836"N 109°39'26.152"W 1.334484.00 9.80 60.80 4369.52 789.39 462.06 640.04 40°08'59.916"N 109°39'25.968"W 1.67



Page 3 of 5

Actual Wellpath Report DYNAMICThree RiversaFe3d 3-23-820 AWP GRAPHICS,INC.PETROl£UPI

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC lot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area three Rivers ell Three Rivers Fed 3-23-820Field UINTAH COUNTY ellbore Three Rivers Fed 3-23-820 AWBFacility Sec.03-T8S-R20E

WELLPA TH DATA (75 statio: sì † = it terpolater lextrapt lated st: tionMD Inclination Azimuth TVD Vert Sect North East Latitude Longitude DLS TommentsIft! (°i !©l lift (fli ift! tirl 1°fl00fr1

4575.00 9.900 59.600 4459.18 804.87 469.80 653.55 40°08'59.992"N 109°39'25.794"W 0.254665.00 8.600 56.800 4548.01 819.29 477.40 665.85 40°09'00.068"N 109°39'25.635"W l.534756.00 6.400 51.400 4638.23 831.15 484.29 675.51 40°09'00.136"N 109°39'25.511"W 2.544847.00 4.400 49.300 4728.82 839.70 489.73 682.12 40°09'00.\89"N 109°39'25.426"W 2.214898.001 3.14: 45.90( 4779.71 843.03 491.98 684.61 40°09'00.212"N 109°39'25.394"W 2.50 .ower Green River4937.00 2.20( 40.700 4818.67 844.82 493.29 685.87 40°09'00.225"N 109°39'25.378"W 2.505006.004 0.63; 12.385 4887.64 846.40 494.67 686.81 40°09'00.238"N 109°39'25.365"W 2.42 lopofProduction5028.00 0.40C 316.100 4909.64 846.48 494.84 686.78 40°09'00.240"N 109°39'25.366"W 2.425118.00 0.300 227.700 4999.64 846.20 494.91 686.39 40°09'00.241"N 109°39'25.371"W 0.555209.00 1.100 217.600 5090.63 845.13 494.06 685.68 40°09'00.232"N 109°39'25.380"W 0.895300.00 1.500 197.100 5181.61 843.34 492.23 684.80 40°09'00.214"N 109°39'25.391"W 0.675390.00 1.600 200.300 5271.58 841.35 489.92 684.02 40°09'00.191"N 109°39'25.401"W 0.155481.00 1.300 187.100 5362.55 839.58 487.71 683.45 40°09'00.169"N 109°39'25.409"W 0.495571.00 1.100 187.900 5452.53 838.29 485.84 683.20 40°09'00.151"N 109°39'25.412"W 0.225662.00 1.500 189.000 5543.51 836.84 483.80 682.90 40°09'00.131"N 109°39'25.416"W 0.445752.00 1.500 195.20E 5633.47 835.08 481.50 682.41 40°09'00.108"N 109°39'25.422"W 0.185843.00 1.600 187.90( 5724.44 833.27 479.09 681.92 40°09'00.084"N 109°39'25.428"W 0.245933.00 1.60C 170.100 5814,41 831.85 476.61 681.96 40°09'00.060"N 109°39'25.428"W 0.556024.00 1.700 167.600 5905.37 830.75 474.04 682.47 40°09'00.034"N 109°39'25.421"W 0.146115.00 1.50C 172.60( 5996.33 829.63 471.54 682.91 40°09'00.010"N 109°39'25.416"W 0.276205.00 1.700 153.500 6086.30 828.85 469.17 683.66 40°08'59.986"N 109°39'25.406"W 0.636296.00 1.800 163.400 6177.26 828.15 466.60 684.67 40°08'59.961"N 109°39'25.393"W 0.356386.00 1.800 130.600 6267.21 828.00 464.32 686.15 40°08'59.938"N 109°39'25.374"W 1.136477.00 1.900 134.50( 6358.17 828.58 462.33 688.31 40°08'59.919"N 109°39'25.346"W 0.186567.00 1.800 148.900 6448.12 828.71 460.08 690.10 40°08'59.896"N 109°39'25.323"W 0.536658.00 1.900 158.700 6539.07 828.20 457.45 691.39 40°08'59.870"N 109°39'25.306"W 0.366722.001 1.686 155.934 6603.04 827.73 455.60 692.16 40°08'59.852"N 109°39'25.296"W 0.36 Wasatch6748.00 l.60f 154.600 6629.03 827.59 454.92 692.47 40°08'59.845"N 109°39'25.292"W 0.366790.00 1.600 166.40( 6671.02 827.25 453.82 692.86 40°08'59.835"N 109°39'25.287"W 0.78 'inal Survey6840.00 1.60C 166.400 6721.00 826.72 452.47 693.19 40°08'59.821"N 109°39'25.283"W 0.00 'rojection To Bit

10/26/20


Page 3 of 5

Actual Wellpath Report DYNAMICThree RiversaFe3d 3-23-820 AWP GRAPHICS,INC.PETROl£UPI

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC lot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area three Rivers ell Three Rivers Fed 3-23-820Field UINTAH COUNTY ellbore Three Rivers Fed 3-23-820 AWBFacility Sec.03-T8S-R20E

WELLPA TH DATA (75 statio: sì † = it terpolater lextrapt lated st: tionMD Inclination Azimuth TVD Vert Sect North East Latitude Longitude DLS TommentsIft! (°i !©l lift (fli ift! tirl 1°fl00fr1

4575.00 9.900 59.600 4459.18 804.87 469.80 653.55 40°08'59.992"N 109°39'25.794"W 0.254665.00 8.600 56.800 4548.01 819.29 477.40 665.85 40°09'00.068"N 109°39'25.635"W l.534756.00 6.400 51.400 4638.23 831.15 484.29 675.51 40°09'00.136"N 109°39'25.511"W 2.544847.00 4.400 49.300 4728.82 839.70 489.73 682.12 40°09'00.\89"N 109°39'25.426"W 2.214898.001 3.14: 45.90( 4779.71 843.03 491.98 684.61 40°09'00.212"N 109°39'25.394"W 2.50 .ower Green River4937.00 2.20( 40.700 4818.67 844.82 493.29 685.87 40°09'00.225"N 109°39'25.378"W 2.505006.004 0.63; 12.385 4887.64 846.40 494.67 686.81 40°09'00.238"N 109°39'25.365"W 2.42 lopofProduction5028.00 0.40C 316.100 4909.64 846.48 494.84 686.78 40°09'00.240"N 109°39'25.366"W 2.425118.00 0.300 227.700 4999.64 846.20 494.91 686.39 40°09'00.241"N 109°39'25.371"W 0.555209.00 1.100 217.600 5090.63 845.13 494.06 685.68 40°09'00.232"N 109°39'25.380"W 0.895300.00 1.500 197.100 5181.61 843.34 492.23 684.80 40°09'00.214"N 109°39'25.391"W 0.675390.00 1.600 200.300 5271.58 841.35 489.92 684.02 40°09'00.191"N 109°39'25.401"W 0.155481.00 1.300 187.100 5362.55 839.58 487.71 683.45 40°09'00.169"N 109°39'25.409"W 0.495571.00 1.100 187.900 5452.53 838.29 485.84 683.20 40°09'00.151"N 109°39'25.412"W 0.225662.00 1.500 189.000 5543.51 836.84 483.80 682.90 40°09'00.131"N 109°39'25.416"W 0.445752.00 1.500 195.20E 5633.47 835.08 481.50 682.41 40°09'00.108"N 109°39'25.422"W 0.185843.00 1.600 187.90( 5724.44 833.27 479.09 681.92 40°09'00.084"N 109°39'25.428"W 0.245933.00 1.60C 170.100 5814,41 831.85 476.61 681.96 40°09'00.060"N 109°39'25.428"W 0.556024.00 1.700 167.600 5905.37 830.75 474.04 682.47 40°09'00.034"N 109°39'25.421"W 0.146115.00 1.50C 172.60( 5996.33 829.63 471.54 682.91 40°09'00.010"N 109°39'25.416"W 0.276205.00 1.700 153.500 6086.30 828.85 469.17 683.66 40°08'59.986"N 109°39'25.406"W 0.636296.00 1.800 163.400 6177.26 828.15 466.60 684.67 40°08'59.961"N 109°39'25.393"W 0.356386.00 1.800 130.600 6267.21 828.00 464.32 686.15 40°08'59.938"N 109°39'25.374"W 1.136477.00 1.900 134.50( 6358.17 828.58 462.33 688.31 40°08'59.919"N 109°39'25.346"W 0.186567.00 1.800 148.900 6448.12 828.71 460.08 690.10 40°08'59.896"N 109°39'25.323"W 0.536658.00 1.900 158.700 6539.07 828.20 457.45 691.39 40°08'59.870"N 109°39'25.306"W 0.366722.001 1.686 155.934 6603.04 827.73 455.60 692.16 40°08'59.852"N 109°39'25.296"W 0.36 Wasatch6748.00 l.60f 154.600 6629.03 827.59 454.92 692.47 40°08'59.845"N 109°39'25.292"W 0.366790.00 1.600 166.40( 6671.02 827.25 453.82 692.86 40°08'59.835"N 109°39'25.287"W 0.78 'inal Survey6840.00 1.60C 166.400 6721.00 826.72 452.47 693.19 40°08'59.821"N 109°39'25.283"W 0.00 'rojection To Bit

10/26/20



Page 4 of 5

Actual Wellpath Report DYNAMICThree Rivers Fed 3-23-820 AWP GRAPHICS,INC.Page 4 of5PETROlÆUlit

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot hree Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area Three Rivers Well hree Rivers Fed 3-23-820Field UINTAH COUNTY Wellbore hree Rivers Fed 3-23-820 AWBFacility Sec.03-T8S-R20E

TARGETSName MD TVD North East Grid East Grid North Latitude Longitude Shapetal iiti irti ift! Its it; ¡Us niThree Rivers Fed 3-23-820 Driller's 4700.00 500.34 687.46 2155531.90 7228699.10 40°09'00.294"N 109°39'25.357"W circleTarget Radius: 5' 2028' FSL &1998' FWLThree Rivers Fed 3-23-820 Target 4700.00 452.34 679.46 2155524.89 7228650.96 40°08'59.820"N 109°39'25.460"W circleOn Plat Radius: 50' 1980' FSL &1980' FWLTarget Box 400' By 400' Center @ 4886.00 452.34 679.46 2 I55524.89 7228650.95 40°08'59.820"N 109°39'25.460"W point1980' FSL & 1980' FWL

WELLPATH COMPOSITION - Ref Wellbore: Three Rivers Fed 3.23-820 AWB Ref Wellpath: Three Rivers Fed 3-23-820 AWPStart MD End MD Positional Uncertainty Model Log Name/Comment Wellbore

13.00 100.00 Unknown Tool (Standard) Conductor Three Rivers Fed 3-23-820 AWB100.00 1015.00 Unknown Tool (Standard) Surface Three Rivers Fed 3-23-820 AWB1015.00 6790.00 MTC (Collar, post-2000)(Standard) MWD Three Rivers Fed 3-23-820AWB6790.00 6840.00 Blind Drilling(std) Projection to bit Three Rivers Fed 3-23-820AWB


Page 4 of 5

Actual Wellpath Report DYNAMICThree Rivers Fed 3-23-820 AWP GRAPHICS,INC.Page 4 of5PETROlÆUlit

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot hree Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area Three Rivers Well hree Rivers Fed 3-23-820Field UINTAH COUNTY Wellbore hree Rivers Fed 3-23-820 AWBFacility Sec.03-T8S-R20E

TARGETSName MD TVD North East Grid East Grid North Latitude Longitude Shapetal iiti irti ift! Its it; ¡Us niThree Rivers Fed 3-23-820 Driller's 4700.00 500.34 687.46 2155531.90 7228699.10 40°09'00.294"N 109°39'25.357"W circleTarget Radius: 5' 2028' FSL &1998' FWLThree Rivers Fed 3-23-820 Target 4700.00 452.34 679.46 2155524.89 7228650.96 40°08'59.820"N 109°39'25.460"W circleOn Plat Radius: 50' 1980' FSL &1980' FWLTarget Box 400' By 400' Center @ 4886.00 452.34 679.46 2 I55524.89 7228650.95 40°08'59.820"N 109°39'25.460"W point1980' FSL & 1980' FWL

WELLPATH COMPOSITION - Ref Wellbore: Three Rivers Fed 3.23-820 AWB Ref Wellpath: Three Rivers Fed 3-23-820 AWPStart MD End MD Positional Uncertainty Model Log Name/Comment Wellbore

13.00 100.00 Unknown Tool (Standard) Conductor Three Rivers Fed 3-23-820 AWB100.00 1015.00 Unknown Tool (Standard) Surface Three Rivers Fed 3-23-820 AWB1015.00 6790.00 MTC (Collar, post-2000)(Standard) MWD Three Rivers Fed 3-23-820AWB6790.00 6840.00 Blind Drilling(std) Projection to bit Three Rivers Fed 3-23-820AWB



Page 5 of 5

Actual Wellpath Report DYNAMICThree Rivers Fed 3-23-820 AWP GRAPHICS,INC.Page 5 of5

PETROLEUM

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area hree Rivers Well hree Rivers Fed 3-23-820Field INTAH COUNTY ellbore Three Rivers Fed 3-23-820 AWBFacility ec.03-T8S-R20E

WELLPATH COMMENTSMD Inclination Azimuth TVD Comment

2800.00 18.859 54.876 2758.32 Top Green River4212.00 13.791 57.693 4103.40 Mahogany4898.00 3.145 45.900 4779.71 Lower Green River5006.00 0.637 12.382 4887.64 Top of Production6722.00 1.686 155.934 6603.04 Wasatch6790.00 1.60C 166.400 6671.02 Final Survey6840.00 1 600 166.400 6721.00 Projection To Bit


Page 5 of 5

Actual Wellpath Report DYNAMICThree Rivers Fed 3-23-820 AWP GRAPHICS,INC.Page 5 of5

PETROLEUM

REFERENCE WELLPATH IDENTIFICATIONOperator ULTRA RESOURCES, INC Slot Three Rivers Fed 3-23-820 (1536' FSL & 1296' FWL)Area hree Rivers Well hree Rivers Fed 3-23-820Field INTAH COUNTY ellbore Three Rivers Fed 3-23-820 AWBFacility ec.03-T8S-R20E

WELLPATH COMMENTSMD Inclination Azimuth TVD Comment

2800.00 18.859 54.876 2758.32 Top Green River4212.00 13.791 57.693 4103.40 Mahogany4898.00 3.145 45.900 4779.71 Lower Green River5006.00 0.637 12.382 4887.64 Top of Production6722.00 1.686 155.934 6603.04 Wasatch6790.00 1.60C 166.400 6671.02 Final Survey6840.00 1 600 166.400 6721.00 Projection To Bit



ULTRA RESOURCES, INC.DAILY COMPLETION REPORT FOR 08/28/2014 TO 09/29/2014

Well Name THREE RIVERS FED 3-23-820 Fracs Planned 7Location: UINTAH County, UTAH(NWSW 3 8S 20E) AFE# 140627Total Depth Date: 08/25/2014 TD 6,840 Formation: (Missing)Production Casing: Size 5 1/2 Wt 17 Grade J-55 Set At 6,824 GL: KB: 4,757

Date: 08/28/2014Supervisor: DuncanWork Objective: Flow test wellContractors: R&R,RheetsCompletion Rig: (Missing) Supervisor Phone: 435-828-1472Upcoming Activity: Turned over to Production DeptCosts ($): Daily: 0 Cum: 2,127 AFE: 948,500

Date: 09/03/2014Supervisor: (Missing)Work Objective: (Nothing Recorded)Contractors: (Missing)Completion Rig: (Missing) Supervisor Phone: (Missing)Upcoming Activity:Costs ($): Daily: 1,000 Cum: 3,127 AFE: 948,500


Date: 09/09/2014Supervisor: StringhamWork Objective: RIH w/ gauge ring and bond log SSE: 2Contractors: Casedhole SolutionsCompletion Rig: Casedhole Sol Supervisor Phone: 435-790-2326Upcoming Activity: RIH w/ gauge ring and bond logActivities1215-1230 Safety Meeting-Review location hazards including ,WHD, WL crane operations, overhead objects, the use of

land guides while backing. Review incident reporting of property damage, & personnel injuries. Slips trips andfalls, Establish smoking area & Muster area.

1340-1420 Swing Gauge Ring From TR_3-13-820. Run 4.65" gauge ring fr/surface to 6739'. POOH w/gauge ring. RunBond Log 9/10/14

Costs ($): Daily: 3,957 Cum: 8,584 AFE: 948,500

Date: 09/10/2014Supervisor: StringhamWork Objective: RIH w/ gauge ring and bond logContractors: Casedhole SolutionsCompletion Rig: Casedhole Sol Supervisor Phone: 435-790-2326Upcoming Activity: Prep for frac workActivities0640-0655 Safety Meeting-Review location hazards including ,WHD, WL crane operations, overhead objects, the use of


0655-0900 RIH & Run CBL/GR/CCL fr/6713' to surface. TOC @ 960'. RDMO WLU.Costs ($): Daily: 4,400 Cum: 12,984 AFE: 948,500

Date: 09/11/2014Supervisor: FletcherWork Objective: Prep for frac workContractors: (Missing)Completion Rig: (Missing) Supervisor Phone: 3036459812Upcoming Activity: CompletionCosts ($): Daily: 0 Cum: 12,984 AFE: 948,500



ULTRA RESOURCES, INC.DAILYCOMPLETION REPORT FOR 08/28/2014 TO 09/29/2014

Well Name THREE RIVERS FED 3-23-820 Fracs Planned 7Location: UINTAH County, UTAH(NWSW 3 8S 20E) AFE# 140627Total Depth Date: 08/25/2014 TD 6,840 Formation: (Missinq)Production Casinq: Size 5 1/2 Wt 17 Grade J-55 Set At 6,824 GL: KB: 4,757

Date: 08/28/2014Supervisor: DuncanWork Obiective: Flow test wellContractors: R&R,RheetsCompletion Riq: (Missinq) Supervisor Phone: 435-828-1472Upcominq Activity: Turned over to Production DeptCosts ($): Daily: 0 Cum: 2,127 AFE: 948,500

Date: 09/03/2014Supervisor: (Missinq)Work Objective: (Nothinq Recorded)Contractors: (Missinq)Completion Riq: (Missinq) Supervisor Phone: (Missinq)Upcominq Activity:Costs ($): Daily: 1,000 Cum: 3,127 AFE: 948,500

Date: 09/06/2014Supervisor: (Missinq)Work Objective: (Nothinq Recorded)Contractors: (Missinq)Completion Rig: (Missing) Supervisor Phone: (Missing)Upcominq Activity:Costs ($): Daily: 1,500 Cum: 4,627 AFE: 948,500

Date: 09/09/2014Supervisor: StringhamWork Obiective: RIH w/ gauge ring and bond loq SSE: 2Contractors: Casedhole SolutionsCompletion Riq: Casedhole Sol Supervisor Phone: 435-790-2326Upcominq Activity: RIH w/ qauqe rinq and bond loqActivities1215-1230 Safety Meetinq-Review location hazards includinq ,WHD, WL crane operations, overhead objects, the use of

land quides while backing. Review incident reporting of property damage, & personnel iniuries. Slips trips an dfalls, Establish smokinq area & Muster area.

1340-1420 Swinq Gauge Rinq From TR 3-13-820. Run 4.65" qauqe rinq fr/surface to 6739'. POOH w/qauqe rinq. RunBond Loq 9/10/14


Date: 09/10/2014Supervisor: StringhamWork Objective: RIH w/ qauqe rinq and bond loqContractors: Casedhole SolutionsCompletion Riq: Casedhole Sol Supervisor Phone: 435-790-2326Upcominq Activity: Prep for frac workActivities0640-0655 Safety Meetinq-Review location hazards includinq ,WHD, WL crane operations, overhead objects, the use of

land quides while backing. Review incident reportinq of property damage, & personnel iniuries. Slips trips an dfalls, Establish smokinq area & Muster area.

0655-0900 RIH & Run CBL/GRICCL fr/6713' to surface. TOC @ 960'. RDMO WLU.Costs ($): Daily: 4,400 Cum: 12,984 AFE: 948,500

Date: 09/11/2014Supervisor: FletcherWork Objective: Prep for frac workContractors: (Missinq)Completion Riq: (Missinq) Supervisor Phone: 3036459812Upcoming Activity: CompletionCosts ($): Daily: 0 Cum: 12,984 AFE: 948,500

Date: 09/12/2014Supervisor: (Missinq)Work Objective: (Nothinq Recorded)Contractors: (Missing)Completion Riq: (Missinq) Supervisor Phone: (Missinq)Upcominq Activity:Costs ($): Daily: 1,500 Cum: 14,484 AFE: 948,500

10/28/2014 2:35 PEHREE RIVERS FED 3-23-820 Page 1

RECEIVED: Oct. 29,


ULTRA RESOURCES, INC.DAILYCOMPLETION REPORT FOR 08/28/2014 TO 09/29/2014

Well Name THREE RIVERS FED 3-23-820 Fracs Planned 7Location: UINTAH County, UTAH(NWSW 3 8S 20E) AFE# 140627Total Depth Date: 08/25/2014 TD 6,840 Formation: (Missinq)Production Casinq: Size 5 1/2 Wt 17 Grade J-55 Set At 6,824 GL: KB: 4,757

Date: 08/28/2014Supervisor: DuncanWork Obiective: Flow test wellContractors: R&R,RheetsCompletion Riq: (Missinq) Supervisor Phone: 435-828-1472Upcominq Activity: Turned over to Production DeptCosts ($): Daily: 0 Cum: 2,127 AFE: 948,500


Date: 09/06/2014Supervisor: (Missinq)Work Objective: (Nothinq Recorded)Contractors: (Missinq)Completion Rig: (Missing) Supervisor Phone: (Missing)Upcominq Activity:Costs ($): Daily: 1,500 Cum: 4,627 AFE: 948,500

Date: 09/09/2014Supervisor: StringhamWork Obiective: RIH w/ gauge ring and bond loq SSE: 2Contractors: Casedhole SolutionsCompletion Riq: Casedhole Sol Supervisor Phone: 435-790-2326Upcominq Activity: RIH w/ qauqe rinq and bond loqActivities1215-1230 Safety Meetinq-Review location hazards includinq ,WHD, WL crane operations, overhead objects, the use of

land quides while backing. Review incident reporting of property damage, & personnel iniuries. Slips trips an dfalls, Establish smokinq area & Muster area.

1340-1420 Swinq Gauge Rinq From TR 3-13-820. Run 4.65" qauqe rinq fr/surface to 6739'. POOH w/qauqe rinq. RunBond Loq 9/10/14


Date: 09/10/2014Supervisor: StringhamWork Objective: RIH w/ qauqe rinq and bond loqContractors: Casedhole SolutionsCompletion Riq: Casedhole Sol Supervisor Phone: 435-790-2326Upcominq Activity: Prep for frac workActivities0640-0655 Safety Meetinq-Review location hazards includinq ,WHD, WL crane operations, overhead objects, the use of


0655-0900 RIH & Run CBL/GRICCL fr/6713' to surface. TOC @ 960'. RDMO WLU.Costs ($): Daily: 4,400 Cum: 12,984 AFE: 948,500

Date: 09/11/2014Supervisor: FletcherWork Objective: Prep for frac workContractors: (Missinq)Completion Riq: (Missinq) Supervisor Phone: 3036459812Upcoming Activity: CompletionCosts ($): Daily: 0 Cum: 12,984 AFE: 948,500

Date: 09/12/2014Supervisor: (Missinq)Work Objective: (Nothinq Recorded)Contractors: (Missing)Completion Riq: (Missinq) Supervisor Phone: (Missinq)Upcominq Activity:Costs ($): Daily: 1,500 Cum: 14,484 AFE: 948,500


RECEIVED: Oct. 29,



Date: 09/15/2014Supervisor: Stringham/DuncanWork Objective: Nipple up BOPContractors: Knight, R&R, RNICompletion Rig: (Missing) Supervisor Phone: 435-790-2326/435-828-1472Upcoming Activity: Prep for frac workActivities1000-1130 MINU Knight 5K BOP, set flow back and frac tanks.Costs ($): Daily: 3,242 Cum: 17,726 AFE: 948,500

Date: 09/16/2014Supervisor: Stringham/DuncanWork Objective: Pressure testContractors: RBS, R&R,RNICompletion Rig: (Missing) Supervisor Phone: 435-790-2326/435-828-1472Upcoming Activity: Prep for frac workActivities1030-1100 MIRU RBS Test Unit, and test csg, WH, Flow back lines, and BOP to 4,250 psig, good test. RDMO Testers.Costs ($): Daily: 8,516 Cum: 26,243 AFE: 948,500

Date: 09/17/2014Supervisor: FletcherWork Objective: Prep for frac workContractors: (Missing)Completion Rig: (Missing) Supervisor Phone: 3036459812Upcoming Activity: CompletionActivities0900-1100 Set Up Live Load Manifold0000-0000 Pre Fill Frac TanksCosts ($): Daily: 16,369 Cum: 42,612 AFE: 948,500

Date: 09/18/2014Supervisor: StringhamWork Objective: Prep for frac workContractors: R&R,Sunrise, RNI, TargetCompletion Rig: (Missing) Supervisor Phone: 435-790-2326Upcoming Activity: PerforatingCosts ($): Daily: 0 Cum: 42,612 AFE: 948,500

Date: 09/19/2014Supervisor: StringhamWork Objective: PerforatingContractors: Casedhole Solutions,R&R,RNI,Sunrise,TargetCompletion Rig: Casedhole Sol Supervisor Phone: 435-790-2326Upcoming Activity: Prep for frac workActivities0600-0615 Safety Meeting-Review location hazards including ,WHD, WL crane operations, overhead objects, the use of


0615-0830 MIRU Casedhole WLU, Perforate Stage 1 @(6536'-6706).Costs ($): Daily: 6,419 Cum: 49,031 AFE: 948,500


Date: 09/23/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and FlowbackContractors: HES, R&R, Target, Rhetts, SunriseCompletion Rig: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcoming Activity: Perf, Frac, and FlowbackActivities1450-1930 Wait On TR_3-14-820.1930-2215 Rig Down From TR_3-14-820 & 3-24-820 And Rig Up On The TR_3-13-820 And 3-23-8202215-2250 Prime Up & Pressure Test Good2250-0010 Frac Stage 1Costs ($): Daily: 17,326 Cum: 67,923 AFE: 948,500


Date: 09/15/2014Supervisor: Stringham/DuncanWork Objective: Nipple up BOPContractors: Knight, R&R, RNICompletion Rig: (Missing) Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Prep for frac workActivities1000-1130 MINU Knight 5K BOP, set flow back and frac tanks.Costs ($): Daily: 3,242 Cum: 17,726 AFE: 948,500

Date: 09/16/2014Supervisor: Stringham/DuncanWork Objective: Pressure testContractors: RBS, R&R,RNICompletion Riq: (Missinq) Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Prep for frac workActivities1030-1100 MIRU RBS Test Unit, and test csq, WH, Flow back lines, and BOP to 4,250 psiq, good test. RDMO TestersCosts ($): Daily: 8,516 Cum: 26,243 AFE: 948,500

Date: 09/17/2014Supervisor: FletcherWork Obiective: Prep for frac workContractors: (Missinq)Completion Riq: (Missinq) Supervisor Phone: 3036459812Upcominq Activity: CompletionActivities0900-1100 Set Up Live Load Manifold0000-0000 Pre Fill Frac TanksCosts ($): Daily: 16,369 Cum: 42,612 AFE: 948,500

Date: 09/18/2014Supervisor: StringhamWork Objective: Prep for frac workContractors: R&R,Sunrise, RNI, TargetCompletion Riq: (Missing) Supervisor Phone: 435-790-2326Upcominq Activity: PerforatinqCosts ($): Daily: 0 Cum: 42,612 AFE: 948,500

Date: 09/19/2014Supervisor: StringhamWork Objective: PerforatinqContractors: Casedhole Solutions,R&R,RNI,Sunrise,TargetCompletion Riq: Casedhole Sol Supervisor Phone: 435-790-2326Upcominq Activity: Prep for frac workActivities0600-0615 Safety Meeting-Review location hazards including ,WHD, WL crane operations, overhead obiects, the use of




Date: 09/23/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and FlowbackContractors: HES, R&R, Target, Rhetts, SunriseCompletion Rig: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Perf, Frac, and FlowbackActivities1450-1930 Wait On TR 3-14-820.1930-2215 Riq Down From TR 3-14-820 & 3-24-820 And Riq Up On The TR 3-13-820 And 3-23-8202215-2250 Prime Up & Pressure Test Good2250-0010 Frac Stage 1Costs ($): Daily: 17,326 Cum: 67,923 AFE: 948,500


RECEIVED: Oct. 29,


Date: 09/15/2014Supervisor: Stringham/DuncanWork Objective: Nipple up BOPContractors: Knight, R&R, RNICompletion Rig: (Missing) Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Prep for frac workActivities1000-1130 MINU Knight 5K BOP, set flow back and frac tanks.Costs ($): Daily: 3,242 Cum: 17,726 AFE: 948,500

Date: 09/16/2014Supervisor: Stringham/DuncanWork Objective: Pressure testContractors: RBS, R&R,RNICompletion Riq: (Missinq) Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Prep for frac workActivities1030-1100 MIRU RBS Test Unit, and test csq, WH, Flow back lines, and BOP to 4,250 psiq, good test. RDMO TestersCosts ($): Daily: 8,516 Cum: 26,243 AFE: 948,500

Date: 09/17/2014Supervisor: FletcherWork Obiective: Prep for frac workContractors: (Missinq)Completion Riq: (Missinq) Supervisor Phone: 3036459812Upcominq Activity: CompletionActivities0900-1100 Set Up Live Load Manifold0000-0000 Pre Fill Frac TanksCosts ($): Daily: 16,369 Cum: 42,612 AFE: 948,500

Date: 09/18/2014Supervisor: StringhamWork Objective: Prep for frac workContractors: R&R,Sunrise, RNI, TargetCompletion Riq: (Missing) Supervisor Phone: 435-790-2326Upcominq Activity: PerforatinqCosts ($): Daily: 0 Cum: 42,612 AFE: 948,500

Date: 09/19/2014Supervisor: StringhamWork Objective: PerforatinqContractors: Casedhole Solutions,R&R,RNI,Sunrise,TargetCompletion Riq: Casedhole Sol Supervisor Phone: 435-790-2326Upcominq Activity: Prep for frac workActivities0600-0615 Safety Meeting-Review location hazards including ,WHD, WL crane operations, overhead obiects, the use of




Date: 09/23/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and FlowbackContractors: HES, R&R, Target, Rhetts, SunriseCompletion Rig: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Perf, Frac, and FlowbackActivities1450-1930 Wait On TR 3-14-820.1930-2215 Riq Down From TR 3-14-820 & 3-24-820 And Riq Up On The TR 3-13-820 And 3-23-8202215-2250 Prime Up & Pressure Test Good2250-0010 Frac Stage 1Costs ($): Daily: 17,326 Cum: 67,923 AFE: 948,500


RECEIVED: Oct. 29,



Date: 09/24/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and Flowback SSE: 2Contractors: HES,R&R,RNI,TARGET,SUNRISECompletion Rig: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcoming Activity: Drill out plugActivities2250-0010 Frac Stage 10010-0135 Perforate Stage 2 (6407'- 6499') Set 5.5" FTFP @ 6519'0135-0140 Wait On TR_3-13-8200140-0210 Change Out Chemical Trailer0210-0300 Frac Stage 2 Pressure Out with 7,000 lbs Of 0.35# Sand In Formation Flush Well. Decision To Re Perforate0300-0330 Wait On Perforate The TR_3-13-8200330-0500 Re-Perforate Stage 2 (6407'- 6499').0500-0700 Frac stage 2. Screened out w/20,000#'s of sand information, and 13,000#'s of sand in the well bore.0700-0740 Attempt to flow sand out of the well bore. Flowed well until sand cleaned up, recovered 254 bbls of fluid.0740-0905 Perforate Stage 3 (6190'- 6367') Set 5.5" FTFP @ 6387'.0905-0935 Change out chemical trailer.0935-1230 Frac stage 3.1230-1340 Perforate Stage 4 (5893'- 6163') Set 5.5" FTFP @ 6179'.1340-1430 Wait On TR_3-13-820.1430-1445 Change out chemical trailer.1445-1645 Frac stage 4.1645-1750 Perforate Stage 5 (5704'- 5856') Set 5.5" FTFP @ 5876'.1750-1945 Wait On TR_3-13-8201945-2110 Waiting On Sand2110-2225 Frac Stage 52225-2235 Perforate Stage 6 (5179'- 5447') Set 5.5" FTFP @ 5464'.2235-0045 Wait On TR_3-13-820Costs ($): Daily: 1,500 Cum: 69,423 AFE: 948,500

Date: 09/25/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and Flowback SSE: 2Contractors: HES,R&R,RNI,TARGET,SUNRISECompletion Rig: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcoming Activity: Drill out plugActivities2235-0045 Wait On TR_3-13-8200045-0135 Going Through Horse Power Pumps0135-0225 Frac Stage 60225-0330 Perforate Stage 7 (5006'- 5148') Set 5.5" FTFP @ 5160'0330-0415 Wait On TR_3-13-8200415-0555 Wait On Sand0555-0710 Frac stage 7. SICP 1258 psi.0710-1330 RDMO vendors.1330-1350 Safety Meeting-Review location hazards including , WHD, crane operations, the use land guides while

backing. Review incident reporting of property damage, & personnel injuries. Slips trips and falls, Establishsmoking area & Muster area.

1350-1550 MIRU IPS 2" CTU. Spot in and RU crane & coil tubing unit. NU. stack, and flow lines. Pick up injector headand NU. lub. Fill coil with water. Install coil connect. Pull test to 25,000# & pressure test to 2500 psi.

1550-1645 Make up ETS BHA as follows: Coil Connector, Bi-Directional jar, MHA Dual Check Valves, 3/4" Ball Seat(back pressure valve) Hydraulic Disconnect, Dual Circ Sub, 5/8" Ball Seat, 8K Burst Disc, motor and 5 blade4.625" mill. Connect lubricator. Function test motor,2.0 BPM @ 1600 PSI.Pressure test to 3500 psi. Openrams, 750 psi well pressure.

1645-1740 RIH with mill and motor to plug @ 5160'. (Coil depth 5170').1740-1750 Drill plug @ 5160’ (550) PSI.1750-1800 Pump a 10 bbl gel sweep. RIH to plug @ 5464'. (Coil depth 5475').1800-1925 Drill plug @ 5464' (750) PSI.1925-1935 Pump a 10 bbl gel sweep. RIH to plug @ 5876'. (Coil depth 5865').1935-2020 Drill plug @ 5876' (750) PSI.2020-2035 Pump a 20 bbl gel sweep. RIH to plug @ 6179'. (Coil depth 6189').2035-2055 Drill plug @ 6179' (750) PSI.2055-2105 Pump a 10 bbl gel sweep. RIH to plug @ 6387'. (Coil depth 6395').2105-2115 Drill plug @ 6387' (750) PSI.2115-2120 Pump a 10 bbl gel sweep. RIH to plug @ 6519'. (Coil depth 6526').2120-2140 Drill plug @ 6519' (750) PSI.2140-2330 RIH To 6590' Tight Spot Can Not Get Thru. Decision Made To POOH And Change Mill To 4.375".. Pump 20

bbl gel sweep, 10 bbl water spacer & 20 bbl gel sweep. Make 500' short trip and retag @ 6590'. POOH @ 50ft/min for 30 min and then continue POOH.

2330-0015 ND Stack Change out Mill Function Test BHA To 2.0 BPM @ 1800 PSI. NU Stack Pressure Test To 4,000 PSIOpen Rams 750 PSI.



Date: 09/24/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and Flowback SSE: 2Contractors: HES,R&R,RNI,TARGET,SUNRISECompletion Rig: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Drillout pluqActivities2250-0010 Frac Stage 10010-0135 Perforate Stage 2 (6407'- 6499') Set 5.5" FTFP @ 6519'0135-0140 Wait On TR 3-13-8200140-0210 Change Out Chemical Trailer0210-0300 Frac Stage 2 Pressure Out with 7,000 lbs Of 0.35# Sand In Formation Flush Well. Decision To Re Perforate0300-0330 Wait On Perforate The TR 3-13-8200330-0500 Re-Perforate Stage 2 (6407'- 6499').0500-0700 Frac stage 2. Screened out w/20,000#'s of sand information, and 13,000#'s of sand in the well bore.0700-0740 Attempt to flow sand out of the well bore. Flowed well until sand cleaned up, recovered 254 bbls of fluid.0740-0905 Perforate Stage 3 (6190'- 6367') Set 5.5" FTFP @ 6387'.0905-0935 Change out chemical trailer.0935-1230 Frac stage 3.1230-1340 Perforate Stage 4 (5893'- 6163') Set 5.5" FTFP @ 6179'.1340-1430 Wait On TR 3-13-820.1430-1445 Change out chemical trailer.1445-1645 Frac stage 4.1645-1750 Perforate Stage 5 (5704'- 5856') Set 5.5" FTFP @ 5876'.1750-1945 Wait On TR 3-13-8201945-2110 Waitinq On Sand2110-2225 Frac Stage 52225-2235 Perforate Stage 6 (5179'- 5447') Set 5.5" FTFP @ 5464'.2235-0045 Wait On TR 3-13-820Costs ($): Daily: 1,500 Cum: 69,423 AFE: 948,500

Date: 09/25/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and Flowback SSE: 2Contractors: HES,R&R,RNI,TARGET,SUNRISECompletion Riq: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Drillout pluqActivities2235-0045 Wait On TR 3-13-8200045-0135 Goinq Through Horse Power Pumps0135-0225 Frac Stage 60225-0330 Perforate Stage 7 (5006'- 5148') Set 5.5" FTFP @ 5160'0330-0415 Wait On TR 3-13-8200415-0555 Wait On Sand0555-0710 Frac stage 7. SICP 1258 psi.0710-1330 RDMO vendors.1330-1350 Safety Meeting-Review location hazards including , WHD, crane operations, the use land guides while

backing. Review incident reportinq of property damage, & personnel iniuries. Slips trips and falls, Establishsmokinq area & Muster area.

1350-1550 MIRU IPS 2" CTU. Spot in and RU crane & coil tubinq unit. NU. stack, and flow lines. Pick up iniector headand NU. lub. Fill coil with water. Install coil connect. Pull test to 25,000# & pressure test to 2500 psi.

1550-1645 Make up ETS BHA as follows: Coil Connector, Bi-Directional |ar, MHA Dual Check Valves, 3/4" Ball Seat(back pressure valve) Hydraulic Disconnect, Dual Circ Sub, 5/8" Ball Seat, 8K Burst Disc, motor and 5 blade4.625" mill. Connect lubricator. Function test motor,2.0 BPM @ 1600 PSI.Pressure test to 3500 psi. Openrams, 750 psi well pressure.

1645-1740 RIH with mill and motor to pluq @ 5160'. (Coil depth 5170').1740-1750 Drillpluq @ 5160' (550) PSI.1750-1800 Pump a 10 bbl qel sweep. RIH to pluq @ 5464'. (Coil depth 5475').1800-1925 Drillplug @ 5464' (750) PSI.1925-1935 Pump a 10 bbl qel sweep. RIH to pluq @ 5876'. (Coil depth 5865').1935-2020 Drillpluq @ 5876' (750) PSI.2020-2035 Pump a 20 bbl qel sweep. RIH to pluq @ 6179'. (Coil depth 6189').2035-2055 Drillpluq @ 6179' (750) PSI.2055-2105 Pump a 10 bbl qel sweep. RIH to pluq @ 6387'. (Coil depth 6395').2105-2115 Drillplug @ 6387' (750) PSI.2115-2120 Pump a 10 bbl qel sweep. RIH to pluq @ 6519'. (Coil depth 6526').2120-2140 Drillpluq @ 6519' (750) PSI.2140-2330 RIH To 6590' Tiqht Spot Can Not Get Thru. Decision Made To POOH And Change MillTo 4.375".. Pump 20

bbl qel sweep, 10 bbl water spacer & 20 bbl qel sweep. Make 500' short trip and retaq @ 6590'. POOH @ 50ft/min for 30 min and then continue POOH.

2330-0015 ND Stack Change out MillFunction Test BHA To 2.0 BPM @ 1800 PSI. NU Stack Pressure Test To 4,000 P3\Open Rams 750 PSI.



RECEIVED: Oct. 29,


Date: 09/24/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and Flowback SSE: 2Contractors: HES,R&R,RNI,TARGET,SUNRISECompletion Rig: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Drillout pluqActivities2250-0010 Frac Stage 10010-0135 Perforate Stage 2 (6407'- 6499') Set 5.5" FTFP @ 6519'0135-0140 Wait On TR 3-13-8200140-0210 Change Out Chemical Trailer0210-0300 Frac Stage 2 Pressure Out with 7,000 lbs Of 0.35# Sand In Formation Flush Well. Decision To Re Perforate0300-0330 Wait On Perforate The TR 3-13-8200330-0500 Re-Perforate Stage 2 (6407'- 6499').0500-0700 Frac stage 2. Screened out w/20,000#'s of sand information, and 13,000#'s of sand in the well bore.0700-0740 Attempt to flow sand out of the well bore. Flowed well until sand cleaned up, recovered 254 bbls of fluid.0740-0905 Perforate Stage 3 (6190'- 6367') Set 5.5" FTFP @ 6387'.0905-0935 Change out chemical trailer.0935-1230 Frac stage 3.1230-1340 Perforate Stage 4 (5893'- 6163') Set 5.5" FTFP @ 6179'.1340-1430 Wait On TR 3-13-820.1430-1445 Change out chemical trailer.1445-1645 Frac stage 4.1645-1750 Perforate Stage 5 (5704'- 5856') Set 5.5" FTFP @ 5876'.1750-1945 Wait On TR 3-13-8201945-2110 Waitinq On Sand2110-2225 Frac Stage 52225-2235 Perforate Stage 6 (5179'- 5447') Set 5.5" FTFP @ 5464'.2235-0045 Wait On TR 3-13-820Costs ($): Daily: 1,500 Cum: 69,423 AFE: 948,500

Date: 09/25/2014Supervisor: Stringham/DuncanWork Objective: Perf, Frac, and Flowback SSE: 2Contractors: HES,R&R,RNI,TARGET,SUNRISECompletion Riq: Hal, HAL RED T4 Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Drillout pluqActivities2235-0045 Wait On TR 3-13-8200045-0135 Goinq Through Horse Power Pumps0135-0225 Frac Stage 60225-0330 Perforate Stage 7 (5006'- 5148') Set 5.5" FTFP @ 5160'0330-0415 Wait On TR 3-13-8200415-0555 Wait On Sand0555-0710 Frac stage 7. SICP 1258 psi.0710-1330 RDMO vendors.1330-1350 Safety Meeting-Review location hazards including , WHD, crane operations, the use land guides while

backing. Review incident reportinq of property damage, & personnel iniuries. Slips trips and falls, Establishsmokinq area & Muster area.

1350-1550 MIRU IPS 2" CTU. Spot in and RU crane & coil tubinq unit. NU. stack, and flow lines. Pick up iniector headand NU. lub. Fill coil with water. Install coil connect. Pull test to 25,000# & pressure test to 2500 psi.

1550-1645 Make up ETS BHA as follows: Coil Connector, Bi-Directional |ar, MHA Dual Check Valves, 3/4" Ball Seat(back pressure valve) Hydraulic Disconnect, Dual Circ Sub, 5/8" Ball Seat, 8K Burst Disc, motor and 5 blade4.625" mill. Connect lubricator. Function test motor,2.0 BPM @ 1600 PSI.Pressure test to 3500 psi. Openrams, 750 psi well pressure.

1645-1740 RIH with mill and motor to pluq @ 5160'. (Coil depth 5170').1740-1750 Drillpluq @ 5160' (550) PSI.1750-1800 Pump a 10 bbl qel sweep. RIH to pluq @ 5464'. (Coil depth 5475').1800-1925 Drillplug @ 5464' (750) PSI.1925-1935 Pump a 10 bbl qel sweep. RIH to pluq @ 5876'. (Coil depth 5865').1935-2020 Drillpluq @ 5876' (750) PSI.2020-2035 Pump a 20 bbl qel sweep. RIH to pluq @ 6179'. (Coil depth 6189').2035-2055 Drillpluq @ 6179' (750) PSI.2055-2105 Pump a 10 bbl qel sweep. RIH to pluq @ 6387'. (Coil depth 6395').2105-2115 Drillplug @ 6387' (750) PSI.2115-2120 Pump a 10 bbl qel sweep. RIH to pluq @ 6519'. (Coil depth 6526').2120-2140 Drillpluq @ 6519' (750) PSI.2140-2330 RIH To 6590' Tiqht Spot Can Not Get Thru. Decision Made To POOH And Change MillTo 4.375".. Pump 20

bbl qel sweep, 10 bbl water spacer & 20 bbl qel sweep. Make 500' short trip and retaq @ 6590'. POOH @ 50ft/min for 30 min and then continue POOH.

2330-0015 ND Stack Change out MillFunction Test BHA To 2.0 BPM @ 1800 PSI. NU Stack Pressure Test To 4,000 P3\Open Rams 750 PSI.



RECEIVED: Oct. 29,



Date: 09/26/2014Supervisor: Stringham/DuncanWork Objective: Drill out plug SSE: 2Contractors: IPS, ETS, R&R, RhettsCompletion Rig: IPS CT 2" Supervisor Phone: 435-790-2326/435-828-1472Upcoming Activity: Flow test wellActivities2330-0015 ND Stack Change out Mill Function Test BHA To 2.0 BPM @ 1800 PSI. NU Stack Pressure Test To 4,000 PSI

Open Rams 750 PSI.0015-0125 RIH with mill and motor to Tight Spot @ 6604' This Trip.0125-0220 Work through Tight Spot To (6606') With 10 Cycles, Torque Out each Time. Pull 8 To 10 K Over.0220-0315 POOH Close Bottom ram, SICP 800#.( Did Not Get To PBTD @ 6821').0315-0330 Bleed off stack. ND. stack and swing to TR_3-13-820.0330-0335 Hand well over to flow testers, open well on 16/64 choke. IP 800#.Costs ($): Daily: 64,511 Cum: 191,124 AFE: 948,500

Date: 09/27/2014Supervisor: DuncanWork Objective: Flow test wellContractors: R&R, RhettsCompletion Rig: (Missing) Supervisor Phone: 435-828-1472Upcoming Activity: Turned over to Production DeptCosts ($): Daily: 481 Cum: 191,605 AFE: 948,500

Date: 09/28/2014Supervisor: Duncan/StringhamWork Objective: Flow test wellContractors: RNI, R&RCompletion Rig: (Missing) Supervisor Phone: (Missing)Upcoming Activity: Turned over to Production DeptCosts ($): Daily: 11,996 Cum: 203,601 AFE: 948,500

Date: 09/29/2014Supervisor: FletcherWork Objective: Turned over to Production DeptContractors: (Missing)Completion Rig: (Missing) Supervisor Phone: 3036459812Upcoming Activity:Costs ($): Daily: 344,207 Cum: 547,808 AFE: 948,500


Date: 09/26/2014Supervisor: Stringham/DuncanWork Objective: Drillout pluq SSE: 2Contractors: IPS, ETS, R&R, RhettsCompletion Rig: IPS CT 2" Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Flow test wellActivities2330-0015 ND Stack Change out MillFunction Test BHA To 2.0 BPM @ 1800 PSI. NU Stack Pressure Test To 4,000 P3\

Open Rams 750 PSI.0015-0125 RIH with mill and motor to Tiqht Spot @ 6604' This Trip.0125-0220 Work through Tight Spot To (6606') With 10 Cycles, Torque Out each Time. Pull 8 To 10 K Over.0220-0315 POOH Close Bottom ram, SICP 800#.( Did Not Get To PBTD @ 6821').0315-0330 Bleed off stack. ND. stack and swing to TR 3-13-820.0330-0335 Hand well over to flow testers, open well on 16/64 choke. IP 800#.Costs ($): Daily: 64,511 Cum: 191,124 AFE: 948,500

Date: 09/27/2014Supervisor: DuncanWork Objective: Flow test wellContractors: R&R, RhettsCompletion Riq: (Missinq) Supervisor Phone: 435-828-1472Upcominq Activity: Turned over to Production DeptCosts ($): Daily: 481 Cum: 191,605 AFE: 948,500

Date: 09/28/2014Supervisor: Duncan/StringhamWork Objective: Flow test wellContractors: RNI, R&RCompletion Rig: (Missing) Supervisor Phone: (Missing)Upcominq Activity: Turned over to Production DeptCosts ($): Daily: 11,996 Cum: 203,601 AFE: 948,500

Date: 09/29/2014Supervisor: FletcherWork Obiective: Turned over to Production DeptContractors: (Missinq)Completion Riq: (Missinq) Supervisor Phone: 3036459812Upcominq Activity:Costs ($): Daily: 344,207 Cum: 547,808 AFE: 948,500


RECEIVED: Oct. 29,


Date: 09/26/2014Supervisor: Stringham/DuncanWork Objective: Drillout pluq SSE: 2Contractors: IPS, ETS, R&R, RhettsCompletion Rig: IPS CT 2" Supervisor Phone: 435-790-2326/435-828-1472Upcominq Activity: Flow test wellActivities2330-0015 ND Stack Change out MillFunction Test BHA To 2.0 BPM @ 1800 PSI. NU Stack Pressure Test To 4,000 P3\

Open Rams 750 PSI.0015-0125 RIH with mill and motor to Tiqht Spot @ 6604' This Trip.0125-0220 Work through Tight Spot To (6606') With 10 Cycles, Torque Out each Time. Pull 8 To 10 K Over.0220-0315 POOH Close Bottom ram, SICP 800#.( Did Not Get To PBTD @ 6821').0315-0330 Bleed off stack. ND. stack and swing to TR 3-13-820.0330-0335 Hand well over to flow testers, open well on 16/64 choke. IP 800#.Costs ($): Daily: 64,511 Cum: 191,124 AFE: 948,500

Date: 09/27/2014Supervisor: DuncanWork Objective: Flow test wellContractors: R&R, RhettsCompletion Riq: (Missinq) Supervisor Phone: 435-828-1472Upcominq Activity: Turned over to Production DeptCosts ($): Daily: 481 Cum: 191,605 AFE: 948,500

Date: 09/28/2014Supervisor: Duncan/StringhamWork Objective: Flow test wellContractors: RNI, R&RCompletion Rig: (Missing) Supervisor Phone: (Missing)Upcominq Activity: Turned over to Production DeptCosts ($): Daily: 11,996 Cum: 203,601 AFE: 948,500

Date: 09/29/2014Supervisor: FletcherWork Obiective: Turned over to Production DeptContractors: (Missinq)Completion Riq: (Missinq) Supervisor Phone: 3036459812Upcominq Activity:Costs ($): Daily: 344,207 Cum: 547,808 AFE: 948,500


RECEIVED: Oct. 29,


10/28/2014 2:35 PM Page 1

ULTRA RESOURCES, INC.PERFORATION AND FRAC SUMMARY FOR THREE RIVERS FED 3-23-820

Well Name: THREE RIVERS FED 3-23-820 Fracs Planned: 7Location: UINTAH County, UTAH (NWSW 003 8S 20E)Stage 1 Frac Date: 09/24/2014 Avg Rate: 50.0 BPM Avg Pressure: 2,355 PSIInitial Completion Proppant: 138,678 lbs total Max Rate: 62.0 BPM Max Pressure: 3,577 PSI

138678 lbs OttawaInitial Annulus Pressure: 26 Final Annulus Pressure: 21 Pump Down Volume:

PreFrac SICP: ISIP: 2,033 PSI Base BBLS to Recover: 4,297 BBLsPseudo Frac Gradient: Pseudo Frac Gradient:0.736 PSI/FT 14.153 LB/GAL

Net Pressure: 728 psi Total BBLS to Recover: 4,297 BBLsBreakdown Pressure: 2761 Breakdown Rate: 2.9 Perfs Open:

ScreenOut: No Tracer: (None)Zones: Perf Date SPF Perf Interval: From To

12 09/19/2014 3 6,536 6,53711 09/19/2014 3 6,545 6,54610 09/19/2014 3 6,558 6,559

9 09/19/2014 3 6,567 6,5688 09/19/2014 3 6,589 6,5907 09/19/2014 3 6,598 6,5996 09/19/2014 3 6,616 6,6175 09/19/2014 3 6,625 6,6264 09/19/2014 3 6,639 6,6403 09/19/2014 3 6,657 6,6582 09/19/2014 3 6,684 6,6851 09/19/2014 3 6,704 6,706

Stage 2 Frac Date: 09/24/2014 Avg Rate: 22.0 BPM Avg Pressure: 2,501 PSIInitial Completion Proppant: 24,958 lbs total Max Rate: 57.0 BPM Max Pressure: 4,445 PSI





10 09/24/2014 3 6,407 6,4089 09/24/2014 3 6,418 6,4198 09/24/2014 3 6,427 6,4287 09/24/2014 3 6,438 6,4396 09/24/2014 3 6,449 6,4505 09/24/2014 3 6,460 6,4614 09/24/2014 3 6,466 6,4673 09/24/2014 3 6,474 6,4752 09/24/2014 3 6,483 6,4841 09/24/2014 3 6,497 6,499




Net Pressure: -1012 psi Total BBLS to Recover: 4,080 BBLsBreakdown Pressure: 1967 Breakdown Rate: 7.9 Perfs Open:


12 09/24/2014 3 6,190 6,19111 09/24/2014 3 6,217 6,21810 09/24/2014 3 6,227 6,228

9 09/24/2014 3 6,235 6,2368 09/24/2014 3 6,248 6,2497 09/24/2014 3 6,263 6,2646 09/24/2014 3 6,271 6,2725 09/24/2014 3 6,286 6,2874 09/24/2014 3 6,328 6,3303 09/24/2014 3 6,348 6,3492 09/24/2014 3 6,361 6,3621 09/24/2014 3 6,366 6,367


ULTRARESOURCES,INC.PERFORATION AND FRAC SUMMARY FOR THREE RIVERS FED 3-23-820

Well Name: THREE RIVERS FED 3-23-820 Fracs Planned: 7Location: UINTAHCounty, UTAH (NWSW 003 8S 20E)Stage 1 Frac Date: 09/24/2014 Avg Rate: 50.0 BPM Avg Pressure: 2,355 PSIInitial Completion Proppant: 138,678 lbs total Max Rate: 62.0 BPM Max Pressure: 3,577 PSI

138678 lbs OttawaInitialAnnulus Pressure: 26 Final Annulus Pressure: 21 Pump Down Volume:

PreFrac SICP: ISIP: 2,033 PSI Base BBLS to Recover: 4,297 BBLsPseudo Frac Gradient: 0.736 PSI/FT Pseudo Frac Gradient: 14.153 LB/GAL



12 090MW2014 3 6,536 6,53711 090MW2014 3 6,545 6,54610 090MW2014 3 6,558 6,559

9 090MW2014 3 6,567 6,5688 090MW2014 3 6,589 6,5907 090MW2014 3 6,598 6,5996 090MW2014 3 6,616 6,6175 090MW2014 3 6,625 6,6264 090MW2014 3 6,639 6,6403 090MW2014 3 6,657 6,6582 090MW2014 3 6,684 6,6851 090MW2014 3 6,704 6,706




Net Pressure: 1238 psi TotalBBLS to Recover: 4,206 BBLsBreakdown Pressure: 1543 Breakdown Rate: 6.2 Perfs Open:


10 0959U2014 3 6,407 6,4089 0959U2014 3 6,418 6,4198 0959U2014 3 6,427 6,4287 0959U2014 3 6,438 6,4396 0959U2014 3 6,449 6,4505 0959U2014 3 6,460 6,4614 0959U2014 3 6,466 6,4673 0959U2014 3 6,474 6,4752 0959U2014 3 6,483 6,4841 0959U2014 3 6,497 6,499






12 09524/2014 3 6,190 6,19111 0959U2014 3 6,217 6,21810 0959U2014 3 6,227 6,228

9 0959U2014 3 6,235 6,2368 0959U2014 3 6,248 6,2497 0959U2014 3 6,263 6,2646 0959U2014 3 6,271 6,2725 0959U2014 3 6,286 6,2874 0959U2014 3 6,328 6,3303 0959U2014 3 6,348 6,3492 0959U2014 3 6,361 6,3621 0959U2014 3 6,366 6,367

RECEIVED: Oct. 29,


ULTRARESOURCES,INC.PERFORATION AND FRAC SUMMARY FOR THREE RIVERS FED 3-23-820

Well Name: THREE RIVERS FED 3-23-820 Fracs Planned: 7Location: UINTAHCounty, UTAH (NWSW 003 8S 20E)Stage 1 Frac Date: 09/24/2014 Avg Rate: 50.0 BPM Avg Pressure: 2,355 PSIInitial Completion Proppant: 138,678 lbs total Max Rate: 62.0 BPM Max Pressure: 3,577 PSI





12 090MW2014 3 6,536 6,53711 090MW2014 3 6,545 6,54610 090MW2014 3 6,558 6,559

9 090MW2014 3 6,567 6,5688 090MW2014 3 6,589 6,5907 090MW2014 3 6,598 6,5996 090MW2014 3 6,616 6,6175 090MW2014 3 6,625 6,6264 090MW2014 3 6,639 6,6403 090MW2014 3 6,657 6,6582 090MW2014 3 6,684 6,6851 090MW2014 3 6,704 6,706




Net Pressure: 1238 psi TotalBBLS to Recover: 4,206 BBLsBreakdown Pressure: 1543 Breakdown Rate: 6.2 Perfs Open:


10 0959U2014 3 6,407 6,4089 0959U2014 3 6,418 6,4198 0959U2014 3 6,427 6,4287 0959U2014 3 6,438 6,4396 0959U2014 3 6,449 6,4505 0959U2014 3 6,460 6,4614 0959U2014 3 6,466 6,4673 0959U2014 3 6,474 6,4752 0959U2014 3 6,483 6,4841 0959U2014 3 6,497 6,499






12 09524/2014 3 6,190 6,19111 0959U2014 3 6,217 6,21810 0959U2014 3 6,227 6,228

9 0959U2014 3 6,235 6,2368 0959U2014 3 6,248 6,2497 0959U2014 3 6,263 6,2646 0959U2014 3 6,271 6,2725 0959U2014 3 6,286 6,2874 0959U2014 3 6,328 6,3303 0959U2014 3 6,348 6,3492 0959U2014 3 6,361 6,3621 0959U2014 3 6,366 6,367

RECEIVED: Oct. 29,


10/28/2014 2:35 PM Page 2






13 09/24/2014 3 5,893 5,89412 09/24/2014 3 5,935 5,93611 09/24/2014 3 5,949 5,95010 09/24/2014 3 5,968 5,969

9 09/24/2014 3 6,017 6,0188 09/24/2014 3 6,029 6,0307 09/24/2014 3 6,049 6,0506 09/24/2014 3 6,062 6,0635 09/24/2014 3 6,085 6,0864 09/24/2014 3 6,095 6,0963 09/24/2014 3 6,118 6,1192 09/24/2014 3 6,125 6,1261 09/24/2014 3 6,162 6,163






13 09/24/2014 3 5,704 5,70512 09/24/2014 3 5,719 5,72011 09/24/2014 3 5,730 5,73110 09/24/2014 3 5,742 5,743

9 09/24/2014 3 5,758 5,7598 09/24/2014 3 5,762 5,7637 09/24/2014 3 5,768 5,7696 09/24/2014 3 5,784 5,7855 09/24/2014 3 5,808 5,8094 09/24/2014 3 5,814 5,8153 09/24/2014 3 5,827 5,8282 09/24/2014 3 5,836 5,8371 09/24/2014 3 5,855 5,856






10 09/24/2014 3 5,179 5,1809 09/24/2014 3 5,212 5,2138 09/24/2014 3 5,219 5,2207 09/24/2014 3 5,251 5,2526 09/24/2014 3 5,270 5,2715 09/24/2014 3 5,307 5,3084 09/24/2014 3 5,429 5,4303 09/24/2014 3 5,433 5,4342 09/24/2014 3 5,437 5,4381 09/24/2014 3 5,445 5,447







13 0959U2014 3 5,893 5,89412 0959U2014 3 5,935 5,93611 0959U2014 3 5,949 5,95010 0959U2014 3 5,968 5,969

9 0959U2014 3 6,017 6,0188 0959U2014 3 6,029 6,0307 0959U2014 3 6,049 6,0506 0959U2014 3 6,062 6,0635 0959U2014 3 6,085 6,0864 0959U2014 3 6,095 6,0963 0959U2014 3 6,118 6,1192 0959U2014 3 6,125 6,1261 0959U2014 3 6,162 6,163






13 0959U2014 3 5,704 5,70512 0959U2014 3 5,719 5,72011 0959U2014 3 5,730 5,73110 0959U2014 3 5,742 5,743

9 0959U2014 3 5,758 5,7598 0959U2014 3 5,762 5,7637 0959U2014 3 5,768 5,7696 0959U2014 3 5,784 5,7855 0959U2014 3 5,808 5,8094 0959U2014 3 5,814 5,8153 0959U2014 3 5,827 5,8282 0959U2014 3 5,836 5,8371 0959U2014 3 5,855 5,856






10 0959U2014 3 5,179 5,1809 0959U2014 3 5,212 5,2138 0959U2014 3 5,219 5,2207 0959U2014 3 5,251 5,2526 0959U2014 3 5,270 5,2715 0959U2014 3 5,307 5,3084 0959U2014 3 5,429 5,4303 0959U2014 3 5,433 5,4342 0959U2014 3 5,437 5,4381 0959U2014 3 5,445 5,447

RECEIVED: Oct. 29,







13 0959U2014 3 5,893 5,89412 0959U2014 3 5,935 5,93611 0959U2014 3 5,949 5,95010 0959U2014 3 5,968 5,969

9 0959U2014 3 6,017 6,0188 0959U2014 3 6,029 6,0307 0959U2014 3 6,049 6,0506 0959U2014 3 6,062 6,0635 0959U2014 3 6,085 6,0864 0959U2014 3 6,095 6,0963 0959U2014 3 6,118 6,1192 0959U2014 3 6,125 6,1261 0959U2014 3 6,162 6,163






13 0959U2014 3 5,704 5,70512 0959U2014 3 5,719 5,72011 0959U2014 3 5,730 5,73110 0959U2014 3 5,742 5,743

9 0959U2014 3 5,758 5,7598 0959U2014 3 5,762 5,7637 0959U2014 3 5,768 5,7696 0959U2014 3 5,784 5,7855 0959U2014 3 5,808 5,8094 0959U2014 3 5,814 5,8153 0959U2014 3 5,827 5,8282 0959U2014 3 5,836 5,8371 0959U2014 3 5,855 5,856






10 0959U2014 3 5,179 5,1809 0959U2014 3 5,212 5,2138 0959U2014 3 5,219 5,2207 0959U2014 3 5,251 5,2526 0959U2014 3 5,270 5,2715 0959U2014 3 5,307 5,3084 0959U2014 3 5,429 5,4303 0959U2014 3 5,433 5,4342 0959U2014 3 5,437 5,4381 0959U2014 3 5,445 5,447

RECEIVED: Oct. 29,


10/28/2014 2:35 PM Page 3






11 09/25/2014 3 5,006 5,00710 09/25/2014 3 5,014 5,015

9 09/25/2014 3 5,021 5,0228 09/25/2014 3 5,039 5,0407 09/25/2014 3 5,048 5,0496 09/25/2014 3 5,067 5,0685 09/25/2014 3 5,079 5,0804 09/25/2014 3 5,097 5,0983 09/25/2014 3 5,109 5,1112 09/25/2014 3 5,136 5,1381 09/25/2014 3 5,147 5,148







11 095 W2014 3 5,006 5,00710 095 W2014 3 5,014 5,015

9 095 W2014 3 5,021 5,0228 095 W2014 3 5,039 5,0407 095 W2014 3 5,048 5,0496 095 W2014 3 5,067 5,0685 095 W2014 3 5,079 5,0804 095 W2014 3 5,097 5,0983 095 W2014 3 5,109 5,1112 095 W2014 3 5,136 5,1381 095 W2014 3 5,147 5,148

RECEIVED: Oct. 29,







11 095 W2014 3 5,006 5,00710 095 W2014 3 5,014 5,015

9 095 W2014 3 5,021 5,0228 095 W2014 3 5,039 5,0407 095 W2014 3 5,048 5,0496 095 W2014 3 5,067 5,0685 095 W2014 3 5,079 5,0804 095 W2014 3 5,097 5,0983 095 W2014 3 5,109 5,1112 095 W2014 3 5,136 5,1381 095 W2014 3 5,147 5,148

RECEIVED: Oct. 29,


Hydraulic Fracturing Fluid Product Component Information Disclosure

Hydraulic Fracturing Fluid Composition:

Job Start Date: 9/23/2014Job End Date: 9/25/2014

State: UtahCounty: Uintah

API Number: 43-047-53953-00-00Operator Name: Ultra Resources

Well Name and Number: Three Rivers Federal 3-23-820Longitude: -109.65950300

Latitude: 40.14870800Datum: NAD27

Federal/Tribal Well: NOTrue Vertical Depth: 7,400

Total Base Water Volume (gal): 1,162,269

Trade Name Supplier Purpose Ingredients

ChemicalAbstract Service

Number(CAS #)

Maximum Ingredient

Concentration in Additive

(% by mass)**

Maximum Ingredient

Concentration in HF Fluid

(% by mass)**

Comments

Fresh Water Operator Base Fluid

Fresh Water 7732-18-5 100.00000 90.70103Density = 8.340

SAND - PREMIUM WHITE

Halliburton Proppant

Crystalline silica, quartz 14808-60-7 100.00000 8.11166

HYDROCHLORIC ACID 10-30%

Halliburton Solvent

Hydrochloric acid 7647-01-0 30.00000 0.25124

LoSurf-300D Halliburton Non-ionic Surfactant

Ethanol 64-17-5 60.00000 0.04881

Heavy aromatic petroleum naphtha

64742-94-5 30.00000 0.02440

Poly(oxy-1,2-ethanediyl), alpha-(4-nonylphenyl)-omega-hydroxy-, branched

127087-87-0 5.00000 0.00407

Naphthalene 91-20-3 5.00000 0.00407

1,2,4 Trimethylbenzene 95-63-6 1.00000 0.00081

WG-35 GELLING AGENT

Halliburton Gelling Agent

Guar gum 9000-30-0 100.00000 0.03609

BC-140 Halliburton Crosslinker

Monoethanolamine borate 26038-87-9 60.00000 0.02173

Total Base Non Water Volume: 0


Hydraulic Fracturing Fluid Product Component Information DisclosureJob Start Date: 9/23/2014Job End Date: 9/25/2014

State: Utat

APINComb

r43-047-53953-00n-ti FracFocus

Operator Name: Ultra Resources Chemical Disclosure RegistryWell Name and Number: Three Rivers Federal 3-23-82C

Longitude: -109.65950300

Latitude: 40.1487080c GRO DWATERDatum: NAD27

Federal/Tribal Well: NcOi &Gas

True Vertical Depth: 7,40CTotal Base Water Volume (gal): 1,162,26ETotal Base Non Water Volume: C

Hydraulic Fracturing Fluid Composition:Maximum MaximumChemical

. In redient In redientAbstract ServiceTrade Name Supplier Purpose Ingredients concentrationin 3oncentration in CommentsNumber Additive HF Fluid(CAS #) (%by mass)** (%by mass)**Fresh Water Operator Base Fluid

Fresh Water 7732-18-5 100.0000C 90.70102Density = 8.340SAND - PREMIUM Halliburton ProppantWHITE

Crystalline silica, quartz 14808-60-7 100.0000C 8.1116EHYDROCHLORIC Halliburton SolventACID 10-30%

Hydrochloric acid 7647-01-0 30.0000C 0.25124LoSurf-300D Halliburton Non-ionic Surfactant

Ethanol 34-17-5 60.0000C 0.04881Heavy aromatic petroleum 34742-94-5 30.0000C 0.02440naphthaPoly(oxy-1,2-ethanediyl), alpha- 127087-87-0 5.0000C 0.00407(4-nonylphenyl)-omega-hydroxy-, branchedNaphthalene 91-20-3 5.0000C 0.004071,2,4 Trimethylbenzene 95-63-6 1.0000C 0.00081

WG-35 GELLING Halliburton Gelling AgentAGENT

Guar gum 9000-30-0 100.0000C 0.0360EBC-140 Halliburton Crosslinker

Monoethanolamine borate 26038-87-9 60.0000C 0.02172

RECEIVED: Oct. 29,


Hydraulic Fracturing Fluid Product Component Information DisclosureJob Start Date: 9/23/2014Job End Date: 9/25/2014

State: Utat

APINComb

r43-047-53953-00n-ti FracFocus

Operator Name: Ultra Resources Chemical Disclosure RegistryWell Name and Number: Three Rivers Federal 3-23-82C

Longitude: -109.65950300

Latitude: 40.1487080c GRO DWATERDatum: NAD27

Federal/Tribal Well: NcOi &Gas

True Vertical Depth: 7,40CTotal Base Water Volume (gal): 1,162,26ETotal Base Non Water Volume: C

Hydraulic Fracturing Fluid Composition:Maximum MaximumChemical

. In redient In redientAbstract ServiceTrade Name Supplier Purpose Ingredients concentrationin 3oncentration in CommentsNumber Additive HF Fluid(CAS #) (%by mass)** (%by mass)**Fresh Water Operator Base Fluid

Fresh Water 7732-18-5 100.0000C 90.70102Density = 8.340SAND - PREMIUM Halliburton ProppantWHITE

Crystalline silica, quartz 14808-60-7 100.0000C 8.1116EHYDROCHLORIC Halliburton SolventACID 10-30%

Hydrochloric acid 7647-01-0 30.0000C 0.25124LoSurf-300D Halliburton Non-ionic Surfactant

Ethanol 34-17-5 60.0000C 0.04881Heavy aromatic petroleum 34742-94-5 30.0000C 0.02440naphthaPoly(oxy-1,2-ethanediyl), alpha- 127087-87-0 5.0000C 0.00407(4-nonylphenyl)-omega-hydroxy-, branchedNaphthalene 91-20-3 5.0000C 0.004071,2,4 Trimethylbenzene 95-63-6 1.0000C 0.00081

WG-35 GELLING Halliburton Gelling AgentAGENT

Guar gum 9000-30-0 100.0000C 0.0360EBC-140 Halliburton Crosslinker

Monoethanolamine borate 26038-87-9 60.0000C 0.02172

RECEIVED: Oct. 29,


Ethylene glycol 107-21-1 30.00000 0.01086

Cla-Web™ Halliburton Additive

Ammonium salt Confidential 60.00000 0.02952Denise Tuck,Halliburton3000 N. Sam Houston Pkwy E.,Houston, TX 77032281-871-6226

MC MX 2-2822 Multi-Chem Scale Inhibitor

Phospate of a Diamine, Sodium Salt

8913 30.00000 0.01289

Methyl Alcohol 67-56-1 30.00000 0.01289

SandWedge® NT Halliburton Conductivity Enhancer

Dipropylene glycol monomethyl ether

34590-94-8 60.00000 0.02107

Heavy aromatic petroleum naphtha

64742-94-5 10.00000 0.00351

FE-1A ACIDIZING COMPOSITION

Halliburton Additive

Acetic anhydride 108-24-7 100.00000 0.00839

Acetic acid 64-19-7 60.00000 0.00503

FR-66 Halliburton Friction Reducer

Hydrotreated light petroleum distillate

64742-47-8 30.00000 0.01103

MC B-8614 Multi-Chem Biocide

Glutaraldehyde 111-30-8 30.00000 0.00558

Alkyl (C12-16) dimethylbenzylammonium chloride

68424-85-1 5.00000 0.00093

OPTIFLO-HTE Halliburton Breaker

Walnut hulls Mixture 100.00000 0.00214

Crystalline silica, quartz 14808-60-7 30.00000 0.00064

HAI-404M™ Halliburton Corrosion Inhibitor

Isopropanol 67-63-0 30.00000 0.00046

Methanol 67-56-1 30.00000 0.00046

Aldehyde Confidential 30.00000 0.00046

Quaternary ammonium salt Confidential 10.00000 0.00015

1-(Benzyl)quinolinium chloride 15619-48-4 10.00000 0.00015

SP BREAKER Halliburton Breaker

Sodium persulfate 7775-27-1 100.00000 0.00169

Other Ingredient(s)

Water 7732-18-5 0.95236

Other Ingredient(s)

Oxyalkylated phenolic resin Confidential 0.02440

Other Ingredient(s)

Polyacrylamide copolymer Confidential 0.01103

Other Ingredient(s)

Oxyalkylated phenolic resin Confidential 0.00813

Ingredients shown above are subject to 29 CFR 1910.1200(i) and appear on Material Safety Data Sheets (MSDS). Ingredients shown below are Non-MSDS.


Ethylene glycol 107-21-1 30.0000C 0.0108ECla-WebTM Halliburton Additive

Ammonium salt Confidential 60.0000C 0.02952Denise Tuck,Halliburton3000 N. Sam Houston PkwyE.,Houston, TX 77032281-871-6226

MC MX 2-2822 Multi-Chem Scale InhibitorPhospate of a Diamine, Sodium 8913 30.0000C 0.0128ESaltMethyl Alcohol 37-56-1 30.0000C 0.0128E

SandWedge® NT Halliburton Conductivity EnhancerDipropylene glycol monomethyl 34590-94-8 60.0000C 0.02107stherHeavy aromatic petroleum 34742-94-5 10.0000C 0.00351naphtha

FE-1A ACIDIZING Halliburton AdditiveCOMPOSITION

Acetic anhydride 108-24-7 100.0000C 0.0083EAcetic acid 34-19-7 60.0000C 0.00502

FR-66 Halliburton Friction ReducerHydrotreated light petroleum 34742-47-8 30.0000C 0.01102distillate

MC B-8614 Multi-Chem BiocideGlutaraldehyde 111-30-8 30.0000C 0.0055EAlkyl(C12-16) 38424-85-1 5.0000C 0.00092dimethylbenzylammoniumchloride

OPTIFLO-HTE Halliburton BreakerWalnut hulls Mixture 100.0000C 0.00214Crystalline silica, quartz 14808-60-7 30.0000C 0.00064

HAl-404MTM Halliburton Corrosion InhibitorIsopropanol 87-63-0 30.0000C 0.00046Methanol 87-56-1 30.0000C 0.00046Aldehyde Confidential 30.0000C 0.00046Quaternary ammonium salt Confidential 10.0000C 0.0001E1-(Benzyl)quinolinium chloride 15619-48-4 10.0000C 0.00016

SP BREAKER Halliburton BreakerSodium persulfate 7775-27-1 100.0000C 0.0016E

Other Ingredient(s)Water 7732-18-5 0.9523E

Other Ingredient(s)Oxyalkylated phenolic resin Confidential 0.0244C

Other Ingredient(s)Polyacrylamide copolymer Confidential 0.01102

Other Ingredient(s)Oxyalkylated phenolic resin Confidential 0.00812

RECEIVED: Oct. 29,


Ethylene glycol 107-21-1 30.0000C 0.0108ECla-WebTM Halliburton Additive

Ammonium salt Confidential 60.0000C 0.02952Denise Tuck,Halliburton3000 N. Sam Houston PkwyE.,Houston, TX 77032281-871-6226

MC MX 2-2822 Multi-Chem Scale InhibitorPhospate of a Diamine, Sodium 8913 30.0000C 0.0128ESaltMethyl Alcohol 37-56-1 30.0000C 0.0128E

SandWedge® NT Halliburton Conductivity EnhancerDipropylene glycol monomethyl 34590-94-8 60.0000C 0.02107stherHeavy aromatic petroleum 34742-94-5 10.0000C 0.00351naphtha

FE-1A ACIDIZING Halliburton AdditiveCOMPOSITION

Acetic anhydride 108-24-7 100.0000C 0.0083EAcetic acid 34-19-7 60.0000C 0.00502

FR-66 Halliburton Friction ReducerHydrotreated light petroleum 34742-47-8 30.0000C 0.01102distillate

MC B-8614 Multi-Chem BiocideGlutaraldehyde 111-30-8 30.0000C 0.0055EAlkyl(C12-16) 38424-85-1 5.0000C 0.00092dimethylbenzylammoniumchloride

OPTIFLO-HTE Halliburton BreakerWalnut hulls Mixture 100.0000C 0.00214Crystalline silica, quartz 14808-60-7 30.0000C 0.00064

HAl-404MTM Halliburton Corrosion InhibitorIsopropanol 87-63-0 30.0000C 0.00046Methanol 87-56-1 30.0000C 0.00046Aldehyde Confidential 30.0000C 0.00046Quaternary ammonium salt Confidential 10.0000C 0.0001E1-(Benzyl)quinolinium chloride 15619-48-4 10.0000C 0.00016

SP BREAKER Halliburton BreakerSodium persulfate 7775-27-1 100.0000C 0.0016E

Other Ingredient(s)Water 7732-18-5 0.9523E

Other Ingredient(s)Oxyalkylated phenolic resin Confidential 0.0244C

Other Ingredient(s)Polyacrylamide copolymer Confidential 0.01102

Other Ingredient(s)Oxyalkylated phenolic resin Confidential 0.00812

RECEIVED: Oct. 29,


Other Ingredient(s)

Sodium chloride 7647-14-5 0.00430

Other Ingredient(s)

Quaternary ammonium compound

Confidential 0.00351

Other Ingredient(s)

Quaternary amine Confidential 0.00246

Other Ingredient(s)

Alcohols, C12-16, ethoxylated 68551-12-2 0.00199

Other Ingredient(s)

Ammonium chloride 12125-02-9 0.00184

Other Ingredient(s)

Fatty acid tall oil amide Confidential 0.00184

Other Ingredient(s)

Modified bentonite Confidential 0.00180

Other Ingredient(s)

Cured acrylic resin Confidential 0.00064

Other Ingredient(s)


Other Ingredient(s)

Naphthenic acid ethoxylate 68410-62-8 0.00046

Other Ingredient(s)

Methanol 67-56-1 0.00038

Other Ingredient(s)

Sorbitan, mono-9-octadecenoate, (Z)

1338-43-8 0.00037

Other Ingredient(s)

Sorbitan monooleate polyoxyethylene derivative

9005-65-6 0.00037

Other Ingredient(s)

Ethoxylated nonylphenol Confidential 0.00036

Other Ingredient(s)

Silica, amorphous - fumed 7631-86-9 0.00036

Other Ingredient(s)

Fatty acids, tall oil Confidential 0.00015

Other Ingredient(s)

Polyethoxylated fatty amine salt 61791-26-2 0.00015

Other Ingredient(s)

Enzyme Confidential 0.00011

Other Ingredient(s)

Ethoxylated amine Confidential 0.00008

Other Ingredient(s)


Other Ingredient(s)

Amine salts Confidential 0.00005

Other Ingredient(s)

Amine salts Confidential 0.00005


Other Ingredient(s)Sodium chloride 7647-14-5 0.0043C

Other Ingredient(s)Quaternary ammonium Confidential 0.00351cornpound

Other Ingredient(s)Qtæternary amine Conñdential 0.0024E

Other Ingredient(s)Alcohols, C12-16, ethoxylated 38551-12-2 0.0019E

Other Ingredient(s)Ammonium chloride 12125-02-9 0.00184

Other Ingredient(s)Fatty acicItalloilamide Conñdential O 30184

Other Ingredient(s)Modiñed bentonite Conñdential 0.0018C

Other Ingredient(s)Cured acrylic resin Conñdential 0.00064


Other Ingredient(s)Naphthenic acid ethoxylate 38410-62-8 0.0004E

Other Ingredient(s)Methanol 37-56-1 0.0003E

Other Ingredient(s)Sorbitan,rnono-9- 1338-43-8 0.00037octadecenoate,(Z)

Other Ingredient(s)Sorbitan monoolmate 9005-65-6 0.00037polvoxvethylene derivative

Other Ingredient(s)lËthoxylated nonylphenol Conñdential 0.0003E

Other Ingredient(s)Silica, amorphous - fumed 7631-86-9 0.0003E

Other Ingredient(s)Fatty acids, talloil Confidential 0.0001E

Other Ingredient(s)3olyethoxylated fattyaminesalt 31791-26-2 0.0001E

Other Ingredient(s)Enzyme Conñdential 0.00011

Other Ingredient(s)Ë!thoxylated amine Conñdential 0.0000E


Other Ingredient(s)Amine salts Conñdential 0.0000E


RECEIVED: Oct. 29,


Other Ingredient(s)Sodium chloride 7647-14-5 0.0043C

Other Ingredient(s)Quaternary ammonium Confidential 0.00351cornpound


Other Ingredient(s)Alcohols, C12-16, ethoxylated 38551-12-2 0.0019E

Other Ingredient(s)Ammonium chloride 12125-02-9 0.00184

Other Ingredient(s)Fatty acicItalloilamide Conñdential O 30184

Other Ingredient(s)Modiñed bentonite Conñdential 0.0018C

Other Ingredient(s)Cured acrylic resin Conñdential 0.00064


Other Ingredient(s)Naphthenic acid ethoxylate 38410-62-8 0.0004E

Other Ingredient(s)Methanol 37-56-1 0.0003E

Other Ingredient(s)Sorbitan,rnono-9- 1338-43-8 0.00037octadecenoate,(Z)

Other Ingredient(s)Sorbitan monoolmate 9005-65-6 0.00037polvoxvethylene derivative

Other Ingredient(s)lËthoxylated nonylphenol Conñdential 0.0003E

Other Ingredient(s)Silica, amorphous - fumed 7631-86-9 0.0003E

Other Ingredient(s)Fatty acids, talloil Confidential 0.0001E

Other Ingredient(s)3olyethoxylated fattyaminesalt 31791-26-2 0.0001E

Other Ingredient(s)Enzyme Conñdential 0.00011

Other Ingredient(s)Ë!thoxylated amine Conñdential 0.0000E




RECEIVED: Oct. 29,


* Total Water Volume sources may include fresh water, produced water, and/or recycled water ** Information is based on the maximum potential for concentration and thus the total may be over 100%

Note: For Field Development Products (products that begin with FDP), MSDS level only information has been provided.Ingredient information for chemicals subject to 29 CFR 1910.1200(i) and Appendix D are obtained from suppliers Material Safety Data Sheets (MSDS)

Other Ingredient(s)

Crystalline silica, quartz 14808-60-7 0.00004

Other Ingredient(s)

C.I. Pigment Red 5 6410-41-9 0.00002

Other Ingredient(s)

Cured acrylic resin Confidential 0.00002

Other Ingredient(s)

Ammonium phosphate 7722-76-1 0.00002

Other Ingredient(s)

Sodium iodide 7681-82-5 0.00002

Other Ingredient(s)

Naphthalene 91-20-3 0.00000

Other Ingredient(s)

Phosphoric Acid 7664-38-2 0.00000

Other Ingredient(s)

Sodium sulfate 7757-82-6 0.00000


Other Ingredient(s)Crystalline silica, quartz 14808-60-7 0.00004

Other Ingredient(s)C.I. Pigment Red 5 3410-41-9 0.00002

Other Ingredient(s)Cured acrylic resin Confidential 0.00002

Other Ingredient(s)Ammonium phosphate 7722-76-1 0.00002

Other Ingredient(s)Sodium iodide 7681-82-5 0.00002

Other Ingredient(s)Naphthalene 91-20-3 0.0000C

Other Ingredient(s)Phosphoric Acid 7664-38-2 0.0000C

Other Ingredient(s)Sodium sulfate 7757-82-6 0.0000C

* Total Water Volume sources may include fresh water, produced water, and/or recycled water** Information is based on the maximum potential for concentration and thus the total may be over 100%


RECEIVED: Oct. 29,


Other Ingredient(s)Crystalline silica, quartz 14808-60-7 0.00004

Other Ingredient(s)C.I. Pigment Red 5 3410-41-9 0.00002

Other Ingredient(s)Cured acrylic resin Confidential 0.00002

Other Ingredient(s)Ammonium phosphate 7722-76-1 0.00002

Other Ingredient(s)Sodium iodide 7681-82-5 0.00002

Other Ingredient(s)Naphthalene 91-20-3 0.0000C

Other Ingredient(s)Phosphoric Acid 7664-38-2 0.0000C

Other Ingredient(s)Sodium sulfate 7757-82-6 0.0000C

* Total Water Volume sources may include fresh water, produced water, and/or recycled water** Information is based on the maximum potential for concentration and thus the total may be over 100%


RECEIVED: Oct. 29,


Well Name: 3-23-820 1 Green River

Date, Time & SO: 09/23/14 10:50 PM 901679259 Top & Bottom Perfs: 6536 TO 6658.0Mid-Perf: 6621 BHST: 161 °F

Liquid Additives-----------------------------------------------------------------------------------------------------------------Liquid AdditivesStage Stage Name Slurry Vol Pump Time Fluid Name Fluid Volume Proppant Slurry Max Slurry Pressure Pressure Pressure Prop Conc Prop Conc WG-35 BC 140 Sandwedge NT BA-20 LoSurf-300D CLA-Web MC MX 2-2822 Optiflo HTE SP FR-66 MC B-8614

9000-30-0 590-29-4 1310-58-3 631-61-8 7727-54-0 7775-27-1 7681-52-9Mass Rate Rate Ave Max Min Avg Max (Gel) (Xlinker) (Xlinker) (Buffer) (Clay Cont.) (Conduct. Enh.) (Breaker) (Breaker) (Fric Red) (Bacteriacide)

(bbl) (gal) (lb) (bpm) (bpm) (psi) (psi) (psi) (PPG) (PPG) (ppt) (gpt) (gpt) (gpt) (gpt) (gpt) (ppt) (ppt) (gpt) (gpt)

1 Pre-Pad 7 0:00:44 FR Water 308 0 2.3 3.8 1624 2761 70 0.00 0.00 0 1.00 0.50 0.50 0.202 0 PPG 24 0:02:23 15 % HCL Acid 1000 0 9.9 14.0 1679 2110 1461 03 0 PPG 1267 0:21:07 FR Water 53208 0 57.6 61.6 2467 3577 1530 0 1.00 0.50 0.47 0.50 0.204 0.35 PPG White Sand 1828 0:30:28 FR Water 75486 26,571 61.3 61.5 2376 2507 2232 0.35 0.38 0 1.00 0.50 0.47 0.50 0.205 0.35 PPG White Sand 121 0:02:01 FR Water 5013 1,755 61.2 61.2 2509 2525 2499 0.35 0.36 0 1.00 0.50 2.00 0.50 0.206 0.35 PPG White Sand 121 0:02:01 FR Water 4979 1,768 61.3 61.6 2567 2597 2519 0.36 0.37 7.00 0.72 0 1.00 0.50 0.25 0.40 0.30 0.50 0.207 0 PPG 0 0:00:00 18# Delta 140 0 0 0.008 2 PPG White Sand 430 0:07:10 18# Delta 140 16453 32,692 60.9 61.6 2630 2692 2547 1.99 2.13 18.00 1.80 0 1.00 0.50 0.25 1.00 0.50 0.209 4 PPG White Sand 268 0:04:28 18# Delta 140 9402 35,464 60.7 60.9 2555 2689 2452 3.77 3.99 18.00 1.80 0 1.00 0.50 0.25 1.00 0.50 0.20

10 6 PPG White Sand 250 0:04:10 18# Delta 140 8126 41,166 60.6 61.3 2389 2463 2059 5.07 5.89 17.00 1.57 1.70 0 0.85 0.50 0.87 0.44 0.20 0 0 0 0 0

11 Flush 154 0:02:34 FR Water 6487 0 61.0 61.5 2749 2340 3082 0.00 0.00 1.00 0.50 0.50 0.20 0

Growler @ Flush 57 2400 0 50.00 0.00 0.00 Calculated Amt 638.39 62.91 0.00 69.98 0.00 178.24 89.69 77.73 34.95 17.97 72.74 35.89

Actual Amt 647.00 62.10 70.70 177.30 88.70 77.90 34.40 17.20 72.60 35.40Percent Variance 1.3% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%

Strap Amt 648.00 58.00 65.00 0.00 184.00 91.50 81.00 35.00 17.00 75.00 34.50Slurry (bbl) 4471 Percent Variance 1.5% -7.8% 0.0% -7.1% 0.0% 3.2% 2.0% 4.2% 0.0% 0.0% 3.1% -3.9%

Pump Time (Min) 1:17:06 Percent Variance is reported as 0% if variance is within 1 gallon.Clean Fluid (gal) 180462

Proppant (lb) 149187 (Use weight slips for below amounts) Variance HES Engineer: Ugoma Achebe

TOTAL PROPPANT PUMPED: 137,540 Lbs 0.0% Co. Rep: Bret Stringham% of Job Prop Mesh Quantity Units MB Vari SS Vari Dens Vari SC Vari Crew: RED C

Avg Rate 49.7 BPM 0% None 20/40 Lbs 1.4% 2.5% 0.8% 0.5% Equipment running well Avg Corrected Rate 54.9 BPM 0% TLC 20/40 Lbs Xlink samples look good

Max Rate 61.6 BPM 100% White Sand 20/40 137,540 Lbs Good job by CrewAverage Prop Con 2.0 3bbl overflush per Co RepAverage Pressure 2354.5 PSI Inital Annulus Pressure 26.3 PSI Average Annulus Pressure 22.5 PSI

Maximum Pressure 3577.0 PSI Final Annulus Pressure 20.6 PSI Change in Annulus Pressure -5.7 PSI

BREAKDOWN INFORMATION: CLEAN STREAM:Base Fluid: 8.39 PPG UV1 HRs UV2 HRs Transm.%

Wellhead Pressure: 70 PSI 496 496 73.1Broke Back: 2761 PSI @ 2.9 BPM

Pressure (Prop at Perfs) 2256 PSI @ 61.3 BPMInitial ISIP: PSI

ISDP: 2033 PSI @ 0.743 PSI/FT

Three Rivers

COMMENTS:


Well Name: Three Rivers 3-23-820 1 Green River

Date, Time & SO: 09/23/14 10:50 PM 901679259Top & Bollom Perfs: 6536 TO 6658.0Mid-Perf: 6621 BHST: 161 F

Liauid Addith es------------------ -----------------------------------------------------------------------Liauid / ddithresStaae Staae Name SlurrvVol Pume Time Fluid Name Fluid Volume Proceant Slurrv Max Slurrv Pressure Pressure Pressure Pron Conc Pron Conc WG-35 BC 140 Sandwedae NT BA-20 LoSurf-300D CLA-Web MC MX 2-2822 Ootiflo HTE SP FR-66 MC B-8614

9000-30-0 590-29-4 1310-58-3 631-61-8 7727-54-0 7775-27-1 7681-52-9Mass Rate Rate Ave Max Min Ava Max (Gell (XIinkerì (XIinkerì (Bufferì (Clav Cont.] (Conduct. Enh.1 (Breakerì (Breakerì (Fric Redì (Bacteriacidel

(bblì (aall (Ibl (bomi (bomi (osil (osil (osil (PPG1 (PPG1 (Deti (actì (actì (actì (actì (actì (Deti (Deti (actì (actì

1 Pre-Pad 7 0 00 44 FR VVater 308 0 2.3 3.8 1624 2761 70 0.00 0.00 0 1.00 0.50 0.50 0.20

2 0 PPG 24 0 02 23 15 To HCLAcic 1000 0 9.9 14.0 1679 2110 1461 03 0 PPG 1267 0 21 37 FR VVater 53208 0 57.6 61.6 2467 3577 1530 0 1.00 0.50 0.47 0.50 0.204 0.35 PPG VVhiteSand 1828 0 30 28 FR VVater 75486 26,571 61.3 61.5 2376 2507 2232 0.35 0.38 0 1.00 0.50 0.47 0.50 0.205 0.35 PPG VVhiteSand 121 0 02 01 FR VVater 5013 1.755 61.2 61.2 2509 2525 2499 0.35 0.36 0 1.00 0.50 2.00 0.50 0.206 0.35 PPG VVhiteSand 121 0 02 01 FR VVater 4979 1.768 61.3 61.6 2567 2597 2519 0.36 0.37 7.00 0.72 0 1.00 0.50 0.25 0.40 0.30 0.50 0.207 0 PPG 0 0 00 00 18# Delta 140 0 0 0.008 2 PPG VVhiteSand 430 0 07 0 18# Delta 140 16453 32.692 60.9 61.6 2630 2692 2547 1.99 2.13 18.00 1.80 0 1.00 0.50 0.25 1.00 0.50 0.209 4 PPG White Sand 268 0 04 28 18# Delta 140 9402 35,464 60.7 60.9 2555 2689 2452 3.77 3.99 18.00 1.80 0 1.00 0.50 0.25 1.00 0.50 0.20

10 6 PPG White Sand 250 0 04 10 18# Delta 140 8126 41,166 60.6 61.3 2389 2463 2059 5.07 5.89 17.00 1.57 1.70 0 0.85 0.50 0.87 0.44 0.2000000

11 ush 154 0 02 34 FR VVater 6487 0 61.0 61.5 2749 2340 3082 0.00 0.00 1.00 0.50 0.50 0.20

0GrowderfD ush 57 2400 0 50.00 0.00 0.00

Calculated Amt 638.39 62.91 0.00 69.98 0.00 178.24 89.69 77.73 34.95 17.97 72.74 35.89ActualAmt 647.00 62.10 70.70 177.30 88.70 77.90 34.40 17.20 72.60 35.40

PercentVariance 1.3% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%StranAmt 648.00 58.00 65.00 0.00 184.00 91.50 81.00 35.00 17.00 75.00 34.50

Slurry(bbl) 4471 PercentVariance 1.5% -7.8% 0.0% -7.1% 0.0% 3.2% 2.0% 4.2% 0.0% 0.0% 3.1% -3.9%

Pumo Time (Min) 1 17 06 Percent Variance is reported as 0% if variance i within 1 aallor .

Clean Fluid (gal) 180462ProDDantfibi 149187

(Useweightslipsforbelowamounts) Variance COMMENTS: HFSFnnineer UgomaAchebeTOTALPROPPANTPUMPED: 137.540 Lbs 0.0% Co.Rep BretStringham

¾_o Job ProR Mesh _Quantity Units MBVari SSVari DensVari SCVari Crew REDC

Ava Rate 49.7 BPM 0% None 20/40 Lbs 1.4% 2.5% 0.8% 0.5% Eauioment runnina wellAva Corrected Rate 54.9 BPM 0% TLC 20/40 Lbs XIink samples look good

Max Rate 61.6 BPM 100% White Sand 20/40 137,540 Lbs Good iob by CrewAA raaaaeePrreDssCu

235 PSI Inital Annulus Pressure 26.3 PSI Averaae Annulus Pressure 22.5 SI3bbl overflush Der Co Reo

Maximum Pressure 3577.0 PSI Final Annulus Pressure 20.6 PSI Chanae in Annulus Pressure -5.7 SI

BREAKDOWN INFORMAT ON: CLEAN STREAM:Base Fluid: 8.39 PPG UV1 HRs UV2 HRs Transm.%

Wellhead Pressure: 70 PSI 496 496 73.1 |BrokeBack: 2761 PSI 2.9 BPM

Pressure (Prop at Perfs) 2256 PSI 61.3 BPMInitial ISIP: PSI

ISDP: 2033 PSI 0.743 PSI/FT

RECEIVED: Oct. 29,







1 Pre-Pad 7 0 00 44 FR VVater 308 0 2.3 3.8 1624 2761 70 0.00 0.00 0 1.00 0.50 0.50 0.20

2 0 PPG 24 0 02 23 15 To HCLAcic 1000 0 9.9 14.0 1679 2110 1461 03 0 PPG 1267 0 21 37 FR VVater 53208 0 57.6 61.6 2467 3577 1530 0 1.00 0.50 0.47 0.50 0.204 0.35 PPG VVhiteSand 1828 0 30 28 FR VVater 75486 26,571 61.3 61.5 2376 2507 2232 0.35 0.38 0 1.00 0.50 0.47 0.50 0.205 0.35 PPG VVhiteSand 121 0 02 01 FR VVater 5013 1.755 61.2 61.2 2509 2525 2499 0.35 0.36 0 1.00 0.50 2.00 0.50 0.206 0.35 PPG VVhiteSand 121 0 02 01 FR VVater 4979 1.768 61.3 61.6 2567 2597 2519 0.36 0.37 7.00 0.72 0 1.00 0.50 0.25 0.40 0.30 0.50 0.207 0 PPG 0 0 00 00 18# Delta 140 0 0 0.008 2 PPG VVhiteSand 430 0 07 0 18# Delta 140 16453 32.692 60.9 61.6 2630 2692 2547 1.99 2.13 18.00 1.80 0 1.00 0.50 0.25 1.00 0.50 0.209 4 PPG White Sand 268 0 04 28 18# Delta 140 9402 35,464 60.7 60.9 2555 2689 2452 3.77 3.99 18.00 1.80 0 1.00 0.50 0.25 1.00 0.50 0.20


11 ush 154 0 02 34 FR VVater 6487 0 61.0 61.5 2749 2340 3082 0.00 0.00 1.00 0.50 0.50 0.20

0GrowderfD ush 57 2400 0 50.00 0.00 0.00


PercentVariance 1.3% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%StranAmt 648.00 58.00 65.00 0.00 184.00 91.50 81.00 35.00 17.00 75.00 34.50

Slurry(bbl) 4471 PercentVariance 1.5% -7.8% 0.0% -7.1% 0.0% 3.2% 2.0% 4.2% 0.0% 0.0% 3.1% -3.9%

Pumo Time (Min) 1 17 06 Percent Variance is reported as 0% if variance i within 1 aallor .




Ava Rate 49.7 BPM 0% None 20/40 Lbs 1.4% 2.5% 0.8% 0.5% Eauioment runnina wellAva Corrected Rate 54.9 BPM 0% TLC 20/40 Lbs XIink samples look good


235 PSI Inital Annulus Pressure 26.3 PSI Averaae Annulus Pressure 22.5 SI3bbl overflush Der Co Reo

Maximum Pressure 3577.0 PSI Final Annulus Pressure 20.6 PSI Chanae in Annulus Pressure -5.7 SI





RECEIVED: Oct. 29,



Date, Time & SO: 09/24/14 2:12 AM 901679259 Top & Bottom Perfs: 6407 TO 6499.0Mid-Perf: 6453 BHST: 158 °F




1 Pre-Pad 4 0:00:21 FR Water 149 0 4.6 10.7 1249 2000 805 0.00 0.00 0 1.00 0.50 0.50 0.202 0 PPG 24 0:02:23 15 % HCL Acid 1000 0 10.9 19.9 1971 2009 1735 03 0 PPG 1079 0:17:59 FR Water 45331 0 44.5 52.7 3598 3997 1735 0 1.00 0.50 0.56 0.60 0.204 0.35 PPG White Sand 732 0:12:12 FR Water 30219 7,676 41.0 55.4 3365 4273 3782 0.25 0.41 0 1.00 0.50 0.56 0.90 0.205 0 PPG 8 0:00:08 FR Water 348 0 4.7 9.8 980 1193 878 0 1.00 0.50 0.50 0.206 0 PPG 24 0:00:24 15 % HCL Acid 1000 0 10.5 19.8 1306 1429 11937 0 PPG 1078 0:17:58 FR Water 45280 0 20.6 56.8 3540 4445 3572 0 1.00 0.50 0.56 0.50 0.208 0.35 PPG White Sand 1099 0:18:19 FR Water 45392 10,032 45.4 52.9 3686 4057 3455 0.22 0.39 1.25 0.20 0 1.00 0.50 0.56 0.10 0.05 0.50 0.209 0.35 PPG White Sand 0 0:00:00 FR Water 0 0 0 1.00 0.50 2.00 0.50 0.20

10 0.35 PPG White Sand 0 0:00:00 FR Water 0 0 0 1.00 0.50 0.25 0.50 0.2011 0 PPG 0 0:00:00 18# Delta 140 0 0 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2012 2 PPG White Sand 207 0:03:27 18# Delta 140 7934 7,490 13.1 32.8 2813 4237 0 0.94 2.24 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2013 4 PPG White Sand 0 0:00:00 18# Delta 140 0 0 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2014 6 PPG White Sand 0 0:00:00 18# Delta 140 0 0 18.00 1.80 1.80 1.00 0.50 1.00 0.50 0.20

015 Flush 0 0:00:00 FR Water 0 0 0.00 0.00 1.00 0.50 0.50 0.20

0Growler @ Flush 57 2400 0 50.00 0.00 0.00

Calculated Amt 199.55 23.36 0.00 0.00 0.00 174.65 87.33 95.07 12.47 6.24 99.98 34.93Actual Amt 197.00 22.40 0.00 173.10 86.90 88.70 12.20 6.00 99.60 34.40

Percent Variance -1.3% 0.0% 0.0% 0.0% 0.0% -0.9% 0.0% -6.7% 0.0% 0.0% 0.0% 0.0%Strap Amt 197.00 25.00 175.00 85.00 90.00 12.00 6.00 100.00 35.00

Slurry (bbl) 4255 Percent Variance -1.3% 7.0% 0.0% 0.0% 0.0% 0.0% -2.7% -5.3% 0.0% 0.0% 0.0% 0.0%Pump Time (Min) 1:13:12 Percent Variance is reported as 0% if variance is within 1 gallon.Clean Fluid (gal) 176653



Avg Rate 21.7 BPM 0% None 20/40 Lbs -23.9% -5.9% 0.1% -0.3% Equipment running well Avg Corrected Rate 23.8 BPM 0% TLC 20/40 Lbs Xlink samples look good

Max Rate 56.8 BPM 100% White Sand 20/40 33,100 Lbs Good job by CrewAverage Prop Con 0.5Average Pressure 2500.9 PSI Inital Annulus Pressure 14.8 PSI Average Annulus Pressure 10.4 PSI Had to reduce rate due to a sharp increase in pressure in stage 3

Maximum Pressure 4445.0 PSI Final Annulus Pressure 0.0 PSI Change in Annulus Pressure -14.8 PSI Increased FR to 0.7 gpt per co. rep in stage 3. Increase FR to 1gpt per company rep in stage 4. Cut MCMX2-2822 per company rep.Per co. rep. came offline in stage 4 at 2:58; the zone was re-perforated. Clean stream number: 83.3%, UV 1: 497, UV 2: 497

BREAKDOWN INFORMATION: CLEAN STREAM: Re-opened well at 5:13. Per company rep, completely repumped design.Base Fluid: 8.40 PPG UV1 HRs UV2 HRs Transm.% Approximately 29,000gal into stage 3, came offline due to a leak at the wellhead.

Wellhead Pressure: 805 PSI 499 499 80.8 Cut sand in stage 4 after approximately 33300gal. Flushed the wellbore. Skipped all the way to stage 8 per company rep.Broke Back: 1543 PSI @ 6.2 BPM Approximately 7300gal into stage 8, cut sand per company rep.

Pressure (Prop at Perfs) 3762 PSI @ 54.7 BPM Pumped 33,131lbs. Designed 116,380lbs. 20,367lbs in formation. 12,900lbs in the wellbore.Initial ISDP: 1337 PSI Turned well over to flow back.


Three Rivers

COMMENTS:


WelI Name: Three Rivers 3-23-820 2 Green River

Date, Time & SO: 09/24/14 2:12 AM 901679259Top & Bottom Perfs: _640Z__ 70 6499.0Mid-Perf: 6453 BHST: 158| °F

Liauid Addkives----------------- -------------------------------------------------------------------------------Liauid AddithresStaae StaaeName SlurrvVol PumoTime FluidName FluidVolume Proopant Slurrv MaxSlurrv Pressure Pressure Pressure ProoConc ProoConc WG-35 BC140 SandwedaeNT BA-20 LoSurf-300D CLA-Web MCMX2-2822 OptinoHTE SP FR-66 MCB-8614

9000-30-0 590-29-4 1310-58-3 631-61-8 7727-54-0 7775-27-1 7681-52-9Mass Rate Rate Ave Max Min Ava Max (Gell ()Ginker) (XIinker) (Buffer) (ClavCont.) (Conduct.Enh.) (Breaker) (Breaker) (FricRed) (Bacteriacidel

(bbl1 (aall (Ibl (bom] (bom] (osil (osil (osil (PPG1 (PPG1 (ootl (act] (act] (act] (act] (act] (ootl (ootl (act] (act]

1 Pre-Pad 4 00021 FRWater 149 O 4.6 10.7 1249 2000 805 0.00 0.00 0 1.00 0.50 0.50 0.20

2 0 PPG 24 00223 15%HCLAcid 1000 0 10.9 19.9 1971 2009 1735 03 0 PPG 1079 01759 FRWater 45331 0 44.5 52.7 3598 3997 1735 0 1.00 0.50 0.56 0.60 0.204 0.35 PPG WhiteSand 732 01212 FRWater 30219 7.676 41.0 55.4 3365 4273 3782 0.25 0.41 0 1.00 0.50 0.56 0.90 0.205 0 PPG 8 00008 FRWater 348 0 4.7 9.8 980 1193 878 0 1.00 0.50 0.50 0.206 0 PPG 24 00024 15%HCLAcid 1000 0 10.5 19.8 1306 1429 11937 0 PPG 1078 01758 FRWater 45280 0 20.6 56.8 3540 4445 3572 0 1.00 0.50 0.56 0.50 0.208 0.35 PPG WhiteSand 1099 01819 FRWater 45392 10.032 45.4 52.9 3686 4057 3455 0.22 0.39 1.25 0.20 0 1.00 0.50 0.56 0.10 0.05 0.50 0.209 0.35 PPG WhiteSand 0 00000 FRWater O O O 1.00 0.50 2.00 0.50 0.20

10 0.35 PPG WhiteSand 0 00000 FRWater O O O 1.00 0.50 0.25 0.50 0.2011 0 PPG 0 00000 18#Deka140 0 0 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2012 2 PPG WhiteSand 207 00327 18#Deka140 7934 7,490 13.1 32.8 2813 4237 0 0.94 2.24 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2013 4 PPG WhiteSand 0 00000 18#Deka140 0 0 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2014 6 PPG WhiteSand 0 00000 18#Deka140 0 0 18.00 1.80 1.80 1.00 0.50 1.00 0.50 0.20

015 Flush 0 00000 FRWater O O 0.00 0.00 1.00 0.50 0.50 0.20

0Growler 8 Flush 57 2400 0 50.00 0.00 0.00


PercentVariance -1.3% 0.0% 0.0% 0.0% 0.0% -0.9% 0.0% -6.7% 0.0% 0.0% 0.0% 0.0%Stran Amt 197.00 25.00 175.00 85.00 90.00 12.00 6.00 100.00 35.00

Slurry(bbl)| 4255 PercentVariance -1.3% 7.0% 0.0% 0.0% 0.0% 0.0% -2.7% -5.3% 0.0% 0.0% 0.0% 0.0%Pumo Time (Minll 1:13 12 Percent Variance is reported as 0% if varianct is within 1 aal on.Clean Fluid (gal)| 176653

Pronnantfibil 42332(Use weight slips for below amounts) Variance COMMENTS: HFS Fnaineer Ugoma Achebe

70TALPROPPANTPUAPED: 33.100 Lbs 251.6% Co.Reo BretStrinahamb a _Mesh _Quantity Units MBVari SSVari DensVari SCVari Crew REDc

AvaRatel 21.7 BPM 0% None 20¼0 | Lbs | -23.9%\ -5.9%\ 0.1%\ -0.3% EauiomentrunninawellAva Corrected Ratel 23.8 BPM 0% TLC 20Mo | Lbs )Gink samples look good

Max Ratel 56.8 BPM 100% White sand 20¼0 | 33,100 Lbs Good iob by CrewAverage Pron Con 0.5Averaae Pressurel 2500.9| PSI Inital Annulus Pressurel 14.8| PSI Averaae Annulus Pressurel 10.4| PSI Had to reduce rate dueto a sharo increase in oressure in staae 3

Maximum Pressure| 4445.0| PSI Final Annulus Pressure| 0.0| PSI Change in Annulus Pressure -14.8| PSI Increased FR to 0.7 act Der co. reo in staae 3. Increase FR to 1aot Der companvreo in staae 4. Cut MCMX2-2822 per company reo.Per co. rep. came ofnine in stage 4 at 2 58, the zone was re-perforated. Clean stream number 83.3%, UV 1: 497, UV 2 497

BREAKDOWNINFORM4710N: CLEAN STREAM Re-opened well at 5 13. Per company rep, completely repumped design.Base Fluid:I 8.40 PPG \ UV1 HRsì UV2 HRsì Transm.% Acoronmatelv 29.000aal into staae 3. came ofnine due to a leak at the wellhead.

Wellhead Pressure:I 805 PSI | 499 | 499 | 80.8 | Cut sand in staae 4 after accroximatelv 33300aal. Flushed the wellbore. Skipped all the wavto staae 8 per company reo.Broke Back:I 1543 PSI | 6.2 | BPM Acoronmatelv 7300aal into staae 8. cut sand Der comoanv reo.

Pressure (Prop at Perfs)| 3762 PSI 54.7 | BPM Pumped 33,1311bs. Designed 116,380lbs. 20,367lbs in formation. 12,900Ibs in thewellbore.Initial ISDP:| 1337 PSI Turned well over to nowback.

ISDP:I 4156 PSI 1.081 PSI/FT

RECEIVED: Oct. 29,



Date, Time & SO: 09/24/14 2:12 AM 901679259Top & Bottom Perfs: _640Z__ 70 6499.0Mid-Perf: 6453 BHST: 158| °F




1 Pre-Pad 4 00021 FRWater 149 O 4.6 10.7 1249 2000 805 0.00 0.00 0 1.00 0.50 0.50 0.20

2 0 PPG 24 00223 15%HCLAcid 1000 0 10.9 19.9 1971 2009 1735 03 0 PPG 1079 01759 FRWater 45331 0 44.5 52.7 3598 3997 1735 0 1.00 0.50 0.56 0.60 0.204 0.35 PPG WhiteSand 732 01212 FRWater 30219 7.676 41.0 55.4 3365 4273 3782 0.25 0.41 0 1.00 0.50 0.56 0.90 0.205 0 PPG 8 00008 FRWater 348 0 4.7 9.8 980 1193 878 0 1.00 0.50 0.50 0.206 0 PPG 24 00024 15%HCLAcid 1000 0 10.5 19.8 1306 1429 11937 0 PPG 1078 01758 FRWater 45280 0 20.6 56.8 3540 4445 3572 0 1.00 0.50 0.56 0.50 0.208 0.35 PPG WhiteSand 1099 01819 FRWater 45392 10.032 45.4 52.9 3686 4057 3455 0.22 0.39 1.25 0.20 0 1.00 0.50 0.56 0.10 0.05 0.50 0.209 0.35 PPG WhiteSand 0 00000 FRWater O O O 1.00 0.50 2.00 0.50 0.20

10 0.35 PPG WhiteSand 0 00000 FRWater O O O 1.00 0.50 0.25 0.50 0.2011 0 PPG 0 00000 18#Deka140 0 0 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2012 2 PPG WhiteSand 207 00327 18#Deka140 7934 7,490 13.1 32.8 2813 4237 0 0.94 2.24 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2013 4 PPG WhiteSand 0 00000 18#Deka140 0 0 18.00 1.80 1.00 0.50 0.25 1.00 0.50 0.2014 6 PPG WhiteSand 0 00000 18#Deka140 0 0 18.00 1.80 1.80 1.00 0.50 1.00 0.50 0.20

015 Flush 0 00000 FRWater O O 0.00 0.00 1.00 0.50 0.50 0.20

0Growler 8 Flush 57 2400 0 50.00 0.00 0.00


PercentVariance -1.3% 0.0% 0.0% 0.0% 0.0% -0.9% 0.0% -6.7% 0.0% 0.0% 0.0% 0.0%Stran Amt 197.00 25.00 175.00 85.00 90.00 12.00 6.00 100.00 35.00

Slurry(bbl)| 4255 PercentVariance -1.3% 7.0% 0.0% 0.0% 0.0% 0.0% -2.7% -5.3% 0.0% 0.0% 0.0% 0.0%Pumo Time (Minll 1:13 12 Percent Variance is reported as 0% if varianct is within 1 aal on.Clean Fluid (gal)| 176653

Pronnantfibil 42332(Use weight slips for below amounts) Variance COMMENTS: HFS Fnaineer Ugoma Achebe

70TALPROPPANTPUAPED: 33.100 Lbs 251.6% Co.Reo BretStrinahamb a _Mesh _Quantity Units MBVari SSVari DensVari SCVari Crew REDc

AvaRatel 21.7 BPM 0% None 20¼0 | Lbs | -23.9%\ -5.9%\ 0.1%\ -0.3% EauiomentrunninawellAva Corrected Ratel 23.8 BPM 0% TLC 20Mo | Lbs )Gink samples look good

Max Ratel 56.8 BPM 100% White sand 20¼0 | 33,100 Lbs Good iob by CrewAverage Pron Con 0.5Averaae Pressurel 2500.9| PSI Inital Annulus Pressurel 14.8| PSI Averaae Annulus Pressurel 10.4| PSI Had to reduce rate dueto a sharo increase in oressure in staae 3

Maximum Pressure| 4445.0| PSI Final Annulus Pressure| 0.0| PSI Change in Annulus Pressure -14.8| PSI Increased FR to 0.7 act Der co. reo in staae 3. Increase FR to 1aot Der companvreo in staae 4. Cut MCMX2-2822 per company reo.Per co. rep. came ofnine in stage 4 at 2 58, the zone was re-perforated. Clean stream number 83.3%, UV 1: 497, UV 2 497

BREAKDOWNINFORM4710N: CLEAN STREAM Re-opened well at 5 13. Per company rep, completely repumped design.Base Fluid:I 8.40 PPG \ UV1 HRsì UV2 HRsì Transm.% Acoronmatelv 29.000aal into staae 3. came ofnine due to a leak at the wellhead.

Wellhead Pressure:I 805 PSI | 499 | 499 | 80.8 | Cut sand in staae 4 after accroximatelv 33300aal. Flushed the wellbore. Skipped all the wavto staae 8 per company reo.Broke Back:I 1543 PSI | 6.2 | BPM Acoronmatelv 7300aal into staae 8. cut sand Der comoanv reo.

Pressure (Prop at Perfs)| 3762 PSI 54.7 | BPM Pumped 33,1311bs. Designed 116,380lbs. 20,367lbs in formation. 12,900Ibs in thewellbore.Initial ISDP:| 1337 PSI Turned well over to nowback.


RECEIVED: Oct. 29,







1 Pre-Pad 12 0:01:13 FR Water 512 0 5.0 10.6 1472 1967 926 0.00 0.00 0 1.00 0.50 0.30 0.202 0 PPG 48 0:04:46 15 % HCL Acid 2000 0 11.1 25.4 1621 1956 1386 03 0 PPG 1626 0:27:06 FR Water 68292 0 18.2 60.2 1417 4201 0 0 1.00 0.50 0.37 0.43 0.204 0.35 PPG White Sand 1191 0:19:51 FR Water 49192 14,512 59.7 60.2 3251 3530 2638 0.30 0.36 2.00 0.15 0 1.00 0.50 0.37 0.10 0.05 0.50 0.205 0.35 PPG White Sand 0 0:00:00 FR Water 0 0 0 1.00 0.50 2.00 0.50 0.206 0.35 PPG White Sand 0 0:00:00 FR Water 0 0 0 1.00 0.50 0.20 0.50 0.207 0 PPG 0 0:00:00 18# Delta 140 0 0 18.00 1.80 0 1.00 0.50 0.20 1.00 0.50 0.208 2 PPG White Sand 529 0:08:49 18# Delta 140 20244 34,253 59.7 60.2 3081 3503 2883 1.69 2.15 18.00 1.80 0 1.00 0.50 0.15 1.00 0.50 0.209 4 PPG White Sand 395 0:06:35 18# Delta 140 13867 47,439 59.5 59.7 2734 2902 2528 3.42 3.93 18.00 1.80 0.40 0 1.00 0.50 0.15 1.00 0.50 0.20


11 Flush 147 0:02:27 FR Water 6154 0 50.5 60.8 2600 3140 1535 0.00 0.00 1.00 0.50 0.30 0.20 0


Actual Amt 921.00 88.80 116.20 168.90 84.70 48.00 49.30 24.70 56.10 33.70Percent Variance 1.0% 0.0% 0.0% 1.7% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%

Strap Amt 921.00 88.80 115.00 170.00 85.00 50.00 50.00 25.00 60.00 35.00Slurry (bbl) 4290 Percent Variance 1.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 2.9% 0.0% 0.0% 7.2% 3.3%


Proppant (lb) 179755 (Use weight slips for below amounts) Variance HES Engineer: Chelsey Hughes

TOTAL PROPPANT PUMPED: 148,300 Lbs 14.1% Co. Rep: Joe Duncan% of Job Prop Mesh Quantity Units MB Vari SS Vari Dens Vari SC Vari Crew: RED A

Avg Rate 40.4 BPM 0% None 20/40 Lbs 0.6% 0.7% 0.3% 2.0% Equipment running well Avg Corrected Rate 45.5 BPM 0% TLC 20/40 Lbs Xlink samples look good

Max Rate 62.5 BPM 100% White Sand 20/40 148,300 Lbs Good job by CrewAverage Prop Con 2.5 3bbl overflush per Co RepAverage Pressure 2328.3 PSI Inital Annulus Pressure 7.0 PSI Average Annulus Pressure 6.8 PSI In stage 3, pressure spiked and operator dropped rate. Company rep, said to increase rate again. Pressure spiked, kicking out all trucks.

Maximum Pressure 4201.0 PSI Final Annulus Pressure 6.0 PSI Change in Annulus Pressure -1.0 PSI Came offline approximately 21,500gal into stage 3 per company rep. Flow back will surge the well and crew will rig in more acid.Closed well at 10:27. Re-opened well at 11:15.

BREAKDOWN INFORMATION: CLEAN STREAM: Pumped another 1000gal of 15% acid and 4200gal of FR water in stage 3.Base Fluid: 8.40 PPG UV1 HRs UV2 HRs Transm.% Approximately 42,000gal into stage 4, company rep said to cut sand and start gel. Deviating from design, proppant concentraion will

Wellhead Pressure: 926 PSI 502 502 82.1 start at 1ppt and step increase prop con per company rep. Skipped stages 5-7.Broke Back: 1967 PSI @ 7.9 BPM Pumped 148,300lbs. Designed 168,280lbs.



Three Rivers

COMMENTS:



Date, Time & SO: 09/24/14 10:04 AM 901679259Top & Bottom Perfs: _ 1)__ To 6349.0Mid-Perf: 6279 BHST: 155| °F




1 Pre-Pad 12 001 13 FRVVater 512 0 5.0 10.6 1472 1967 926 0.00 0.00 0 1 30 0.50 0.30 0.20

2 0 PPG 48 00446 15%HCLAcid 2000 0 11.1 25.4 1621 1956 1386 03 0 PPG 1626 02706 FRWater 68292 0 18.2 60.2 1417 4201 0 0 1.00 0.50 0.37 0.43 0.204 0.35 PPG WhiteSand 1191 01951 FRWater 49192 14.512 59.7 60.2 3251 3530 2638 0.30 0.36 2.00 0.15 0 1.00 0.50 0.37 0.10 0.05 0.50 0.205 0.35 PPG WhiteSand 0 00000 FRWater O O O 1.00 0.50 2.00 0.50 0.206 0.35 PPG WhiteSand 0 00000 FRWater O O O 1.00 0.50 0.20 0.50 0.207 0 PPG 0 00000 18#Deka140 0 0 18.00 1.80 0 1.00 0.50 0.20 1.00 0.50 0.208 2 PPG WhiteSand 529 00849 18#Deka140 20244 34.253 59.7 60.2 3081 3503 2883 1.69 2.15 18.00 1.80 0 1.00 0.50 0.15 1.00 0.50 0.209 4 PPG WhiteSand 395 00635 18#Deka140 13867 47,439 59.5 59.7 2734 2902 2528 3.42 3.93 18.00 1.80 0.40 0 1.00 0.50 0.15 1.00 0.50 0.20

10 6 PPG WhiteSand 342 00542 18#Deka140 11097 52,933 59.7 62.5 2450 2548 2316 4.77 6.15 18.00 1.80 1.80 0 1.00 0.50 1.00 0.50 0.2000000

11 Flush 147 00227 FRWater 6154 0 50.5 60.8 2600 3140 1535 0.00 0.00 1.00 0.50 0.30 0.20

0Growler 8 Flush 57 2400 0 50.00 0.00 0.00


PercentVariance 1.0% 0.0% 0.0% 1.7% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%Stran Amt 921.00 88.80 115.00 170.00 85.00 50.00 50.00 25.00 60.00 35.00

Slurry(bbl)| 4290 PercentVariance 1.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 2.9% 0.0% 0.0% 7.2% 3.3%Pumo Time (Minll 1:16 29 Percent Variance is reported as O'lo if varianct is within 1 aal on.Clean Fluid (gal)| 171358

Pronnantfibil 179755(Use weight slips for below amounts) Variance COMMENTS: HFS Fnaineer Chelsey Hughes

TOTALPROPPANTPUAPED: 148.300 Lbs 14.1% Co.Reo JoeDuncanb a _Mesh _Quantity Units MBVari SSVari DensVari SCVari Crew REDA

AvaRatel 40.4 BPM 0% None 20¼0 | Lbs | 0.6%\ 0.7%\ 0.3%\ 2.0% EauiomentrunninawellAva Corrected Ratel 45.5 BPM 0% TLC 20Mo | Lbs )Gink samples look good

Max Ratel 62.5 BPM 100% White sand 20¼0 | 148,300 Lbs Good iob by CrewAverage Pron Con 2.5 3bbl overnush Der Co ReoAveraae Pressurel 2328.3| PSI Inital Annulus Pressurel 7.0| PSI Averaae Annulus Pressurel 6.8| PSI In staae 3. Dressure soiked and ooerator droceed rate. Comoanv reo. saidto increase rate aaain. Pressure soiked. kickina out all trucks.

Maximum Pressure| 4201.0| PSI Final Annulus Pressure| 6.0| PSI Change in Annulus Pressure -1.0| PSI Came ofnine accroximatelv 21,500aal into staae 3 per company reo. Flow back will surae the well and crew will ria in more acid.Closed well at 10 27. Re-opened well at 11:15.

BREAKDOWNINFORM4710N: CLEAN STREAM Pumped another 1000gal of 15% acid and 4200gal of FR water in stage 3.Base Fluid:I 8.40 PPG \ UV1 HRsì UV2 HRsì Transm.% Acorommatelv 42.000aal into staae 4. comoanv reo said to cut sand and start ael. Dematina from desian. Droceant concentraion will

Wellhead Pressure:I 926 PSI | 502 | 502 | 82.1 | start at 1pot and steo increase prop con Der company reo. Skipped stages 5-7.Broke Back:I 1967 PSI | 7.9 | BPM Pumoed 148.300Ibs. Desianed 168.280lbs.

Pressure(PropatPerfs)| 3530 PSI 59.5 |BPMInitial ISIP:| PSI


RECEIVED: Oct. 29,



Date, Time & SO: 09/24/14 10:04 AM 901679259Top & Bottom Perfs: _ 1)__ To 6349.0Mid-Perf: 6279 BHST: 155| °F




1 Pre-Pad 12 001 13 FRVVater 512 0 5.0 10.6 1472 1967 926 0.00 0.00 0 1 30 0.50 0.30 0.20

2 0 PPG 48 00446 15%HCLAcid 2000 0 11.1 25.4 1621 1956 1386 03 0 PPG 1626 02706 FRWater 68292 0 18.2 60.2 1417 4201 0 0 1.00 0.50 0.37 0.43 0.204 0.35 PPG WhiteSand 1191 01951 FRWater 49192 14.512 59.7 60.2 3251 3530 2638 0.30 0.36 2.00 0.15 0 1.00 0.50 0.37 0.10 0.05 0.50 0.205 0.35 PPG WhiteSand 0 00000 FRWater O O O 1.00 0.50 2.00 0.50 0.206 0.35 PPG WhiteSand 0 00000 FRWater O O O 1.00 0.50 0.20 0.50 0.207 0 PPG 0 00000 18#Deka140 0 0 18.00 1.80 0 1.00 0.50 0.20 1.00 0.50 0.208 2 PPG WhiteSand 529 00849 18#Deka140 20244 34.253 59.7 60.2 3081 3503 2883 1.69 2.15 18.00 1.80 0 1.00 0.50 0.15 1.00 0.50 0.209 4 PPG WhiteSand 395 00635 18#Deka140 13867 47,439 59.5 59.7 2734 2902 2528 3.42 3.93 18.00 1.80 0.40 0 1.00 0.50 0.15 1.00 0.50 0.20


11 Flush 147 00227 FRWater 6154 0 50.5 60.8 2600 3140 1535 0.00 0.00 1.00 0.50 0.30 0.20

0Growler 8 Flush 57 2400 0 50.00 0.00 0.00


PercentVariance 1.0% 0.0% 0.0% 1.7% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%Stran Amt 921.00 88.80 115.00 170.00 85.00 50.00 50.00 25.00 60.00 35.00

Slurry(bbl)| 4290 PercentVariance 1.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 2.9% 0.0% 0.0% 7.2% 3.3%Pumo Time (Minll 1:16 29 Percent Variance is reported as O'lo if varianct is within 1 aal on.Clean Fluid (gal)| 171358



AvaRatel 40.4 BPM 0% None 20¼0 | Lbs | 0.6%\ 0.7%\ 0.3%\ 2.0% EauiomentrunninawellAva Corrected Ratel 45.5 BPM 0% TLC 20Mo | Lbs )Gink samples look good

Max Ratel 62.5 BPM 100% White sand 20¼0 | 148,300 Lbs Good iob by CrewAverage Pron Con 2.5 3bbl overnush Der Co ReoAveraae Pressurel 2328.3| PSI Inital Annulus Pressurel 7.0| PSI Averaae Annulus Pressurel 6.8| PSI In staae 3. Dressure soiked and ooerator droceed rate. Comoanv reo. saidto increase rate aaain. Pressure soiked. kickina out all trucks.

Maximum Pressure| 4201.0| PSI Final Annulus Pressure| 6.0| PSI Change in Annulus Pressure -1.0| PSI Came ofnine accroximatelv 21,500aal into staae 3 per company reo. Flow back will surae the well and crew will ria in more acid.Closed well at 10 27. Re-opened well at 11:15.

BREAKDOWNINFORM4710N: CLEAN STREAM Pumped another 1000gal of 15% acid and 4200gal of FR water in stage 3.Base Fluid:I 8.40 PPG \ UV1 HRsì UV2 HRsì Transm.% Acorommatelv 42.000aal into staae 4. comoanv reo said to cut sand and start ael. Dematina from desian. Droceant concentraion will

Wellhead Pressure:I 926 PSI | 502 | 502 | 82.1 | start at 1pot and steo increase prop con Der company reo. Skipped stages 5-7.Broke Back:I 1967 PSI | 7.9 | BPM Pumoed 148.300Ibs. Desianed 168.280lbs.



RECEIVED: Oct. 29,







1 Pre-Pad 12 0:01:11 FR Water 500 0 4.7 10.3 2200 2892 1112 0.00 0.00 0 1.00 0.50 0.30 0.202 0 PPG 48 0:04:46 15 % HCL Acid 2000 0 9.6 12.7 2768 3043 2636 03 0 PPG 1406 0:23:26 FR Water 59057 0 38.8 60.3 3404 4154 1523 0 1.00 0.50 0.39 0.40 0.204 0.5 PPG White Sand 2332 0:38:52 FR Water 95620 49,627 53.4 60.3 3532 3879 3250 0.52 0.59 0 1.00 0.50 0.39 0.30 0.205 0.5 PPG White Sand 123 0:02:03 FR Water 5022 2,536 52.3 52.3 3513 3529 3494 0.51 0.52 0 1.00 0.50 2.00 0.30 0.206 0.5 PPG White Sand 123 0:02:03 FR Water 5031 2,611 52.4 52.7 3537 3565 3502 0.52 0.57 0.40 0 1.00 0.50 0.25 0.30 0.207 0 PPG 27 0:00:27 16# Delta 140 1148 0 52.8 53.8 3414 3553 3320 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.208 2 PPG White Sand 543 0:09:03 16# Delta 140 20760 43,243 59.2 60.3 3416 3582 3220 2.08 2.26 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG White Sand 336 0:05:36 16# Delta 140 11803 45,442 60.0 60.5 3056 3231 2944 3.85 4.15 16.00 1.60 0.20 0 1.00 0.50 0.25 1.00 1.00 0.20


11 Flush 139 0:02:19 FR Water 5850 0 49.5 61.1 3103 3742 1584 0.00 0.00 1.00 0.50 0.30 0.20 0


Actual Amt 638.00 70.00 90.50 211.60 106.00 79.70 43.70 43.70 57.10 42.20Percent Variance -3.2% 0.0% 0.0% 1.3% 0.0% -0.8% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%

Strap Amt 638.00 70.00 90.00 210.00 105.00 80.00 45.00 45.00 60.00 40.00Slurry (bbl) 5353 Percent Variance -3.2% 0.0% 0.0% 0.0% 0.0% -1.6% -1.6% 0.0% 4.3% 4.3% 4.8% -6.3%



TOTAL PROPPANT PUMPED: 188,600 Lbs 0.0% Co. Rep: Joe Duncan% of Job Prop Mesh Quantity Units MB Vari SS Vari Dens Vari SC Vari Crew: RED A

Avg Rate 44.8 BPM 0% None 20/40 Lbs -0.3% -2.3% -0.2% -3.0% Equipment running well Avg Corrected Rate 48.8 BPM 0% TLC 20/40 Lbs Xlink samples look good

Max Rate 61.1 BPM 100% White Sand 20/40 188,600 Lbs Good job by CrewAverage Prop Con 2.1 3bbl overflush per Co RepAverage Pressure 3176.3 PSI Inital Annulus Pressure 3.0 PSI Average Annulus Pressure 2.9 PSI In stage 3, pressure spiked and kicked out all trucks. Per company rep pumped another 1000gal of 15% HCl.

Maximum Pressure 4154.0 PSI Final Annulus Pressure 4.0 PSI Change in Annulus Pressure 1.0 PSI





Three Rivers

COMMENTS:



Date, Time & SO: 09/24/14 2:50 PM 901679259Top & Bottom Perfs: To 6096.0Mid-Perf: 6028 BHST: 152| °F




1 Pre-Pad 12 001 11 FRVVater 500 0 4.7 10.3 2200 2892 1112 0.00 0.00 0 1 30 0.50 0.30 0.20

2 0 PPG 48 00446 15%HCLAcid 2000 0 9.6 12.7 2768 3043 2636 03 0 PPG 1406 02326 FRWater 59057 0 38.8 60.3 3404 4154 1523 0 1.00 0.50 0.39 0.40 0.204 0.5 PPG WhkeSand 2332 03852 FRWater 95620 49.627 53.4 60.3 3532 3879 3250 0.52 0.59 O 1.00 0.50 0.39 0.30 0.205 0.5 PPG WhkeSand 123 00203 FRWater 5022 2,536 52.3 52.3 3513 3529 3494 0.51 0.52 0 1.00 0.50 2.00 0.30 0.206 0.5 PPG WhkeSand 123 00203 FRWater 5031 2.611 52.4 52.7 3537 3565 3502 0.52 0.57 0.40 0 1.00 0.50 0.25 0.30 0.207 0 PPG 27 00027 16#Deka140 1148 0 52.8 53.8 3414 3553 3320 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.208 2 PPG WhiteSand 543 00903 16#Deka140 20760 43.243 59.2 60.3 3416 3582 3220 2.08 2.26 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG WhiteSand 336 00536 16#Deka140 11803 45,442 60.0 60.5 3056 3231 2944 3.85 4.15 16.00 1.60 0.20 0 1.00 0.50 0.25 1.00 1.00 0.20


11 Flush 139 00219 FRWater 5850 0 49.5 61.1 3103 3742 1584 0.00 0.00 1.00 0.50 0.30 0.20

0Growler 8 Flush 57 2400 0 50.00 0.00 0.00


PercentVariance -3.2% 0.0% 0.0% 1.3% 0.0% -0.8% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%Stran Amt 638.00 70.00 90.00 210.00 105.00 80.00 45.00 45.00 60.00 40.00

Slurry(bbl)| 5353 PercentVariance -3.2% 0.0% 0.0% 0.0% 0.0% -1.6% -1.6% 0.0% 4.3% 4.3% 4.8% -6.3%

Pumo Time (Minll 1 34 10 Percent Variance is reported as 0% if varianct is within 1 aal on.Clean Fluid (gal)| 215356



AvaRatel 44.8 BPM 0% None 20¼0 | Lbs | -0.3%\ -2.3%\ -0.2%\ -3.0% EauiomentrunninawellAva Corrected Ratel 48.8 BPM 0% TLC 20Mo | Lbs )Gink samples look good

Max Ratel 61.1 BPM 100% White sand 20¼0 | 188,600 Lbs Good iob by CrewAverage Pron Con 2.1 3bbl overnush Der Co ReoAveraae Pressurel 3176.3 PSI Inital Annulus Pressurel 3. PSI Averaae Annulus Pressurel 2.9 PSI In staae 3. Dressure soiked and kicked out all trucks. Per comoanvreo cumoed another 1000aal of 15% HCI

Maximum Pressure| 4154.0 PSI Final Annulus Pressure| 4. PSI Change in Annulus Pressure 1.0 PSI

BREAKDOWNINFORM4710N: CLEANSTREAMBase Fluid:I 8.40 PPG \ UV1 HRsì UV2 HRsì Transm.%

WellheadPressure:I 1114 PSI | 505 | 505 | 82.4 |BrokeBack:I 2892 PSI | 9.4 |BPM



RECEIVED: Oct. 29,



Date, Time & SO: 09/24/14 2:50 PM 901679259Top & Bottom Perfs: To 6096.0Mid-Perf: 6028 BHST: 152| °F




1 Pre-Pad 12 001 11 FRVVater 500 0 4.7 10.3 2200 2892 1112 0.00 0.00 0 1 30 0.50 0.30 0.20

2 0 PPG 48 00446 15%HCLAcid 2000 0 9.6 12.7 2768 3043 2636 03 0 PPG 1406 02326 FRWater 59057 0 38.8 60.3 3404 4154 1523 0 1.00 0.50 0.39 0.40 0.204 0.5 PPG WhkeSand 2332 03852 FRWater 95620 49.627 53.4 60.3 3532 3879 3250 0.52 0.59 O 1.00 0.50 0.39 0.30 0.205 0.5 PPG WhkeSand 123 00203 FRWater 5022 2,536 52.3 52.3 3513 3529 3494 0.51 0.52 0 1.00 0.50 2.00 0.30 0.206 0.5 PPG WhkeSand 123 00203 FRWater 5031 2.611 52.4 52.7 3537 3565 3502 0.52 0.57 0.40 0 1.00 0.50 0.25 0.30 0.207 0 PPG 27 00027 16#Deka140 1148 0 52.8 53.8 3414 3553 3320 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.208 2 PPG WhiteSand 543 00903 16#Deka140 20760 43.243 59.2 60.3 3416 3582 3220 2.08 2.26 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG WhiteSand 336 00536 16#Deka140 11803 45,442 60.0 60.5 3056 3231 2944 3.85 4.15 16.00 1.60 0.20 0 1.00 0.50 0.25 1.00 1.00 0.20


11 Flush 139 00219 FRWater 5850 0 49.5 61.1 3103 3742 1584 0.00 0.00 1.00 0.50 0.30 0.20

0Growler 8 Flush 57 2400 0 50.00 0.00 0.00


PercentVariance -3.2% 0.0% 0.0% 1.3% 0.0% -0.8% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%Stran Amt 638.00 70.00 90.00 210.00 105.00 80.00 45.00 45.00 60.00 40.00

Slurry(bbl)| 5353 PercentVariance -3.2% 0.0% 0.0% 0.0% 0.0% -1.6% -1.6% 0.0% 4.3% 4.3% 4.8% -6.3%

Pumo Time (Minll 1 34 10 Percent Variance is reported as 0% if varianct is within 1 aal on.Clean Fluid (gal)| 215356



AvaRatel 44.8 BPM 0% None 20¼0 | Lbs | -0.3%\ -2.3%\ -0.2%\ -3.0% EauiomentrunninawellAva Corrected Ratel 48.8 BPM 0% TLC 20Mo | Lbs )Gink samples look good

Max Ratel 61.1 BPM 100% White sand 20¼0 | 188,600 Lbs Good iob by CrewAverage Pron Con 2.1 3bbl overnush Der Co ReoAveraae Pressurel 3176.3 PSI Inital Annulus Pressurel 3. PSI Averaae Annulus Pressurel 2.9 PSI In staae 3. Dressure soiked and kicked out all trucks. Per comoanvreo cumoed another 1000aal of 15% HCI

Maximum Pressure| 4154.0 PSI Final Annulus Pressure| 4. PSI Change in Annulus Pressure 1.0 PSI





RECEIVED: Oct. 29,









11 Flush 136 0:02:16 FR Water 5709 0 59.9 60.5 2940 3237 2530 0.00 0.00 1.00 0.50 0.30 0.20 0


Actual Amt 521.00 52.80 69.50 165.00 82.60 76.90 33.00 33.00 84.80 33.00Percent Variance -1.8% 0.0% 0.0% 0.0% 0.0% -0.6% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%

Strap Amt 521.00 57.00 70.00 0.00 160.00 81.00 73.00 33.00 33.00 89.00 32.50Slurry (bbl) 4158 Percent Variance -1.8% 6.7% 0.0% 0.0% 0.0% -3.6% -2.4% -5.8% 0.0% 0.0% 5.6% 0.0%




Avg Rate 48.8 BPM 0% None 20/40 Lbs 4.0% 1.8% 0.1% -0.3%Avg Corrected Rate 53.9 BPM 0% TLC 20/40 Lbs Xlink samples look good

Max Rate 62.4 BPM 100% White Sand 20/40 144,900 Lbs Good job by CrewAverage Prop Con 2.1 3bbl overflush per Co RepAverage Pressure 2589.7 PSI Inital Annulus Pressure 5.2 PSI Average Annulus Pressure 4.3 PSI Increased FR concentration per co. rep.

Maximum Pressure 3935.0 PSI Final Annulus Pressure 3.7 PSI Change in Annulus Pressure -1.5 PSI In stage 4, a truck went off; brought on another truck to make job rateTruck pressures were fluctuating and we lost prime; after job trucks were re-booted and re-primed





Three Rivers

COMMENTS:







1 Pre-Pad 13 0 01 20 FR VVater 558 0 3.0 26.3 1400 1633 1350 0.00 0.00 0 1.00 0.50 0.30 0.20

2 0 PPG 24 0 02 23 15 To HCLAcic 1000 0 11.1 24.6 1680 1703 1605 03 0 PPG 1090 0 8 0 FR VVater 45768 0 55.3 60.6 3214 3935 1683 0 1.00 0.50 0.51 0.56 0.204 0.5 PPG VVhke Sand 1736 0 28 56 FR VVater 71158 38,070 60.0 60.6 2875 2852 2598 0.54 0.70 0 1.00 0.50 0.51 0.70 0.205 0.5 PPG VVhke Sand 123 0 02 03 FR VVater 5032 2.692 60.3 60.3 2839 2852 2824 0.54 0.54 0 1.00 0.50 2.00 0.70 0.206 0.5 PPG VVhke Sand 119 0 01 59 FR VVater 4865 2.613 60.3 60.4 2858 2876 2835 0.54 0.55 4.00 0.40 0 1.00 0.50 0.25 0.30 0.30 0.70 0.207 0 PPG 0 0 00 00 16# Delta 140 0 0 0.008 2 PPG VVhiteSand 417 0 06 57 16# Delta 140 15951 30.578 59.3 60.5 2833 2924 2681 1.92 2.05 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG White Sand 258 0 04 18 16# Delta 140 9070 34,638 59.3 61.1 2707 3007 2219 3.82 4.27 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.20


11 ush 136 0 02 6 FR VVater 5709 0 59.9 60.5 2940 3237 2530 0.00 0.00 1.00 0.50 0.30 0.20

0GrowderfD ush 57 2400 0 50.00 0.00 0.00


PercentVariance -1.8% 0.0% 0.0% 0.0% 0.0% -0.6% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%StranAmt 521.00 57.00 70.00 0.00 160.00 81.00 73.00 33.00 33.00 89.00 32.50

Slurry(bbl) 4158 PercentVariance -1.8% 6.7% 0.0% 0.0% 0.0% -3.6% -2.4% -5.8% 0.0% 0.0% 5.6% 0.0%Pumo Time (Min) 1 12 24 Percent Variance is reported as 0% if variance i within 1 aallor .




Ava Rate 48.8 BPM 0% None 20/40 Lbs 4.0% 1.8% 0.1% -0.3%

Ava Corrected Rate 53.9 BPM 0% TLC 20/40 Lbs XIink samples look goodMax Rate 62.4 BPM 100% White Sand 20/40 144,900 Lbs Good iob by Crew

AA raaaaeePrreDssCu258 PSI Inital Annulus Pressure 5.2 PSI Averaae Annulus Pressure 4.3 PSI

3nbcb sRhcDoerrc tRaeonDer co. reo.

Maximum Pressure 3935.0| PSI Final Annulus Pressure 3.7 PSI Chanae in Annulus Pressure -1.5|PSI In staae 4. a truckwent off brought on another truckto make iob rateTruck pressures were fluctuating andwe lost prime; after iob truckswere re-booted and re-primed





RECEIVED: Oct. 29,







1 Pre-Pad 13 0 01 20 FR VVater 558 0 3.0 26.3 1400 1633 1350 0.00 0.00 0 1.00 0.50 0.30 0.20

2 0 PPG 24 0 02 23 15 To HCLAcic 1000 0 11.1 24.6 1680 1703 1605 03 0 PPG 1090 0 8 0 FR VVater 45768 0 55.3 60.6 3214 3935 1683 0 1.00 0.50 0.51 0.56 0.204 0.5 PPG VVhke Sand 1736 0 28 56 FR VVater 71158 38,070 60.0 60.6 2875 2852 2598 0.54 0.70 0 1.00 0.50 0.51 0.70 0.205 0.5 PPG VVhke Sand 123 0 02 03 FR VVater 5032 2.692 60.3 60.3 2839 2852 2824 0.54 0.54 0 1.00 0.50 2.00 0.70 0.206 0.5 PPG VVhke Sand 119 0 01 59 FR VVater 4865 2.613 60.3 60.4 2858 2876 2835 0.54 0.55 4.00 0.40 0 1.00 0.50 0.25 0.30 0.30 0.70 0.207 0 PPG 0 0 00 00 16# Delta 140 0 0 0.008 2 PPG VVhiteSand 417 0 06 57 16# Delta 140 15951 30.578 59.3 60.5 2833 2924 2681 1.92 2.05 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG White Sand 258 0 04 18 16# Delta 140 9070 34,638 59.3 61.1 2707 3007 2219 3.82 4.27 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.20


11 ush 136 0 02 6 FR VVater 5709 0 59.9 60.5 2940 3237 2530 0.00 0.00 1.00 0.50 0.30 0.20

0GrowderfD ush 57 2400 0 50.00 0.00 0.00


PercentVariance -1.8% 0.0% 0.0% 0.0% 0.0% -0.6% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%StranAmt 521.00 57.00 70.00 0.00 160.00 81.00 73.00 33.00 33.00 89.00 32.50

Slurry(bbl) 4158 PercentVariance -1.8% 6.7% 0.0% 0.0% 0.0% -3.6% -2.4% -5.8% 0.0% 0.0% 5.6% 0.0%Pumo Time (Min) 1 12 24 Percent Variance is reported as 0% if variance i within 1 aallor .




Ava Rate 48.8 BPM 0% None 20/40 Lbs 4.0% 1.8% 0.1% -0.3%

Ava Corrected Rate 53.9 BPM 0% TLC 20/40 Lbs XIink samples look goodMax Rate 62.4 BPM 100% White Sand 20/40 144,900 Lbs Good iob by Crew

AA raaaaeePrreDssCu258 PSI Inital Annulus Pressure 5.2 PSI Averaae Annulus Pressure 4.3 PSI

3nbcb sRhcDoerrc tRaeonDer co. reo.

Maximum Pressure 3935.0| PSI Final Annulus Pressure 3.7 PSI Chanae in Annulus Pressure -1.5|PSI In staae 4. a truckwent off brought on another truckto make iob rateTruck pressures were fluctuating andwe lost prime; after iob truckswere re-booted and re-primed





RECEIVED: Oct. 29,









11 Flush 123 0:02:03 FR Water 5148 0 60.6 60.7 3281 3591 2788 0.00 0.00 1.00 0.50 0.30 0.20 0


Actual Amt 313.00 31.40 37.30 97.20 48.70 74.80 19.60 19.60 36.70 19.40Percent Variance -1.1% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%

Strap Amt 312.00 32.50 39.00 0.00 97.00 48.00 72.50 20.00 20.00 34.00 20.50Slurry (bbl) 2454 Percent Variance -1.4% 0.0% 0.0% 5.1% 0.0% 0.0% 0.0% -3.2% 0.0% 0.0% -7.7% 0.0%




Avg Rate 48.5 BPM 0% None 20/40 Lbs 0.9% 1.2% -0.2% 0.5% Equipment running well Avg Corrected Rate 53.4 BPM 0% TLC 20/40 Lbs Xlink samples look good

Max Rate 61.2 BPM 100% White Sand 20/40 82,800 Lbs Good job by CrewAverage Prop Con 2.0 3bbl overflush per Co RepAverage Pressure 3001.7 PSI Inital Annulus Pressure 0.0 PSI Average Annulus Pressure 0.0 PSI Increased FR concentration per. Co. rep.

Maximum Pressure 4140.0 PSI Final Annulus Pressure 0.0 PSI Change in Annulus Pressure 0.0 PSI





Three Rivers

COMMENTS:



Date, Time & SO: 09/25/14 1:37 AM 901679259Top & Bollom Perfs: 5179 TO 5447.0Mid-Perf: 5313 BHST: 141 F

Liauid AdditWes------------------ -----------------------------------------------------------------------Liauid / ddithresStaae Staae Name SlurrvVol Pume Time Fluid Name Fluid Volume Proceant Slurrv Max Slurrv Pressure Pressure Pressure Pron Conc Pron Conc WG-35 BC 140 Sandwedae NT BA-20 LoSurf-300D CLA-Web MC MX 2-2822 Ootiflo HTE SP FR-66 MC B-8614



1 Pre-Pad 1 0 00 07 FR VVater 50 0 4.9 10.4 2247 2635 1033 0.00 0.00 0 1.00 0.50 0.30 0.20

2 0 PPG 24 0 02 23 15% HCL Acid 1000 0 10.9 20.8 2574 2645 2426 03 0 PPG 641 0 10 41 FR Water 26916 0 48.3 60.3 3430 4140 2457 0 1.00 0.50 0.95 0.45 0.204 0.5 PPG White Sand 888 0 14 48 FR Water 36399 17,326 60.2 60.3 3204 3384 3055 0.48 0.54 0 1.00 0.50 0.95 0.50 0.2050.5PPGWhiteSand 123 00203 FRWater 5055 2.442 60.2 60.3 3101 3114 3092 0.48 0.49 0 1.00 0.50 2.00 0.50 0.206 0.5 PPG VVhke Sand 119 0 01 59 FR VVater 4861 2.406 60.3 60.5 3110 3122 3092 0.50 0.51 4.00 0.40 0 1.00 0.50 0.25 0.35 0.35 0.50 0.207 0 PPG 0 0 00 00 16# Delta 140 0 0 0.008 2 PPG VVhiteSand 239 0 03 59 16# Delta 140 9135 17.786 60.1 60.5 3115 3183 3049 1.95 2.19 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG White Sand 148 0 02 28 16# Delta 140 5185 19,677 60.0 60.2 3073 3165 2958 3.80 6.75 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.20


11 ush 123 0 02 03 FR VVater 5148 0 60.6 60.7 3281 3591 2788 0.00 0.00 1.00 0.50 0.30 0.20

0GrowderfD ush 57 2400 0 50.00 0.00 0.00


PercentVariance -1.1% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%Stran Amt 312.00 32.50 39.00 0.00 97.00 48.00 72.50 20.00 20.00 34.00 20.50

Slurry(bbl) 2454 PercentVariance -1.4% 0.0% 0.0% 5.1% 0.0% 0.0% 0.0% -3.2% 0.0% 0.0% -7.7% 0.0%Pumo Time (Min) O 42 59 Percent Variance is reported as 0% if variance i within 1 aallor .




Ava Rate 48.5 BPM 0% None 20/40 Lbs 0.9% 1.2% -0.2% 0.5% Eauioment runnina wellAva Corrected Rate 53.4 BPM 0% TLC 20/40 Lbs XIink samples look good


300 PSI Inital Annulus Pressure 0.0 PSI Averaae Annulus Pressure 0.0 SI3nbcb sRhcDoerrc tRaeon

Der. Co. reo.Maximum Pressure 4140.0 PSI Final Annulus Pressure 0.0 PSI Chanae in Annulus Pressure 0.0 SI





RECEIVED: Oct. 29,



Date, Time & SO: 09/25/14 1:37 AM 901679259Top & Bollom Perfs: 5179 TO 5447.0Mid-Perf: 5313 BHST: 141 F

Liauid AdditWes------------------ -----------------------------------------------------------------------Liauid / ddithresStaae Staae Name SlurrvVol Pume Time Fluid Name Fluid Volume Proceant Slurrv Max Slurrv Pressure Pressure Pressure Pron Conc Pron Conc WG-35 BC 140 Sandwedae NT BA-20 LoSurf-300D CLA-Web MC MX 2-2822 Ootiflo HTE SP FR-66 MC B-8614



1 Pre-Pad 1 0 00 07 FR VVater 50 0 4.9 10.4 2247 2635 1033 0.00 0.00 0 1.00 0.50 0.30 0.20

2 0 PPG 24 0 02 23 15% HCL Acid 1000 0 10.9 20.8 2574 2645 2426 03 0 PPG 641 0 10 41 FR Water 26916 0 48.3 60.3 3430 4140 2457 0 1.00 0.50 0.95 0.45 0.204 0.5 PPG White Sand 888 0 14 48 FR Water 36399 17,326 60.2 60.3 3204 3384 3055 0.48 0.54 0 1.00 0.50 0.95 0.50 0.2050.5PPGWhiteSand 123 00203 FRWater 5055 2.442 60.2 60.3 3101 3114 3092 0.48 0.49 0 1.00 0.50 2.00 0.50 0.206 0.5 PPG VVhke Sand 119 0 01 59 FR VVater 4861 2.406 60.3 60.5 3110 3122 3092 0.50 0.51 4.00 0.40 0 1.00 0.50 0.25 0.35 0.35 0.50 0.207 0 PPG 0 0 00 00 16# Delta 140 0 0 0.008 2 PPG VVhiteSand 239 0 03 59 16# Delta 140 9135 17.786 60.1 60.5 3115 3183 3049 1.95 2.19 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG White Sand 148 0 02 28 16# Delta 140 5185 19,677 60.0 60.2 3073 3165 2958 3.80 6.75 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.20


11 ush 123 0 02 03 FR VVater 5148 0 60.6 60.7 3281 3591 2788 0.00 0.00 1.00 0.50 0.30 0.20

0GrowderfD ush 57 2400 0 50.00 0.00 0.00


PercentVariance -1.1% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%Stran Amt 312.00 32.50 39.00 0.00 97.00 48.00 72.50 20.00 20.00 34.00 20.50

Slurry(bbl) 2454 PercentVariance -1.4% 0.0% 0.0% 5.1% 0.0% 0.0% 0.0% -3.2% 0.0% 0.0% -7.7% 0.0%Pumo Time (Min) O 42 59 Percent Variance is reported as 0% if variance i within 1 aallor .




Ava Rate 48.5 BPM 0% None 20/40 Lbs 0.9% 1.2% -0.2% 0.5% Eauioment runnina wellAva Corrected Rate 53.4 BPM 0% TLC 20/40 Lbs XIink samples look good


300 PSI Inital Annulus Pressure 0.0 PSI Averaae Annulus Pressure 0.0 SI3nbcb sRhcDoerrc tRaeon

Der. Co. reo.Maximum Pressure 4140.0 PSI Final Annulus Pressure 0.0 PSI Chanae in Annulus Pressure 0.0 SI





RECEIVED: Oct. 29,







1 Pre-Pad 12 0:01:13 FR Water 514 0 5.1 16.8 1172 1429 1016 0.00 0.00 0 1.00 0.50 0.30 0.202 0 PPG 24 0:02:23 15 % HCL Acid 1000 0 10.7 24.3 1448 1454 1429 03 0 PPG 990 0:16:30 FR Water 41591 0 54.9 60.4 2477 2997 1449 0 1.00 0.50 0.57 0.35 0.204 0.5 PPG White Sand 1548 0:25:48 FR Water 63459 29,508 60.3 60.4 2372 2479 2323 0.47 0.51 0 1.00 0.50 0.57 0.30 0.205 0.5 PPG White Sand 123 0:02:03 FR Water 5022 2,486 60.3 60.3 2350 2368 2324 0.50 0.51 0 1.00 0.50 2.00 0.30 0.206 0.5 PPG White Sand 123 0:02:03 FR Water 5036 2,357 60.4 60.7 2350 2368 2329 0.47 0.49 10.00 0.80 0 1.00 0.50 0.25 0.50 0.50 0.30 0.207 0 PPG 77 0:01:17 16# Delta 140 3216 0 60.7 60.8 2340 2349 2332 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.208 2 PPG White Sand 378 0:06:18 16# Delta 140 14444 26,476 60.2 60.8 2297 2424 2240 1.83 2.03 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG White Sand 234 0:03:54 16# Delta 140 8227 30,662 60.2 60.3 2135 2251 2051 3.73 3.93 16.00 1.60 1.15 0 1.00 0.50 0.25 1.00 1.00 0.20


11 Flush 81 0:01:21 FR Water 3414 0 33.6 60.4 1835 2343 1204 0.00 0.00 1.00 0.50 0.30 0.20 0


Actual Amt 620.00 59.20 83.50 152.90 76.50 77.50 36.90 36.90 38.50 30.60Percent Variance 1.9% 0.0% 0.0% 0.0% 0.0% -0.7% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%

Strap Amt 620.00 60.00 85.00 150.00 75.00 80.00 36.00 36.00 39.00 30.00Slurry (bbl) 3866 Percent Variance 1.9% 0.0% 0.0% 1.6% 0.0% -2.5% -2.5% 2.9% -3.7% -3.7% 3.2% 0.0%



TOTAL PROPPANT PUMPED: 131,702 Lbs -0.5% Co. Rep: Joe Duncan% of Job Prop Mesh Quantity Units MB Vari SS Vari Dens Vari SC Vari Crew: RED A

Avg Rate 47.9 BPM 0% None 20/40 Lbs -10.1% 4.9% -11.1% 1.9%Avg Corrected Rate 52.1 BPM 0% TLC 20/40 Lbs Xlink samples look good

Max Rate 60.8 BPM 100% White Sand 20/40 131,702 LbsAverage Prop Con 1.7Average Pressure 2074.8 PSI Inital Annulus Pressure 0.0 PSI Average Annulus Pressure 0.0 PSI In stage 6, proppant concentration began to drop. Castle 272 went empty when the scale was reading 16,250lbs left in the bin.

Maximum Pressure 2997.0 PSI Final Annulus Pressure 0.0 PSI Change in Annulus Pressure 0.0 PSI Went to flush when both castles were confirmed empty.





Three Rivers

COMMENTS:



Date, Time & SO: 09/25/14 5:56 AM 901679259Top & Bottom Perfs: _5006__ To 5138.0Mid-Perf: 5077 BHST: 137 °F




1 Pre-Pad 12 001 13 FRVVater 514 0 5.1 16.8 1172 1429 1016 0.00 0.00 0 1 30 0.50 0.30 0.20

2 0 PPG 24 00223 15%HCLAcid 1000 0 10.7 24.3 1448 1454 1429 O3 0 PPG 990 01630 FRWater 41591 0 54.9 60.4 2477 2997 1449 O 1.00 0.50 0.57 0.35 0.204 0.5 PPG WhkeSand 1548 02548 FRWater 63459 29.508 60.3 60.4 2372 2479 2323 0.47 0.51 0 1.00 0.50 0.57 0.30 0.205 0.5 PPG WhkeSand 123 00203 FRWater 5022 2,486 60.3 60.3 2350 2368 2324 0.50 0.51 0 1.00 0.50 2.00 0.30 0.206 0.5 PPG WhkeSand 123 00203 FRWater 5036 2.357 60.4 60.7 2350 2368 2329 0.47 0.49 10.00 0.80 0 1.00 0.50 0.25 0.50 0.50 0.30 0.207 0 PPG 77 00117 16#Deka140 3216 0 60.7 60.8 2340 2349 2332 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.208 2 PPG WhiteSand 378 00618 16#Deka140 14444 26.476 60.2 60.8 2297 2424 2240 1.83 2.03 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG WhiteSand 234 00354 16#Deka140 8227 30,662 60.2 60.3 2135 2251 2051 3.73 3.93 16.00 1.60 1.15 0 1.00 0.50 0.25 1.00 1.00 0.20


11 Flush 81 00121 FRWater 3414 0 33.6 60.4 1835 2343 1204 0.00 0.00 1.00 0.50 0.30 0.20

0Growler 8 Flush 57 2400 0 50.00 0.00 0.00


PercentVariance 1.9% 0.0% 0.0% 0.0% 0.0% -0.7% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%Stran Amt 620.00 60.00 85.00 150.00 75.00 80.00 36.00 36.00 39.00 30.00

Slurry(bbl)| 3866 PercentVariance 1.9% 0.0% 0.0% 1.6% 0.0% -2.5% -2.5% 2.9% -3.7% -3.7% 3.2% 0.0%Pumo Time (Minll 1 07 26 Percent Variance is reported as 0% if varianct is within 1 aal on.Clean Fluid (gal)| 154906


TOTALPROPPANTPUAPED: 131.702 Lbs -0.5% Co.Reo JoeDuncanb a _Mesh _Quantity Units MBVari SSVari DensVari SCVari Crew REDA

AvaRatel 47.9 BPM 0% None 20¼0 | Lbs | -10.1%\ 4.9%\ -11.1%\ 1.9%Ava Corrected Ratel 52.1 BPM 0% TLC 20Mo | Lbs )Gink samples look good

MaxRatel 60.8 BPM 100% Whitesand 20¼0 | 131,702 LbsAverage Pron Con 1.7Averaae Pressurel 2074.8 PSI Inital Annulus Pressurel 0. PSI Averaae Annulus Pressurel 0.0 PSI In staae 6. Droceant concentration beaan to droo. Castle 272went emotvwhen the scale was readina 16.250lbs left in the bin

Maximum Pressure| 2997.0 PSI Final Annulus Pressure| 0. PSI Change in Annulus Pressure 0.0 PSI Wentto Bush when both castles were conBrmed emotv.





RECEIVED: Oct. 29,



Date, Time & SO: 09/25/14 5:56 AM 901679259Top & Bottom Perfs: _5006__ To 5138.0Mid-Perf: 5077 BHST: 137 °F




1 Pre-Pad 12 001 13 FRVVater 514 0 5.1 16.8 1172 1429 1016 0.00 0.00 0 1 30 0.50 0.30 0.20

2 0 PPG 24 00223 15%HCLAcid 1000 0 10.7 24.3 1448 1454 1429 O3 0 PPG 990 01630 FRWater 41591 0 54.9 60.4 2477 2997 1449 O 1.00 0.50 0.57 0.35 0.204 0.5 PPG WhkeSand 1548 02548 FRWater 63459 29.508 60.3 60.4 2372 2479 2323 0.47 0.51 0 1.00 0.50 0.57 0.30 0.205 0.5 PPG WhkeSand 123 00203 FRWater 5022 2,486 60.3 60.3 2350 2368 2324 0.50 0.51 0 1.00 0.50 2.00 0.30 0.206 0.5 PPG WhkeSand 123 00203 FRWater 5036 2.357 60.4 60.7 2350 2368 2329 0.47 0.49 10.00 0.80 0 1.00 0.50 0.25 0.50 0.50 0.30 0.207 0 PPG 77 00117 16#Deka140 3216 0 60.7 60.8 2340 2349 2332 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.208 2 PPG WhiteSand 378 00618 16#Deka140 14444 26.476 60.2 60.8 2297 2424 2240 1.83 2.03 16.00 1.60 0 1.00 0.50 0.25 1.00 1.00 0.209 4 PPG WhiteSand 234 00354 16#Deka140 8227 30,662 60.2 60.3 2135 2251 2051 3.73 3.93 16.00 1.60 1.15 0 1.00 0.50 0.25 1.00 1.00 0.20


11 Flush 81 00121 FRWater 3414 0 33.6 60.4 1835 2343 1204 0.00 0.00 1.00 0.50 0.30 0.20

0Growler 8 Flush 57 2400 0 50.00 0.00 0.00


PercentVariance 1.9% 0.0% 0.0% 0.0% 0.0% -0.7% 0.0% 0.0% 0.0% 0.0% 0.0% 0.0%Stran Amt 620.00 60.00 85.00 150.00 75.00 80.00 36.00 36.00 39.00 30.00

Slurry(bbl)| 3866 PercentVariance 1.9% 0.0% 0.0% 1.6% 0.0% -2.5% -2.5% 2.9% -3.7% -3.7% 3.2% 0.0%Pumo Time (Minll 1 07 26 Percent Variance is reported as 0% if varianct is within 1 aal on.Clean Fluid (gal)| 154906


TOTALPROPPANTPUAPED: 131.702 Lbs -0.5% Co.Reo JoeDuncanb a _Mesh _Quantity Units MBVari SSVari DensVari SCVari Crew REDA

AvaRatel 47.9 BPM 0% None 20¼0 | Lbs | -10.1%\ 4.9%\ -11.1%\ 1.9%Ava Corrected Ratel 52.1 BPM 0% TLC 20Mo | Lbs )Gink samples look good

MaxRatel 60.8 BPM 100% Whitesand 20¼0 | 131,702 LbsAverage Pron Con 1.7Averaae Pressurel 2074.8 PSI Inital Annulus Pressurel 0. PSI Averaae Annulus Pressurel 0.0 PSI In staae 6. Droceant concentration beaan to droo. Castle 272went emotvwhen the scale was readina 16.250lbs left in the bin

Maximum Pressure| 2997.0 PSI Final Annulus Pressure| 0. PSI Change in Annulus Pressure 0.0 PSI Wentto Bush when both castles were conBrmed emotv.





RECEIVED: Oct. 29,




FORM 9









9. API NUMBER: 43047539530000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 116 Inverness Drive East, Suite #400 , Englewood, CO, 80112 303 645-9809 Ext



COUNTY: UINTAH

STATE: UTAH

11.





10 /3 /2014














This well was previously misreported for the date of first production.The first production date for this well was 10/3/2014. Ultra requests

that the State updates the records for this well to reflect this date.

NAME (PLEASE PRINT) PHONE NUMBER Jasmine Allison 307 367-5041

TITLE Sr. Permitting Analyst

SIGNATURE N/A

DATE 5 /19 /2016

May 19, 2016


FORM 9STATE OF UTAH







3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:116 Inverness Drive East, Suite #400 , Englewood, CO, 80112 303 645-9809 Ext THREE RIVERS

















This well was previously misreported for the date of first production. Accepted by theThe first production date for this well was 10/3/2014. Ultra requestS Utah Division of

that the State updates the records for this well to reflect this date. Oil, Gas and Mining

FOR RECORD ONLYMay 19, 2016

NAME (PLEASE PRINT) PHONE NUMBER TITLEJasmine Allison 307 367-5041 Sr. Permitting Analyst


RECEIVED: May. 19,


FORM 9STATE OF UTAH







3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:116 Inverness Drive East, Suite #400 , Englewood, CO, 80112 303 645-9809 Ext THREE RIVERS

















This well was previously misreported for the date of first production. Accepted by theThe first production date for this well was 10/3/2014. Ultra requestS Utah Division of

that the State updates the records for this well to reflect this date. Oil, Gas and Mining

FOR RECORD ONLYMay 19, 2016

NAME (PLEASE PRINT) PHONE NUMBER TITLEJasmine Allison 307 367-5041 Sr. Permitting Analyst


RECEIVED: May. 19,

STATE OF UTAH FORM 6DEPARTMENTOF NATURALRESOURCES

DIVISION OF OIL, GAS AND MINING

ENTITY ACTION FORM

Operator: Ultra Petroleum Operator Account Number: N 4045

Address: 116 Inverness Drive East, Suite 400

city Englewood

state CO zip 80112 Phone Number: (303) 645-9839

Well 1

API Number Well Name OO Sec Twp Rng County4304753951 TR3-13-820 NWSW 3 8S 20E UintahAction Code Current Entity New Entity Spud Date Entity Assignment

Number Number EffectiveDate

D 19652 \ 8/19/2014 6/1/2018Comments:

Moving to new entity, 3-24TB

Well 2

API Number Well Name 00 Sec Twp Rng County4304753953 TR3-23-820 NWSW 3 8S 20E UintahAction Code Current Entity New Entity Spud Date Entity Assignment

Number Number Effective Date

D 19654 8/23/2014 6/1/2018Comments:


Well 3

API Number Well Name OO Sec Twp Rn9 county4304753952 TR3-14-820 NWSW 3 8S 20E Uintah

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

D 19653 8/27/2014 6/1/2018Comments:


ACTION CODES:A - Establish new entity for new well (single well only) Jennifer BrownB - Add new well to existing entity (groupor unit well) Name (Please Print)C - Re-assign well from one existing entity to another existing entityD - Re-assign well from one existing entity to a new entity SignatureE - Other (Explain in 'comments' section) Engineering Technician 5/31/2018

Title Date

threerivers yes commingling application) no · location at surface 1475€fsl€€€1237€fwl€...

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