DIVISION OF OIL, GAS AND MINING DIVISION · utu-8894a 11. mineral ownership federal indian state...

STATE OF UTAHDEPARTMENT OF NATURAL RESOURCES

DIVISION OF OIL, GAS AND MINING

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME and NUMBER

FEDERAL 13-5D-64

2. TYPE OF WORK

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

BRUNDAGE CANYON

4. TYPE OF WELLOil Well Coalbed Methane Well: NO

5. UNIT or COMMUNITIZATION AGREEMENT NAME

6. NAME OF OPERATORBERRY PETROLEUM COMPANY

7. OPERATOR PHONE303 999-4044

8. ADDRESS OF OPERATOR4000 South 4028 West Rt 2 Box 7735, Roosevelt, UT, 84066

9. OPERATOR [email protected]

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

UTU-8894A

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 1338 FSL 972 FWL NWSW 5 6.0 S 4.0 W U

Top of Uppermost Producing Zone 821 FSL 746 FWL SWSW 5 6.0 S 4.0 W U

At Total Depth 654 FSL 665 FWL SWSW 5 6.0 S 4.0 W U

21. COUNTYDUCHESNE

22. DISTANCE TO NEAREST LEASE LINE (Feet)972

23. NUMBER OF ACRES IN DRILLING UNIT1280

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

2300

26. PROPOSED DEPTHMD: 5964 TVD: 5931

27. ELEVATION - GROUND LEVEL

7240

28. BOND NUMBER

UTB000035

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

43-11041

ATTACHMENTS

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

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

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

DIRECTIONAL SURVEY PLAN (IF DIRECTIONALLY OR HORIZONTALLY

DRILLED)

TOPOGRAPHICAL MAP

NAME Kathy K. Fieldsted TITLE Sr. Regulatory & Permitting Tech. PHONE 435 722-1325

SIGNATURE DATE 04/27/2010 EMAIL [email protected]

API NUMBER ASSIGNED

43013503370000

Permit Manager

APPROVAL

FORM 3

AMENDED REPORT

API Well No: 43013503370000 Received: 4/27/2010API Well No: 43013503370000 Received: 4/27/2010

FORM 3STATE OF UTAH

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

APPLICATION FOR PERMIT TO DRILL 1. WELL NAME andFENDUEMRAL3-5D-64

2. TYPE OF WORK 3. FIELD OR WILDCATDRILL NEW WELL REENTER P&A WELL DEEPEN WELL BRUNDAGE CANYON

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

6. NAME OF OPERATOR 7. OPERATOR PHONEBERRY PETROLEUM COMPANY 303 999-4044

8. ADDRESS OF OPERATOR 9. OPERATOR E-MAIL4000 South 4028 West Rt 2 Box 7735, Roosevelt, UT, 84066 [email protected]

10. MINERAL LEASE NUMBER 11. MINERAL OWNERSHIP 12. SURFACE OWNERSHIP(FEDERAL, INDIAN, OR A88E9)4A

FEDERAL INDIAN STATE FEE FEDERAL INDIAN STATE I FEE I

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 I (Submit Commingling Application) NO l' VERTICALI DIRECTIONAL I HORIZONTAL

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

LOCATION AT SURFACE 1338 FSL 972 FWL NWSW 5 6.0 S 4.0 W U

Top of Uppermost Producing Zone 821 FSL 746 FWL SWSW 5 6.0 S 4.0 W U

At Total Depth 654 FSL 665 FWL SWSW 5 6.0 S 4.0 W U

21. COUNTY 22. DISTANCE TO NEAREST LEASE LINE (Feet) 23. NUMBER OF ACRES IN DRILLING UNITDUCHESNE 972 1280

25. DISTANCE TO NEAREST WELL IN SAME POOL 26. PROPOSED DEPTH(Applied For Drilling or Completed) MD: 5964 TVD: 59312300

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

7240 UTBOOOO35 43-11041

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 TOPOGRAPHICAL MAPDRILLED)

NAME Kathy K. Fieldsted TITLE Sr. Regulatory & Permitting Tech. PHONE 435 722-1325

SIGNATURE DATE 04/27/2010 EMAIL [email protected]

API NUMBER ASSIGNED APPROVAL

43013503370000

Permit

Proposed Hole, Casing, and Cement

String Hole Size Casing Size Top (MD) Bottom (MD)

Prod 7.875 5.5 0 5964

Pipe Grade Length Weight

Grade J-55 LT&C 5964 15.5




Prod 7.875 5.5 0 5964


Grade J-55 LT&C 5964



Surf 12.25 8.625 0 350


Grade J-55 ST&C 350 24.0




Surf 12.25 8.625 0 350


Grade J-55 ST&C 350

'APIWellNo:43013503370000''APIWellNo:43013503370000'

T6S, R4 W, U.S.B.&M. BERRY PETROLEUM COMPANYWell location, FEDERAL #13-5D-64, located osshown in the NW 1/4 SW 1/4 of Section 5,

Set Stone, Pae of Stones,Pa.ors,...,,

e-wrencean. T6S, R4W, U.S.B.&M., Duchesne County, Utah.E-w rencelhe SB9 4J'117 S29°50'17"W

-

Li SB925'08"W - 2663.73' (Meas.) 2627.51' (Meas.) TSS --'.=suisìNB956'JP"W - 5268.85' (Meas.)-- - -- ---

CC Re-¿slablished C.C.Set Stone By Ge¤rings frees Set Stone, Pge NE Cor. Sec. 4

of Stones, E-W 1983 St SE

Tence/heBASIS OF ELEVATION

Lot 4 Lot 3 Lot 2 Lot 1BENCH MARK (M67) LOCATEDIN THE SW 1/4 OF SECTION

BASIS OF BEARINGS 3 9, T5S, R4W, U.S.B.&M., TAKEN FROM THE DUCHESNESE& O QUADRANGLE,UTAH, DUCHESNECOUNTY, 7.5 MINUTEQUAD.

BASIS OF BEARINGS IS A G.P.S. OBSERVATION. *(TOPOGRAPHICMAP) PUBLISHEDBY THE UNITED STATESDEPARTMENT OF THE INTERIOR, GEOLOGICAL SURVEY. SAIDELEVATION IS MARKED ON CAP AS BEING6097 FEET.

LINE TABLE& LINE DIRECTION LENGTHo L1 S60 34'36"W 151.00'

L2 S24 14'26"W 753 05'

FEDERÆ g J-5D-64SCALE

o . Elev Ungraded Ground = 7240' tiffo 972 CERTIFICATE t.Ah

THIS IS TO CERTIFY THAT THE ABOVE PREPA DFIELDNOTESOF ACTUAL SURVEYSMA

Bottom SUPERVISION AND THATTHE SAME A O CORREC TBEST OF MY KNOWLEDGEANDBELIE No. 161319

Hole

RfGG ED L D ORREGisi N 16:319

REVISED: 04-12-10 C.C. STATEOo REVISED: 04-08-09 C.C, 76 Œ U

set toeSB9°28'29"W

- 5JJ4.96' (Meas.) UINTAH ENGINEERING & LAND YING

85 SOUTH 200 EAST - VERNAL, UTAH 84078(435) 789-1017

LEGEND: NAD 83 (TARGETBOTTOM HOLE) NAD 83 (SURFACELOCATION) 5CALE DATESURVEYED: DATEDRAWN:

LATITUDE = 39'59'0008"(39.983356) LATITUDE = 39°59'06.86"(39985239)1"=1000° 09-30-08 10-24-08

=90° SYMBOL LONGITUDE= 110°21'5781" (110.366058) LONGITUDE= 110°21'5384" (110364956) PARTY REFERENICES

= PROPOSED WELL HEAD. NAD 27 (TARGET BOTTOM HOLE) NAD 27 (SURFACELOCA110N) S.H. J.R. S.L- C.L.O. PLAT

A = SECTION CORNERSLOCATED LATITUDE =39°59'0021" (39983392) LATITUDE =

39°59'07.00" (39.985278) WEATHER FILE

LONGITUDE= 110'21 55 26" (110.365350) LONGITUDE= 110'21'51.29" (110 364247) COOL BERRY PE TROLEUM


Well PlanningProposal

FOR

Berry Petroleum Co.Federal 13-5D-64Duchesne Co., UT

Well File: Design #1 (3/22/10)

Presented By:

Pat RasmussenRegional Manager

Bret WolfordWell

'APIWellNo:43013503370000''APIWellNo:430 13503370000'

Project Duchesne Co., UT (UT27C)I Site: Federal Sec.5 Pads (Sec.5-T6S-R4W)Well: Federal 13-5D-64

Wellbore: Wellbore #1 GRSTWHHLt

9e*9 7 01 N K B-EEMIIR---EU.E

Longitude: 110° 21' 51.289 WGround Level: 7238.00

WELL @7252.00ft (Original Well Elev)

PROJECT DETAILS: Duchesne Co., UT (UT27C) REFERENCE INFORMAT10N

Geodetic System: US State Plane1927 (Exact solution) Co-ordinate (ME) Reface: Wen Federal13-5D-64, True NorthDatum: NAD 1927 (NADCON CONUS) Vertical (TVD) Reference: WELL @7252.00ft (Original Well Elev)

Ellipsoid: Clarke 1866 Section (V6) Reference: Slot - (0.00N, 0.00E)Zone: Utah Central 4302 Measured Depth Reference: WELL@ 7252.00R (Original Well Elev)

Calculation Method: Minimum CurvatureSystem Datum: Mean Sea Level

0 - -- -- WELL DETAILS: Federal13.EDB4

- 8 5 5" Csg. ..._...._____...1 Ground Leve1: F238.00StartNudgm200 •NI-5 +EiW Northing Easling Lalittude Longitudo SFo1

0.00 0.00 503703.335 2318233.001 39" 59 7,001N 110 216 51.289 W

400WELLBORE TARGET DETALS IMAP CO ORDINATES AND LATILONGI

Narne Tvb •Nr.$ +E/ W Northing Easting Lelitude Longitude ShapaFed 13·5044 Tgt 5596.00 486.49 ·308.54 503012,983 2317933.203 39" SB'0.216 N 110" 21' 55.253 W Polygon

800 - --- - - -Start 3958.27 held al 1979 37 MD I I

SECTTON DETAILS

MD inc Azi TVC *Ni-5 *EW OLeg TFace vsac Annoration1200 0.00 400 o.00 0,00 0.00 000 0.00 0.00 0.00

450.00 400 0.00 460.00 0.00 0 00 0.00 0.00 0.00 $tart Nudge 2.0D*

F30.00 1.00 160.00 749.45 -14.75 5.37 2.00 160.00 11.26 Slart DLS 2.00' TFO 84.621079.37 1.16 206.00 10F6.18 -54,53 ·0.25 2.00 50,62 40,Bi Slat1 2958.23' hold at 10F9.37 MD

Greeri River 5037.60 1.16 206.00 4983.94 420.83 -276,51 0.00 0.60 679,82 S1art Drop ·1.00

1600 - - - - - · -- - · -

5953.56 I,00 0.00 5895 00 486,49 -300.54 1.00 180.00 752.54 To at 5953.56

FORMATION TOP DETAIL6

. TVDPath MDPath Formation2000- - -- -- --- - - -- - -- 0 1342.39 1349.02 Green River

Green Rlv r Upr Mkr 1892.93 1906.67 Green River Upr Mkr2501.12 2522,71 Mahogany3522.71 3557.50 Tgr3 Mkr4266,04 4310.43 Douglas Creek4849.35 4901.30 Black Shale

2400 - - - - --- - - --- -- - - - - - - - -- - 5033.23 5087.50 1/2 T11rough Obj.5168.50 5224.09 Castle Peak

000 5611.97 5669.41 Uteland Buite Ls.5801.72 5859,28 Wasatch

o2800-------------- -- ---

M AzimuthstoTrueNorth\ Magnetic North: 11.57°

Magnetic FieldStrength: 52335.OsnT

3200 Dip Angle: 65.73"Date: 201WO3/19

Model: IGRF200510

3600-- -- -- -- -- - - -- - - --- 300--- - - ----- ---- -Tgr3 Mk¢

4000 0- - --- - ·---- ---$1art 2 00

1338 FSL 972 FWLSEC5-TES-R4W S D.8200 TF 8562

ddCO- - - - - - - - -- - - -- - -- --- ----- -300 -- - -- -

Black S ui e S rl Drop -100•

4000 - -600- - -- ,- - c

5200 . 900- - -- a

;1 2 Through Ob.

I- CastePekLOOD 1200- - - --- -- ggggg S 30854 W ¯ ¯

TD st 5953.5 650 F5L 666 FWL y,E I

T gotle.460Within |SWSWUd 114 I

6000- ------- - -------- Er, , ,

¯Wasatrh

1,00 900 -600 -300 0 200 600 Gr2

West(-)/East(+) (600 ftlin)

cao: , i i i , i i i , i i i , a s . , , , ' Plan: Design #1 (Federal 13-5D-64/Wellbore #1)810 -400 t 400 8t0 1230 1600 2000

Vertical Section at 204 20" (800 ftlin) Created By: Bret Wolford Date: 13:49, March 22


Berry Petroleum CompanyDuchesne Co., UT (UT27C)Federal Sec.5 Pads (Sec.5-T6S-R4W)Federal 13-5D-64

Wellbore #1

Plan: Design #1

Standard Planning Report22 March, 2010

AGREATMRTEDNIECHONAL SEllwŒ8,


Great White Directional Services, LLC GREMMfiTEPlanning Report « ..

Database: EDM 2003.21 Single User Db Local Co-ordinate Reference: Well Federal 13-5D-64Company: Berry Petroleum Company TVD Reference: [email protected] (OriginalWell Elev)Project: Duchesne Co., UT (UT27C) MD Reference: WELL@7252 00ft (OriginalWell Elev)Site: Federal Sec 5 Pads (Sec 5-T6S-R4W) North Reference: TrueWell: Federal 13-5D-64 Survey Calculation Method: MinimumCurvatureWellbore: Wellbore #1Design: Design #1

Project Duchesne Co., UT (UT27C)

Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea LevelGeo Datum: NAD 1927 (NADCONCONUS)Map Zone: Utah Central 4302

Site Federal Sec.5 Pads (Sec 5-T6S-R4W)

Site Position: Northing: 606,072.191 ft Latitude: 39° 59' 30.350 NFrom: Lat/Long Easting: 2,318,718.76711 Longitude: 110° 21' 44 662 WPosition Uncertainty: 0 00 ft Slot Radius: " Grid Convergence: 0 73 °

Well Federal 13-5D-64

Well Position +NI-S -2,362.50 ft Northing: 603,703.335 ft Latitude: 39" 59' 7.001 N+El-W -515.81 ft Easting: 2,318,233.001 ft Longitude: 110° 21' 51 289 W

Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 7,238.00ft

Wellbore Wellbom #1

Magnetics Model Name Sample Date Declination Dip Angle Field Strength(*) (*) (nT)IGRF200510 2010/03/19 11 57 65.73 52,335

Design Design #1

Audit Notes:Version: Phase: PLAN Tie On Depth: 0.00

Vertical Section: Depth From (TVD) +NI-S +El-W Direction(ft) (R) (it) (*)

0.00 0.00 0.00 204.20

Plan Sections

Measured Vertical Dogleg Build TurnDepth Inclination Azimuth Depth +NI-S +El-W Rate Rate Rate TFO

(ft) (*) (*) (ft) (it) (ft) (°I100ft) (°Ii00ft) (°Ii00ft) (*) Target

0.00 0.00 0 00 0.00 0.00 0 00 0 00 0 00 0.00 0 00450 00 0 00 0.00 450.00 0.00 0.00 0 00 0 00 0.00 0 00750.00 6 00 160.00 749.45 -14.75 5.37 2 00 2 00 0.00 160.00

1,079.37 9.16 206.00 1,076 18 -54.53 -0 25 2 00 0 96 13.97 86.625,037.60 9.16 206.00 4,983.94 -620.83 -276.51 0 00 0 00 0.00 0.005,953 56 0 00 0.00 5,896.00 -686.49 -308.54 1.00 -1 00 0.00 180.00 Fed 13-5D-64 Tgt

2010/03/22 1 46:04PM Page 2 COMPASS 2003.21 Build


Great White Directional Services, LLC GREMWMTEPlanning Report s -

Database: EDM2003.21 Single User Db Local Co-ordinate Reference: Well Federal 13-5D-64Company: Berry Petroleum Company TVD Reference: [email protected] (OriginalWell Elev)Project: Duchesne Co., UT (UT27C) MD Reference: [email protected] (OriginalWell Elev)Site: Federal Sec.5 Pads (Sec.5-T6S-R4W) North Reference: TrueWell: Federal 13-5D-64 Survey Calculation Method: MinimumCurvatureWellbore: Wellbore #1Design: Design #1

Planned Survey

Measured Vertical Vertical Dogleg Build TurnDepth Inclination Azimuth Depth +NI-S +El-W Section Rate Rate Rate

(ft) (*) (*) (R) (R) (ft) (R) (*Ii00ft) (*il00ft) (*I100ft)

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00100.00 0 00 0.00 100 00 0.00 0.00 0.00 0.00 0.00 0.00200.00 0.00 0.00 200 00 0.00 0.00 0.00 0.00 0 00 0.00300.00 0.00 0.00 300 00 0.00 0.00 0.00 0.00 0 00 0.00

8 518"Csg.350.00 0.00 0 00 350 00 0.00 0.00 0.00 0.00 0 00 0.00400.00 0.00 0.00 400 00 0.00 0.00 0.00 0.00 0 00 0.00

Start Nudge 2.00°450.00 0.00 0.00 450 00 0.00 0.00 0.00 0.00 0 00 0.00500.00 1.00 160.00 500.00 -0 41 0.15 0.31 2.00 2 00 0.00600.00 3.00 160.00 599 93 -3.69 1.34 2.81 2.00 2 00 0.00700.00 5.00 160.00 699 68 -10.24 3.73 7.82 2.00 2.00 0.00

Start DLS 2.00° TFO 86.62750.00 6.00 160.00 749 45 -14 75 5.37 11.25 2.00 2 00 0.00800.00 6.14 169.37 799 17 -19.83 6.75 15.32 2 00 0.28 18.75900.00 6.86 185.93 898 54 -31.03 7.12 25 38 2.00 0.72 16.56

1,000.00 8.03 198 53 997 70 -43.60 4 29 38.01 2 00 1.17 12.61Start 3958.23' hold at 1079.37 MD1,079.37 9.16 206 00 1,076.18 -54.53 -0.25 49.84 2.00 1.43 9 411,100.00 9.16 206.00 1,096 55 -57.48 -1 69 53.12 0.00 0.00 0 001,200.00 9.16 206 00 1,195.27 -71.79 -8.66 69.03 0.00 0.00 0.001,300.00 9.16 206 00 1,294 00 -86.09 -15 64 84.94 0.00 0.00 0 00

Green River1,349.02 9.16 206.00 1,342 39 -93.11 -19.07 92.74 0.00 0.00 0 001,400.00 9.16 206 00 1,392 72 -100 40 -22.62 100.85 0.00 0.00 0.001,500.00 9.16 206 00 1,491.45 -114 71 -29.60 116.76 0.00 0.00 0.001,600.00 9.16 206 00 1,590 17 -129 01 -36 58 132.67 0 00 0.00 0.001,700.00 9.16 206 00 1,688 90 -143 32 -43 56 148.58 0 00 0 00 0.001,800.00 9.16 206 00 1,787 62 -157.63 -50 54 164.49 0 00 0 00 0.001,900.00 9 16 206 00 1,886.35 -171 94 -57.52 180 40 0 00 0.00 0.00

Green River Upr Mkr1,906.67 9 16 206 00 1,892.93 -172.89 -57.99 181 47 0 00 0 00 0.002,000.00 9.16 206.00 1,985 07 -186 24 -64 50 196 31 0 00 0.00 0.002,100 00 9.16 206 00 2,083.80 -200 55 -71.48 212 23 0 00 0.00 0.002,200 00 9.16 206 00 2,182 52 -214 86 -78 46 228 14 0 00 0.00 0.002.300 00 9.16 206.00 2,281 25 -229.16 -85 44 244.05 0 00 0.00 0 002,400 00 9.16 206.00 2.379 97 -243 47 -92 42 259.96 O00 0.00 0 002,500.00 9.16 206 00 2,478.70 -257 78 -99 40 275 87 0.00 0.00 0 00

Mahogany2,522.71 9.16 206 00 2,501.12 -261 03 -100 98 279.48 0 00 0.00 0 002,600 00 9.16 206 00 2,577 42 -272.08 -106 38 291 78 0 00 0.00 0 002,700 00 9.16 206 00 2,676 14 -286 39 -113 36 307.69 0 00 0.00 0 002,800 00 9.16 206 00 2,774 87 -300.70 -120 34 323 60 0 00 0.00 0 002,900.00 9.16 206 00 2,873 59 -315 00 -127.31 339 51 0 00 0.00 0.003,000.00 9.16 206 00 2,972.32 -329.31 -134 29 355 42 0.00 0.00 0 003,100.00 9.16 206 00 3,071 04 -343.62 -141 27 371 33 0 00 0.00 0 003,200.00 9.16 206 00 3,169 77 -357.92 -148.25 387 24 0 00 0.00 0 00

3,300.00 9.16 206 00 3,268 49 -372.23 -155.23 403.15 0 00 0.00 0 003,400.00 9.16 206 00 3,367 22 -386 54 -162 21 419 06 0 00 0.00 0 003,500.00 9.16 206 00 3,465 94 -400 85 -169 19 434 97 0 00 0.00 0 00

Tgr3 Mkr3,557.50 9.16 206 00 3,522.71 -409.07 -173 20 444 12 0.00 0.00 0.003,600.00 9.16 206 00 3,564.67 -415.15 -176 17 450 88 0.00 0.00 0.00

2010/03/22 1:46:04PM Page 3 COMPASS 2003.21 Build


Great White Directional Services, LLC GREATWMTEPlanning Report , ..,--mo .

Database: EDM 2003.21 Single User Db Local Co-ordinate Reference: Well Federal 13-5D-64Company: Berry Petroleum Company TVD Refemnce: [email protected] (OriginalWell Elev)Project: Duchesne Co., UT (UT27C) MD Reference: [email protected] (OriginalWell Elev)Site: Federal Sec.5 Pads (Sec.5-T6S-R4W) North Reference: TrueWell: Federal 13-5D-64 Survey Calculation Method: MinimumCurvatureWellbore: Wellbore #1Design: Design #1

Planned Survey


(ft) (*) (*) (ft) (R) (R) (R) (*ii00ft) (*I100ft) (*l100ft)

3,700.00 9.16 206 00 3,663.39 -429.46 -183.15 466.80 0.00 0.00 0 003,800.00 9.16 206.00 3,762.12 -443.77 -190.13 482.71 0.00 0.00 0.003,900.00 9.16 206.00 3,860.84 -458.07 -197.11 498.62 0.00 0.00 0 004,000.00 9.16 206.00 3,959.57 -472.38 -204.09 514.53 0.00 0.00 0.004,100.00 9.16 206.00 4,058.29 -486.69 -211.07 530.44 0.00 0.00 0 004,200.00 9 16 206.00 4,157.02 -500.99 -218 05 546.35 0.00 0.00 0 004,300.00 9.16 206.00 4,25574 -515.30 -225.03 562.26 0.00 0.00 0.00

Douglas Creek4,310.43 9.16 206.00 4,266.04 -516.79 -225.76 563.92 0.00 0.00 0.004,400.00 9.16 206.00 4,354.47 -529.61 -232.01 578.17 0 00 0.00 0.004,500.00 9.16 206.00 4,453.19 -543.91 -238 99 594 08 0.00 0.00 0.004,600.00 9.16 206.00 4,551.92 -558.22 -245.97 609 99 0.00 0.00 0.004,700.00 9.16 206.00 4,650.64 -572.53 -252 94 625 90 0.00 0.00 0.004,800.00 9.16 206.00 4,749.37 -586.83 -259.92 641.81 0.00 0.00 0.004,900.00 9.16 206.00 4,848.09 -601.14 -266.90 657.72 0.00 0.00 0.00

Black Shale4,901.30 9.16 206.00 4,849.38 -601.33 -266.99 657.93 0.00 0.00 0.005,000.00 9.16 206.00 4,946.82 -615.45 -273.88 673.63 0.00 0.00 0.00

Start Drop -1.00°

5,037.60 9.16 206.00 4,983.94 -620.83 -276.51 679.62 0.00 0.00 0.001/2 Through Obj.5.087.50 8 66 206.00 5,033.23 -627 77 -279.90 687.34 1.00 -1.00 0.005,100.00 8.54 206.00 5,045.59 -629.45 -280.72 689 21 1.00 -1.00 0.005,200.00 7.54 206.00 5,144.61 -642.02 -286.84 703 18 1.00 -1.00 0.00

Castle Peak5,224.09 7.29 206.00 5,168.50 -644 81 -288.21 706 29 1.00 -1.00 0.005,300 00 6.54 206.00 5,243.86 -653 03 -292.21 715 42 1 00 -1.00 0.005,400 00 5 54 206.00 5,343.30 -662 48 -296.82 725 93 1.00 -1.00 0.005,500 00 4 54 206.00 5,442.91 -670 36 -300 67 734 71 1 00 -1.00 0.005,600 00 3 54 206.00 5,542.67 -676 69 -303.76 741 74 1.00 -1.00 0.00

Uteland Butte Ls.5,669 41 2 84 206.00 5,611.97 -680 16 -305.45 745 60 1 00 -1 00 0.005,700.00 2.54 206.00 5,642.52 -681 45 -306.08 747 03 1.00 -1.00 0.005,800.00 1.54 206.00 5,742.46 -684 64 -307.64 750 58 1.00 -1 00 0.00

Wasatch5,859 28 0.94 206 00 5,801 72 -685 79 -308 20 751 86 1 00 -1 00 0.005,900 00 0.54 206 00 5,842 44 -686 27 -308.43 752 39 1.00 -1 00 0.00

TD at 5953.56 - Fed 13-SD-64 Tgt5,953.56 0.00 0 00 5,896 00 -686 49 -308.54 752 64 1.00 -1 00 0.00

2010/03/22 1 46 04PM Page 4 COMPASS 2003 21 Build


Great White Directional Services, LLC SHEATWNTEPlanning Report , ..--sw.

Database: EDM2003.21 Single User Db Local Co-ordinate Reference: Well Federal 13-5D-64Company: Berry Petroleum Company TVD Reference: [email protected] (OriginalWell Elev)Project: Duchesne Co., UT (UT27C) MD Reference: WELL @7252.00ft (OriginalWell Elev)Site: Federal Sec.5 Pads (Sec.5-T6S-R4W) North Reference: TrueWell: Federal 13-5D-64 Survey Calculation Method: MinimumCurvatureWellbore: Wellbore #1Design: Design #1

Design Targets

Target Name- hit/miss target Dip Angle Dip Dir. TVD +NI-S +El-W Northing Easting-Shape (*) (*) (ft) (ft) (R) (ft) (ft) Latitude Longitude

Fed 13-5D-64 Tgt 0.00 0.00 5,896 00 -686.49 -308.54 603,012.983 2,317,933.203 39° 59' 0.216 N 110 21' 55.253 W- plan hits targetcenter- Polygon

Point 1 5,896.00 192.90 -204.90 603,203.27 2,317,725.87Point 2 5,896.00 195.80 205.20 603,211.37 2,318,135.90Point 3 5,896 00 -192.50 205.70 602,823.11 2,318,141.33Point 4 5,896 00 -196.30 -206.00 602,814.08 2,317,729.71

- Lasmg ro mur

Measured Vertical Casing HoleDepth Depth Diameter Diameter

(A) (A) Name (") (")350.00 350.00 8 5/8" Csg. 8-5/8 12-1/4

Formations

Measured Vertical DipDepth Depth Dip Direction

(it) (it) Name Llthology (°) I I1,349.02 1,346 00 Green River -2.23 204.201,906.67 1,900 00 Green River Upr Mkr -2.23 204.202,522.71 2,512.00 Mahogany -2.23 204.203,557.50 3,540 00 Tgr3 Mkr -2.23 204.204,310.43 4,288 00 Douglas Creek -2.23 204.204,901.30 4,875 00 Black Shale -2.23 204.205,087.50 5,060.00 1/2 Through Obj. -2 23 204.205,224.09 5,196 00 Castle Peak -2.23 204.205,669.41 5,641.00 Uteland Butte Ls. -2 23 204.205,859.28 5,831.00 Wasatch -2.23 204.20

Plan Annotations

Measured Vertical Local CoordinatesDepth Depth +NI-S +El-W

(R) (ft) (it) (ft) Comment450.00 450 00 0.00 0.00 Start Nudge 2.00°750.00 749.45 -14.75 5 37 Start DLS 2.00° TFO 86.62

1,079.37 1,076 18 -54.53 -0 25 Start 3958.23' hold at 1079.37 MD5,037 60 4,983 94 -620.83 -276 51 Start Drop -1.00°

5,953.56 5,896.00 -686.49 -308 54 TD at 5953.56

2010 3/22 1:46:04PM Page 5 COMPASS 2003 21 Build


SELF-CERTIFICATION STATEMENT

The following self -certification statement is provided per federal requirements dated May 7, 2007.

Please be advised that Berry Petroleum Company is considered to be the operator of the following well.

Federal 13-5D-64NW 1/4, SW 1/4, 1338' FSL 972' FWL, Section 5, T. 6 S., R. 4 W., U.S.B.&M.

BHL: SW 1/4, SW 1/4, 654' FSL, 665' FWLLease USA UTU-8894ADuchesne, County, Utah

Berry Petroleum Company is responsible under the terms of the lease for the operations conducted upon thelease lands.

Kathy K. ieldstedSr. Regulatory & Permitting Tech.Berry Petroleum Company4000 South 4028 WestRoute 2, Box 7735Roosevelt, Utah 84066435-722-1325


BERRY PETROLEUM COMPANYFederal 13-5D-64

Surface location NW 1/4, SW 1/4, 1338' FSL 972' FWL, Section 5, T. 6 S., R. 4 W., U.S.B.&M.BHL: SW 1/4, SW 1/4, 654' FSL, 665' FWL

Duchesne County, Utah

ONSHORE ORDER NO. 1

DRILLING PROGRAM

1,2 Estimated Tops of Geological Markers and Formations Expected to Contain Water, Oil andGas and Other Minerals

FORMATION DRILL DEPTH * DRILL DEPTH * Measured@SHL (TVD) @BHL (TVD) Depth

Uinta Surface On SurfaceGreen River Fm 1,346' 1,315' 1,350'Green River Upper Marker 1,900' 1,872' 1,909'Mahogany 2,512' 2,475' 2,522'Tgr3 Marker 3,540' 3,505' 3,557'*Douglas Creek Mbr 4,288' 4,247' 4,305'*Black Shale Mbr 4,875' 4,826' 4,894'*Castle Peak Mbr 5,196' 5,164' 5,220'Uteland Butte Mbr. 5,641' 5,590' 5,663'Wasatch 5,83 l' 5,796' 5,864'TD 5,93 l' 5,896' 5,964'

Base of Moderately SalineWater (less than 10,000 ppm) 1,287' 1,410'

*PROSPECTIVE PAYBerry is locating the well at the proposed surface location and directionally drilling to the proposedbottom hole location primarily because of severe topographical limitations. By drilling directionally,Berry Petroleum Company will improve field development efficiency by potentially combiningmultiple surface hole locations together. This will significantly reduce total surface disturbance pluscombine the use of access roads and existing pipelines.Furthermore, Berry hereby certifies that it is the sole working interest owner of all the surrounding40 acre locations. The proposed well bore will at no point throughout the objective pay section (topDouglas Creek to top Wasatch) approach within 460' of any of the potential offsetting 40 acre wellsites.

3 Pressure Control Equipment : (Schematic Attached)

The BOP and related equipment shall meet the minimum requirements of Onshore Oil and GasOrder No. 2 for equipment and testing requirements, procedures, etc., for a 2M_system when thewell is drilled to the base of the Uteland Butte Limestone formation, and individual componentsshall be operable as designed. The attached diagram depicts the use of an annular in conjunctionwith double rams. However, an annular, double rams or both may be used depending on thedrilling rig contracted. Chart recorders will be used for all pressure tests.

Test charts, with individual test results identified, shall be maintained on location while drillingand shall be made available to a BLM representative upon request.All required BOP tests and/or drills shall be recorded in the IADC report.The anticipated bottom hole pressure will be less than 3,000 psi.


Berry Petroleum Company Drilling ProgramFederal 13-5D-64 Duchesne County, Utah

4 Proposed Casing and Cementing Program

The proposed Casing Program will be as follows:

Purpose Depth Hole Size Casing Size Type Connection Weight

Surface 350' 12 ¼" 8 5/8" J-55 ST&C or LT&C 24#Production 5964' 7-7/8" 5 ½" J-55 LT&C 15.5#

Surface Fill Type & Amount

O'-350' 350' Approximately 200 sx Class "G" (Type III) cement +

additives or a similar slurry with a minimum weightof 15.8ppg and approximate yield of 1.15 cuft/sk,minimum 24 hr compressive strength = 500 psi(Cement will be circulated to surface and topped off,if necessary.)

Production with lost circulation Type & Amount

O'-5964' SEE ATTACHED CEMENT PROCEDURES

Production without lost circulation Type & Amount

0'- 5964' SEE ATTACHED CEMENT PROCEDURES

For production casing, actual cement volumes will be determined from the caliper log plus a minimum of15% excess.



5 Drilling Fluids Program

Interval Weight Viscosity Fluid Loss Remarks

0'-350' 8.3-8.6 27-40 NC Spud Mud or air350'-TD 8.6-8.9 27-40 NC KCL Water

6 Evaluation Program

Logging Program: HRI-GR-SP with SDL-DSN-PE: surfàce casing to TD.Preserve samples from all show intervals.

Sampling: 10' dry cut samples: Douglas Creek to TD. Preserve samplesFrom all show intervals.

Surveys: As deemed necessary

Mud Logger: As deemed necessary

Drill Stem Tests: As deemed necessary

Cores: As deemed necessary

7 Abnormal Conditions

No abnormal temperatures or pressures or other hazards are anticipated.

8 Anticipated Starting Dates and Notification of Operations

Drilling Activity:

Anticipated Commencement Date: Upon approval of the APD.Drilling Days: Approximately 6 days.Completion Days: Approximately 7 days.



SCHEMATIC DIAGRAM OF 2,000 PSI BOP STACK

[ Flow Line

Fill-Up LineI

II I

Annular Preventer

I i

BlindRams

Pipe Rams

Kill ine

Ad ustable Choke

To Mud/Gas Separator and/or Pit

3Bleed Line To Pit

BlowoutPrevemerStack Outlet

To Mud/Gas Separator and/or Pit2" Line

Adjustable Choke


BERRY PETROLEUM COMPANYFederal 13-5D-64

Surface location NW 1/4, SW 1/4, 1338' FSL 972' FWL, Section 5, T. 6 S., R. 4 W., U.S.B.&M.BHL: SW 1/4, SW 1/4, 654' FSL, 665' FWL

Duchesne County, Utah

ONSHORE ORDER NO. 1

MULTI POINT SURFACE USE & OPERATIONS PLAN

1 Existing Roads

To reach the Berry Petroleum Company well, Federal 13-5D-64 located, in Section 5-T6S-R4W:

Start in Myton, Utah. Proceed west on US Highway 40, 8.6 miles to the Antelope Creek/SowersCanyon Road at the Bridgeland turnoff. Turn south and proceed 8.6 miles on the BrundageCanyon road. Proceed southwest 7.8 on main road, from there turn east on the access road 330'+/- miles to the proposed Federal 13-5D-64 location.

The existing oilfield service road may need some surface material to prevent or repair holes in theroad due to heavy truck traffic during the drilling and completion operation. If repairs are made theoperator will secure material from private sources.

Please see the attached map for additional details.

2 Planned Access Road

See Topographic Map "B" for the location of the proposed access road.

On National Forest Service (NFS) lands, access roads will conform to standards outlined in theBLM and Forest Service publication, Surface Operating Standards and Guidelines forOil andGas Exploration and Development "Gold Book" 4* Edition, 2006.

Surface disturbance and vehicular traffic will be limited to the approved location and approvedaccess route. Any additional area needed will be approved in advance.

New access roads will be crowned (2 to 3%), ditched, and constructed with a running surface of 22feet and a maximum disturbed width of 35 feet. Graveling or capping the roadbed will beperformed as necessary to provide a well constructed, safe road. Prior to construction orupgrading, the proposed road shall be cleared of any snow and shall be allowed to dry completely.

The disturbed width needed may be wider than 35 feet to accommodate larger equipment wheredeep cuts are required for road construction; intersections or sharp curves occur; or, as proposedby the operator. Approval will be required from the Forest Supervisor, Vernal, Utah (FS).

Appropriate water control structures will be installed to control erosion.

Unless otherwise specified, the following specifications will apply:

The road grade in the Project Area will be 10% or less, wherever possible. The 10% grade wouldonly be exceeded in areas where physical terrain or unusual circumstances require it.Turn-out areas will not be constructed unless they were deemed necessary for safety reasons.


Berry Petroleum Company Multi Point Surface Use & Operations PlanFederal 13-5D-64 Duchesne County, Utah

There will be no major cuts and fills, culverts, or bridges. If it becomes necessary to install aculvert at some time after approval of the APD, the operator will submit a Sundry Noticerequesting approval of the USFS Authorized Officer.

The access road will be centerline flagged during time of staking.

There will be no gates, cattle guards, fence cuts, or modifications to existing facilities without priorconsent of the FS.

Surfacing material may be necessary, depending upon weather conditions.

The road surface and shoulders will be kept in a safe and usable condition and will be maintainedin accordance with the original construction standards. Best efforts will be made such that alldrainage ditches and culverts will be kept clear and free flowing and will be maintained accordingto the original construction standards- The access road ROW will be kept free of trash duringoperations. All traffic will be confined to the approved running surface. Road drainage crossingsshall be of the typical dry creek drainage crossing type. Crossings shall be designed so they willnot cause siltation or accumulation of debris in the drainage crossing, nor shall the drainages beblocked by the roadbed. Erosion of drainage ditches by runoff water shall be prevented bydiverting water off at frequent intervals by means of cutouts. Should mud holes develop, the holesshall be filled in and detours around the holes avoided. When snow is removed from the roadduring the winter months, the snow should be pushed outside the borrow ditches, and the cutoutskept clear so that snowmelt will be channeled away from the road.

3 Location of Existing Wells

See Topographic Map "C" for the location of existing wells within a lmile radius.

4 Location of Tank Batteries, Production Facilities and Production Gathering and ServiceLines

All permanent (on site for six months or longer) structures constructed or installed will be painteda flat, non-reflective, earth tone color to match one of the standard environmental colors, asdetermined by the five state Rocky Mountain Inter-Agency Committee. All facilities will bepainted within six months of installation. Facilities required to comply with the OccupationalSafety and Health Act (OSHA) will be excluded. The required paint color is desert brown (10YR6/4) unless otherwise designated by the Authorized Officer.

A containment dike will be constructed completely around those production facilities whichcontain fluids (i.e., production tanks, produced water tanks). This dike will be constructed ofcompacted subsoil, be impervious, and hold 150% of the capacity of the largest tank. The use oftopsoil for the construction of dikes will not be allowed. A Spill Prevention, Control, andCountermeasure (SPCC) Plan is required by the Environmental Protection Agency, thecontainment dike may be expanded with the BLM/VFO Authorized Officer's approval to meetSPCC requirements.

A description of the proposed pipeline and a map illustrating the proposed route is attached.

Berry Petroleum Company Multi Point Surface Use & Operations Plan


Federal 13-5D-64 Duchesne County, Utah

All site security guidelines identified in Federal regulation 43 CFR 3126.7, will be adhered to. Alloff-lease storage, off-lease measurement, or commingling on-lease or off-lease production willhave prior written approval form the Authorized Agency Officer.

Gas meter runs will be located approximately 100 feet from the wellhead. Where necessary, thegas line will be anchored down from the wellhead to the meter.

5 Location and Type of Water Supply

Water for the drilling and completion will be pumped or trucked from the Berry source wellslocated in Sec. 23, T5S, R5W or Sec. 24, T5S, R5W, permit # 43-11041, or from Duchesne CityCulinary Water Dock located in Sec. 1, T4S, R5W or from East Duchesne Water, Arcadia Feedlot,Sec. 28, T3S, R3W or Myton (Moon) Pit, SE/NE Sec. 27, T3S, R2W or from PetroglyphOperating Company 08-04 Waterplant, Sec. 8, T5S, R3W or from Kenneth V. & Barbara U.Richens source well located in Sec. 34, T3S, R2W, permit #43-1723 or Brundage Canyon Fieldproduced water or Leo Foy source well located in-Sec.34, TSS, R5W, permit #43-11324.

6 Source of Construction Materials

All construction materials for this location site and access road shall be borrow materialaccumulated during construction of the location site and access road.

Additional gravel or pit lining material will be obtained from a private source.

The use of materials under Authorized Agency jurisdictionwill conform with 43 CFR 3610.2-3.

7 Methods of Handling Waste Materials

Drill cuttings will be contained in a closed loop system or a reserve pit and buried in the reserve pitor spread on location.

Drilling fluids, including salts and chemicals, will be contained in a closed loop system or areserve pit. Upon termination of drilling and completion operations, the liquid contents of thereserve pit will be used at the next drill site or will be removed and disposed of at an approvedwaste disposal facility. For wells completed from October 1 through April 30, any hydrocarbonsin the pit shall be removed from May 1 to September 30 in accordance with 43 CFR 3162.7-1.

Unless specified in the site specific APD, the reserve pit will be constructed on the location andwill not be located within natural drainages, where a flood hazard exists or surface runoff willdestroy or damage the pit walls. The reserve pit will be constructed so that it will not leak, break,or allow discharge of liquids.

If it is determined at the onsite that a pit liner is necessary, the reserve pit will be lined with asynthetic reinforced liner a minimum of 12 millimeters thick, with sufficient bedding used to coverany rocks. The liner will overlap the pit walls and be covered with dirt and/or rocks to hold it inplace. Trash or scrap that could puncture the liner will not be disposed of in the pit.

Reserve pit leaks are considered an unacceptable and undesirable event and will be orally reportedto the Authorized Officer.




Drain tanks will be installed with a 3" sand or dirt pad underneath a 20 millimeter thick liner whichwill extend 12" over the top edges of the pit. There will be room around the outside walls of thetank for visual inspection. There will be an escape route for animals from the bottom of the pit toground level.

After first production, produced wastewater will be trucked to one of the following approved wastewater disposal sites: R.N. Industries, Inc. Sec. 4, T2S, R2W, Bluebell; MC & MC Disposal Sec.12, T6S, Rl9E, Vernal; LaPoint Recycle & Storage Sec. 12, TSS, R19E, LaPoint or WaterDisposal Inc. Sec. 32, Tl S, Rl W, Roosevelt, used in the operations of the field or, unlessprohibited by the Authorized Officer, disposed of to the approved pit for a period not to exceed 90days. The use of such pit is hereby approved as part of this Application for Permit to Drill.

All production fluids will be disposed of at approved disposal sites. Produced water, oil, and otherbyproducts will not be applied to roads or well pads for control of dust or weeds. Theindiscriminate dumping of produced fluids on roads, well sites, or other areas will not be allowed.

Any spills of oil, gas, salt water, or other noxious fluids will be immediately cleaned up andremoved to an approved disposal site.

A chemical portable toilet will be furnished with the drilling rig.

Garbage, trash, and other waste materials will be collected in a portable, self-contained, fullyenclosed trash cage during operations. Trash will not be burned on location.

All debris and other waste materials not contained in the trash cage will be cleaned up andremoved from the location promptly after removal of the completion rig.

Any open pits will be fenced during the operations. The fencing will be maintained until such timeas the pits are backfilled.

No chemicals subject to reporting under SARA Title III (hazardous materials) in an amount equalto or greater than 10,000 pounds will be used, produced, stored, transported, or disposed ofannually in association with the drilling, testing, or completing of wells. Furthermore, extremelyhazardous substances, as defined in 40 CFR 355, in threshold planning quantities, will not be used,produced, stored, transported, or disposed of in association with the drilling, testing, or completingof wells within these areas.

8 Ancillary Facilities

There are no ancillary facilities planned for at this time and none are foreseen in the future.

9 Wellsite Layout

The attached Location Layout diagram describes drill pad cross-sections, cuts and fills, andlocations of the mud tanks, reserve pit, pipe racks, trailer parking, spoil dirt stockpile(s) andsurface material stockpile(s).

The diagram describes rig orientation, parking areas, and access roads as well as the location of thefollowing:




The reserve pit.

The stockpiled topsoil, which shall not be used for facility berms. All brush removedfrom the well pad during construction will be stockpiled with the topsoil.

The flare pit, which will be located downwind from the prevailing wind direction.

The access road.

All pits will be fenced according to the following minimum standards:

39-inch net wire shall be used with at least one strand of barbed wire on top of the netwire. Barbed wire is not necessary if pipe or some type of reinforcement rod is attachedto the top of the entire fence.

The net wire shall be no more than two inches above the ground. The barbed wire shallbe three inches over the net wire. Total height of the fence shall be at least 42 inches.

Corner posts shall be cemented and/or braced in such a manner as to keep the fence tightat all times.

Standard steel posts shall be used between the corner braces, between the corner posts.Distance between any two posts shall be no greater than 16 feet.

All wire shall be stretched using a stretching device before it is attached to the cornerposts.

The reserve pit fencing will be on three sides during drilling operations and on the fourth sidewhen the rig moves off location. Pits will be fenced and maintained until cleanup.

10 Plans for Restoration of the Surface

The dirt contractor will be provided with approved copies of the Surface Use Plan and theseStandard Operating Procedures prior to construction activities.

Upon well completion, within 30 days the location and surrounding area will be cleared of allunused tubing, materials, trash, and debris not required for production.

On lands administered by the Forest Service, abandoned well sites, roads, and other disturbedareas will be restored as near as practical to their original condition. Where applicable, theseconditions may include the re-establishment of appropriate soil conditions, and the re-establishment of vegetation as specified.

All disturbed areas will be re-contoured to the approximate natural contours.

Any drainage rerouted during the construction activities shall be restored to its original line of flowor as near as possible.

Prior to backfilling the reserve pit, the fence surrounding the reserve pit will be removed. The pitliner will be folded and torn after the pit dries and prior to backfilling the reserve pit.




Before any dirt work associated with reserve pit restoration takes place, the reserve pit shall be asdry as possible. All debris in it will be removed. Other waste and spoil materials will be disposedof immediately upon completion of operations. The reserve pit will be reclaimed within 180 daysfrom the date of well completion, weather permitting. Once reclamation activities have begun, theactivities will be completed within 30 days.

After the reserve pit has been reclaimed, no depressions in the soil covering the reserve pit will beallowed. The object is to keep seasonal rainfall and runoff from seeping into the soil used to coverthe reserve pit. Diversion ditches and water bars will be used to divert runoff as needed.

Prior to the construction of the location, the top 12 inches of soil material (if present) will bestripped and stockpiled. Placement of the topsoil will be noted on the location plat attached to thesite specific APD. Topsoil shall be stockpiled separately from subsoil materials. Topsoil salvagedfrom the reserve pit shall be stockpiled separately near the reserve pit.

When restoration activities have been completed, the location site and new access road cuts andshoulders shall be reseeded. Prior to reseeding, all disturbed areas, including the old access road,will be scarified and left with a rough surface.

The Authorized Officer or the appropriate surface management agency shall be contacted for therequired seed mixture. Seed will be broadcast and the amount of seed mixture per acre will bedoubled. The seeded area will then be "walked" with a dozer to assure coverage of the seeds. Theseed mixture will reflect the recommendation from the Archeology study done on the site specificAPD.

At final abandonment, all casing shall be cut off at the base of the cellar or 3 feet below finalrestored ground level, whichever is deeper, and cap the casing with a metal plate a minimum of0.25 inches thick. The cap will be welded in place and the well location and identity will bepermanently inscribed on the cap. The cap also will be constructed with a weep hole.

11 Surface Ownership

United States Forest Service

12 Other information

All lease and/or unit operations will be conducted in such a manner that full compliance is madewith all applicable laws, regulations, Onshore Oil and Gas Orders, the approved Plan ofOperations, and any applicable Notice to Lessees. The operator is fully responsible for the actionsof his subcontractors. A copy of these conditions will be furnished to the field representative toensure compliance.

The operator will control noxious weeds along access road use authorizations, pipeline routeauthorizations, well sites or other applicable facilities. A list of noxious weeds may be obtainedfrom the Forest Service, BLM, or the appropriate County Extension Office. On NFS administeredland, it is required that a Pesticide Use Proposal be submitted and approved prior to the applicationof herbicides or other pesticides or possibly hazardous chemicals.




Drilling rigs and/or equipment used during drilling operations on this location will not be stackedor stored on National Forest Service-administered lands after the conclusion of drilling operationsor at any other time without authorization by the NFS. If authorization is obtained, such storage isonly a temporary measure.

Travel is restricted only to approved travel routes.

Unless previously conducted, a class III archaeological survey will be conducted on all ForestService lands. All personnel will refrain from collecting artifacts and from disturbing anysignificant cultural resources in the area. The operator is responsible for informing all persons inthe area who are associated with this project that they may be subject to prosecution for knowinglydisturbing historic or archaeological sites or for collecting artifacts. All vehicular traffic,personnel movement, construction, and restoration activities shall be confined to the areasexamined, as referenced in the archaeological report, and to the existing roadways and/or evaluatedaccess routes. If historic or archaeological materials are uncovered during construction, theOperator is to immediately-stopwork that might further disturb such materials and contact theAuthorized Officer.

Within five working days, the Authorized Officer will inform the operator as to:

Whether the materials appear eligible for the National Historic Register of HistoricPlaces;

The mitigation measures the operator will likely have to undertake before the site can beused (assuming in-situ preservation is not necessary); and,

The time frame for the Authorized Officer to complete an expedited review under 36 CFR800.11 to confirm, through the State Historic Preservation Officer, that the findings of theAuthorized Officer are correct and that the mitigation measures are appropriate.

If the operator wishes, at any time, to relocate activities to avoid the expense of mitigation and/orthe delays associated with this process, the Authorized Officer and/or the surface owner willassume responsibility for whatever recordation and stabilization of the exposed materials may berequired. Otherwise the operator will be responsible for mitigation costs. The Authorized Officerand/or the surface owner will provide technical and procedural guidelines for the conduct ofmitigation. Upon verification from the Authorized Officer that required mitigation has beencompleted, the Operator will then be allowed to resume construction.

On surface administered by the NFS, all surface use will be conducted in accordance with theSTIPULATION FOR LANDS OF THE NATIONAL FOREST SYSTEM UNDERJURISDICTION OF THE DEPARTMENT OF AGRICULTURE, including:

If the surface is owned by another entity (FEE OWNER) and the mineral rights are ownedby the BLM, a right-of-way will be obtained from the other entity.

Operator's employees, including subcontractors, will not gather firewood along roadsconstructed by the operator.




All roads constructed by the operator will have appropriate signs. Signs will be neat andof sound construction. The sign will state: (a) that the land is located within the AshleyNational Forest boundary (b) the name of the Operator, (c) that firearms are prohibited,(d) only authorized personnel are permitted.

All well site locations will have appropriate signs indicating the name of the operator, the leaseserial number, the well name and number, the survey description of the well (either footages or thequarter/quarter section; the section, township, and range).

13 Operator's Representative and Certification

A) Representative

NAME: Kathy K. FieldstedSr. Regulatory & Permitting Tech.

ADDRESS: Berry Petroleum Company4000 South 4028 WestRt. 2 Box 7735Roosevelt, UT 84066

PHONE: 435-722-1325 or 435-823-1920

E-MAIL: [email protected]

All lease and/or unit operations will be conducted in such a manner that full compliance is madewith all applicable laws, regulations, Onshore Oil and Gas Orders and any applicable Notice toLessees.The operator will be fully responsible for the actions of its subcontractors. A complete copy of theapproved "Application for Permit to Drill" and the Standard Operating Procedures will befurnished to the field representative(s) to ensure compliance and shall be on location during allconstruction and drilling operations.The drilling permit will be valid for a period of two years from the date of approval. After permittermination, a new application will be filed for approval for any future operations.

B) Certification:

I hereby certify that I, or persons under my direct supervision, have inspected the proposed drillsite and access route; that I am familiar with the conditions which presently exist; that thestatements made in this plan are, to the best of my knowledge and belief, true and correct; and thatthe work associated with the operations proposed herein will be performed by Berry PetroleumCompany and its contractors and subcontractors in conformity with this plan and the terms andconditions under which it is approved. This statement is subject to the provisions of 18 U.S.C.1001 for the filing of a false statement.

DATE Kathy K. IdstedSr. Regul ry & Permitting Tech.Berry Petroleum Company


PETROSERVICES INCORPORATED

Berry PetroleumASHLEY FOREST5 ½ Production StringWell Name: Federal 13-5D-64

T.D. 350 ftHole Size 12 ¼ inCasing Size 8 5/8 inCasing Weight 24 lbs/ftCement Coverage 350ft to SurfaceCement Excess 50%

Cement 200 sacks 15.8#lgal 1.15cuft/sk 5.0gallskG Cement 100% BWOCCalcium Chloride 2% BWOCFlocel 1/4# per sack

Total mix water (cement only) 1000 gallonsWater ahead 10 bbls(8.33 ppg)Gel Sweep 20 bbls(8.44 ppg)200 sacks of Cement 40.9 bbls(15.8 ppg)Drop Rubber Top PlugDisplacement 19.3 bbls(8.33


P QPETROSERVICES INCORPORATED


With Loss CirculationT.D. 5964 ftHole Size 7 7/8 inCasing Size 5 ½ inCasing Weight 15.50 lbl ftTail Cement Coverage 5964 ft to 3500 ftTail Cement Excess 15 %Lead Cement Coverage 3500 ft to surfaceLead Cement Excess 15 %

Hifill Lead Cmt 200sks 11.0 #/gal 3.82 cuft/sk 23.0 gallskPremium Type V Cmt 100 % (BWOC)Gel 16 % (BWOC)Gilsonite 10 #/skGR 3 3 #/skSalt 3 % (BWOC)Flocele ¼ # /sk

Premium Lite Tail 300 sks 13.1#lgal 1.69 cuft/sk 8.8 gallskPremium Class G Cmt 65 % (BWOC)Poz 35 % (BWOP)Gel 6% (BWOC)CDI 33 .4 % (BWOC)CFL 175 .4 % (BWOC)Flocele ¼ # /skSalt 10 %


P QPETROSERVICES INOORPORATED


Total Mix Water (Cement Only) 7240 gallons

Water ahead 10 bbls(8.33 ppg)Mud Flush 20 bbls(8.34 ppg)Water Spacer 10 bbls(8.33 ppg)Lead Cement 136 bbls(11 ppg)Tail Cement(With No loss Circulation) 89 bbls(14.2 ppg)Wash Pump and Lines and Drop Top PlugDisplacemnet (KCL) 140.8 bbls(8.4


P QPETRO '

SERVICES INOORPORATED


No loss of circulationT.D. 5964 ftHole Size 7 7/8 inCasing Size 5 ½ inCasing Weight 15.50 lb/ ftTail Cement Coverage 5964 ft to 3500ftTail Cement Excess 15 %Lead Cement Coverage 3500 ft to surfaceLead Cement Excess 15 %

Hifill Lead Cmt 200 sks 11.0 #/gal 3.82 cuft/sk 23.0 gallskPremium Type V Cmt 100 % (BWOC)Gel 16 % (BWOC)Gilsonite 10 #/skGR 3 3 #lskSalt 3 % (BWOC)Flocele ¼ # /sk

50/50 Poz Tail Cmt 400 sks 14.2 #/gal 1.26 cuft/sk 5.75 gallskPremium Class G Cmt 50 % (BWOC)Poz 50 % (BWOP)Gel 2 % (BWOC)Salt 10 % (BWOW)CDI 33 .4 % (BWOC)CFL 175 .4 % (BWOC)Flocel ¼


BERRY PETROLEUM COMPANYFEDERAL #11-5D-64, #12-5D-64, #13-5D-64 & #14-5D-64

LOCATED IN DUCHESNE COUNTY, UTAHSECTION 5, T6S, R4W, U.S.B.&M.

PHOTO: VIEW OF LOCATION STAKES CAMERA ANGLE: NORTHEASTERLY

PHOTO: VIEW FROM BEGINNING OF PROPOSED ACCESS CAMERA ANGLE: SOUTHEASTERLY

LOCATIONPHOTæ 10 24 08 PHOTO85 South 200 East Vernal, Utah 84078 vonu mR

e .4 - (435) 789-1017 * FAX (435) 789-1813 TAKENBY:J.R. DRAWNBY:Z.L. REVISED:


BERRY PETROLEUM COMPANYLOCATION LAYOUT FOR

ge FEDERAL #11-50-64, #12-5D-64, #13-5D-64 & #14-5D-64SECTION 5, T6S, R4W, U.S.B.&M. SCALE: 1" = 50'

DATE: 10-24-08NW 1/4 SW 1/4 DRAWN BY: S.L.

i ,st

.2-1o5c c

110'

Round Corners \Approx. as needed

Top of No 16131

Cut Slope

NO : inE/are Pit is to ibe located a minof 100' from the PIPE RACKS

We// Head i i i'

C-8.9 ApproxB. 473° •30 Toe of

C-1.4' 60 Fili siopeD. J9.8'I ,i

~

C-31.0' C-13£/ 5 4' -- -- ,

0.J'100' Sg 1+_75

-,-

C-2 0--ro

es;pg.- o a 404 '-

f-----C-9.0 a 25 J'- EI.

47.4°--

408Pu

MUD HED TOILET

- -- - II II -

. n- - - HOPPER

POWER

TOOLS o

IFUEL 0

/ - b

----STORAGE \ Sto. 0+00

;IANK

Proopdosed Acce

| Dev Ungraded Ground at /13--50 Location Stoke = 7240.4.

, UINTAH ENGINEERING & LAND SURVEYINGDev Graded Ground at /13-50 Location Stoke = 7238.4 85 So. 200 East • Vertial. Utah 840'78 • (435)


BERRY PETROLEUM COMPANY^o

TYPICALCROSS SECTIONSFOR " x-sectionFEDERAL#11-5D-64, #12-5D-64, #13-5D-64 & #14-5D-64 scale

SECTION 5, T6S, R4W, U.S.B.&M. -= so

NW 1/4 SW 1/4

curanishedcrode

IJ 10 40' 100

- 10' 70 40 100

I5

20 100

F/LL QUAN71TY/NCLUDES5X FOR COMPACT/0N SM. 0+00

NOTE:

|APPROX/MATE ACREAGESTopsoil should not be

Stripped Below Finished PROPOSED WELLS/TE D/S1URBANCE = ± 2.418 ACRESGrade on Substructure Area. PROPOSED ACCESS D/S7URBANCE = ± 0.229 ACRES

PROPOSED P/PEL/NE S/7E O/S7URBANCE = ± 0.207 ACRESAPPROXIMATEYARDAGES TorAL = ± 2.854 ACRES

CUT EXCESS MATERIAL =20,600 Cu. Yds.(6") Topsoil Stripping = 2,080 Cu. Yds. Topsoil & Pit Backfill = 4,030 Cu. Yds.

(1/2 Pit Vol.)Remaining Location = 28,7JO Cu. Yds.EXCESS UNBALANCE = 16,570 Cu. Yds.

TOTALCUT = JO,810 CU.YDS. (After Interirn Rehabilitation)UINTAH ENGINEERING & LAND SURVEYINGFILL = 10,210 CU.YDS 86 So. 200 East * Vernal, Utah 84078 * (485)


BERRY PETROLEUM COMPANYLOCATION LAYOUT FOR

FEDERAL #11-5D-64, #12-5D-64, g13-5D-64 & #14-5D-64SECTION 5, T6S, R4W, U.S.B.&M. SCALE: 1" =

50°

DATE: 10-24-08NW 1/4 SW 1/4 DRAWN BY: S.L.

REV: 04-12-10 C.C

F-17.7'6 8 8 20. 7'

6'

110'

und Cornersas needed reApprox. ---

No 161313 ) -Top of re .. o -Cut Slope RO

NOT :Flore Pit is tobe located a rnin

IPE RAcKsof 100' frorn theWel/ Hea

Approx47] 0 eS

pe

I.70 o

5 4'O oo _Stg. 1·.

. , , | 9 C-2.0.... a

bD 40.4'

r' - C-9. O 25 J'EI. 42« C-2.4O 40.8'

MUD HEO TOILET Q

HOPPER

.-4

AGE Û-/·

C-9 9 F-6.2'48.3

ProoposedAccessy R 322'

Dev Ungraded Ground at /13-50 Location Stoke = 7240.4e fÏINTAH ENGINEERING & LAND SURVEYING

Dev Graded Ground at /13-50 Locotion Stoke = 72JB.4 85 So 200 East • Vernal, Utah 84078 • (435)


s

BERRY PETROLEUM COMPANYoTYPICALCROSS SECTIONSFOR " x-section

FEDERAL #11-5D-64, #12-5D-64, #13-5D-64 & #14-5D-64 scaleSECTION 5, T6S, R4W, U.S.B.&M. y _

so.NW 1/4 SW 1/4 DATE: 10-24-08

---

. D Y: S.L.110°

100' E

I

110

curTTI- TT 11- -- ' S/ e = 1 1/2: 1

-

STA 1+75

I|

100 .

-STA 0+50

I110 100'

¯l

¯ijl

* NOTE

- FILL

F/LL QUAN71TY/NCLUDES "N\5X FOR COMPACT/0N STA. 0+00

NOTE:

I. APPROX/MA7EACREAGES

Topsoil should not beStripped Below Finished PROPOSED WELLS/TE D/S7URBANCE = ± 2.418 ACRESGrade on Substructure Area. PROPOSED ACCESS O/S7URBANCE = ± 0.229 ACRES

PROPOSED P/PEL/NE S/7E D/STURBANCE = ± 0.207 ACRES

APPROXIMATEYARDAGES TOTAL = ± 2.854 ACRES

CUT(6") Topsoil Stripping = 2,060 Cu. Yds. EXCESS MATERIAL = 16,690 Cu. Yds.

Topsoil = 2, 060 Cu. Yds.Remaining Location = 24,840 Cu. Yds. EXCESS UNBALANCE = 14,630 Cu. Yds.

TOTALCUT = 26,900 CU.YDS. (After Interim Rehabilitation)UINTAH ENGINEERTNG & LAND SURVEYINGFILL = 10,210 CU.YDS' 86 So. 200 East * Yenuzi, Utah 84078 * (485)


MHON 17.2 Mi +/-

U S. rGHW 40 8 MI. +/-

5 4WW

ssT6S r

SE TOPO "B"

í PROPOSED LOCATION:FEDERAL #11-50-64, #12-5 D-64, , 7#13-SD-64 & #14-SD-64 ,- -

LEGEND: BERRY PETROLEUM COMPANYN FEDERAL #11-5D-64

PROPOSED LOCATION '#12-50 -64. #13-50-64 & #14-5D-64SECTION 5. T6S. RJW, U.S.B.&AL

11 NO 1/4 SW U4usemaurÆWWWMŒ@l-ÐÐ-WoDEMEGd ·¾BM MalSEmmmm -WR"- --P

- Uintah Engineering & Land Surveying TOPO R A P 0 I 74 ()g85 South 200 East Vernal, Utah 84078 y

¯ -

(435) 789-1017 * FAX (435) 189-1813..

MONTH DAY YEAR

SCAL 4WNBY:ZL VISED:


T6S

PROPOSED LOCATION:FEDERAL #11-5D-64, #12-5D-64#13-5D-64 & #14-5D-64

.

LEGEND: BERRY PETROLEUM COMPANYEXISTING ROAD N FEDERAL #ll-5D-64,

----------- PROPosi:n Arri:ss ROAD #l2-5D-64. #13-50-64 & #14-50-64

SECTION 5, T6S, R4W, U.S.B.&M.NW 1/4 SW ll4

- Uintah EngineeringÑi,ail¯Šurveying

TOPOGR A P if I ClO 24 08 m85 South 200 Itust Veruni, Utah 84978 N A I MONTH DAY YEAR $(435) 789-1017 * I LX (435) 789-1813

SCALE:1"= 2000' DRAWNBY:Z.L. REVISED:


ST6S

) EXISTING PIPELINE

PROPOSED LOCATION:FEDERAL #11-5D-64, #12-5D-64,# 5D-64 5D-64

APPROXIMATE TOlAL PIPEl INE DISlANCE = 300' -

LEGEND: BERRY PETROLEUM COMPANYPROPOSED ACCESS ROAD N FEDERAL #11-5D-64,

---·----- EXISTING PIPELINE #12-5D-64, #13-5D-64 & #14-5D-64----------- PI(Opua.( II I•|PI | |\I

PROPOSED PIPELINE SECTION 5, T6S, R4W, U.S.B.&M.<st R\ ICl\GOlllER MI:I I b) NW 1/4 SW 1/4

Uintah Engineering & Land Surveying TOPOG 11 .\ l' 11 1 0 10 24 0885 South 200 East VernaL, Utah 84078 \Î ,\ Ÿ 10NTH DA1 YEAR

't (435) 789-1017 * FAX (435) 789-1813SCALE:1" = 1000' DRAWNBY:Z.L. VISED:

'APIWellNo:43013503370000''AP ellNo:4 135 3 0000'

T6S

PROPOSED LOCATION:FEDERAL #1I-5D-64 #12-50-64

5D-64 & #14-

1LEGEND: BERRY PETROLEUM COMPANY

DisrosAL WELLS WATER WELLs N FEDERAL #11-59-64,

O PRODUCING WELLS ABANDONED WELLS #12-50-64, #13-50-64 & #14-50-64

slitT IN WELLS -G- TEMPORARILY ABANDONED SECTION 5, T6S, R4W, U.S.B.&&l.NM 1/4 SW l/4

Uintah Engineering & Land Surveying TOPOGR A P II I Cl 0 24 08- 85 South 200 East Vernal, Utah 84078 \l A 13 MONTE DAY YEAR(435) 789-1017 * FAX (435) 789-1813

SCALE:1" = 2000' DRAWNBY:Z.L


Berry Petroleum CompanyBrundage Canyon Field

4000 South 4028 WestRt. 2 Box 7755

Roosevelt, UT 84066

Ph: (435) 722-1325. Fax: (435) 722-1321

Apnl 6, 2010 www.bry.com

State of UtahDivision of Oil, Gas and MiningP.O. Box 145801Salt Lake City, UT 84115-5801

Re: Directional Drilling R649-3-11Federal 13-5D-64: 1,338' FSL, 972' FWL (NWSW) (surface)

654' FSL, 665' FWL (SWSW) (bottomhole)Section 5, T6S-R4WDuchesne, County, Utah

Pursuant to the filing of Berry Petroleum's Application for Permit to Drill regarding theabove referenced well, we are hereby submitting this letter in accordance with Oil & GasConservation Rule R649-3-11 pertaining to the Exception to Location and Siting ofWells.

• The Federal 13-5D-64 well is to be located within the Brundage Canyon FieldArea.

• Berry is locating the well at the surface location and directionally drilling fromthis location to minimize surface disturbance and Berry will be able to utilize theexisting road and pipelines in the area.

• Furthermore, Berry hereby certifies that it is the sole working interest owner with460 feet of the entire directional well bore and the remainder of the Ute Tribalsection.

Therefore, based on the above stated information Berry Petroleum Company requests thepermit be granted pursuant to R649-3-11.

Kathy . FieldstedRegulatory & Permitting Specialist

Corporate Headquarters - 1999 Broadway, Ste. 3700 • Denver, CO 80202

'APIW

ellNo:43013503370000'

T6 S, R4 W, U.S. B. &M. BERRY PETROLEUM COMPANYWell location, FEDERAL#13-5D-64, located osshown in the NW 1/4 SW 1/4 of Section 5,

¾i,7.,, fwim T6S, R4W. U.S.B.&M., Duchesne County, Utoh.r-w rencane 589'43'11"E 5 17 « -

58925 08"W - 26617J' (Meos.) 262751' (Meas.) TSS .ca£>s1-NB9'56'JS"W - 5288.85' (Meas.)--

CC Re-Tsfab½oe CCSei Storre Ðy georings free, 6 S s,, s,... ,,, se c4 s., 4

of Stoner. E-y 190J &ost

BASIS OF ELEVATION oLot 4 Lot 3 Lot 2 Lot 1

BENCH MARK (M67) LOCATEDIN THE SW 1/4 OF SECTIOM

BASIS OF BEARINGS 9. T5S, R4W, U.S.B.&M., TAKEN FROM THE OUCHESNESEh QUADRANGLE,UTAH, DUCHESNECOUNTY, 7.5 MINUTEQUAD.

BASIS OF BEARINGSIS A C P.S. OBSERVATION• (TOPOGRAPHICMAP) PUBLISHEDBY THE UNITEDSTATESDEPARTMENT OF THE INTERIOR.GEOLOCICALSURVEY. SAIDELEVATION FS MARKEDON CAP AS BEING6097 FEET.

LINE TABLE ILINE DIRECTION LENCTH

o L1 SBQQ4'7"W Ig).QO'L2 524•t4'26"W 753.05

5 ser sten,

o

RAL /13-50--64SCALE

.Dev Ungraded Ground = 7?40' IH

9 2 OFRilrirA TFTHIS IS TO CEltT1FY THAT THE ABOVE

A

PICLDNOTE5Or ACTUALSURVEYSM tB tom ERVIS10N AND THAT THESAMEA E O CORREC

B T OŸ MY WNOWLEOGEAND BEDER No 161319

I-RECIST 181319

REVISED: 04-12-10 C.C. syggyREVISED: 04-08-09 C.C. TE (p 6Set Stone

SB92829"w - 5334.96' (Me¤s.)Um·rauENOMERNG a Lamo vmc

se r "' 85 SOUTH 200 BAST - VERNAL, UTAH 84078(435) 789-1017

LEGEND: Nao a3 (Tancer eotrou notE) NAO 83 (SURrAŒ LOCATØi) SCALC DATE$URVEWD OATE DRAWFe

=90° SYMBOL l.Azauot . Je'se0008" (39.983356) LATITUDE = 39'59'05.86" (39985239) 1 = 100Ô 09-30-08 TÔ-24-OS

t.0NGITUDE - 110'21'57.81" (110 366058) LONGITUDE= 110'21'53.84' (110 364956) PARrY REFERENCES

= PROPOSED WELL HEAD. NAD 27 (TAncET potrOM NOLE) NAO 27 (SURVAŒ LOCARON)S.H. J.R. S.L G.L.0 Pt.AT

A = SECTION CORNERS LOCATED LATITuoE - 39'se'oa21" (39983392) LATivuot - 39'se'or,co" (39985278)W£AINCO fiLE

• LONORUDE = MOW5526" 10.365360) LONGRUDE e MOWS1,29" 01o364¾) COOL BERRY PËTROLEUM

'APIW

ellNo:43013503370000'

BERRY PETRO UM COMPANYBHL 654 FSL, BBS'FWL

y Nat ona o Prooject

2.944

BUo

201


uin kant issiu.a,

ui mai.ii-s2o-a ule imuu.wry uIe inituu.u-wa-" API Number: 4301350337noor • 333793 .4301335902 4301333090E L 11-318

412-32-54

0B 11-33-" Well Name: FEDERAL 13-5D-64

ETRI 14-31D-54 ETRIBAL 14-Me UTE TRIBAL 16-32D-54 TOWAShip 06.0 8 Range 04.0 W Section 6

5 30 31 UTE T L 15S S UTE TRIBAL 13 32-54 4301332926 33 UTE TRIBAL 14-33-54 Merldlan: UBM4soi so .4301832692 * 4301333093e Operator: BERRY PETROLEUMCOMPANY

UTE TR lAL 1 $$ UTE TRIBAL 15-32 54 4301332742430138 56 UTETRIBAL 16-31-54 4301332e6e Map Prepared:

4301332745 Map Produced by Diana Mason

BRUNDAGE CANYON FIELDFEDERALB4De4 ms ....

FEDERAL1-644 suununow g on-ap..um.a4301350266 anser Eo cut-ap...asam.c--o

E 3-5EMI4 ERAL4-5D44 FN' / om.a......

FEDERAL 8-1 85430133 ED1E

SD 64 as-o.au...

4301350350 ERAL 54D44 FEDE L6-5D44 350259 FEDERAL&444E Sti 45 4301 86 430 333450 e ton.m.i....

4301350288 m.m A em---

ERAL 7 60 64 - * m.ne..sai......

FEDERAL 64D44 4301334020 Temness 4 mm-mm.ao.m

6 «soinvas 4 .. , e --.-.=-

1 ..... e ..r-.....=•

am--naa..m-O- arm-a.aa.oim

ý m.maal.....L o m.mm

FEDERAL14-5 ** 12-5944 / inum-mmm

FEDEF .L 14 6044 ERAL 134DS4 4301350338 250340 / mr mrn....m

430133 285 01350347 FEDERAL13-SO44 -DERAL11-5 84 e m.m.umma.em

FEDER.L 11 8044D 12-6D44 4301350357 4301-150348

430133 284

a..es. Location Map

t-b

12 7 6 9 --

tone eos o teenman

WORKSHEETAPPLICATION FOR PERMIT TO DRILL

APD RECEIVED: 4/27/2010 API NO. ASSIGNED: 43013503370000

WELL NAME: FEDERAL 13-5D-64

OPERATOR: BERRY PETROLEUM COMPANY (N2480) PHONE NUMBER: 435 722-1325

CONTACT: Kathy K. Fieldsted

PROPOSED LOCATION: NWSW 5 060S 040W Permit Tech Review:

SURFACE: 1338 FSL 0972 FWL Engineering Review:

BOTTOM: 0654 FSL 0665 FWL Geology Review:

COUNTY: DUCHESNE

LATITUDE: 39.98531 LONGITUDE: -110.36424

UTM SURF EASTINGS: 554282.00 NORTHINGS: 4426110.00

FIELD NAME: BRUNDAGE CANYON

LEASE TYPE: 1 - Federal

LEASE NUMBER: UTU-8894A PROPOSED PRODUCING FORMATION(S): GREEN RIVER

SURFACE OWNER: 1 - Federal COALBED METHANE: NO

RECEIVED AND/OR REVIEWED: LOCATION AND SITING:

PLAT R649-2-3.

Bond: FEDERAL - UTB000035 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: 43-11041 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: 4 - Federal Approval - dmason 15 - Directional - dmason 23 - Spacing - dmason

WORKSHEETAPPLICATION FOR PERMIT TO DRILL

I

I

APD RECEIVED: 4/27/2010 API NO. ASSIGNED: 43013503370000

WELL NAME: FEDERAL 13-5D-64

OPERATOR: BERRY PETROLEUM COMPANY (N2480) PHONE NUMBER: 435 722-1325

CONTACT: Kathy K. Fieldsted

PROPOSED LOCATION: NWSW 5 060S 040W Permit Tech Review:

SURFACE: 1338 FSL 0972 FWL Engineering Review:

BOTTOM: 0654 FSL 0665 FWL Geology Review:

COUNTY: DUCHESNE

LATITUDE: 39.98531 LONGITUDE: -110.36424

UTM SURF EASTINGS: 554282.00 NORTHINGS: 4426110.00

FIELD NAME: BRUNDAGE CANYON

LEASE TYPE: 1 - Federal

LEASE NUMBER: UTU-8894A PROPOSED PRODUCING FORMATION(S): GREEN RIVER

SURFACE OWNER: 1 - Federal COALBED METHANE: NO

I

RECEIVED AND/OR REVIEWED: LOCATION AND SITING:

PLAT R649-2-3.

Bond: FEDERAL - UTBOOOO35 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: 43-11041 Board Cause No: R649-3-11

RDCC Review: Effective Date:

Fee Surface Agreement Siting:

Intent to Commingle R649-3-11. Directional Drill

Commingling Approved

I

Comments: Presite Completed

Stipulations: 4 - Federal Approval - dmason15 - Directional - dmason23 - Spacing -

Permit To Drill

******************Well Name: FEDERAL 13-5D-64

API Well Number: 43013503370000

Lease Number: UTU-8894A

Surface Owner: FEDERAL

Approval Date: 5/12/2010

Issued to:BERRY PETROLEUM COMPANY, 4000 South 4028 West Rt 2 Box 7735, Roosevelt, UT 84066

Authority:Pursuant to Utah Code Ann. §40-6-1 et seq., and Utah Administrative Code R649-3-1 et seq., theUtah Division of Oil, Gas and Mining issues conditions of approval, and permit to drill the listedwell. This permit is issued in accordance with the requirements of R649-3-11. The expectedproducing formation or pool is the GREEN RIVER Formation(s), completion into any other zoneswill require filing a Sundry Notice (Form 9). Completion and commingling of more than one poolwill require approval in accordance with R649-3-22.

Duration:This approval shall expire one year from the above date unless substantial and continuous operationis underway, or a request for extension is made prior to the expiration date

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

Conditions of Approval:State approval of this well does not supercede the required federal approval, which must be obtainedprior to drilling.

In accordance with Utah Admin. R.649-3-11, Directional Drilling, the operator shall submit acomplete angular deviation and directional survey report to the Division within 30 days followingcompletion of the well.

This proposed well is located in an area for which drilling units (well spacing patterns) have not beenestablished through an order of the Board of Oil, Gas and Mining (the “Board”). In order to avoid thepossibility of waste or injury to correlative rights, the operator is requested, once the well has beendrilled, completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soon as is practicableafter completion of its analysis, and if the analysis suggests an area larger than the quarter-quartersection upon which the well is located is being drained, the operator is requested to seek anappropriate order from the Board establishing drilling and spacing units in conformance with suchanalysis by filing a Request for Agency Action with the Board.

Notification Requirements:

API Well No: 43013503370000API Well No: 43013503370000

State of Utah, DEPARTMENT OF NATURAL RESOURCES"

MICHAEL R. STYLER

GAR . H HERT Excutiw Drotor

comrwr Division of Oil, Gas and MiningGREGORY S. BELL JOHN R. BA2ALieuterard Gowrver Dusion Dmctor

Permit To Drillkkkkkkkkkkkkkkkkkk

Well Name: FEDERAL 13-5D-64API Well Number: 43013503370000

Lease Number: UTU-8894ASurface Owner: FEDERALApproval Date: 5/12/2010

Issued to:BERRY PETROLEUM COMPANY, 4000 South 4028 West Rt 2 Box 7735, Roosevelt, UT 84066

Authority:Pursuant to Utah Code Ann. §40-6-1et seq., and Utah Administrative Code R649-3-1 et seq., theUtah Division of Oil, Gas and Mining issues conditions of approval, and permit to drill the listedwell. This permit is issued in accordance with the requirements of R649-3-11. The expectedproducing formation or pool is the GREEN RIVER Formation(s), completion into any other zoneswill require filing a Sundry Notice (Form 9). Completion and commingling of more than one poolwill require approval in accordance with R649-3-22.

Duration:This approval shall expire one year from the above date unless substantial and continuous operationis underway, or a request for extension is made prior to the expiration date

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

Conditions of Approval:State approval of this well does not supercede the required federal approval, which must be obtainedprior to drilling.

In accordance with Utah Admin. R.649-3-11, Directional Drilling, the operator shall submit acomplete angular deviation and directional survey report to the Division within 30 days followingcompletion of the well.

This proposed well is located in an area for which drilling units (well spacing patterns) have not beenestablished through an order of the Board of Oil, Gas and Mining (the "Board"). In order to avoid thepossibility of waste or injury to correlative rights, the operator is requested, once the well has beendrilled, completed, and has produced, to analyze geological and engineering data generatedtherefrom, as well as any similar data from surrounding areas if available. As soon as is practicableafter completion of its analysis, and if the analysis suggests an area larger than the quarter-quartersection upon which the well is located is being drained, the operator is requested to seek anappropriate order from the Board establishing drilling and spacing units in conformance with suchanalysis by filing a Request for Agency Action with the Board.

Notification

The operator is required to notify the Division of Oil, Gas and Mining of the following actions duringdrilling of this well: • Within 24 hours following the spudding of the well – contact Carol Daniels at 801-538-5284 (please leave a voicemail message if not available) OR submit an electronic sundry notice (pre-registration required) via the Utah Oil & Gas website at https://oilgas.ogm.utah.gov

Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas Conservation General Ruleswill 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:

Gil HuntAssociate Director, Oil & Gas

API Well No: 43013503370000API Well No: 43013503370000

The operator is required to notify the Division of Oil, Gas and Mining of the following actions duringdrilling of this well:

• Within 24 hours following the spudding of the well - contact Carol Daniels at 801-538-5284(please leave a voicemail message if not available)ORsubmit an electronic sundry notice (pre-registration required) via the Utah Oil & Gas websiteat https://oilgas.ogm.utah.gov

Reporting Requirements:All reports, forms and submittals as required by the Utah Oil and Gas Conservation General Ruleswill 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:

Gil HuntAssociate Director, Oil &

Form 3160-3 ' FORM APPROVED(August 2007) OMB No. 1004-0136

UNITED STATES Expires July 31, 2010

DEPARTMENT OF THE INTERIORBUREAU OF LAND MANAGEMENT 5. LeaseserialNo.

UTU8894A

APPLICATION FOR PERMIT TO DRILL OR REENTER 6. It Indian, Allottee or Tribe Name

la. Typeof Work: g bklLL 0 kEEN Ikk ). It Unitor CA Agreement, Name and No.

8. LeaseName and wellNo.

Ib. Type of Well: g Oil Well O Gas Well O Other 0 Single Zone Multiple Zone FEDERAL 13-5D-64

2. Name of Operator Contact: kA IHY k HELDS IED 9. APIWellNo.BERRY PETROLEUM E-Mail: [email protected]

3a. Address 3b. Phone No. (molude area code) 10. Field and Pool,or LxploratoryROUTE 2 BOX 7735 4000 SO. 4028 W. Ph: 435-722-1325 BRUNDAGE CANYONROOSEVELT, UT 84066 Fx: 435-722-1321

4. Locationof Well (Report locationclearly and in accordance with any State requirements.*) 11. Sec., 1.,k., Ivi.,or Blk.and surveyor Area

At surface NWSW 1338FSL 972FWL Sec 5 T6S R4W Mer UBMAt proposed prod. zone SWSW 654FSL 665FWL

14. bistance m miles and directionfrom nearest town or post ottice* 12. County or Parish 13.btate25 DUCHESNE UT

15.Distancefiom proposed locationto nearest property or 16. No. of Acres m Lease l'/. Spacing Unitdedicatedto this welllease line, it. (Also to nearest drig. unit line, if any)

972 1280.00

18. bistance trom proposed locationto nearest well, drillmg, 19. Proposed Depth 20. JaLivl/blA BondNo. on filecompleted, applied for, on this lease, ft.

2300 5964MD UTBOOOO35 -

5931 TVD21. Elevations (showwhether DP,kh, kl', GL,etc. 22. Approximate datework will start 23. Estimatedduration

7240 GL

24. Attachments

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

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

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

25. Signature Ñame(Printedityped) bate(Electronic Submission) KATHYK FIELDSTED Ph: 435-722-1325 05/03/2010

ÍitleSR. RE ULATORY & PERMITTING TE

Approved re) Name (Prin Da

e

dA

Ottice

VERNALFIELDOFFICEApplication approval does not warrant or certify e applicant holdslegalor equitable title to those rights in tile subject leasewhich would entitle the apphcant to conductoperations thereon.Conditions of approval, if any, are attached. 00NDITIONSOFAPPROVALATTACHEDTitle 18 U.S.C. Section 1001 and Title43 U.S.C. Section 1212, make it a crime for any person knowingly and willfully to make to any department or agency ofthe UmtedStates any false, fictitious or fraudulent statements or representations as to any matter within its jurisdiction.

Electronic Submission #85786 verified by the BLM Well Information SystemFor BERRY PETROLEUM, sent to the Vernal

Committed to AFMSS for processing by ROBIN R. HANSEN on 05/03/2010 ()RECEIVED NOS 3 /JUL19 2010 NOTICEOFAPPROVAL

DIV.0FOIL,GAS&MINING** OPERATOR-SUBM TED ** OPERATOR-SUBMITTED ** OPERATOR UBMITTED

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: Berry Petroleum Company Location: NWSW, Sec. 5, T6S, R4WWell No: Federal 13-5D-64 Lease No: UTU-8894AAPI No: 43-013-50337 Agreement: NIA

BLM OFFICE NUMBER: (435) 781-4400Forest Service Number: (435) 790-3924

BLM OFFICE FAX NO.: (435) 781-3420Forest Service Fax No.: (435) 781-5215

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 an(Notify Forest Service Environmental access roads.Scientist Sherry Fountain)Location Completion - Prior to movingon the drilling rig.(Notify Forest Service EnvironmentalScientist Sherry Fountain)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: ut vn [email protected].

BOP & 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 off production for

more than ninety (90)

of 9Well: Federal 13-5D-64

6/17/2010

SURFACE USE PROGRAMCONDITIONS OF APPROVAL (COAs)

Conditions of Approval for 2009 Berry CE Drilling ProposalRoosevelt - Duchesne Districts, Ashley National ForestCompiled by David Herron, August 20, 2009

IntroductionThe following is a list of conditions of approval (COAs), being required by the Ashley National Forest, aspart of the approval for specific wells and well pads, and their associated development and productionactivities. These wells and well pads were proposed for construction and development as part of BerryPetroleum's 27-well drilling proposal and Surface Use Plan (SUPO), submitted to the Ashley NationalForest during the spring of 2009, and being approved by the Ashley National Forest in August 2009. TheseConditions of Approval are in connection with, and in addition to, those listed in the Surface Use Plan ofOperations (SUPO) submitted by Berry Petroleum for the proposed wells and associated well pads andproduction equipment.

List of Well Pads and WellsThe following is a list of the proposed well pads, and associated wells, which are being approved forconstructions and development, and to which these conditions of approval will apply. These wells and wellpads are also shown on the map accompanying this document.

Map # Well Pad Name Well Name Legal Location

1 ANF 4-6D-64 Berry 3-6D-64 T6S R4W NW ¼ Section 6 USM.Berry 4-6D-64Berry 5-6D-64 Revised 03/30/2010 by S. Fountain

2 ANF 14-6D-64 Berry 11-6D-64 T6S R4W SW ¼ Section 6 USM.Berry 12-6D-64Berry 13-6D-64Berry 14-6D-64

3 ANF 3-5D-64 Berry 3-5D-64 T6S R4W NW ¼ Section 5 USM.Berry 4-5D-64Berry 5-5D-64Berry 6-5D-64

4 ANF 1-6-64 Berry 1-6-64 T6S R4W NE ¼ Section 6 USM.Berry 2-6D-64Berry 8-6D-64

5 ANF 8-lD-65 Berry 8-lD-65 T6S R5W NE ¼ Section 1 USM.Berry 9-lD-65Berry


6/17/2010

6 ANF 12-5D-64 Berry 11-5D-64 T6S R4W SW ¼ Section 5 USM.Berry 12-5D-64Berry 13-5D-64Berry 14-5D-64

7 ANF 12-lD-65 Berry ll-lD-65 T6S R5W SW ¼ Section 1 USM.Berry 12-1D-65Berry 13-lD-65Berry 14-1D-65

General Conditions of ApprovalThese Conditions of Approval apply to all the wells and well pads listed above.

Vegetation Resources

• To reduce the spread/introduction of noxious and invasive weed species via project-related vehiclesand equipment into the Project Area, Berry and its contractors will power-wash all constructionequipment and vehicles prior to the start of construction.

• Berry will implement a weed control program. Weed control will be conducted through anApproved Pesticide Use and Weed Control Plan from the Authorized Officer. Weed monitoring andreclamation measures will be continued on an annual basis (or as frequently as the AuthorizedOfficer determines) throughout the 30 year life of the project. Berry will reseed all portions of wellpads and access and pipeline ROW not being utilized for the project operations, as well as anydisturbed sites within the Project Area determined necessary by the USFS. Reseeding will beaccomplished using native plant species, and as directed by the Forest Service.

Wildlife Protection

• Prior to any surface disturbing activity between April 30 and August 31, Berry or their contractor, incoordination with a USFS Biologist, will survey all areas within 0.25 mile of proposed surfacedisturbance for the presence of raptor nests. If occupied/active raptor nests are found, constructionwill not occur during the critical nesting season for that species within the species-specific spatialbuffer, unless the nest is obscured from visual or noise-related impacts through vegetative ortopographic screening. USFS biologists will determine spatial buffers based on site-specificvegetative and topographic features within the vicinity of occupied nests.

• Well pad and road construction, roads upgrading, and drilling operations will not be conductedbetween November 15 and April 30, to protect elk winter range.

Paleontology

• Well pads or road construction activities involving excavation of bedrock must be monitored by aqualified Paleontologist. If significant paleontological resources are discovered or observed,construction activities will be halted and the USFS notified. Operations in the area of the


6/17/2010

(well pad or road or pipeline in question) will not resume until authorization to proceed has beenreceived from the Forest Service.

Cultural Resources

• If cultural resources are inadvertently discovered, construction activities will be halted and the ForestService notified. Operations in the area of the discovery (well pad or road or pipeline in question)will not resume until authorization to proceed has been received from the Forest Service.

Access Roads

• Construction or upgrading of roads will not be allowed during muddy or frozen conditions. Shouldmud holes develop in access roads, they would be filled in with appropriate materials. Detoursaround mud holes are not allowed.

• Where road developments cross existing cattle fences, cattle guards will be installed and fences willbe repaired to functioning condition.

• As needed, Berry will apply water to utilized roads to reduce fugitive dust from vehicle traffic. Ifwater application does not adequately reduce fugitive dust, the use of Magnesium Chloride (MgCl)or other dust-abatement treatments may be required.

• Road drainage crossings for new or upgraded roads will be designed, and maintained for the life ofthe project, such that drainages are not blocked by road crossings, and so the road crossings do notcause erosion or siltation within the drainages being crossed.

Pipelines

• Where possible, pipelines will be buried along areas where surface pipelines would be at risk fromenvironmental hazards (stream crossings, debris flow fans, etc.).

Soils / Water /Floodplains / Wetlands

• Vegetation and/or structural measures to control erosion will be implemented as soon as possibleafter initial soil disturbance to prevent erosion of disturbed soils.

• Energy dissipaters such as straw bales and silt fences may be required to prevent excess erosion ofsoils from disturbed areas into adjacent surface waters or floodplains. These structures would beinstalled during construction, and would be left in place and maintained for the life of the project oruntil the disturbed slopes have revegetated and stabilized.

Noise

• Pump jack engines will be equipped with high grade mufflers to reduce noise during the operationallife of the project.

Reserve Pits

• All pits containing materials that might be hazardous to wildlife will be covered with steel meshscreen or netting to prevent entry by migratory birds, bats, or other wildlife


6/17/2010

• Reserve pits will be lined with 20 mil (or thicker) synthetic reinforced material. The liner wouldoverlay a felt liner pad which would protect the liner from punctures if rock is encountered duringexcavation.

Conditions of Approval Related to Specific Well Pads

Soils / Water / Floodplains / Wetlands

The following Conditions of Approval apply to construction and maintenance of the following proposedwell pads: ANF 14-6D-64 well pad, and ANF 1-6-64 well pad.

• Engineered earthen berms, diversion channels, and/or other pad design modifications, are requiredfor this site, in order to divert ephemeral surface drainages and potential debris flows away from thewell pad, access road, and reserve pit areas. Diversions will be done in a way that minimizesimpacts to the existing channels and canyon bottom, maintains original drainage grade, does notconstrict ephemeral flows, and also protects the well site from potential flooding. These structureswill be installed during construction, and will be left in place and maintained for the life of theproject or until all disturbed areas have been reclaimed, revegetated, and stabilized.

( end of document


6/17/2010

DOWNHOLE PROGRAMCONDITIONS OF APPROVAL (COAs)

SITE SPECIFIC DOWNHOLE COAs:

• None.

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

DRILLINGICOMPLETIONIPRODUCING OPERATING STANDARDS

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

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

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

• Blowout prevention equipment (BOPE) shall remain in use until the 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 i by the rig pumps. Test shall be reported in the driller's

• BOP drills shall be initially conducted by each drilling crew within 24 hours of drilling out 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 within casing.

• Cement baskets shall not be run on surface casing.

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

• The operator must report encounters of all non oil & gas mineral resources (such as Gilsonite, tarsands, oil shale, 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 (a\ong with a telephone number) should the BLMneed to obtain additional


6/17/2010

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

• While activelydrilling, 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 Engineersuntil the 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 BLMVernal Field


6/17/2010

OPERATING REQUIREMENT REMINDERS:

• Allwells, whether drilling, producing, suspended, or abandoned, shall be identified in accordancewith 43 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.

• In accordance with 43 CFR 3162.4-3, thiswell shall be reported on the "Monthly Report ofOperations" (Oil and Gas Operations Report ((OGOR)) starting with the month in which operationscommence and continue each month until the well is physically plugged and abandoned. Thisreport shall be filed in duplicate, directly with the Minerals Management Service, P.O. Box 17110,Denver, Colorado 80217-0110, or call 1-800-525-7922 (303) 231-3650 for reporting information.

• Should the well be successfully completed for production, the BLMVernal Field office must benotified when it is placed in a producing status. Such notification will be by 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 notification shall provide, as a minimum, the followinginformational items:

o Operator name, address, and telephonenumber.

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 royalty will bepaid).

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 thenon-Federal or non-Indian land category, i.e., State or private.

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

o Communitization agreement number, ifapplicable.

• 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 willbereported to the BLM,Verna\ Field Office. Major events, 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, "Well Completion 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


6/17/2010

Submit with the well completion report a geologic report including, at a minimum, formation tops,and a summary and conclusions. Also include deviation surveys, sample descriptions, strip logs,core data, drill stem test data, and results of production tests if performed. Samples (cuttings, fluid,and/or gas) shall be submitted onlywhen requested by the BLM,Vernal Field Office.

• All off-lease storage, off-lease measurement, or commingling on-lease or off-lease, shall have priorwritten approval from the BLMVernal Field Office.

• Oil and 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 calibrationand allfuture meter proving schedules. A copy of the meter calibration reports shall be submitted to theBLMVernal Field Office. All measurement facilities willconform to the API standards for liquidhydrocarbons and the AGA standards for natural gas measurement. All measurement 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.All site security regulations as specified in Onshore Oil & Gas Order No. 3 shall be adhered to. Allproduct lines entering and leaving hydrocarbon storage tanks will be effectively sealed inaccordance with Onshore Oil & Gas Order No. 3.

• Any additional construction, reconstruction, or alterations of facilities, including roads, gatheringlines, batteries, etc., which willresult in the disturbance of new ground, shall require the filing of asuitable plan and need prior approval of the BLMVernal 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. If operations are to be suspended for more than 30 days, priorapproval of the BLMVernal Field Office shall be obtained and notification given before resumptionof operations.

• Pursuant to Onshore Oil & Gas Order No. 7, this is authorization for pit disposal of water producedfrom this well for a period of 90 days from the date of initial production. A permanent disposalmethod must be approved by this officeand 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 will be considered as an Incident of Noncompliance and will begrounds for issuing a shut-in order until an 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 notified at least 24 hours in advance of the plugging of the well, inorder that a representative may witness plugging operations. Ifa well is suspended or abandoned,all pits must be fenced immediately until theyare backfilled. The "Subsequent Report ofAbandonment" (Form BLM3160-5) must be submitted within 30 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

API Well No: 43013503370000


DIVISION OF OIL, GAS, AND MINING

FORM 9

5.LEASE DESIGNATION AND SERIAL NUMBER: UTU-8894A

SUNDRY NOTICES AND REPORTS ON WELLSDo not use this form for proposals to drill new wells, significantly deepen existing wells below currentbottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION FOR PERMIT TODRILL form for such proposals.

6. IF INDIAN, ALLOTTEE OR TRIBE NAME:

7.UNIT or CA AGREEMENT NAME:

1. TYPE OF WELL Oil Well

8. WELL NAME and NUMBER: FEDERAL 13-5D-64

2. NAME OF OPERATOR: BERRY PETROLEUM COMPANY

9. API NUMBER: 43013503370000

3. ADDRESS OF OPERATOR: 4000 South 4028 West Rt 2 Box 7735 , Roosevelt, UT, 84066

9. FIELD and POOL or WILDCAT: BRUNDAGE CANYON

4. LOCATION OF WELL FOOTAGES AT SURFACE: 1338 FSL 0972 FWL QTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: Qtr/Qtr: NWSW Section: 05 Township: 06.0S Range: 04.0W Meridian: U

COUNTY: DUCHESNE

STATE: UTAH

11.

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

TYPE OF SUBMISSION TYPE OF ACTION

NOTICE OF INTENTApproximate date work will start:

SUBSEQUENT REPORTDate of Work Completion:

SPUD REPORTDate of Spud:

7/26/2010

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.

PLEASE NOTE THAT THE FEDERAL 13-5D-64 WAS SPUD ON JULY 26, 2010 ATAPPROX 11:30 PM BY CRAIG'S ROUSTABOUT SERVICES.

NAME (PLEASE PRINT) Kathy K. Fieldsted

TITLE Sr. Regulatory & Permitting Tech.

SIGNATURE N/A

DATE 7/27/2010

PHONE NUMBER:303 999-4044 Ext

PHONE NUMBER435 722-1325

July 27, 2010

iPI Well No: 43013503370000

FORM 9STATE OF UTAH

DEPARTMENT OF NATURAL RESOURCESDIVISION OF OIL, GAS, AND MINING 5.LEASE D4ESIGNATION AND SERIAL NUMBER:

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

Do not use this form for proposals to drill new wells, significantly deepen existing wells below currentbottom-hole depth, reenter plugged wells, or to drill horizontal laterals. Use APPLICATION FOR PERMIT TO 7.UNIT or CA AGREEMENT NAME:

DRILL form for such proposals.

1. TYPE OF WELL 8. WELL NAME and NUMBER:Oil Well FEDERAL 13-5D-64

2.NAMEOFOPERATOR: 9.APINUMBER:BERRYPETROLEUMCOMPANY 43013503370000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:4000 South 4028 West Rt 2 Box 7735 , Roosevelt, UT, 84066 303 999-4044 Ext BRUNDAGE CANYON

4.LOCATIONOFWELL COUNTY:FOOTAGES AT SURFACE: DUCHESNE

1338 FSL 0972 FWLQTR/QTR, SECTION, TOWNSHIP, RANGE, MERIDIAN: STATE:

Qtr/Qtr: NWSW Section: 05 Township: 06.05 Range: 04.0W Meridian: U UTAH

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



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


SDUato

WENrkRCEPmOption: DEEPEN FRACTURE TREAT NEW CONSTRUCTION


SPUD REPORTPRODUCTION START OR RESUME RECLAMATION OF WELL SITE RECOMPLETE DIFFERENT FORMATION

Date of Spud:

7/26/2010 REPERFORATE CURRENT FORMATION SIDETRACK TO REPAIR WELL TEMPORARY ABANDON


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


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

PLEASE NOTE THAT THE FEDERAL 13-5D-64 WAS SPUD ON JULY 26, 2010 ATAPPROX 11:30 PM BY CRAIG'S ROUSTABOUT SERVICES.

NAME (PLEASE PRINT) PHONE NUMBER TITLEKathy K. Fieldsted 435 722-1325 Sr. Regulatory & Permitting Tech.

SIGNATURE DATEN/A 7/27/2010

RECEIVED July 27,

STATE OF UTAH FORM 6DEPARTMENTOFNATURALRESOURCES

DIVISIONOF OIL,GAS AND MINING

ENTITY ACTION FORM

Operator: BERRY PETROLEUM COMPANY Operator Account Number: N 2480

Address: 4000 S. 4028 W., RT. 2 BOX 7735

city ROOSEVELT

state UT zio 84066 Phone Number: (435) 722-1325

Well 1API Number Well Name QQ Sec Twp Rng County4301350349 FEDERAL 12-SD-64 NWSW 5 6S 4W DUCHESNE

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

7/26/2010Comments:

SPUDDED BY: CRAIG'S ROUSTABOUT

Well 2API Number Well Name QQ Sec Twp Rng County4301350337 FEDERAL 13-5D-64 NWSW 5 6S 4W DUCHESNE


C Ej // ' 7/26/2010Comm nts: / /

SPUDDED 3Y CRAIG'S ROUSTABOUT

Well 3

API Number Well Name QQ Sec Twp Rng County4301350338 FEDERAL 14-5D-64 NWSW 5 6S 4W DUCHESNE


' / O 7/27/2010 / OComments:

SPUDDED BY CRAIG'S ROUSTABOUT

ACTION CODES:A - Establish new entity for new well (single well only) KATHY K . FIELDSTEDB - Add new well to existing entity (groupor unit well) N (P se nt)C - Re-assign well from one existing entity to another existing entity -

D - Re-assign well from one existing entity to a new entity Si atureE - Other (Explain in 'comrnents' section) Sr. Reg tory& Permitting 7/27/2010

RECElVED ""' °•''(5/2000)

JUL212010DIV.OF0tLGM A

API Well No: 43013503370000



FORM 9








9. API NUMBER: 43013503370000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 4000 South 4028 West Rt 2 Box 7735 , Roosevelt, UT, 84066 303 999-4044 Ext



COUNTY: DUCHESNE

STATE: UTAH

11.







8/13/2010












PLEASE SEE THE ATTACHED DRILLING HISTORY FOR THE FEDERAL 13-5D-64.

NAME (PLEASE PRINT) PHONE NUMBER Kathy K. Fieldsted 435 722-1325


SIGNATURE N/A

DATE 8/16/2010

August 16, 2010

iPI Well No: 43013503370000

FORM 9STATE OF UTAH






2. NAME OF OPERATOR: 9. API NUMBER:BERRY PETROLEUM COMPANY 43013503370000

3. ADDRESS OF OPERATOR: PHONE NUMBER: 9. FIELD and POOL or WILDCAT:4000 South 4028 West Rt 2 Bo× 7735 , Roosevelt, UT, 84066 303 999-4044 E×t BRUNDAGE CANYON









SDUato




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


DRILLINRLRErD e. WATER SHUTOFF SI TA STATUS EXTENSION APD EXTENSION

8/13/2010WILDCAT WELL DETERMINATION OTHER OTHER:


PLEASE SEE THE ATTACHED DRILLING HISTORY FOR THE FEDERAL 13-5D-64.Accepted by theUtah Division of

Oil, Gas and Mining

FOR RECQgp6,wLY


SIGNATURE DATEN/A

August 16, 2010August 16, 2010

Berry Daily Drilling Report Report Date: 8/6/2010Report #: 1, DFS:

Well Name: FEDERAL 13-5D-64 Depth Progress:API/UWI Surface Legal Location Spud Date Nobce APD State AFE Number Totat AFE Amount43-013-50337 NWSW SECTION 5, Utah C10 032048 381,666

T6S-R4W dailyCosi 0umÙostTO Date

Spud Date Rig Release Date¯ KB-GroundDistance ([1) GrouridElevetton (ftKB) 46,114 46,114

8/8/2010 5:30:00 AM 8/13/2010 14.00 7,238 Daily Mud Cost Mud Additive Cost To Date

Operations at Report Time Operations Next 24 HoursTest BOPE Test BOPE Rig repair Depth Start (itKB) Depth End (ftKB)

OperaiionsSummary 0 0Skid Rig to Federal 13-5D-64 Rig up on new well, Test BOPE Depth Štart(TVD) (ftKB) Depth End (TVD) (ftKB)

RemarksSafety Meeting crews/ Truck Drivers/ Testet ÌargelFormation Target Depth (ftKB)

Weather Temperature ('F) Road Condition Hole Condition Wasatch 5,830Daily Contacts

Last Casing Set Job Contact Mobile

Casmg Desception Set Depth (flKB) OD (in) Comment Bud Pease 281-605-2103Surface 342 8 5/8 Cemented Rigs

Contractor Rig NumberTime Log Frontier 5StartTime EndTime Dur (hrs) Operation Comment13:00 20:00 7.00 Rig Up & Tear Down Rig down Mob rigto Federal 13-5D-64 Mud Pumpa

20 00 23:00 3.00 Repair Rig Rig repair, replace Transmission Bearing, ,Gardnper-De eD

m r n) Stroké Length (in)pull guards, out put shaft Right angle drive 750.0 7.99for DraworkS Liner Size (in) VollStk OR (bbl/stk)

23:00 01:00 2.00 Rig Up & Tear Down Rig up floor/ Plu Kelly01:00 03:00 2.00 NU/ND BOP Nippleup BOPE Pressure (psi) SlowSpd Strokes (spm) Eff (%)

03:00 06:00 3.00 Test BOP Test BOPE No |# 2, Gardner-Denver, PZ-8

Mud Checks Pump Rating (hp) |Roci Diameter (in) stroket.ength(in)

Type Time Depth (ftKB) Density (Ib/gal) Vis (slql) PV Calc (cp) Yield Point (infl100fP) 750.0 7.99Lmer Size (in) Vol/Sik ÓR (bbl/stk)

Gol(10s} (Ibit100 . Gel (10m) (Ibf/10... Gel (30m) (Ibf/10 Fillrate {mLI30min) Filler Cake (132") pH Šol (Pressure (psi) Slow Spd Strokes (spm) Eff (%)

MBT (Ib/bbl) Pe<cent Oil (%) Percent Water (%f Chlorides (mgiL) Calcium(mg/L) KOL(%) ËÍeäsiistin (V) No

CEC for Cuttings¯ WhoÑiÀà Add (bbl) Mud i ost to i ole (bbÏí ud Lo f (S iiÏ( Mud Voi (Res) (bbi) Mud Ÿo](Aci)l6bl)

___ Mud Additive Amounkconsumed Daily cost

Air Data Job SuppliesDiesel Fuel, <Unit Label?>

Patasite ACFM(if/min) 0ÏiÏlpipeACFM (ffimm) CÖBit (16/gii) ECD Parasite (ÏbÏgal) Šup y lie Description Art Label

Corrosion Inhibitor Injected in 24hr Period Ý0iaTRe ed Total Consumed Total Returnedgla injected down Parasile (gal) gis In¡ected n Mud (gal) gis Biocide injected in Mud (gal) 557.0

Diesel Fuel ConsumptionDate Consumed

Drill Strings 8/1212010 557.0

Bil Run IlBit IADCBit Dull

StringLength(ft) StringWI 100 Ib } BH P (ÏL

Drill String Componentsmax

Lobe Bil-Bend ft mingpm OpmJis IIem Desenption OD (in) Len (fi) config Stages rpm/gpm (fi) {gpm) (gpm) SN

Drilling ParametersWeilbore Start (ftKB) Depth End (flKB) CumDepth (ft) DrillTime (hrs) Cum DrillTime . Int ROP (filbr} Flow Rate (gpm)

WOB (1000tbf) RPM (rpm) SPP (ps) Rot HL (10001bf) PU HL (100DibF) SO HL (1000tbf) Drilling Torque OffStm Tq

0 (gini)(iti . Motor AÑil(iptÑ T (Ïn|)( F (liH Änn)( T (bh) Í É(ŠurfÄnn). T (surÏann¶... ËÍ(ÌÍqliriiÏg Ö(àretum) .

Deviation Surveys

A i I e Ôesm EWTie In... Ìnclin...MÚTie in (fË..ÑŠf6 In TVDTiein (ÏL.

0.00 8/8/2010 All Survey 0.00_ 0.00 0.00 0.00 0.00Survey Data

| MD (flKB) | Incl (*) Azm (*) TVD (itKB) NS (It) i EW (ft) VS (11) | DLS('t100ft)

0.00j 0.00 0.00 0.00 0.001 0.00 0.00 0.00

RECEIVED August 16,


Berry Daily Drilling Repod Report Date: 8/7/2010Report #: 2, DFS:

Well Name: FEDERAL 13-5D-64 Depth Progress:APITUWI Surface Legat Location Spud Date Notice APD State AFE Number TotaÍÀËËAmount43-013-50337 NWSW SECTION 5, Utah C10 032048 381,666

T6S-R4W Daily Cost Cum Cosl To Dale

Spud Dale Rig Release Date KB-GroundDistance (ft) Ground Elevation (ftKB) 20,361 66,4758/8/2010 5:30:00 AM 8/13/2010 14.00 7,238 Daily Mud Cost Mud Additive Cost To Date

Operaliens at Report Time Operations Next 24 Hours 450 450rig rgpgj¶ Depth Start (ftKB) Depth End (ftKB)

Operations Summary 0 0Rig repair/Changed out Right angle drive to draworkS Depth Start (TVD) (ftKB) Depth End (TVD) (ftKB)

RemarksSaftey meeting Crews/ Mechanic Target Formalion Targel Depth (ftKB)

Weather Temperature ('F) Road Condition Holo Condition Wasatch 5,830Daily Contacts

Last Casing Set Job Contact Moblle

Casing Desenprion Set Depth (ftKB) OD (in) comment Bud Pease 281-605-2103Surface 342 8 5/8 Cemented Rigs

Contractor Rig NumberTime Log Frontier 5Start Time End Time Dur (hrs) Operation Comment06:00 07:30 1.50 Repair Rig Wait on paits Nipple down,Bad threads Mud Pumpo

on Screw on flange #1, Gardner-Denver, PZ-8Pump Rating (hp) Rod Diameter (in) Slroke Length (in)

07:30 08:30 1.00 Repair Rig Wait on parts Slip/cut driling line 750.0 7.9908:30 10:00 1.50 Repair Rig Wait on parts, w.o. New flange Liner Size (in) Vol/Stk OR (bbl/stk)

10:00 11:00 1.00 Repair Rig wait on parts, Nipple up11:00 13:30 2.50 Repair Rig Test BOPE: Test upper kelly,saftey valve Pressure (psi) Slow Spd Strokes(spm) Eff (%)

pipe, blind rams, choke manifold to 250 # Nolow, 2000 # high. Annular tested to 250 # # 2, Gardner-Denver, PZ-8low, 1500 # high. Surface csg to 1500# for Pump Rating (hp) Rod Diameter (in) Stroke Length (in)

30 min. 750.0 7.99Liner Size (in) Vol/Sik OR (bbilstk)

13:30 06:00 16.50 Repair Rig wait on partsPressure (psi) Slow Spd Strokes (spm) Eff (%}

Mud Checks NoType Time |Depth (ftKB) Density (Ib/gal) IVis (sigt) PV Calc (cp) Yield Pomt (Ibf/100ft'

Mud Additive AmountsGel (10s) (!bfl100.. Gel (10m) (Ibf/10 5el (3ÕmibiliÕ Filtrale (mL/30min) ÑIle? CikeÏ¾') pH Š0ÏÍds(*À) Description Consumed Daily Cost

Engineer 1.0 450.00MBT (Ib/bbl) Percenl Oil (%) Percent Water (%) Chlorides (mg/L) Calcium (mg/L) KCL (%) Electric Stab

(V)¯ Job SuppliesDiesel Fuel, <Unit Label?>

CEC for Cultmgs Whole Mud Add (bbl) Mud Lostto¯Hole

(bbl) Mud Lost (Surf) (bbl) MuciVol Res) (bbi d Voi (Aci) (bbi) Supply Item Description Unit LabelDiesel Fuel

Air Data Iolal Received Tolal Consumed Total Returned557.0

Parasile ACFM (ft=lmin) Drilipipe ACFM (ft=/min) ECD Bit (Ib/gal) ECD Parasile (Ib/gal) Diesel Fuel ConsumptionDate Consumed

Corrosion Inhibitor Injected in 24hr Period' 0/12/2010 557.0

gls Injected down Parasite (gal) gis injected in Mud (gal) gis Biocide injected n Mud (gal)

Drill Strings

Bit Run DrillBil lADC Bit Duff TFA (incl Naz) (in2

Nozzles (/32°) ŠtrÍngLength (ft) String Wt (10001bt) BHA ROP (ft


Lobe Bit-Bend ft. mingpm gpmJts Item Description OD (in) Len (ft) config Stages rpm/gpm (ft) (gpm) (gpm) SN

I IDrliling ParametersWellbore Start (ftKB) Depth End (ftKB) Cum Depth (ft) DrillTime (hrs) Cum DrillTime .. Int ROP (ft/hr) Flow Rate (gpm)

WOB (1000]bf) RPM (rpm) SPP (psi) Rot HL (1005|bi) PU HL (1000Ïbf)SO HL (10001bf) Drilling Torque Off Btm Tq

Q (g inj) (ftal Motor RPM (rpm) T (Inj) ( F) P (BH Ann) ( T (bh) (F) P(Surf Ann) T (surf ann) Q (lig rtrn) (g Q (g relurn)

Deviation SurveysAIISurveyAzim... Date escriplion EWTie ln Inclin D Ïie in (ft . NSTie in . DTie In (ft0.00 8/8/2010 IlSurvey 0.00 0.00 0.00 0.00 0.00

Survey DataMD (ftKB) Incl (*) Azm (*) TVD (flKB) NS (R) EW (ft) | VS (It) DLS (°/100ft)

0.00 0.00 0.00 0.00 0.00 0.00| 0.00 0.00

RECEIVED August 16,


Berry Daily Drilling Report Report Date: 8/8/2010Report #: 3, DFS: 0.0 i

Well Name: FEDERAL 13-5D-64 Depth Progress: 37IAPl/UWI Surface Legal Location Spud Date Notice APD State AFE Number Total AFE Amount43-013-50337 NWSW SECTION 5, Utah C10 032048 381,666

T6S-R4W Daily Cost Cum Cost To Date

Spud Date¯

Rig Release Date KB-GroundDistance (ft) Ground Elevation (ftK0) 20,554 87,0298/8/2010 5:30:00 AM 8/13/2010 14.00 7,238 Daily Mud Cost Mud Additive Cost To Date

Operations al Reporl Time Operations Next 24 Hours 450 900Drilling @382'Spud @05:308/8/2010 Drillahead Depth Start (ftKB) Depth End (ftKB)

Operalions Surimary 345 382Rig repair Change out right angle drive draworkS Depth Sfart )(ftkŠl Depth End (TVD) (ftkB)

Remarks 345 382Saftey meeting crews/ Mechanic Target Formalion Target Deplh (ftKB)

Weather Temperature ("F)JÏÏ¯ad

Condilion Hole Condition Wasatch 5,830oailycontact.

Last Casing Set Job Contact Mobile

Casing Descnption Set Depth (itKB) OD (in) Comment Bud Pease 281-605-2103Surface 342 8 5/8 Cemented Rigs

Contractor Rig NumberTime Log Frontier 5Stait Time End Time Dur (hrs) Operation Comment06:00 16:30 10.50 Repair Rig Waiting on Parts Mud Pumpa

#1, Gardner-Denver, PZ-816:30 00:00 7.50 Repair Rig Put in right angle drive, drive sprocket,driVO Pump Rating (hp} Rod Diameter(m) Siroke Lengih in)

chain, hydromatic tank ,guards, pump 750.0 7.99fluids, fillevrything up. Liner Size (in) VollStk OR (bbilstk)

i 00:00 02:00 2.00 Cut Off Drilling Line Šliplcutdrilling line 6 1/2 0.07802:00 04:00 2.00 Miscellaneous P/U directional tools/scribe in Pressure (psi) Slow Spd Slrokes (spm) (Eff (%)

04:00 05:00 1.00 Miscellaneous P/U rest of BHA iNo |

05:00 05:30 0.50 DrilÍOut Cement/Retainers Drillout Cement/ Guide shoe # 2, Gardner-Denver, PZ-8

05:30 06:00 0.50 DrilÏiiig DriÏ\Ïormation349 to 382' Špud@ 05:30 Pump R7a g (hp) Rod Diameter (in) Stroke I n9gth(in)

8-8-2010Liner Size (in) Vol/Stk OR (bbl/stk)

6 1/2 0.078 iMud ChecksType Time Depth (flKB) Density (Ib/gal) Vis (s/ql) PV Calc (cp) Yield Point (Ibf/100fF)

Pressure (pri) Slow Špd Strokes (spm) Eff (%}

Gel (10s) (Ibf/100 .. Gel (10m) (Ibfl10.. Gel (30m) (Ibfl10... FilÏrale(mL/30min) Filter Cake (/32") pH Solids (%) ¯ Mud Additive AmountsDescription Consumed Daily Cost

MBT (Ib/bbl) Percent Oil (¾) Percent Water (%) Chlorides (mg/L) Calcium (mglL) KCL (%) Electric Stab (V) Engineer 1.0 450.00Job Supplies

CEC for Cullings Whole Mud Add (bbl) Mud Lost to Hole (bbl) Mud Lost (Surf) (bbl) Mud Vol (Res) (bbl) Mud Vol (Act) (bbf) DIOSei Fuel, <Unit Label?>Supply item Description ÙnitLebel

Air Data Diesel FuellotaÏlieceived Total 0onsumed 70tal Relumed

Parasite ACFM (ft2/min) DriÏIpipe ACFM (ft'/min) ECD Bit (Ib/gal) ECD Parasile (Ib/gal) 557.0 I,Diesel Fuel Consumption

ICorrosion Inhibitor Injected in 24hr Period Date Consumed

Igis Injecled down Parasite (gal) gls Injected in Mud (gal) gis Blocide injected in Mud (gal) 8/12/2010 557.0

Drill StringsBHA #1, SteerableBit Run Drill Bit IADC Bil Dull TFA (incl Noz) (in2)

1 7 7/8in, FX 65M, 11291776 ------- 1,18Nozzles (/32") String Length (ft) StringWt (1000Ibf) BHA ROP (ft

16/16/16/16/16/16 5,830.15 41 79.5Drill String Components

maxLobe Bit-Bend ft. mingpm gpm

Jts item Description OD (in) Len (ft) confi9 Stages rpm/gpm (ft) (gpm) (gpm) SN1 Kelly 40.00

149 Drillpipe 4,7f6.0030 HWDP 4 1/2 919.98 9,651

2 DriffCollars 6.15 59.121 NMDC 6.15 31.401 Gap SUB 6 1/2 5.63

DrillCollar 6 1/2 29.861 Motor 6 1/2 28.16

Drilling ParametersWefibore Slart (ftKB) Deplh End (ftKB) Cum Depth (ft) DrillTime (hrs) Cum Drill Time .. Jot ROP (ft/hr) Flow Rate (gpm)Original 345.0 382.0 37.00 0.50 0.50 74.0HoleWOB (1000ibÏjRPM (r im) SPP (psi) Rot HL (1000\bf) PU HL (1000Ïlif)SO HL (100DIbf) ÖrÏIlingTorqüe Off Bim Tq

Q (ginj10ft3/

Motor RPÑI (r m) T (Inj) (°F) P (BH Ann) (.. T (bh) (°F) P(Surf Änn) f(surf ann) . Q (liq rtrnj(g . Q (g return) ,

IRECEIVED August 1 ,


i.

Berry Daily Drilling Report Report Date: 8/8/2010Report #: 3, DFS: 0.0

Well Name: FEDERAL 13-5D-64 Depth Progress: 37Deviation SurveysAll SurveyAzim ale ÓÃsgiption ÊWÌiein i ie In (fl . ÑŠÏieIri Ïn]ÎÏ0.00 8/8/2010 AIISurvey 0.00 0.00 0.00 0.00 0.00

Survey DataMD (ItKB} | Inci (*) Azm (*) TVD (ftKB) NS (ft) EW (til VS (It) [ DLS('/1000)

Ii

RECEIVED August 15,


Berry Daily Drilling Repod Report Date: 8/9/2010Report #: 4, DFS: 1.0

Well Name: FEDERAL 13-5D-64 Depth Progress: 2,288APIlUWI Surface Legal Location Spud Date Nolice APD State AFE Number Total AFE Amount43-013-50337 NWSW SECTION 5. Utah C10 032048 381,666

T6S-R4W baiiyCos( mÓosÏÌ6ÙaÏeSpud Dale Rtg Relenie Date KB-Gr ocÏDistance (1() Ground Efevatión (ftKB) 25.225 112,254

8/8/2010 5:30:00 AM 8/13/2010 14.00 7,238 nallyüù¿ëosi iiAdiffiveCostto DateOperal ons at Report Time Õ¾Iions NexÏ2ÄHäurs 2,797 3,697Drilling @2670' Drillahead Depth Starf(WB} Depth End (ftKB)operaiionssummary 382 2,670Drill77/8 hole Depth Start (TVD) (itKB) Depth End (TVD) (flKB)

Remarks 382 2,641Safety Meeting Crews Target Formation Targel Deplh (ftKB)

WealÑer Ìemperature(F) RoacfCondiÏÍön FÏIo 0onoË1Ïõn Wasatch 5,830

| | Daily ContactsLast Casing Set Job Contact Mob le

Caseg Description Set Depth (ItKB) OD (in) Comment Bud Pease 281-605-2103 |Sulface 342 8 5/8 Cemented Rigs

Conitactor Rig NumberTime Log Frontier 5Stati Time End Time Our(hrs) Operation | Comment06:00 09:30 3.50 Drilling Drilltslide f 382' to654, Mud Pumpa

09:30 10:00 0 50 LubrÏcateRig Rig service p# ,Gaardner-Deno

o met r ni strokeLength (.n)10,00 06:00 20 00 Drilling Drill/ Slide 654 to 2670' 750.0 7.99 i

Uner Size (in) VollStkOR (bbl/stk)Mud Checks 6 1/2 0.078Type Time Depth (ftKB) Density (Ibigal) Vis (s/qt) PV Calc (cp) Yield Point (ibil100fla

ressure ási) Slow Spd Strokes (spm) Eff (%)GDe

( Os) (16tliC0 Gil (10m} bÏI10 ÕeÏ( m ÜÏÕ FiÌtrat ( ÙŠ0miÑ)il(erCá7ke

(/32") pÑ ŠoÍids(Ÿ•Ï No

1LS 1.0 #2, Gardner-Denver, PZ-8

MBT (Ib/bbl) Percent Oil(%) Percent Water (%) Chlorides(mg/L) Calcium (mail.) KCL (%) Electric Stab (V)Pump Rahn0 (hp) Roci Diameter (in) Stroke Lenglh (m)

99.0 500 000 550.000 750.0 7.99

CEC for Cultirgs Whole Mud Add (bbi) Ñudfost to Hole (bbl) Mud Lost (Surf) (b6Ï) ÑIutiVoi Res) (66 ÑÍldŸT(Aci) (bbÏ)̄ Lmer Size (i

1/2VollStkOR (bbilsik)

Precture (pei) |?lo-?pd Strokes (spm) ff (%)Air Data No

Pe<asite ACFM (ffimin) ÕrilipipeACFM (ft=Imin) ECD Bit (ib/gal) ECD Parasile (thigal)- Mud Additive Amounts

Description Consumed Daily CostI I Defnamer 2.0 250.00

Corrosion Inhibitor injected in 24hr Period Fngineer 1.0 450.00gis Inlacted down Parasite (gal) gis In¡ected in Mud (gal) gis Biocide Injected in Mud (gal) Gypsum 120.0 1,260.00

PallEts 2.0 29.00Drill Strings Poly plus 2.0 241.00BHA#1, Steerable Sawdust 50.0 225.00Bil Run Drill Bit lADC Bit Dull TFA (inci Noz) (in') Sh ink wrap 2.0 29.00

1_ 7 7/8in, FX 65M, 11291776 --- 1.18 Tax 1.0 313.00Nozzles (132") SiririgLength (It) 5iängWt (1 ÏfÏ¶ WÔP (fÌ

16/16/16/16/16/16 5,830.15 41 79.5 Job SuppliesDiesel Fuel, <Unit Label?>

Drill String ComponentsRiirrly item nascrirtion uniiniisi

Lobe Hit·Bend fl mingpm 9 Diesel FuelJts item Description OD (in) Len (ft) conft9 Stages rpmigpm (it) (gpm) (gpm) SN Total Received Total Consumed Total Returned

1 Kelly 40.00 | 557.0149 DNÏÏpipe 4,71Š.00 Diesel Fuel Consumption

30 HWDP Ài/ž 519.98 9,051 Date consumed8/12/2010 557.02 DrillCollars 6.15 59.12

1 NMDC Š.15 31.40i Gap SUB 6 1/2 5.031 DrillCollar 6 1/2 29.861 Motor 6 1/2 28.16

Drilling ParametersWelibere Start (itKB) Depth End (flKB) CumDepth (ft) Dnli Time (hrs) Cum DrillTime Int ROP (filhr) Flow Rate (gpm)Original 382.0 2.670.0 2,325.00 23.50 24.00 97.4HoleWOB (1000Ibf) RPM (rpm) SPP (psi) Rot HL (1000Ibf) PU HL (10001bf) SO HL (10001bf) Drilling Torque Off Bim Tq

20 65 80 62Q (g ini) (4 MoiorWWÍ(rpriij i (in(¶( (äl·iÄnn[(Tith) (Ÿj (ŠurfÄrm rfaan rirnj(g g returni

Deviation SurveysAII SurveyAzam.. ale Description EWile in. Inclin MD Tie in (it NSTie in Tie in (it0.00 8/8/2010 All Survey 0.00 0.00 0.00 0.00 0.00

Survey DataMD (BKB) [ Incl f) Azm (*) TVD (ftKB) NS (R) EW (6) VS (A) DLS ("I100ft)

421.00 1.85 158.48 420.93 -6.32 2.49 5,00 0.44481.00 3.25 159.71 480.87 -8.82 3.44 6.99 2.33543.00 5.05 158.98 542.70 -13.01 5.03 10.33 2.90

RECEIVED August 16,



Well Name: FEDERAL 13-5D-64 Depth Progress: 2,288|Survey Data| MD (f(KB) Inci (*) Azm (') TVD (ftKB) NS (fi) EW (ft) ' VS (It) DLS (°1100!!)

604.00 6.46 163.93 603.39 -18.82 6.94 15.05 2.45665.00 7.16 171.49 663.96 -25.88 8.45 21.09 1.86726,00 7.91 178.52 724.44 -33.83 9.12 28.27 1.95

I 819.00 9.05 192.58 816.43 -47.37 7.69 41.41 2.54911.00 9.84 197.42 907.18 -61.93 3.77 56.41 1.22

1.003.00 10.55 201.20 997.73 -77.29 -1.63 72.67 1.061.098.00 10.90 200.23 1,091.07 -93.82 -7.88 90.35 0.411,193.00 10.50 207.09 1,184.42 -109.96 -14.93 107.94 1.401,288.00 10.02 205.68 1,277.90 -125.11 -22.46 124.79 0.571,383.00 9.89 207.79 1,371.47 -139.78 -29.84 141.13 0.411,479,00 9.58 207.97 1,466.09 -154.13 -37.43 157.26 0.321,574.00 9.05 204.71 1.559.84 -167.90 -44.26 172.56 0.791,669.00 10.50 206.91 1,653.46 -182.40 -51.30 188.63 1.581,764.00 10.24 204.10 1,746.91 -197.83 -58.67 205.68 0.601,859.00 9.05 201.90 1,840.56 -212.47 -64.91 221.58 1.311,954.00 9.80 203.13 1,934.28 -226.84 -70.87 237.13 0.822,049.00 9.45 207.70 2,027.94 -241.18 -77.67 252.96 0.882,144.00 9.71 204.80 2,121.62 -255.36 -84.66 268.70 0.582.239.00 8.53 204.54 2,215.42 -269.04 -90.94 283.73 1.242,335.00 9.67 206.03 2,310.21 -282.76 -97.44 298.87 1.212,430.00 8.75 201.55 2,403.98 -296.65 -103.59 314.05 1.232.525.00 9.89 206.38 2,497.73 -310.68 -109.87 329.40 1.452,620.00 8.92 207.26 2,591.45 -324.54 -116.87 344.85 1.03

I

RECEIVED August 1 ,



Well Name: FEDERAL 13-5D-64 Depth Progress: 1,644APf/UWI Surface Legaf Location Spud Date Notice APD Stale AFE Number Total AFE Amount43-013-50337 NWSW SECTION 5, Utah C10 032048 381,666

T6S-R4W DaÏlyCost Cum Cost To Dale

Spud Dale Rig Release Date KB-Ground Distance (ft) Ground Elevation (ftKB) 37,950 150,2048/8/2010 5:30:00 AM 8/13/2010 14.00 7,238 Daily Mud Cost Mud Additive Cosl To Date

Operations at Report Time Operalions Next 24 Hours 3,364 7,061Drilling 4314' Drillahead to TD Depth Start (ftKB) Depth End (ftKB)

Operations Summary 2,670 4,314Stuck pipelsur. Worked free/3 sx sapp sweep/ drilled 5hrs. Short tripthrew tight spot/ drilled ahead Deplh Start (TVD) (ftKB) Depth End (WD) (ftKB)

Remarks 2,641 4,264Safety Meeting Targel Formation Target Depth (ftKB)

Weather Temperalure (°F) Road Condition Hole Condition Wasatch 5,830

\_ | Daily ContactsLast Casing Set Job Contact Moblie

Casing Descophen Set Depth (ftKB) OD (m) Comment Bud Pease 281-605-2103Surface 342 8 5/8 Cemented Rigs

Contractor Rig NumberTime Lo9 Frontier 5Stait Time End Time Dur (hrs) Operation Comment06:00 09:00 3.00 Drilling Drillf 2670 to 2955, Mud Pumpo

09:00 10:30 f Š0Miscellaneous Work stuck pipe, purnp sweeps, pump 00pp p#1 Gaardner-DenoD met r(n) Stroke Length(m)

sweep (3 sx over sucktion) freed up work 750,0 7.99pipe sweep hole Liner size (in) vollstkoR tobitstki

10:30 15:30 5.00 DrÍÏIÏng Drillf 2955 to 3335'15:30 17:00 1.50 ÍrÌps ŠÏiorttri oW90• Pressure (psij Slow Spd Strokes (spm) Eff (%)

17:00 18:00 1.00 Drilling Drilling 77/8 hole f 3335 to4314 1,050.0 Yes 65 95# 2, Gardner-Denver, PZ-8

Mud Checks Pump Rating (hp) Rod Diameter (in) Stroke Length (in)

Type Time Depth (ftKB) Density (Ib/gal) Vis (s/qt) PV Calc (cp) Yield Point (Ibf/100ft2) 750.0 7.99, DAP 06:00 2,830.0 8.40 27 Lmer Size (in) Vol/Stk OR (bb1/stk)

Gei (10s) (ibf/100 . Gel (10m) (fbf/10 . Get (30m) (Ibf/10.. Fîltrate (mL/30min) Filter Cake (/32") pH Solids (%)7.0 1.0 Pressure (psi) Slow Spd Strokes (spm) (Eff (%)

i MBT (Ibibbi) Percent 0TI"À) Percent Water (%) Chlorides (mg/L) Calcium (mg/L) KCL (%) Electiic Stab (V) 1,050.0 Yes 64 | 9599.0 500.000 450.000 Mud Additive Amounts

CEC for Cuttings Whole Mud Add (bbl) Mud Lost to Hole (bbl) Mud Lost (Surf) (bbl) Mud Vol (Res) (bbl) Med Vol (Act) (bbl) Description Consumed Daily Cost

,500.0 i | Dap 32.0 912.00

Air Data Defoamer 2.0 250.00Engineer 1.0 450.00

Parasite ACFM (ft*/min) Drillpipe ACFM (ft*/min) ECD Bit (Ib/gal) ECD Parasite (Ib/gal) Gypsum 120.0 1,260.00Pellets 2.0 29.00

Corrosion Inhibitor Injected in 24hr Period Poly pliis 1.0 120.50gis injected down Parasite (gal) gis Injecled in Mud (gal) gis Biocide Injected in Mud (gal) Shink wrap 2.0 29.00

, Tax 1.0 313.00Drill Strings Job SuppliesBHA #1, Steerable Diesel Fuel, <Unit Label?>

ft Run Onff Bit IADC Bil Duli TFA (inci Noz) (in2) Supply ltem Description Unit Label1 7 7/8in, FX 65M, 11291776 --- 1.18 Diesel Fuel

ozzles (/32") String Length (ft) String Wl (1000Ibf) BHA ROP (ft Total Received Total Consumed Tolal Returned16/16/16/16/16/16 5,830.15 41 79.5 557.0 i

Drill String Components Diesel Fuel Consumptionmax Date Consumed

Lobe Bit-Bendft. mingpm gpm 8/12/2010 557.0Jts item Description OD (in) Len (ft) confi9 Stages rpm/gpm (ft) (gpm) (gpm) SN

1 Kelly 40.00149 Drillpipe 4,716.0030 HWDP 4 1/2 919.98 9,651

2 DrillCollars 6.15 59.121 NMDC 6.15 31.401 Gap SUB 6 1/2 5.631 DrillCollar 6 1/2 29.861 Motor 6 1/2 28.16

Drilling ParametersWellboro Start (ftKB) Depth End (ftKB) Cum Depth (ft) Dri!!Time (hrs) Cum Onil Tima Int ROP (filhr) Flow Rate (gpm)Original 2,670.0 4,314.0 3,969.00 21.00 45.00 78.3HoleWOB Ï1000Ibt) RPM (rpm) SPP (psi) Rot HL (1000\bf) PU HL (10001bf) SO HL(1000lbf) Drilling Torque Off Btm Tq

22 85 110 80O (g inj) (ft / WÍotorRPM (rpm) T (Inj) ('F) P (BH Ann) ( T (bh) (°F) P(SuriAn ) sTann) ... Q (lig rtrn) (g return)

Deviation SurveysAllmSU

a e Description EV\TTiein .. nelin MD Tie In (ft-.. NSTie In DTie In (fl,0.00 8/8/2010 All Survey 0.00 0.00 0.00 0 0.00

RECEIVED August 16,



Well Name: FEDERAL 13-5D-64 Depth Progress: 1,644

2,715.00 9.23 203.13 2,685.26 -338.09 -123.24 359.79 0.762,810.00 9.58 205.59 2,778.98 -352.23 -129.64 375.28 0.562,905.00 9.89 203.83 2,872.62 -366.82 -136.36 391.31 0.453,001.00 9.76 201.46 2,967.21 -381.94

-142.66 407.68 0.443,095.00 10.20 205.42 3,059.79 -396.87

-149.15 423.95 0.873,190.00 9.84 204.80 3,153.34 -411.84 -156.17 440.44 0.403,285.00 9.76 204.45 3,246.95 -426.53 -162.90 456.58 0.103,475.00 9.49 200.93 3,434.28 -455.83

-175.17 488.32 0.343,570.00 8.92 200.85 3,528.06 -470.02

-180.58 503.52 0,603,665.00 8.57 200.58 3,621.95 -483.53 -185.69 517.96 0.373,758.00 8.57 197.59 3,713.91 -496.62 -190.22 531.81 0.483,853.00 7.82 197.95 3,807.94 -509.52 -194.36 545.32 0.793,949.00 8.35 202.60 3,902.99 -522.17 -199.05 558.81 0.884,044.00 8.61 200.85 3,996.95 -535.18 -204.23 572.82 0.39 I

4,137.00 8.31 200.85 4,088.94 -547.97 -209.10 586.50 0.324.232.00 8.26 197.24 4,182.95 -560.90 -213.56 600.18 0.55

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RECEIVED August 16,



Well Name: FEDERAL 13-5D-64 Depth Progress: 1,519APllUWI Surface Legal Location Spud Date Nolice APD State AFE Number Total AFE Amount43-013-50337 NWSW SECTION 5, Utah C10 032048 381,666

T6S-R4W Daily Cost CtÏmCost To Dale

Spud Date Rig Release Date KB-Ground Dislance (ft) Ground Elevation (ftKB) 51,095 201.2998/8/2010 5:30:00 AM 8/13/2010 14.00 7,238 Daily Mud Cost Mud Additive Cost To Date

Operations at Report Time Operations Next 24 Hours 5,646 12,707Drilling @5833' Drillto TD, Wiper trip, Lay down Depth Start (ftKB) Depth End (ftKB)

Operations Summary 4,314 5,833Drilled 77/8 hole Depth Slart (TVD) (ftKB) Depth End (TVD) (ftKB)

Remarks 4,264 5,776Saftey meeting/ crews Target Formation Target Depth (ftKB)

Weather Ïemperature ( F) ÑoacÏCondition Hole Condition Wasatch 5,830Daily Contacts

Last Casing Set Job Contact i Mobile

Casmg Descnption Set Depth (ftKB) OD (in) Comment Bud Pease |281-605-2103Surface 342 8 5/8 Cemented Rigs

Contractor Rig NumberTime Log Frontier 5Start Time End Time Dur (hrs) Operation Comment06:00 12:00 6.00 Drilling Drill/Slide 77/8 hole F 4314' to 4693 Mud Pumpo

12:00 12:30 0.50 Lubricate Nig Rig service ç# 1, Gaarcinper-DORnoD mtr (n) Stroke Length (in)

12:30 06:00 17.50 Drilling Drill77/8 hole 4693 to 5833' 750.0 7.99Liner Size (in) VollStk OR (bbl/stk)

Mud ChecksType Time Depth (ftKB) Density (Ib/gal) Vis (s/qt) PV Calc (cp) Yield Point (Ibf/100ft2

ure (psi) Slow Spd Strokes (spm) (Eff (%)DAP 06:00 4,420.0 27 No |Gel (10s) (Ibf/100. Gel (10m) (lbf/10 Gei (30m) (Ibf/10 Filtrale (mLl30min) Filter Cake (132") pH Solids ( # 2, Gardner-Denver, PZ-8

Pump Rating (hp) Rod Diameter (in) Stroke Length (in)MBT (Ib/bbl) Percenl Oil (%) Percent Water (%) Chlorides (mg/L) Calcium(mg/L) KOL (%) Electric Stab (V) 750.0 7.9999.0 500.000

Liner Size (in) VollStkOR (bbilstk)CEC for Cuttings Whole Mud Add (bbl) Mud Lost to Hole (bbl) Mud Lost (Surf) (bbl) Mud Voi (Res) (bbl) M IciVoÌ(Act) (bbl)

Prenure (pei) Islow spd Strokes (spm) Eri (%)|Air Data No

Parasite ACFM (fiiÍäln) 0rilipipeAÒFÑI(ff/min) EdÖBit (Ib/gal) ËCÕëarasile(Ibigal Mud Additive AmountSConsumed Daily Cost

Dap 22.0 627.00Corrosion Inhibitor injected in 24hr Period Defnamer 8.0 1,000.00gis Injected down Parasite (gal) fgls injected in Mud (gal) gis Biocide injecled in Mud (gal) Engineer 1.0 450.00

Eiber seal 5.0 82.501Drill Strings Gypsum 220.0 2,310.00BHA #1,Steerable Nut Shell 15.0 247.50Bit Run Dn1lBit IADC Bil Dull TFA (incl Noz) (in2) Pallets 8.0 116.00

1 7 7/8in, FX 65M, 11291776 -- 1.18 Sapp 3.0 271.50Nozzles (/32") String Length (ft) String Wt (1000Ibf) HA ROP (It Sawdust 25.0 112.5016/16/16/16/16/16 5,830.15 41 79.5

Shink wrap 8.0 116.00Drill String Components Tax 1.0 313.00max

Lobe Blt-Bendf! mingpm gpm Job SuppliesJts Item Description OD (in) Len (ft) config Stages rpm/gpm (ft) (gpm) (gpm) SN Diesel Fuel, el Init I shel?>

1 Kelly 40.00 Supply Ilem Description Unil Label149 DrillpÌpe 4,716.00 Diesel Fuel30 HWDP 4 1/2 919.98 9,651 Total Received Total Consumed Total Retumed

2 DrillCollars 6.15 59.12 557.01 NMDC 6.15 31.40 Diesel Fuel Consumption1 Gap SUB 6 1/2 5.63 Date consumed

- 8/12/2010 557.01 DrillCollar 6 1/2 29.861 Motor 6 1/2 28.16

Drilling ParametersWellbore Start (ftKB) Deplh End (ftKB) Cum Depth (ft) DrillTime (hrs) Cum DrillTime . Int ROP (ft/hr) Flow Rale (gpm)Original 4,314.0 5,833.0 5,488.00 23.50 68.50 64.6HoleWOB (1000lbf) RPM (rpm) SPP (psi) Rot HL (1000Ibf) PU HL (1000Ibf) SO HL (1000|bf) Dr ihng Torque Off Btm Tq

24 115 140 105Q (g inj) (fPI Molor RPM (rpm) T (In)) ('F) P (BH Ann) { T (bh) (°F) ud Ann) T (surf ann) Q (liq rtrÑ(g Q (g return) .

Deviation Surveys.AII SurveyAzim... Date Descriplion EWTie In inclin D Tie In (ft . NSTie In , FVDTie In (ft0.00 8/8/2010 All Survey 0.00 0.00 0.00 0.00 0.00

Survey DataMD (ftKB) Inci (*) | Azm (*) | TVD (ftKB) NS (ft) EW (ft) [ VS (It) OLS (°/100ft)

4,327.001 7.51 197.24 4,277.05 -573.35 -217.43 613.18 0.794,421.001 7.82 202.16 4,370.21 -585.14 -221.66 625.70 0.774,516.001 7.47 204.80 4,464.36 -596.73 -226.69 638.33 0.52

RECEIVED August 16,



Well Name: FEDERAL 13-5D-64 Depth Progress: 1,519Survey Data

MD (ftKB) Inci (') Azm (*) TVD (flKB) NS (ft) EW (ft) | VS (ft) OLS ('l100ft}4,611.00 7.16 206.21 4,558.59 -607.65 -231.89 650.39 0.384,706.00 6.99 208.58 4,652.87 -618.04 -237.27 662.02 0.364,801.00 6.46 206.65 4,747.21 -627.89 -242.44| 673.07 0.614,896.00 6.02 209.11 4,841.65 -637.02 -247.26 683.32 0.544,991.00 5.19 206.91 4,936.20 -645.20 -251.62 692.53 0.905,086.00 5.01 198.03 5,030.82 -652.98 -254.85 700.95 0.855,181.00 4.57 200.90 5,125.49 -660.46

-257.49 708.87 0.535,277.00 4.48 198.65 5,221.19 -667.58 -260.05 716.44 0.215,371.00 4.35 197.16 5,314.91 -674.47 -262.28 723.67 0.185,466.00 4.13 199.79 5,409.65 -681.13 -264.50 730.68 0.315,561.00 4.39 198.12 5,504.39 -687.80

-266.79| 737.73 0.305,656.00 4.13 198.30 5,599.13 -694.51 -268.99 744.78 0.275,751.00 4.35 197.68 5,693.87 -701.19

-271.16,i 751.79 0.24

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IRECEIVED August 16,



Well Name: FEDERAL 13-5D-64 Depth Progress: 156APl/UWI Surface Legal Location Spud Dale Notice APD State AFE Number Total AFE Amount\43-013-50337 NWSW SECTION 5, Utah C10 032048 381,666

T6S-R4W Daily cost cumCost To Date

Spud Date Rig Release Date KB-Ground Distance (ft) GroundEÍeialion(ÏtRBy 44,797 246,0968/8/2010 5:30:00 AM 8/13/2010 14.00 7,238 Daily Mud Cost Mud Addilive Cost To Dale

Operations at Report Time Operalions Next 24 Hours 6,741 19,448Running loggs Log well, run casing, cement, nipple down, set slips. Depth Start (itKB) Depth End (ftKB)

Release rig for move. 5,833 5,9890perationsSummary Depth Starl (TV0) (ftKB) Depth End (TVD) (ftKB)

TD well @5989', Circ and sweep hole, Trip out of hole ( tight spot @2835', Lay down directional tools, Trip _ _ 5.776in hole with slick assy. Rig up lay down truck,Circ and cond hole for tripout, Lay down drill pipe, Rig down Target Formation Target Depth (ftKB)

lay down truck. Wasatch 5,830

Remarks Daily ÛOnÍSCÍS

Safety meeting - working with 3rd party companies Job Contact Mobile

Weather Temperature (°F) Road Condllion Hole Condition--- R. Boyd Cottam 281-605-2103

Cloudy 61.0 Dusty Good RIqsColitiactoi Rig Number

(Last Casing SetiCasing Description Set Depth (ftKB) OD (in) Comment Frontier 5Surface 342 8 5/8 Cemented Mud Pumps

#1, Gardner-Denver, PZ-8Time Log Pump Rating (hp) od Diameter (in) Stroke Length (in)Start Time End Time Dur (hrs) Operation Comment 750.0 7.9906:00 08:30 2.50 Drilling Drill6866' to 5085' Wasatch came in @ Unersize (in) vol/Stk ÓR (bbl/stk)

5885'. WOB 24. RPM 65, GPM 42508:30 09:30 1.00 Condition Mud & CircuÏate Cind cond hole for trip Ran iwosweeps. Pressure (psi) Slow Spd Strokes (spm) Eff (%)

09:30 13:30 4.00 Trips Trip out of hole. Work tight spot @2835'. INo

13:30 14:30 1.00 Trips Lay down directional tools. #2, Gardner-Denver, PZ-8Pump Rating (hp) Rod Diameter (in) Stroke Length (in)14:30 20:00 5.50 Trips Pick up bit, bit sub, and tripin hole. Break 750.0 7,99circ @3100'. Trip in hole, wash and ream 3 Liner Size (in) Vol/Stk OR (bbl/stk)jts to btm.

20:00 22:00 2.00 Condition Mud & Circulate Circ and cond hole for trip. Rig up lay down Pressure (psi) Slow Spd Strokes (spm) Eff (%)truck. No

22:00 03:00 5.00 LD Drillpipe Lay down drill pipe. Mud Additive Amounts03:00 06:00 3.00 ŸVireLine Logs Rig up Bal er AtÏasand run triplecombo log Description Consumed Daily Cost

Daµ 25.0 712.50Mud Checks Defoamer 4.0 500.00Type Time Depth (ftKB) Density (Ib/gal) Vis (s/qt) PV Calc (cp) Yield Point (ibf/100ftl Engineer 1.0 450.00Dap 06:00 5,989.0 8.40 27 1.0 1.000 Gypsum 200.0 2,100.00Gel (10s) (Ibfl100 . Get (10m) (Ibfl10 Gol(30m) (Ibf/10 Fillrate (mL/30min) Filter Cake (/32") pH Solids(%) Pallets 5.0 72.507.0 1.0MBT (Ib/bbl) Percent /o) Percent Water (%) Chlorides (mg/L) Calcium

(ÑigÏL)¯KCL (%) Efectric Stab (V) Poly plus 1.0 120.50

99.0 500.000 400.000 Sawdust 50.0 225,00CEC for Cuttings Whole Mud Add (bbl) Mud Lost to Hole (blil) ÑÍudLost (Surf) (bbÍ) Mud Vol (Res) (bbl) Mud Voi (Act) (bbl) Sea Mud 45.0 675.00

337 0 Shink wrap 5.0 72.50Air Data Tax 1.0 313.00

Trucking 1.0 1,500.00Parasile ACFM (ft=lmin) Drillpipe ACFM (fPlmin) ECD Bit (Ib/gaÏ) ECD ParasÍte(Ib/gal)

JOb SuppliesDiccol Fuol, /Unit Label?

Corrosion Inhlbitor Injected in 24hr Period SupplyItem Descriplion Unit Latelgls injecled down Parasile (gal) gis Injected in Mud (gal) gis Biocide Injected in Mud (gal) DieSel Fuel

Total Received Total Consumed Tolal Returned557.0

Drill Strings.Disaal Fuel QuilauliiplionBHA #1, Steerable _ _ _ Date Consumed

Bil Run Dail Bit lADC Bil Duil TFA (inci Noz) (ins 8/12/2010 557.01 7 7/8in, FX 65M, 11291776 ------- 1.18Nozzles (I32 ) String Lerigth Ïfi)SÏnngWt((000161)BHA R0P (ft

16/16/16/16/16/16 5,830.15 41 79.5Drill String Components

maxLobe Bit-Bend ft min gpm gpm

Jts Item Description OD (in) Len (ft) config Stages rpm/gpm (ft) (gpm) (gpm) SN1 Kelly 40.00

149 Drill pipe 4.716.0030 HWDP 4 1/2 919.98 9,651

2 DrillCollars 6.15 59.121 NMDC 6.15 31.401 Gap SUB 6 1/2 5.631 DrillCollar 6 1/2 29.861 Motor 6 1/2 28.16

RECEIVED August 15,



Well Name: FEDERAL 13-5D-64 Depth Progress: 156Drilling ParametersWelibere Start (ftKB) Depth End (itKB) Cum Depth (ft) DriliTime (hrs) CumOnll Tim In: ROP (filbr) Flow Rate (gpm)Original 5.833.0 5,989.0 5.644.00 2.50 71.00 62.4 425HoleWOS (1000Ibt) RPÑÏ(rpm) SPP (psi) Rot HL (1000Itif) ÙHL (100016¶) SO HL (1000lof) DrÏIling Torque Óff$tmTq

24 65 1,450.0 115 140 105O (gÏni)(ft Ñ!oÎorRÈM (rpm) (ÌnÔ(T) Ë(BH Ann) LT (bh) (*F) P(Surf Ann) . T(surf ann) Õ Qigitiii)(g return)

Deviation SurveysAll SurveyAzim Date D ion EWTie in inclin ]ÑiD Tie in (ft NSTie In TVDTie in (ft0.00 8/8/2010 AIISurvey 0.00 0.00 | 0.00 | 0.00 0.00

Survey Data1 MD (flKB) loci (*) Azm (') TVD (ftKB) NS (it) EW (ft) | VS (ft) DLS('l100ft)

5,845.00 4.39 203.04 5,787.59 -707.89 -273.65 758.95 0.445,940.00 4.09 199.88 5,882.33 -714.43 -276.23 765.97 0.40

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RECEIVED August 16,


.Berry Daily Drilling Report Report Date: 8/13/2010

Report #: 8, DFS: 4.5Well Name: FEDERAL 13-5D-64 Depth Progress: 0

APl/UWi Surface Legal Location Spud Date Notice APO Slate AFE Number Total AFE Amount43-013-50337 NWSW SECTION 5, Utah C10 032048 381,666

T6S-R4W Daily cost cumCost To Date

Spud Date Rig Release Date KB-Ground Distance (ff) GroundElevation (flKB) 55.641 301,7378/8/2010 5:30:00 AM 8/13/2010 14.00 7.238 Daily Mud Cosl Mud Additive Cost To Date

OpeÍaiÍonsat Report Time Operalions Next 24 Hours 19,448Rigging down for move Move rig onto the 14-5D-64 Depth Starl(ftKB) Depth End (ftKB)

operationsSummary 5,989 5,989Run Logs, Ran casing, cement, Nipple down, set slips w/ 80,000, Rigging down for move. Rig released @ Deplh Start (TVD) (ftKB) Depth End (TVD) (flKB)

midnight.Remarks Target Formation Target Depth (ftKB)

Safety meeting - running casing. Wasatch 5,830Wealher Temperalure ( F) Road Condition Hole Condition DailyContactsClear | 50.0 Dusty Good Job Contact Moblie

Last Casing Set R. Boyd Cottam 281-605-2103

Casing Descnption Set Depth (ftKB) OD (in) Comment Rig5Production 5,985 5 1/2 Cemented Contraclor Rig Number

Froritiel 5Time Lo9 Mud PumpsStart Time End Time Dur (hrs) Operation Comment06:00 11:00 5.00 Wire Line Logs Ran induction, Density. Neutron, Gamma j#1, Gaardnper-DORno

D m i r (n) Stroke Length (in)Ray logs 750.0 7.99

11:00 16:00 5.00 Run Casing & Cement Run production casing 139 jtS Liner Size (in) VolìStk OR (bblÍstk)16:00 18:30 2.50 Condition Mud & Circulate Circ and cond for cement18:30 19:30 1.00 Run Casing & Cement Öement:Lead 120 bbis, 11 #, 3.82 Yield, Pressure sij Slow Spa Šlrokes(spm) (Eti(%)

Tail 150 bbis, 13.1 #, Yield 1.7, 140.5 bbls No |displacement # 2. Gardner-Denver, PZ-8

- Pump Rating (hp) Rod Diameter (in) Stroke Length (in)19:30 20:30 1.00 NU/ND BOP Nipple down and set slips 80,000 750.0 7.9920:30 00:00 3.50 Miscellaneous Clean Mud tanks Liner Size (in) Vol/Stk OR (bbl/stk)00:00 06:00 6.00 Rig Up &Tear Down Rigging down for move

Pressure (psi) Sfow Spd Strokes (spm) Eff (%)Mud Checks NoType Time Depth (ftKB) Density (Ib/gal) Vis (s/ql) PV Calc (cp) ]Yleid Point (ibf/100ft2

Mud Additive Amountsdet (10sÏÏ6ÌÑ00. Get (10m) (Ibil10... Gel (30m) (Ibfl10 . 'Filtrate (mL/3Dmin) Filter Cake (132") pH Solids (%)

- Description Consumed Daily Cost

MBT (Ib/bbl) Percent Oil (%) Percent Water (%) Chlorides (mg/L) Calcium (mg/L) KOL(%) Elecine Slab (V) Job SuppliesDiesel Fuel, <Unit Label?>

CEC for Cuttings |WhõÍeMud Aid (bbi) Mud Lost to Hole (bbi) Mud Lost (Surf) (bbl) Vol (Res) (bbÍ) Mud Vol (Act) (bbl) Sup y Item Des ripÏion Unii LaGeÏDiesel Fuel

Air Data'

iotai seceivec Totai consumed Total Returned- 557.0 |

Parasite ACFM (ft /min) Drilipipe ACFM (fl2/min) ECD Bit (Ib/gal) ECD Parasite (Ib/gal) Diesel Fuel ConsumptionDate Consumed

Corrosion Inhibitor Injected in 24hr Period 0/12/2010 557.0gis injected down Parasite (gal) gis injected in Mud (gal) gis Biocide injected in Mud (gal)

Drill Strings

Bil Run DrillBit lADC Bit Dull TFA (inci Noz) (in2)

Nozzles (137) String Length (fi) S1ring Wt (10001bf) BHA RÖP ÜÏ


Lobe Bit-Bend fL mingpm gpmJts Item Description OD (in) Len (ft) confi9 Stages rpm/gpm (ft) (gpm) (gpm) SN

,l I Ill i iDrilling ParametersWellbore Start (ftKB) Depth End (ftKB) Cum Depth (ft) Drill Time (hrs) Cum DrillTime Int ROP (ft/hr) Flow Rate (gpm)

WOB (1000Ibf) RPM (rpm) SPP (psi) Rol HL (1000160 PÙHL (î000\bf) S0 HL (10001bf) ÕrillingTorque ÖffBtm Tq

Q (g inj) (ft / Motor RPM (rpm) Ï (Inj) ( F) Ï3(BH Ann) (.. T (bh) (°F) Ann) T (surf ann) 0 (lig rtrn) (g Q (g return)

Deviation SurveysAll SurveyAzim... Date Description EWTie In Inclin... MD Tie In (fl . [NSTie in . TVDTie In (ft0.00 8/8/2010 |All Survey 0.00 0.00 0.00 | 0.00 0.00

Survey DataMD (flKB) Inc1(*) Azm (*) TVD (ftKB) NS (11) EW (ft) | VS (ft) | DLS (°/1000)

RECEIVED August 16,

API Well No: 43013503370000



FORM 9








9. API NUMBER: 43013503370000




COUNTY: DUCHESNE

STATE: UTAH

11.




9/7/2010













WILDCAT WELL DETERMINATION OTHER OTHER: COMPLETION PROCEDURE


PLEASE SEE THE ATTACHED COMPLETION PROCEDURE FOR THE FEDERAL13-5D-64.



SIGNATURE N/A

DATE 9/1/2010

September 01, 2010

September 09, 2010

iPI Well No: 43013503370000

FORM 9STATE OF UTAH

DEPARTMENT OF NATURAL RESOURCESDIVISION OF OIL, GAS, AND MINING TEUAs8ED4ESIGNATION AND SERIAL NUMBER:













NOTICE OF INTENTApproximate date work will start: CHANGE TO PREVIOUS PLANS CHANGE TUBING CHANGE WELL NAME

9/7/2010CHANGE WELL STATUS COMMINGLE PRODUCING FORMATIONS CONVERT WELL TYPE

SUBSEQUENT REPORT DEEPEN FRACTURE TREAT NEW CONSTRUCTIONDate of Work Completion:



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


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

WILDCAT WELL DETERMINATION OTHER OTHER: COMPLETION PROCE


PLEASE SEE THE ATTACHED COMPLETION PROCEDURE FOR THE FEDERAL13-5D-64. Accepted by the

Utah Division ofOil, Gas and Mining

Date: S me¯09



RECEIVED September 01,

September 01, 2010September 01, 2010

Berry Petroleum Company1999 Broadway, Suite 3700

Denver, CO 80202

Main (303) 999-4400Fax (303) 999-4401

www.bry.com

Date: August 31, 2010

Well Name: Federal 13-5D-64APl#: 43-013-50337Location: Sec 5-T6S-R4WCounty, State: Duchesne County, Utah

SHL: 654 FSL& 665 FWLBHL:Elevations: 7254 ft KB;7240 ft GLRTD: 5989 ftPBTD: 5940 ftSurf Csg: 8 5/8" 24# @342 ft; cmt w/ ?? sksProd Csg: 5 1/2" 15.5# @ 5985 ft; cmt w/ 220 sks lead & 320 sks tailMkr Jnts: ? ftTbg:SN:TOC:Existing Perforations:

Green River Frac Procedure:

1. MIRU wireline unit. Perforate Uteland Buttes f/ 5651ft to5805 ft w/ 2 spf, 120 deg phase, 19 gm charges, 0.36"EHD, See attached table. RD wireline off wellhead.

2. RUfrac euip. Frac Stage 1down 5 ½" csg per design (see attached table). Record ISIP, RD frac equip off wellhead.

3. RU wireline unit. 5et CBP @ ~5620 ft. Perforate Lower Castle Peak f/ 5507 to 5540 ft & Castle Peak f/ 5322 to5540 ft w/ 2 spf, 120 deg phase, 19 gm charges, 0.36" EHD. See attached table. RDwireline off wellhead.

4. RU frac euip. Frac Stage 2 down 5 ½" esg per design (see attached table). Record ISIP, RD frac equip off wellhead.5. RU wireline unit, Set CBP @ ~5290 ft. Perforate 3 Point f/4690 to 4756 ft w/ 2 spf, 120 deg phase, 19 gm charges,

0.36" EHD. See attached table. RD wireline off wellhead.6. RUfrac euip. Frac Stage 3 down 5 ½" csg per design (see attached table). Record IslP. RD frac equip off wellhead,7. RU wireline unit. Set CBP@ ~4660 ft. Perforate Douglas Creek f/ 4337 to 4588 ft w/ 2 spf, 120 deg phase, 19 gm

charges, 0.36" EHD. See attached table. RD wireline off wellhead.8. RU frac euip. Frac Stage 4 down 5 ½" esg per design (see attached table). Record ISIP. RD frac equip off wellhead.9. RUwireline unit. Set killCBP@ ~4300 ft.10. RDMO wireline unit. RDMO frac equip. NU BOPE.11. MIRU service unit. RU drlg equip and drill out CBP's and circulate clean to PBTD ft. Record fluid rates and

pressures while cleaning out well. RD drlg equip.12. RIHw/ tail joint, SN & tbg anchor on 2 7/8" tbg. Set EOT@~5830 ft. ND BOPE.13. RIHw/ pump & rods. Seat pump, space out. Fill tbg & pressure test to 500 psi.14. RDMOservice unit.15. Start well pumping.



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FLUIDSPECIFICATIONSAND REQUIREMENTS

Tank Requirements: 6 - 500 bbl tanks Tank Bottoms: 30 bbl/tank

Fluid1: 25 lb Gelled Water 109,687 GallonsAdditives:

257 2% CL-57 LiquidKCIReplacement2001 25 ppt MAV-3 Guar Gel

106 2 gpt NE-6 Non-Emulsifier

141 0.05 qpt BREAKER-503L Liquid Enzyme Breaker592 2.5 gpt MAVLINKBW Borate X-Linker (Wlnterlzed)

142 ppt GB-3 Oxidative Breaker

Fluid Required (Not Including Tank Bottoms): 109,687 Gallons2,612 Bbis

Tank Bottoms: 180 BbisTotal Fluid Requred: 2,792 Bbis

ACID REQUIREMENTSAcid Requlroments:

Acid 1: 15 % HCL 1,000 GallonsAdditives:

610 5 ppt IC-100 Iron Control303 4 gpt MAVHIB-3 Acid Inhibitor(Moderate Temp)

PROPPANT REQUIREMENTS

SAND 16/30 Texas Gold 196,000 lbsTotal: 196,000 lbs

BERRY Federal #13-5D-64 083010 email.xis Page 4



8/31/2010

Susan SearsBerry Petroleum1999 Broadway Ste 3700Denver, Co 80202

Thank you for the opportunity to present the following treatmentproposal. This recommendation is submitted for your consideration.

Weu DataCasing: 5 in 15 lb/ft, J-55Tubing:

Stage Info Stage 1 Stage 2 Stage 3 Stage 4Formation: UTELANDBUTTE L CASTLE PEAK 3 POINT DOUGLASCREEK

Packer/EOT Depth:TVD (For Deviated Wellbore):

Perf #1 - Top: 5.651 5,322 4.690 4,337Btm: 5,805 5,540 4.756 4,588SPF: 2 2 2 2

Perf #2 - Top:Btm;SPF:

Perf #3 - Top:Btm:SPE:

Perf #4 - Top:Stm:SPF:

Perf #5 - Top:Btm:SPF:

Total Shots: 24 26 12 14Perf Diameter: 0.36 0.36 0.36 0.36

Bht (deg F.): 153.104 147.758 135.014 130.325Estimated Frac Gradient: 0.85 0.85 0.85 0.85

Treatment Summary

Prima y Fluid SpGr: 1.01 1.01 1.01 1.01Treat Via: Casing Casing Casing Casing

Primary Fluid Type: MavFrac MavFrac MavFrac MavFracCO2 (y/n) N N N N

Estimated Treat psi 3,820 3,540 3,020 3,970Estimated Perf Fric (psi) 489 417 765 1,438

Acld Volume (gls) 500 250 250Total Clean Fluid/Foam(gls): 36.750 25,327 16,000 12,360

Pad Volume (gls): 11,250 8,100 5.120 4,200SLF Volume (gls): 25,500 17,227 10,880 8,160

Estimated Flush Volume (gls): 5,401 5,072 4,440 4,337

Proppant Volume (Ibs): 60,0DO 64,600 40,800 30,600Estimated Pump Time (min): 29.1 20.0 21 5 10.8

*NOTE: Total clean fluid/foam volume does not include flush volume.

Page 2BERRYFederal #13-5D-64 083010 emaitxis


API Well No: 43013503370000



FORM 9








9. API NUMBER: 43013503370000




COUNTY: DUCHESNE

STATE: UTAH

11.







9/20/2010












PLEASE SEE THE ATTACHED COMPLETION HISTORY FOR THE FEDERAL13-5D-64.



SIGNATURE N/A

DATE 9/21/2010

September 21, 2010

September 21, 2010

iPI Well No: 43013503370000

FORM 9STATE OF UTAH
















SDUato

WENrkRCEPmOpRetion: DEEPEN FRACTURE TREAT NEW CONSTRUCTION






9/20/2010WILDCAT WELL DETERMINATION OTHER OTHER:


PLEASE SEE THE ATTACHED COMPLETION HISTORY FOR THE FEDERAL13-5D-64. Accepted by the


FOR RE er9,¾Ï





Berry Daily Completion and Workover

/ Well Name: FEDERAL 13-5D-64Report # 1, Report Date: 9/3/2010

API/UWI Surface Legal Location Spud Dale Notice Field Name APD State43013503370000 i NWSW SECTION 5, T6S-R4W Ashlegorest UtahWellConfiguration Type Original KB Elevation (ftKB) rKB-Ground Distance (It) KB-CasingFlange Distance (ft) KB-Tubing Head Distance (ft)

7,252 , 14.00Primary Job Type Secondary Job TypeInitial CompletionÓbjective

Contractor ÑigNum6eÏ

ÃFE Number ofal AFE Amount ÖaiÍyÚosl CumCost To DateC10 032048 401,695 305,897 305,897

Wealher T (°F) Road Condition TubingPressure (psi) Casing Pressure (psi) Rig Time(hrs)

Job Contact Title Mobile

Time Log| Start Time End Time ( Dur(hrs) Code 1 Operation I Comment

00:00 00:00 CTUW W/L Operation RIGUP WIRELINE AND RUN CEMENT BOND LOGFRAM 5876' TO SURFACE.BOND LOOKED GOOD, CEMENT TOP AT 285'. SHORT JT AT 3921-32. RIGDOWN WIRELINE.

Report Fluids SummaryFluid To well(bbl) From well(bbi) To lease (bbl) From

lease¯bbÌ)

Daily CostsCode 1 Code 2 Code 3 Cost Cost Descriptlon

152 9999 301,737 ICC-CONTINGENCY152 2345 2,660 ICC-PERFORATING152 2380 1,500 ICC-SURFACE RENTALS

Safety ChecksTime Description Type Comment

LogsDate Type Top (ftKB) Btm (ftKB) Cased?

No

PerforationsDate Zone Top (itKB) Btm (ftKB)

¯Current Status

Date Zone Type Stim/Treat Company

SigNo. Stage Type Top (ftKB) Btm (ftKB) V (pumped) (bbt)

Other In HoleDescription Run Date OD (in) Top (ftKB) Btm (ftKB)

CementDescription Start Date CementÒomp

www.peloton.com Page 1/1 Report Printed: 9/21/2010





APf/UWi SurfaceLegal Location Spud Date Notice Field Name APD State

43013503370000 NWSW SECTION 5, T6S-R4W Ashley Forest UtahWell Configuration Type Original KB Elevalion (ftKB) KB-Ground Distance (it) KB-Casing Flange Dislance (ft) KB-Tubing i lead Distance (ft)

7,252 14.00Primary Job Type Secondary Job TypeInitial CompletionObjective

Contractor Rig Ñúmber

AFE Number Total AFE Amount Daily Cost Cum Cost To DateC10 032048 401,695 13,900 323,497

Weather T (°I j Road Condition Tubing Pressure (psi) Casing Pressure (psi) Rig Time (hrs)


Time LogStart Time 1 End Time Dur (hrs) Code 1 Operation Comment

00:00 00:00 FRAC Frac. Job RIG UP MAVERICK AND BREAK DOWN THE UTELAND BUTTEPERFS AT3085PSI PUMP 6 BBLS OF ACID AND 262 BBLSOF PAD. PUMP 464 BBLS OF 1 TO3 #/GAL 16/30 SAND, RAMPED. PUMP 143 BBLS OF 3 TO 4 #/GAL 16/30 SAND,RAMPED. PUMP 137 BBLS OF ACID AND FLUSH. ISIP 2450 PSI. 5 MIN 2360PSI. AVG RATE 39 BPM, AVG PR 2549 PSI, MAX RATE 39.9 BPM, MAXPR3247 PSI. 60,000# OF SAND IN PERFS. SHUT WELL IN FOR WIRELINE.

00:00 00:00 PFRT Perforating RIG UP WIRELINE AND SET COMPOSITE PLUG AT 5580'. PERFORATE THECASTLE PEAK WITH 3 1/8" CSG GUN, 2 SPF. 5322-23, 5339-40, 5362-65,5378-79, 5401-02, 5424-25, 5433-34, 5448-49, 5507-08, 5514-15, 5539-40.RIG DOWN WIRELINE.

00:00 00:00 FRAC Frac. Job RIG UP FRAC CREW AND BREAK DOWN THE CASTLE PEAK PERFS AT 1825PSI. PUMP 193 BBLS OF PAD. PUMP 256 BBLS OF 1 TO 5 /GAL 16/30 SAND,RAMPED. PUMP 154 BBLSOF 5 #/GAL 16/30 SAND. PUMP 130 BBLS OF ACIDAND FLUSH. ISIP 1275 PSI. 5 MIN 1210 PSI. AVG RATE 39 BPM, AVG PR 1460PSI, MAX RATE 39.8 BPM, MAXPR 1942 PSI. 64,600#OF SAND IN PERFS.SHUT WELL IN FOR PERFORATORS.

00:00 00:00 PFRT Perforating RIG UP WIRELINE AND SET COMPOSITE PLUGAT 4800'. PERFORATE THE 3 -

POINT WITH 3 1/8" CSG GUN, 2 SPF. 4690-91, 4727-28, 4737-38, 4753-56. RIGDOWN WIRELINE AND SHUT WELL IN FOR NIGHT.

Report Fluids SummaryFluid To well (bbi) | From wett(bbl) | To lease (bbl) _ j From lease (Obl)

Daily CostsCode 1 Code 2 Code 3 Cost Cost Description

152 9999 500 ICC-CONTINGENCY152 2106 5,200 ICC-WATER&WATERHAULING152 2358 3,200 ICC-BRIDGE PLUGS & PACKERS152 2380 1,500 ICC-SURFACE RENTALS152 2340 3,500 ICC-HOT OILING

Safety ChecksTime Descnplion Type Comment

LogsDate Type Top (ftKB) Bim (ftKB) Cased?

No

PerforationsDate Zone Top (ftKB) Btm (ftKB) Current Status

Date Zone Type StimíTreat Company

StgNo. Stage Type Top (flKB) Btm (ftKB) V (pumped) (bbl)

Other In HoleDescription Run Date OD (in) Top (itKB) Btm (ftKB)






APl/UWI SurfaceLegal Location Spud Dale Notice Field Name APD State43013503370000 NWSW SECTION 5, T6S-R4W Ashley Forest UtahWell Configuration Type Original KB Elevation (ftKB) KB-Ground Distance (ft) KB-Casing Flange Distance (ft) iKB-Tubing Head Distance (ft)

7,252 14.00

CementDescription Start Dale Cement Comp





Well Name: FEDERAL 13-5D-64Report # 4, Report Date: 9/9/2010

APf/UWi Sui1ace Legaf Location SpudDate Notice Field Name APD State43013503370000 NWSW SECTION 5. T6S-R4W Ashley Forest Utah\Nell Configuration Type ÓriginalKB Elevation (ftKB) KB-Ground Òislance(ft) KB-CasingFlange Dislance (ft) KB TubÏngIleaa Dislance (ft)

7,252 14.00Pnmary Job Type SecondaryJob TypeInitial CompletionobjectÍVO

Contractór g Number

AFE Number Total AFE Amount Daily Cost Cum Cost To DateC10 032048 401,695 | 114,575 438,072

Weather T (°F) Road Condition Tubing Pressure (psi) Casing Pressure (psi) Rig Time (hrs)


Time LogStart Time EndTime Dur (hrs) Code 1 Operation Comment

00:00 00:00 i FRAC Frac. Job RIGUP FRAC CREW AND BREAK DOWN 3-POINT PERFS AT2180 PSI. PUMP122 BBLS OF PAD. PUMP 162 BBLSOF 1 TO 5 #lGAL 16/30 SAND, RAMPED.PUMP 97 BBLS OF 5 #/GAL 16/30 SAND. PUMP 115 BBLS OF ACID AND FLUSH.ISIP 2070 PSI. 5 MIN 1740 PSI. AVG RATE 30 BPM, AVG PR 2197 PSI, MAX

RATE 30.7 PSI, MAX PR 2813 PSI. 40.800 # OF SAND IN PERFS. SHUT WELLIN.

00:00 00:00 PFRT Perforating RIG UP WlRELINE AND SET COMPOSITE PLUG AT 4630'. PERFORATE THEDOUGLAS CREEK WITH 3 1/8" CSG GUN, 2 SPF. 4337-40, 4489-90, 4565-67,4587-88. RIG DOWN WIRELINE.

00:00 00:00 FRAC Frac. Job RIG UP FRAC CREW AND BREAK DOWN THE DOUGLAS CREEK PERFS AT3595 PSI. PUMP 105 BBLS OF PAD. PUMP 121 BBLS OF 1 TO 5 #/GAL 16/30SAND, RAMPED. PUMP 73 BBLS OF 5 #/GAL 16/30 SAND. PUMP 103 BBLS OFFLUSH. ISIP 1830 PSI, 5 MIN 1560 PSI. AVG RATE 20 BPM, AVG PR 2935 PSI,MAXRATE 24.6 BPM, MAX PR 4249 PSI. 30,600 # OF SAND IN PERFS. SHUT

WELL INAND RIG DOWN FRAC CREW OFF OF WELL.

Report Fluids SummaryFluid To well (bbl) From well (bbl) To lease (bbl) From lease (bbl)

Daily CostsCode 1 Code 2 Code 3 Cost Cost Description

152 9999 500 ICC-CONTINGENCY152 2125 975 ICC-CONTRACTSUPERVISION152 2345 12,500 ICC-PERFORATING152 2358 1,600 ICC-BRIDGE PLUGS & PACKERS152 2360 97,500 ICC-STIMULATION/ACIDIZING152 2380 1,500 ICC-SURFACE RENTALS

Safety ChecksT1me Description Type Comment

LogsDate Type Top (ftKB) Stm (flKB) Cased?

No

PerforationsDate Zone Top (ftKB) Btm (ftKB) Current Status

Date Zone Type Stim/Treat Company

StgNo. Stage Type Top (ftKB) Btm (ftKB) V (pumped) (bbl)

Other In HoleDescription Run Date | OD (in) Top (ftKB) Btm (ftKB)

ICement

Description Start Date ÓementComp




IBerry Daily Completion and Workover


APf/UWI Surface Legal Location Spud Dale Notice Field Name APD State43013503370000 NWSW SECTION 5, T6S-R4W Ashley Forest UtahWell Configuralion Type Onginal KB Elevalion (flKB) ,KB-Ground Distance (ft) KB-Casing Flange Dislance (fl) KB-Tubing Head Distance (ft)

7,252 14.00Primary Job Type

¯Secondary Job Type

Initial CompletionObjective

ConIracior Rig Number

AFE Number Total AFE Amount Daily Cost Cum Cost To DateC10 032048 401,695 38,090 476.162

Ñealher T (°F) ÍÏoa CondÍÏion Tubing Pressure (psi) Casing Pressure (psi) Rig Ïime rs)


Time Log| Start Time End Time Dur (hrs) Code 1 1 Operation | Comment

00:00 00:00 CLN Clean Out Hole RIG UP ON WELL AND REMOVE FRAC HEAD AND VALVE.INSTALLTBG HEADAND BOP. TALLEY, DRIFT, AND PICK UP 2 7/8" TBGAND RUN IN THE HOLEWITH 4 3/4" BIT. PICK UP 84 JTS AND SHUT WELL IN FOR NIGHT.

Report Fluids SummaryFluid Towell(bbl) From well(bbl) To fease (bbl) Fromlease (bbl)

Daily Costs| | Code i Code 2 Code 3 Cost Cost Description

152 9999 500 ICC-CONTINGENCY152 3705 900 ICC-BITS&REAMERS152 2305 1,990 ICC-RIGCOST-COMPLETION152 2380 1,500 ICC-SURFACE RENTALS154 3530 32,000 TCC-TUBING&ATTACHMENTS154 3525 1.200 TCC-WELLHEADíTREEEQUIPMENT

Safety ChecksTime Description Type Comment

LogsDate Type Top (ftKB} 8tm (ftKB) Cased?

No

PerforationsDate Zone Top (ftKB) Stm (ftKB) CurrentStatus

Date Zone Type Stimffreat Company

StgNo. Stage Type Top (ftKB) Btm (flKB) V (pumped) (bbl)


CementDescription Start Date Cement C mp





Well Name: FEDERAL 13-5D-64Report # 6, Report Date: 9/17/2010

APf/UWi |Surface Legal Location Spud Date Notice Field Name APD Slate

43013503370000 ) NWSW SECTION 5. T6S-R4W Ashley Forest UtahWell Configuration Type |Original KB Elevation (ftKB) KB-Ground Distance (ft) KB-Casing Flange Distance (ft) KB-Tubing Head Distance (ft)

7,252 14.00Primary Job Type Secondary Job TypeInitial CompletionObjective

IContractor AlgÑumber

AFE Number Tolal AFE Amount Daily Cost Cum Cost To Dale

C10 032048 401,695 7,520 483,682Weather T (°F) Road Cor ition Tubing Pressure (psi) Casing Pressure (psi) Rig Time rs)


Time LogStart Time End Time Dur (hrs) Code 1 Operation Comment

00:00 00:00 CLN Clean Out Hole CONTINUE TO PICKUP TBG AND TAG SAND AT 4594', PICK UP POWERSWIVEL AND CIRCULATE WELL. CLEAN OUT SAND TO PLUGAT 4630'. DRILLOUT PLUG AND CIRCULATE HOLE CLEAN.

00:00 00:00 CLN Clean Out Hole RUN TBG AND TAG FILLAT 4768'. CIRCULATE AND CLEAN OUT TO PLUG AT4800'. DRILLOUT PLUG AND CIRCULATE HOLE CLEAN.

00:00 00:00 CLN Clean Out Hole RUN ÏBG AND TAG ÄÏ 5520'. CLEÁN 0UT HOLE TO PLUG AT 5580'. DRILLOUT PLUG AND CIRCULATE HOLE CLEAN.

00:00 00:00 CLN Clean Out Hole RUN TBG AND TAG FILLAT 5842'. CIRCULATE AND CLEAN OUÏ HOLE Ï0PBTD AT 5931'. CIRCULATE HOLE CLEAN AND LAY DOWN POWER SWlVEL.LAY DOWN 3 JTS TBG AND SHUT WELL IN FOR NIGHT.

Report Fluids SummaryFluid To well(bbl) From well (bbi) To lease (bbl) _| From lease (bbl)

I _ I _ _ LDaily Costs

Code 1 Code 2 Code 3 Cos! | Cost Description152 9999 500 ICC-CONTINGENCY152 2106 500 ICC-WATER&WATERHAULING152 2125 975 ICC-CONTRACTSUPERVISION152 2305 4,045 ICC-RIGCOST-COMPLETION152 2380 1,500 ICC-SURFACE RENTALS

Safety ChecksTime [ Description Type Comment

ILogs

Dale Type Top (ftKB) Btm (ftKB) Cased?No

PerforationsDate Zone Top (flKB) Blm (ftKB) ÒurrentŠtatus

||Date Zone Type Stim/Treat Õompany

Stg |No. | Stage Type Top (ftKB) Btm (ftKB) V (pumped) (bbl)

Other In HoleDescription Run Date OD (in) Top (ftKB) _ Btm (ftKB)

CementDescription Start Date Cement Comp






APl/UWf Surface Legal Location Spud Date Nolice FieÍdÑame APD State

43013503370000 NWSW SECTION 5, T6S-R4W Ashley Forest UtahWell 0onfigurationType Original KB Elevation (ftKB) KB-Ground Distance (ft) KB-Casing Flange Dislance (ft) REÏ-Tubing Head Distance (fi)

7,252 14.00

Primary Job Type¯

Secondary Job Type

Initial CompletionÒbjective

ntrNaum

er Total ÄFE Ämount ailyCos!

Rig Number

Cum Cosi To Date

C10 032048 401,695 7,520 491,202Weather T (°F) Road Condition Tubing Pressure (psi) basingPressure (psi) R me (hrs)


Time LogStart Time End Time _Dur (hrs) Code 1 Operation Comment

00:00 00:00 PULT Pull Tubing WELLHEAD PT 0 PSI. PULL TBGOUT OF THE HOLE AND LAYDOWN BITANDBIT SUB. MAKE UP AND RUN 1 JT TBG, PSN, TBG ANCHOR, AND 185 JTS OFTBG. SET TBG ANCHOR AND REMOVE BOP. LANDTBG WITH 12,000#TENSION. MAKE UP WELLHEAD.

00:00 00:00 RURP Run Rods & Pump CHANGE OVER TO ROD TOOLS AND RÜN IN THE HOLE VŸÌÏHPÜIVÌPÃNDRODS FOR PRODUCTION. SEAT PUMP AND MAKE UP STUFFING BOX. FILLTBG WITH 5 BBLS WATER AND PRESSURE TEST TBG AND PUMP TO 500 PSI.HELD OK. HANG WELL OFF AND RIG DOWN .

00:00 00:00 LOAD WATER 2850 BBLS.FINAL REPORT.

Report Fluids SummaryFluid To well(bbl) Fromwell(bbij To lease (bbl) From lease (bbl)

Daily CostsCode 1 Code 2 Code 3 Cost | Cost Description

152 9999 500 ICC-CONTINGENCY152 2106 500 ICC-WATER&WATERHAULING152 2125 975 ICC-CONTRACTSUPERVISION152 2305 4,045 ICC-RIGCOST-COMPLETION152 2380 1,500 ICC-SURFACE RENTALS

Safety ChecksTime | Description Tyve Comment

LogsDate Type Top (ftKB) Btm (ftKB) Cased7

No

PerforationsDate Zone Top (ftKB) Stm (ftKB) Current Status

Dale Zone Type StimíTreat Company

StgNo. Stage Type Top (ftKB) Btm (ftKB) V (pumped) (bbl)


CementDescription Start Date _ Cement Comp



API Well No: 43013503370000



FORM 9








9. API NUMBER: 43013503370000




COUNTY: DUCHESNE

STATE: UTAH

11.





9/29/2010














PLEASE NOTE THAT THE FEDERAL 13-5D-64 WENT TO SALES ON SEPTEMBER29, 2010.



SIGNATURE N/A

DATE 10/1/2010

October 01, 2010

October 05, 2010

iPI Well No: 43013503370000

FORM 9STATE OF UTAH
















SDUato


9/29/2010 OPERATOR CHANGE PLUG AND ABANDON PLUG BACK







PLEASE NOTE THAT THE FEDERAL 13-5D-64 WENT TO SALES ON SEPTEMBER29, 2010. Accepted by the


FOR REÇQgggY



RECEIVED October 01,

O .

STATE OF UTAH AMENDEDREPORT Ü FORM 8DEPARTMENT OF NATURALRESOURCES (highlight changes)

DIVISIONOF OIL, GAS AND MINING 5. LEASEDESIGNATIONANDSERIALNUMBER:

UTU8894A

WELL COMPLETION OR RECOMPLETIONREPORT AND LOG6. IFINDIAN,ALLOTTEEORTRIBENAME

la. TYPE OF WELL:LL

SLL DRY OTHER7. UNITor CA AGREEMENTNAME

b. TYPE OF WORK: 8. WELLNAMEand NUMBER:

J¶. HATRSZ. EP-RY R. OTHER FEDERAL13-5D-64

2. NAMEOF OPERATOR: 9. API NUMBER:BERRY PETROLEUMCOMPANY 4301350337

3. ADDRESS OF OPERATOR: PHONE NUMBER: 10 FIELDAND POOL, OR WILDCAT

4000 S. 4028 W. cerv ROOSEVELT sTATE UT ze 84066 (435) 722-1325 BRUNDAGE CANYON4. LOCATIONOF WELL(FOOTAGES) 11. QTRIQTR, SECTION, TOWNSHIP, RANGE,

MERIDIANATSURFACE: 1338 FSL, 972 FWL NWSW 5 6S 4W UAT TOP PRODUCING INTERVALREPORTED BELOW: 821 FSL, 746 FWL SWSW

12. COUNTY 13. STATEATTOTALDEPTH: 620 FSL, 695 FWL SWSW DUCHESNE UTAH

14. DATESPUDDED: 15. DATET.D. REACHED: 16. DATECOMPLETED: 17. ELEVATIONS(DF, RKB, RT, GL):

7/26/2010 8/13/2010 9/20/2010 ABANDONED READYTO PRODUCE O 7240 GL18. TOTALDEPTH: MD 5,989 19. PLUG BACKT.D.: MD 5,931 20. IF MULTIPLECOMPLETIONS, HOW MANY?* 21. DE BSREI E MD

Tv 593¾ TVD TVD

22. TYPE ELECTRICANDOTHE MECHANICALLOGS RUN (Submit copy of each) 23.

ELECTRONIC C- / / " / C-pf-4 y WASWELLCORED7 NO YES (S bmitanalysis)

ECDTONRAUL

URVEY? PY

24. CASING AND LINER RECORD (Report all strings set in welt}

HOLE SIZE SIZEIGRADE WEIGHT (#llt.) TOP (MD) BOTTOM(MD) STAGEDCEMHENTERCNE NFS

CKESVO

UMREBL) CEMENTTOP ** AMOUNTPULLED

12.5 8.625 J-55 24 0 342 G 185

7.875 5.5 J-55 15.5 5,985 PL 220 285 CBLPLHS 320

25. TUBING RECORD

SIZE DEPTH SET (MD) PACKER SET (MD) SIZE DEPTH SET (MD) PACKER SET (MD) SIZE DEPTH SET (MD) PACKER SET (MD)

2.875 | 5,86026. PRODUCING INTERVALS 27. PERFORATION RECORD

FORMATIONNAME TOP (MD) BOTTOM(MD) TOP (TVD) BOTTOM(TVD) INTERVAL(ToplBot - MD) SIZE NO. HOLES PERFORATION STATUS

(A) UTELAND 5,651 5,805 5,651 5,805 .36 24 open Squeezed

(B) CASTLE PEAK 5,322 5,540 5,322 5,540 .36 26 OP•n 2 Squeezed

(c) 3 POINT 4,690 4,756 4,690 4,756 .36 12 open Squeezed

(D) DOUGLASCREEI 4,337 4,588 4,337 4,588 .36 14 open Squeezed

28. ACID, FRACTURE, TREATMENT,CEMENTSOUEEZE, ETC.

DEPTH INTERVAL AMOUNTANDTYPE OF MATERIAL

UTELAND FRAC W/ 60,000 LBS SAND & 1012 BBLS FLUIDCASTLE PEAK FRAC W/ 64,600 LBS SAND &733 BBLS FLUID3 POINT FRAC W/ 40,800 LBS SAND &496 BBLS FLUID

29. ENCLOSED ATTACHMENTS: 30. WELL STATUS:

O ELECTRICALIMECHANICALLOGS GEOLOGIC REPORT DST REPORT DIRECTIOÑALSURVEY

O SUNDRY NOTICE FOR PLUGGINGANDCEMENT VERIFICATION CORE ANALYSIS OTHER:

(5/2000) (CONTINUEDON BACK) RECEIVED' NOV17 2018DIV.0F OIL,GAS&

31. INITIALPRODUCTION INTERVALA (As shown in item #28)

DATE FIRST PRODUCED: TEST DATE: HOURS TESTED: TEST PRODUCTION OIL - BBL: GAS - MCF: WATER - BBL PROD. METHOD:9/29/2010 10/1/2010 24 RATES: -+ 78 45 100 PUMPING

CHOKE SIZE: TBG. PRESS. CSG. PRESS. API GRAVITY BTU - GAS GASIOILRATIO 24 HR PRODUCTION OIL- BBL: GAS- MCF: WATER- BBL: INTERVALSTATUS:250 73 RATES: -* PRODUCIN(

INTERVALB (As shown in Item #26)

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

CHOKE SIZE: TBG. PRESS. CSG. PRESS. API GRAVITY BTU - GAS GASIOILRATIO 24 HR PRODUCTION OIL- BBL: GAS - MCF: WATER - BBL: INTERVALSTATUS:RATES: -+

INTERVALC (As shown in item #26)

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

CHOKE SIZE: TBG. PRESS. CSG. PRESS. API GRAVITY BTU - GAS GASIOILRATIO 24 HR PRODUCTION OIL- BBL GAS - MCF: WATER - BBL: INTERVALSTATUS:RATES: -+

INTERVALD (As shown in item #26)

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

CHOKE SIZE: TBG. PRESS. CSG. PRESS. API GRAVITY BTU - GAS GASIOILRATIO 24 HR PRODUCTION OIL- BBL: GAS- MCF: WATER - BBL: INTERVALSTATUS:RATES: ->

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

SOLD33. SUMMARYOF POROUS ZONES (include Aquifers): 34. FORMATION(Log) MARKERS:

Show all important zones ofpomsity and contents thereof Cored intervals and all drill-stem tests, including depth intervaltested, cushionused, timetoolopen, flowingand shut-inpressures and recoveries.

Formation o o m Descriptions, Contents, etc. Name (Measu Depth)

GR (NEW) 1,897MAHOGANY 2,522TGR3 3,544DOUGLAASCREEK 4,291BLACKSHALE 4,900CASTLE PEAK 5,214UTELAND 5,648WASATCH 5,847

35. ADDITIONALREMARK: (include plugg ng procedure)

28. DOUGLASCREEK: FRAC W/ 30,600 LBS SAND &402 BBLS FLUID

36. I hereby certify thatthe foregoing and attached Information is complete and correct as determined from all availablerecords.

NAME(PLEASE PRI T KATHYK FIELDST D, TITLE SR REGULATORY& PERMITTINGTECH

SIGNATURE DATE 11/11/2010

This report must be sub itted within 30 days of• completing or plugging a new well e reentering a previously plugged and abandoned well• drillinghorizontal laterals from an existing well bore e significantly deepening an existing well bore below the previous bottom-hole depth• recompleting to a different producing formation • drillinghydrocarbon exploratory holes, such as core samples and stratigraphic tests

* ITEM20: Show the number of completions if production is measured separately from twoor more formations.**lTEM24: Cement Top -Show how reported top(s)of cement were determined (circulated (CIR),calculated (CAL),cement bond log (CBL),temperaturesurvey (TS)).

Send to: Utah Divisionof Oil, Gas and Mining Phone: 801-538-53401594 West North Temple, Suite 1210Box 145801 Fax: 801-359-3940Salt Lake City, Utah 84114-5801

A GREATWMTEDIRECT70NAL SERVICES LLC

Survey Certification Sheet

Report Date: 8-23-10

GWDS Job #: 02276-432-21 / Directional

Operator: Berry Petroleum Co.Well Name: Federal 13-5D-64API#: 43-013-50337County/State: Duchesne Co., UTWell SHL: 1338' FSL & 972' FWL (NWSW) Sec. 5-T6S-R4WWell SHL: 39° 59' 7.001" N (NAD27)

110° 21' 51.289" W (NAD27)

Drilling Rig Contractor: Berry Rig 5 (RKB: 14')

Surveyed Dates: 8/8/10-8/11/10Surveyed froma depth of: OH: 421.00' MD to 5940.00' MD

Type of Survey: MWD Surveys (STB=50')

The data and calculations for this survey have been checked by me and conform to thecalibration standards and operational procedures set forth by Great White Directional Services,LLC. I am authorized and qualified to review the data, calculations and this report, and that thereport represents a true and correct Directional Survey of this well based on the original datacorrected to True North and obtained at the well site. Wellbore Coordinates are calculated usingminimum curvature method.

Bret Wolford

Great White Directional Services, LLC - Well Planner

PO Box 427 • MlLLS, WY 82644 •63 CASPER VIEW COURT • MlLLS, WY 82644OFFICE (307) 472-7400 •FAX (307)

Project: Duchesne Co., UT (UT27C)Site: Federal Sec.5 Pads (Sec.5-T6S-R4W)

Well: Federal 13-5D-64Wellbore: Weilbore #1

Lt d9ed59

7 01 Num

Longitude: 110° 27 51.289 WGround Level: 7238.00

WELL @7252.00ft (Berry Rig 5)

PROJECT DETAILS: Duchesne Co,, UT (UT27C)- REFERENCE INFORMATIONGeodetic System: US State Plane 1927 (Exact solution) .. - .

Datum: NAD 1927 (NADCON CONUS) Co-ordinate (NIE) Reference: Well Federal 13-5D 64 True NorthEllipsoid: Clarke 1866 Veitical (TVD) Reference: WELL @7252.00ft (Berry Rig 5)

,Zone: Utah Central 4302 Section (VS) Reference: Slot -(0.00N, 0.00E)

Measured Depth Reference: WELL @ 7252.00ft (Berry Rig 5)System Datum: Mean Sea Level Calculation Method: Minimum Curvature

0 - WELL DETAILS: Federal 13-5DA4

Ground Level: 7238.00mm sur | +NOO-S +EO

0603N7o03

2318 39° 59Ottudi

110° 21 2

WELLBORE TARGET DETAILS(MAP CO-ORDINATES AND LATILONG)

Name TVD +NI-S +El-W Northing Easting Latitude Longitude ShapeFed 13-5D-64 TgE896.00 -686.49 -308.54 603012.9832317933.203 39° 59' 0.216 N 110 21' 55.253 W Polygon

I t

SECTION DETAILS

MD toc Azi TVD +N/-S +Ef-W DLeg TFace VSec Annotation1200 0.00 0.00 o.oo o.oo 0.00 0.00 0.00 0.00 0.00

450.00 0.00 0.00 450.00 0.00 0,00 0.00 0.00 0.00 Start Nudge 2.00°- - ¯ ¯ ¯

750.00 6.00 160.00 749.45 -14.75 5.37 2.00 160.00 11.25 Start DLS 2,00 TFO 86,621079.37 9.16 206.01 1076.18 -54.53 -0.25 2,00 86,62 49,84 Start 3958 23 hold at 1079,37 MD5037.60 9,16 206,01 4983.94 -620.82 -276.51 0.00 0.00 679.61 Start Drop -1,00°

5953.56 0.00 0.00 5896.00 -686 49 -308.54 1.00 180.00 752.63 TD at 5953.56

1600 - -- --FORMATIONTOP DETAILS

-- ¯TVDPath MDPath Formation

1342.39 1349,02 Green River2000 -- -- -- - 1892.93 1906.67 Green River Upr Mkr

0 a 2501.12 2522,71 Mahogany3522.71 3557.49 Tgr3 Mkr

¡Ogd 4266.04 4310.43 Douglas Creek4849.38 4901,30 Black Shale5033.23 5087.50 1/2 Through Obj.

2 5168.50 5224.09 Castle Peak2400 5611.97 5669.41 Uteland Butte Ls.- 3L 5801,72 5859 28 Wasatch

Magnetic FieldStrengkh, 52265.4enT

Dip Angle: 66.71*3200 - Date 07f29f20l0

- Modsi: IGFtF2010

3600 - - -

4000-

SHL

4400

97

4800 -

5600 - - ,- 1200-- - -- 68649'S,30884 W654 FSL & 66F FWL

SEC.S-TSMt4W

1 00 900 BOU 300 0 300 800 900

West( )/East(+) (600 ftlin)

Plan: Design #1 (Federal 13-5D-64/Wellbore #1)-a iO -40 0 4U0 SUO 1200 1600 2000

Vertical Section at 204 20 (800 ftlin)Created By: Bret Wolford Date: 13:54, August 23

Berry Petroleum CompanyDuchesne 00., UT {UT27C)Federal Sec.5 Pads (Sec.5-T6S-R4W)Federal 13-5D-64

Wellbore #1

Survey: Survey #1

Standard Survey Report23 August, 2010

AGREATWHlTEDMECHONM SERWŒS,

Great White Directional Services, LLC GREMWMTE. , Survey Report

Company: Berry Petroleum Company Local Co-ordinate Reference: Well Federal 13-5D-64

Project: Duchesne Co , UT (tJT27C) TVD Reference: WELL @ 7252 00ft (Berry Rig 5)Site: Federal Sec 5 Pads (Sec 5-T6S-R4W) MD Reference: WELL @7252.00ft (Berry Rig 5)Well: Federal 13-5D-64 North Reference: TrueWeilbore: Wellbore #1 Survey Calculation Method: Minimum CurvatureDesign: Wellbore #1 Database: EDivi 2003 21 Single User Db

Project Duchesne Co , UT (UT27C)

Map System: US State Plane 1927 (Exact solution) System Datum Mean Sea LevelGeo Datum: NAD 1927 (NADCON CONUS)Map Zone: Utah Central 4302

Site Federal Sec 5 Pads (Sec 5-T6S-R4W)

Site Position: Northing: 606 072.191ft Latitude 39° 59' 30.350 NFrom: Lat/Long Easting: 2,318,718.767ft Longitude: 10° 21' 44.662 WPosition Uncertainty: 0 00 ft Slot Radius " Grid 0onvergence: 0.73 °

eil Federal 13-50-64

Well Position +N/-S 0.00 ft Northing: 603,703.331 ft Latitude: 39° 59' 7.001 N+El-W 0.00 ft Easting: 2,318,233.001 ft Longitude: 110° 21' 51.289 W

Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 7 238.00ft

Wellbore Wellbore #1

Magnétics lulodel Name Sani¡iie Date Declination Dip Angle Field Strength(*) nT)IGRF2010 07/29/10 11 53 65 71 52,266

Design Wellbore #1

Audit Notes

Version: 1 0 Phase: ACTUAL Tie On Depth: 0.00

Vertical Section Depth From (TVD) +N/-S +El-W Direction

0 00 0 00 0.00 204.20

Survey Program Date 08/23/10

From To(ft) (ft) Survey (Welihore) Too Name Description

421.00 5,990.00 Survey #1 (Wellbore #1) MWD MWD - Standard

Survey

Measured Vertica Vertica Dagleg Build TurrtDGPÙl hiclination Aziniuth Depth +N/-S +EÏ-W Section Rate Rate Rate

(ft) (°) ( ) (ft) {ft) (ft) (ft) It00ft) lì00ft) 1100ft)

0.00 0.00 0 00 0 00 0 00 0 00 0 00 0 00 0.00 0 00First MWD Survey

421 00 1.85 158 48 420 93 -6 32 2 49 4 74 0 44 0.44 0.00481 00 3.25 159 71 480.87 -8 82 3 44 6 63 2 33 2.33 2.05543 00 5.05 158 98 542 70 -13.01 5 03 9 81 2 90 2.90 -1.18

604 00 6.46 163 93 603 39 -18 82 6 94 14 32 2 45 2.31 8.11

665 00 7.16 171 49 663 96 -25 88 8 45 20 14 1 86 1 15 12.39726 00 7.91 178 52 724 44 33 83 9 12 27 12 1 95 1.23 11 52819 00 9.05 192 58 816 43 4T37 7 69 40 05 2.54 1 23 15.12911 00 9 84 197 42 907 18 -61 93 3 77 54 95 1 22 0 86 5.26

1,003 00 10 55 201 20 997 73 -77 29 -1.63 71 16 1 06 0 77 4.11

1,098 00 10 90 200 23 1 091 07 -93 82 7.88 88 81 0 41 0 37 -1.021,193.00 10 50 207 09 1 184 42 -109 96 -14.93 106 42 1 40 0 42 7.22

08/23/10 2 00 56RM Page 2 COMPASS 2003 21 Build

Great White Directional Services, LLC GREMWMTESurvey Report


Project: Duchesne Co , UT (UT27C) TVD Reference: WELL @7252 00ft (Berry Rig 5)Site: Federal Sec.5 Pads (Sec 5-T6S-R4W) MDReference: WELL@7252 00ft (Berry Rig 5)Weil: Federal 13-5D-64 North Reference: TrueWellbore: Wellbore #1 Survey Calculation Method: MinimumCurvatureDesign: Wellbore #1 Database: EDM 2003 21 Single User Db

Survey


(II) ( ) (*) (A) (ft) (ft) (ft) (°/100ft} (*I100ft) (*l100ft)

1,288.00 10.02 205.68 1,277:90 -125.11 -22.46 123.32 0.57 -0.51 -1.48

1,383 00 9.89 207.79 1,371.47 -139.78 -29 84 139.73 0 41 -0.14 2 221,479.00 9.58 207.97 1,466.09 -154.13 -37 43 155.93 0 32 0.32 0,191,574 00 9.05 204.71 1,559.84 167.90 -44 26 171.29 0 79 -0.56 -3.43

1,669.00 10 59 206.91 1,ð53.44 -182.47 -51 34 187.48 1.67 1.62 2.321,764.00 10 24 204.10 1,746.88 -197.96 -58 74 204.64 0.65 -0.37 -2 961,859.00 9 05 201.90 1,840.53 -212.60 -64 9 220.55 1.31 -1 25 -2.32

1,954 00 9 80 203.13 1,934.25 -226.97 -70 93 236.10 0.82 0.79 1,29

2,049 00 9.45 207.70 2,027.92 -241.31 -77 74 251.97 0.88 -0.37 4.812,144 00 9.71 204.80 2,121.59 -255.49 -84 72 267.77 0 58 0.27 -3.05

2,239 00 8.53 204.54 2,215.39 -269.17 -91 01 282.82 1 24 -1.24 -0 272,335 00 9.67 206.03 2,310.18 -282.89 -97 50 298.00 1 21 1 19 1 552,430.00 8.75 201.55 2,403.95 -296.78 -103 66 313.19 1 23 -Q97 -4.72

2,525 00 9.89 206.38 2,497.70 -310.81 -109 94 328.57 1 45 1 20 5.082,620 00 8 92 207.26 2,591.42 -324.67 -116 94 344.07 1 03 -1 02 0.932,715.00 9 23 203.13 2,685.23 -338.22 -123.30 359.05 0 76 0.33 -4.35

2,810 00 9 58 205.59 2,778.96 -352.36 429.71 374.5T 0 56 0.37 2,592,905 00 9.89 203.83 2,872 59 -366.95 -136 42 390 63 0 45 0 33 -1.85

3,001.00 9,76 201.46 2,967.18 -382.07 -142 73 407.00 0.44 -0 14 -2.47

3,095.00 10 20 205 42 3,059.76 -397.00 -149 22 423.28 0.87 0 47 4.213,190.00 9 84 204.80 3,153.31 -411.97 -156.23 439.81 0.40 -O38 -0 653,285.00 9 76 204.45 3,246.92 -426 67 -162.97 455.98 0.10 -0.08 -0.37

3,380.00 9 62 202.52 3,340.57 -441.33 -169 34 471.96. 0.37 -0.15 -2.03

3,475.00 9 49 200.93 3 434,25 -455.98 -175 18 487.72 0.31 -0.14 -1.67

3,570.00 8 92 200.85 3,528.03 -470.1T -180 60 502.89 0.60 -0.60 -0.08

3,665.00 8 57 200.58 3,621 92 -483.68 -185.71 5t7.30 0.37 0.37 -0.28

3,758.00 8 57 197.59 3,713.89 -496.78 -‡90.24 531.10 0.48 0.00 -3.22

3,853.00 7 82 197.95 3,807.92 -509 67 -194.37 544.56 0.79 0.79 0.38

3,949.00 8 35 202,60 3,902.96 -522.32 -199.06 558.02 0.88 0.55 4.844,044.00 8 61 200.85 3,996 92 -535.33 -204.25 572.01 0.39 0.27 -1.84

4,137.00 8 31 200.85 4,088.91 -548.12 -209.11 585.67 0.32 -0,32 0.004,232.00 8 26 197.24 4,182.92 -561.05 -213.58 599.30 0.55 -0.05 -3.80

4,327,00 7 51 197.24 4,277,02 -573 50 -217 44 612.23 0.79 -0.79 0.004,421 00 7.82 202.16 4,370.18 585.29 -221.68 624 72 0.77 0.33 5.234,516.00 7.47 204.80 4,464 34 -596.88 -226.70 637 36 0.52 -0.37 2 784,611 00 7.16 206.21 4,558.56 -607 80 -231.91 649 45 0.38 -0.33 1.484,706.00 6.99 208.58 4,652 84 -61819 -237.29 661 13 0.36 -0.18 2.494,801 00 6 46 206.65 4,747 19 -628 04 -242 45 672 23 0.61 -0.56 -2.03

4,896 00 6 02 209.11 4,841 62 -637 17 -247.27 682.54 0.54 -0.46 2,594 991 00 5.19 206.91 4,936.17 -645.35 -251.64 691.79 0.90 -0.87 -2.32

5,086.00 5.01 198.03 5,030 80 -653.13 -254 87 700 21 0.85 -0.19 -9 355,181.00 4 57 200.49 5,125.46 -660.62 -257.48 708.11 0.51 -0.46 2 595 277.00 4 48 198.65 5,221.16 -667.75 -260 02 715.66 0.18 -0.09 -1 92

5 371.00 4 35 197.16 5,314 89 -674 64 262 24 722.85 0.18 -0.14 -1 595 466.00 4.13 199.79 5,409 63 -681.30 -284 46 729.83 0 31 -0.23 2 775 561.00 4 39 198.12 5,504 36 -681 97 -266 15 Ì36.86 0 30 0 27 -1 765 656.00 4.13 198.30 5,599 10 494.68 -268 96 743 88 0 27 0.27 0 195 751.00 4.35 197 68 5,693 84 -701 36 -271 13 750.86 0 24 0.23 -0 65

5 845.00 4.39 203 04 5,787 57 708 06 273 62 758.00 0 44 0.04 5 70Last MWD Survey5,940 00 4 09 199 88 5.882 31 -T14 60 -276 19 765.01 0 40 -0.32 -3 33

Proj to Bit5 990.00 4 09 199 88 5,932 18 -717 95 -277.40 768.57 0 00 0 00 0.00

08/23/10 2 00 56PU Page 3 COMPASS 2003.21 Build

Great White Directîonal Services, LLc GRERWMTE


Project: Duchesne Co , UT (UT27C) TVD Reference: WELL @7252 00ft (Berry Rig 5)Site: Federal Sec 5 Pads (Sec 5-T6S-R4W) MD Reference: WELL@7252 00ft (Berry Rig 5)Well: Federal 13-5D-64 North Reference: TrueWellbore: Wellbore #1 Survey Calculation Method: Minimum CurvatureDesign: Wellbore #1 Database: EDM 2003 21 Single User Db

Survey Annotations

Measured Vertical Local CoordinatesDepth Depth +NI-S +El-W

(ft) (ft) (ft) (ft) Comment421.00 420.93 -6.32 2.49 First MWD Survey

5,940.00 5,882.31 -714 60 -276.19 Last MWD Survey5,990.00 5,932,18 -71T 95 -277.40 Proj. to Bit

Checked By: Approved By: Date

08/23/10 2 OQ56RM Page 4 COMPASS2003 21 Build

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