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Home My WebLink About210-084 • • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q L 0 - ©s q- Well History File Identifier Organizing (done) ❑ Two -sided llIIIIII IIIl ❑ Rescan Needed 1 111111 I I I III RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: ❑ Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: 11 Other:: BY: Maria Date: ghi6pc9. /s/ MP Project Proofing IIIIIIIIIIII IIII BY: Maria Date: 7/ //ic . /s/ rV1P Scanning Preparation x 30 = + = TOTAL PAGES /7 / (Count does not include cover sheet) / ) BY: Date: 7/6// Production Scanning I IIII I II I I Stage 1 Page Count from Scanned File: / (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: Y ES NO BY: Date: 7//6// o'. lsl , p Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I I llIJIlIIIl 1111 ReScanned 1 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked II HFIlIl I11111 12/22/2011 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 719/2012 Permit to Drill 2100840 Well Name /No. PRUDHOE BAY UNIT 05 -16C Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20262 -03 -00 MD TVD Completion Date Completion Status Current Status EXPIR UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number Name Scale Media No Start Stop CH Received Comments Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? Y / N Chips Received? Y / N Formation Tops Y / N Analysis Y / N Received? Comments: Y i Compliance Reviewed By: >"� Date: C I 1 �— • IF SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05 -16C BP Exploration (Alaska), Inc. Permit No: 210 -084 Surface Location: 3367' FSL, 38' FWL, Sec. 32, T11N, R15E, UM Bottomhole Location: 4623' FSL, 2746' FEL, Sec. 30, T11 N, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable Y P Y PP licable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Daniel . Seamount, Jr. � Chair DATED this l day of July, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) STATE OF ALASKA litUtilitp_dfee• ALAS•IL AND GAS CONSERVATION COMMI•N JUN 2 3 2010 6-S-/ PERMIT TO DRILL 20 AAC 25.005 Alaska Oil & Gas CMS. Commission 1 a. Type of work: 1 b. Proposed Well Class: ® Development Oil ❑ Service - Winj ❑ Single Zone 1 c. SpecilibiroMiroposed for: ❑ Drill ® Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas 0 Gas Hydrates ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU 05 -16C . 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 13490' TVD 8740'ss Prudhoe Bay Field / Prudhoe 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028326 3367' FSL, 38' FWL, SEC 32, T11 N, R15E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 4028' FSL, 1304' FEL, SEC 30, T11 N, R15E, UM July 25, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4623' FSL, 2746' FEL, SEC 30, T11 N, R15E, UM 2560 36740' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 65.00 feet 15. Distance to Nearest Well Open Surface: x- 697092 y- 5949530 Zone- ASP4 GL Elevation above MSL: feet to Same Pool: 710' 16. Deviated Wells: Kickoff Depth: 11620' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3260 Surface: 2380 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 4 -1/8 "" 3 -1/2" x 2 -7/8" 9.2# / 6.4# L -80 STL 2390' 11100' 8564'ss 13490' 8740'ss 116 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 14135' 8808' None 14050' 8808' 14043' Casing Length Size Cement Volume MD TVD Conductor / Structural 116' 20" 248 sx Permafrost 116' 116' Surface 2723' 13 -3/8" 5950 sx Permafrost II 2723' 2723' Intermediate 10039' 9 -5/8" 700 sx Class '0'. 300 sx Permafrost 10039' 7824' Production Liner 1946' 7" 339 sx Class 'G' 8669' - 10615' 6951' 8191' Liner 3685' 4 -1/2" 465 sx Class 'G' 10450' - 14135' 8123' - 8808' Perforation Depth MD (ft): 11700' - 13998' Perforation Depth TVD (ft): 8782' - 8809' 20. Attachments: ❑ Property Plat IS BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the � �t nd correct. Contact Amanda Suddreth, 564 -5543 Printed Name w� .ipe:/ /� Title Engineering Team Leader ' - r Prepared By Name/Number: Signatu Phone 564 -4711 Date 6 �3 /6 Elizabeth Barker, 564-4628 Commission Use Only Permit To Drill API Number: Permit Apr I aje' See cover letter for Number: ' ', a /004 7 4 6 . 50- 029 - 20262 -03 -00 �` other requirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbe methane, gas hydrates, or gas contained shales: Er Other: 3500 es c 8o1 _ Samples Req'd: ❑� I es ' No Mud Log Req'd: ❑ es 'No ii. ZSOo e re_ An n w (Gs -f- , ( "0/ HA Measures: ® Yes ❑ No Directional Survey Req'd: hG Yes ❑ No ,/ �f APPROVED BY THE COMMISSION 7 17(Z-v Date , COMMISSIONER Form 10-401 Revised 07 009 This permit is valid for 24 months from - date of approval (20 AAC 25.005(g)) Submit In Duplicate ORIGINAL 7--/-/o /, e�.� • 05 -16C Coiled Tubing Drilling To: Alaska Oil & Gas Conservation Commission From: Amanda Suddreth bp CTD Engineer Date: June 15, 2010 Re: 05 -16C Permit to Drill Application Coil Tubing Sidetrack: Drill and Complete Summary Pre -Rig Work: (scheduled to begin July 4, 2010) 1. S Caliper tubing from 11,330' (DONE 4/19/10) 2. F MIT -IA to 3000psi, MIT -OA to 2000 psi (DONE; PASS 4/19/10) 3. W PPOT -T, function LDS. PT tree (MV, SV, WV) 4. S Dummy WS drift to -10,600' MD (limited by deviation) 5. C Mill XN nipple at 10,427' SLMD (10,445' MD) w/ LH mill 6. D Bleed wellhead pressures to zero. • 7. 0 Remove wellhouse, level pad. 8. V Set BPV. Pe Rig Work: (scheduled to begin on July 25, 2010) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. RIH and set 4 -1/2" monobore packer whipstock, with top @ 11,600' MD. 3. Mill 3.8" window at 11,600' and 10' of rathole. Swap the well to Power -Vis. 4. Drill Build: 4.125" OH, 308' (35 deg /100 planned) 5. Drill Lateral: 4.125" OH, 1632' (12 deg /100 planned) with resistivity 6. Run 3 -1/2" x 2 -7/8" solid carbon liner leaving TOL at 11,100' '-) Prt' 7. Pump primary cement leaving TOC at 11,100', 24 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL/GR /CCL log 9. Test liner lap to 2000 psi. [iaEa To P fo'esaL ; 0. „.6_J4. 4 T'/' /a 10. Perforate liner per asset instructions (-1200') 11. Freeze protect well, RDMO • Post -Rig Work: 1. Re- install wellhouse and flowlines 2. Generic GLV's 3. RU test separator, flow test well 6/17/2010 • 05 -16C Coiled Tubing Drilling Mud Program: • Well kill: 8.6 ppg seawater / brine • • Milling /drilling: 8.6 ppg Power -vis Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. 9 p 9 1 • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.125 ", 11,600' - 13,490' - Casing Program: • 3 -1/2" 9.2 #, L -80, STL solid liner 11,100' MD — 11,550' MD • 2 -7/8" 6.4 #, L -80, STL solid liner 11,550' MD — 13,490' MD • A minimum of 24 bbls of 15.8 ppg cement will be to cement the solid liner (TOC at 11,100') Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. . • The annular preventer will be tested to 250 psi and 2,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line — 36,740' to the Southwest • Distance to nearest well within pool — 710' (05 -23B, north) Anticollision Summary • No anti - collision issues Logging • MWD directional, GR and Resistivity will be run over the lateral portion of the open hole section. • A cased hole GR /CCUCNL log will be run. Hazards • DSO5 is not considered a high -level H pad. Although the maximum recorded level on DS05 is 580ppm (05 -09A, recorded 6/25/98) readings taken around the same time are between 2ppm (05 -15B, 10/29/94) and 12ppm (8/17/98). • Lost circulation risk is high, due to two anticipated fault crossings and proximity to regional graben; take appropriate steps for lost circulation mitigation. Reservoir Pressure • Reservoir pressure is estimated to be 3,260 psi at 8,800'TVDss (7.1 ppg EMW). • Maximum surface pressure with gas (0.10 psi /ft) to surface is 2,380 psi. , Amanda Suddreth CTD Engineer 6/17/2010 WELLHEAD = 4 -1/16" FMC 0 05-1 6 C S SA OTES: WELL ANGLE > 70° @ 11280' ACTUATOR = BAKER C I A COMM. OPERATING PRESSURE OF THE KB. ELEV = 65' Proposed CTD Sidetrack 9 -5/8" & 13 -3/8" ANNULUS MUST NOT EXCEED BF. ELEV = 40.7' 2000 PSI (11/19/02 WAIVER) * ** ***TxIA COMM. KOP = 3150' OPERATING LIMITS: MAX IAP = 2000 PSI, MAX Max Angle = 94 @ 12278' OAP = 1000 PSI (12/04/03 WAIVER) * ** Datum MD = Datum ND = 8800' SS ' ' 2199' H4 -1/2" HES X NIP, ID = 3.813" 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2723' I GAS LIFT MANDRELS �� ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3739 3709 26 MMG DOME RK 16 12/02/08 Minimum ID = 2.30" 11100' 2 7826 6403 48 MMG SO RK 20 12/02/08 3 10318 8187 44 KBG -2L *DMY INT 0 01/03/06 TOL 3-1/2" *EXTENDED PACKING J 8669' IH TOP OF BKR TIEBACK SLV I 8675' H 9 -5/8" X 7" BKR ZXP PKR, ID = 6.313" I 8683' H 9 -5/8" X 7" BKR HMC HGR, ID = 6.250" I PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 83 @ 11700' 9 -5/8" CSG MILLOUT WINDOW 10039' - 10067' (OFF WS) Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 11700 - 11756 0 07/16/03 2 -7/8" 4 11765 - 11790 0 01/29/02 2 -7/8" 4 11780 - 11805 0 05/06/01 2 -7/8" 4 11987 - 12165 0 11/19/99 2 -7/8" 4 12225 - 12961 0 11/19/99 2 -7/8" 4 13004 - 13650 0 11/19/99 2 -7/8" 4 13702 - 13998 0 11/19/99 61, t.. ,.., 1 X 1 1 1 1 .., 111111 111 111 10428' I 7" X 4 -1/2" HES TNT PKR, 11 11 1 11 1111 111 4;, 11:11 ,11 114 4 44, ID = 3.875" 1 111 111 11 1111 1 ' . . 11 1 14 N I% ,'' 11 — 4 -1/2" HES XN NIP, ID milled to 111 1 111 1111111 4, �i 10445' 1111,11 X 1111 1111111 1111 • 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10480' .%.. . . . 1 10450' I� BKR TIEBACK SLV A 10458' H4 -1/2" WLEG I 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 10456' 44, I, 17" X 5" BKR ZXP PKR, ID = 4.375" I--I 10457' I � TOL, TOC 17" X 5" BKR HMC HGR, ID = 4.375" I- 10464' ID = 2.30" 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I- 10615' I 45 TSGR 10615' ` b! - I 11600' H4 -1/2" pkr w hip A 82 C l :- I 3-1/2" X 2 -7/8" liner H 13490' I 1 1550' 1 3 -1 /2 x 2 -7/8 XO I 0' B 4 -1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I 14135' ' *0 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/02/77 ORIGINAL COMPLETION 01/16/06 KSB /PAG TTP PULLED (01 /11/06) WELL: 05 -16' 03/07/87 RWO 12/03/08 RLM/PJC SET CIBP (11/13/08) PERMIT No: 11/18/94 CTD SIDETRACK ( 05 -16A) 12/12/08 GJF /SV GLV C/O (12/02/08) API No: 50- 029 - 20262 -03 11/20/99 SIDETRACK ( 05 -16B) 01/12/09 RDB /SV MILLED CIBP(12/25/08) SEC 32, T11N, R15E, 3367' FSL & 38' FWL 12/26/03 ATD/TLH WAVER SAFETY NOTE 04/28/10 MSE PROPOSED CTD SIDETRACK 03/11/04 DAV/TLH PATCH PULLED /PLUG SET BP Exploration (Alaska) TREE= 4- 1/16" FMC WELLHEAD = FMC SOTES: WELL AN > 70 0 @ 11280' ACTUATOR = BAKER C 05-1 6 * * VI COMM OP PR ES SURE OF THE KB. ELEV = 65' 9 -5/8" & 13 -3/8" ANNULUS MUST NOT EXCEED BF. ELEV = 40.7' 2000 PSI (11/19/02 WAIVER) * ** * * *TxIA COMM. KOP = 3150' OPERATING LIMITS: MAX IAP = 2000 PSI, MAX Max Angle = 94 @ 12278' OAP = 1000 PSI (12/04/03 WAIVER) * ** Datum MD = Datum TVD = 8800' SS ' ' 2199' —14 -1/2" HES X NIP, ID = 3.813" I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2723' GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH FORT DATE 1 3739 3709 26 MMG DOME RK 16 12/02/08 Minimum ID = 3.725" ^ 10445' 2 7826 6403 48 MMG SO RK 20 12/02/08 v 3 10318 8187 44 KBG -2L *DMY INT 0 01/03/06 4 -1/2" HES XN NIP * EXTENDED PACKING J I 8669' H TOP OF BKR TIEBACK SLV I 8675' H 9 -5/8" X 7" BKR ZXP PKR, ID = 6.313" I 8683' H9-5/8" X 7" BKR HMC HGR, ID = 6.250" I I PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 83 @ 11700' 9 -5/8" CSG MILLOUT WINDOW 10039' - 10067' (OFF WS) Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 11700 - 11756 0 07/16/03 2 -7/8" 4 11765 - 11790 0 01/29/02 2 -7/8" 4 11780 - 11805 0 05/06/01 2 -7/8" 4 11987 - 12165 0 11/19/99 2 -7/8" 4 12225 - 12961 0 11/19/99 2 -7/8" 4 13004 - 13650 0 11/19/99 1 fi 2 -7/8" 4 13702 - 13998 0 11/19/99 4W5 NM 11111111111 11111111111 1 1 1 1 1 1 1 1 �0 1 10428' I— 7" X 4 HES TNT PKR, 1 044441044 111 i'1j114 �i ID = 3.875 1111 11 11111 1111 '1 ••■• 1 1 1 1 1 1 1 1.0 1 �e, 10445'1-14-1/2" HES XN NIP, ID = 3.7251 0400 00 1 • •1 1 1: 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 ( / 4 � 1�4 � 4�4 � 1�4 4 4 4 4 4 0 10450' I� BKR TIEBACK SLV I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10480' l E 10458' — I4 - 1/2" WLEG I I4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 10456' I 17" X 5" BKR ZXP PKR, ID = 4.375" H 1045T I 17" X 5" BKR HMC HGR, ID = 4.375" I—I 10464' 14043' — FISH: MILLED CIBP IT LNR, 26 #, L -80, .0383 bpf, ID = 6.276" H 10615' I ` (12/25/08) ilk ` PBTD - 14050' I OW s 14-1/2" LNR, 12.6 #, L -80, .0152 bpf, ID = 3.958" I — I 14135' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/02/77 ORIGINAL COM PLETION 01/16/06 KSB /PAG TTP PULLED (01/11/06) WELL: 05 -16B 03/07/87 RWO 12/03/08 RLM/PJC SET CIBP (11/13/08) PERMIT No: '1991000 11/18/94 CTD SIDETRACK (05 - 16A) 12/12/08 GJF /SV GLV GO (12/02/08) API No: 50- 029 - 20262 -02 11/20/99 RIG SIDETRACK (05 - 16B) 01/12/09 RDB /SV MILLED CIBP (12/25/08) SEC 32, T11 N, R15E, 3367' FSL & 38' FWL 12/26/03 ATD/TLH WAIVER SAFETY NOTE 03/11/04 DAV/TLH PATCH PULLED/PLUG SET BP Exploration (Alaska) BAKER HUGHES INTEQ North America - ALASKA - BP • Prudhoe Bay PB DS 05 05 -16 Plan 5, 05 -16C Plan: Plan 5 BP Coil Tubing Report 04 June, 2010 � bp Mill BPPASSPORT % tiffs BP Coil Tubing Report 0 b . 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 05 -16 Project: Prudhoe Bay TVD Reference: 05 -16B @ 65.00ft (Nabors 7ES) Site: PB DS 05 MD Reference: 05 -16B @ 65.00ft (Nabors 7ES) Well: 05 -16 North Reference: True Wellbore: Plan 5, 05 -16C Survey Calculation Method: Minimum Curvature Design: Plan 5 Database: EDM .16 - Anc Prod - WH24P Survey Tool Program Date 6/4/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 10,000.00 05 -16 Gyrodata (05 -16) GYD -CT -CMS Gyrodata cont.casing m/s 10,025.00 11,305.60 05 -16B GyroData (05 -16B) GYD -CT -CMS Gyrodata cont.casing m/s 11,305.60 11,570.50 3 : MWD - Standard (05 -16B) MWD MWD - Standard 11,570.50 13,490.00 Plan 5 (Plan 5, 05 -16C) MWD MWD - Standard Planned Survey MD Inc Azi TVDSS N/S EM Northing Easting DLeg V. Sec TFace (ft) ( ( (ft) (ft) (ft) (ft) (ft) (1100ft) (ft) ( °) 11,570.50 81.94 358.01 8,700.24 5,813.01 - 1,357.62 5,955,305.28 695,582.42 0.00 1,859.09 0.00 TIP 11,600.00 82.27 357.66 8,704.29 5,842.21 - 1,358.72 5,955,334.44 695,580.55 1.62 1,862.74 -46.44 KOP 11,620.00 81.00 356.37 8,707.20 5,861.97 - 1,359.75 5,955,354.16 695,579.00 9.00 1,865.48 - 135.00 End of 9 Deg /100' DLS 11,650.00 73.67 348.65 8,713.78 5,890.95 - 1,363.53 5,955,383.03 695,574.47 35.00 1,871.78 - 135.00 4 11,700.00 75.49 330.59 8,727.18 5,935.91 - 1,380.27 5,955,427.54 695,556.56 35.00 1,892.36 -86.50 11,750.00 78.66 312.93 8,738.44 5,973.98 - 1,410.33 5,955,464.81 695,525.51 35.00 1,925.63 -81.66 5 11,800.00 81.57 295.41 8,747.09 6,001.50 - 1,450.93 5,955,491.26 695,484.21 35.00 1,968.48 -82.00 11,850.00 85.25 278.18 8,752.87 6,015.77 - 1,498.30 5,955,504.28 695,436.49 35.00 2,016.91 -78.97 6 11,900.00 89.92 261.30 8,754.99 6,015.53 - 1,548.06 5,955,502.74 695,386.75 35.00 2,066.46 -75.00 11,900.87 90.00 261.00 8,754.99 6,015.40 - 1,548.92 5,955,502.58 695,385.90 35.00 2,067.30 -74.28 End of 35 Deg /100' DLS 12,000.00 90.62 272.88 8,754.46 6,010.12 - 1,647.73 5,955,494.72 695,287.26 12.00 2,165.28 87.00 12,050.87 90.93 278.98 8,753.77 6,015.38 - 1,698.30 5,955,498.65 695,236.58 12.00 2,216.11 87.06 8 12,100.00 90.95 273.08 8,752.97 6,020.54 - 1,747.13 5,955,502.53 695,187.63 12.00 2,265.21 -89.75 6/4/2010 12:56:04PM Page 3 COMPASS 2003.16 Build 71 ma-. BPPASSPORT Wins BP Coil Tubing Report 0 bP 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 05 -16 Project: Prudhoe Bay TVD Reference: 05 -16B @ 65.00ft (Nabors 7ES) Site: PB DS 05 MD Reference: 05 -16B @ 65.00ft (Nabors 7ES) Well: 05 -16 North Reference: True Wellbore: Plan 5, 05 -16C Survey Calculation Method: Minimum Curvature Design: Plan 5 Database: EDM .16 - Anc Prod - WH24P Planned Survey MD Inc Azi TVDSS N/S EN! Northing Easting DLeg V. Sec TFace (ft) ( ( (ft) (ft) (ft) (ft) (ft) ( 1100ft) (ft) ( °) 12,200.00 90.96 261.08 8,751.30 6,015.46 - 1,846.80 5,955,494.85 695,088.13 12.00 2,364.06 -89.85 12,300.00 90.93 249.08 8,749.65 5,989.77 - 1,943.24 5,955,466.64 694,992.40 12.00 2,457.89 - 90.050 12,300.87 90.93 248.98 8,749.63 5,989.46 - 1,944.05 5,955,466.31 694,991.60 12.00 2,458.67 -90.25 9 12,400.00 90.91 260.88 8,748.04 5,963.73 - 2,039.59 5,955,438.09 694,896.77 12.00 2,551.60 90.00 12,500.00 90.85 272.88 8,746.50 5,958.29 - 2,139.25 5,955,430.04 694,797.30 12.00 2,650.41 90.19 12,600.00 90.75 284.88 8,745.10 5,973.69 - 2,237.86 5,955,442.85 694,698.32 12.00 2,749.99 90.38 12,600.87 90.75 284.98 8,745.09 5,973.91 - 2,238.70 5,955,443.05 694,697.48 12.00 2,750.84 90.54 10 12,700.00 90.73 296.88 8,743.80 6,009.26 - 2,331.12 5,955,475.97 694,604.17 12.00 2,845.99 90.00 12,700.87 90.73 296.98 8,743.79 6,009.65 - 2,331.89 5,955,476.34 694,603.39 12.00 2,846.79 90.15 11 12,800.00 90.72 285.09 8,742.53 6,045.17 - 2,424.24 5,955,509.42 694,510.14 12.00 2,941.89 -90.00 12,900.00 90.67 273.08 8,741.31 6,060.93 - 2,522.80 5,955,522.59 694,411.21 12.00 3,041.45 -90.15 12,950.87 90.64 266.98 8,740.73 6,060.95 - 2,573.64 5,955,521.29 694,360.39 12.00 3,092.09 -90.30 12 13,000.00 90.63 272.88 8,740.19 6,060.89 - 2,622.75 5,955,519.94 694,311.30 12.00 3,141.01 90.00 13,100.00 90.60 284.88 8,739.10 6,076.30 - 2,721.37 5,955,532.76 694,212.32 12.00 3,240.59 90.07 13,200.00 90.55 296.88 8,738.09 6,111.87 - 2,814.62 5,955,565.87 694,118.17 12.00 3,336.60 90.20 13,220.87 90.54 299.38 8,737.89 6,121.70 - 2,833.02 5,955,575.22 694,099.52 12.00 3,355.78 90.32 13 13,300.00 90.53 289.89 8,737.15 6,154.65 - 2,904.87 5,955,606.28 694,026.84 12.00 3,430.23 -90.00 13,400.00 90.50 277.88 8,736.25 6,178.60 - 3,001.77 5,955,627.68 693,929.36 12.00 3,528.84 -90.09 13,490.00 90.45 267.08 8,735.50 6,182.50 - 3,091.54 5,955,629.23 693,839.52 12.00 3,618.62 -90.20 TD at 13490.00 6/4/2010 12:56:04PM Page 4 COMPASS 2003.16 Build 71 Project: Prudhoe Bay A Ma 2, lh gnetic Nenh: 22 Tme NOnh 28 WELLBORE DETAILS: Plan 5, 05-16C REFERENCE INFORMATION 11111111 0 13 Site: PB DS 05 Coodinate(NIE) Reference: We1105- 16, True Narlh IllUCIER P Well: 05 - 16 Strer Magnetic 8.43 Parent Wellbore: 05 Verliral(ND)Reference : Mean Sea Level Wellbore: Plan 5, 05 - 160 OpAngle eo_sa Tie on MD: 11570.50 580I0O (VS/Reference: Slot- (0.00N, O.WE) M �N P lan: Plans 05 /Plan 5, 05 - 160 Dale. 0412010 M adeI:BGGM200E Measured Depth Reference: 05 -160 ©65.coE(Nabors 7ES) Calculation Method: Minimum Curvature IN Q ■ 6900 - _ I 1[ WELL DETAILS: 05-16 6750 Ground Level: 0.00 +N /-S *E / -W Northing Easting Latinude Longitude Slot 05- 1645-16B 05- 16/05 -16A 0.00 0.00 5949530.13 697091.68 70° 15' 58.647 N 148° 24' 22.462 W SECTION DETAILS ANNOTATIONS 6450 g--- i 05 16/Plan 5, 45 - 16C Sec MD Inc Azi ssTVD +N / -S +E / -W DLeg Tface VSec 631' . 1 TD 01349( 00 1 11570.50 81.94 358.01 8700.24 5813.01 - 1357.62 0.00 0.00 1859.09 TIP Edof35 eg/100'DLS 2 11600.00 8227 357.66 8704.29 5842.21 - 1358.72 1.62 -46.44 1862.74 KOP �l t �� _ 3 11620.00 81.00 356.37 8707.20 5861.97 - 1359.75 9.00 225.00 1865.48 End of 9 Deg /100' DLS q t 1 ■�� 4 11650.00 73.67 348.65 8713.78 5890.95 -1363.53 35.00 225.00 1871.78 4 '� �` , 10 9 ` 5 5 11750.00 78.66 312.93 8738.44 5973.98 - 1410.33 35.00 273.50 1925.63 5 0 6 11850.00 8525 278.18 8752.87 6015.77 -1498.30 35.00 278.00 2016.91 6 h 05 16C 111111.1w 4 r 05.16/5.6 7 11900.87 90.00 261.00 8754.99 6015.40 - 1548.92 35.00 285.00 2067.30 End of 35 Deg/100' DLS 7...."5850 n11111111 - KOP 8 12050.87 90.93 278.98 8753.77 6015.38 - 1698.30 12.00 87.00 2216.11 8 ill } : 5 - 16C f3.2 05 I6CT31 9 12300.87 90.93 248.98 8749.63 5989.46 - 1944.05 12.00 270.25 2458.67 957aD 'TIP 10 12600.87 90.75 284.98 8745.09 5973.91 - 2238.70 12.00 90.00 2750.84 10 Eedof9Deg100DLS 11 12700.87 90.73 296.98 8743.79 6009.65 - 2331.89 12.00 90.00 2846.79 11 0 12 12950.87 90.64 266.98 8740.73 6060.95 - 2573.64 12.00 270.00 3092.09 12 5550 13 13220.87 90.54 299.38 8737.89 6121.70 - 2833.02 12.00 90.00 3355.78 13 14 13490.00 90.45 267.08 8735.50 6182.50 - 3091.54 12.00 270.00 3618.62 TD at 13490 .' 1 \ -, 0 Ch 5250-- 5100 4950 4800 -3600 -3450 -3300 -3150 -3000 -2850 -2700 -2550 -2400 -2250 -2100 -1950 -1800 -1650 -1500 -1350 -1200 -1050 -900 West( - )/East( +) (150 ft/in) 8500. \ 8550 8600 4- • 8650. VC/1 05- 165-168 I , End ef9DeE /100'DS 05-16CTargt t 3 `■ 6700 - la-16C T). I 05- 16CT32 1 1 N 875 / ; � - I t • _. _. Q 5 `\ 8 10 11 12 13 - (t5- 16 /r' -1.' 6 ' 9 U • 8800_ End af35D:g/I00'JLS 05.16/Plar 5,05 -16C 1 05-1605-16 > _ • 8850 TJar13 6) a 8900 F 8950 .' J 9000 t0 N to 9050 .. a 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 3350 3400 3450 3500 3550 3600 3650 m Vertical Section at 275.00° (50 ft/in) Project: Prudhoe Bay x�rbrm. zz WELLBORE DETAILS: Plan 5, 05-16C REFERENCEINFOl2M4TI0N ��■ Site: PB DS 05 Coordinate INIE) Reference: Well 00 -16, True North Mag 7 6 6 rl ltl Parent Wel bore: 11570 BAKER GHES Well: 05-16 shag1 51�eAS1T Te on MD: 11570.50 Ves TVD)Ref 0516B@65.0008rtors7ES) Wellbore: Plan 5, 05-16C DE hoo e. Seceon(V Refe Slot 1000N,000E) Plan: Plan 5(05 5, 05.160) N1odae Measured Depth Reference. 05168 @ 65.00R (Nabors 7ES) CalcWation Method: M:oreunCONaW2 1NTEQ 691 1■■■■■■■■ ■■■■■■■■■■■■,.l.■■■■■■■■PIiu�:■1 6825 6750 I : j II - I 7 ■■■I • 6371 ii•u■■■■■ MIMEI■■■■■■■■■■■.,■■■■.'■■.■■I 6311,1■■■.■■! l.]! i� C• 3111 aJ1 ..��.■■■■■■■■■■■■.■ _ 6225, .■■■■��■■■_■_..■.■■.■■■..■■, _'.■■■■I 6111111111111111111 ^6075 O 1. i'll11111111•1111111MENOMMIIIIIIIIIIMIIMMEINMIIIIN1111921,1■■•■„"•■ �� ,�E�111 ■■ •■1 1. ■11UiauI ■UU uI •IL ■U•lIUiiE..AII■Ii■■IN1 571 1uii•u•iu■■ ■ ►�■uu■��■u ■u ■ri ■u ■� uiu•i ■ ■I 5625 , E i 5 Stn 5025 168 65: A 9I l Ii i i IlIlIIIllIIIIIIIIlIlilIlIII 951 ��r_��R r_ -36 00 -3525 -3450 -3375 -3300 .- 3125 -3150 - 305:: 411 -2925 -2850 -2775 -2700 -2625 -2550 -2475 -2400 -2325 -2250 -2175 -2100 -2025 -1950 -1875 -1800 -1725 -1650 -1575 -1500 -1425 -1350 -1275 -1200 -1125 -1050 -975 -900 -825 West( - )/East( +) (75 Win) WWI • BPPASSPORT • BAKER HUGHES Travelling Cylinder Report 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 05 -16 Project Prudhoe Bay TVD Reference: 05 -16B @ 65.00ft (Nabors 7ES) Reference Site: PB DS 05 MD Reference: 05 -16B @ 65.00ft (Nabors 7ES) Site Error: 0.00ft North Reference: True Reference Well: 05 -16 Survey Calculation Method: Minimum Curvature I Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 5, 05 -16C Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan 5 Offset TVD Reference: Offset Datum Reference Plan 5 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 11,570.50 to 13,490.87ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,545.99ft Error Surface: Elliptical Conic Survey Tool Program Date 6/16/2010 From To (ft) (ft) Survey (Welibore) Tool Name Description 100.00 10,000.00 05 -16 Gyrodata (05 -16) GYD -CT -CMS Gyrodata cont.casing m/s 10,025.00 11,305.60 05 -16B GyroData (05 -16B) GYD -CT -CMS Gyrodata cont.casing m/s 11,305.60 11,570.50 3 : MWD - Standard (05 -16B) MWD MWD - Standard 11,570.50 13,490.00 Plan 5 (Plan 5, 05 -16C) MWD MWD - Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter 1 (ft) (ft) Name (in) (in) 13,490.00 8,800.50 2 7/8" 2.875 4.125 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Welibore - Design (ft) (ft) (ft) (ft) PB DS 05 05 -16 - 05 -16 - 05 -16 11,586.62 11,525.00 93.38 12.74 81.49 Pass - Major Risk 05 -16 - 05 -16A - 05 -16A 11,587.18 11,525.00 93.21 13.01 84.75 Pass - Major Risk 05 -16 - 05 -16B - 05 -16B 11,600.00 11,600.00 0.00 2.09 -1.71 FAIL - Major Risk 05 -28 - 05 -28A - 05 -28A 11,635.26 11,975.00 771.59 276.52 495.32 Pass - Major Risk 05 -28 - 05 -28A - Plan #3 11,594.23 11,825.00 880.90 271.86 609.51 Pass - Major Risk 05 -28 - 05- 28APB1 - 05- 28APB1 11,625.88 11,900.00 878.65 275.50 603.76 Pass - Major Risk 05 -28 - 05 -28B - 05 -28B 11,750.00 12,875.00 1,063.23 223.98 839.39 Pass - Major Risk 05 -28 - 05- 28BPB1 - 05- 28BPB1 11,704.76 12,451.00 1,236.63 227.24 1,009.41 Pass - Major Risk 05 -31 - 05 -31 - 05 -31 Out of range 05 -31 - 05 -31A - 05 -31A Out of range 05 -31 - Plan 05 -31 B - Plan #5 05 -31 B Out of range 05 -35 - 05 -35 - 05 -35 Out of range 05 -35 - 05 -35A - 05 -35A Out of range 05 -36 - 05 -36 - 05 -36 Out of range 05 -36 - 05 -36A - 05 -36A Out of range 05 -36 - 05- 36APB1 - 05- 36APB1 Out of range PB DS 18 18 -11 - 18 -11A- 18 -11A 13,159.83 11,825.00 1,304.58 234.31 1,084.68 Pass - Major Risk 18 -14 - 18 -14A - 18 -14A 13,475.00 11,035.00 1,176.19 192.36 983.95 Pass - Major Risk 18 -14 - 18- 14APB1 - 18- 14APB1 13,450.00 10,850.00 1,380.83 198.47 1,182.67 Pass - Major Risk 18 -14 - 18 -14C - 18 -14C 13,325.00 12,960.00 1,297.88 262.73 1,035.11 Pass - Major Risk 18 -22 - 18 -22 - 18 -22 12,200.00 11,854.00 838.08 182.03 656.12 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 6/16/2010 4:00:23PM Page 2 of 18 COMPASS 2003.16 Build 71 05 -16C Coiled Tubing Drilling All Measurements are from top of Riser 6/15/2010 0 () CC 05 -16C top of bag -� BAG bttm of bag middle of blind /shears I Blind /Shears TOTs middle of pipe slips 2 3/8" combi pipe/slips I I.. I I middle of flow cross Mud Cross Mud Cross 1 I I 2 3/8" x 3-1/2" VBRs '' middle of rams " "•. TOTs 2 3/8" combi pipe /slips middle of pipe/slips I, I I 16wab Valve 7 11.1111 7 11111° Flow Tee 6/17/2010 • 1 TRANSMITTAL LETTER CHECKLIST WELL NAME /2fi./ PTD# ✓ Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: ,44/26 POOL: �l,/./doe:27 t/ ©/ Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - . API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(0, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Alaska Department of Naturaltources Land Administration System • Page 1 of 2 Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources I Alaska DNR Case Summary File Type: ADL File Number: 28326 Printable Case File Summary See Township, Range, Section and Acreage? New search C) Yes 0 No LAS Menu 1 Case Abstract 1 Case Detail 1 Land Abstract File: ADL 28326 mac Search for Status Plat Updates As of 06/25/2010 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2491.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 015E Section: 29 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 015E Section: 30 Section Acres: 604 Meridian: U Township: 011N Range: 015E Section: 31 Section Acres: 607 Meridian: U Township: O11N Range: 015E Section: 32 Section Acres: 640 Legal Description 05 -28 -1965 * * *SALE NOTICE LEGAL DESCRIPTION* * * C14-156 T11N-R15E-UM 29,30,31,32 2491.00 U- 3- 7 End of Case Summary Last updated on 06/25/2010. http: / /dnr. alaska.gov /projects /las /Case_ Summary.cfin ?FileType= ADL &FileNumber = 2832... 6/25/2010 ` , I '°*` ' Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 *' ;� ., , : k ,_ Well Name: PRUDHOE BAY UNIT 05-16C Program DEV __. Well bore seg PTD#: 2100840 Company BP EXPLORATION (ALASKA) INC - _ Initial Class /Type DEV./ PEND GeoArea 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 1 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 1 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes 4DS 6/25/2010 - ' 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For NA 1 15 All wells within 1/4 mile area of review identified (For service well only) NA 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) NA 117 Nonconven. gas conforms to AS31.05.030(y1.A),(j.2.A -D) NA 18 Conductor string provided NA Conductor set in DS 5 -15B Engineering 19 Surface casing protects all known USDWs NA Surface casing set in DS 5 -16B 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing cemented in DS 5-16B 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in DS 5-16B 22 CMT will cover all known productive horizons Yes Cemented and perfed Liner is planned. 23 Casing designs adequate for C, T, B & permafrost Yes 1 24 Adequate tankage or reserve pit Yes Rig equipped with steel pits. All waste to approved disposal wells. 25 If a re- drill, has a 10 -403 for abandonment been approved Yes 310 -194 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Well path departs away from motherbore. 27 If diverter required, does it meet regulations NA Wellhead in place. BOP to be placed on top of production tree. Appr Date 28 _ Drilling fluid program schematic & equip list adequate Yes Max Formation pressure = 3260 psi ( 7.1 ppg) Will Drill with 8.6 ppg mud LS 7/1/201 '29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2380 psi will test BOP to 3500 psi 31 Choke manifold complies w /API RP -53 (May 84)_ Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S present at DS 5... Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) NA --- ------ - - - - -- 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S on pad DS05 was 580ppm on well 05 -09A (6/25/98) Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 6/25/2010 38 Seabed condition survey (if off - shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Commissioner: Date: Co�ner: Date Commissioner Date -4.. 7 -6-10