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208-091
• STATE OF ALASKA • tom~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0 C T 0 9 7 o l i 1. Operations Performed yy�, Abandon 0 Plug Perforations 0 Fracture Stimulate 0 C Pull Tubing ❑ OperatiotfS'� C ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change App.�ro-vved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other Set(Patchb t el, / 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-091 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number 50-029-20766-01-00 7. Property Designation(Lease Number): ADL 0028308 8. Well Name and Number. PBU 02-25A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 11728 feet Plugs measured 9988/10890 feet true vertical 9041 feet Junk measured feet Effective Depth: measured 9988 feet Packer measured 8660 feet true vertical 9017 feet Packer true vertical 8086 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 31-111 31-111 1490 470 Surface 2627 13-3/8"72#L-80 31-2658 31-2658 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9040-9060 feet feet 9060-9070 feet 10055-10085 feet 10200-10510 feet 10550-10810 feet 11020-11330 feet 11470-11640 feet True vertical depth: 8443-8462 feet feet 8462-8471 feet 9039-9046 feet 9053-9039 feet 9038-9036 feet 9043-9046 feet 9047-9045 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2'Baker Hydro Set Packer 8660 8086 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED NOV 2 8 2017, Treatment descriptions including volumes used and final pressure: 13. , Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 229 22336 31 880 799 Subsequent to operation: Shut-In 380 150 14.Attachments:(required per20 MC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Stone,Christopher Contact Name: Stone,Christopher Authorized Title: D>S. &18 PE ]]]] / Contact Email: Christopher.Stone@bp.com Authorized Signature: �/ Date: fo11/(n. Contact Phone: +1 907 564 5518 Form 10-404 Revised 04/2017 Z //7 ( (, �!!! Vn— I / 1-119' RE LL/ G u Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary October 9, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Adding of Perforations and Setting a Patch for Well 02-25A, PTD # 208-091. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. 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H : a- O_: (A J : « d (A J J a a CA J « H « o o f a E o. a•E i) -0 E. � � N. 0 0 0 0 N N N 0 _N _N 0 0 a) 0 0 0 O • N C E L 7 Q a a co f-- O I 2 N N w O O M • CO o a a a� CC ca y 0 c m a� 2 a) (I) v 2 OccooO m M N Nd TREE= 5-1/8"FMC • WELLHEAD= FtiC 02-25A 2_25A SAFETY NOTES:BAL&CONTROL UNE IN COMM wAA ACTUATOR= BAKER (08/15/}6)'•'WELL ANGLE>70°@ 10034'."` KB ELEV= 64' I BF.ELEV= KOP= 3200' CM 2167' H5-1/2'CAMCO BAL-O SSSV NP,D=4.562" Max Angle= 97"©1019T 20" 13(6 Datum MD= 9 fi09' . 91.5#,H 40, GAS LFT MANDRELS D3tumTVD= 88000'SSS D=19.124" TV ST MD D DEV TYPE VLV LATCH PORT CATE 1 2895 2895 5 MIG Otis' RK 0 08/05/17 13-3/8"CSG,72#,L-80 BTC,D=12.347" --J 2660' 2 4965 4810 26 MIG DMY RK 0 08/05/17 Minimum ID=2.30" 8640' 3 6446 6109 30 MM3 DMY RK 0 07/12/82 4 7494 7021 27 /AUG DMY RK 0 07/12/82 BTT DEPLOYMENT SLY PROFILE 5 8156 7620 24 MIG DMY RK 0 07/12/82 6 8233 7690 24 MMG DMY RK 0 07/02/16 5-1/2-BKR FLO GUARD PAT<7i �— 8180'-$212' 0 0 7 8543 7976 21 MIG DMY RK 0 07/12/82 D=2.40"(09/04/17) • � 8 8619 8047 20 MUG DMY RKID 0 47/12/82 I 8628_--14-1/2"SCOOP GUDE,D=2.37"(11/20/15) $632'J--I3-1/2"BKR DEPLOY SLV,D=3.000" I 8640' H BTT SELRT AL PROF,(NULLED TO 2.30"(XX/XX/XX) I lid kg 1 04 5-1/2"1BG,17#,L-80 8RD ABMOD, H 8646' I.— 1 «'`-4 8646' H5-1/2"BKR PBR ASSY 06 .0232 bpf,ID=4.892" 4 v�b; �- 8662' 9518"X 7"BKR SAB PKR,D=4.865" N. V - 1 8666' -17"1,41.1011T ERCT,D= .11 8673' --17'X 4-1/2"XO,D=3.958" i 8682' H3-1/2"hES x fa,D=2.813" 3-1/2"LNR 9.2#,L-80 STL,.0087 bpf,D H=2.992" 8716' g p% 8716' H3-1'2"X 3-3/16"XO,D=2.786" TOP OF T LNR H 8716' `.# 1 `' 8734' H4-1/2'CAM DB-6 LANDING NP,ID=3.813" A ISA 8745' —4-1/2"BKR SHEARouT sw I 4-12'TBG PC,12.6#,N-80, —I 8746' ..--t.,� 1.A ' 8746' H4-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" ►�` 1►'4 1.14,' 111.16,'- 8733' -I EL I D TT LOGGED 01/30/83 9-5/8'CSG,47#,L-80,D=8.681' --I 8996' ►''tif VII.' ME lb1MLLOUT YITDOW (05-25A) 9197'-9201' TOP OF WHIPSTOCK(07/21/08) — 9192' Imoi I I RA TAG H 9203' N. '. , �►' �4R� �� -{FISH UN-1'PES GDEBRIS(04/27/17) 7"LM,2911,L-80 BTC,.0371 bpf,ID=6.184" —I 9816' *.%i�.�,\ di, ( 9988' H EXTENDED RANGE YVFD CEP(11/19/16) I PERFORATION SUMMARY ee i`` 1 442 . 4.40. � 10474' -13 3/16'X 2-7/8"XO,D=2.370" •A AA NA •,0 4 REF LOG:MCNJGRLCCL OF 08/23/08 �N.* .ti ? —FISH:KEYS FR DB LOCK ANGLE AT TOP PERF: 20° 9040' �� `� . &DOGS OFF COLLET t bte:Refer to Production OB for historical perf data �,4� �y (06/08/10) SIZE SPF INTERVAL Opn/Sgz SHOT SQZ V CAN-ANNA" d ` '♦�i 10890' 2-7/8"BKR CEP 1.69" 7.5 9040-9070 0 04/27/17 ' ` 2" 6 10055-10085 C 02/20/16 3-3/16"LNR,6.2#,L-80 TCII, 10474' ♦ .♦,."�' (1121/15} 2" 6 10200-10510 C 08/24/09 .0076 bpf,D=2.80" f 44 2" 6 10550-10810 C 08/24/09 •‘i 444; 2" 6 11020-11330 C 08/24/09 PBTD H 11640' A . 2' 6 11470-11640 C 08/24/09 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,ID=2.441" H 11668' DATE REV BY COMMENTS DATE REV BY COMENTS PRUDHOE BAY WIT 7112/82 tOWAN 3 ORIGINAL COMPLETION 10/24/16 JR/JM3 PULLED DSSSV&EVOTRIEVE WELL: 02-25A 8/25/08 NORM 1 CTD SIDETRACK(02-25A) 11/08/16 CJWJMD GLV C/O(11/05/16) PERMT'No:"2080910 02/22/16 SRLYJM)ADPERFS(02/20/16) 1128/16 GJB/JMD SET EXT RANGE CBP(11/19/16) AR No: 50-029-20766-01 03/02/16 SW/JMD SET DSSSV(11/20/15) 05/01/17 MS/JMD ADFERFS&FISH(04/27/17) SEC 36,T11N,R14E,15'FWL&1681'FN- 07/07/16 JMfWJMD DSSSV GO&GLV GO(07/01-02/1E 08/07/17 fGS/JM I GLV GO(08/05/17) 09/13/16 JMMYJM3 SET EVOTREVE PLUG(06/30/16) 09/06/17 NXW/JIC SET FLO-GUARD PATCH(09/04/17) BP Exploration(Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, October 3, 2017 1:02 PM To: AK, OPS EOC Specialists;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Dean,James A; G GPB FS1 Drillsites; Stone, Christopher; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua; Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer 02-25A(PTD#2080910)Well barriers restored with tubing patch All, Producer 02-25A(PTD#2080910)was made not operable on 7/3/2016 after Slickline ran a memory acoustic leak detection log on 7/2/16 and found tubing by inner annulus communication through a hole in the production tubing at 8,193' MD. On 09/4/17 Electric Line set a patch over the leak. On 09/30/17 fullbore performed a passing MIT-IA to 2,727psi.The passing MIT-IA confirms the integrity of the primary and secondary well barriers. At this time the well is reclassified as Operable. Please mind fluid packed annuli when bringing the well online. Please respond with any questions, Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska SCANNED Office:907-659-8110 Cell:307-399-3816 Fro K, GWO Well Integrity Well Information Sent: Fri.. November 18, 2016 3:44 PM To: AK, GWO •• Well Integrity; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AKOpsPro• •CTL; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; Cismoski, Doug A; AK, RES GPB West Wells Opt Engr; AK, • GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; G GPB FS1 Drillsites; •z t•aard, Finn; AK, OPS FS1 DS1 Operator; Stone, Christopher Cc: AK, GWO DHD Well Integrity; AK, • Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; McVey, Adrienne; 'Regg, James B (DOA) (jim.regg@alaska.gov) lj.•s.regg@alaska.gov); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, '- ; Sternicki, Oliver R; Tempel,Troy; Worthington, Aras J; 'chris.wallace@alaska.gov'; Odom, Kristine; Worthington, Je ' a; Dickerman, Eric; Daniel, Ryan Subject: NOT OPERERABLE: Producer 02-25A(PTD #2080910) • for Economic Evaluation All, Producer 02-25A(PTD#2080910)well testing is complete. Economic evaluation of well t conducted indicate that restoring tubing integrity is not competitive at this time.The well is now reclassified as Not Op ble and will remain shut in until tubing integrity is restored. 1 �\ • ! Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Thursday,April 27, 2017 3:04 PM To: Wallace, Chris D (DOA) Subject: DS 02-25 - Request to place well Under Evaluation Attachments: 02-25A.pdf; DS 02-25 CIBP CMIT test -well service report.pdf Chris; BP would like to put producer 02-25 (PTD 2080910),Under Evaluation for 28 days and flow the well for economic evaluation. The wells current perforations have been isolated by a CIBP, set at 9988ft on 11/19/2016 and tested with a passing combination mechanical integrity test(CMIT)on 11/20/2016. Please see the attached wellbore schematic and the well service report for the CIBP CMIT testing. Recently as of today,the well is being perforated in the Sag River. The wells current type, is a natural flow well(capable of unassisted flow)and also has tubing by inner annulus communication. As such, I need your approval from the AOGCC prior to putting the well Under Evaluation and allowing the well to be monitored while being flowed. Thanks Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 {WED JUN 2320w%, • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, October 23, 2016 11:51 AM To: AK, GWO SUPT Well Integrity;AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AKOpsProdEOCTL;AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; Cismoski, Doug A;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn;AK, OPS FS1 DS1 Operator; Stone, Christopher Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey,Adrienne; Regg,James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;Wallace, Chris D (DOA); Odom, Kristine; Worthington,Jessica; Dickerman, Eric;AK, GWO Well Integrity Well Information; Daniel, Ryan Subject: UNDER EVALUATION: Producer 02-25A(PTD#2080910) POP for Economic Evaluation All, Producer 02-25A(PTD#2080910)was a secured Not Operable well with TxIA communication through a connection leak at 8193'. The well was secured with a plug and passed a CMIT-TxIA to 2500 psi on 07/01/2016, demonstrating competent production casing and packer. Subsequent to securing, Drill Site 2 installed a new well testing kit. Slickline pulled the plug on 10/20/16 for a well test. The plan forward for this well is to POP as Under Evaluation to evaluate economics of a tubing patch to mitigate TxIA communication. This well is now classified as Under Evaluation. Plan forward: 1. Slickline: Pull Plug—Done 10/20/16 2. Well Integrity: Classify as Under Evaluation—Done 10/23/16 3. Operations: POP for economic evaluation 4. APE: Determine secure or patch repair Thanks, Jack Lau SCANNED MAY I ft2'1'I (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W:907.659.5102 C: 907.943.0296 H:x2376 From: AK, I SUPT Well Integrity Sent: Sunday, July I , 116 6:05 AM To: AK, OPS FS1 OSM; AK, •• Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AKOpsProdEOCTL; AK, GWO SUPT Special Projects; AK, G '• • Slickline; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS El -cialists; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; G 1 WELL LOG TRANSMITTAL '2-7 so.11c II, EC DATA LOGGED PROACTIVE DIACINOSTIC SERVICES, INC. ti► ■ E �D ?/21/201�p p 2 K BENDER JUL" 2016 To: AOGCC 4Ci .:1 Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 NOV ��� gancpdc(a)bp.com SC014 and ProActive Diagnostic Services, Inc. Attn: Diane F.Williams 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) LeakPointTM Survey 01-Jul-16 02-25A BL/CD 50-029-20766-01 2) Signed : 11/),,dza.47.0„,"/P) � Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(CIIMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D.\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BP Transmit.docx • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,July 03, 2016 6:05 AM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OIL;AK, OPS FS1 Field OIL;AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC IL;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;G GPB FS1 Drillsites;Oestgaard, Finn;AK,OPS FS1 DS1 Operator; Stone, Christopher Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey,Adrienne; Regg,James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;Wallace, Chris D (DOA); Odom, Kristine; Sayers, Jessica; Dickerman, Eric;AK, GWO SUPT Well Integrity Subject: NOT OPERABLE: Producer 02-25A (PTD#2080910)Well Secured All, Producer 02-25A(PTD#2080910) has been secured with a tubing tail plug and passing CMIT-tubing x inner annulus confirms two well barrier envelopes.The well is now reclassified as Not Operable until tubing integrity is restored. Ryan Holt Well Integrity—GWO Alaska (Alternate:Lee Grey) 0: (907)659-5102 SCANNED DEC 0 9 2 16 H: 2376 Email: AKDCWelllntegritvCoordinatort BP.com From: D&C Well Integrity Coordinator Sent: Tuesd- une 21, 2016 2:15 PM To: AK, OPS FS1 • • AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services a•-rations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; B FS1 Drillsites; Oestgaard, Finn; AK, OPS FS1 DS1 Operator; Stone, Christopher Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Proj- Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, Adrienne; 'Regg, ••-s B (DOA) (jim.regg@>alaska.gov)' (jim.recigOalaska.gov); Hibbert, Michael; Janowski, Carrie; Montgom- • Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy; Worthington, Aras J; 'c .wallace@alaska.gov'; Odom, Kristine; Sayers, Jessica; Dickerman, Eric Subject: UNDER EVALUATION: Producer 02-25A (PTD #2080910)TIFL Failed All, Producer 02-25A(PTD#2080910)was reported to have sustained IA casing pressure above MOASP on 0• 7/2016. Pressures were confirmed to be TBG/IA/OA=2400/2180/200.A cold TIFL failed on 06/18/16,and a warm TI .iled on 06/21/16.The well is reclassified as Under Evaluation for further diagnostics. 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday,June 21, 2016 2:15 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS PCC EOC IL;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn;AK, OPS FS1 DS1 Operator; Stone, Christopher Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep;AK, D&C Well Integrity Coordinator; McVey,Adrienne; Regg,James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy; Worthington,Aras J;Wallace, Chris D (DOA); Odom, Kristine; Sayers,Jessica; Dickerman, Eric Subject: UNDER EVALUATION: Producer 02-25A(PTD#2080910)TIFL Failed All, Producer 02-25A(PTD#2080910)was reported to have sustained IA casing pressure above MOASP on 06/17/2016. Pressures were confirmed to be TBG/IA/OA=2400/2180/200.A cold TIFL failed on 06/18/16, and a warm TIFL failed on 06/21/16.The well is reclassified as Under Evaluation for further diagnostics. Plan forward: 1. Slickline:Set Dummy GLV's, MIT-IA 2. Fullbore:Assist Slickline- MIT-IA 3. Well Integrity Engineer: Additional diagnostics as needed Please reply if in conflict with proposed plan. Thanks, Adrienne McVey SCANNED JAN 0 4/01? Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0: (907) 659-5102 C: (907)943-0296 H: 2376 Email: AKDCWellIntegrityCoordinator@BP.com 1 STATE OF ALASKA eLASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate Q Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-091 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20766-01-00 7. Property Designation(Lease Number): ADL 0028308 8. Well Name and Number: PBU 02-25A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: = Pm Total Depth: measured 11728 feet Plugs measured 10890 feet true vertical 9041 feet Junk measured feet MAR 21 2016 Effective Depth: measured 10890 feet Packer measured 8660 feet �O+(�,r1;` (C` true vertical 9038 feet Packer true vertical 8086 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 31 -111 31-111 1490 470 Surface 2627 13-3/8"72#L-80 31 -2658 31 -2658 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10055-10085 feet 10200-10510 feet 10550-10810 feet 11020-11330 feet 11470-11640 feet True vertical depth: 9039-9046 feet feet 9053-9039 feet 9038-9036 feet 9043-9046 feet 9047-9045 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"Baker Hydro Set Packer 8660 8086 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: F,Pe7 2016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 39 25189 1 320 791 Subsequent to operation: 149 23496 15 900 833 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature C - -5 Phone +19075644424 Date 3/21/16 Form 10-404 Revised 5/2015 Vii-- 4 PZ/I V MAR Z 2 2016 y/y/`/ RBDMS V Submit Original Only • • • to O O O OO O O CO CO L0N CO O d CO Y` O O M N CC) O N •CY LO N- CO 1"-- 11) 1) 0 0 0 0 0O O O O C) CO r` Cfl O CONr 7 V C) CO CO co O O CO CO N O t ( "Cr Cn O O N. CO O) .Cr V C5) CO O CC) N CO CO CO CO CA 0) CO CO F- O O CO CO CO O CO CA O) CO N- CO CO V CO O) CO CO N CC) 0 0 v- O N O N- CO CO CO CO CO 0) CO Nr •cr CON- M O N CA O N- V CO (O N- N cO CO CO CO ()) CO CO V 4-0 Q i 1 1 1 1 1 1 1 1 1 1 Q csi _ N '- () Cf) r Cr) CO LC) r (O N NM N CD CO COCOO CO CO O N CO W a ©1- 7coCID CO CO 0 --10 -1 CO J J J ()° 4:k J J J z C = ° 4 * N *k (I) J N Cfl 4$ (fl N 4:kN 0) r CO CO _ N U OMtoco � N � � � � N N co 6) U) A M O CO A N . r O V Ln O N O) O 0) V CC) CO V N C CO CO O C° O CO N- '- CO N- J N CO CO W p)0 - - cF- W ❑ ❑ .- W 00u_ l ( c Z Z zWWWWWmm O J H H Z Z z z z D D O U) Z Z J J J J F- F- 0 • _oo o 6 \ - = co _ ± \ c \ ) 7\ \ c \ \ 0t0 / / E2 r-0 Q C o ° P - Cl.) = Ti)' c U _ / k \ 0 / § _ = n2 2 o E 7 $ / Ea \ co E > C \ sa _ / E E D o § k \ / 0 S 2 < _ 2 \ - B 0O / / $ x) I Cl, c 2 b 2 T 0 o e e a. o >- / / ƒ $ \ co E CU < $ CC E -0 o E o " 2 E E > f c D CL 0 0 2 Cr) » 0 c R 1 \ 0_ t § \ 2 a \ -0 6 __ 0 6- = o 0 5 / ) 7 / _5 _ G e f a m q ± © a \ 3 - o £ o f 0 co - ee & ± co f = 0 / / � o § \ \ w f % o 75 k 0 :a _ .0 I _ m .= - 7 CO e ® = e : - co ± 0 / So / - / 0 / IE % c / ® § / 6-± CC Ce c\Jtea) E,- Oa - = E as.- ® I— 0 / / 2 / � / / \/ / �– c - % a CL § \ -0 G ƒ -0_ / k ƒ _ ƒ \ -/ / / e \ m 0 CC '- / E0 / Eg05 - CD 0 E \ / ƒ 0 / - E ,- E o C - I ° as o o = g - @ 2 k c e ® ® � - ° © ® ® �/ � ® ° ® ® ® w � ® .= 2 \ � w2 & cm kc\ \ & c22oa) 2 = \ 4_ 228 ¢ k � CO (0O \ a % 7 e / \ a / / j a k 0 / ® 0 0 0 - / a » co _ I ® m 7 = co _ = y @ 0 > _ – U a CO 5 ® ® \ g \$ * 0 ® 0 0 \( £ E E 4t f \ % \ 0 _ 0cn ° / –ct § y 0-/ / -/ 0 0 0 2 3 = H .° U I E o % m � ? f 0 o O - # R O « _ _ O O 2 o a: 0 O : _1 _J I CD . m 0 O : E 2 ± : # CO / \ \ L I- < CO CO o F / CD / U) co \ c $ / / % n / & < Ifs 5-1/8"FMC SAAIOTES:BAL&CONTROL UNE IN COMM w/IA WELLHEAD= FARC �2 A (08/15/06)***WELL ANGLE>70°(10034'**** ACTUATOR= BAKER KB.ELEV= 64' BF.ELEV= _- 2157' H5-1/2"CAMCO DB SSSV NP,D=4.562' 1 KOP= 3200' 20"GOND, $� r7 �5-1/2"CAMCO DSSSV,ID=2.62"(111220/15) Max Angle= 97°@ 10197 91 H 4U, GAS LIFT MANDRELS Datum PA)= 9609' D=19.124" ® MD ND DEV TYPE VLV LATCH PORT DATE Datum ND= 8800'SS 1 2895 2895 5 MMS DOME RK 16 08/29/08 13-3/8"CSG,72#,L-80 BTC,13=12.347" — 2660' 2 4965 4810 26 MMG SO RK 20 08/29/08 Ing 3 6446 6109 30 MM3 OM' RK 0 07/12/82 4 7494 7021 27 WIG DM( RK 0 07/12/82 5 8156 7620 24 tvTMC DMY RK 0 07/12/82 Minimum ID =2.30" @ 8640' 6 8233 7690 24 MM3 DMI' RK 0 07/12/82 BTT DEPLOYMENT SLV PROFILE 7 8543 7976 21 MAG DMY RK 0 07/12/82 8 8619 8047 20 1443 DMI' RK 0 07/12/82 8628' —{4-112"SCOOP GUIDE,D=2.37"(11/20/15) maw }3-1f2"BKR DEPLOY SLV,D=3.000" g 8640' H BTT SELRT AL PROF,MILLED TO 2.30"(XX/XX/XX) 5-1/2"TBG,17#,L-80 8RDABMDD, --I 8646' I— 8646' —I5-1/2"BKR FBRASSY .0232 bpf,ID=4.892" `VII8662' —I9-5/8'X 7"BKR SAB PKR,D=4.865" 1 F: 8666' —17"MLLOUT EXT,D= i (11 ...--------- 8673' —17"X 4-1/2"XO,D=3.958" ill ii 8682' H3-1/2"I CS X NP,D=2.813" 3-1/2"LMR,9.2#,L-80 STL,.0087 bpf,D=2.992" --1 8715' IN TOP OF 7"LNR 8716' * 8715' —I 3-112"X 3-3/16"XO,ID=2.786" 4: _Ailib 8734' —4-1/2"CAM DB-6 LANDING NP,ID=3.813" r 8745' H 4-1/2"BKR Si-EAROUT SW 4-1/7 TBG-PC,12.6#,N-80, 8746' R 111:23111-14-1/2"WLEG,D=3.958" 0152 bpf,D=3.958" t* 8733' --I B.MD TT LOGGED 01!30/83 9-5/8"CSG,47#,L-80,D=8.681" 8996' k% , MILLOUT WINDOW 05-25A 9197'-9201' TOP OF WHPSTOCK(07121!08} 9192' + ( ) RA TAG 9203' 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" — 9816' 'Ay. ♦ *'.+' 10474' —13-3/16"X 2-7/8"XO,D=2.370" PERFORATION St1MM .%;.":. :1..."...,4 RY . .. REF LOG:MCNUGRLCXX OF 08/23108 ? —FISH:KEYS FR DB LOCK ANGLE AT TOP FERE: 74°@ 10055' I &DOGS OFF COLLET Note:Refer to Production DB for historical pert data (06/08/10) SIZE SPF NTERVAL Cpn/Sqz SHOT SQZ 'IP �r* 10890' —2-7/8"BKR CEP 2" 6 10055-10085 0 02/20/16 2" 6 10200-10510 0 08/24/09 3-3/16"LMR 6.2#,L-80 TCA, 10474' /�* (11/21/15) 2" 6 10550-10810 0 08/24/09 .0076 bpf,ID=2.80" '* 2" 6 11020-11330 C 08/24/09PSTD 11640' 2" 6 11470-11640 C 08/24/09 2-7/8"LNR,6.16#,L-80 Sm,.0058 bpf,ID=2.441" — 11658' DATE REV BY COMMENTS DATE I REV BY COMMENTS PRUDI-OE BAY UNIT 7/12/82 ZOWAN3 ORIGINAL COMPLETION 12/03/15 1 IR/JMD SET CBP(11/21/15) WELL: 02-25A 8/25/08'NORDIC 1 CTD SIDETRACK(02-25A) 02/22/16',SRLYJMD ADPERFS(02/20/16) PERMIT No: 2080910 06/25/10 WEGPJC LTTP w/CAT VALVE(06/09/10) 03/02/16 SW/JMD SET DSSSV(11/20/15) API No: 50-029-20766-01 04/14/11 CRHIJM?LTTPw/CAT VLV FULLED(06/17/10) SEC 36,T11 N,R14E,15'FAL&1681'FML 12/10/14 MSS/PJC DSSSV/REFORE4fATWNG WBS 12/03115 RCT/JMD SET SCOOP GUIDE(11/20/15) BP Exploration(Alaska) •. 2.o%•oc t P D 24,92.b VOW MAR 14 2016 PRINT DISTRIBUTION LIST BAKER HUGHES /GC^ Please sign and return one copy of this transmittal form to: �,/ COMPANY BP Exploration Alaska Inc. BP Exploration (Alaska)Inc. Petrotechnical Data Center,LR2-1 3T;;0/GOG� WELL NAME 02-25A 900 E.Benson Blvd. K BENDER Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska LOG DATE February 19,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE March 11,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: FIELD/ FINAL CD/DVD FINAL COMPANY PRELIM (las,dlis,PDF,META, SURVEY REPORT LOGS LOGS CGM,Final Surveys) (Compass) ADDRESS WILL NOT DELIVER TO P.O.BOX) #OF SHIN I S #OF COPIES #OF COPIES #OF COPIES PERSON ATTENTION #OF PRINTS r V V V V 1 BP North Slope. I 0 1 0 1 0 I 0 I 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 I 1 I 1 I 0 I 0 I Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 I 1 1 1 I 0 I 0 I Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 I 1 I 1 I 0 I 0 I Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 I 1 I 1 t 0 I 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 I 0 I 0 I 0 I 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 0 4 4 TOTALS FOR ALL PAGES: 0 4 4 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 5C f CI 8/7 V7f- 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-091 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20766-01-00 7. Property Designation(Lease Number): ADL 0028308 8. Well Name and Number: PBU 02-25A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11728 feet Plugs DEC 17 2015 Pmeasured 10890 feet true vertical 9041 feet Junk measured feet Effective Depth: measured 10890 feet Packer measured 8660 feet ^^ true vertical 9038 feet Packer true vertical 8086 feet A GCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 31-111 31-111 1490 470 Surface 2627 13-3/8"72#L-80 31-2658 31 -2658 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10200-10510 feet 10550-10810 feet 11020-11330 feet 11470-11640 feet True vertical depth: 9053-9039 feet 9038-9036 feet 9043-9046 feet 9047-9045 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"Baker Hydro Set Packer 8660 8085.84 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): �p N Treatment descriptions including volumes used and final pressure: ''As'r , # CLE LE ( 4 _GIC 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 395 32372 6 520 910 Subsequent to operation: 233 24791 4 340 817 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil m Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer ce�1' Signature 1� s �4A Phone +1 907 564 4424 Date 12/16/15 Form 10-404 Revised 5/2015 seri_ /Z/Z J//SI RBDMS DEC 212015 Submit Original Only .177' . • m • O O O O 0) O O N co (b O 0 N V O1 ON- _ (D ti U o 0 0 0 C) 00 0 • O CO I- (0 O V' CO 3 V 0) COO r Ch V m V' (o (p c' (b I� CO 00 O C) CO CO N O V' O V Cf) O O N- CO 0) V V' 0) (0 (O Cf) t O r 10 0 0 0 a- a-- N- CO CO 00 00 0) 0) CO CO CI H O O CO CO CO O (0 a- (3) 0) (0 N- CO C V C0 0) CO CO N O O O '- O N O N- CO CO CO CO O) CO CO V V Cf) r- coLoc° (.0 O (O (O N CO (b CO CO O a- CO CO V 0 < N _ V N CO Cf) O N CO (0 O M (") (N CO O C` N N (D CV CO_ O CO CO CO Cr) CO O • co O O O O a W O pOp Cr) CO 0D 0 CO i V' J Q J J It O J J J Z • a) *k N OJ N (D CO N LO N- N- It CV co 1 N N •N N - - N- 0 CO 0) O - U 0) M ° N N N O N o , �n00 � � r•-• O co Com) N V O N O) O 0) V C0 (b V (N CO (0 O '- (D N- CO N- G) N CO O 00 J W W Q Q W▪ 0 0 •NUU W W 0 fx Lt cc [c [c Z_ Z_ Z W W W W W W W pp pp Q J H I- Z Z Z Z Z D j U W Z Z J J J J J H 0 • _ o_ r_a 3 2 ,_ a) c co o > (a N co -a 0/) O ' a) -O I LO a) c `a a)V/ Q c a a) L J ID a C 0 ❑ E .0 .0 cn Y O O o O (0 -8 O O cB C� . 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EtI- • � 00u) 0 >;g)0(1) -C - ZF- , o a) o Www IY W 0- 01. �U ^0 o O 0)w O U a s WaoN000QD DEOHO CCioZ c ce, 0 ink a --5_ .c CD _ Z - (noo) inoo• ZZQ ~ o Y o0QN0 � � � p ONNNC) M Z - fid In o < 20020 « HJ ,- % o a) U 2 m F- a N N N N N CO 4 a) m _ - - a) H w O C -4 ') L O a) OwZZZZZZ • O _3J � Z DF- I-- Zu, N .-w > D cCo o - u' � 2 mQQQQQQJ * * D1- Q tWMQ = = O F- o ,- p * o a) L a) * 0 d' CYR' IY W' (n * * d Q 2' s?w N cC N L 2 0 * 0 0 - a)* 0 0 0 Z inLU in O O O N N N Y2 co co O r L V - N N N CO N r r TRE-. 5-1/8"FMC • 02-25ik SAFIDNOTES:BAL&CONTROL LINE IN COMM w/lA (0811 5106)."WELL ANGLE>70"ft 1 00 34'**** IAELLHEAD= FMC ACTUATOR= E3A KER KB.ELEV= 64. I I B216T h 5-1/2'CA MCO DB SSSV KIP,ID=4.562" E(LEV= KOP= 3200' -, C, 20"CONDUCTOR, 130' I Max Angle= 7 @ 10197' S LFT MANDRELS Datum AC= 9609. 91.5#,1440 GA ST IAD ND DEV TYPE VLV LATCH FORT DATE ., Datum 1VD= 8800'SS D=19.124' 1 2895 2895 5 WIG DOLE PIK 16 08/2908 13-3/8"CSG,72#,L-80 BTC ID=12.34 7" — 2660' 2 4965 4810 26 MG SO RK 20 08/29/08 3 6446 6109 30 PVM3 DAN RK 0 07112182 4 7494 7021 27 ASG CW RC 0 07/12182 5 8156 7620 24 MAC DW RK 0 07/12/82 Minimum ID = 2.30" @ 8640' 6 8233 7690 24 PW DMY RK 0 07/12/82 7 8543 7976 21 WAG DW RC 0 07/12/82 BTT DEPLOYMENT SLV PROFILE 8 8619 8047 20 RAC MY RK 0 07/12/82 8628' H4-1/2"SCOOP GUIDE,0=2.37' (11/20/15) II 8632' —3-1/2'BKR DEPLOY SLV,ID=3.000' 8640' BTT SELRT AL PROF,MLLED TO 2.30'(XX/XX/XX) ti 0 o 5-1/2"TBG,17#,L-80 8RD ABAJ3D, — 8646' — 8646' H5-1/7 BKR MR ASSY I 0232 bpf,ID=4.897 A Ili A 5 8662' —I 9-5/5"X 7'BKR SAB PKR,13=4.865" 8666' _—7'MILLOUT EXT,0= - 8673' —17'X 4-1/2"X0,D=3.958" 4 1 1 ig 8682' —3-1/2"FES X kr,D=2.813" 3-1/7 LM,9.2#,L-80 SIL,.0087 bpf,ID=2.997 I— 8715' 1 :: 8715' —3-1/7 X 3-3/16"X0,ID=2.786" TOP OF 7"LW — 8716' % , % ' NA $ 8734' —4-1/2"CAM DB-6 LAMING NP,13=3.813' -‘, $ 8745' —4-1/7 BKR SHEAROUT sie 4-1/7 TBG-PC, 12.6#,N-80, 8746' .4. 0'0 . 8746' 4-1/2'WLEG,D=3.958" .0152 bpf,ID=3.958" 8733' —law-rr LOGGED 01/30/83 1 9-5/8"CSG,47#,L-80,I).8.681' — 8996' ;re TOP OF WI-1PSTOCK(07/21/08) 9192' v MLLOUT WINDOW (05-25A) 9197 -9201' RA TAG TAG 9203' .•t.,>. Ns. 7'LW,29#,L-80 BTC. 0371 bpf,ID=6.184" — 9816' ON • 10474' —3-3/181 X 2-7/8"XO,13=2.37(7' 4'4. 4Plk - - - - - PERFORATION SUMMARY —41/4ik 4 * ? --"FISH:KEYS FR DB LOCK . REF LOG:hCtlIGRI_CCL OF 08/23/08 = &DOGS OFF COLLET ) ANGLE AT TOP PERE: 960 @ 10200' IIIN 4b 41/4 Z.4, 4 (06/08/10) ugaum Nate:Refer to Production 06 for historical pert data lb* '4 10890' —2-7/8'BKR CEP SIZE SPF NTI3RVAL Opn/Sqz SHOT SOZ -.0. 4.4, 41%' .44 (11/21(15) 2' 6 10200- 10510 0 08/24/09 3-3/16"L? 6.2#,L-80 TCI, 10474' .4t 2" -1fAi4itip 6 10550- 10810 0 08/24/09 .0076 bpf,ID=2.80" It "4 2" 6 11020-11330 C 08/24/09 4;4*.N., . •At4k" 2' 6 11470- 11640 C 08/24/09 PE3TD 11640' 2-7/8"LNR,6.16#,L-80 5Th..0058 bpf,ID=2.441' — 11658' DATE REV BY OakfuENTS DATE I REV BY CENTS PRUDHOE BAY LNT 7112182 tOWAN 3 ORIGINAL COMPLETION 12/03/15 I IN/JAAD SET CIBP(11/21/15) WELL: 02-25A _ 8/25/08 ICROIC CTD SIDETRACK(02-25A) PERNIT No:"2080910 06/25/10 WEC/PJC LI IP w/CAT VALVE(06/09/10) AFI No: 50-029-20766-01 04/14/11 CRI-VAD Li IP w/CAT VLV PULLED(06/17/10) SEC 36,T11N,R14E,15'FIM,8 1681'FT•IL 12/10/14 MSS/PJC DSSSV/REFOREMATING WBS 12/03/15 RCT/J143 SET SCOOP GUDE(11/20/15) E3P Exploration(Alaska) • 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 ~ - Q 9 ~ Well History File Identifier Organizing (done) ^ Two-sided III II'III II III II III ^ Rescan Needed III (I'lII II II III III RE AN DIG TAL DATA Color Items: Diskettes, No. ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~. /~ ~~ ~s~ ProjectProofing III IIIIIIIIIII IIIII BY: Maria Date: p2 /a `a ~s~ Scanning Preparation .~ x 30 = ~ Q + v~s =TOTAL PAGES ~~ ^ ~// D / ~~ (Count does not include cover sheet) , /t BY: `/ Maria Date: / /sl lYl!V-I~.- Production Scanning Stage 1 Page Count from Scanned File: _s~, (Count does include cov r sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: a/1 b !O lsl ~/~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO , t II BY: Maria Date: ~s~ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: a~a,.~~e~ked ii;uiiiuuuiuu 10/6/2005 Well History File Cover Page.doc 0 bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 Mr. Tom Maunder 41/6 t Alaska Oil and Gas Conservation Commission 10 ' (If 333 West 7 Avenue ��''� Anchorage, Alaska 99501 o C ''ss. Subject: Corrosion Inhibitor Treatments of GPB DS -02 ab s _ Ti Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator S 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02-40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 DATA SUBMITTAL COMPLIANCE REPORT 2/9/2010 Permit to Drill 2080910 Well Name/No. PRUDHOE BAY UNIT 02-25A Operator BP EXPLORATION (ALASK/~ INC API No. 50-029-20766-01-00 MD 11728 TVD 9041 Completion Date 8/25/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional DATAINFORMATgN Types Electric or Other Logs Run: MWD DIR / GR, MCNL / GR /CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type IAedlFrmt Number Name Scale Media No Start Stop CH Received Comments E D Asc Directional Survey 0 11728 Open 9/17/2008 ED D Asc Directional Survey 0 11728 Open 9/11/2008 t Dir ctional Survey 0 11728 Open 9/11/2008 D C Lis 17218 Neutron 8495 11565 Case 11/28/2008 LIS Veri, GR, CNT Neutron 2 Blu 8600 11563 Case 11/28/2008 Mem CNL, CCL, GR, 23- Aug-2008 C Las 17269,iNgutron 8492 11567 Open 12/10/2008 MCNL, CCL, GR, TNF Las 17273 Induction/Resistivity 9088 11728 Open RPM, GR, RAD, RAM, ROP, RPD FIELD DATA pt LIS Verification 9088 11731 Open 12/15/2008 LIS Veri, GR, ROP, RAD, RAS, RPS, RPS ~~ D C Lis 17295 ~fnduction/Resistivity 9088 11731 Open 12/15/2008 LIS Veri, GR, ROP, RAD, RAS, RPS, RPS 1.L'og Induction/Resistivity 25 Col 9192 11728 Open 12/15/2008 MD MPR, GR 22-Aug-2008 og Induction/Resistivity 25 Col 9192 11728 Open 12/15/2008 TVD MPR, GR 22-Aug- 2008 o Gamma Ray 25 Col 9192 11728 Open 12/15/2008 MD GR 22-Aug-2008 og Gamma Ray 2 Col 9080 11690 Open 12/15/2008 Depth Shift Monitor Plot • DATA SUBMITTAL COMPLIANCE REPORT 2/9/2010 Permit to Drill 2080910 Well Name/No. PRUDHOE BAY UNIT 02-25A Operator BP EXPLORATION (ALASKA INC MD 11728 TVD 9041 Completion Date 8/25/2008 Completion Status 1-OIL Current Status 1-OIL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Numt~er Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~7N' Analysis Y`ti~t, Received? Daily History Received? ~-' N Formation Tops APi No. 50-029-20766-01-00 UIC N Comments: Compliance Reviewed By: Date: •I INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC - 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 02-25A Contains the following: ~ ~~~ 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2143355 Sent by: Catrina Guidry Date: 12/12/08 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ® 7260 Homer Drive ~~ Anchorage, Alaska 99518 ____ Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 ~ CUMYANY WELL NAME FIELD -~ - ~.' BAKER F~t~6NE5 Baker Atlas PRINT DISTRIBUTION LIST BY EXYLURA'1'lUN (ALASKA) 1NC CUUN'I Y NUR'I'H SLUYE BURUUUH 02-25A STATE ALASKA PRUDHOE BAY UNIT DATE 12/12/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #:2143355 Copies of Copies Digital Copies of Copies Digital Each Log of Film Da[a Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~~~,°~ ,' Page 1 of 1 Sc~lum6erg~r Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.4960 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 t 1 /24/08 Well Job # Lo Descri tion Date BL Color CD 02-25A 12066545 MCNL .. / 08/23/08 1 1 OWDW-NW 12096915 RS 10/05/08 1 1 OWDW-SE 11975798 RST ~ 10/04/08 1 1 OWDW-SW 12096916 RST /» n [n[ ~ .-7~i'77 1 ~ ~ j L, 10/05/08 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 40 Anchorage, AK 99503-2 38 ATTN: Beth / Received by: 5 _~/~ STATE OF ALASKA "~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION; ; WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~....,,r~ ~ ~ ... 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZe.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Com letions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati ra hic 2. Operator Name: BP Ex location (Alaska) Inc. 5. Date Comp., Susp., or Aban ~ 8/25/2008 12. Permit to Drill Number 208-091 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/16/2008 13. API Number 50-029-20766-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 8/21/2008 14. Well Name and Number: PBU 02-25A FWL, SEC. 36, T11N, R14E, UM 1681 FNL, 14 Top of Productive Horizon: 2670' FNL, 2765' FEL, SEC. 35, T11 N, R14E, UM 8. KB (ft above MSL): 64' Ground (ft MSL): 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 2954' FNL, 1176' FEL, SEC. 35, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 11641' 9045' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 686784 y- 5949499 Zone- ASP4 10. Total Depth (MD+TVD) 11728' 9041' 16. Property Designation: ADL 028308 TPI: x- 684031 y_ 5948442 Zone- ASP4 - 5948198 Zone- ASP4 th: x 685627 T t l De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: - y p o a 18. Directional Survey ®Yes ^ No m' ' n r 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and Tinted inform ion per 20 AA 25.071): MWD DIR / GR, MCNL / GR / CCL L//i/GO/J,~ ~/9~M0 ~53~~'TY~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOB AMOUNT WT. PER FT. GRADE. TOP BOTTOM TOP BOTTOM .SIZE CEMENTING RECORD PULLED 1. II - / " 47# L-80 / S00-95 4 -1 /4" F ' ' 2 72' -1/" x ~-~rr~xa-airs°xzare° s.zxis.zuis.isu 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each I f T & B P MD+TVD tt nterval open n Si nd N mber): f ti SIZE DEPTH SET MD PACKER .SET MD om; er ora ze a u o op o o ( 6 spf 2" Gun Diameter 5-1/2", 17#, L-80 x 8673' 8662' , MD TVD MD TVD 4-1/2", 12.6#, N-80 8673' - 8746' 10200' -10510' 9053' - 9039' 10810' 9038' 9036' 10550' 25. ACID, FRACTURE, CEMeNr SQUEEZE, ETC. - - 11020' -11330' 9043' - 9046' DEPTH INTERVAL MD AMDUNT & KIND OF MATERIAL USED 11470' - 11640' 9047' - 9045' 2500' Freeze Protect w/ 30 Bbls McOH 26: PRODUCTION TEST Date First Production: Au ust 27, 2008 Method of Operation (Flowing, Gas Lift, etc.): Flowin Date of Test: 9/9/2008 HOUfS Tested: 7 PRODUCTION FOR TEST PERIOD OIL-BBL: 238 GAS-MCF: 1,026 WATER-BBL: 58 CHOKE SIZE: 86 GAS-OIL RATIO: 4,310 Flow Tubing Press. 163 Casing Press: 1,500 CALCULATED 24-Ha~R RATE. OIL-BBL: 816 GAS-MCF: 3,517 WATER-BBL: 198. OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core s) A uired? ^Yes ®No Sidewal l Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, 'If needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. COr~PLE7i0N'~ None 8 ~TE~ ~J lI Form 10-40 Kewsea ozizooi `~ •, - CONTINUED VN KEVERSE JIDE ~iz3 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ENCOUNTERED): 29. RMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. 42S6 /Zone 4A 9259' 8651' None Top CGL /Zone 3 9340' 8723' Base CGL /Zone 2C 9451' 8796' 23SB /Zone 26 9628' 8872' 22TS 9756' 8926' 21TS /Zone 2A 9854' 8965' Zone 1 B 10003' 9023' Formation at Total Depth (Name): Zone 1 B 10003' 9023' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~~ / Signed Terrie Hubble Title Drilling Technologist Date ~ ` f PBU 02-25A 208-091 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Mary Endacott 564-4388 INSTRUCT1ONs GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: Provide a listing of intervals coned and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITEM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours' Task '. Code NPT Phase Description of Operations 8/14/2008 08:30 - 08:45 0.25 MOB P PRE PJSM for pulling off well. 08:45 - 09:30 0.75 MOB P PRE Move rig off well. 09:30 - 12:30 3.00 MOB N PRE Wait on placement of plywood on access road. Rig Mats were placed during the previous tour. 12:30 - 15:30 3.00 MOB P PRE Move rig to DS2-25. 15:30 - 00:00 8.50 MOB N RREP PRE Break down 0.25 mile past K-pad access road. Drive motor failed 8/15/2008 00:00 - 02:00 2.00 MOB N RREP PRE Repair drive motor 02:00 - 09:00 7.00 MOB P PRE Continue moving to drillsite 2 09:00 - 09:30 0.50 MOB N WAIT PRE Standby for spotting rig mats. 09:30 - 11:00 1.50 MOB P PRE Move onto rear pad extention and spot rig over well. Accept rig at 11:00 hours 11:00 - 13:00 2.00 BOPSU P PRE NU BOP. 13:00 - 13:30 0.50 RIGU P PRE PU reel into reel house. 13:30 - 18:50 5.33 BOPSU P PRE Test BOP. Witnessing BOP tested was waived by AOGCC Anchorage Engr Tom Maunder 15:40 hrs and Chuck Scheeve AOGCC Field Inspector. 18:50 - 20:30 1.67 RIGU P PRE Pull coil across, Stab injector, change pack offs, open SSV & install fusible cap 20:30 - 22:00 1.50 RIGU P PRE Slack management. Cut 100' coil and 10' a-line. 22:00 - 23:00 1.00 RIGU P PRE MU coil connector and Baker tool. 23:00 - 23:30 0.50 BOPSU P PRE PT inner reel valve. 23:30 - 00:00 0.50 KILL P WEXIT Open well at surface. Well is flowing gas cut McOH about 1 bpm. Flow well to Tiger Tank to determine if this is trapped gas. 8/16/2008 00:00 - 00:15 0.25 KILL P WEXIT Continue to flow well to Tiger Tank to determine if flow will drop off. Well continues to flow. 00:15 - 00:30 0.25 KILL N FLUD WEXIT PU nozzle. 00:30 - 01:15 0.75 KILL N FLUD WEXIT Stab onto well. Bullhead 5 bbls, WHP came up to 3000 psi. Shutdown pumps, WHP constant. Bleed well to Tiger Tank. Well continues to flow. 01:15 - 02:45 1.50 KILL N FLUD WEXIT RIH to 9100'. 02:45 - 04:30 1.75 KILL N FLUD WEXIT Displace well to 2%KCL + 2ppb Biozan double slick while POOH. 04:30 - 04:45 0.25 STWHIP P WEXIT Flow check at surface; well is dead. PJSM for LD Nozzle BHA and PU Milling BHA. Discuss procedure, and risks associate 04:45 - 05:10 0.42 STWHIP P WEXIT PU Milling BHA. 05:10 - 07:00 1.83 STWHIP P WEXIT RIH w/ Milling BHA to 9100 . Wt CK 42K up. Continue to RIH tag at 9196.5' 07:00 - 15:00 8.00 TWHIP WEXIT Mill cement to 9198.3. to I . orrect to 9160.0 . Mill window ~ 1 fph azLSfl 07:13 9196.2 2.63/2.60 bpm @ 2600 psi ECD 8.97 09:00 9198.0 2.64/2.65 bpm ~ 2802 psi ECD 8.96 PT 282bb1 10:00 9198.7 2.65/2.67 bpm ~ 2900 psi ECD 8.97 PT 283bb1 11:00 9199.1 2.66/2.68 bpm C~ 2870 psi ECD 8.96 PT 283 bbl 12:00 9200.0 2.66/2.68 bpm ~ 2911 psi EDC 8.96 PT 283 WOB 3.3K WOB fall off to 2.7K 1300 9201.1 2.65/2.67 bpm ~ 2845 psi ECD 8.96 PT 283 Printed: 8/25/2008 2:23:39 PM BP EXPLORATION Page 2 of 10 Opperations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: I '~ NPT i Phase Description of Operations Date From - To Nours ' Task Code --- 8/16/2008 07:00 - 15:00 8.00 STWHIP P WEXIT WOB 3K 1400 9202.5 2.69/2.66 bpm ~ 2800-3200 psi ECD 8.98 PT 283 Motor work spikes to 3200 psi drilled off ~ 9202.6 Drill rat hole 2.66/2.66 bpm ~ 2933 psi 2.32K WOB, 12 ROP. to 9212.5 15:00 - 16:00 1.00 STWHIP P WEXIT Ream wind I to OK. lean window. 16:00 - 16:40 0.67 STWHIP P WEXIT Circulate FLO Pro to Mill. 16:40 - 18:15 1.58 STWHIP P WEXIT POH for rillin BHA; Continue swapping to mud. 18:15 - 18:30 0.25 STWHIP P WEXIT PJSM for LD BHA #2. Talk about the procedure, and hazards associated. 18:30 - 19:45 1.25 STWHIP P WEXIT LD Millin BHA #2, string reamer and mill are both gage. 3.80" go 3.79" no-go. PU Drill Assy BHA #3, CTC, CoilTrak, 2-7/8" BHI X-Treme 2.4 deg motor, Hughes BiCenter Bit 19:45 - 21:00 1.25 DRILL P PROD1 RIH with Drilling Assembly 21:00 - 21:45 0.75 DRILL P PROD1 Tie-in from 9090' - 9200' at 130 fUhr (+0.4 Correction) 21:45 - 23:00 1.25 DRILL P PROD1 RIH and tag bottom, Bring pumps up to 2.5 bpm and start drilling. Drill to 9252.5' ~ 2.60bpm/2.59bpm, 3000 psi, 2860 psi FS, 0.1 k WOB, 0.5fpm, IA 291 psi, OA 293psi 23:00 - 00:00 1.00 DRILL P PROD1 Drill to 9230' ~ 2.60bpm/2.59bpm, 3000 psi, 2860 psi FS, 0.1 k WOB, 0.5fpm, IA 291 psi, OA 293psi 8/17/2008 00:00 - 01:00 1.00 DRILL P PROD1 Continue Drilling at 2.62/2.64, 3060 psi, 2860 psi FS, 0.58k WOB, 70-75 fph, IA 310, OA 733 01:00 - 02:00 1.00 DRILL P PROD1 Continue Drilling at 2.63/2.61, 3100 psi, 2800 psi FS, 1.34 WOB, 20-30 fph, IA 315, OA 475 Slow drilling, frequent stalls 02:00 - 04:00 2.00 DRILL P PROD1 Continue drilling at 2.55/2.40, 3100 psi, 2720 psi FS, 5.04 WOB, 10-20 fph, IA 327, OA 216, Drill to 9386 Hard drilling, frequent stalls, Samples show 20-40% Frac Chert A roximate start of con lomerate 9340'-9 50' 04:00 - 04:15 0.25 DRILL P PROD1 Wiper trip to window 04:15 - 05:45 1.50 DRILL N RREP PROD1 Wait inside cased hole while the packing on pump #2 is replaced. 05:45 - 07:45 2.00 DRILL P PROD1 RBIH to TD and continue drillin at 2.7/2.67 bpm ~ 3120 psi, 2700 psi FS. WOB 5.64K, ECD 9.18 ~Jo Progress. POH to check bit. 07:45 - 09:20 1.58 DRILL P PROD1 POH. 09:20 - 10:20 1.00 DRILL P PROD1 ~ r ded 7-2 run -out . PU 2.2 motor. 10:20 - 10:50 0.50 DRILL C PROD1 Finish installing CT Inspect. 10:50 - 12:45 1.92 DRILL P PROD1 RIH to 9160 12:45 - 13:00 0.25 DRILL P PROD1 Log tie-in correction -2'. 13:00 - 13:15 0.25 DRILL P PROD1 RIH 9120. Log RA C~? 9203 wo pump 13:15 - 13:45 0.50 DRILL C PROD1 RIH 9350 PU to 9180. Remove CT Inspect. 13:45 - 13:52 0.12 DRILL P PROD1 RIH taa at 9387. 13:52 - 16:30 2.63 DRILL P PROD1 Drill 2.61/2.52 bpm f~ 3040 psi, FS 2830 psi,2.7K WOB, ECD9.22 ROP33fph. 16:30 - 16:45 0.25 DRILL P PROD1 POH to window. 16:45 - 17:45 1.00 DRILL P PROD1 Safety Shut down. As requested a Safety shut down was conducted to discuss the recent increase in the Recordable Injury rate and the concern that a upward trend was occuring. Printed: 8/25/2008 2:23:39 PM BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From- To Hours Task Code NPT Phase Description of Operations 8/17/2008 16:45 - 17:45 1.00 DRILL P PROD1 The Three most recent incidents were reviewed. The Golden rules reviewed with examples. 17:45 - 18:20 0.58 DRILL P PROD1 RIH to bottom. 18:20 - 19:15 0.92 DRILL P PROD1 Drill 2.63/2.62 bpm ~ 3180 psi, FS 2830 psi,1.8K WOB, ECD 9.27, ROP 25fph, IA 320psi, OA 260psi. 19:15 - 19:25 0.17 DRILL P PROD1 BHA wiper. 19:25 - 21:00 1.58 DRILL P PROD1 Drill 2.64/2.63 bpm ~ 3400 psi, FS 3000 psi, 2.OK WOB, ECD 9.28, ROP 35fph, IA 323psi, OA 298psi. 21:00 - 22:00 1.00 DRILL P PROD1 Drill to 9572' at 2.55/2.53 bpm ~ 3060 psi, FS 2870 psi, 1.95K WOB, ECD 9.30, ROP 44fph, IA 332psi, OA 398psi. 22:00 - 23:45 1.75 DRILL P PROD1 POH to surface for BHA change. 23:45 - 23:50 0.08 DRILL P PROD1 PJSM discussing procedures, hazards, and safe work practices to standback injector, PU BHA, & change the motor. 23:50 - 00:00 0.17 DRILL P PROD1 standback injector and blowdown BHA. 8/18/2008 00:00 - 00:45 0.75 DRILL P PROD1 Pull BHA OOH. Service LOC. Change motor setting to 1.2deg and PU new bit. 00:45 - 01:10 0.42 DRILL P PROD1 Secure well and close master valve. H2S Rig Evacuation Drill 01:10 - 02:10 1.00 DRILL P PROD1 SAFETY STAND DOWN 02:10 - 02:55 0.75 DRILL P PROD1 PU BHA, service UOC, and stab injector. 02:55 - 04:25 1.50 DRILL P PRODi RIH to whipstock. 04:25 - 04:40 0.25 DRILL P PROD1 Log tie in w/ -5' correction. 04:40 - 04:55 0.25 DRILL P PROD1 RIH to bottom. 04:55 - 08:15 3.33 DRILL P PROD1 Drill to '96 0 at 2.32/2.32 bpm X2760 psi, 0.76K WOB, ECD 9.28, ROP 41fph, IA 294psi, OA 110psi. Drill to 9800. 08:15 - 10:15 2.00 DRILL P PROD1 POH for planned change in motor bend. 10:15 - 11:30 1.25 DRILL P PROD1 PU 3.4 degree motor per plan. 11:30 - 13:15 1.75 DRILL P PROD1 RIH to 9215' 13:15 - 13:30 0.25 DRILL P PROD1 Log tie-in.-5' 13:30 - 13:45 0.25 DRILL P PROD1 RIH to e9800 13:45 - 17:15 3.50 DRILL P PROD1 Drill 2.48/ 2.48 ~ 2975 psi ,2800 psi FS.ROP 40, WOB .4K, ECD 9.37. 17:15 - 18:15 1.00 DRILL P PROD1 Wiper to window. 18:15 - 19:15 1.00 DRILL P PROD1 Drill 2.55/2.57 ~ 3090 psi, 2800 psi FS, ROP 90-120 fph WOB 3K, ECD 9.39, IA 333, OA 498 Drill to 10,010' 19:15 - 21:00 1.75 DRILL P PROD1 Drill 2.53/2.52 ~ 3200 psi, 2800 psi FS, ROP 60-75 fph, WOB 2.9K, ECD 9.39, IA 336, OA 275 Drill to 10,100 21:00 - 22:00 1.00 DRILL P PROD1 Wiper top window. 22:00 - 22:15 0.25 DRILL P PROD1 Drill 2.57/2.52 ~ 3160 psi, 2800 psi FS, ROP 60-80 fph, WOB 2.2K, ECD 9.43, IA 343, OA 352, Drill to 10140' 22:15 - 23:00 0.75 DRILL P PROD1 Circulate Bottoms uo for confirmation of H[)T f;FC~ rnnfirmc H Tw ° 23:00 - 00:00 1.00 DRILL P PROD1 Drill 2.55/2.52 @ 3100 psi, 2750 psi FS, ROP 60-70 fph, WOB 2.2 K, ECD 9.43, IA 335, OA 410 Drill to 10180' 8/19/2008 00:00 - 00:30 0.50 DRILL P PROD1 Continue Drilling 2.54/2.52, ROP 40-60 fph, 3150 psi, 2800 psi FS Drill to 10.202' 00:30 - 02:15 1.75 DRILL P PROD1 POOH for lateral BHA 02:15 - 02:30 0.25 DRILL P PROD1 PJSM for LD BHA #6. Discuss the procedure and risks involved 02:30 - 04:15 1.75 DRILL P PROD1 PU new bit, 1.2 degree motor and resistivity 04:15 - 05:45 1.50 DRILL P PROD1 RIH with BHA #7, UOC, LOC, Comms, EDC, DPS sub, DGS, RES, HOT, 1.2 deg motor, HCC BiCenter bit Printed: 8/25/2008 2:23:39 PM ~ ~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date ; From - To Hours Task ~ Code NPT Phase Description of Operations 8/19/2008 05:45 - 06:00 0.25 DRILL P PROD1 Log tie-in +8' correction. 06:00 - 06:30 0.50 DRILL P PROD1 Continue to RIH. Tag ~ 06:30 - 07:00 0.50 DRILL P PROD1 Drill to 10245. , 07:00 - 07:15 0.25 DRILL P PROD1 Attempt to MAD Pass to window. PU Differentially stuck. Pull 78K. Relax pipe . Shut downpump. Order Crude. POP free. 07:15 -:09:00 1.75 DRILL P PROD1 MAD Pass up 600 fpm. to 9215'. 09:00 - 09:20 0.33 DRILL P PROD1 RIH 09:20 - 11:15 1.92 DRILL P PROD1 Drilling 2.56/2.55 bpm ~ 3120 psi, 2900 psi FS, ROP 110, WOB 3.1 K, ECD 9.46. PT 265. 11:15 - 12:15 1.00 DRILL P PROD1 Wiper to window. 12:15 - 13:50 1.58 DRILL P PROD1 Drilling 2.61/2.61 bpm ~ psi, 3100 psi FS, ROP , WOB 3.1 K, ECD 9.57. Swap mud. Drilled to 10 550'. 13:50 - 14:10 0.33 DRILL P PROD1 Log GR tie-in at RA tag. added 4'. 14:10 - 15:00 0.83 DRILL P PROD1 RIH clean to bottom. 15:00 - 16:30 1.50 DRILL P PROD1 Drill Zone 1 B lateral, 2.65 bpm, 3000-3700 psi, 2K wob, 89 deg incl, 9.3 ecd, 110 fph, Drilled to 10 700'. No si n of ex ected faul , 16:30 - 19:00 2.50 DRILL P PROD1 POH for Rib steer Motor BHA. 19:00 - 19:15 0.25 DRILL P PROD1 PJSM for LD the BHA and picking up the RSM BHA. Discuss procedure and possible hazards 19:15 - 20:15 1.00 DRILL P PROD1 LD BHA #7 and PU RSM BHA #8. w/ 3.75" HCC PDC bit, RSM, RES, DGS, DPS, EDC, PowComms, Sub Wear, LOC, UOC, xo, CTC 20:15 - 22:15 2.00 DRILL P PROD1 RIH with RSM assy. 22:15 - 22:30 0.25 DRILL P PROD1 Tie-in at 9,180' (-7' correction) 22:30 - 23:15 0.75 DRILL P PROD1 RIH to 10,700', with NO roblems throw h the hi her DLS 23:15 - 00:00 0.75 DRILL P PROD1 Drill 2.55/2.49 ~ 2940 psi, 2650 psi FS, 1.6k WOB, 9.3 ECD, 180 TF, 90 deg inclin, 80-100 fph 8/20/2008 00:00 - 00:45 0.75 DRILL P PROD1 Drill 2.51/2.49 ~ 3000 psi, 2650 psi FS, WOB 3K, 70-90 fph, 180 TF, ECD 9.29, 90.1 near bit incln. Having some trouble getting the tool to drop, looking to get 3' TVD deeper. 00:45 - 01:00 0.25 DRILL P PROD1 Drill 2.38/2.37 @ 2880 psi, 2540 psi FS, WOB 2.4K, 80-110 fph, 180 TF, ECD 9.3, 90.7 near bit incln. 01:00 - 01:30 0.50 DRILL P PROD1 et h ro needed 01:30 - 03:15 1.75 DRILL P PROD1 Drill 2.52/2.52 ~ 2850 psi, 2655 psi FS, WOB 2.16, 40-50 fph, 180 TF, ECD 9.29, 90.41 near bit incln. 03:15 - 05:30 2.25 DRILL N DPRB PROD1 Decide to trip for bent motor. Could not get the drop needed (3' TVD) 05:30 - 06:15 0.75 DRILL N DPRB PROD1 Crew change. PJSM for LD RSM BHA and PU BHA #9. Discuss the procedure and hazards associated with the job. 06:15 - 07:45 1.50 DRILL N DPRB PROD1 M/U Lateral BHA #9 with 3.75" DS49 Bit #7, 1.1 deg Xtreme motor, CoilTrak and RES tool. BHA OAL = 78.66'. 07:45 - 09:45 2.00 DRILL N DPRB PROD1 RIH with lateral /RES BHA #9 09:45 - 10:00 0.25 DRILL N DPRB PROD1 Log GR tie-in at RA tag, -5 ft CTD. 10:00 - 10:40 0.67 DRILL N DPRB PROD1 RIH clean to bottom. 10:40 - 11:40 1.00 DRILL P PROD1 Drill Z1 B lateral, 2.6 bpm, 3000-3600 psi, 2K wob, 86 deg incl, 130 fph, 22 RES, 9.4 ecd, No problem dropping hole inclination to 86 deg. Drilled to 10,940'. Pfiflt8tl: t3/ZS/"LUUH 'L:L:i::1y PM ~ ~ BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ;Code NPT Phase Description of Operations 8/20/2008 ~ 11:40 - 12:10 0.50 DRILL P PROD1 Drill Zi B lateral, 2.6 bpm, 3050-3700 psi, 2K wob, 86 deg incl, 120 fph, 9.5 ecd, Drilled to 11,000'. 12:10 - 13:40 1.50 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 13:40 - 13:50 0.17 DRILL P PROD1 Log MAD pass up from bottom to check GR reading. Seeing high G totals. 13:50 - 14:45 0.92 DRILL P PROD1 Drill Z1 B lateral, 2.4 bpm, 2700-3500 psi, 2K wob, 92 deg incl, 100 fph, 9.5 ecd, Drill to 11 14:45 - 15:15 0.50 DRILL P PROD1 Drill Zi B lateral, 2.4 bpm, 2700-3500 psi, 2K wob, 92 deg incl, 100 fph, 9.5 ecd, Drilled to 11,150'. 15:15 - 16:00 0.75 DRILL P PROD1 Log MAD pass up with RES tool for GEO. 16:00 - 17:00 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 17:00 - 19:30 2.50 DRILL P PROD1 Drill Z1 B lateral, 2.4 bpm, 2700-3500 psi, 2K wob, 92 deg incl, 100 fph, 9.5 ecd, Drilled to 11 309' 19:30 - 21:15 1.75 DRILL P PROD1 Wiper trip to the window. Tie-in (+4.5' correction) 21:15 - 22:00 0.75 DRILL P PROD1 Drill Zi B lateral, 2.3/2.31, 3300 psi, 2900 FS, 2K WOB, 85 deg incln, 9.59 ecd, 70 fph Talk to eolo ist and DD, not able to build incln. Drilled back into the HOT. Decide to trip for a bigger bend 22:00 - 00:00 2.00 DRILL N DPRB PROD1 POOH to Surface 8/21/2008 00:00 - 00:15 0.25 DRILL N DPRB PROD1 POOH to surface 00:15 - 00:30 0.25 DRILL N DPRB PROD1 PJSM for LD BHA and PU BHA #10 00:30 - 02:15 1.75 DRILL N DPRB PROD1 LD BHA #9, Bit looks good, Graded 1,1, Test MWD tools, all tools check out, need to go with more aggressive motor P B A # 10 Re-run 3.75" DS49 Hycalog, 1.7 deg motor, HOT, USMPR, DGS, DPS, EDC, Powercomms, Sub Wear, LOC, UOC, XO, CTC 02:15 - 03:45 1.50 DRILL N DPRB PROD1 RIH w/ BHA #10 03:45 - 04:00 0.25 DRILL N DPRB PROD1 GR tie-in (+4.5' Correction) 04:00 - 04:30 0.50 DRILL N DPRB PROD1 Finish running in hole to bottom Swap to new FloPro at 11,400'. 4% Lubes. 04:30 - 05:30 1.00 DRILL P PROD1 Drill 2.4/2.38 @ 3390 psi, 3000 psi FS, 3.1 WOB, 270 TF, 60 fph, Near Bit inclination 90 05:30 - 06:45 1.25 DRILL P PROD1 Drill 2.45/2.40 C«~ 3250 psi, 2750 psi FS, 3.1 WOB, 9.41 ECD, 92 near bit inclination, 40-50 fph Drillin shale. Drilled to 11458'. 06:45 - 07:45 1.00 DRILL P PROD1 Drill Z1 B, 2.4 bpm, 2950-4000 psi, 70L TF, 93 deg incl, 40 fph, drilling shale, Stacking wt. Drilled to 11472'. 07:45 - 09:30 1.75 DRILL P PROD1 Wiper trip to window. 2.6 bpm, 3100 psi. Clean hole. RIH clean to bottom. 09:30 - 11:10 1.67 DRILL P PROD1 Drill Z1 B, 2.4 bpm, 2950-3600 psi, 2K wob, 70R TF, 90 deg incl, 80 fph, Good sand at 11,470'. Dilled to 11 60 '. 11:10 - 13:00 1.83 DRILL P PROD1 Wiper trip to window. 2.7 bpm, 3300 psi. Clean hole. RIH clean to bottom. 13:00 - 14:20 1.33 DRILL P PROD1 Drill Zi B, 2.4 bpm, 2950-3600 psi, 2-3K wob, 70R TF, 90 deg incl, 80 fph, Printed: 8/25/2008 2:23:39 PM A ~ BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: ~ ~ i~ NPT Phase. Qescription of Operations Date From - To Hours Task Code __ 8/21/2008 13:00 - 14:20 1.33 DRILL - P PROD1 Stacking wt. Drilled to 11,630'. 14:20 - 15:00 0.67 DRILL P PROD1 Short wiper trip up to 11400', to help slide. Ream 11,400-11500'. RIH to bottom. 15:00 - 16:00 1.00 DRILL P PROD1 Drill Z1 B, 2.5 bpm, 3150-3900 psi, 2-3K wob, 50R TF, 90 deg incl, 60 fph, Stacking wt. Not able to drill ahead. Drilled to 11 65 '. 16:00 - 17:45 1.75 DRILL P PROD1 Wiper trip to window. Opened EDC. Cleanout 7" liner with 2.8 bpm up to 8700' and down to window. Close EDC. 17:45 - 18:00 0.25 DRILL P PROD1 Log GR tie-in at RA tag. added 12'. 18:00 - 19:00 1.00 DRILL P PROD1 RIH clean to bottom. 19:00 - 19:30 0.50 DRILL P PROD1 Drill zon 1 2.55/2.55 C~3 3440 psi, 3100 psi FS, 70R TF, 3-4K WOB, 90 near bit, 20 fph 19:30 - 20:00 0.50 DRILL P PROD1 Drill Zone 1 B ~ 2.63/2.6 ~ 3670 psi, 3150 psi FS, 90R TF 2-3K WOB, 92 near bit, 100 fph, Drill to TD 20:00 - 21:15 1.25 DRILL P PROD1 Wiper trip to window 21:15 - 21:30 0.25 DRILL P PROD1 GR tie-in (+1.5' Correction) 21:30 - 22:30 1.00 DRILL P PROD1 RIH to TD 22:30 - 00:00 1.50 DRILL P PROD1 POOH start la in clean floPro ill_ 8/22/2008 00:00 - 00:45 0.75 DRILL P PROD1 Flnish POOH, paint EOP flags 00:45 - 01:00 0.25 DRILL P PROD1 PJSM for LD BHA. Discuss procedure, and hazards 01:00 - 01:30 0.50 DRILL P PROD1 LD drillig BHA, Bit came out 3.73 go, 3.72 no-go 01:30 - 02:00 0.50 BOPSU P PROD1 PJSM for Function testing BOPS, Function test BOP's 02:00 - 05:00 3.00 CASE P RUNPRD Cut 10' of coil, install baker CTC, PU 1 stand of PH6, stab onto well, pump slack out of coil, pumped 362' of eline out of coil, stand back PH6 05:00 - 05:15 0.25 CASE P RUNPRD PJSM for MU of 3-1/2" x 3-3/16" x 2-7/8" liner. Discuss procedure, hazards and mitigations 05:15 - 06:00 0.75 CASE P RUNPRD Begin MU of liner 06:00 - 06:30 0.50 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running liner and BTT SELRT. 06:30 - 11:00 4.50 CASE P RUNPRD Run total of 40 its, 2-7/8" STL liner and 56 its, 3-3/16", TCII liner and 2'ts 3-1/2" STL liner. Liner OAL = 3026.01'. 11:00 - 13:15 2.25 CASE P RUNPRD M/U BTT Deployment sleeve, SELRT, 4 jts PH6 Tbg, Circ out 60 bbl water from coil. M/U BTT Swivel and CTC. BHA OAL = 3163.5'. 13:15 - 14:20 1.08 CASE P RUNPRD RIH with liner on CT. Circ at 0.2 bpm, 720 psi. Held kick while trip drill while RIH. w first fla on de th at 9163'. Up wt = 47K. 14:20 - 15:40 1.33 CASE P RUNPRD RIH clean thru window. RIH at 60 fph, circ at 0.2 bpm at 500 psi. 25K dwn wt at 10500'. 24K dwn wt at 11200'. 21 K dwn wt at 11600'. Stacked wt at 11663'. Up wt = 60K. Shale at this depth. Stack wt several times at this depth. Clean pickup. 15:40 - 17:30 1.83 CASE N DPRB RUNPRD Set down at 11663'. circ at 0.5 bpm, 1400 psi, full returns. RIH at various speeds to 11 665'. Not able to get past ledge, No ro ress. Pump at 1.6 bpm at 2200 psi to clear indexing guide shoe and Printed: 8/25/2008 2:23:39 PM BP EXPLORATION .Operations Summary Report Page 7 of 10 Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/22/2008 15:40 - 17:30 1.83 CASE N DPRB RUNPRD 17:30 - 21:00 3.50 CASE P RUNPRD 21:00 - 21:15 0.25 CASE P RUNPRD 21:15 - 21:45 0.50 CEMT P RUNPRD 21:45 - 23:00 1.25 CEMT P RUNPRD 23:00 - 00:00 1.00 CEMT P RUNPRD 8/23/2008 00:00 - 01:00 1.00 CEMT P RUNPRD try to help it function. No luck. Landed at same depth many times. Anc. Office pave OK to cement liner at this depth. Very solid bottom for liner. Up wt = 56K, no pump. Down wt = 23.5K. Up depth pick up = 11,652.2' at wt break over. Tag up at 11,664'. Place liner at ball drop position. Insert 5/8" steel ball. Displace with FloPro at 2.0 bpm to 40 bbls. Slow pump to 1.0 bpm at 40 bbls. Ball on seat at 50.5 bbl Slack off with 10k to 11,667' and Circluate well over to 2% double slick KCI Ria up cementers PJSM for cement job. Discuss the procedure, good communication, hazards and mitigations Start Batching cement, Cement batched at 21:25, PT lines to 6500 psi, good test Online w/cement Stage 37.0 bbl, 15.8 PPG, G Cement, 35 bbl, 1.75 bpm, 2500 psi 37.0 bbl out, stop pump, isolate cementers, clean cementing line. Zero the in MM Displace cement with 2# Bio, using rig pump with Micromotion Stage 2# Biozan displ. 10 bbl displ, 2.5 bpm, 3400 psi 20 bbl displ, 2.4 bpm, 2260 psi 30 bbl displ, 2.4 bpm, 1640 psi 40 bbl displ, 2.4 bpm, 1390 psi 47 bbl Cement at shoe 50 bbl displ, 2.4 bpm, 2000 psi 60 bbl displ, 2.4 bpm, 2400 psi 61.8, down on pumps Pick up 13' to 11645' Circ. 7 bbl through side exhaust, 1.9 bpm, 1440 psi, (2 bbl cmt, 5 bbl Bio to backside) 69.1 bbl displ, stop pump, Open Baker choke. RIH with coil, stack wt at same depth, Close Baker choke. Zero in and out totalizers, LWP sheared at 0.4 bbl, at 2000 psi, looks good 10 bbl, 2.2 bpm, 2.1 returns, 2344 psi 15 bbl, 2.2 bpm, 2.1 returns, 2325 psi 18 bbl, 2.19 bpm, 2.11 returns, 2230 psi, drop pump rate 20 bbl, 1.5 bpm, 1.46 returns, 1850 psi Bump LWP at 21.2 bbls, calc was 21.3 bbl. hold 3000 psi. 5 min. no leak. Out totalizer had 41.4 bbls when bumped plug, no losses were seen during job Bled press to zero, check floats, floats holding. Press up to 500 psi and sting out clean from top of liner. SELRT worked very well. POOH to lay down POOH to surface with SELRT BHA Printed: 8/25/2008 2:23:39 PM • • BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date ~ From - To Hours Task '; Code NPT Phase Description of Operations 8/23/2008 01:00 - 01:15 0.25 CASE P RUNPRD PJSM for LD of SELRT tool 01:15 - 02:30 1.25 CASE P RUNPRD LD SELRT, 10' a-line out end of coil. 02:30 - 03:45 1.25 CASE P RUNPRD Jet stack and clean reel manifold 03:45 - 04:00 0.25 EVAL P LOWERI PJSM for picking up cleanouUlogging BHA, discuss procedure, and hazards 04:00 - 09:00 5.00 EVAL P LOWERI j?U cleanouUloaaina BHA 2.3" HCC diamond parabolic mill, 2 jts of CSH, SWS MCNUGR/CCL logging carrier, 98 jts of CSH, 2 jts of 2-3/8" PH6, swivel and CTC. BHA OAL = 3207'. 09:00 - 11:00 2.00 EVAL P LOWERi RIH with 2.30" mill, motor and MCNUGR BHA. Circ at 0.25 bpm 11:00 - 13:00 2.00 EVAL P LOW ER1 Ta AL rofile in de to ment sleeve at 8641'. Mill AL rofile out to 2.30" at 1.4 bpm, 2500 psi. Ream area up /down, 3 times. area is clean. 13:00 - 15:15 2.25 EVAL P LOWERI Log down with SWS MCNUGR/CCL from 9520' at 30 fph to PBTD. circ 0.9 bpm, 1100 psi. Tag PBTD at 11,643', uncorrected CTD. 15:15 - 16:00 0.75 EVAL P LOWERI Log up at 60 fpm to 9500'. Lay in new FloPro 20 bbl pert pill while logging up. 16:00 - 16:45 0.75 EVAL P LOWERi POH with memory logging / cleanout BHA. 16:45 - 17:00 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH workstring. 17:00 - 19:15 2.25 EVAL P LOWERi Stand back 49 stds of CSH. 19:15 - 19:30 0.25 EVAL P LOWERI PJSM. Review procedure, hazards, and mitigation for LD the logging tool w/ sources 19:30 - 20:20 0.83 EVAL P LOWERI Stand back logging carrier, 1 stand of CSH, the motor and mill 20:20 - 20:35 0.25 PERFO P LOWERI PJSM for loading guns into the pipe shed. Discuss procedure, hazards and mitigations 20:35 - 21:05 0.50 EVAL P LOWERI PT liner la to 2000 si IA started at 242 psi Lost 52 psi in first 15 min, IA at 242 psi Lost 18 psi in second 15 min, IA 249 psi Start loading guns into pipe shed 21:05 - 22:00 0.92 EVAL P LOWERI Load guns into pipe shed, PJSM, reviewed handling operational procedures 22:00 - 22:30 0.50 EVAL P LOWERI RU, PU, RIH 5 joints of 2" pert guns, well had a slight flow over lubricator nipple with crude, stabbed, RIH with safety valve joint, shut well on annular preventor, 0 psi on choke, IA 242 psi. Note communication throw h SSSV to IA was predetermined vin on well. 22:30 - 23:45 1.25 EVAL N DPRB LOWERI Bled down IA from 242 to 100 psi, open choke with minor intermittent flow back of less than 30 seconds, opened annular, monitor well for 30 minutes, no flow. Notified BP CTD Supt, Ken Miller and AOGCC John Crisp of well event 23:45 - 00:00 0.25 EVAL N DPRB LOWERI review on handling and running pert guns. 8/24/2008 00:00 - 04:15 4.25 PERFO P LOWERI PU,RIH 68 joints of pert guns, PJSM for RIH 1-1/4" CSH, RIH 27 stands of 1-1/4" CSH BHA OAL = 3200.18 04:15 - 04:45 0.50 PERFO P LOWERI PU, stab injector 04:45 - 06:25 1.67 PERFO P LOWERI RIH with guns to PBTD of 11640 Printed: 8/25/2008 2:23:39 PM • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date i From - To Hours Task ~ Code', NPT Phase Description of Operations 8/24/2008 06:25 - 06:30 0.08 PERFO P LOWERI Practice rolling pumps Crew change out 06:30 - 07:00 0.50 PERFO P LOWERI Practice rolling pumps. OK. Start firing pump sequence. No pumps for 2 min 0.3 bpm for 1 min 135 psi 1.5 bpm for 1 min 1350 psi Repeat this sequence two more times roll pumps at 0.3 bpm for one minute, bring pumps back up to 1.5 bpm for 2.5 minutes drop pumps down to 0.3 bpm for one minute and start to creep up hole at 2 ft/min Fir ', 90 sec after last sequence. Good firin detection also lost circ. volume fr m s. No overpull after firing guns, clean pick up. 07:00 - 09:00 2.00 PERFO P LOWERI POH with fired pert guns. Flow check at top of liner. No flow. POH. Flow check at surface. No flow. 09:00 - 09:15 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH workstring. 09:15 - 11:00 1.75 PERFO P LOWERi Stand back CSH workstring. 11:00 - 11:15 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for Laying out fired 2" pert guns. 11:15 - 15:15 4.00 PERFO P LOWERi Lay out SWS 2" PJ Perf guns. All shots fired. PERFORATED INTERVALS: 10,200 - 10,510' 10,550 - 10,810' 11,020 - 11,330' 11,470 - 11,640' TOTAL PERFORATED LENGTH = 1,050'. SWS 2" PJ guns, loaded at 6 SPF with 60 deg phasing 15:15 - 16:30 1.25 BOPSU N DPRB LOWERI Pressure test annular at first available time after use on previous BHA. Test Annular at 250 / 2500 psi. Charted test and sent test report to AOGCC. 16:30 - 18:45 2.25 WHSUR P POST RIH with nozzle on coil and freeze protect 5-1/2" tubing to 2500' with 30 BBL MEOH. POH. 18:45 - 20:15 1.50 WHSUR N WAIT POST Wait for BPV crew to arrive after safety standdown 20:05 - 20:25 0.33 WHSUR P POST Safety meeting for setting BPV. Discuss procedure and hazards 20:25 - 21:30 1.08 WHSUR P POST D rod and set 5 1/8" FMC BPV. SSV pretruding in run of tree not allowing BPV to pass, manipulate SSV to allow BPV to fall through 21:30 - 21:45 0.25 WHSUR P POST PJSM for Blowing down the reel 21:45 - 00:00 2.25 WHSUR P POST Cool nitrogen, pump 10 bbl of fresh water and 10 bbl of McOH, pressure test lines to 3500 psi, pressure test good, Blow reel down with nitrogen, bleed down pressure, RD Nitrogen 8/25/2008 00:00 - 00:15 0.25 BOPSU P POST PJSM for ND BOPE, discuss procedure and hazards 00:15 - 02:00 1.75 WHSUR P POST Clean pits Printed: sizsizoos z:zs:ss Pnn i • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 02-25 Common Well Name: 02-25 Spud Date: 6/25/1982 Event Name: REENTER+COMPLETE Start: 8/5/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 8/25/2008 00:15 - 02:00 1.75 WHSUR P POST N/D BOPs , install tree cap. Pressure test tree cap TOTAL TIME OF 9 DAYS, 15 HOURS ON THE DS 02-25A WELL. RIG ON STANDBY WAITING ON RIG MATS TO GET OFF THE DS 2 LOCATION. ALL FUTURE RIG INFORMATION WILL BE IN DIMS UNDER WELL: E-29A ALL RIG MOVE AND STANDBY RIG COSTS WILL BE BILLED TO E-29A. Printed: 8/25/2008 2:23:39 PM by BP Alaska Baker Hughes INTEQ Survey Report INTEQ ~ Company: BP Amoco Date: 8/22/2008 Time: 14:36:48 Page: . 1 ~ Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-25, True North Site: PB DS 02 Vertical (1'VD) Reference: 52:25 6/25/1982 00;00 64.0 Well: 02-25 Section (VS) Reference: Well (O.OON,O.OOE,223.05Azi) i Wellpath:. 02-25A Survey Calculation Method: Minimum Curvature Db: Orate Field: Prudhoe Bay - ~ _ -- - _ -- North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 --- Site: PB DS 02 --- ---- - - - -- _~ TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5948800.37 ft Latitude: 70 15 53.847 N I From: Map Easting: 687638.44 ft Longitude: 148 28 58.060 W ~ Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg _ -_ Well: 02-25 Slot Name: 25 02-25 Well Position: +N/-S 719.37 ft Northing: 5949498.63 ft Latitude: 70 16 0.922 N ~ +E/-W -836.35 ft Easting : 686784.47 ft Longitude: 148 29 22.403 W Position Uncertainty: 0.00 ft Wellpath: 02-25A Drilled From: 02-25 500292076601 Tie-on Depth: 9100.00 ft ~ Current Datum: 52:25 6/25/1982 00:00 Height 64.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/13/2008 Declination: 23.33 deg ' Field Strength: 57679 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.00 0.00 0.00 223.05 Survey Program for Definitive Wellpath Date: 5/13/2008 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Naroe ft ft 100.00 9100.00 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 9192.00 11728.00 MWD (9192.00-11728.00) MWD MWD -Standard Annotation MD TVD ft ft 9100.00 8499.69 TIP 9192.00 8586.80 KOP 11728.00 9041.13 TD j Survey: MWD Start Date:. 8/18/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DL5 Tool ft deg. deg ft ft ft ft ft ft ft degl100ft 9100.00 19.18 236.28 8499.69 8435.69 -1210.16 -2292.91 5948232.03 684522.43 2449.52 0.00 MWD 9192.00 18.34 236.60 8586.80 8522.80 -1226.52 -2317.57 5948215.06 684498.19 2478.30 0.92 MWD 9240.15 70.61 8633.13 8569.13 -1230.64 -2329.77 5948210.64 684486.09 2489.64 21.22 MWD 9270.67 20.12 289.59 8662.31 8598.31 -1228.83 -2338.44 5948212.23 684477.38 2494.24 26.75 MWD 9298.13 27.04 284.96 8687.47 8623.47 -1225.63 -2348.93 5948215.17 684466.81 2499.07 26.07 MWD 9326.81 33.41 278.91 8712.24 8648.24 -1222.72 -2363.05 5948217.73 684452.63 2506.58 24.59 MWD 9355.41 39.86 273.82 8735.18 8671.18 -1220.89 -2379.99 5948219.14 684435.64 2516.80 24.91 MWD 9385.61 46.28 264.77 8757.25 8693.25 -1221.24 -2400.56 5948218.28 684415.10 2531.10 29.47 MWD 9417.95 53.08 259.53 8778.18 8714.18 -1224.66 -2424.95 5948214.25 684390.80 2550.25 24.37 MWD 9448.65 59.30 256.10 8795.25 8731.25 -1230.07 -2449.86 5948208.23 684366.03 2571.20 22.28 MWD 9475.09 63.96 256.83 8807.81 8743.81 -1235.51 -2472.47 5948202.23 684343.57 2590.61 17.79 MWD BP Alaska by Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco - -- Dater 8/22/2008 Time: 14:36:48 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-25, True North Site: PB DS 02 Vertical (TVD) Reference: 52 ; 25 6/25/1982 00:06 64.0: Well: 02-25 Section (VS) Reference: WeIC(().OOfV,0.00E,223.05Azi) Wellpath: 02-25A Survey Calculation Method: Minimum Curvature I)b: Oracle. Survey MD Incl Azim TVD ft deg deg ft 9509.15 63.78 261.33 8822. 82 9536.99 67.00 270.09 8834. 43 9567.07 66.21 277.33 8846. 39 9602.47 64.28 281.57 8861. 22 9631. 35 63. 79 287. 01 8873. 87 9665. 38 65. 32 291. 04 8888. 49 9696. 53 65. 58 294. 17 8901. 44 9726. 90 65 .96 298. 45 8913 .91 9756. 18 66 .02 302. 53 8925 .83 9786. 55 66 .13 306. 70 8938 .15 9815. 69 65 .63 317. 69 8950 .09 9849. 29 68 .21 330. 15 8963 .30 9878. 59 67 .84 341. 82 8974 .30 9915. 17 67 .19 354. 37 8988 .33 9943. 01 66 .68 3. 71 8999 .26 9975. 59 66 .86 18. 80 9012 .17 10004. 77 68 .60 28. 77 9023 .26 10033. 55 72 .83 39. 79 9032 .79 10070 .99 75 .64 52. 96 9043 .00 10099 .67 79 .70 64. 86 9049 .14 10130 .17 82 .35 78. 19 9053 .92 10145 .51 86 .66 82. 29 9055 .39 10163 .49 91 .32 86. 97 9055 .71 10196 .74 96 .54 97. 33 9053 .42 10229 .43 94 .03 102. 38 9050 .41 10261 .50 93 .17 107. 01 9048 .40 10289 .34 93 .32 111. 86 9046 .82 10330 .24 93 .78 106. 49 9044 .28 10358 .08 93 .05 103. 81 9042 .63 10389.32 91.97 99.61 9041.26 10418.76 90.64 96.53 9040.59 10449.66 90.86 92.04 9040.18 10483.45 90.68 86.72 9039.73 10511.94 90.80 81.97 9039.36 10540.06 91.99 79.57 9038.68 10579.64 91.75 82.05 9037.38 10606.12 90.43 85.46 9036.88 10638.94 89.39 91.47 9036.93 10669.04 89.57 95.87 9037.20 10700.54 90.25 99.79 9037.25 10740.18 90.89 100.79 9036.86 10771.78 90.80 102.09 9036.39 10800.26 90.28 102.77 9036.13 10831.05 90.28 103.46 9035.97 10860.87 88.47 105.19 9036.30 10891.19 86.44 108.60 9037.65 10922.91 85.89 105.48 9039.77 10955.39 88.10 103.49 9041.47 10990.57 88.65 100.70 9042.47 11029.57 89.48 97.65 9043.11 11062.05 91.01 95.12 9042:97 11096.97 92.92 90.70 9041.77 11144.83 90.40 86.11 9040.38 Sys TVD N/S ft ft 8758.82 -1241.30 8770.43 -1243.17 8782.39 -1241.39 8797.22 -1236.12 8809.87 -1229.72 8824.49 -1219.70 8837.44 -1208.81 8849.91 -1196.54 8861.83 -1182.97 8874.15 -1167.20 8886.09 -1149.38 8899.30 -1124.45 8910.30 -1099.68 8924.33 -1066.70 8935.26 -1041.12 8948.17 -1011.87 8959.26 -987.21 8968.79 -964.83 8979.00 -940.06 8985.14 -925.64 8989.92 -916.13 8991.39 -913.54 8991.71 -911.86 8989.42 -913.09 8986.41 -918.67 8984.40 -926.78 8982.82 -936.03 8980.28 -949.43 8978.63 -956.70 8977.26 -963.03 8976.59 -967.16 8976.18 -969.47 8975.73 -969.10 8975.36 -966.29 8974.68 -961.79 8973.38 -955.47 8972.88 -952.59 8972.93 -951.71 8973.20 -953.64 8973.25 -957.93 8972.86 -965.01 8972.39 -971.27 8972.13 -977.40 8971.97 -984.39 8972.30 -991.77 8973.65 -1000.57 8975.77 -1009.84 8977.47 -1017.95 8978.47 -1025.32 8979.11 -1031.54 8978.97 -1035.15 8977.77 -1036.92 8976.38 -1035.59 E/W MapN MapE ft ft ft -2502.48 5948195.70 684313.71 -2527.69 5948193.20 684288.56 -2555.21 5948194.30 684261.00 -2586.92 5948198.78 684229.18 -2612.06 5948204.56 684203.88 -2641.10 5948213.85 684174.60 -2667.26 5948224.09 684148.19 -2692.07 5948235.74 684123.07 -2715.12 5948248.73 684099.71 -2737.95 5948263.93 684076.48 -2757.62 5948281.25 684056.38 -2775.75 5948305.73 684037.64 -2786.79 5948330.21 684025.99 -2793.75 5948363.01 684018.21 -2794.18 5948388.56 684017.15 -2788.36 5948417.95 684022.24 -2777.47 5948442.87 684032.51 -2762.18 5948465.62 684047.25 -2736.14 5948491.03 684072.66 -2712.19 5948506.04 684096.24 -2683.68 5948516.25 684124.51 -2668.64 5948519.21 684139.48 -2650.75 5948521.34 684157.32 -2617.66 5948520.92 684190.43 -2585.60 5948516.15 684222.61 -2554.65 5948508.80 684253.75 -2528.45 5948500.21 684280.18 -2489.91 5948487.77 684319.04 -2463.08 5948481.17 684346.03 -2432.53 5948475.60 684376.73 -2403.39 5948472.20 684405.96 -2372.59 5948470.65 684436.81 -2338.82 5948471.86 684470.56 -2310.48 5948475.37 684498.82 -2282.73 5948480.56 684526.44 -2243.68 5948487.84 684565.32 -2217.37 5948491.38 684591.55 -2184.58 5948493.07 684624.31 -2154.55 5948491.89 684654.38 -2123.35 5948488.37 684685.67 -2084.35 5948482.26 684724.83 -2053.38 5948476.77 684755.94 -2025.57 5948471.33 684783.90 -1995.58 5948465.09 684814.05 -1966.69 5948458.43 684843.11 -1937.72 5948450.35 684872.29 -1907.46 5948441.83 684902.77 -1876.06 5948434.50 684934.36 -1841.68 5948427.99 684968.91 -1803.19 5948422.73 685007.54 -1770.91 5948419.92 685039.89 -1736.07 5948419.02 685074.77 -1688.26 5948421.53 685122.52 VS DLS Tool ft deg/1OOft 2615.33 11.87 MWD 2633.90 30.85 MWD 2651.39 22.24 MWD 2669.18 12.17 MWD 2681.67 17.02 MWD 2694.17 11.60 MWD 2704.06 9.18 MWD 2712.03 12.91 MWD 2717.84 12.73 MWD 2721.91 12.56 MWD 2722.31 34.46 MWD 2716.47 34.95 MWD 2705.90 36.95 MWD 2686.55 31.74 MWD 2668.16 30.92 MWD 2642.81 42.55 MWD 2617.35 32.17 MWD 2590.56 39.00 MWD 2554.68 34.67 MWD 2527.79 42.92 MWD 2501.38 44.03 MWD 2489.23 38.69 MWD 2475.79 36.72 MWD 2454.10 34.81 MWD 2436.29 17.19 MWD 2421.10 14.66 MWD 2409.97 17.40 MWD 2393.45 13.15 MWD 2380.45 9.96 MWD 2364.22 13.87 MWD 2347.35 11.39 MWD 2328.01 14.55 MWD 2304.69 15.75 MWD 2283.30 16.68 MWD 2261.06 9.52 MWD 2229.79 6.29 MWD 2209.72 13.81 MWD 2186.70 18.58 MWD 2167.61 14.63 MWD 2149.45 12.63 MWD 2128.00 3.00 MWD 2111.44 4.12 MWD 2096.94 3.01 MWD 2081.57 2.24 MWD 2067.24 8.40 MWD 2053.89 13.08 MWD 2040.02 9.97 MWD 2024.51 9.15 MWD 2006.43 8.08 MWD 1984.70 8.10 MWD 1965.31 9.10 MWD 1942.82 13.78 MWD 1909.21 10.94 MWD by ~ BP Alaska ~ s Baker Hughes INTEQ Survey Report iNTEQ Company: BP Amoco Date: 8/22/2008 Time:.. 14:36:48 Page: 3 ~ Field: Prudhoe Bay Co-ordinate(NEpl2efereoce: Well: 02-25, True North Site: PB DS 02 Vertical (1'VD) Reference: 52:25 6/25/1982 OO;tlO 64.0 We1L• 02-25 Section (VS) Reference: Well (t).OQN,O.OOE,223.05Azi) ~ Wellpath: 02-25A Survey Calculation Method: Minimum Curvature. Db: OraGe Survey MD Incl Azim TVD Sys TVD N/S E/R' ft deg deg ft ft ft ft 11174.47 89.97 87.22 9040.29 8976.29 -1033.86 -1658.67 11204.27 90.21 91.18 9040.24 8976.24 -1033.45 -1628.88 11228.55 88.74 95.85 9040.46 8976.46 -1034.94 -1604.66 11258.97 87.76 98.17 9041.39 8977.39 -1038.65 -1574.48 11288.93 85.84 101.36 9043.06 8979.06 -1043.72 -1545.01 11316.85 85.05 104.52 9045.28 8981.28 -1049.95 -1517.89 11346.45 85.05 107.86 9047.84 8983.84 -1058.17 -1489.57 11378.89 87.57 112.36 9049.93 8985.93 -1069.30 -1459.18 11409.45 91.26 113.39 9050.24 8986.24 -1081.18 -1431.03 11438.78 93.07 109.62 9049.13 8985.13 -1091.92 -1403.77 11471.92 93.97 109.79 9047.09 8983.09 -1103.07 -1372.63 11502.01 92.25 115.13 9045.46 8981.46 -1114.55 -1344.87 11532.43 91.14 122.22 9044.56 8980.56 -1129.13 -1318.21 11561.87 90.37 127.77 9044.17 8980.17 -1146.00 -1294.11 11594.77 89.14 132.28 9044.31 8980.31 -1167.16 -1268.92 11633.95 90.18 138.37 9044.54 8980.54 -1195.00 -1241.39 11664.63 92.00 144.33 9043.96 8979.96 -1218.95 -1222.24 11685.13 92.67 148.72 9043.12 8979.12 -1236.03 -1210.94 11728.00 92.67 148.72 9041.13 8977.13 -1272.63 -1188.71 MapN MapE ft ft 5948423.99 685152.06 5948425.15 685181.83 5948424.26 685206.08 5948421.30 685236.34 5948416.96 685265.93 5948411.41 685293.19 5948403.89 685321.70 5948393.52 685352.36 5948382.35 685380.79 5948372.28 685408.31 5948361.91 685439.72 5948351.13 685467.74 5948337.21 685494.76 5948320.94 685519.27 5948300.42 685544.97 5948273.27 685573.19 5948249.81 685592.92 5948233.01 685604.64 5948196.98 685627.77 VS DLS Too ft l deg/100ft 1887.75 4.02 MWD i 1867.11 13.31 MWD 1851.66 20.16 MWD 1833.78 8.28 MWD 1817.36 12.41 MWD 1803.40 11.63 MWD 1790.08 11.24 MWD ~ 1777.47 15.87 I MWD ~ 1766.94 12.54 MWD 1756.18 14.25 MWD 1743.07 2.76 MWD 1732.51 18.62 MWD 1724.97 23.58 MWD 1720.85 19.03 MWD 1719.12 14.21 MWD 1720.67 15.77 MWD 1725.10 20.31 MWD 1729.87 1741 44 21.64 0 00 MWD MWD . . LLHEAD = FMC TUATOR = ' AXELSON ~~_ 64' DRLG DRAFT ~ P = 3200' ~ Angle = 97' @ 10197' um MD = 9609' um TV D = 8800' SS 20" CONDUCTOR, 91.5#, H-40, ID = 19.124" $0' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2660' Minimum ID = 2.30" @ 8640' BTT Deployment Slv profile 8632' TOP3-1/2" x 3-3116" x 2-718" LINER 8640' I~ BTT SELRT AL PROFILE, Milled out to 2.30" 5-1/2" TBG-PC, 17#, L-80, 8RD ABMOD. I~ g661' 0.0232 bpf, ID = 4.892" 86$2' I-~3-1/2" X- NIPPPLE, 2.813" Profile TOP OF 7" LNR I-{ $716' 8715' I~ 3-1/2" x 3-3/16" X-OVER 02-25A L ~,( o- vc ~..ri rvi~..v uo ooov wir, Iu -Y.JVG • W/5.5 DSSSV (01/16/07), ID=2.62 {pulled} GAS LIFT MANDRELS S NOTES:***BALANCE 8~ CONTROL LINE ~MMUNICATION w/ IA (8/15/06)** ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 2895 2895 5 MMG DOME RK 16 08/29/01 2 4965 4810 26 MMG SO RK 20 08/29/01 3 6446 6109 30 MMG DMY RK 0 07/12/8: 4 7494 7021 27 MMG DMY RK 0 07/1218: 5 8156 7620 24 MMG DMY RK 0 07/12/8: 6 8233 7690 24 MMG DMY RK 0 07/12/8: 7 8543 7976 21 MMG DMY RK 0 07/12/8: 8 8619 8047 21 MMG DMY RK 0 07/12/8: $~-15-1/2" BAKER PBR ASSY I 8662' 9-5/8" X 7" BAKER SAB PKR 8673' ~-17" X 4-1/2" XO 8734' I-14-112" CAM DB-6 LANDING NIP, ID = 3.813" 8745' 4-1/2" BAKER SHEAROUT SUB 4-1/2" TBG-PC, 12.6#, N-80, 8746' BUTT, 0.0152 bpf, ID = 3.958" 3-5/8" CSG, 47#, L-80 &SOO-95, ID = 8.681" I~ 8996' PERFORATION SUMMARY REF LOG: MCNL/GRLCCL OF 08/23/08 ANGLE AT TOP PERF: 96° @ 10,200' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10200 - 10510 OPEN 8/24/2008 2" 6 10550 - 10810 OPEN 8/24/2008 2" 6 11020 - 11330 OPEN 8/24/2008 2" 6 11470 - 11640 OPEN 8/24/2008 PBTD 9770' ~0 0.0371 bpf, ID = 6.184" 9816' $746' ~4-1/2" TUBING TAIL 8733' ELMD TT LOGGED 01 /30183 4 1/2" x 7" w hipstoci< I~ 9192' 10474' 3-3116" x 2-7/8" XOVER Tp 11728' PBTD 11640' ~,. 3-1/2" x 3-3/16"x 2-7/8" Liner, Cemented & Perf'd 11658' 9590' I~ TOP OF CEMENT (06/15/06) DATE REV BY COMMENTS DATE REV BY COMMENTS 7/12/82 ROWAN 35 ORIG COMPLETION 8/24/08 NORDIC 1 CTD SDTRCK (02-25A) X8/26/08 PJC DRLG CORRECTIONS 9/01/08 GJF/PJC GLV C/O (08!29/08) PRUDHOE BAY UNfT WELL: 02-25A PERMfT No: 2080910 API No: 50-029-20766-01 SEC 36, T11 N, R14E, 15' FWL & 1681' FNL BP Exploration (Alaska) ! • BAKE Nt»IES 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: September 15, 2008 Please find enclosed directional survey data for the following wells: Pl-24L1 Pl-24L1-Ol E-29A Enclosed for each well is: V-115L1 V-115L2PB1 V-115L2 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: tip.%~ V ~ State of Alaska AOGCC DATE: Cc: State of Alaska, AOGCC ~~~ ~~ ~~ ~~~' 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: September 08, 2008 Please find enclosed directional survey data for the following wells: Pl-24L1 Pl-24L1-O1 02-25A '~ ~,~~ a~ ~ E-29A Enclosed for each well is: V-115L 1 V-115L2PB1 V-115L2 tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ,State of Alaska AOGCC DATE: ~,c~-~1 Cc: State of Alaska, AOGCC ~----- d ~ ~ ~ SARAH PAL/N, GOVERNOR C01~5ERQ~ ATIO C ~~~5'IO~ 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-25A BP Exploration Alaska Inc. Permit No: 208-091 Surface Location: 1681' FNL, 14' FWL, SEC. 36, T11N, R14E, UM Bottomhole Location: 2822' FNL, 1173' FEL, SEC. 35, T11N, R14E, UM Dear Ms. Endacott: -- - Enclosed-is--the approved application for permit to redrill th erence 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 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). '~' Sincerely,.! Daniel T. Seamount, Jr. Chair ~~ DATED this ~ Zday of June, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 IVD ~~ ~~ ivl~Y ~ 9 2008 1 a. Type of work ^ Drill ~ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Speci ' #t' ~ e~ ..~ ` ^Coalbed Methane ;®;ilFtes ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU 02-25A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11700 TVD 8981'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1681' FNL 14' FWL SEC 36 T11 N R14E UM 7. Property Designation: ADL 028308 Pool , , , , , . Top of Productive Horizon: 2900' FNL, 2291' FEL, SEC. 35, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: July 15, 2008 Total Depth: 2822' FNL, 1173' FEL, SEC. 35, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-686784 y-5949499 Zone-ASP4 10. KB Elevation (Height above GL): 64' feet 15. Distance to Nearest well within Pool: 1,190' 16. Deviated Wells: Kickoff Depth: g1 g2 feet Maximum Hole An le: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3200 Surface: 2304 f8'. Ca in -Pr ram: S cificatio ns ' To -'Settin De h =Bo ttom uanti of ment cf: or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" s-v2~~ X s-svs~' 9.2# / 6.2# L-80 STL / TCI I 3000' 8700' 8060'ss 11700' 8981'ss 184 sx Class 'G' x 2-7/8" / 6.16# 19. PRESE NT wELLCONDITION S UMMARY. (To be completed. for Redrill :and Re-entry Operations) Total Depth MD (ft): 9816' Total Depth TVD (ft): 9184' Plugs (measured): 9590' Effective Depth MD (ft): 9590' Effective Depth TVD (ft): 8966' Junk (measured): 9597' Casing- Length Size CemenYVolume MD TVD Conductor /Structural 8p' 20" 385 sx Arcticset II 80' 80' Surface 2660' 13-3/8" 2300 sx Fondu 400 sx Permafrost'C' 2660' 2660' Intermediate 8996' 9-5/8" 500 sx Class 'G' 300 sx Permafrost'C' 8996' 8402' Produ tion Liner 1094' 7" 350 sx Class'G' 8722' - 9816' 8144' - 9184' Perforation Depth MD (ft): 8565' - 9580' Perforation Depth TVD (ft): 8942' - 8957' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer Prepared By Name/Number: Si nature ~~~ ~ /~ ~ ~~ ~` - Phone 564-4388 Date .5 2 Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: D O9/O API Number: 50-029-20766-01-00 Permit Approval Date: ( • 0 See cover letter for other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me-t.,h/ane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes t~ No Mud Log Req'd: ^ Yes ~No cc^^hhrr--~~ HZS Measures: I~Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~~w Q! ~ c ~~'C "'F~ ~~-- ~~ APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate IOtI BPXA Prudhoe Bay DS 02-25A CTD Sidetrack May 27, 2008 CTD Sidetrack Summary Pre-Rig Work Summary: (Scheduled to begin on June 15, 2008) 1. S Dummy off all GLM's (passed MIT-IA - 4/2/08) 2. S Pull SSSV 3. S Drift with dummy whipstock 3.625" x 17' to 9300' 4. E Set whipstock at 9192' 5. C Downsqueeze -20bb1 cement past whipstock 6. W Bleed gas lift and production flowlines down to zero and blind flange. 7. W Remove wellhouse, level pad. "" by 3o~s- \`, Rig Sidetrack Operations: (Scheduled to begin on July 15, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Mill 3.80" window at 9,192'. 4. Drill build/turn section with 3.75" x 4.125" bicenter bit, and land well. ;-~ .~ ~~^~~~ 5. Drill lateral section to 11,700'. , V'\ ~ ~1J 6. Run and cement a 3-1/2" x 3-3/16" x 2-7/8" L-80 liner. 7. Make a cleanout run with mill and motor and with a SWS MCNL-GR/SCMT logging tool. 8. Perforate well. 9. Circulate well to KWF brine. FP well to 2000' with diesel. 10. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 11. RDMO Nordic 1. Post-Rig Work: 1. W Pull BPV. 2. O Re-install well house and FLs 3. S Run gas lift design, re-install SSSV 4. T RU test separator, flow test well. 1000' of Perforations Mud Program: • • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.75"x 4.125" (bi-center bits will be used) Casing Program: fully cemented liner • 3-1 /2", L-80, 9.2#, STL 8700'-9100' • 3-3/16", L-80 6.2# TCII 9,100' and - 10,500' and • 2-7/8", L-80 6.16# STL 10,500' and -11,700' and • A minimum of 38 bbls 15.8 ppg cement will be used for liner cementing. (Assuming TD C~ 11,700', and planning on 40% excess in the open hole interval) • TOC planned at TOL Existing casing/tubing Information 13-3/8" 72#, L-80, Burst 5380psi, collapse 2670psi 9 5/8", L-80, 47#, Burst 6870 psi, collapse 4750 psi 7", L-80, 29#, Burst 8160 psi, collapse 7020 psi 5-1/2" L-80, 17# Burst 7740 psi, collapse 6280psi 4-1/2", N-80, 12.6#, Burst 8430psi, collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 90.0 deg at 10,394'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 24,000 ft. • Distance to nearest well within pool -1190 ft. (02-07A, first perforation at 11,400') Logging • MWD directional, Gamma Ray will be run over all of the open hole section. • Cased hole MCNUGR/CCL, logs will be run. Hazards • There is not H2S data recorded for well DS 02-25. • The maximum recorded H2S level on DS 02 was 100 ppm on well 02-29A. • One small fault crossing, lost circulation not expected. Reservoir Pressure • Expected reservoir pressure 3,200 psi at -8,958' TVDSS. (6.87 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,304 psi. M.S.Endacott CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREE _ ? WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV KOP = 3200' Max Angle = 31 @ 6500' Datum MD = 9483' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2660' Minimum ID = 2.62" @ 2157' 5-1 /2" CAMCO DSSSV 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" 0 2 ~2 5 IIV~OMMU I ATION wL/ A (8/ 5 O6) TROL LINE r 2157' S-1/2" CAMCO DB SSSV NIP, ID =4.562" O W/ 5.5 DSSSV (03/24/08), ID = 2.62 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2895 2895 5 CA-MMIG DMY RK 16 03/24/08 2 4965 4810 26 CA-MMIG DMY RK 20 03/24/08 3 6446 6109 30 CA-MMIG DMY RK 0 4 7494 7021 27 CA-MMIG DMY RK 0 5 8158 7619 24 CA-MMIG DMY RK 0 6 8232 7689 24 CA-MMIG DMY RK 0 7 8543 7976 21 CA-MMIG DMY RK 0 8 8618 8046 21 CA-MMIG DMY RKP 0 $646' --~5-1/2" BAKERPBRASSY 8662' 9-5/8" X 5-1/2" BAKER SAB PKR $67$' ~ 5-1/2" X 4-1/2" XO TOP OF 7" LNR ~-1 8722' 4-1/2" TBG-PC, 12.6#, N-80, 8746' .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 8996' PERFORATION SUMMARY REF LOG: BHCS ON 07/08/82 ANGLE AT TOP PERF: 17° @ 9565' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9565 - 9580 O 12/30/06 2-1/8" 6 9568 - 9578 O 01/29/04 3-3/8" 2 9572 - 9578 S 08/23/97 2" 6 9574 - 9578 O 08/15/03 3-1/8" 4 9595 - 9624 S 11/16/89 3-1/8" 4 9627 - 9647 S 11/16/89 3-3/8" 4 9634 - 9649 C 11/27/89 3-3/8" 4 9657 - 9669 C 11/27/89 2-1/2" 6 9670 - 9705 C 01/30/00 3-1/2" 5 968 - 9578 O 08/13/06 PBTD 9770' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9816 DATE REV BY COMMENTS DATE REV BY COMMENTS 7/12/82 ORIGINAL COMPLETION 12/30/06 RRDITLH ADPERFS 06/15/06 CJA/PJC CEMENT SOZ 01/20/07 SWC/PAG MID ID CORRECTION 08/13/06 DRF/PJC RE-PERF 03/29/08 KDC/SV GLV C/O & RESET' DSSSV 08/15/06 BSEJPJC SET DSSSV/ SAFETY NOTE 04/06/08 PJC GLV CORRECTIONS 08/15/06 DAV/TLH GLV C/O 11!23/06 CJN/PJC PULL DSSSV PRUDHOE BAY UN(f WELL: 02-25 PERMIT No: 1820960 API No: 50-029-20766-00 SEC 36, T11 N, R14E, 2450.99' FEL & 3010.77' FNL BP Exploration (Alaska) 8734' -14-1/2" CAM DB-6 LANDING NIP, ID = 3.813" 8745' 4-1/2" BAKER SHEAROUT SUB 8746' 4-1/2" TUBING TAIL 8733 ELMD TT LOGGED 01/30/83 SLM FISH-5 (5-1/2") DB LOCK KEYS & 7 DB LOCK COLLET FINGERS (11/19/06) ~0' ~ TOP OF CEMENT (06/15/06) TREE _ ? WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 64' BF. ELEV = KOP = 3200' Max Angle = 31 @ 6500' Datum MD = 9483' Datum TV D = 8800' SS • O ~ -2 5A OMMU ICATIONB ww/ AI (8/ 5 06) TROL LINE Proposed CTD Sidetrack 13-3/8" CSG, 72#, L-80, ID = 12.347" ( 2660' Minimum ID = 2.62" @ 2157' 5-1 /2" CAMCO DSSSV 2157' 5-1/2" CAMCO DB SSSV NIP, ID =4.562" W/ 5.5 DSSSV (01/16/07), ID = 2.62 to be GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 1 2895 2895 5 CA-MMIG DOME RK 16 08/15/06 2 4965 4810 26 CA-MMIG SO RK 20 08/15/06 3 6446 6109 30 CA-MMIG DMY RK 0 4 7494 7021 27 CA-MMIG DMY RK 0 5 8156 7619 24 CA-MMIG DMY RK 0 6 8232 7689 24 CA-MMIG DMY RK 0 7 8543 7976 21 CA-MMIG DMY RK 0 8 8618 8046 21 CA-MMIG DMY RK?? 0 8646' -{5-1/2"BAKERPBRASSY 8662' ~ 9-5/8" X 5-1/2" BAKER SAB PKR 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" ~ 8672' TOP OF 7" LNR 8722' 15-1/2" X 4-1/2" XO 8700' -{TOP 3-1/2" x 3-3/16" x 2-7/8" LINER 8710' 3-1/2" X NIP2.813" ID 4-1/2" TBG-PC, 12.6#, N-80, 8746' .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 8996' PERFORATION SUMMARY REF LOG: BHCS ON 07/08/82 ANGLE AT TOP PERF: ??? @ 9565' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9565 - 9580 O 12/30/06 2-1 /8" 6 9568 - 9578 O 01 /29/04 3-3/8" 2 9572 - 9578 S 08/23/97 2" 6 9574 - 9578 O 08/15/03 3-1/8" 4 9595-9624 S 11/16/89 3-1/8" 4 9627 - 9647 S 11/16/89 3-3/8" 4 9634 - 9649 C 11 /27/89 3-3/8" 4 9657 - 9669 C 11 /27/89 2-1 /2" 6 9670 - 9705 C 01 /30/00 3-1/2" 5 9868 - 9578 O 08/13/06 PBTD 9770' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9816' $734' 4-1/2" CAM DB-6 LANDING NIP, ID = 3.813" $7414-1/2" BAKER SHEAROUT SUB 8746' 4-1l2" TUBING TAIL 87~ ELMD TT LOGGED 01 /30/83 1/2" x 7"whipstock ~--~ 9192' • 10500' 3-3/16" x 2-7/8" XOV ER I 11660' I 3-1/2" x 3-3/16"x 2-7/8" Liner, Cemented & Perf'd 11700' 9590' TOP OF CEMENT (06/15/061 DATE REV BY COMMENTS DATE REV BY COMMENTS 7/12/82 ORIGINAL COMPLETION 12/30/06 RRD/TLH ADPERFS 06/15/06 CJA/PJC CEMENT SOZ 01/20/07 SWGPAG MID ID CORRECTION 08/13/06 DRF/PJC RE-PEKE 05/07/08 MSE PROPOSED CTD SIDETRACK 08/15/06 BSFJPJC SET DSSSV/ SAFETY NOTE 08/15/06 DAV/TLH GLV GO 11/23/06 CJWPJC PULL DSSSV PRUDHOE BAY UNfr WELL: 02-25A PERMIT No: API No: 50-029-20766-01 SEC 36, T11 N, R14E, 2450.99' FEL & 3010.77' FNL BP Exploration (Alaska) by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P uvTEQ Company: BP Amoco ---- Date: 5/19/2008 Time: - 14:37:09 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 02-25, True North Site: PB DS 02 Vertical (TVD) Reference: 52 :25 6/25/1982 00:00 64.0 j Well: 02-25 Section (VS) Reference: Well (O.OON,O.OOE,90.O OAzi) Wellpatb: Plan 6, 02-25A Survey Calculation Method: Mi ___ _ - nimum Curvature - Db: Sybase Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 19 27 Map Zone: Alaska, Zone 4 ~, Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 - Site: PB DS 02 - -- TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5948800.37 ft Latitude: 70 15 53.847 N From: Map Easting: 687638.44 ft Longitude: 148 28 58.060 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.43 deg Well: 02-25 Slot Name: 25 02-25 Well Position: +N/-S 719.37 ft Northing: 5949498.63 ft Latitude: 70 16 0.922 N +FJ-W -836.35 ft Eas6ng : 686784.47 ft Longitude: 148 29 22.403 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, 02-25A Drilled From: 02-25 500292076601 Tie-on Depth: 9 100.00 ft Current Datum: 52:25 6/25/1982 00 :00 Height 64.00 ft Above System Datum: Mean Sea Level Magnetic Data: 5/13/2008 Declination: 23.33 deg Field Strength: 57679 nT j Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~_ 34.00 0.00 0.00 90.00 Plan: Plan #6 Date Composed: 5/13/2008 ~ copy Mary's plan 6 Version: 6 j Principal: Yes Tied-to: From : Definitive Path Targets Map Map <---- Latitude ----> < -- Longitude ---> Name Description TVD +N/-S +FJ-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. n ft ft ft ft 02-25A Polygon 64.00 -812.46 -2880.69 5948615.00 683925.00 70 15 52.926 N 148 30 46.239 W -Polygon 1 64.00 -812.46 -2880.69 5948615.00 683925.00 70 15 52.926 N 148 30 46.239 W -Polygon 2 64.00 -715.05 -2573.16 5948720.00 684230.00 70 15 53.885 N 148 30 37.290 W -Polygon 3 64.00 -877.17 -2087.00 5948570.00 684720.00 70 15 52.292 N 148 30 23.140 W -Polygon 4 64.00 -979.49 -1189.21 5948490.00 685620.00 70 15 51.288 N 148 29 57.012 W -Polygon 5 64.00 -1285.78 -1141.79 5948185.00 685675.00 70 15 48.276 N 148 29 55.630 W -Polygon 6 64.00 -1076.49 -2722.18 5948355.00 684090.00 70 15 50.330 N 148 30 41.624 W 02-25A Faults 64.00 -855.60 -2351.56 5948585.00 684455.00 70 15 52.504 N 148 30 30.840 W -Polygon 1 64.00 -855.60 -2351.56 5948585.00 684455.00 70 15 52.504 N 148 30 30.840 W -Polygon 2 64.00 -951.57 -2313.93 5948490.00 684495.00 70 15 51.560 N 148 30 29.744 W -Polygon 3 64.00 -1808.93 -2030.10 5947640.00 684800.00 70 15 43.129 N 148 30 21.477 W j -Polygon 4 64.00 -951.57 -2313.93 5948490.00 684495.00 70 15 51.560 N 148 30 29.744 W 02-25A Fault 2 64.00 -803.66 -2630.38 5948630.00 684175.00 70 15 53.013 N 148 30 38.955 W -Polygons 64.00 -803.66 -2630.38 5948630.00 684175.00 70 15 53.013 N 148 30 38.955 W -Polygon 2 64.00 -684.69 -2587.41 5948750.00 684215.00 70 15 54.184 N 148 30 37.706 W 02-25A Fault 3 64.00 -521.30 -2318.26 5948920.00 684480.00 70 15 55.791 N 14830 29.874 W -Polygonl 64.00 -521.30 -2318.26 5948920.00 684480.00 70 15 55.791 N 148 30 29.874 W i -Polygon 2 64.00 -786.70 -2104.76 5948660.00 684700.00 70 15 53.182 N 148 30 23.658 W j j 02-25A Fault 4 64.00 -1029.44 -990.37 5948445.00 685820.00 70 15 50.797 N 148 29 51.225 W -Polygon 1 64.00 -1029.44 -990.37. 5948445.00 685820.00 70 15 50.797 N 148 29 51.225 W ~ -Polygon 2 64.00 -1538.16 -847.94 5947940.00 685975.00 70 15 45.794 N 148 29 47.078 W by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P ~, ~.ii`Y. , i1~iL•{~ Company: BP Amoco ~ Field: Prudhoe Bay i Site: PB DS 02 Well: 02-25 ~Weilpath: Plan 6, 02-25A Annotation MD TVD j ft, ft Date: 5/t9/2008 Time: 14:37:09 Page: 2 Co=ordinate(NE)Refereace: Well: 02-25, True North Vertical (TVD) Reference: 52:25 6!25/1982 00:00 64.0 SecGon(VS)Reference: Well (O.OON,O.OOE,90.OOAzi) Survey Calculation Method: Minimum Curvature Db: Sybase __ - 9100.00 _ 8499.69 TIP 9192.00 8586.80 KOP 9212.00 8605.88 End of 9 Deg/100' DLS 9412.00 8754.00 4 9512.00 8798.76 End of 25 Deg/100' DLS 9572.00 8825.85 6 9672.00 8870.33 7 9852.00 8947.37 Begin 40 Deg/100' DLS ~ 10144.87 9045.40 End of 40 Deg/100' DLS i 10394.87 9045.70 10 ~ 10594.87 9045.54 11 10844.87 9046.02 12 11074.87 9045.36 13 11274.87 9045.57 14 11474.87 9045.77 15 11700.00 0.00 TD Plan Section Information MD Inc! Azim TVD +N/-S +E/-W' DLS Build Tum TFO Target ~ ft deg deg ft ft ft deg/1130ft deg/t00ft deg/100ft deg i, 9100.00 19.18 236.28 8499.69 -1210.16 -2292.91 0.00 0.00 0.00 0.00 j 9192.00 18.34 236.60 8586.80 -1226.52 -2317.57 0.92 -0.91 0.35 173.17 9212.00 16.54 236.60 8605.88 -1229.82 -2322.57 9.00 -9.00 0.00 180.00 9412.00 64.70 261.67 8754.00 -1260.57 -2443.57 25.00 24.08 12.53 30.00 9512.00 63.02 289.51 8798.76 -1252.11 -2531.70 25.00 -1.68 27.84 100.00 9572.00 63.38 281.45 8825.85 -1237.84 -2583.26 12.00 0.59 -13.43 271.00 9672.00 64.00 294.82 8870.33 -1210.00 -2668.17 12.00 0.63 13.37 90.00 9852.00 65.95 318.60 8947.37 -1113.25 -2797.48 12.00 1.08 13.21 90.00 10144.87 89.39 78.89 9045.40 -907.51 -2709.04 40.00 8.00 41.07 104.00 10394.87 90.47 108.87 9045.70 -924.23 -2462.45 12.00 0.43 11.99 88.00 ~ i 10594.87 89.62 84.89 9045.54 -948.01 -2265.34 12.00 -0.43 -11.99 268.00 j 10844.87 90.17 114.88 9046.02 -990.44 -2021.85 12.00 0.22 12.00 89.00 111074.87 90.15 87.28 9045.36 -1034.21 -1798.32 12.00 -0.01 -12.00 270.00 11274.87 89.73 111.28 9045.57 -1066.23 -1602.38 12.00 -0.21 12.00 91.00 11474.87 90.16 87.28 9045.77 -1098.24 -1406.43 12.00 0.22 -12.00 271.00 11700.00 90.14 114.30 9045.16 -1140.00 -1187.33 12.00 -0.01 12.00 90.00 Survey r MD Inc! Azim SS TVD N/S E/W ]14apN MapE DLS VS TFO Too) ft deg dog ft ft` ft ft ft deg/100ft ft deg. __ _ _ - 9100.00 18.18 236.28 8435.69 -1210.16 -2292.91 5948232.03 684522.43 0.00 -2292.91 0.00 MWDI ', 9125.00 18.95 236.36 8459.32 -1214.69 -2299.71 5948227.33 684515.75 0.92 -2299.71 173.17 MWD 9150.00 18.72 236.45 8482.98 -1219.15 -2306.43 5948222.70 684509.14 0.92 -2306.43 173.09 MWD 9175.00 18.50 236.54 8506.67 -1223.56 -2313.08 5948218.13 684502.60 0.92 -2313.08 173.01 MWD 9192.00 18.34 236.60 8522.80 -1226.52 -2317.57 5948215.06 684498.19 0.92 -2317.57. 172.92 MWD 9200 .00 17. 62 236.60 8530 .41 -1227.88 -2319.63 5948213. 65 684496. 16 9.00 -2319.63 180.00 MWDI 9212 .00 16. 54 236.60 8541 .88 -1229.82 -2322.57 5948211. 64 684493. 27 9.00 -2322.57 180.00 MWDI 9225 .00 19. 42 241.49 8554 .25 -1231.87 -2326.01 5948209. 50 684489. 88 25.00 -2326.01 30.00 MWDI 9250 .00 25. 21 247.77 8577 .37 -1235.87 -2334.60 5948205. 29 684481. 39 25.00 -2334.60 25.35 MWD. 9275 .00 31. 16 251.81 .8599 .40 -1239.91 -2345.69 5948200. 98 684470. 41 25.00 -2345.69 19.53 MWD' 9300 .00 37. 21 254.64 8620 .07 -1243.93 -2359.13 5948196. 62 684457. 07 25.00 -2359.13 15.97 MWDI 9325 .00 43. 30. 256.79 8639 .14 -1247.90 -2374.78 5948192. 27 684441. 52 25.00 -2374.78 13.62 MWD 9350 .00 49. 43 258.49 8656 .38 -1251.76 -2392.45 5948187. 98 684423. 96 25.00 -2392.45 11.98 MWD .9375 .00 55. 58. 259.91 8671 .59 -1255.46 -2411.93 5948183. 79 684404. 58 25.00 -2411:93 10.80 MWDI 9400 .00 61. 74 261.13 8684 .59 -1258.97 -2432.98 5948179. 76 684383. 62 25.00 -2432.98 9.94 MW D ~! 9412. 00 64, 70 261.67 8690 .00 -1260.57 -2443.57 5948177. 90 684373. 08 25.00 -2443.57 9.30 MWD; ~ 9425. 00 64: 18 265.22 8695 .61 -1261.91 -2455.22 5948176. 27 684361. 47 25.00 -2455.22 100.00 MWD! 9450. 00 63. 42 272.14 8706 .65 -1262.43 -2477.62 5948175. 19 684339. 08 25.00 -2477.62 98.47 MWDj _9475.00 63. 01 279.12 8717 .93 -1260.25 -2499.82 5948176. 82 684316. 84 25.00 -2499.82 95.41 MWDI by ~ BP Alaska Baker Hu hes INTEQ Plannin Re ort g g P INTEQ Company: BP Amoco" ' _- i Field: Prudhoe Bay Site: PB DS 02 Well: 02-25 Wellpath: Plan 6, 02-25A Survey MD Inc! Azim ;--_ ft deg deg 9500.00 62.93 286.14 9512.00 63.02 289.51 ' 9525.00 63.06 287.76 9550.00 63.19 284.40 9572.00 63.38 281.45 i 9575.00 63.38 281.85 9600.00 63.43 285.21 9625.00 63.55 288.56 9650.00 63.76 291.89 9672.00 64.00 294.82 9675.00 64.00 295.22 i 9700.00 64.05 298.56 9725.00 64.18 301.89 j 9750.00 64.37 305.21 9775.00 64.65 308.52 9800.00 65.00 311.82 9825.00 65.42 315.09 ' 9850.00 65.91 318.34 9852.00 65.95 318.60 9875.00 64.05 328.53 9900.00 62.77 339.63 9925.00 62.39 350.89 9950.00 62.91 2.13 9975.00 64.31 13.19 10000.00 66.52 23.92 10025.00 69.44 34.24 10050.00 72.94 44.14 10075.00 76.90 53.65 10100.00 81.20 62.85 10125.00 85.72 71.83 10144.87 89.39 78.89 10150.00 89.41 79.51 10175.00 89.52 82.50 10200.00 89.63 85.50 10225.00 89.73 88.50 10250.00 89.84 91.50 10275.00 89.95 94.50 10300.00 90.06 97.49 10325.00 90.17 100.49 10350.00 90.28 103.49 10375.00 90.39 106.49 10394.87 90.47 108.87 10400.00 90.45 108.26 10425.00 90.35 105.26 10450.00 90.24 102.26 10475.00 90.13 99.26 10500.00. 90.02 96.26 10525.00 89.92 93.27 10550.00 89.81 90.27 10575.00 89.70 87.27 10594.87 89.62 84.89 10600.00 89.63 85.50 Date: 5!19/2008 Time: 14:37:09 Page: 3 Go~ordinate(NE)Reference: Well: 02-25, True North Vertical (TVD) Reference: 52:25 6/25/1982 00:00 64.0 Section (VS) Reference: WeII (O.OON,O.OOE,90.OOAzi) Survey Calculation Method: Minimum Curvature Db: Sybase SSTW N!S E/W MapN MapE DLS VS T TFO Too ft ft ft ft ft deg/100ft ft deg 8729.30 -1255.38 -2521.53 5948181.15 684295.02 25.00 -2521.53 92.26 MWD 8734.76 -1252.11 -2531.70 5948184.17 684284.77 25.00 -2531.70 89.07 MWD 8740.65 -1248.41 -2542.68 5948187.59 684273.70 12.00 -2542.68 271.00 MWD 8751.95 -1242.23 -2564.11 5948193.23 684252.13 12.00 -2564.11 271.79 MWD 8761.85 -1237.84 -2583.26 5948197.15 684232.88 12.00 -2583.26 273.31 MWD 8763.19 -1237.30 -2585.88 5948197.63 684230.24 12.00 -2585.88 90.00 MWD 8774.39 -1232.07 -2607.61 5948202.31 684208.39 12.00 -2607.61 89.82 MWD 8785.55 -1225.58 -2629.02 5948208.28 684186.83 12.00 -2629.02 88.32 MWD 8796.64 -1217.83 -2650.03 5948215.50 684165.63 12.00 -2650.03 86.82 MWD 8806.33 -1210.00 -2668.17 5948222.87 684147.31 12.00 -2668.17 85.34 MWD 8807.65 -1208.86 -2670.61 5948223.95 684144.84 12.00 -2670.61 90.00 MWD 8818.60 -1198.70 -2690.65 5948233.62 684124.55 12.00 -2690.65 89.82 MWD 8829.51 -1187.38 -2710.08 5948244.45 684104.85 12.00 -2710.08 88.36 MWD 8840.37 -1174.93 -2728.84 5948256.43 684085.78 12.00 -2728.84 86.91 MWD 8851.13 -1161.39 -2746.89 5948269.51 684067.40 12.00 -2746.89 85.47 MWD 8861.77 -1146.80 -2764.18 5948283.67 684049.76 12.00 -2764.18 84.04 MWD 8872.25 -1131.19 -2780.65 5948298.86 684032.91 12.00 -2780.65 82.64 MWD 8882.56 -1114.61 -2796.27 5948315.05 684016.89 12.00 -2796.27 81.27 MWD 8883.37 -1113.25 -2797.48 5948316.38 684015..64 12.00 -2797.48 79.93 MWD 8893.11 -1096.51 -2809.85 5948332.80 684002.86 40.00 -2809.85 104.00 MWD 8904.33 -1076.46 -2819.61 5948352.61 683992.61 40.00 -2819.61 99.79 MWD 8915.87 -1055.05 -2825.25 5948373.87 683986.44 40.00 -2825.25 94.81 MWD 8927.39 -1032.93 -2826.59 5948395.95 683984.55 40.00 -2826.59 89.61 MWD 8938.53 -1010.79 -2823.60 5948418.16 683986.99 40.00 -2823.60 84.43 MWD 8948.96 -989.29 -2816.36 5948439.83 683993.69 40.00 -2816.36 79.50 MWD 8958.35 -969.08 -2805.10 5948460.31 684004.45 40.00 -2805.10 75.03 MWD 8966.43 -950.78 -2790.15 5948478.97 684018.94 40.00 -2790.15 71.15 MWD 8972.94 -934.95 -2771.98 5948495.25 684036.71 40.00 -2771.98 67.95 MWD 8977.70 -922.07 -2751.12 5948508.64 684057.24 40.00 -2751.12 65.47 MWD 8980.55 -912.52 -2728.23 5948518.76 684079.88 40.00 -2728.23 63.72 MWD 8981.40 -907.51 -2709.04 5948524.24 684098.95 40.00 -2709.04 62.69 MWD 8981.45 -906.55 -2704.00 5948525.33 684103.96 12.00 -2704.00 88.00 MWD 8981.69 -902.64 -2679.31 5948529.85 684128.54 12.00 -2679.31 87.99 MWD 8981.87 -900.03 -2654.45 5948533.07 684153.33 12.00 -2654.45 87.97 MWD 8982.01 -898.72 -2629.49 5948535.00 684178.25 12.00 -2629.49 87.94 MWD 8982.11 -898.72 -2604.49 5948535.62 684203.24 12.00 -2604.49 87.93 MWD 8982.15 -900.02 -2579.53 5948534.94 684228.22 12.00 -2579.53 87.92 MWD 8982.15 -902.64 -2554.67 5948532.94 684253.14 12.00 -2554.67 87.91 MWD 8982.10 -906.54 -2529.98 5948529.65 684277.92 12.00 -2529.98 87.91 MWD 8982.00 -911.74 -2505.53 5948525.06 684302.49 12.00 -2505.53 87.92 MWD 8981.85 -918.20 -2481.38 5948519.20 684326.78 12.00 -2481.38 87.93 MWD 8981.70 -924.23 -2462.45 5948513.64 684345.86 12.00 -2462.45 87.95 MWD 8981.66 -925.87 -2457.59 5948512.13 684350.76 12.00 -2457.59 268.00 MWD 8981.49 -933.07 -2433.65 5948505.52 684374.86 12.00 -2433.65 268.00 MWD 8981.36 -939.02 -2409.37 5948500.18 684399.28 12.00 -2409.37 267.97 MWD 8981.28 -943.69 -2384.82 5948496.12 684423.95 12.00 -2384.82 267.96 MWD 8981.25 -947.06 -2360.05 .5948493.36 684448.79 12.00 -2360.05 267.95 MWD 8981.26 -949.14 -2335.14 5948491.90 684473.74 12.00 -2335.1.4 267.95 MWD 8981.32 -949.91 -2310.15 5948491.75 684498.74 12.00 -2310.15 267.95 MWD 8981.43 -949.37 -2285.16 5948492.91 684523.71 12.00 -2285.16 267.95 MWD 8981.54 -948.01 -2265.34 5948494.76 684543.49 12.00 -2265.34 267.97 MWD 8981.58. -947.58 -2260.23 5948495.32 684548.59 12.00 -2260.23 89.00 MWD • by ~ BP Alaska ~ •'`~ Baker Hu hes INTEQ Plannin Re ort g g P tNT~ I~ Company: BP AmoCO Date: 5/1.9!2008 Time: 14:37:09 Page: 4 Field:. Prudhoe Bay Go-ordinste(NE) Reference: Well: 0225, True North Site: PB DS 02 Vertical (TVD) Reference: 52:25 6/25/1982 00:00 64. 0 WeIL• 02 -25 Section (VS}Reference: Well (O.OON,O.OOE,90.OOAz i) ~ Wellpath: Plan 6, 0225A Survey Calculation McWod: Minimum Curvatu re Db: Sybase Survey MD ' Intl Azitn ^ SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg tleg ft ft ft ft ',ft deg/100ft ft deg 10625.00 89.68 - 88.50 - 8981.73 -946.27 -2235.27 5948497.24 684573.51 12.00 -2235.27 89.00 - MWD 10650.00 89.74 91.50 8981.85 -946.28 -2210.27 .5948497.86 684598.49 12.00 -2210.27 88.98 MWD 10675.00 89.79 94.50 8981.96 -947.58 -2185.31 5948497.17 684623.48 12.00 -2185.31 88.96 MWD 10700.00 89.85 97.50 8982.04 -950.20 -2160.45 5948495.18 684648.40 12.00 -2160.45 88.95 MW D 10725.00 89.90 100.50 8982.09 -954.11 -2135.76 5948491.88 684673.17 12.00 -2135.76 88.94 MWD 10750.00 89.96 103.50 8982.12 -959.30 -2111.31 5948487.30 684697.74 12.00 -2111.31 88.93 MWD 10775.00 90.01 106.50 8982.13 -965.77 -2087.16 5948481.43 684722.04 12.00 -2087.16 88.93 MWD 10800.00 90.07 109.50 8982.11 -973.50 -2063.39 5948474.30 684746.00 12.00 -2063.39 88.93 MWD 10825.00 90.13 112.50 8982.07 -982.45 -2040.05 5948465.92 684769.55 12.00 -2040.05 88.93 MWD 10844.87 90.17 114.88 8982.02 -990.44 -2021.85 5948458.39 684787.93 12.00 -2021.85 88.94 MWD 10850.00 90.17 114.27 8982.00 -992.57 -2017.19 5948456.38 684792.65 12.00 -2017.19 270.00 MWD 10875.00 90.17 111.27 8981.93 -1002.24 -1994.14 5948447.28 684815.93 12.00 -1994.14 270.00 MWD i 10900.00 90.17 108.27 8981.85 -1010.70 -1970.61 5948439.41 684839.66 12.00 -1970.61 269.99 MWD ' ~I 10925.00 90.17 105.27 8981.78 -1017.91 -1946.68 5948432.80 684863.76 12.00 -1946.68. 269.98 MWD it 10950.00 90.17 102.27 8981.71 -1023.85 -1922.40 5948427.46 684888.18 12.00 -1922.40 269.97 MWD. 10975.00 90.16 99.27 8981.64 -1028.52 -1897.84 5948423.40 684912.84 12.00 -1897.84 269.96 MWDI; 11000.00 90.16 96.27 8981.57 -1031.90 -1873.08 5948420.64 684937.69 12.00 -1873.08 269.95 MWDI 11025.00 90.16 93.27 8981.50 -1033.98 -1848.17 5948419.18 684962.64 12.00 -1848.17 269.95 MWDI 11050.00 90.15 90.27 8981.43 -1034.75 -1823.18 5948419.03 684987.63 12.00 -1823.18 269.94 MWDI 11075.00 90.15 87.28 8981.36 -1034.21 -1798.19 5948420.19 685012.60 11.94 -1798.1.9 269.93 MWDI 11100.00 90.10 90.30 8981.31 -1033.68 -1773.20 5948421.33 685037.57 12.06 -1773.20 91.00 MWDI 11125.00 90.04 93.30 8981.28 -1034.47 -1748.21 5948421.17 685062.57 12.00 -1748.21 91.01 MWDI 11150.00 89.99 96.30 8981.27 -1036.56 -1723.30 5948419.70 685087.52 12.00 -1723.30 91.01 MWD~i 11175.00 89.94 99.29 8981.29 -1039.95 -1698.54 5948416.92 685112.36 12.00 -1698.54 91.01 MWD 11200.00 89.89 102.29 8981.32 -1044.63 -1673.98 5948412.85 685137.02 12.00 -1673.98 91.01 MWD 11225.00 89.83 105.29 8981.38 -1050.59 -1649.71 5948407.50 685161.44 12.00 -1649.71 91.00 MWD 11250.00 89.78 108.29 8981.47 -1057.81 -1625.77 5948400.87 685185.54 12.00 -1625.77 91.00 MWD 11275.00 89.73 111.28 8981.58 -1066.28 -1602.25 5948392.99 685209.26 11.94 -1602.25 90.99 MWD 11300.00 89.78 108.26 8981.68 -1074.73 -1578.73 5948385.13 685232.99 12.06 -1578.73 271.00 MWD 11325.00 89.84 105.26 8981.76 -1081.94 -1554.80 5948378.52 685257.09 12.00 -1554.80 271.01 MWD 11350.00 89.89 102.26 8981.82 -1087.88 -1530.52 5948373.17 685281.51 12.00 -1530.52 271.02 MWD 11375.00 89.94 99.26 8981.86 -1092.55 -1505.96 5948369.12 685306.17 12.00 -1505.96 271.03 MWD 11400.00 90.00 96.26 8981.87 -1095.93 -1481.19 5948366.35 685331.02 12.00 -1481.19 271.03 MWD 11425.00 90.05 93.26 8981.86 -1098.00 -1456.28 5948364.90 685355.97 12.00 -1456.28 271.04 MWD 11450.00 90.11 90.27 8981.83 -1098.77 -1431.29 5948364.75 685380.96 12.00 -1431.29 271.03 MWD 11475.00 90.16 87.28 8981.77 -1098.24 -1406.30 5948365.91 685405.93 11.94 -1406.30 271.03 MWD 11500.00 90.16 90.30 8981.70 -1097.71 -1381.31 5948367.05 685430.90 12.06 -1381.31 90.00 MWD 11525.00 90.16 93.30 8981.63 -1098.49 -1356.33 5948366.89 685455.90 12.00 -1356.33 90.01. MWD ~ 11550.00 90.16 96.30 8981.56 -1100.58 -1331.42 5948365.42 685480.85 12.00 -1331.42 90.02 MWD i 11575.00 90.16 99.30 8981.49 -1103.98 -1306.65 5948362.64 685505.69 12.00 -1306.65. 90.03 MWD 11600.00 90.15 102.30 8981.42 -1108.66 -1282.10 5948358.57 685530.35 12.00 -1282.10 90.03 MWD ', 11625.00 90.15 105.30 8981.35 -1114.62 -1257.82 5948353.21 685554.77 12.00 -1257.82 90.04 MWD 11650.00 90.15 108.30 . 8981.29 -1121.84 -1233.89 5948346.58 685578.87 12.00 -1233.89 90.05 MWDI 11675.00 90.15 111.30 8981.22 -1130.31 -1210.37 5948338.71 685602.59 12.00 -1210.37 90.06 MWD I 11700.00 90.14 114.30 _ 8981.16 _ 1140.00 -1187.33 5948329.60 685625_87 12.00 -1187.33 90.07 _ 2_87 BP Alaska ~ar~;~, r~r al~pN~: 0:-:! ~wTN an MD: MOD.DO AFB: R v. Datu~w. D.~;32.a31DO'~N'19 imm MD MAD11 D D a a a I~~~spYy LEGEND Nws iozz az-zsy ~/~/i ~ 02-25 (02-25) n° ° ~ vI ~~ BA fAiflR Plan 6, 02-25A .r :am zz vian as "°' NuaNC by msn~~sF,='~ °°~n~,,,°~ 1NTEQ 'b°°"°°°"'~' ~mMi~°~ °~~'e,'°~ ea<o°, • • Vertical Sectbn at 80.00' [SOfNn[ • We~~ DS 02-39 ~ 2.25 9.23 ~_ • ~ ud Cross 14.89 HCR '!M Fiydril Annular 7 1116" Annular x 5000 psi - - 7 1;16" 5000 psi, RX-46 Blind Shears TOT 2.3?S Combi's 7 1116" 5000 psi RX-46 R,4ud Cross I Choke Line .r 16.10 ~- 23E' K: ::' Varlat}le Ba 16.66 `._ ~ 2.3?s" Com TOT ~- 7 1,'16" X 3 tiB" Flanged Adapter Swab Valve SSV Master Vabe Ground Level Alaska Department of Natural Resources Land Administration System Page 1 of~'~ ..: ~~ :T:~,~ .j~3~;,~ t :jr~a '..::~~r: ~'~~~., ~ pis Recorci2r`s Search State Cabins ~~tlf8~ Sr~4!['~S Alaska D'NR Case summary File Type: A~~ File Number: ~ 28308 -o Printable Case File Summary See Township, Range, Section and Acreage? Yes No New Search !_,4S Mer,!~ !Case Abstract !Case Detail ~ band Abstract ~~, Pi/e: .4DL 28308 ''~~'~° Search fcr Status Plat Updates =~~ of UG/0~)%200$ Czrstomer.~ 000107377 BP EXPLORATION (ALASKA)1NC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 's~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DN OIL AND GAS Corse Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/] 965 Office of primary Responsibilith~ DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype : NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT AP PROVED Meridian: U Township: 011 N Range: O l 4E Sectinn: 25 Seett~~fr , ~ eras: 640 Search Plats llferi~(iair: U 7~ncr~~hri~: 01 1 ti~ Run,~re.~ 014E Section: 26 .S~~~c~iufz .4eres: 640 1~1E~rr~liun~ U l~~tir~t~hi/~: Ol1N I~u~~~e.~ 014E Sutton: 35 ~~'c~clir~rr:tcr~~~.~ (~~~0 Mf~ridiut~~ L1 lnirirship: U1IN Range: 014E ,Section: 36 Sec~[inn~-lcrrs.~ 6-10 Legal. Description OS-28-1965 * * *SALE NOTICE LEGAL DESCRI~TION~** Clot-12911N ICE UM2~,26,35,362560.00 U- 3:. 7 ~~td ~f Case ~ nary Last updated on 06/09/2008. http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumbet=28308&... 6/9/2008 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~~"~S~ ' PTD# ~~~~ 9~~ ~Development~ Service Exploratory Stratigraphic Test Non-Conventional Well t FIELD: /~-.~1/d.S~OE' ~!~ Y 'POOL: ~,e~/.Q~DE L~f ~ ~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{f), 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 / infect is contingept 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 throu h tar et 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 Narae) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. S,ComQany Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 1/1 !2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Weli Name: PRUDHOE BAY UNIT 02-25A Program DEV Well bore seg ^ PTD#:2080910 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11650 OnlOif Shore On Annular Disposal ^ Administration 1 Pe[mitfee atia4hed- - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate---- -. _ -- -----Yes-- -- -- - ---- - ------ - ---- - - -- 3 Unique well-nameandnumber------------- -- - - - - Yes--- - --- - - - -- -- -------- - --- -- - - --- -- - 4 WeIIIQCatedin_a_definedpool______________-__-______ _______Yes__-___ _PrudhoeBayFieldlP[udhoeBayP9ol.____________________________________________ 5 Well located Proper distancef[omdrillingun~_boundary--------------- --- Yes------ ----------------------_-------------------------------------____-- 6 Well locatedp[operdistancefromotherwelis_____-__-__-_--_--- -_---_---Yes-_--- ----------------__- ------------------------------------------------- 7 Sufficient acreageayailableindrillinqunit___-______--_______ ______--Yes------ -2569 acres-------------__--_---__________________-__-- -------------- 8 If deviated, is wellb2re Plat_included - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 9 OpetatoronlyaffectedPaRY------------ ---- ----- - - --Yes------ - -- - -- ----- ---- -- -- - - -- - 10 Ope~atolhes_apProPriatebondNforGe------------------------ ---------Yes------ -ElenketBond#61641g$---------------------------------------------------- 11 Pet'mitcanbeissuedwAhQUtCOnservatignorder----------------- ---------Yes------ ----------------------------------------------------------------- Appr Date 12 Permitcanbeisstledwhhoutadminist[ative_app[ovel________________ _________Yes__--_ -------_-----------_----_._____-______-_ -------------------------- ACS 61912008 13 CanPertnAbeAPRr4vedbef9re15-daY-wait---------------------- ---------Yes------ ------------------------------------------------------------------ 14 Well located within area and_sfrata authorized by_Injection Order ~ (pui_10# in_comments)_(F4r- NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - _ - - _ - - _ - - - _ - - - _ _ - - _ - - - - - - - - - - - - _ _ 15 Allwells_within1l4_mileereeofreyiev_uiderrtified(Forservieewelipnly)__-_ _________ NA_-_____ ______________________--------___----_--,---_------- - --~ - - - - 16 Pre•Rroducedinjector.durationofPreProductionlessthan3months_(1=orse[viceweltonly)___t~--____ _______________________________--_---_-_____---------__ _ -_--_ 17 Noncornen,9asc9of9rmstoA$31,05,0~Q(1.1.A),(1.2.A-D)-- --- -- - - -- NA --- - ----- - ---------- -------- ------- - -- - --- - Engineering 16 Copduciorstnrtg-Rrovided-------------------------------- _-_--___KA_------ _Ccnduct4rsetint)502-25(18.996).---------------------------.--------------_- 19 Su[facecasingpr4fectsaliknownUSDWS_____________________ _________ NA_______ _NOaquifers,_AIQ4l3,_conFlusion5.-___-__________ 20 CMT_v_oladequate_tocirculateonconductor~sun`csg_______________ __________KA____ _Surfacecasing SetiRRS92-25._--__-_---_--________-__-___-______-___________ 21 CMT_voladequate_tgtie-iniongstringtosurfcsg______.___--___- --____-__ NA_______ _Productioncasingseiin_D$02-25,__________--___________--------------------- , 22 CMT_wilJcoyerallknown-produciivehorizons__________________ __ ___--Yes------ ----.--------------._---------------------_----------------____-- 23 Casing designs adequate for G,TB&_permafrost --- -- -- ------ -- Yes_ - -- -- - - -- -- ----~-- ------ ---- - --- - -- 24 -Adequate tankage_ or reserye pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - _ - - _ Rig equipped with gfeel pits. No rQServe pif planned._ Ali waste_to approved disposal well(s), - - _ _ - _ _ _ _ _ _ _ _ 25 Ifa-re-drill,has-a10.403forabandonment been approved----------- --------Yes------ .308-191------------------------------------------------------------ 26 Adequate wehbote separation proposed. _ _ _ _ .. - _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - _ - No proximity issues reported._ All drilling work within reservoir. . - - _ - - - - - - _ - - _ , - _ - - _ _ _ - _ _ _ _ 27 Ifdiverter-regalred, doesitmeetregulations__________________ __.______NA------- -@OPStaGkwillalreadY-be in place,-----------------------------------_------- Appr Date 28 Drilling fluid program schematic & equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - _ _ - - -Maximum expected formation pressure 6,9_ EMW._ MW planned 8.6 ppg. _ - - _ _ - _ _ _ - _ _ _ _ _ _ - TEM 611212008 29 BOPEs,dothey-meet regulati9a---------------------------- ---------Yes------ ----------------------------------------------------------------- 30 ROPEpress rating appropriate; test to_(put prig in comments)- - - - - - - - - - - - - - - - - - - -Yes MASP calculated at 2304psi, 3500_psi_BOP testplanned, _ - _ - ----------------------- 31 Choke-manifold complieswlAPI_RP-53 (May 64)- - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Workwilioccurwithoutoperationshutdown___________________ _____Yes------ --------------------_----------------------------------.,- __--- 33 Is presence of N2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - _ _ H2$ is repeded_on DS_ 2. ,Mud should preclude on rig._ Rig has sensors and alarms. _ - - _ - - - - - - - - , - _ 34 Mechanical_cgnditionofweltswithinAORverified(_FCrservicewellontya___- -____-___ NA_--___ _____________________________--_--_--__,-_-----_------_ --- _-- Geology 35 Permft-can be issuedwlo hydrogen_suifiida measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ - - _ - - - _ Max H~$ level on-DS 2 was 100ppm for well_02-29A._ _ _ _ _ _ _ _ _ _ - _ --------------------- 36 Data-pJesented on Roiential9verpressurezgnes- - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 37 Seismicana{ysisofshallowgas_zones------------------------- --------- NA------- -------------------------__- ACS 61912008 38 SeabedcQnditionsurYey_(ifoff_-shore)_________________________ _____.__ NA____ - ------------------------------------ ---------------------------------------------- 39 ContaCtname/phoneforweekly_progressrep9ds(exploratoryor~ly]_____- _______--Yes----- -MaryEndacetf-564.4388.-------------------------------------------_----- Geologic Engineering P Commissioner: Date: Commissioner: Date is ' er Date ~~~~ ~~~g 6-~z-o9 • iNell History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 08/12/09 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/08/21 2143355 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9088.0000: Starting Depth STOP.FT 11731.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 02-25A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 16' 0.922"N 148 deg 29' 22.403"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 21 Aug 2008 API API NUMBER: 500292076601. Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 24 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 64 DMF DF EKB .F 0 EDF .F 64 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. • (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tool s ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Pri mary Depth Control) log provided by Schlumberger GR CNL dated 23 Aug 2008 per Priya Maraj with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 02-25 through a milled window in a 7 inch liner. Top of window 9196 ft.MD (8526.6 ft.TVDSS) Bottom of window 9200 ft.MD (8530.4 ft.TVDSS) (9) Tied to 02-25 at 9100 feet MD (8435.7 feet TVDSS). (10) The interval from 11688 feet to 11728 feet MD (8979.0 feet to 8977.2 feet TVDSS) was not logged due to sensor to bit offset at well TD. (11) The resistivity from 9192 feet to 10202 feet MD (8522.8 feet to 8988.9 feet TVDSS) was re-logged on run 6 70.9 hours after being drilled. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP AVG -> Rate of Penetration, feet/hour _ RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 9090.16, 9089.96, ! -0.207031 9092.03, 9092.24, ! 0.207031 9094.72, 9094.31, ! -0.414062 9096.18, 9095.76, ! -0.415039 9103.02, 9103.02, ! 0 9108.61, 9109.24, ! 0.62207 9119.81, 9119.39, ! -0.415039 9121.05, 9120.84, ! -0.208008 9123.75, 9123.95, ! 0.207031 9128.1, 9127.68, ! -0.415039 9132.66, 9132.45, ! -0.208008 9136.39, 9136.6, ! 0.207031 9138.26, 9138.05, ! -0.207031 9139.5, 9139.92, ! 0.414062 9145.93, 9145.72, ! -0.207031 9147.38, 9147.58, ! 0.207031 9149.87, 9150.07, ! 0.208008 9155.88, 9155.46, ! -0.414062 9192.71, 9195.4, ! 2.69434 9201.62, 9201.83, ! 0.208008 9202.45, 9203.07, ! 0.62207 9203.9, 9204.73, ! 0.829102 9208.05, 9208.05, ! 0 9209.92, 9210.54, ! 0.62207 9211.57, 9211.99, ! 0.415039 9213.44, 9214.48, ! 1.03613 9220.9, 9221.32, ! 0.414062 9223.8, 9224.01, ! 0.208008 • 9226.08, 9226.08, 9228.99, 9229.4, 9232.71, 9232.92, 9241.62, 9241, 9244.73, 9244.11, 9247.22, 9247.01, 9256.13, 9256.13, 9258.41, 9258.62, 9274.38, 9274.58, 9276.66, 9276.86, 9278.73, 9279.14, 9282.05, 9281.63, 9299.44, 9300.27, 9302.76, 9303.59, 9309.81, 9310.84, 9311.67, 9312.09, 9314.37, 9314.78, 9315.61, 9316.44, 9327.01, 9327.63, 9332.4, 9332.4, 9334.48, 9334.89, 9337.58, 9336.55, 9338.83, 9337.79, 9351.47, 9352.5, 9404.94, 9405.56, 9408.26, 9408.67, 9409.92, 9410.33, 9412.82, 9413.23, 9447.68, 9447.68, 9453.49, 9453.07, 9504.94, 9504.94, 9531.83, 9531, 9544.68, 9546.13, 9550.49, 9550.28, 9552.15, 9551.94, 9568.72, 9568.31, 9596.91, 9596.91, 9600.02, 9601.06, 9604.17, 9603.75, 9610.74, 9611.36, 9628.56, 9628.56, 9630.43, 9630.84, 9639.16, 9634..37, 9636.65, 9636.44, 9642.04, 9643.49, 9647.22, 9649.92, 9653.23, 9654.48, 9667.33, 9667.74, 9673.75, 9674.17, 9676.45, 9676.86, 9704.58, 9702.29, 9710.79, 9710.38, 9755.3, 9755.92, 9757.37, 9757.78, 9760.69, 9761.1, 9762.76, 9763.17, 9770.84, 9771.88, 9786.18, 9786.18, 9795.51, 9796.34, 9799.66, 9800.07, 9818.36, 9817.73, 9825.61, 9824.78, 9828.1, 9827.48, 9830.59, 9830.79, 9833.9, 9833.07, 9838.67, 9838.05, 9843.02, 9841.99, 0 0.415039 0.207031 -0.621094 -0.621094 -0.208008 0 0.208008 0.208008 0.207031 0.414062 -0.414062 0.829102 0.829102 1.03613 0.415039 0.414062 0.829102 0.62207 0 0.415039 -1.03613 -1.03613 1.03613 0.62207 0.415039 0.415039 0.415039 0 -0.415039 0 -0.829102 1.45117 -0.207031 -0.207031 -0.415039 0 1.03613 -0.415039 0.62207 0 0.414062 0.207031 -0.207031 1.45117 2.69434 1.24316 0.415039 0.415039 0.414062 -2.28027 -0.414062 0.62207 0.414062 0.415039 0.414062 1.03711 0 0.829102 0.415039 -0.62207 -0.830078 -0.62207 0.207031 -0.829102 -0.62207 -1.03613 9846.34, 9845.72, 9848.83, 9848.21, 9850.9, 9850.69, 9856.71, 9857.54, 9869.97, 9869.14, 9872.05, 9871.22, 9891.93, 9891.1, 9895.45, 9894.21, 9901.88, 9899.19, 9911.83, 9908.93, 9914.94, 9913.28, 9918.26, 9916.6, 9920.12, 9918.46, 9927.79, 9925.72, 9929.66, 9927.79, 9931.94, 9929.66, 9940.44, 9938.99, 9951.72, 9948.61, 9954.21, 9951.31, 9965.2, 9960.64, 9968.72, 9966.03, 9973.9, 9970.17, 9975.35, 9972.04, 9984.27, 9980.95, 9986.34, 9983.65, 9990.07, 9986.96, 9993.8, 9991.52, 10001.9, 9997.95, 10007.1, 10002.8, 10012.5, 10008.4, 10015, 10011.1, 10021.6, 10016.4, 10024.5, 10019.3, 10027, 10022, 10043.6, 10039.9, 10047.3, 10041.9, 10052.7, 10047.1, 10054.4, 10049.4, 10059.1, 10054.6, 10074, 10068.8, 10090.1, 10084.1, 10095.7, 10090.1, 10098.6, 10092.2, 10103.8, 10097.6, 10106.7, 10101.5, 10113.3, 10108.4, 10115.4, 10110, 10127.6, 10121.4, 10135.7, 10130.1, 10140.7, 10134.5, 10141.7, 10135.5, 10147.3, 10141.7, 10159.8, 10152.5, 10164.1, 10157.1, 10167.3, 10160.7, 10169.4, 10163.4, 10175.4, 10168.6, 10178.7, 10172.3, 10201.1, 10192.2, 10234.3, 10232.2, 10237.8, 10235.7, 10241.3, 10238.6, 10242.6, 10240.7, 10244, 10242.1, 10247.1, 10244.6, 10251.3, 10248.4, 10256, 10252.5, -0.62207 -0.62207 -0.208008 0.829102 -0.830078 -0.829102 -0.829102 -1.24316 -2.69531 -2.90234 -1.6582 -1.6582 -1.65918 -2.07324 -1.86523 -2.28027 -1.45117 -3.10938 -2.90234 -4.56055 -2.69531 -3.73145 -3.31641 -3.31641 -2.69531 -3.11035 -2.28027 -3.93848 -4.35254 -4.14551 -3.93848 -5.18164 -5.18262 -4.97461 -3.73145 -5.38965 -5.59668 -4.97461 -4.55957 -5.18164 -6.01172 -5.59668 -6.42676 -6.21875 -5.18262 -4.97559 -5.38965 -6.21875 -5.59668 -6.21875 -6.21875 -5.59668 -7.25488 -7.04785 -6.63379 -6.01074 -6.84082 -6.42676 -8.91406 -2.07324 -2.07324 -2.69434 -1.86621 -1.86621 -2.48828 -2.90234 -3.52344 10266.7, 10265.7, 10272.1, 10271.5, 10275.2, 10273.7, 10278.5, 10277.3, 10286.2, 10285.1, 10288.3, 10286.8, 10291.2, 10289.5, 10297.8, 10294.7, 10299, 10297.4, 10305.7, 10304.4, 10307.7, 10307.5, 10313.1, 10311.7, 10315.3, 10313.5, 10321.6, 10320.3, 10327.4, 10325.1, 10512.8, 10512.3, 10518.6, 10517.3, 10525.4, 10522.9, 10536.6, 10534.1, 10537.8, 10535.4, 10554.2, 10553, 10564.4, 10563.5, 10568.9, 10567.1, 10584.7, 10584.5, 10586.5, 10586.1, 10607.7, 10605.5, 10610.8, 10608.1, 10611.9, 10610.4, 10614.8, 10612.7, 10640.8, 10641.1, 10656.2, 10654.1, 10815.6, 10813.5, 10826.6, 10827, 10830.1, 10829.7, 10836.1, 10833.6, 10841.9, 10837.6, 10864, 10861.1, 10880.8, 10877.1, 10889.9, 10887.2, 10893.6, 10890.5, 10905.5, 10901.7, 10918.9, 10916, 10923.1, 10919.1, 10926.8, 10923.3, 10930.7, 10927.8, 10932.4, 10930.5, 10935.7, 10932.8, 10937.6, 10934.5, 10939.7, 10937.2, 10941.5, 10938.8, 10943.6, 10941.5, 10948.4, 10946.5, 10952.7, 10950.9, 10957.9, 10956.9, 10982.4, 10979, 10987.9, 10984, 10992.1, 10987.5, 10999.6, 10994.8, 11005.1, 11000.8, 11009.7, 11005.6, 11013.6, 11010.7, 11018.2, 11015.3, 11026.7, 11025.7, 11058.1, 11054.2, 11062, 11057.9, 11067.8, 11063.9, 11069.9, 11066.6, ! -1.03613 ! -0.62207 ! -1.45117 ! -1.24316 ! -1.03613 ! -1.45117 ! -1.6582 ! -3.11035 -1.6582 ! -1.24414 ! -0.208008 ! -1.45117 ! -1.86621 ! -1.24414 ! -2.28027 ! -0.415039 ! -1.24316 ! -2.4873 ! -2.4873 ! -2.48828 -1.24414 ! -0.829102 ! -1.86621 ! -0.207031 ! -0.415039 ! -2.28027 ! -2.69434 ! -1.45117 ! -2.07227 ! 0.208008 ! -2.07227 ! -2.07324 0.414062 ! -0.415039 ! -2.4873 ! -4.35352 -2.90137 ! -3.73145 ! -2.69434 ! -3.10938 ! -3.73145 -2.90234 ! -3.93848 ! -3.52344 ! -2.90137 ! -1.86523 ! -2.90234 ! -3.10938 ! -2.4873 ! -2.69434 ! -2.07324 ! -1.86523 ! -1.86523 ! -1.03711 -3.31738 -3.93848 ! -4.56055 ! -4.76855 ! -4.35352 ! -4.14551 ! -2.90234 ! -2.90234 ! -1.03613 ! -3.93848 -4.14551 ! -3.93945 ! -3.31641 11072.4, 11069.9, 11081.1, 11079.7, 11094.8, 11093.3, 11097.9, 11095.4, 11100, 11097.5, 11105.4, 11101, 11109.5, 11104.7, 11111.8, 11107.8, 11114.1, 11110.1, 11116.3, 11113.4, 11124.1, 11120.9, 11127.2, 11123.4, 11129.9, 11125.9, 11135.2, 11135.2, 11155.4, 11153.5, 11156.8, 11155.4, 11158.7, 11158.3, 11184.9, 11183.2, 11215.8, 11214.1, 11233.2, 11233, 11258.1, 11256.1, 11261.5, 11258.4, 11291.5, 11287.2, 11296.1, 11291.1, 11330.4, 11325.4, 11332.2, 11330.6, 11334.5, 11333.1, 11347.8, 11347, 11372.2, 11375.1, 11380.5, 11383.8, 11385, 11388.8, 11395.4, 11394, 11400, 11398.9, 11403.3, 11401.4, 11405.6, 11403.9, 11410.5, 11408.3, 11414.9, 11411.6, 11418.2, 11415.7, 11421.1, 11419.5, 11424.2, 11424.4, 11425.9, 11425.9, 11429.4, 11430, 11432.9, 11435.2, 11435.6, 11438.7, 11440.4, 11443.1, 11442, 11445.4, 11445.6, 11449.3, 11451, 11455.1, 11453.9, 11457.8, 11455.9, 11461.9, 11459.5, 11465.9, 11461.3, 11467.5, 11464.2, 11470.2, 11502.8, 11506.5, 11535.1, 11538.8, 11540.1, 11543.8, 11543.6, 11546.5, 11547.1, 11549, 11549.6, 11551.7, 11552.1, 11554.4, EOZ END ! BASE CURVE: GROH, Tape Subfile: 1 -2.4873 -1.45117 -1.45117 -2.48828 -2.4873 -4.35254 -4.76855 -3.93848 -3.93848 -2.90234 -3.10938 -3.73047 -3.93848 0 -1.86523 -1.45117 -0.415039 -1.6582 -1.6582 -0.208008 -2.07324 -3.10938 -4.35254 -4.97461 -4.97559 -1.6582 -1.45117 -0.830078 2.90234 3.31641 3.73145 -1.45117 -1.03613 -1.86621 -1.65918 -2.28027 -3.31738 -2.4873 -1.6582 0.207031 0 0.62207 2.28027 3.10938 2.69434 3.31641 3.73047 4.14551 3.93945 6.01172 6.42578 6.21875 6.01172 3.73145 3.73145 3.73047 2.90234 1.86523 2.07324 2.28027 OFFSET CURVE: GRAX 366 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 02-25A 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN 02-25A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 23 Aug 2008 per Priya Maraj with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------------------ CNAM - ODEP GR GR - ---------- GRAX ----------------- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 147 Tape File Start Depth = 9088.000000 Tape File End Depth = 11730.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .002 1024 160 records... 54 bytes 4124 bytes *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 02-25A.xtf LCC 150 CN BP Exploration (Alaska) WN 02-25A APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** • !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: CIFO MNEM ----- CHAN DIMT ------------------ CNAM ----------- ODEP - ---- GR GR - GRAX ---------- -- 0.0 ROP ROP ROPA 0.0 RAD RAD RACLX 0.0 RAS RAS RACHX 0.0 RPD RPD RPCLX 0.0 RPS RPS RPCHX 0.0 C7 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM Total Data Records: 294 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9088.000000 Tape File End Depth = 11728.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 307 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/08/21 2143355 01 **** REEL TRAILER **** MWD 08/12/09 BHI O1 • Tape Subfile: 4 2 records... v Minimum record length: 132 bytes Maximum record length: 132 bytes a ~' Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9088.0000 79.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9088.5000 84.3199 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 285.2363 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 24.9336 -999.2500 0.6016 2000.0000 -999.2500 -999.2500 9300.0000 43.7936 81.8843 2000.0000 455.7503 50.2036 38.9449 9400.0000 23.0973 33.2973 2000.0000 2000.0000 95.1111 74.0115 9500.0000 22.1640 34.6520 2000.0000 2000.0000 108.9165 84.3405 9600.0000 60.1433 51.0604 2000.0000 328.7767 56.9005 46.6161 9700.0000 31.2562 109.4094 68.6775 41.6327 25.9480 23.9310 9800.0000 40.0525 93.1147 24.9044 18.0217 12.9689 10.9183 9900.0000 25.9688 48.3414 30.1045 22.2961 19.0600 17.9148 10000.0000 51.0445 69.7473 18.1643 16.4029 14.2488 13.7931 10100.0000 98.3716 103.4959 15.3165 13.7824 12.0937 11.3777 10200.0000 33.4233 118.4604 14.8703 12.8168 11.6861 11.4216 10300.0000 41.2868 123.8912 21.2372 18.3410 16.3090 15.8305 10400.0000 65.5913 106.6642 35.4893 28.6177 23.5745 23.0216 10500.0000 48.9168 124.8599 19.4235 14.0559 12.1335 10.9176 10600.0000 43.3419 126.4524 19.5695 16.5416 13.6520 12.5841 10700.0000 33.8204 57.6137 16.3548 14.5626 12.1808 11.7826 10800.0000 38.2614 128.8373 19.4788 16.9931 14.0653 13.1939 10900.0000 65.3000 147.3806 19.6275 16.8670 • 14.0195 13.0405 11000.0000 97.2062 136.9062 12.8006 12.3292 11100.0000 56.2012 108.4242 12.4554 11.7771 11200.0000 34.4799 106.4398 13.4494 12.9928 11300.0000 35.5000 62.2000 15.6500 14.9230 11400.0000 79.7650 169.4208 16.3683 16.2576 11500.0000 40.7600 115.6328 13.9865 13.4425 11600.0000 57.5992 83.1125 13.6172 12.9696 11700.0000 -999.2500 138.2805 -999.2500 -999.2500 11730.5000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9088.000000 Tape File End Depth = 11730.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet e 17.1266 17.3078 16.9839 22.4510 21.3185 19.4923 18.7252 -999.2500 -999.2500 14.2650 13.9908 15.1372 18.6350 18.4377 15.7462 15.8917 -999.2500 -999.2500 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9088.0000 79.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9088.2500 85.3000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9100.0000 285.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9200.0000 27.6000 0.9000 0.3180 2129.8896 0.1780 0.2870 9300.0000 44.2000 84.1000 2179.3999 1615.7439 49.7310 37.3560 9400.0000 21.1000 33.3000 2179.3999 6064.5400 100.6330 76.1240 9500.0000 21.9000 35.1000 2179.3999 6064.5400 109.1950 84.5640 9600.0000 78.8000 45.0000 2179.3999 304.3060 51.7220 43.0400 9700.0000 32.0000 97.9000 92.0410 42.5670 22.2160 18.8170 9800.0000 39.3000 93.7000 25.0850 17.9230 12.8460 10.7870 9900.0000 29.3000 34.0000 33.5360 26.5940 23.2390 23.5950 10000.0000 26.1000 69.3000 18.9670 17.0840 14.0870 13.1220 10100.0000 50.5000 136.9000 14.8350 13.5880 11.8440 11.3490 10200.0000 40.7000 173.5000 14.2990 11.9240 10.6630 9.9590 10300.0000 58.5000 106.5000 21.1370 18.4740 16.2050 15.7430 10400.0000 60.7000 103.6000 35.1310 28.8050 23.7900 23.2590 10500.0000 47.1000 108.0000 19.3430 14.0160 12.1220 10.9170 10600.0000 47.5000 127.5000 19.6940 16.6010 13.8060 12.7760 10700.0000 37.3000 75.6000 16.1940 14.3830 12.0960 11.6190 10800.0000 36.2000 110.7000 19.5100 17.2110 14.3150 13.7620 10900.0000 52.5000 104.5000 19.5990 17.1810 • 14.1910 13.1640 11000.0000 84.0000 94.4000 13.0360 12.4780 11100.0000 43.0000 109.4000 12.8360 12.1990 11200.0000 35.9000 102.3000 13.4290 13.0060 11300.0000 37.1000 152.3000 15.8310 15.2360 11400.0000 104.5000 149.3000 16.6080 16.5280 11500.0000 33.6000 126.8000 15.0840 14.7900 11600.0000 94.4000 91.4000 13.5890 12.8850 11700.0000 -999.2500 135.2000 -999.2500 -999.2500 11728.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9088.000000 Tape File End Depth = 11728.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 17.4410 17.1970 16.9980 22.1170 20.7260 20.0620 18.3130 -999.2500 -999.2500 14.4490 14.3610 15.1140 18.5640 18.5770 16.6890 15.6000 -999.2500 -999.2500 • • Tape Subfile 4 is type: LIS
