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HomeMy WebLinkAbout203-148MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC PSI-07 PRUDHOE BAY UNIT PSI-07 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/24/2025 PSI-07 50-029-23177-00-00 203-148-0 W SPT 8066 2031480 2016 2195 2195 2195 2190 0 294 284 277 4YRTST P Josh Hunt 11/19/2024 Good test. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT PSI-07 Inspection Date: Tubing OA Packer Depth 36 2921 2890 2882IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH241119161123 BBL Pumped:4.7 BBL Returned:4.5 Friday, January 24, 2025 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.24 15:33:14 -09'00' Rau PS -o7 Regg, James B (CED) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Sunday, November 24, 2019 7:35 PM To: Regg, James B (CED) Cc: AK, OPS FF Well Ops Comp Rep; AK, OPS GPB AOM Subject: East Dock #7, SSV gagged for flange leak Importance: High Jim, Notification that water injector PSI -07 has its LPP blocked for maintenance repairs. Repairs are expected to not exceed 5 days and the defeated device is carried on the Safety Defeated Device log. Once returned to normal BPXA will notify the AOGCC. Please call with any questions that you may have. Vince Vince Pokryfki GPB Pipeline and Well Ops Compliance BP Exploration (Alaska) Inc. PBOC — B103 Office (907) 659-5332 Cell (907)354-1352 Harmony — 7187 Alternate: Lee Hulme From: AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOosLead@bo com> Sent: Sunday, November 24, 2019 5:17 PM To: Pokryfki, Vince J <PokryfVJPBP.com> Cc: Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bo.com> Subject: East Dock #7, SSV gagged for flange leak Vince, We need to gag the SSV on PSI -7 for 12 -24 hours while we isolate and remedy the drain flange leak. Let me know if have any questions or concerns. Thanks, Ron White MEMORANDUM TO: Jim Regg P.I. Supervisor 4 FROM: Guy Cook Petroleum Inspector Well Name PRUDHOE BAY UNIT PSI -07 IInsp Num: mitGDC201108063222 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, November 12, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PSI -07 PRUDHOE BAY UNIT PSI -07 Src: Inspector Reviewed By P.I. Supry`J 12— Comm API Well Number 50-029-23177-00-00 Inspector Name: Guy Cook Permit Number: 203-148-0 Inspection Date: 11/8/2020 . Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI 07 "Type Inj w, 'TVD 8066 Tubing 2152 2151 2151 2152 ' - ---- - PTD 2031480 Type Test SPT 'Test psi 2016 IA 0 2695 2679 - 2675 ' - - - - BBL Pumped: 4A IBBL Returned: 4.3 OA 82 474 467 462 ' ----' J - - Interval I 4YRTST /F P Notes' Testing completed with a triplex pump, a bleed tank and calibrated gauges. Thursday, November 12, 2020 Page 1 of 1 • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,November 21,2016 TO: Jim Re P.I.Supeergvisor L ,C` ZE/I SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. PSI-07 FROM: Bob Noble PRUDHOE BAY UNIT PSI-07 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJge-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI-07 API Well Number 50-029-23177-00-00 Inspector Name: Bob Noble Permit Number: 203-148-0 Inspection Date: 11/15/2016 Insp Num: mitRCN161115140330 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI-07 Type Inj W" TVD 8066 ' Tubing 640 644 644 - 644 - PTD 2031480 - Type Test SPT Test psi 2016 - IA 20 2600 -1 2586 - 2582 - Interval 4YRTST P/F P V OA 280 648 ' 648 637 - Notes: 1-:t-e) rlesst p 64- c '�7c-E2e) scppiED JUN E0 7 2017( Monday,November 21,2016 Page 1 of 1 • S N '• r �f.ftH rte) 5 4 c a $ 3 41%4' • 113 • J �� I • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 NNED JAN 2 4 2E December 21, 2010 Mr. Tom Maunder y_ Alaska Oil and Gas Conservation Commission 333 West 7 Avenue �` w ?tn. Anchorage, Alaska 99501 cart, cons. C- : ;�si►on Subject: Corrosion Inhibitor Treatments of GPB PSI '>ilep;ge Dear Mr. Maunder, p Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB PSI 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, Torin Roschinger BPXA, Well Integrity Coordinator . . BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12/21/10 Corrosion Initial top of Vol. 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 gaf PSI -01 2021450 50029231040000 NA 1 NA 5.10 10/25/2010 PSI -05 2031390 50029231740000 NA 1 NA 5.95 10/24/2010 PSI -06 2020790 50029230820000 NA 12.3 NA 45.90 10/25/2010 PM-07 2031480 5002923t770000 NA 1.2 NA 6.80 10/24/2010 PSI -08 2021720 50029231140000 NA 1.3 NA 6.80 10/23/2010 PSI -09 2021240 50029230950000 NA 1.9 NA 12.80 10/23/2010 PSI -10 2021590 50029231100000 NA 0.7 NA 3.40 10/23/2010 r Recent MITIA for wells: 04-28 (D #1852800), LGI-06 (PTD #18606701-01 (PTD #19002... Page 1 of 1 Regg, James B (DOA) ,' y ~ 2~~ 14~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, November 25, 2008 8:18 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~~~ >1(7.~ ~~~ Cc: NSU, ADW Well Integrity Engineer Subject: Recent MITIA for wells: 04-28 (PTD #1852800), LGI-06 (PTD #1860670), P1-01 (PTD #1900270), PSI-05 (PTD #2031390), PSI-07 (PTD #2031480), and W-11 (PTD #1891070). Attachments: ATT9468657.txt; MIT PBU 04-28 11-20-08.x1s; MIT LPC LGt-06 11-14-08.x1s; MIT GPMA P1-01 11- 15-08.x1s; MIT PBU PSI-05 11-24-08.x1s; MIT PBU PSI-07 11-14-08.x1s; MIT PBU W-11 11-20-08.x1s Hi Jim, Tom, and Bob, Please find the attached MITIA forms for wells 04-28 (PTD #1852800), LGI-06 (PTD #1860670), P1-01 (PTD #1900270), PSI-05 (PTD #2031390), PSI-07 (PTD #2031480), and W-11 (PTD #1891070). 04-28: UIC MITIA post patch LGI-06: UIC MITIA P1-01: UIC MITIA post rig workover PSI-05: UIC MITIA PSI-07: UIC MITIA ~©'3' ~ ~$ -11: UIC MITIA «MIT PBU 04-28 11-20-08.x1s» «MIT LPC LGI-06 11-14-08.x1s» «MIT GPMA P1-01 11-15-08.x1s» «MIT PBU PSI-05 11-24-08.x1s» «MIT PBU PSI-07 11-14-08.x1s» «MIT PBU W-11 11-20-08.x1s» 11/25/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / PSI pad ~~,~ rj~~~'Ze~~ DATE: 11/14/08 OPERATOR REP: Andrea Hughes AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well PSI-07 Type Inj. W TVD 8,066' Tubing 1,200 1,200 1,200 1,200 Interval 4 P.T.D. 2031480 Type test P Test psi 2016 Casing 50 2,500 2,470 X2,470 P/F P Notes: MIT-IA to 2500 psi for 4 year compliance testing OA 520 880 880 880 Pumped 3.6 bbls of meth to reach test pressure. Declined to witness by Jeff Jones Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interva- P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU PSI-07 11-14-08.x1s • • ~._ ~r~~--- MICROFILMED 03/01 /2008 DO NOT PLACE ~',,, , q ~._: ~; ;.- ,~ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc Permit to Drill 2031480 )ro ~ DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Well Name/No. PRUDHOE BAY UNIT PSI-07 Operator BP EXPLORATION (ALASKA) INC MD 11383./ TVD 8652 ,/' Completion Date 8/16/2004 --- -~-,-- REQUIRED INFORMATION - -- ---.-- Completion Status 1WINJ -- ~~~- Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD 1 GR, MWD 1 GR I PWD, US/T, MWD I GR 1 RES 1 NEU 1 DEN Well Log Information: Electr Digital Dataset Med/Frmt Number Logl Data Type I t t: i£D ¡ Rpt b'/C ~ ( Lis I¡/ r I ! I ì Asc Name Log Log Scale Media Run No Temperature Blu Cement Evaluation 5 Col Casing collar locator 5 Col Directional Survey Directional Survey Cement Evaluation Blu 13373 Reservoir Saturation 13373 Reservoir Saturation 25 Blu 13374 Reservoir Saturation 5 Blu Density 25 Blu Compo Current Status 1WINJ ,)/lCll IC~J.A(J API No. 50-029-23177-00-00 os- 11Ir. v ~ Direction~urv~_~__ ----_.- (data taken from Logs Portion of Master Well Data Maint Interval Start Stop OHI CH 8400 Received 11/29/2005 11299 Case 3/2812006 8590 10952 Case 1 0/18/2003 8590 1 0952 Case 10/18/2003 0 11383 Open 10/27/2003 0 11383 Open 10/27/2003 8590 10952 Case 5/3/2004 10819 11295 Case 11/21/2005 100 11282 Case 11/21/2005 10800 11282 Case 11/21/2005 10950 11383 Open 11/29/2005 . Comments l Temperature Warm back I Survey I PBMS/GR/CCLITEMPERA TURE/PRESSURE 28 July I 2005 , ¡ I I I I ! I ULTRASONIC IMAGING I TOOL, USIT-A/GRlCCL I RST-C SIGMA, GR, I CCL,TEMP,PRES,JEWEL ! RY + PDS Graphics 27- I Oct-2003 I RESERCO/R I SATURATION TOOL RST-I SIGMAlTEMP/PRES/JEWE I LRY 27-0CTOBER-2003 I Reservoir Saturation Tool I RST-C/Sigma Mode 26- I December-2003 I VISION Density Neutron [ True Vertical Depth Log I Composite FINAL Print I I ~~~____J Ultrasonic Imaging Tool USIT-AlGamma Ray/CCL Ultrasonic Imaging Tool - USIT-AlGamma Ray/CCL Schlumberger & Anadrill Schlumberger & Anadrill . DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2031480 Well NamelNo. PRUDHOE BAY UNIT PSI-07 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23177-00-00 MD 11383 TVD 8652 Completion Date 8/16/2004 Completion Status 1WINJ Current Status 1WINJ UIC Y r-:-- Density 1 ¡ L3J 25 Blu compo 10950 11383 Open 11/29/2005 VISION Density Neutron I Measured Depth Log I i Composite FINAL Print I I !.J;P9 I nduction/Resistivity 25 Blu compo 108 11383 Open 11/29/2005 VISION Resistivity True I !c6g Vertical Depth Log [ Composite FINAL Print I Induction/Resistivity 25 Blu 108 11383 Open 11/29/2005 VISION Resistivity ¡ compo I I Measured Depth Log [ . I Composite FINAL Print I tc°g Induction/Resistivity 25 Blu 10950 11383 Open 11/29/2005 True Vertical Depth Log I Composite FINAL Print I ~g CNP/GR/RES Induction/Resistivity 25 Blu 10950 11383 Open 11/29/2005 Measured Vertical Depth I I Log Composite FINAL ~c Print CNP/GR/RES I I 13389 I nd uction/Resistivity 137 11382 Open 11/2912005 Density I Neutron/ResistivityNision ~ Service 10/12/2003 Formation Tester Col 10987 11313 Case 7/25/2006 Modular Formation ¡ I Dynamics Tester PS-HY- [ I PC-GR 13-0ct-2003 I __._._1 Well Cores/Samples Information: Interval Sample Set Name Start Stop Sent Received Number Comments . ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~ Formation Tops lbN àJN Daily History Received? Analysis Received? ~ ._~..~- -~--- Comments: --~.~---_.- oat; ] ~ ~~- Compliance Reviewed By: ~ J:t\ ¡ 07/19/06 Sc~lIn~el'ger NO. 3880 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 éJJ3 ~ ì1~ UT(\ Attn: Christine Mahnken A TTN: Beth _\..:...- 333 West 7th Ave, Suite 100 Anchorage. AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Color CD 15-12A 11211420 RST GRAVEL PACK 06/25/06 1 . 17-08 11211509 INJECTION P-ROFILE 06/24/06 1 P2-11A 11221564 JEWELRY/STATIC SURVEY 04/27/06 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 P2-01 11223106 STATIC PRESSURE/JEWELRY 03/25/06 1 L5-08 11217256 PROD PROFILE W/GHOST & DEFT 06106/06 1 ;Q 16-04A 11217245 PROD PROFILE W/DEFT 05/08106 1 05-40 11223123 LDL 07/07/06 1 ,~ 17-09 11211412 PROD PROFILE WIDEFT & GHOST 06/26/06 1 MPC-07 NIA SENSA/MEMORY GLS 04/22/06 1 04-18 1121584 USIT 06/27/06 1 h-51 11212873 USIT 06/28/06 1 04-31 11217264 USIT 07107/06 1 D-14A 11217265 USIT 07109/06 1 PSI-07 10703937 MDT 10/13/03 1 02-16B 11209601 MCNL 04/25/06 1 1 L2....8A 11217234 MCNL 04/06/06 1 1 L5-09 11212847 MCNL 04/25/06 1 1 Z-26A 11216205 MCNL 07/05/06 1 1 . 12-01 11072866 RST 07/06/05 1 1 E-17A 10928602 MCNL (Prints sent 1/24/05) 10/30104 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well PSI-07 PSI-07 PSI-07 PSI-07 PSI-07 PSI-07 PSI-07 Z-02A S-14A ¥-1OA D.S. 03-33A C-19B 09-20 D.S. 09-31 C P-06A 2-22A K-20B D.S. 06-20 C-18A P1-07A BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 40009685 40009685 40009685 40009685 40009685 40009685 40009685 11132059 10987547 10889216 10893093 10928633 10889215 NIA 11076455 11084275 11075899 11062630 10621788 10621778 II 14)C:1 \ 06 ~~'l~r'~~ \""'" 1 ".jJ L...~J t\~! 2.<3 øms CÚínn1~~fì .. £)JH~hi)ífJge Log Des¡:ription OH LDWG EDIT OF MWD/LWD MD VISION DENSITY TVD VISION DENSITY lÀj~) --- ¡4·ß MD VISION DEN/NEUTRON TVD VISION DEN/NEUTRON MD VISION SERVICE TVD VISION SERVICE US IT USIT SCMT SCMT SCMT SCMT SCMT SCMT SCMT SCMT US IT SCMT SCMT Date 10/12/03 10/12/03 10/12/03 10/12/03 10/12/03 10/12/03 10/12/03 10/06/05 09/13/05 02/21/05 03/05/05 05/15/05 02/18/05 11/05/05 07/29/05 07/10105 07104/05 06/14/05 06/06/04 04/21/04 NO. 3613 Company: State of Alaska Alaska Oil & Gas Cons Comm Altn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. BL Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ReœNed bt~~&1Ð(j , 11/28/05 . . Schlumberger Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # log Description Date BL 02-30B 10980587 RST 07/17/05 1 PSI-07 .;,>ð3-¡4-R 10674389 RST 10/27/03 1 PSI-07 " r( 10679045 RST 12/26/03 1 l3-02 11072860 RST 06/13/05 1 X-16A 10980531 RST 03/01/05 1 F-30 10987523 RST 06/22/05 1 W-31 10913021 RST 06/30105 1 Z-15 10980580 RST 07/10/05 1 C-30 10980583 RST 07/13/05 1 W-39A 10928650 MCNL 10/16/05 1 18-31A 10942210 MCNl 04/28105 1 H-02A 10928622 MCNL 04/05/05 1 05-24A 10928609 MCNL "(PRINT SENT 1/24/05) " 12/22/04 K-06A 11075903 MCNL 07/30/05 1 L-03 10913041 OH LDWG EDIT FOR WIRELlNE DATA 08/01/05 2 B-02A 10889169 SCMT 09/22/04 H-05 10674407 CBL 01/21/04 G-13A 10563175 SCMT 06/17103 E-06A 11051045 SCMT 05/19/05 W·20 10672389 USIT 06/03/04 MPF·87A 10708043 US IT 01/08/04 MPA-03 11058243 US IT 09/07/05 MPF·89 11051088 US IT 08/17/05 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 gOO E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~:~.\ç, nltlV 0 \ I jjcct;; 11/17105 NO. 3602 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne PI. Color . CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 133TS 13~7 4- 1 1 1 1 1 1 1 1 1 . Alaska Data & Consulting Services 2525 Gambe" Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth R~;'ed byt~\ (r . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor R~ I/(U{01 DATE: Wednesday, November 17, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PSI-07 PRUDHOE BAY UNIT PSI-07 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv ~ Comm NON-CONFIDENTIAL Well Name: PRUDHOEBAYUNITPSI-07 Insp Num: mitCS04I115133952 Rei Insp Num: API Well Number: 50-029-23177-00-00 Permit Number: 203-148-0 Inspector Name: Chuck Scheve Inspection Date: 1lI14/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well PSI-07 Type Inj. S TVD 8066 IA 0 2500 2450 2410 2390 P.T. 2031480 TypeTest SPT Test psi 2016.5 OA 240 600 600 570 550 Interval INITAL PIF P Tubing 2025 2025 2025 2025 2025 Notes: Pretest pressures observed and found stable. Temperature ofinjection fluid cooled slightly during test Wednesday, November 17,2004 Page I of 1 a STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COMM"jSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG R'~s~êf: u1'1/0~L~,~u.!,?n '1njection 1b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 203-148 13. API Number 50- 029-23177-00-00 14. Well Name and Number: PBU PSI-07 15. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool , .. r 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 181 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3857' NSL, 4408' WEL, SEC. 15, T11N, R15E, UM Top of Productive Horizon: 3722' NSL, 2495' WEL, SEC. 09, T11 N, R15E, UM Total Depth: 3823' NSL, 2555' WEL, SEC. 09, T11 N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 707996 y- 5966158 Zone- ASP4 TPI: x- 704478 y- 5971209 Zone- ASP4 Total Depth: x- 704415 y- 5971308 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD / GR, MWD I GR / PWD, One Other Gas Cap Injection 5. Date Comp., Susp., or Aband. 8/16/2004 6. Date Spudded 10/1/2003 7. Date T.D. Reached 10/12/2003 8. KB Elevation (ft): 45.4' 9. Plug Back Depth (MD+ TVD) 11298 + 8570 10. Total Depth (MD+TVD) 11383 + 8652' 11. Depth where SSSV set (Nipple) 2232' MD 19. Water depth, if offshore N/A MSL CASING SIZE 20" 13-3/8" 9-518" USIT, MWD I GR I RES / NEU / DEN CASING, LINER AND CEMENTING RECORD SÞRINGOERTHMP SETtiNG DEPTH TVD HOLE Top BO'rTOM Top BO'rTOM SIZE Surface 108' Surface 108' 42" 28' 5723' 28' 4638' 16" 25' 10963' 25' 8250' 12-1/4" 10859' 11383 8152' 8652' 8-1/2" 22. FT. 91.51# 68# 40# I 47# 26# H-40 L-80 S-95/ L-80 L-80 7" 23. Perforations open to Production (MD + TVD of To)? and Bottom Interval, Size and Number; if none, state' none"): 3-3/8" Gun Diameter, 6 spf MD TVD MD TVD 11228' - 11256' 8503' - 8530' 26. Date First Production: October 24, 2004 Date of Test Hours Tested PRODUCTION FOR TesT PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Press. 24-HoUR RATE 24. SIZE 7",26# x 7-5/8",29.7# L-80 25. Ft Ft 16. Property Designation: ADL 034631 17. Land Use Permit: NIA - Fee Simple Pad 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 260 sx Arctic Set (Approx.) 1333 sx AS III Lite, 590 sx Class 'G' 477 sx Class 'G' 140 sx Class 'G' DEPTH SET (MD) 10809' PACKER SET (MD) 10768' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 144 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection OIL-BsL GAs-McF WATER-BsL OIL-BsL GAs-McF W A TER-BsL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS BFL NOV _ 0'2004 None ~ : Form 10-407 Revised 12/2003 O 0 I G I \' Ai , .\,,,-..til~¡ L- CONTINUED ON REVERSE SIDE G(r b .. ,. IÞ GEOLOGIC MARKERS 29. - FORMATION TESTS 28.' , NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 6306' West Sak 8574' Colville Mudstone 9203' Top HRZ 10774' Base HRZ 1 Top Sadlerochit I 10984 ' Zone 3 I LCU Zone 2C 11040' Zone 2B 11094' Zone 2A 11176' Zone 1 B 11215' Zone 1A 11255' Base Sadlerochit I TKVK 11322' 5001' None 6424' 6824' 8071' 8270' 8324' 8375' 8453' 8491' 8529' 8593' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work Summary, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble -íQ l\W. ~ tit<.. ~ Title Technical Assistant Date / 1- D 3 - D Y PBU PSI-07 203-148 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Rob Tirpack, 564-4166 Permit NO.1 Approval No. INSTRUCTIONS 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. 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 elevation in feet above mean low low water. 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: True vertical thickness. 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). I ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only " _ STATE OF ALASKA . ALASKAII'IL AND GAS CONSERVATION COM QSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 181 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P,O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3857' NSL, 4408' WEL, SEC. 15, T11N, R15E, UM Top of Productive Horizon: 3722' NSL, 2495' WEL, SEC. 09, T11 N, R15E, UM Total Depth: 3823' NSL, 2555' WEL, SEC. 09, T11N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 707996 y- 5966158 Zone- ASP4 TPI: x- 704478 y- 5971209 Zone- ASP4 Total Depth: x- 704415 y- 5971308 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD I GR, MWD / GR I PWD, One Other Gas Cap Injection 5. Date Comp., Susp., or Aband. 8/16/2004 6. Date Spudded 10/1/2003 7. Date T.D. Reached 10/12/2003 8. KB Elevation (ft): 45.4' 9. Plug Back Depth (MD+ TVD) 11298 + 8570 10. Total Depth (MD+TVD) 11383 + 8652' 11. Depth where SSSV set (Nipple) 2232' MD 19. Water depth, if offshore NIA MSL CASING SIZE 20" 13-3/8" 9-5/8" US IT, MWD I GR 1 RES I NEU / DEN CASING, LINER AND CEMENTING RECORD SrnlNG DEP1HMD SeTTINGDEP11-ItìfÐ HOLE Top BOTTOM Top BOTTOM SIZE Surface 108' Surface 108' 42" 28' 5723' 28' 4638' 16" 25' 10963' 25' 8250' 12-1/4" 10859' 11383 8152' 8652' 8-1/2" 22. WT.PER FT. 91.51# 68# 40# 147# 26# GRADE H-40 L-80 S-95 I L-80 L-80 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3-318" Gun Diameter, 6 spf MD TVD MD TVD 11228' - 11256' 8503' - 8530' 26. Date First Production: Not on Injection Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE""" 24. 1b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 203-148 13. API Number 50- 029-23177-00-00 14. Well Name and Number: PBU PSI-07 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 034631 17. Land Use Permit: N/A - Fee Simple Pad 20. Thickness of Permafrost 1900' (Approx.) 260 sx Arctic Set (Approx.) 1333 sx AS III Lite, 590 sx Class 'G' 477 sx Class 'G' 140 sx Class 'G' TUBING RECORD DEPTH SET (MD) 10809' SIZE 7",26# x 7-5/8",29.7# L-80 25. AcID,FRACTURE, CEMI;NTSQUEEZE,ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 144 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA Oll-BBl GAs-McF WATER-Bel Oll-BBl 27. GAs-McF WATER-Bel PACKER SET (MD) 10768' CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core c;hip§; if none, state "none". RE CE IVE 0 None /{!W4YJ \~_::_\\f'~ St~ (, 0 R ,~ I f'\I l~· L SEP 1 62004 .' vg~. t: , ........... .~:.... ' ¡ J q +. . ~._:: ¡' "·..ut,_ "-w.. ..~ Alaska Oil & Gas Cons. v..mmission lof Anchurayu Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE -, e 28. GEOLOGIC MARKERS NAME MD TVD Ugnu 6306' 5001' West Sak 8574' 6424' Colville Mudstone 9203' 6824' Top HRZ 10774' 8071' Base HRZ 1 Top Sadlerochit I 10984' 8270' Zone 3 I LCU Zone 2C 11040' 8324' Zone 2B 11094' 8375' Zone 2A 11176' 8453' Zone 1 B 11215' 8491' Zone 1A 11255' 8529' Base Sadlerochit 1 TKVK 11322' 8593' 29. e FORMATION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None RECEIVED SEP 16 2004 Ala¡¡kliS PiI & t7.tUHh Commission ÄntiþQragQ 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work Summary, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~~. ti<.G6-&. Title Technical Assistant Date oq· / S -OV PBU PSI-07 203-148 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Rob Tifipack, 564-4166 Permit No. I Approval No. INSTRUCTIONS 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. 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 elevation in feet above mean low low water. 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: True vertical thickness. 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: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 OR,r"l ... t lJ I r, L ¡'-'\ . Submit Original Only Legal Name: PSI-O? Common Name: PSI-O? 10/6/2003 10/12/2003 FIT FIT 5,723.0 (ft) 10,963.0 (ft) 4,638.0 (ft) 8,250.0 (ft) 9.00 (ppg) 9.00 (ppg) 725 (psi) 431 (psi) 2,893 (psi) 4,288 (psi) 12.01 (ppg) 10.01 (ppg) e - Printed: 10120/2003 8:50:43 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10/18/2003 913012003 09:00 - 12:00 3.00 RIGU P PRE Move rig off PSI-OS 12:00 - 15:00 3.00 RIGU P PRE Spot Sub, Pits, Pumps, Motors, Boilers, Rockwasher and Pipe shed 15:00 - 16:30 1.50 RIGU P PRE Complete rig acceptance check list Note; Accepted rig @ 1500 hrs 9/30/03 16:30 - 17:30 1.00 DIVRTR P SURF Nipple up 21-1/4" Diverter and 16" knife valve, Riser, Turn buckles, Hydraulic lines. 17:30 - 22:30 5.00 DRILL P SURE Move 20 stands of drill pipe to the off drillers side, Pick up 105 joints 5" drill pipe, 23 joints 5" HWDP & Jars 22:30 - 23:00 0.50 DIVRTR P SURE Function test Diverter-OK, Test witness waived by AOGCC John Crisp 23:00 - 00:00 1.00 DRILL P SURE Pick up stand of 8" NMDC's 10/1/2003 00:00 - 01 :00 1.00 DRILL P SURF Held divterter drill with all personal, Fill conductor & check for leaks, Test mud lines to 3500 psi. 01 :00 - 02:00 1.00 DRILL P SURF Pick up BHA #1, Motor, Bit, 2- Lead collars, NM Stab, RIH wI stand of NMDC's to 108' 02:00 - 00:00 22.00 DRILL P SURF Drill f/108' to 1560', Take Gyro surveys @ 638',728',819', 910', 1002', 1095', ART= 4.52 hrs AST= 8.48 hrs, UP 100K, ON 100K, ROT 100K, WOB 35/45K, RPM 0/50, 650-700 GPM, 1500 psi (Note; KOP 638, having extreme difficulty achieving dogleg even with 100% sliding) 10/2/2003 00:00 - 01 :45 1.75 DRILL P SURF Drill f/1560' to 1745', ART= 0 hrs AST=1.69 hrs, UP 118K, ON 110K, WOB 0/45K, 650-700 GPM, 1750 psi. (Note: Sliding 100%- very difficult achieving build rate and extreme right hand walk, also much slower ROP) 01 :45 - 03:30 1.75 DRILL P SURF Circulate 3 btm's up @ 700 GPM @ 1225 psi & 50 RPM, (Hole not cleaning up, excess sand - possible running) 03:30 - 04:00 0.50 DRILL P SURF POOH to BHA @ 913', Hole in good shape- good pipe displacement 04:00 - 06:00 2.00 DRILL P SURF POOH wI BHA, Change bits, Check MWD orientation, RIH wI BHA to 913' 06:00 - 06:30 0.50 DRILL P SURF RIH to 1655'- No problems, Precautionary wash to 1745'- OK 06:30 - 00:00 17.50 DRILL P SURF Drill f/17 45' to 3879', AST= 7.44 hrs ART= 2.93 hrs, UP 150K, ON 107K, ROT 127K, TQ on 8/9K- off 6/8, WOB 5/35K, RPM 80, 850 GPM @ 2500 psi 10/3/2003 00:00 - 19:30 19.50 DRILL P SURF Drill f/3879' to 5738' (16" TO), AST= 3.36 hrs ART= 9.79 hrs, UP 185K, ON 130K, ROT 140K, TQ on 12K- off 11, WOB 5/55K, RPM 80,880 GPM @ 3150 psi 19:30-21:30 2.00 DRILL P SURF Circ. hole clean wI 2 btm's up, 880 GPM @ 2800 psi and 100 RPM 21 :30 - 00:00 2.50 DRILL P SURF Wipe hole f/5738' to 1655', Several 25 to 65K over pulls on trip out, Hole took correct fill. 10/4/2003 00:00 - 01 :30 1.50 DRILL P SURF RIH to 5646', Precautionary wash to btm @ 5738' - OK 01 :30 - 03:30 2.00 DRILL P SURF Circ. hole clean wI 2 times btm's up wI 880 GPM @ 2900 psi & 100 RPM 03:30 - 05:45 2.25 DRILL P SURF POOH to 913', 1-40K pull @ 3240' wiped out -OK, Hole in good shape 05:45 - 08:30 2.75 DRILL P SURF POOH & stand back HWDP & DC's, Lay down 16" stab's, MWD & mud motor, Bit, Clear rig floor 08:30 - 08:45 0.25 CASE P SURF Rig up & make dummy run wI 13-3/8" Hanger 08:45 - 18:30 9.75 CASE P SURF Ran 13 3/8" 68#, L-80 BTC Csg to 5722.90' with no problems, ran HES 13 3/8" float shoe, 2 jts 13 3/8" csg, HES 13 3/8" float Printed: 1012012003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10/18/2003 10/4/2003 08:45 - 18:30 9.75 CASE P SURF collar, thread locked conn below float collar and checked float equip, cont running 13 3/8" csg, ran 115 jts 133/8" csg, MU Tam port collar with pup jt above & below, then ran 23 add jts of 13 3/8" csg, MU Hanger & Landed csg with float shoe at 5,722.90' and float collar at 5,638.83', ran a total of 138 jts of 133/8" csg, 2 pup jts, Tam port collar, Ran 27 Bow spring centralizers per program, No mud loss while RIH with csg. Note: Broke circulation at 2,500 and circulated 3 jts. down at 10 minutes per joint. Total of 3,200 strokes pumped. No losses while staging up to 8 bpm. Circulated down 3 joints from 4,712 to 4,831 due to down drag of 60K. Ran remaining string in with no pumps or adverse hole conditions. Circulate down last joint and begin reciprocating and circulating with franks tools. Initial pickup wt. was 430K and reduced to 350k while working pipe and conditioning mud. Pumped two complete bottoms up prior to landing casing and changing out franks tool to cement head. 18:30 - 20:00 1.50 CEMT P SURF Make up FMC hanger, Break circ & circ btm's up, Stage pump rate up to 12 BPM @ 950 psi- No mud loss, Reciprocate casing 15' wI 350K UP & 205K ON. 20:00 - 20:45 0.75 CEMT P SURF Lay down Franks fill up tool, Make up Dowell cement head. 20:45 - 23:00 2.25 CEMT P SURF Circ. & condition mud for cmt. job w/12 BPM @ 950 psi, Reciprocate casing 15' wI 350K UP & 205K ON 23:00 - 00:00 1.00 CEMT P SURF Turned over to Dowell and pumped 5 bbls FW, pressure tested lines to 3,500 psi, then Pumped 75 bbls of 10.2 ppg Mud Push II at ave 5.0 bpm at 60 psi, shut down and dropped btm plug, mixed & begin pumping 1,016 bbls, 1,332 sxs of Arctic set Lite at 10.7 ppg and 4.28 yield with additives, pumping at an ave of 8.5 bpm at 350 psi. Note: Set casing down on hanger and stopped working pipe when started pumping Lead cement, due to casing becoming tight wI 430K. 10/5/2003 00:00 - 03:45 3.75 CEMT P SURF Continue mix & pump total of 1016 bbls, 1,332 sxs of Arctic set Lite at 10.7 ppg and 4.28 yield with additives, pumped at ave. rate of 8.5 bpm @ 350 psi, followed by 123 bbls, 590 sxs of class "G" cmt with additives at 15.8 ppg and 1.17 yield at rate of 5.0 bpm @ 230 psi, Note; After 70 bbls of MudPush rounded shoe lost total returns for 42 bbls, regained circ with cmt out of shoe, continue cementing with full returns, Shut down, Drop top plug, Dowell pumped 10 bbls fresh water, turned over to rig and displaced cement wI 840.2 bbls 9.5 ppg mud, initial rate of 12 bpm @ 725 psi, max pressure of 1700 psi at 12 bpm, slowed rate to 3 bpm for last 10 bbls, bumped plug wI 2,200 psi, check floats- OK, had good returns through displacement with 388 bbls 10.7 ppg cement back to surface, CIP @ 03:30 hrs 10/5/2003 03:45 - 05:00 1.25 CEMT P SURF Rig down cement head, Lay down landing joint & flush out diverter 05:00 - 08:30 3.50 DIVRTR P SURF Nipple down 21-1/4" diverter system 08:30 - 09:45 1.25 WHSUR P SURF Nipple up speed head & orient tubing spool, Set test plug 09:45 - 10:30 0.75 BOPSURP SURF Nipple up BOP Stack 10:30 - 10:45 0.25 BOPSURP SURF Nipple down BOP Stack 10:45 - 12:00 1.25 WHSUR P SURF Nipple down tubing spool & dress threads on speed head Printed: 10/20/2003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10/18/2003 10/5/2003 12:00 - 12:30 0.50 WHSUR P SURF Nipple up speed head & orient tubing spool, Test to 1000 psi- OK 12:30 -13:30 1.00 BOPSURP SURF Nipple up BOP Stack 13:30 - 17:30 4.00 BOPSURP SURF Test BOPE to 250 psi low & 4000 psi high, Hydril to 250 low & 2500 psi high, Test waived by AOGCC John Crisp, Pull test plug & set wear bushing. 17:30 - 18:30 1.00 DRILL P SURF Slip & cut drilling line 182' 18:30 - 21 :30 3.00 DRILL P SURF Make up BHA #3, Surface test Power drive & MWD, RIH to 903' 21 :30 - 00:00 2.50 DRILL P SURF RIH, picking up 5" Drill pipe 10/6/2003 00:00 - 02:30 2.50 DRILL P INT1 Continue picking up 5" drill pipe & RIH wI BHA #3 to 5360' (Total of 144 Jts.), RIH wI pipe from derrick to 5545' 02:30 - 03:30 1.00 DRILL P INT1 Break circ. 10 min., Rig & test 13-3/8" csg. to 3500 psi f/30 min.- OK 03:30 - 04:30 1.00 DRILL P INT1 Drill out float collar @ 5638' and cement to top of shoe @ 5720' (Begin New 9.0 ppg LSND change over at 5690') 04:30 - 05:30 1.00 DRILL P INT1 Finish 9.0 ppg LSND mud change over, Obtain new slow pump rates. 05:30 - 06:00 0.50 DRILL P INT1 Drill out Shoe @ 5721', Cement in rate hole & 20' new hole to 5758' 06:00 - 07:00 1.00 DRILL P INT1 Pull into Shoe, Circ. btm's up wI 780 GPM @ 1800 psi. 07:00 - 07:30 0.50 DRILL P INT1 Rig & perform FIT wI 725 psi, 9.0 ppg mud, TVD 4638'= 12.0 EMW 07:30 - 08:00 0.50 DRILL P INT1 Obtain PWD base line, RIH to 5758' 08:00 - 00:00 16.00 DRILL P INT1 Drill 12-1/4" hole f/5758' to 7956' ADT= 11.52 hrs, UP 218K, ON 137K, ROT 174K, TQ on btm 20K I off 17K, WOB 10/20K, RPM 110, 863 GPM @ 2800 psi 10/7/2003 00:00 - 08:30 8.50 DRILL P INT1 Drill 12-1/4" hole f/7956' to 8607' ADT= 8.0 hrs, UP 245K, ON 140K, ROT 180K, TQ on btm 13-26K I off 21-22K, WOB 10/20K, RPM 120, 863 GPM @ 2800 psi Note; Bit quit drilling last 5' 08:30 - 11 :30 3.00 DRILL P INT1 Circ & Pump nut pluglGlass bead sweep in attempt to unball & clean up bit, Circ 2 times surface to surface at rate of 860 GPM @ 2900 psi, Obtain SPR's, Observe well. 11 :30 - 12:00 0.50 DRILL P INT1 POOH to 8145', Hole swabbing with very minor overpulls. 12:00 - 12:30 0.50 DRILL P INT1 Pump out f/8145' to 7750',825 GPM @ 2700 psi 12:30 - 13:00 0.50 DRILL P INT1 POOH to 7560', Hole swabbing with no overpulls. 13:00 - 13:30 0.50 DRILL P INT1 Pump out f/7560' to 6940',835 GPM @ 2700 psi- ECD's increased to 10.4 ppg. Began to see wallcake at shakers with minimal amount of cuttings. No indications of packing off or tight hole. 13:30 -14:00 0.50 DRILL P INT1 Back ream slow f/6940' to 6650', wI 50 RPM, 800 GPM @ 2650 psi- ECD's decreased to 10.0 ppg as dry job was pumped out of hole & shakers cleaned up. No indications of packing off or tight hole. 14:00 - 15:00 1.00 DRILL P INT1 Pump out f/6650' to shoe @ 5723', 800 GPM @ 2650 psi. 15:00 - 18:00 3.00 DRILL P INT1 Pump dry job, POOH, Handle BHA, Lay down bit & down load MWD 18:00 - 19:30 1.50 DRILL P INT1 Make up bit #4,(RR from PSI-O?) Surface test Power drive- No good (Surface test showed good down link results, but irregular drilling mode sequence) 19:30 - 22:00 2.50 DRILL N INT1 Change out Power drive tools, Surface test tool with same results as first tool, Trouble shoot tool, Consult Anadrill Printed: 10/20/2003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10/18/2003 1 01712003 19:30 - 22:00 2.50 DRILL N INT1 engineering team in Anchorage and England, Decision is made to run the tool due to possible magnetic surface interference. 22:00 - 00:00 2.00 DRILL P INT1 RIH wI BHA, RIH to 3224' 10/8/2003 00:00 - 00:15 0.25 DRILL P INT1 RIH wI Bit #4 to 3964' 00:15 - 01 :15 1.00 DRILL N RREP INT1 Change out hydralic hose on Iron roughneck 01:15-03:30 2.25 DRILL P INT1 RIH to 8516', Precautionary wash & ream to 8607'.( No adverse hole conditions or fill noted on TIH.) 03:30 - 00:00 20.50 DRILL P INT1 Drill f/8607' to 9,812. Pumping weighted sweeps every 300 ft.( Hole appears to be clean. Minor increase with sweeps.) Maintain ECD under .5ppg of calculated during all drilling and reaming. Backreaming 45 ft. on each stand at full drilling rates on upstroke and reduced to 75% flow on down stroke. Began 2 degree drop at 9,255. Added 16 ppg spike fluid to mud over 3 circulations increasing MW to 10.5 prior to entering CM2. (10,008 MD 17,534 TVD. ) Add lubes and resinex as needed to maintain lubes at 4% with 2 % lubetex and 2 % Flo-Lube. Drilling with following: WOB==15 to 25 GPM==800 RPM==100-120 Rotary steerable== setting between 40 to 60 % lowside for drop section. Note: A very hard streak was drilled from 6,441 to 6,452 TVD which resulted in 1 to 1.5 FPH ROP's. The original PDC bit which drilled app. 7' of this 18' measured depth ft.section was pulled with a grade of 6 4 with a ring out in the cone area. The current bit was set on bottom very cautiously and started as if junk may be present. The average ROP was app. 2 ft. per hour before it broke out of hard stringer. The MD for this hard streak was 8,600 to app. 8,618. The previous well (PSI-O?) drilled the hard streaks in this area with ROP's in the 18 to 20 ft. range. 10/9/2003 00:00 - 04:15 4.25 DRILL P INT1 Drill f/9,812' to 10,110' UP 250K, ON 165K, ROT 205K, WOB 15/25K, RPM 110/120, TQ on btm 16/26K off btm 18K, 795 GPM @ 3500 psi, Maintaining 4% Lubs (2% FLO-LUBE, 2% LUBETEX) Mud wt. 10.5 ppg, BGG 10/20 units 04: 15 - 07:00 2.75 DRILL N INT1 Had wash out on stand pipe gooseneck, Rig up to circ. wI cement line, Work pipe and circ @ 600 GPM @ 3150 psi while repair stand pipe. 07:00 - 21 :30 14.50 DRILL P INT1 Drill f/1 0,11 0' to 10,830' UP 265K, ON 185K, ROT 220K, WOB 22K, RPM 120, TQ on btm 20K off btm 13K, 800 GPM @ 3500 psi, Maintaining 41/2% Lubs, Mud wt. 10.5 ppg, BGG 10/20 units. (Added 1/2 % EP slowly to mud system to reduce torgue.) Torgue was reduced from 20-28k to 15-22k while on bottom drilling. Now able to increase WOB from 15 to 25K without stalling string. Updrag was reduced by 5K. 21 :30 - 22:30 1.00 DRILL N INT1 Circ. & work pipe while repair head in #2 pump. 22:30 - 00:00 1.50 DRILL P INT1 Drill f/10,830' to 10,926' UP 265K, ON 185K, ROT 220K, WOB 22K, RPM 120, TQ on btm 20K off btm 13K, 800 GPM @ 3500 psi, Maintaining 4-1/2% Lubs (2% FLO-LUBE, 2% LUBETEX, 1/2% EP LUBE), Mud wt. 10.5 ppg, BGG 10/20 units Printed: 10120/2003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10/18/2003 10/10/2003 00:00 - 00:45 0.75 DRILL P INT1 Drill f/1 0,926' to 10,968' UP 275K, ON 182K, ROT 220K, WOB 15/25K, RPM 120, TQ on btm 17/27K off btm 13K, 800 GPM @ 3500 psi, Maintaining 4-1/2% Lubs (2% FLO-LUBE, 2% LUBETEX, 1/2% EP LUBE), Mud wt. 10.5 ppg, BGG 10/20 units. 00:45 - 02:30 1.75 DRILL P INT1 Pump 25 bbl Hi-Vis, 2 ppg over mud weight sweep, Circ hole clean wI 800 GPM @ 3450 psi, 110 RPM 02:30 - 06:30 4.00 DRILL P INT1 Wipe hole to 10,650' on elevators, Pulled 40K over @ 10,650', Back ream out of hole f/1 0,650' to 10,186' wI drilling perameters, Pulled out on elevators f/10,186' to 8052' (10/20K overpulls), RIH to 10,968' with no problems. 06:30 - 11 :00 4.50 DRILL P INT1 Pump 25 bbl Hi-Vis, 2 ppg over mud weight sweep (Had heavy amounts of wall cake, and ECD's reached 11.7 ppg on btm's up) , Circ & condo mud and hole clean wI 800 GPM @ 3500 psi, 110/120 RPM 11 :00 - 16:30 5.50 DRILL P INT1 Monitor well, POOH 10 stands, Pump dry job, POOH to 200' (Hole in very good shape) 16:30 - 18:00 1.50 DRILL P INT1 POOH & Lay down BHA & Bit 18:00 - 19:30 1.50 CASE P INT1 Pull wear bushing, Set test plug, Change top pipe rams to 9-5/8", Test door seals to 3500 psi-OK 19:30 - 21 :30 2.00 CASE P INT1 Pull test plug, Make dummy run wI FMC 9-5/8" csg hanger, PJSM wI all personal on running casing, Rig to run 9-5/8" casing. 21 :30 - 00:00 2.50 CASE P INT1 Began running 9 5/8" 47# L-80 & 40#, S-95 BTC-M Csg to 2,021' with no problems, ran HES 9 5/8" float shoe, 2 jts 9 5/8" 47# csg, HES 9 5/8" float collar, thread locked conn below float collar and checked float equip, ran another 15 jts of 95/8" 47# L-80 BTC-M csg, (17 total) cont running 95/8" 40# S-95 BTC-M csg to 2,021' (49 jts of 265 in hole), Ran total of 37 Rigid straight blade centralizers all floating full length of joint, except 1-5' above shoe & 1-5' float collar. 10/11/2003 00:00 - 04:00 4.00 CASE P INT1 Cont RIH with 9 5/8" csg from 2,021' to 5,720' (133/8" csg shoe) 139 jts total in hole. 04:00 - 05:00 1.00 CASE P INT1 Break circ, Stage rate up to 8 bpm @ 620 psi, Circ capacity of csg. 05:00 - 12:00 7.00 CASE P INT1 ConI. RIH wI 9-5/8" csg. f/5,720' to 10,883', Circ. down 3 joints @ 7,500' & 9,500' at 10 minljl. to break circulation at rate of 8 bpm with no losses. 12:00-12:15 0.25 CASE P INT1 Make up hanger, Landing joint, Wash down & tag landing ring with shoe @ 10,963'. 12:15 - 14:00 1.75 CASE P INT1 Break circ., Stage rate up f/3 bpm to 12 bpm @ 1400 psi, Circ 1-1/2 times bottom's up with frank's fill up tool, UP 415K, ON 225K 14:00 - 14:30 0.50 CASE P INT1 Lay down Frank's fill up tool, Rig up Dowell's cement head. 14:30 - 16:00 1.50 CASE P INT1 Circ. & condo mud to cement 9-5/8" csg total of 1-1/2 times btm's up, Hold PJSM with all personal, Batch mix cement, Casing UP weight began to climb as lubes in mud decreased due to dilution of mud, Set casing on landing ring when PIU wts. reached 450K. (The string was reciprocated with app. 20 ft. strokes for 3112 bottoms up.) 16:00 -17:30 1.50 CEMT P INT1 Turned over to Dowell, pumped 5 bbls CW 100 at 8.3 ppg, pressure tested lines to 4,000 psi, pumped additional 75 bbls (80 total) of CW 100 at 6.2 bpm at 290 psi, pumped 50 bbls of Printed: 1012012003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10/18/2003 10/11/2003 16:00 - 17:30 1.50 CEMT P INT1 MudPush II spacer at 11.0 ppg at 6.0 bpm at 320 psi, shut down & dropped btm plug, mixed & pumped lead cement on the fly, pumped 237.0 bbls, 477 sxs of Premium "G" cmt at 11.5 ppg and 2.79 yield with additives, ave 5.7 bpm at 200 psi, pumped batch mixed tail cement, pumped 123.5 bbls, 578 sxs of Premium "G" cement with additives at 15.8 ppg and 1.20 yield, ave 6.0 bpm at 60 psi, shut down 17:30 - 19:00 1.50 CEMT P INT1 Dropped top plug and Dowell pumped 10 bbls FW behind plug, turned over to rig and displaced cement with 10.5 ppg mud, initial rate of 12 bpm at 910 psi, reduced rate to 9 bpm with 775 bbls away (1420 PSI) then to 3 BPM with app. 10 bbls. to bump. Max pressure while displacing cmt was 1420 psi, bumped plug to 3,500 psi with total of 816.6 bbls mud and 10 bbls fresh water, checked floats and held, had good returns during job, CIP at 19:00 hrs 10/11/2003, estTOC at 6,723'. Note: As lead cement rounded shoe app 15 bbl. loss was noted. 19:00 - 20:00 1.00 CEMT P INT1 Bleed off pressure and check floats, Lay down landing joint & casing equip. 20:00 - 21 :30 1.50 WHSUR P INT1 Install 9-5/8" x 13-3/8" Pack off & test same to 5000 psi for 10 min. 21 :30 - 22:00 0.50 EVAL P INT1 Perform Injectivity test on 9-5/8" x 13-3/8" annulas= 12.6 ppg EMW wI 528 psi, 4638' TVD, 528 psi Pumped away 10 bbls. mud. Repeated this every two hours to insure no cement is setting up in annulus. Compression strength of 500 was reported by Dowell lab at 4:30. 22:00 - 22:30 0.50 BOPSUR. P INT1 Change top pipe rams back to 3-1/2" x 6" varibles. 22:30 - 00:00 1.50 BOPSUR P INT1 Rig & test BOPE to 250 psi low & 4000 psi high, test waived by AOGCC Chuck Sheave. 10/12/2003 00:00 - 03:00 3.00 BOPSURP INT1 Test BOPE, 250 psi low, 4000 psi high, Hydril to 3500 psi high, Test waived by AOGCC Chuck sheave, Install wear bushing. 03:00 - 04:15 1.25 DRILL P LNR1 Rig & Pick up BHA #5, Bit, Motor, Pony, Stb, ARC, MWD, ADN. 04:15 - 04:45 0.50 DRILL P LNR1 Pump 6 bbls down 9-5/8" x 13-3/8" annulas to insure injectivity, PJSM for R.A.Sources 04:45 - 05:45 1.00 DRILL P LNR1 Load R.A. Sources, PIU 2- DC's, Jars, 2- HWDP, Surface test MWD tools. 05:45 - 09:45 4.00 DRILL P LNR1 RIH to 10,825' 09:45 - 10:45 1.00 DRILL P LNR1 Slip & cut drilling line 114', Service top drive while circ at 3.5 bpm. Note; Flushed 9-5/8" x 13-3/8" annulas with 50 bbls fresh water at 1.8 bpm @ 1700 psi, Rig up Little Red Service and Freeze protect annulas with 135 bbls 100 deg. Dead Crude at 1.5 bpm @ 1700 psi. 10:45 - 11 :45 1.00 CASE P LNR1 Rig & test 9-5/8" casing to 3500 psi for 30 min.- OK 11 :45 - 13:00 1.25 DRILL P LNR1 Wash down & tag float collar @ 10,877', Drill out shoe track & rate hole to 10,968'. 13:00 - 14:30 1.50 DRILL P LNR1 Change over to 9.0 ppg FLO-PRO NT Mud 14:30 -15:30 1.00 DRILL P LNR1 Drill 20' new hole to 10,988', Circ. 15 min. 15:30 - 16:00 0.50 DRILL P INT1 Perform FIT to 10.0 ppg EMW wI 431 psi, 8250' TVD, 9.0 ppg mud weight 16:00 - 22:30 6.50 DRILL P LNR1 Drill f/10,988' to 11,383' (8651' TVD) 8-1/2" TO, ART= 6.05 hrs, UP 280K, ON 190K, ROT 225K, TQ on 11 K- off WOB 40K, Printed: 10/20/2003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10/18/2003 10/12/2003 16:00 - 22:30 6.50 DRILL P LNR1 RPM 100/110, 11 K, 600 GPM @ 2650 psi, BGG 20 to 40 units, Maintain 3% lubes in mud 1-1/2% LUBETEX, 1-1/2% FLOLUBE. 22:30 - 00:00 1.50 DRILL P LNR1 Pump 25 bbl Hi-vis unweighted sweep & Circ. hole clean wI 2 times btm's up wI 600 GPM @ 2500 psi 10/13/2003 00:00 - 01 :00 1.00 DRILL P LNR1 Wipe hole f/11,383' to 10,920' (Had 40K pulls @ 11,200'), RIH to btm. @ 11,383' (No problems or fill). 01 :00 - 03:45 2.75 DRILL P LNR1 Circ. btm's up prior to pumping sweep- 15% increase in cuttings, No detectible trip gas, Pump 25 bbl weighted Hi-vis sweep & circ hole clean- 15% increase in cuttings on sweep, Circ total of 4 times btm's up. 03:45 - 04:15 0.50 DRILL P LNR1 Monitor well, POOH to 10,920'- No problems, Hole in very good shape. 04:15 - 04:30 0.25 DRILL P LNR1 Monitor well, Pump dry job, Drop 2-3/16" rabbit. 04:30 - 09:00 4.50 DRILL P LNR1 POOH to 292', Recover rabbit on top of jars. 09:00 - 11 :00 2.00 DRILL P LNR1 Lay down BHA #5, Clear floor. 11 :00 - 23:00 12.00 DRILL P LNR1 Rig Schlumberger wireline service, Rig & run MDT set tool 28 times from 11,313' to 10,983', Hole in very good shape. 23:00 - 00:00 1.00 DRILL P LNR1 Rig & run USIT log. 10/14/2003 00:00 - 04:30 4.50 EVAL P PROD1 Fin logging run #2 with US IT Bond log, POOH and RD Schlumberger wireline 04:30 - 05:00 0.50 CASE P PROD1 RU Doyon's 7" liner running equipment 05:00 - 05:15 0.25 CASE P PROD1 Held PJSM on running 7" liner 05:15 - 06:15 1.00 CASE P PROD1 PU & ran 12 jts of 7" 26#, L-80 BTC-M liner with 1-10' pup jt, MU Float shoe on btm of 1 st jt, float collar on btm of 2nd jt and landing collar in pin end of 3rd jt, thread locked conn below LC and checked float equip, Liner length 499.74' 06: 15 - 06:45 0.50 CASE P PROD1 MU Baker 7" x 9 5/8" HMC liner hanger & ZXP liner top pkr, RIH 1 std 5" DP & circ liner cap. 06:45 - 12:30 5.75 CASE P PROD1 Run 7" liner on 5" Dp from 526' to 10,910', (53' f/csg shoe) good returns while RIH 12:30 - 13:00 0.50 CASE P PROD1 Circ 1 DP and liner cap at shoe, circ at 6 bpm at 750 psi, string Up wt 235K, On wt 175K 13:00 - 13:30 0.50 CASE P PROD1 RIH with 7" liner on 5" DP from 10,910 and tagged btm at 11,383' with no problems in open hole 13:30 - 15:30 2.00 CASE P PROD1 MU Bakers plug dropping head and circ 1 btms up, staged pump rate up to 8 bpm at 1,250 psi, String wt Up 255K, On wt 180K, reciprocated pipe with no problems, held PJSM on cementing liner and batch mixed cement while circ hole 15:30 - 16:00 0.50 CEMT P PROD1 Dowell pumped 2 bbls FW and tested lines to 4,500 psi, then pumped 30 bbls CW 100 at 8.3 ppg followed with 30 bbls of MudPush at 11.0 ppg, pumped 30 bbls, 140 sxs of class "G" cement with additives at 15.8 ppg and 1.2 yield, pumped cement at an ave of 5 bpm at 500 psi, reciprocated pipe, shut down and washed up lines to cement head 16:00 - 16:45 0.75 CEMT P PROD1 Dropped DP wiper dart and displaced cement with 9.1 ppg FloPro mud, initial rate of 8 bpm at 1,175 psi, slowed rate and did not see Liner Wiper plug shear, cont displacement slowing to 4 bpm and bumped plug, pressured up to 4,500 psi to ensure liner wiper plug was sheared, bumped plug at 16:30 hrs, reciprocated pipe throughout job with full returns 16:45 -17:00 0.25 CASE P PROD1 Increased pressure to 4,000 psi to set Baker HMC liner hanger, bled off pressure and checked floats, ok. Released from Printed: 10/20/2003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10118/2003 10/14/2003 16:45 - 17:00 0.25 CASE P PROD1 hanger with 20 turns to right, press up to 1,000 psi and PU out of hanger, observed pressure loss when running tool was picked up app. 8 ft.. Circ 50 bbls at 10 bpm at 1,400 psi, set 60K wt down and set ZXP pkr. Note: 7" liner set at 11,383' with landing collar at 11,298' and top of liner at 10,859'. 17:00 - 19:00 2.00 CASE P PROD1 Circ hole clean at top of liner, at btms up, circ out 200 bbls of spacerlcement contaminated FloPro mud and no cement back to surface. ( PH up to 12.5 with wts. of 10.8) Lots of very thick, paste looking, solids coming over shakers app. 1000 stks following bottoms up. circ hole clean staging pump rate up to 18 bpm at 3,100 psi, circ a total of 3 btms up, st wt after releasing liner 225K up wt, 180K dn wt 19:00 - 00:00 5.00 CASE P PROD1 Pumped dry job and POOH to liner setting tool 10/15/2003 00:00 - 00:30 0.50 CASE P PROD1 LD Baker Liner Setting tool 00:30 - 02:00 1.50 CASE P PROD1 PU 6 1/8" Clean out BHA #6,6 1/8" bit, 7" csg scraper, XO, 14 jts 3 1/2" DP, XO & 9 5/8" csg scraper and RIH to 460' 02:00 - 03:30 1.50 CASE P PROD1 TIH with HWDP & Jars and BHA #6 on 5" DP to 6,550' 03:30 - 05:00 1.50 CASE P PROD1 Circ 2 hole volumes at 6,550', circ out contaminated mud and staged pump rate up to 18 bpm, 756 gpm at 1,900 psi and 70 rpm's, circ hole clean 05:00 - 06:45 1.75 CASE P PROD1 Cont TIH with bit & scrapers, tagged landing collar at 11,298', no problem RIH, PU wt 220K, ON wt 195K 06:45 - 09:00 2.25 CASE P PROD1 Circ 2.5 X btms up, circ out contaminated mud, circ hole clean, staged pump rate up to 18 bpm at 2,650 psi, 80 rpm's 09:00 -11:15 2.25 CASE P PROD1 Pumped 40 bbl Hi Vis 9.0 ppg seawater sweep and followed with 8.5 ppg seawater(Flushed both pumps, mud manifolds, kill line, etc., etc. at beginning of displacement) Displace out 9.0 ppg FloPro LSND mud with seawater, displaced hole at 18 bpm at 2,550 psi, Rot wt 200K, Up wt 250K, On wt 180K, 80 rpm's with 15K ft-Ibs off btm torque. Note: Pipe rotation was halted app. 3/4 of the way thru the displacement when torque reached 15 to 17,000. 11 :15 - 12:00 0.75 CASE P PROD1 RU & tested 7" liner & 9 5/8" csg to 4,000 psi for 30 min, good test 12:00 - 17:00 5.00 CASE P PROD1 POOH with bit and scrapers to 9 5/8" scraper to 460'. SLM with no correction. 17:00 - 18:00 1.00 CASE P PROD1 POOH LD BHA #6, bit, scrapers & 3 1/2" DP 18:00 - 18:45 0.75 RUNCOfvP COMP RU Doyon's 7" handling tools and held PJSM on PU tbg tail assembly 18:45 - 19:30 0.75 RUNCOfvP COMP Began to PU & MU 7" tbg tail assembly with 7" TC-II conn, MU WLEG and PU SABL-3 packer with pups and found packer element to be cut/damaged, LD packer and WLEG. Check with materials for equipment to change out TC-11 pups top and bottom of packer. No TC-11 collars or pups available. (sent in packer assembly to Baker machine to heat collars and liquefy BakerLok. Back out bad packer and replace.) 19:30 - 21 :30 2.00 RUNCOfvP COMP Pulled wear bushing & installed test plug, changed out top set of rams over to 7 5/8" and tested door seals to 2,000 psi and ck ok, pulled test plug and re-installed wear bushing, 21 :30 - 23:00 1.50 RUNCOfvP COMP Slip & cut 58' of drlg line 23:00 - 00:00 1.00 RUNCOfvP COMP Prepared pipe shed to LD 5" DP and PU 7 5/8" completion while waiting on new 7" x 9 5/8" SABL-3 Pkr with 7" TC-II pup Printed: 10/20/2003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 9/30/2003 10/18/2003 Spud Date: 10/1/2003 End: 10/18/2003 10/15/2003 23:00 - 00:00 1.00 RUNCOIIIP COMP jts. 10/16/2003 00:00 - 00:30 0.50 RUNCOIIIP COMP Serviced Top Drive and service loop, unloaded Baker 7" SABL-3 Pkr 00:30 - 01:15 0.75 RUNCOIIIP COMP PU tbg tail assembly, PU & MU 7" tbg tail assembly with 7" TC-II conn, assembly includes WLEG, RN nipple, R Nipple and SABL-3 packer, with pups, PBR and setting tool overall toollenght 89.76' 01:15 - 06:30 5.25 RUNCOIIIP COMP RIH with Tbg tail & Pkr assembly, tagged TOL at 10,859', dropped ball & rod & PU 54" to put Pkr on depth @ 10,764 with WLEG at 10,805, string Up wt 237K, On wt 181 K St Wt's at 3,000' Up 98K, On 100K, at 6,000' Up 147K, On 128K, at 9,000' Up 195K, On 156K 06:30 - 07:45 1.25 RUNCOIIIP COMP Set 7" x 9 5/8" SABL-3 pkr, with ball on seat pressured up to 3,500 psi and held for 15 min and ck ok, bled down, Push pulled pkr, then pressure tested annulus to 1,000 psi for 15 min and ck ok, set down 15K and rotated 15 turns to right & released pkr. Set WLEG at 10,805', SABL-3 Pkr at 10,764" and PBR at 10,728'. 07:45 - 15:00 7.25 RUNCOIIIP COMP POOH LD 5" DP, LD 339 jts 5" DP & 21 jts 5" HWDP 15:00 - 15:30 0.50 RUNCOIIIP COMP LD Baker running tool and pulled wear bushing 15:30 -16:30 1.00 RUNCOIIIP COMP RU Doyon's 7" & 7 5/8" handling equipment with torque turn to run completion 16:30 -16:45 0.25 RUNCOIIIP COMP Held PJSM with rig crew, Tbg thread rep, and Doyon csg on running 7" & 7 5/8" completion 16:45 - 00:00 7.25 RUNCOIIIP COMP MU 7" Seal assembly with "R" Nipple & XO to 7 5/8" 29.7#, L-80 ST-L tbg, began PU 7 5/8" completion tbg and RIH to 4,455' (111 jts of 264 in the hole) Up wt 142K, On wt 127K 10/17/2003 00:00 - 09:30 9.50 RUNCOIIIP COMP Fin TIH with seal assmbly PU 7 5/8" 29.7# L-80 STL tbg, RIH with 263 jts to 10,656' 09:30 - 11 :30 2.00 RUNCOIIIP COMP MU jt #264 of 7 5/8" tbg circ slowly and located top of PBR with seal assembly, LD jt and spaced out 7 5/8" tbg string with 2- 7 5/8" pup jts, st wt up 330K, dn 287K (block wt 35K), MU landing jt with hanger 11 :30 - 12:45 1.25 RUNCOIIIP COMP Reverse circ 165 bbls of treated 8.5 ppg seawater with COREXIT corrosion inhibitor at 5 bpm at 650 psi. 12:45 - 15:00 2.25 RUNCOIIIP COMP RU Little Red and pumped 144 bbls of Diesel for freeze protection down 9 5/8" x 7 5/8" annulus. Connected tbg to annulus and allowed to U-tube 15:00 - 17:00 2.00 RUNCOIIIP COMP Landed 7 5/8" tbg in hanger with WLEG at 10,809', SABL-3 Pkr at 10,768', end of seals at 10,746', 3' off NO GO, top of PBR set at 10,732' and "DB" Nipple at 2,232', RILDS NOTE:There is a Rod and Ball assembly on seat in the "RN" NO-GO nipple at 10,796. This is a 1 7/8" steel Ball/Rod assy. (00=2.125") 17:00 - 19:30 2.50 RUNCOIIIP COMP RU & tested 7 5/8" tbg to 4,000 psi for 30 min using Little Red, good test, bled tbg down to 2,500 psi, pressure tested annulus to 4,000 psi for 30 min, good test, bled down both annulus and tbg. NOTE: John crisp with AOGCC waived witnessing of test 19:30 - 20:45 1.25 RUNCOIIIP COMP LD Landing Jt and drained diesel in stack, NOTE: Had difficulty backing out landing jt and found threads galled on 7" TC-II pin XO back to DP 20:45 - 00:00 3.25 RUNCOIIIP COMP Installed TWC and NO BOP stack Printed: 10/20/2003 8:50:55 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-O? PSI-O? DRILL +COMPLETE DOYON DOYON 141 Start: 9/30/2003 Rig Release: 10/18/2003 Rig Number: Spud Date: 10/1/2003 End: 10/18/2003 10/18/2003 00:00 - 02:30 02:30 - 03:30 2.50 WHSUR 1.00 WHSUR COMP COMP N/U adapter flange and tree. Pressure test tree and adapter flange with diesel to 5,000. Good test. Pull back pressure valve and lay down lubricator. Remove double annulus valve from tree. M/U blank flange of Swab valve. Secure tree for release. P/U cellar area. 03:30 - 04:30 04:30 - 06:00 1.00 WHSUR 1.50 WHSUR COMP COMP Note: Release rig from PSI-07 @ 06:00 HRS. 10-18-2003 per Alan Madsen Printed: 1012012003 8:50:55 AM - e Well: Field: API: Permit: PSI-O? Prudhoe Bay Unit 50-029-23177-00-00 203-148 Accept: Spud: Release: Ri~r 09/30/03 10/01/03 10/18/03 Doyon 141 POST RIG WORK 10/25/03 PULLED BALL & ROD FROM 10776' SLM. PULLED RCH @ 10,780' SLM. PULLED RBX NIPPLE REDUCER @ 10,778' SLM. DRIFTED WI 33/8" DUMMY GUN TO 11,294' SLM. SMALL SAMPLE OF DRILLING MUD & FINES. 10/27/03 RST SIGMA LOW WITH TEMPERATURE PASSES. DEPTH REFERENCED TO SLB MWD GR DATED12-0CT- 2003, TAG TD AT 11296'. TEMP PASS LOGGED AT 100 FPM DOWN SURFACE TO TD. RST LOG WILL BE USED TO MONITOR FUTURE FLUID MOVEMENT. PAD OPERATOR NOTIFIED WELL LEFT SHUT-IN. 12/26/03 RST SIGMA LOG, RAN FOUR LOGGING PASSES FROM 10800' - 11296' AS PER PROGRAM. THERE IS A DISCREPANCY IN THE WELL SCHEMATIC, TIED INTO SLB RST LOG RUN 27-0CT-03. SET ALL TOOL PARAMETERS THE SAME AS RST LOG 27-0CT-03. ALL LOGGING PASSES AT 3600 FTIHR, TAGGED BOTTOM AT 11296'. SHUT IN. 04/20/04 PERFORMED THREE RST PASSES IN SIGMA MODE: ONE @ 30 FPM & TWO @ 60 FPM FROM TD (11296' TO 10750'). TIED INTO SCHLUMBERGER RST LOG DATED 27-0CT-2003. SET ALL TOOL PARAMETERS THE SAME AS RST LOG DATED 27-0CT-2003. WELL LEFT SHUT-IN. 08/16/04 RUN 3.38" HSD 6 SPF 60 DEG PHASED POWER JET CHARGES TO PERFORATE 11228' - 11256' AS PER PROGRAM. USED COLLAR LOCATOR TO TIE-IN TO SLB RST LOG DATED 27-0CT-2003. WELL HEAD PRESSURE WAS 250 PSI BEFORE AND 100 PSI AFTER SHOOTING. GOOD SHOT INDICATION. NOTIFIED PAD OPERATOR, WELL SHUT-IN AND SECURE. 08/19/04 RAN SBHPS SEE LOG FOR TIMES & STOPS. 08/20/04 FINISH RUNNING SBHPS. SET 7" A-1ISSSV (SERIAL # HVS-398). NOTIFIED DSO OF WELL STATUS. SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay Unit Well. . . . . . . . . . . . . . . . . . . . .: PSI-07 API number...............: 50-029-23177-00 Engineer.................: E. Roux RIG:.....................: Doyon 141 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent.......: 17.40 ft KB above permanent.......: N/A - Top Drive OF above permanent.......: 45.40 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70 18 39.251 Departure (+E/W-)........: W 148 18 51.78 Azimuth from rotary table to target: 326.75 degrees 13-0ct-2003 04:40:15 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 6 01-0ct-03 13-0ct-03 123 0.00 ft 11383.00 ft e ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2002 Magnetic date............: 30-Sep-2003 Magnetic field strength..: 1151.37 HCNT Magnetic dec (+E/W-).....: 25.92 degrees Magnetic dip.............: 80.88 degrees ----- MWD survey Reference Reference G.... ..........: Reference H........... ...: Reference Dip............: Tolerance of G....... ....: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1151.37 HCNT 80.88 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees - ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.92 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.92 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 13-0ct-2003 04:40:15 Page 2 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (de g) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 200.00 0.23 156.70 200.00 200.00 -0.40 -0.37 0.16 0.40 156.70 0.12 GYR None 3 300.00 0.27 121.91 100.00 300.00 -0.81 -0.68 0.44 0.81 147.11 0.15 GYR None 4 400.00 0.39 130.58 100.00 400.00 -1.35 -1.02 0.90 1. 36 138.78 0.13 GYR None 5 500.00 0.31 134.50 100.00 499.99 -1. 94 -1. 43 1. 35 1. 97 136.78 0.08 GYR None 6 544.00 0.37 119.17 44.00 543.99 -2.18 -1. 59 1. 56 2.22 135.55 0.25 GYR None e 7 634.00 0.35 126.22 90.00 633.99 -2.70 -1. 89 2.03 2.78 132.94 0.05 GYR None 8 725.00 0.48 74.27 91. 00 724.99 -3.07 -1. 95 2.62 3.27 126.65 0.42 GYR None 9 817 . 00 0.56 39.90 92.00 816.99 -3.06 -1.50 3.28 3.61 114.60 0.34 GYR None 10 909.00 0.94 43.94 92.00 908.98 -2.76 -0.61 4.10 4.14 98.53 0.42 GYR None 11 1004.00 1. 41 26.19 95.00 1003.96 -1. 99 1. 00 5.15 5.25 79.06 0.62 GYR None 12 1120.03 1. 75 57.50 116.03 1119.95 -1. 29 3.23 7.28 7.96 66.07 0.79 MWD IFR MSA - 13 1213.64 2.09 69.63 93.61 1213.50 -1.69 4.59 10.08 11. 08 65.52 0.56 MWD IFR MSA - 14 1306.66 1. 91 54.55 93.02 1306.47 -2.01 6.08 12.93 14.29 64.82 0.60 MWD IFR MSA - 15 1398.97 1. 97 29.18 92.31 1398.73 -1.21 8.36 14.96 17.14 60.81 0.92 MWD IFR MSA 16 1491. 80 3.18 345.74 92.83 1491.47 1.96 12.25 15.11 19.45 50.97 2.38 MWD IFR MSA - 17 1585.30 2.42 1. 34 93.50 1584.86 6.04 16.73 14.51 22.15 40.93 1.14 MWD IFR MSA - 18 1677.34 2.22 67.75 92.04 1676.84 7.30 19.35 16.21 25.24 39.95 2.77 MWD IFR MSA - 19 1770.00 2.43 67.44 92.66 1769.42 6.59 20.78 19.68 28.63 43.44 0.23 MWD IFR MSA - - 20 1863.06 2.25 60.23 93.06 1862.40 6.11 22.45 23.09 32.20 45.81 0.37 MWD IFR MSA e - 21 1955.85 2.06 8.77 92.79 1955.14 7.24 25.00 24.93 35.30 44.91 2.02 MWD IFR MSA - 22 2049.32 5.47 333.09 93.47 2048.40 12.92 30.64 23.17 38.41 37.09 4.26 MWD IFR MSA - - 23 2142.12 8.31 330.97 92.80 2140.52 24.01 40.45 17.91 44.23 23.88 3.07 MWD IFR MSA - 24 2234.66 10.95 330.20 92.54 2231.75 39.45 53.92 10.29 54.90 10.81 2.86 MWD IFR MSA - 25 2327.17 13.58 330.86 92.51 2322.14 59.06 71.04 0.64 71.04 0.51 2.85 MWD IFR MSA 26 2420.75 15.84 335.47 93.58 2412.65 82.64 92.25 -10.02 92.80 353.80 2.72 MWD IFR MSA - - 27 2513.66 19.66 336.09 92.91 2501.12 110.61 118.09 -21. 62 120.05 349.62 4.12 MWD IFR MSA 2586.39 - 28 2605.67 24.42 332.72 92.01 144.82 149.16 -36.62 153.59 346.21 5.35 MWD IFR MSA 92.78 2669.52 - 29 2698.45 28.26 331.00 185.81 185.43 -56.07 193.72 343.18 4.22 MWD IFR MSA 2749.73 - 30 2791.46 32.52 328.77 93.01 232.78 226.09 -79.72 239.73 340.58 4.74 MWD IFR MSA SCHLUMBERGER Survey Report 13-0ct-2003 04:40:15 Page 3 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2883.71 36.78 326.22 92.25 2825.61 285.20 270.27 -107.94 291. 03 338.23 4.88 MWD IFR MSA - 32 2976.98 40.73 326.07 93.27 2898.33 343.58 318.74 -140.46 348.32 336.22 4.24 MWD IFR MSA 91.60 2966.15 370.19 409.16 - 33 3068.58 43.73 327.30 405.13 -174.26 334.79 3.40 MWD IFR MSA - 34 3161.50 47.79 326.83 92.92 3030.96 471.69 426.05 -210.45 475.19 333. 71 4.38 MWD IFR MSA - 35 3254.53 50.69 327.19 93.03 3091.69 542.14 485.15 -248.81 545.23 332.85 3.13 MWD IFR MSA - 36 3346.77 51.17 327 . 41 92.24 3149.83 613.75 545.41 -287.50 616.55 332.21 0.55 MWD IFR MSA e - 37 3440.02 50.72 327.72 93.25 3208.58 686.16 606.53 -326.34 688.75 331.72 0.55 MWD IFR MSA - 38 3534.24 51.11 326.31 94.22 3267.99 759.29 667.87 -366.15 761. 65 331.27 1. 23 MWD IFR MSA - 39 3627.40 51. 59 325.51 93.16 3326.17 832.03 728.12 -406.93 834.12 330.80 0.85 MWD IFR MSA - 40 3719.51 51.67 325.52 92.11 3383.35 904.23 787.65 -447.82 906.05 330.38 0.09 MWD IFR MSA - - 41 3810.93 51.97 326.05 91.42 3439.86 976.09 847.07 -488.23 977.70 330.04 0.56 MWD IFR MSA - 42 3904.54 51. 52 325.76 93.61 3497.82 1049.59 907.94 -529.43 1051.03 329.75 0.54 MWO IFR MSA - - 43 3997.03 50.44 324.40 92.49 3556.05 1121.41 966.86 -570.56 1122.66 329.45 1. 63 MWO IFR MSA 93.34 3616.62 - - 44 4090.37 48.64 325.06 1192.38 1024.84 -611.57 1193.45 329.17 2.00 MWD IFR MSA 325.18 92.99 3677.88 - - 45 4183.36 48.94 1262.31 1082.23 -651.58 1263.24 328.95 0.34 MWD IFR MSA - 46 4276.56 50.11 324.69 93.20 3738.38 1333.17 1140.26 -692.31 1333.97 328.74 1. 32 MWD IFR MSA 92.96 3797.79 - - 47 4369.52 50.44 325.70 1404.64 1198.96 -733.11 1405.33 328.56 0.91 MWD IFR MSA 51.73 324.75 92.36 3855.81 - 48 4461.88 1476.47 1257.98 -774.10 1477.08 328.39 1. 61 MWD IFR MSA 93.00 - 49 4554.88 52.04 325.53 3913.21 1549.61 1318.02 -815.93 1550.14 328.24 0.74 MWD IFR MSA 92.37 3970.40 - 50 4647.25 51.46 325.78 1622.14 1377.92 -856.85 1622.60 328.12 0.66 MWD IFR MSA - - - 51 4739.81 52.18 325.43 92.56 4027.61 1694.88 1437.95 -897.95 1695.30 328.02 0.83 MWD IFR MSA 93.01 - - 52 4832.82 51. 21 325.58 4085.26 1767.85 1498.11 -939.29 1768.21 327.91 1. 05 MWD IFR MSA - 53 4925.93 51.53 325.34 93.11 4143.39 1840.57 1558.02 -980.53 1840.89 327.82 0.40 MWD IFR MSA 325.52 93.44 4201.39 - - 54 5019.37 51.73 1913.81 1618.34 -1022.10 1914.08 327.72 0.26 MWD IFR MSA 92.24 - - 55 5111.61 51.69 325.62 4258.55 1986.19 1678.06 -1063.03 1986.43 327.65 0.10 MWD IFR MSA - - 56 5204.15 51.49 325.51 92.54 4316.04 2058.69 1737.87 -1104.03 2058.90 327.57 0.24 MWD IFR MSA 5296.82 51.26 325.29 92.67 4373.89 2131.07 1797.46 - 57 -1145.14 2131.25 327.50 0.31 MWD IFR MSA 58 5388.88 51. 20 324.29 92.06 4431. 54 2202.80 1856.10 -1186.53 - 2202.94 327.41 0.85 MWD IFR MSA 59 5482.21 51.38 324.87 93.33 4489.90 2275.57 1915.45 -1228.73 - - 2275.69 327 . 32 0.52 MWD IFR MSA 60 5576.07 52.25 325.00 93.86 4547.93 2349.31 1975.84 -1271.12 - - 2349.40 327.25 0.93 MWD IFR MSA - SCHLOMBERGER Survey Report 13-0ct-2003 04:40:15 Page 4 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ---..,......- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ========= -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 5670.32 52.08 325.03 94.25 4605.74 2423.71 2036.82 -1313.80 2423.78 327.18 0.18 MWD IFR MSA - 62 5763.00 51.72 324.90 92.68 4662.93 2496.61 2096.54 -1355.67 2496.66 327.11 0.40 MWD IFR MSA - 63 5857.12 51.61 325.36 94.12 4721.31 2570.41 2157.11 -1397.87 2570.44 327.06 0.40 MWD IFR MSA - - 64 5950.67 51.71 325.39 93.55 4779.34 2643.76 2217.49 -1439.57 2643.79 327.01 0.11 MWD IFR MSA - - 65 6043.81 51.53 324.26 93.14 4837.17 2716.73 2277.17 -1481.63 2716.75 326.95 0.97 MWD IFR MSA - 66 6136.18 51.36 325.58 92.37 4894.74 2788.93 2336.28 -1523.14 2788.94 326.90 1.13 MWD IFR MSA e - - 67 6229.22 51.11 325.47 93.04 4952.99 2861.46 2396.09 -1564.20 2861.46 326.86 0.28 MWD IFR MSA - 68 6322.04 50.85 325.61 92.82 5011.43 2933.55 2455.55 -1605.01 2933.56 326.83 0.30 MWD IFR MSA - 69 6415.06 50.60 325.46 93.02 5070.32 3005.55 2514.91 -1645.76 3005.55 326.80 0.30 MWD IFR MSA - 70 6507.49 50.69 325.33 92.43 5128.93 3077.00 2573.74 -1686.35 3077.00 326.77 0.15 MWD IFR MSA - 71 6600.49 51.25 325.75 93.00 5187.49 3149.22 2633.31 -1727.22 3149.22 326.74 0.70 MWD IFR MSA - 72 6692.93 51. 79 326.21 92.44 5245.01 3221.58 2693.29 -1767.71 3221.58 326.72 0.70 MWD IFR MSA - 73 6785.34 52.27 325.97 92.41 5301.87 3294.42 2753.74 -1808.35 3294.43 326.71 0.56 MWD IFR MSA - - 74 6878.50 52.37 325.94 93.16 5358.81 3368.15 2814.84 -1849.63 3368.15 326.69 0.11 MWD IFR MSA - 75 6971.19 52.35 326.49 92.69 5415.42 3441.54 2875.84 -1890.44 3441.54 326.68 0.47 MWD IFR MSA - 76 7063.93 52.49 327.03 92.74 5471.98 3515.04 2937.31 -1930.73 3515.04 326.68 0.49 MWD IFR MSA - - 77 7156.47 52.32 326.72 92.54 5528.44 3588.36 2998.72 -1970.80 3588.36 326.69 0.32 MWD IFR MSA - 78 7249.93 51.69 327.01 93.46 5585.97 3662.01 3060.39 -2011.06 3662.02 326.69 0.72 MWD IFR MSA - 79 7346.64 50.76 326.33 96.71 5646.54 3737.41 3123.39 -2052.48 3737.41 326.69 1.11 MWD IFR MSA - 80 7431.76 50.09 325.95 85.12 5700.76 3803.01 3177.87 -2089.04 3803.02 326.68 0.86 MWD IFR MSA - - 81 7525.69 50.50 325.84 93.93 5760.77 3875.27 3237.71 -2129.56 3875.27 326.67 0.45 MWD IFR MSA - 82 7620.32 50.93 325.36 94.63 5820.69 3948.50 3298.14 -2170.94 3948.50 326.65 0.60 MWD IFR MSA - 83 7714.70 51.04 325.36 94.38 5880.10 4021. 81 3358.47 -2212.62 4021.82 326.62 0.12 MWD IFR MSA - 84 7807.05 50.83 325.28 92.35 5938.30 4093.49 3417.44 -2253.42 4093.50 326.60 0.24 MWD IFR MSA - 85 7900.54 50.80 324.79 93.49 5997.37 4165.92 3476.82 -2294.95 4165.94 326.57 0.41 MWD IFR MSA - 86 7992.95 50.90 325.21 92.41 6055.71 4237.55 3535.53 -2336.05 4237.58 326.55 0.37 MWD IFR MSA - 87 8085.72 50.68 325.74 92.77 6114.36 4309.41 3594.75 -2376.79 4309.45 326.53 0.50 MWD IFR MSA - 88 8178.23 50.57 326.01 92.51 6173.05 4380.92 3653.94 -2416.91 4380.95 326.52 0.26 MWD IFR MSA - 89 8270.86 50.41 326.75 92.63 6231.98 4452.38 3713.45 -2456.48 4452.42 326.52 0.64 MWD IFR MSA - 90 8364.38 50.58 326.52 93.52 6291.47 4524.54 3773.72 -2496.16 4524.57 326.52 0.26 MWD IFR MSA - SCHLOMBERGER Survey Report 13-0ct-2003 04:40:15 Page 5 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8456.62 50.81 327.61 92.24 6349.90 4595.91 3833.62 -2534.96 4595.94 326.53 0.95 MWD IFR MSA - 92 8549.01 50.68 327.78 92.39 6408.36 4667.44 3894.09 -2573.20 4667.47 326.54 0.20 MWD IFR MSA 93.36 - 93 8642.37 50.48 328.30 6467.65 4739.54 3955.28 -2611.37 4739.57 326.57 0.48 MWD IFR MSA 94.52 4812.42 - 94 8736.89 50.45 327.94 6527.82 4017.18 -2649.87 4812.44 326.59 0.30 MWD IFR MSA - - 95 8828.96 50.42 327 . 43 92.07 6586.46 4883.39 4077.16 -2687.82 4883.40 326.61 0.43 MWD IFR MSA - 96 8920.06 50.50 327.21 91.10 6644.46 4953.64 4136.29 -2725.75 4953.65 326.62 0.21 MWD IFR MSA e - 97 9014.13 50.57 327.10 94.07 6704.25 5026.26 4197.31 -2765.14 5026.27 326.62 0.12 MWD IFR MSA - 98 9105.65 50.74 327.91 91.52 6762.27 5097.03 4257.00 -2803.16 5097.04 326.64 0.71 MWD IFR MSA - - 99 9197.69 50.98 328.07 92.04 6820.37 5168.40 4317.54 -2841.00 5168.40 326.65 0.29 MWD IFR MSA - 100 9292.55 50.50 327.83 94.86 6880.40 5241.83 4379.79 -2879.97 5241.83 326.67 0.54 MWD IFR MSA - 101 9384.66 49.63 327.64 92.11 6939.53 5312.44 4439.51 -2917.68 5312.45 326.69 0.96 MWD IFR MSA 91.99 - - 102 9476.65 48.41 327.54 6999.85 5381. 88 4498.14 -2954.90 5381. 89 326.70 1. 33 MWD IFR MSA 93.06 5450.16 - - 103 9569.71 46.00 327.53 7063.07 4555.75 -2991.55 5450.16 326.71 2.59 MWD IFR MSA 94.03 7129.89 5516.29 - - 104 9663.74 43.41 327.47 4611. 53 -3027.09 5516.29 326.72 2.75 MWD IFR MSA 92.49 - 105 9756.23 41. 42 327.22 7198.17 5578.67 4664.06 -3060.74 5578.67 326.73 2.16 MWD IFR MSA - - 106 9848.67 39.69 327.46 92.44 7268.41 5638.77 4714.65 -3093.18 5638.77 326.73 1. 88 MWD IFR MSA 37.69 327.38 92.71 7340.77 5696.71 -3124.38 - 107 9941.38 4763.48 5696.71 326.74 2.16 MWD IFR MSA 93.14 5752.16 - 108 10034.52 35.39 327.06 7415.59 4810.11 -3154.40 5752.16 326.74 2.48 MWD IFR MSA - 109 10127.43 33.71 326.64 92.91 7492.11 5804.85 4854.22 -3183.21 5804.85 326.74 1.83 MWD IFR MSA 93.02 5854.89 - - 110 10220.45 31.38 325.80 7570.52 4895.82 -3211.02 5854.89 326.74 2.55 MWD IFR MSA - - e 111 10313.44 28.94 325.30 92.99 7650.92 5901.59 4934.35 -3237.44 5901.59 326.73 2.64 MWD IFR MSA 93.09 - - 112 10406.53 26.46 325.68 7733.33 5944.85 4970.00 -3261. 96 5944.85 326.72 2.67 MWD IFR MSA 91. 63 - - 113 10498.16 23.89 324.98 7816.25 5983.81 5002.06 -3284.12 5983.81 326.71 2.82 MWD IFR MSA - - 114 10592.61 22.79 323.88 94.45 7902.97 6021.20 5032.50 -3305.88 6021.20 326.70 1. 25 MWD IFR MSA 91. 90 - - 115 10684.51 21.92 324.47 7987.96 6056.12 5060.83 -3326.34 6056.12 326.68 0.98 MWD IFR MSA - - 116 10775.80 20.20 327.60 91.29 8073.16 6088.91 5088.01 -3344.69 6088.91 326.68 2.25 MWD IFR MSA 93.34 - - 117 10869.14 18.76 329.17 8161.15 6120.02 5114.51 -3361.02 6120.02 326.69 1. 64 MWD IFR MSA 18.05 329.12 38.90 8198.06 6132.29 5125.05 -3367.32 - 118 10908.04 6132.29 326.69 1. 83 MWD IFR MSA 11033.63 17.75 329.66 125.59 8317.57 6170.85 5158.27 -3386.97 - 119 6170.85 326.71 0.27 MWD IFR MSA 120 11125.54 17.49 328.85 91.91 8405.17 6198.64 5182.18 -3401.19 - - 6198.64 326.72 0.39 MWD IFR MSA - SCHLUMBERGER Survey Report 13-0ct-2003 04:40:15 Page 6 of 6 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 121 11218.74 16.83 328.85 93.20 8494.22 6226.12 5205.72 -3415.42 6226.12 326.73 0.71 MWD IFR MSA - 122 11311.01 16.64 328.46 92.27 8582.58 6252.67 5228.41 -3429.24 6252.67 326.74 0.24 MWD IFR MSA 123 11383.00 16.64 328.46 71.99 8651.56 6273.28 5245.98 -3440.02 6273.28 326.75 0.00 Projected to TD e [(c)2003 IDEAL 108 1C 01 ] - - e Schlumbepuep PSI-07 Survey Report Survey I DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 326.750' Vertical Section Origin: N 0.000 It, E 0.000 It TVD Reference Datum: KB TVD Reference Elevation: 45.40 ft relative to MSL Sea Bed I Ground Level Elevation: 17.40 ft relative to MSL Magnetic Declination: 25.734' Tolel Field Strength: 57592.906 nT Magnetic Dip: 80.907' Declination Date: October 03, 2003 Magnetic Declination Model: BGGM 2003 North Reference: True North Total Corr Mag North"> True North: +25.734' Local Coordinates Referenced To: WeD Head Report Date: 13-0ct-03 Client: 8P Exploration Field: Prudhoe Bay Unit - Usburne Struclure I Slot: East Dock (PSI) / PSI-7 Well: PSI-07 Borehole: PSI-07 UWUAPI#: 500292317700 Survey Name I Date: PSI-07 I October 13, 2003 TortI AHD I DDII ERD ratio, 133.227' /6311.55 ft! 6.044/0.730 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lal/Long' N 70.31090311, W 148.31438346 Location Grid NlE YIX: N 5966158.980 ftUS, E 707996.330 ftUS Grid Convergence Angle: +1.58711851' Grid Scale Faclor: 0.99994915 Measured I Depth (It) 0.00 200.00 300.00 400.00 500.00 544.00 634.00 725.00 817.00 909.00 1004.00 1120.03 1213.64 1306.66 1398.97 1491.80 1585.30 1677.34 1770.00 1863.06 1955.85 2049.32 2142.12 2234.66 2327.17 2420.75 Inclination I ( deg) 0.00 0.23 0.27 0.39 0.31 2.06 5.47 8.31 10.95 13.58 15.84 Azimuth I (deg) 0.00 156.70 121.91 130.58 134.50 0.37 0.35 0.48 0.56 0.94 119.17 126.22 74.27 39.90 43.94 Course I Length (It) 0.00 200.00 100.00 100.00 100.00 95.00 116.03 93.61 93.02 92.31 92.83 93.50 92.04 92.66 93.06 92.79 93.47 92.80 92.54 92.51 93.58 TVD I Sub-Sea TVD I (It) (It) 0.00 -45.40 200.00 154.60 300.00 254.60 400.00 354.60 500.00 454.60 44.00 90.00 91.00 92.00 92.00 543.99 633.99 724.99 816.99 908.98 498.59 588.59 679.59 771.59 863.58 958.56 1074.55 1168.10 1261.07 1353.33 1446.07 1539.46 1631.44 1724.02 1817.00 1909.74 2003.00 2095.12 2186.35 2276.74 2367.25 SUNeyEditor Ver 3.1 RT -SP3.03-HF1.2 Bld( d031 n-546 ) 1.41 1.75 2.09 1.91 1.97 26.19 57.50 69.63 54.55 29.18 3.18 2.42 2.22 2.43 2.25 345.74 1.34 67.75 67.44 60.23 8.77 333.09 330.97 330.20 330.86 335.47 1003.96 1119.95 1213.50 1306.47 1398.73 1491.47 1584.86 1676.84 1769.42 1862.40 1955.14 2048.40 2140.52 2231.75 2322.14 2412.65 Vertical I Section (ft) 0.00 -0.40 -0.81 -1.35 -1.94 -2.18 -2.70 -3.07 -3.06 -2.76 -1.99 -1.29 -1.69 -2.01 -1.21 1.96 6.04 7.30 6.59 6.11 7.24 12.92 24.01 39.45 59.06 82.64 NS (ft) 0.00 -0.37 -0.68 -1.02 -1.43 -1.59 -1.89 -1.95 -1.50 -0.61 12.25 16.73 19.35 20.78 22.45 25.00 30.64 40.45 53.92 71.04 92.25 EW (ft) 0.00 0.16 0.44 0.90 1.35 1.00 3.23 4.59 6.08 8.36 -10.02 Closure I (ft) 0.00 0.40 0.81 1.36 1.97 1.56 2.03 2.62 3.28 4.10 5.15 7.28 10.08 12.93 14.96 15.11 14.51 16.21 19.68 23.09 19.45 22.15 25.24 28.63 32.20 ~?su: I DLS I Build Rate I Walk Rate I (:~) (dlg/100 ft) (dlg/100 fI) (dlg/100 fI) 0.00 0.00 0.00 0.00 156.70 0.12 0.12 0.00 147.11 0.15 0.04 -34.79 138.78 0.13 0.12 8.67 136.78 0.08 -0.08 3.92 2.22 2.78 3.27 3.61 4.14 135.55 132.94 126.65 114.60 98.53 24.93 23.17 17.91 10.29 0.64 35.30 38.41 44.23 54.90 71.04 5.25 7.96 11.08 14.29 17.14 79.06 66.07 65.52 64.82 60.81 92.80 50.97 40.93 39.95 43.44 45.81 44.91 37.09 23.88 10.81 0.51 353.80 PSI-7\PSI-07\PSI-07\PSI-07 0.25 0.05 0.42 0.34 0.42 0.62 0.79 0.56 0.60 0.92 2.38 1.14 2.77 0.23 0.37 2.02 4.26 3.07 2.86 2.85 2.72 0.14 -0.02 0.14 0.09 0.41 0.49 0.29 0.36 -0.19 0.06 1.30 -0.81 -0.22 0.23 -0.19 -0.20 3.65 3.06 2.85 2.84 -34.84 7.83 -57.09 -37.36 4.39 -18.68 26.98 12.96 -16.21 -27.48 -46.80 16.68 72.15 -0.33 -7.75 -55.46 -38.17 -2.28 -0.83 0.71 2.42 Northing (flUS) 5966158.98 5966158.62 5966158.31 5966157.98 5966157.58 5966157.44 5966157.15 5966157.10 5966157.57 5966158.48 5966160.12 5966162.41 5966163.85 5966165.42 5966167.75 5966171.64 5966176.11 5966178.77 5966180.30 5966182.06 5966184.66 5966190.25 5966199.90 5966213.16 5966230.00 4.93 5966250.92 Eastlng (flUS) 707996.33 707996.50 707996.79 707997.25 707997.72 707997.93 707998.41 707999.01 707999.65 708000.44 708001.45 708003.51 708006.28 708009.09 708011.05 708011.09 708010.37 708012.00 708015.43 708018.79 70B020.55 708018.64 708013.11 708005.13 707995.00 707983.76 e Latitude Longitude N 70.31090311 W 148.31438346 N 70.31090211 W 148.31438217 N 70.31090126 W 148.31437991 N 70.31090032 W 148.31437619 N 70.31089920 W 148.31437253 N 70.31089878 W 148.31437084 N 70.31089795 W 148.31436699 N 70.31089778 W 148.31436220 N 70.31089901 W 148.31435686 N 70.31090144 W 148.31435028 N 70.31090583 W 148.31434172 N70.31091193 W 148.31432450 N 70.31091566 W 148.31430177 N 70.31091972 W 148.31427A. N 70.31092595 W 148.3142~ N 70.31093657 W 148.31426107 N 70.31094883 W 148.31426587 N 70.31095598 W 148.31425213 N 70.31095990 W 148.31422398 N 70.31096444 W 148.31419637 N 70.31097142 W 148.31418150 N 70.31098681 W 148.31419576 N 70.31101361 W 148.31423836 N 70.31105043 W 148.31430005 N 70.31109718 W 148.31437830 N 70.31115515 W 148.31446462 Generated 10/23/2003 4:41 PM Page 1 of 4 2513.66 19.66 336.09 92.91 2501.12 2455.72 110.61 118.09 -21.62 120.05 349.62 4.12 4.11 0.67 5966276.42 707971.45 N 70.31122572 W 148.31455863 2605.67 24.42 332.72 92.01 2586.39 2540.99 144.82 149.16 -36.62 153.59 346.21 5.35 5.17 -3.66 5966307.06 707955.59 N 70.31131061 W 148.31468017 2698.45 28.26 331.00 92.78 2669.52 2624.12 185.81 185.43 -56.07 193.72 343.18 4.22 4.14 -1.85 5966342.78 707935.15 N 70.31140970 W 148.31483774 2791.46 32.52 328.77 93.01 2749.73 2704.33 232.78 226.09 -79.72 239.73 340.58 4.74 4.58 -2.40 5966382.76 707910.39 N 70.31152076 W 148.31502936 2883.71 36.78 326.22 92.25 2825.61 2780.21 285.20 270.27 -107.94 291.03 338.23 4.88 4.62 -2.76 5966426.14 707880.95 N 70.31164146 W 148.31525807 2976.98 40.73 326.07 93.27 2898.33 2852.93 343.58 318.74 -140.46 348.32 336.22 4.24 4.24 -0.16 5966473.69 707847.10 N 70.31177389 W 148.31552159 3068.58 43.73 327.30 91.60 2966.15 2920.75 405.13 370.19 -174.26 409.16 334.79 3.40 3.28 1.34 5966524.19 707811.90 N70.31191445 W 148.31579542 3161.50 47.79 326.83 92.92 3030.96 2985.56 471.69 426.05 -210.45 475.19 333.71 4.38 4.37 -0.51 5966579.01 707774.17 N 70.31206703 W 148.31608870 3254.53 50.69 327.19 93.03 3091.69 3046.29 542.14 485.15 -248.81 545.23 332.85 3.13 3.12 0.39 5966637.03 707734.19 N 70.31222849 W 148.31639953 3346.77 51.17 327.41 92.24 3149.83 3104.43 613.75 545.41 -287.50 616.55 332.21 0.55 0.52 0.24 5966696.19 707693.85 N 70.31239312 W 148.31671303 3440.02 50.72 327.72 93.25 3208.58 3163.18 686.16 606.53 -326.34 688.75 331.72 0.55 -0.48 0.33 5966756.20 707653.34 N 70.31256008 W 148.31702776 3534.24 51.11 326.31 94.22 3267.99 3222.59 759.29 667.87 -366.15 761.65 331.27 1.23 0.41 -1.50 5966816.42 707611.84 N 70.31272765 W 148.31735041 3627.40 51.59 325.51 93.16 3326.17 3280.77 832.03 728.12 -406.93 834.12 330.80 0.85 0.52 -0.86 5966875.51 707569.41 N 70.31289225 W 148.31768088 3719.51 51.67 325.52 92.11 3383.35 3337.95 904.23 787.65 -447.82 906.05 330.38 0.09 0.09 0.01 5966933.88 707526.89 N 70.31305486 W 148.31801223 3810.93 51.97 326.05 91.42 3439.86 3394.46 976.09 847.07 -488.23 977.70 330.04 0.56 0.33 0.58 5966992.16 707484.86 N 70.31321720 W 148.3183. 3904.54 51.52 325.76 93.61 3497.82 3452.42 1049.59 907.94 -529.43 1051.03 329.75 0.54 -0.48 -0.31 5967051.87 707441.98 N 70.31338350 W 148.318673 3997.03 50.44 324.40 92.49 3556.05 3510.65 1121.41 966.86 ·570.56 1122.66 329.45 1.63 -1.17 -1.47 5967109.62 707399.24 N 70.31354445 W 148.31900692 4090.37 48.64 325.06 93.34 3616.62 3571.22 1192.38 1024.84 -611.57 1193.45 329.17 2.00 -1.93 0.71 5967166.44 707356.64 N 70.31370283 W 148.31933928 4183.36 48.94 325.18 92.99 3677.88 3632.48 1262.31 1082.23 -651.58 1263.24 328.95 0.34 0.32 0.13 5967222.69 707315.07 N 70.31385960 W 148.31966350 4276.56 50.11 324.69 93.20 3738.38 3692.98 1333.17 1140.26 -692.31 1333.97 328.74 1.32 1.26 -0.53 5967279.56 707272.75 N 70.31401812 W 148.31999361 4369.52 50.44 325.70 92.96 3797.79 3752.39 1404.64 1198.96 -733.11 1405.33 328.56 0.91 0.35 1.09 5967337.11 707230.33 N 70.31417848 W 148.32032434 4461.88 51.73 324.75 92.36 3855.81 3810.41 1476.47 1257.98 -774.10 1477.08 328.39 1.61 1.40 -1.03 5967394.98 707187.72 N 70.31433972 W 148.32065656 4554.88 52.04 325.53 93.00 3913.21 3867.81 1549.61 1318.02 -815.93 1550.14 328.24 0.74 0.33 0.84 5967453.83 707144.26 N 70.31450373 W 148.32099552 4647.25 51.46 325.78 92.37 3970.40 3925.00 1622.14 1377.92 -856.85 1622.60 328.12 0.66 -0.63 0.27 5967512.56 707101.69 N 70.31466734 W 148.32132722 4739.81 52.18 325.43 9256 4027.61 3982.21 1694.88 1437.95 -897.95 1695.30 328.02 0.83 0.78 -0.38 5967571.44 707058.94 N 70.31483134 W 148.32166036 4832.82 51.21 325.58 93.01 4085.26 4039.86 1767.85 1498.11 -939.29 1768.21 327.91 1.05 -1.04 0.16 5967630.42 707015.96 N 70.31499566 W 148.32199540 4925.93 51.53 325.34 93.11 4143.39 4097.99 1840.57 1558.02 -980.53 1840.89 327.82 0.40 0.34 -0.26 5967689.17 706973.08 N 70.31515933 W 148.32232967 5019.37 51. 73 325.52 93.44 4201.39 4155.99 1913.81 1618.34 -1022.10 1914.08 327.72 0.26 0.21 0.19 5967748.31 706929.86 N 70.31532411 W 148.32266661 5111.61 51.69 325.62 92.24 4258.55 4213.15 1986.19 1678.06 -1063.03 1986.43 327.65 0.10 -0.04 0.11 5967806.87 706887.29 N 70.31548723 W 148.32299840 5204.15 51.49 325.51 92.54 4316.04 4270.64 2058.69 1737.87 -1104.03 2058.90 327.57 0.24 -0.22 -0.12 5967865.51 706844.65 N 70.31565060 W 148.32333077 5296.82 51.26 325.29 92.67 4373.89 4328.49 2131.07 1797.46 -1145.14 2131.25 327.50 0.31 -0.25 -0.24 5967923.94 706801.90 N 70.31581339 W 148.32366402 5388.88 51.20 324.29 92.06 4431.54 4386.14 2202.80 1856.10 -1186.53 2202.94 327.41 0.85 -0.07 -1.09 5967981.41 706758.92 N 70.31597358 W 148.32399947 5482.21 51.38 324.87 93.33 4489.90 4444.50 2275.57 1915.45 -1228.73 2275.69 327.32 0.52 0.19 0.62 5968039.57 706715.08 N 70.31613570 W 148.32434162 5576.07 52.25 325.00 93.86 4547.93 4502.53 2349.31 1975.84 -1271.12 2349.40 327.25 0.93 0.93 0.14 5968098.75 706671.04 N 70.31630065 W 148.32468. 5670.32 52.08 325.03 94.25 4605.74 4560.34 2423.71 2036.82 -1313.80 2423.78 327.18 0.18 -0.18 0.03 5968158.53 706626.70 N 70.31646724 W 148.3250311 5763.00 51.72 324.90 92.68 4662.93 4617.53 2496.61 2096.54 -1355.67 2496.66 327.11 0.40 -0.39 -0.14 5968217.06 706583.19 N 70.31663036 W 148.32537059 5857.12 51.61 325.36 94.12 4721.31 4675.91 2570.41 2157.11 -1397.87 2570.44 327.06 0.40 -0.12 0.49 5968276.44 706539.32 N 70.31679582 W 148.32571276 5950.67 51.71 325.39 93.55 4779.34 4733.94 2643.76 2217.49 -1439.57 2643.79 327.01 0.11 0.11 0.03 5968335.63 706495.98 N 70.31696075 W 148.32605075 6043.81 51.53 324 26 93.14 4837.17 4791.77 2716.73 2277.17 -1481.63 2716.75 326.95 0.97 -0.19 -1.21 5968394.12 706452.28 N 70.31712377 W 148.32639173 6136.18 51.36 325.58 92.37 4894.74 4849.34 2788.93 2336.28 -1523.14 2788.94 326.90 1.13 -0.18 1.43 5968452.06 706409.15 N 70.31728523 W 148.32672829 6229.22 51.11 325.47 93.04 4952.99 4907.59 2861.46 2396.09 -1564.20 2861 .46 326.86 0.28 -0.27 -0.12 5968510.70 706366.45 N 70.31744859 W 148.32706120 6322.04 50.85 325.61 92.82 5011.43 4966.03 2933.55 2455.55 -1605.01 2933.56 326.83 0.30 -0.28 0.15 5968569.00 706324.01 N 70.31761100 W 148.32739202 6415.06 50.60 325.46 93.02 5070.32 5024.92 3005.55 2514.91 -1645.76 3005.55 326.80 0.30 ·0.27 -0.16 5968627.22 706281.64 N 70.31777317 W 148.32772240 6507.49 50.69 325.33 92.43 5128.93 5083.53 3077.00 2573.74 -1686.35 3077.00 326.77 0.15 0.10 -0.14 5968684.89 706239.44 N 70.31793385 W 148.32805149 6600.49 51.25 325.75 93.00 5187.49 5142.09 3149.22 2633.31 -1727.22 3149.22 326.74 0.70 0.60 0.45 5968743.30 706196.93 N 70.31809656 W 148.32838291 6692.93 51.79 326.21 92.44 5245.01 5199.61 3221.58 2693.29 -1767.71 3221.58 326.72 0.70 0.58 0.50 5968802.13 706154.80 N 70.31826039 W 148.32871116 6785.34 52.27 325.97 92.41 5301.87 5256.47 3294.42 2753.74 ·1808.35 3294.43 326.71 0.56 0.52 ·0.26 5968861.44 706112.50 N 70.31842553 W 148.32904069 SurveyEditor Ver 3.1 RT-SP3.03-HF1.2 Bld( d031 rt·546 ) PSI-7IPSI-07\PSI-07IPSI-07 Generated 10/23/20034:41 PM Page 2 of 4 6878.50 52.37 325.94 93.16 5358.81 5313.41 3368. 15 2814.84 -1849.63 3368. 15 326.69 0.11 0.11 -0.03 5968921.36 706069.55 N 70.31859240 W 148.32937538 6971.19 52.35 326.49 92.69 5415.42 5370.02 3441.54 2875.84 -1890.44 3441.54 326.68 0.47 -0.02 0.59 5968981.21 706027.06 N 70.31875903 W 148.32970633 7063.93 52.49 327.03 92.74 5471.98 5426.58 3515.04 2937.31 -1930.73 3515.04 326.68 0.49 0.15 0.58 5969041.54 705985.09 N 70.31892694 W 148.33003299 7156.47 52.32 326.72 92.54 5528.44 5483.04 3588.36 2998.72 -1970.80 3588.36 326.69 0.32 -0.18 -0.33 5969101.81 705943.34 N 70.31909467 W 148.33035790 7249.93 51.69 327.01 93.46 5585.97 5540.57 3662.01 3060.39 -2011.06 3662.02 326.69 0.72 -0.67 0.31 5969162.34 705901.39 N 70.31926313 W 148.33068436 7346.64 50.76 326.33 96.71 5646.53 5601.13 3737.41 3123.39 -2052.48 3737.41 326.69 1.11 -0.96 -0.70 5969224.16 705858.24 N 70.31943520 W 148.33102027 7431.76 50.09 325.95 85.12 5700.76 5655.36 3803.01 3177.87 -2089.04 3803.02 326.68 0.86 -0.79 -0.45 5969277.61 705820.19 N 70.31958401 W 148.33131669 7525.69 50.50 325.84 93.93 5760.77 5715.37 3875.27 3237.71 -2129.56 3875.27 326.67 0.45 0.44 -0.12 5969336.29 705778.03 N 70.31974745 W 148.33164527 7620.32 50.93 325.36 94.63 5820.69 5775.29 3948.50 3298.14 -2170.94 3948.50 326.65 0.60 0.45 -0.51 5969395.55 705735.00 N 70.31991251 W 148.33198084 7714.70 51.04 325.36 94.38 5880.10 5834.70 4021.81 3358.47 -2212.62 4021.82 326.62 0.12 0.12 0.00 5969454.71 705691.66 N 70.32007731 W 148.33231886 7807.05 50.83 325.28 92.35 5938.30 5892.90 4093.49 3417.44 -2253.42 4093.50 326.60 0.24 -0.23 -0.09 5969512.52 705649.25 N 70.32023836 W 148.33264971 7900.54 50.80 324.79 93.49 5997.37 5951.97 4165.92 3476.82 -2294.95 4165.94 326.57 0.41 -0.03 -0.52 5969570.72 705606.09 N 70.32040056 W 148.33298649 7992.95 50.90 325.21 92.41 6055.71 6010.31 4237.55 3535.53 -2336.05 4237.58 326.55 0.37 0.11 0.45 5969628.26 705563.38 N 70.32056090 W 148.33331983 8085.72 50.68 325.74 92.77 6114.36 6068.96 4309.4 1 3594.75 -2376.79 4309.45 326.53 0.50 -0.24 0.57 5969686.33 705521.02 N 70.32072265 W 148.33365023 8178.23 50.57 326.01 92.51 6173.05 6127.65 4380.92 3653.94 -2416.91 4380.95 326.52 0.26 -0.12 0.29 5969744.39 705479.28 N 70.32088434 W 148.3339_ 8270.86 50.41 326.75 92.63 6231.98 6186.58 4452.38 3713.45 -2456.48 4452.42 326.52 0.64 -0.17 0.80 5969802.78 705438.08 N 70.32104688 W 148.3342 8364.38 50.58 326.52 93.52 6291.47 6246.07 4524.54 3773.72 -2496.16 4524.57 326.52 0.26 0.18 -0.25 5969861.92 705396.74 N 70.32121148 W 148.33461836 8456.62 50.81 327.61 92.24 6349.90 6304.50 4595.91 3833.62 -2534.96 4595.94 326.53 0.95 0.25 1.18 5969920.72 705356.30 N 70.32137510 W 148.33493307 8549.01 50.68 327.78 92.39 6408.36 6362.96 4667.44 3894.09 -2573.20 4667.47 326.54 0.20 -0.14 0.18 5969980.10 705316.41 N 70.32154025 W 148.33524318 8642.37 50.48 328.30 93.36 6467.65 6422.25 4739.54 3955.28 -2611.37 4739.57 326.57 0.48 -0.21 0.56 5970040.21 705276.55 N 70.32170738 W 148.33555283 8736.89 50.45 327.94 94.52 6527.81 6482.41 4812.42 4017.18 -2649.87 4812.44 326.59 0.30 -0.03 -0.38 5970101.01 705236.36 N 70.32187645 W 148.33586511 8828.96 50.42 327.43 92.07 6586.46 6541.06 4883.39 4077.16 -2687.82 4883.40 326.61 0.43 -0.03 -0.55 5970159.92 705196.77 N 70.32204029 W 148.33617287 8920.06 50.50 327.21 91.10 6644.46 6599.06 4953.64 4136.29 -2725.75 4953.65 326.62 0.21 0.09 -0.24 5970217.98 705157.21 N 70.32220179 W 148.33648056 9014.13 50.57 327.10 94.07 6704.25 6658.85 5026.26 4197.31 -2765.14 5026.27 326.62 0.12 0.07 -0.12 5970277.87 705116.15 N 70.32236844 W 148.33680005 9105.65 50.74 327.91 91.52 6762.27 6716.87 5097.03 4257.00 -2803.16 5097.04 326.64 0.71 0.19 0.89 5970336.49 705076.49 N 70.32253148 W 148.33710847 9197.69 50.98 328.07 92.04 6820.37 6774.97 5168.40 4317.54 -2841.00 5168.40 326.65 0.29 0.26 0.17 5970395.95 705036.99 N 70.32269682 W 148.33741542 9292.55 50.50 327.83 94.86 6880.40 6835.00 5241.83 4379.79 -2879.98 5241 .83 326.67 0.54 -0.51 -0.25 5970457.10 704996.31 N 70.32286685 W 148.33773159 9384.66 49.63 327.64 92.11 6939.53 6894.13 5312.45 4439.51 -2917.68 5312.45 326.69 0.96 -0.94 -0.21 5970515.75 704956:97 N 70.32302996 W 148.33803743 9476.65 48.41 327.54 91.99 6999.85 6954.45 5381.88 4498.14 -2954.90 5381.89 326.70 1.33 -1.33 -0.11 5970573.32 704918.14 N 70.32319009 W 148.33833937 9569.71 46.00 327.53 93.06 7063.07 701767 5450.16 4555.75 -2991.55 5450.16 326.71 2.59 -2.59 -0.01 5970629.89 704879.91 N 70.32334744 W 148.33863670 9663.74 43.41 327.47 94.03 7129.89 7084.49 5516.29 4611.53 -3027.09 5516.29 326.72 2.75 -2.75 -0.06 5970684.66 704842.85 N 70.32349980 W 148.33892499 9756.23 41.42 327.22 92.49 7198.17 7152.77 5578.67 4664.06 -3060.74 5578.67 326.73 2.16 -2.15 -0.27 5970736.23 704807.75 N 70.32364324 W 148.33919803 9848.67 39.69 327.46 92.44 7268.41 7223.01 5638. 77 4714.65 -3093.18 5638.77 326.73 1.88 -1.87 0.26 5970785.91 704773.93 N 70.32378143 W 148.3394~. 9941.38 37.69 327.38 92.71 7340.77 7295.37 5696.71 4763.48 -3124.38 5696.71 326.74 2.16 -2.16 -0.09 5970833.85 704741.38 N 70.32391480 W 148.33971 10034.52 35.39 327.06 93.14 7415.59 7370.19 5752.16 4810.11 -3154.40 5752.16 326.74 2.48 -2.47 -0.34 5970879.62 704710.09 N 70.32404214 W 148.33995 10127.43 33.71 326.64 92.91 7492.11 7446.71 5804.85 4854.22 -3183.21 5804.85 326.74 1.83 -1.81 -0.45 5970922.92 704680.07 N 70.32416262 W 148.34019156 10220.45 31.38 325.80 93.02 7570.52 7525.12 5854.89 4895.82 -3211.02 5854.89 326.74 2.55 -2.50 -0.90 5970963.73 704651.12 N 70.32427623 W 148.34041719 10313.44 28.94 325.30 9299 7650.92 7605.52 5901.59 4934.34 -3237.44 5901.59 326.73 2.64 -2.62 -0.54 5971001.51 704623.64 N 70.32438145 W 148.34063153 10406.53 26.46 325.68 93.09 7733.33 7687.93 5944.85 4970.00 -3261.96 5944.85 326.72 2.67 -2.66 0.41 5971036.47 704598.15 N 70.32447882 W 148.34083044 10498.16 23.89 324.98 91.63 7816.25 7770.85 5983.81 5002.06 -3284.12 5983.81 326.71 2.82 -2.80 -0.76 5971067.90 704575.11 N 70.32456638 W 148.34101023 10592.61 22.79 323.88 94.45 7902.97 7857.57 6021 .20 5032.50 -3305.88 6021.20 326.70 1.25 -1.16 -1.16 5971097.72 704552.51 N 70.32464951 W 148.34118676 10684.51 21.92 324.47 91.90 7987.96 7942.56 6056.12 5060.83 -3326.34 6056.12 326.68 0.98 -0.95 0.64 5971125.48 704531.28 N 70.32472691 W 148.34135275 10775.80 20.20 327.60 91.29 8073.16 8027.76 6088. 91 5088.01 -3344.69 6088.91 326.68 2.25 -1.88 3.43 5971152.14 704512.18 N 70.32480113 W 148.34150162 10869.14 18.76 329.17 93.34 8151.15 8115.75 6120.02 5114.51 -3361.02 6120.02 326.69 1.64 -1.54 1.68 5971178.17 704495.13 N 70.32487350 W 148.34163410 10908.04 18.05 329.12 38.90 8198.06 8152.66 6132.29 5125.05 -3367.32 6132.29 326.69 1.83 -1.83 -0.13 5971188.54 704488.54 N 70.32490229 W 148.34168521 11033.63 17.75 329.66 125.59 8317.57 8272.17 6170.85 5158.27 -3386.97 6170.85 326.71 0.27 -0.24 0.43 5971221.20 704467.97 N 70.32499303 W 148.34184470 11125.54 17.49 328.85 91.91 8405.17 8359.77 6198.64 5182.18 -3401.20 6198.64 326.72 0.39 -0.28 -0.88 5971244.71 704453.10 N 70.32505833 W 148.34196010 SurveyEditor Ver 3.1 RT-SP3.03-HF1.2 Bld( d031 rt-546) PSI-7\PSI-07\PSI-07\PSI-07 Generated 10/23/2003 4:41 PM Page 3 of 4 11218.74 11311.01 11383.00 Leqal Description: 16.83 16.64 16.64 328.85 328.46 328.46 93.20 92.27 71.99 8494.22 8582.58 8651.56 Surface: 3856 FSL 4408 FEL S15 T11N R15E UM BHL: 3821 FSL 2557 FEL S9 T11N R15E UM 8448.82 8537.18 8606.16 SUlVeyEditor Ver 3.1 RT-SP3.03-HF1.2 Bld( do31rt-546) 6226.12 6252.67 6273.28 Northinq (YI fftUS] 5966158.98 5971307.40 5205.72 5228.41 5245.98 -3415.42 -3429.24 -3440.02 6226.12 6252.67 6273.28 Eastinq (XI fftUS] 707996.33 704412.52 326.73 326.74 326.75 PSI-7\PSI-07\PSI-07\PSI-07 0.71 0.24 0.00 -0.71 -0.21 0.00 0.00 -0.42 0.00 5971267.83 5971290.13 5971307.40 704438.23 704423.78 704412.52 N 70.32512261 W 148.34207551 N 70.32518458 W 148.34218765 N 70.32523256 W 148.34227515 e e Generated 10/23/2003 4:41 PM Page 4 of 4 WEE = WELLf-EA 0 = <'M~_ HH..._______A~, AClUA TOR = KB. ELBI = __A' __A_.A'~~_^, BF. ELBI = Kop ;MM ~iv'axÄrìgle ;~ Datum fvÐ = Datum NO"=· e FMC 45.4' 22.83' 150Õ; 52 @ 7064' "11383' 8600' SS 113-3I8"CSG, 68",L-80,10=10=12.415" H 5723' 17-518" TBG, 29.7#, L-80, .0459 bpf, 10 = 6.875" H 10696' Minimum ID = 5.770" @ 10798' 7" HES RN NO-GO NIPPLE IT' TBG, 26#, L-80, .0383 bpf, 10 = 6.276" H 10728' IT' 1BG, 26#, .0383 bpf, 10 = 6.276" H 10809' I ÆRFOAA 110N SLMMARY REF LOG: RST/TEMPLOG ANGLE AT TOP PERF: 17 @ 11228' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11228 - 11256 0 08/16/04 PSI-07 .L ~ ~ z ~ 9-5/8"CSG,47#,L-80,10=8.681" H 10963' ~ ~ 11299' IT' LNR, 26#, L-80, .0383 bpf, 10 = 6.276" H 11383' DATE 10/20/03 01/20/04 08/16/04 REV BY COfllMENTS AM'TLP ORIGINAL COMPLETION CA O/TLH CORREGrIONS LOK/TLP ADD PERF DATE ~ RBI BY J { I --1 1 1 1 ~ J 1 ~ I I \ 1 1 ~ CO fIlM B\lTS -e SAFETY NOTES: THREADS ON TBG HGR WERE DAMAGED - WILL REQUIRE A SPEAR TO REMOVE TBG IF RWO IS EVER REQUIRED. 1000' H13-3/8" TAM FORT COLLAR I 2231' H7-5I8" X T' XO. 10= 6.276" I 2232' H 7" CArvCO DB NIP, 10 = 6.00" 2234' H7" X 7-5/8" XO, 10 = 6.276" I 10698' H 7 -5/8" X T' XO, 10 = 6.276" I 1070T H7" I-ES R NIP, 10 = 5.963" I 10732' H7"BAKERPBR(20'),10=7.50" I 10768' H9~5/8" X T' BAKER SABL-3 PERI'v1 A<R. 10 = 6.00" 10785' H7" I-ES R NIP, 10 = 5.963" I 10796' H 7" I-ES RN NO-GO NIP, 10 = 5.770" I 1 0809' H 7" WLB3, 10 = 6.276" I H ELfvÐ TT NOTLOGGEO I 10859' H 7" X 9-5/8" ZXP A<R. 10 = 6.300" I PRLDHOE BA Y UNIT WELL: PSI-07 PERI'v1IT No: 2031480 AA No: 50-029-23177-00 SEe 15, T11 N, R15E. 1423' FN... & 872' FWL BP Exploration (Alaska) . . Ð03'J LI~ MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No PSI-07 Date Dispatched: 15-0ct-03 I nstallation/Rig Doyon 141 Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 r \.; R . dB ~r-;\' ~ { '. ecelve y: \'(". '0U-j'V\" \~,,~ C"'t '-i.........e-/'v'"""\. Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ~-'.' . .- '\..: .=:~ 'v\ ' ......... ,....., ~\::,\,\.~ . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I PSI 10/17/03 Ferguson ~~~ \2Jl.b\Ó~ Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Packer Depth Pretest Initial 15 Min. 30 Min. well/PSI-07 J Type Inj. S TVD I 8,066' TUbing 01 3,3001 3,3001 3,3°°1 P.T.D. 2031480 .. Type test P Test psi 2,017 Casing 0 4,000 3,995 3,990 Notes: Pre-injection MITIA. An AOGCC witnessed MITIA will be performed once the well is POI. Interval P/F o p weill I Type Inj. I I TVD I I TUb~ngl II nterval P.T.D. Type test Test psi Casing P/F Notes: weill Type Inj.1 I TVD I I TUb~ngl II nterval P.T.D. Type test Test psi Casing P/F Notes: weill Type Inj. I TVD I TUb~ngl Intervall P.T.D. Type test Test psi Casing P/F Notes: weill Type Inj. I TVD I I TUb~ng Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: Pressure readings were taken from a chari recorder. TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU PSI-0710-17-03.xls . . ITIì 0¿) í l FRANK H. MURKOWSKI, GOVERNOR i f / i AI/ASliAOILAND GAS j CONSERVATION COMMISSION ,f Bill Isaacson i Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe bay Unit PS1-07 BP Exploration (Alaska), Inc. Permit No: 203-148 Surface Location: 3857' NSL, 4408' WEL, Sec. 15, TllN, R15E, UM Bottomhole Location: 3856' NSL, 2579' WEL, Sec 09, T11N, R15E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ ~VL. Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this..lj day of August, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section I~'+ g/l1/l,.OO3 .. STATE OF ALASKA . ALASKA_AND GAS CONSERVATION CO .. ISSI'oN PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test II Service 5. Bond: 1m Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 11200' rvD 8626' 7. Property Designation: ADL 034631 II Drill 0 Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3857' NSL, 4408' WEL, SEC. 15, T11N, R15E, UM Top of Productive Horizon: 3747' NSL, 2507' WEL, SEC. 09, T11N, R15E, UM Total Depth: 3856' NSL, 2579' WEL, SEC. 09, T11 N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-707996 y-5966158 Zone-ASP4 16. Deviated Wells: Kickoff Depth .18;Oasingi?rogra 11 Size Casing 20" 13-3/8" 9-518" 694 ft Maximum Hole Angle Hole 42" 16" Weight Grade 91.51# H-40 68# L -80 40# 147# S-95/ L-80 26# L-80 Coupling Welded BTC BTC·-M BTC--M 12-1/4" 8-1/2" 7" 8. Land Use Permit: NIA - Fee Simple Pad 9. Acres in Property: 2560 o Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU PSI-07 ,/' 12. Field / Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 13. Approximate Spud Date: 09/23/03 14. Distance to Nearest Property: 20,091 ' 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool (Height above GL): 45.4 feet PSI-08 is 24' away at 594' MD 17. Anticipated pressure (see 20 AAC 25.035) Max. Downhole Pressure: 3837 psig. Max. Surface Pressure: 2979 psig ~ettil'lgp$pth .... f C~ment Top >.i i...·.··...<·>. Bottom oks) MD rvD MD rvD (including stage data) Surface Surface 108' 108' 260 sx Arctic Set (Approx.) Surface Surface 5629' 4595' 1291 sx AS III Lite, 603 sx Class 'G' - Surface Surface 10804' 8251' 536 sx Class 'G' ./ 10704' 8155' 11200' 8626' 125 sx Class 'G' " 49° Length 80' 5601' 10776' 496' 19. ÞRe:SENT WELL CONDITION SUMMA~Y(Tpb~.col11pleted forRèdriIIANPRØ+~nt¡"yQperations) Total Depth MD (ft): Total Depth rvD (ft): Plugs (measured): Effective Depth MD (ft): IEffective Depth TVD Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments 1m Filing Fee 0 BOP Sketch 1m Property Plat 0 Diverter Sketch perfOration Depth rvD (ft): 1m Drilling Program 0 Time vs Depth Plot o Seabed Report 1m Drilling Fluid Program 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Billlsaacson Title Senior Drilling Engineer Junk (measured): o Shallow Hazard Analysis 1m 20 AAC 25.050 Requirements Date: Contact Rob Tirpack, 564-4166 Phone 564-5521 Permit To Drill API Number: Number:.203-/7'f? 50- (";?.9~ ..:/ -::; / /';7 Conditions of Approval: Samples Required DYes ¡g No Hydrogen Sulfide Measures ~ Yes DNa Other:1€. '>t- þcìÇ' E to 4000 r ç c' . r~ 1-0 A-tt-c 1- ':).41 z. C 6\, f'~w ~+t.... ~~ Approved By: Form 10-401 Revised 3/2003 Permit Approval Date: 8/2 J l~) Mud Log Required Directional Survey Required See cover letter for other requirements DYes ~ No gj Yes D No ~b w ~rn...~.f I ç. wtV.' (¡ 't..~ . BY ORDER OF '( , /. o Ki~ì't\1Ä CE COMMISSION Dale S!~~ ~Jcale e I Well Name: I e PSI-O? Drill and Complete Summary I Type of Well (producer or injector): 1 Injector - Water Surface Location: (As Built) Target Location: Bottom Hole Location: x = 707,996 / Y = 5,966,159 3856' FSL,4408'FEL, Sec. 15, T11N, R15E X = 704,465 / Y = 5,971,234 3747'FSL,2507' FEL, Sec. 09, T11N, R15E X = 704,390 / Y = 5,971,341 3856' FSL,2579'FEL,Sec.09,T11N, R15E J< /' I AFE Number: I PBD4P1905 I Estimated Start Date: I 09/23/03 I Rig: 1 Doyon 141 I Operating days to complete: 123.7 "... I MD: 111,200' 1 I TVD: 18,626' I I GL: 117.4' 1 I KB: 128.0' 1 I KBE: 1 45.4' I I Well Design (conventional, slim hole, etc.): I Big Bore I Objective: I High rate water injection into Ivishak Gas Cap, Zones 3 through 1 / Formation Markers Formation Tops MD TVD TVDss Comments Base PF 1910' 1895' 1850' 8.6 ppg SV4 3943' 3495' 3450' 8.6 ppg SV3 4571' 3905' 3860' 8.6 ppg SV2 4878' 4105' 4060' 8.6 ppg SV1 5476' 4495' 4450' 8.6 ppg UG4 6247' 4998' 4953' 8.6 ppg UG3 6628' 5247' 5202' 8.6 ppg UG1 7602' 5882' 5837' 8.6 ppg West Sak 2 8428' 6421' 6376' 8.6 ppg West Sak 1 8715' 6608' 6563' 8.6 ppg CM3 9030' 6814' 6769' 8.6 ppg CM2 10009' 7534' 7489' 10.0 ppg HC Bearing CM1 10156' 7660' 7615' 10.0 ppg HC Bearing THRZ 10601' 8061' 8016' 8.6 ppg BHRZlLCUfTZ3 10804' 8251' 8206' 7.3 ppg; HC Bearing TZ2 10857' 8301' 8256' 7.3 ppg; HC Bearing TZ2B 10914' 8355' 8310' 7.3 ppg; HC Bearing TZ2A 11000' 8436' 8391' 7.3 ppg; HC Bearing TZ1 B 11038' 8472' 8427' 7.3 ppg; HC Bearing BSAD 11149' 8577' 8532' 7.3 ppg; HC Bearing TD (Kavik) 11200' 8626' 8581' 7.3 ppg TLSB N/A 8688' 8643' Not Penetrated Surface TD Criteria: Based on -100' TVD below SV1 Top Intermediate TD Criteria: Casing to be set above the BHRZrTZ3 transition TD Criteria: Based upon 50' TVD above TLSB \ 0.) PSI-07 Permit to Drill Page 1 It CasinglTubing Program Hole Size CsglTbg O.D. WtlFt Grade 42" Insulated 20" 91.51# H-40 (34" 00) 13-3/8" 9-5/8" 9-5/8" 7" e Conn Welded Length 80' Top MDITVD GL Btm MDITVD -108' / 108' BTC BTC-M BTC-M BTC-M STL GL GL 10,304'/7,787' 10,704'/8,155' GL 5,629'/4,595' 10,304'/7,787' 10,804'/8,251 ' 11,200'/8,626' 10,674'/8,130' *' Pi pe Data ./ /" O.D. Weight Grade I.D. Drift I.D Burst Collapse Tensile Conductor 20" 91.51# H-40 19.124 18.937 1533 515 1,077,000 Surface 13-3/8" 68# L-80 12.415 12.259 5020 2260 1,556,000 Intermediate 9-5/8" 40# S-95 8.835 8.679 7900 4230 1,260,000 Intermediate 9-5/8" 47# L-80 8.681 8.525 6870 4750 1,086,000 Production 7" 26# L-80 6.276 6.151 7240 5410 604,000 Tubing 7-5/8" 29.7# L-80 6.875 6.750 6890 4790 683,000 Directional (Anadril P9) KOP: I 694' MO Maximum Hole Angle: Close Approach Well: Closest Wells: Survey Program: -490 In intermediate section from 3,287' to 9,186' L3-01 Passes BP Anti-Collision policy when risk baseç!..at-t/2Ut). PSI-08: 24' at 594' MD. PSI-01: 197' at 1,752' M!Y'L3.-01:.,.a59' at 11,187' MO MWO Surveys with IFR and MS from surface to"fu~ ¡{q. 01~ Mud Program 16" Surface Hole I Freshwater Spud Mud I From Surface to -100' TVO below top SV1 Interval Density Viscosity YP (ppg) (seconds) (lb/100ft2) 8.6 - 8.8 200-300 50-70 9.5 200-250 30-45 9.5 75-150 20-35 Initial Base Perm Interval TO tauo API FL pH (lb/100ft2) (mls/30min) >8 35-55 8.5- 9.5 >6 30-40 8.5-9.5 >6 16-30 8.5-9.5 12-1/4" Intermediate Hole I LSND From Surface Casing Shoe to BHRZ Interval Density Plastic Viscosity (ppg) (cp) Initial to CM2 9.D-9.5 10-15 CM2 to BHRZ 10.5 / 10-15 YP (lb/100ft2) 25-30 20-30 tauo (lb/100ft2) 4-7 4-7 10' Gel API HTHP FL pH (mis/30m in) 10 6-10 8.5-9.5 10 4-6/<12.0 8.5-9.5 LGS % vol <5 <5 8-1/2" Production Hole I Flo-Pro NT From Intermediate Casing Shoe to TO Interval Density Plastic Viscosity (ppg) (cp) 8.8 10-15 Ivishak YP (lb/100ft2) 17-25 tauo 10' Gel API HTHP FL pH LGS (lb/100ft2) (mls/30min) % vol 3-5 10 4-6<12.0 8.5-9.5 <5 Page 2 PSI-07 Permit to Drill e e Well Evaluation Program 16" Surface: Drilling: MWD / GR - Recorded over entire interval. Open Hole: None Cased Hole: None Coring: None Sampling: None 12-1/4" Intermediate: Drilling: MWD / GR / PWD- Realtime over entire interval Open Hole: None Cased Hole: USIT Coring: None Sampling: Cuttings Samples and Gas Detection - from 500' above BHRZ to section TD 8-1/2" Production: Drilling: MWD / GR / Res / Neu-Dens Realtime over entire interval Open Hole: None Cased Hole: None Coring: None Sampling: Cuttings Samples and Gas Detection - Entire Interval Cement Program The following surface casing cement calculations are based upon a single stage job. As contingency, a port collar will be run in the casing at -1000' MD to allow circulating cement to surface if the single stage is unsuccessful. Casing Size 113-3/8" Surface 1 Basis: Lead: Open hole volume + 400% excess in permafrost; 50% excess below permafrost. Lead TOC: To Surface. Tail: Open hole volume + 50% excess + 82' shoe track volume. Tail TOC: 1000' MD above 13-318" shoe (-4629' MD) I Fluid Sequence & Volumes: Pre None Flush Spacer Lead 75 bbls MudPUSH Viscj)8ff¡ied Spacer weighted to 10.0 ppg 1021 bbl I 5732 fti11 2~}~ks of Dowell ArticSET III-Lite at 10.7 ppg and 4.44 cf/sk, BHS ' 9° I BHCT 80°, TT = 6.0 hrs 125 bbl I 700 fe ~ sks of Dowell Premium 'G' at 15.8 ppg and 1.16 cf/sk, BHST ° I BHCT 80°, TT = 4 hrs Tail I Casing Size I 9-5/8" Intermediate Basis: Lead: None Tail: Open hole volume + 50% excess + 82' shoe track volume Tail TOC: 500' above CM2 (-9,508' MD) I Fluid Sequence & Volumes: Pre 10 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 50 bbls MudPUSH Viscosified Spacer weighted to 11.5 ppg None ~ 115 bbl I 643fe ~ 3 s of Dowell Premium 'G' at 15.8 ppg and 1.20 cf/sk, BHS 70° I BHCT 131°, TT = Batch Mix + 4.0 hrs PSI-07 Permit to Drill Page 3 e e I Liner Size I 7" Production Basis: Lead: None Tail: Open hole vqlume + 50% Excess + 82' shoe track + 100' liner lap + 200' of 9-5/8" x 5" DP annulus volume. / Tail TOG: -1~J/MD - LinertoJ. I Fluid Sequence & Volomés: Pre 30 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 40 bbls MudPUSH Viscosified Spacer weighted to 11.0 ppg None 26 bbl 1145 fe Þ12~ks of Dowell Premium Latex 'G' at 15.8 ppg and 1.16 cf/sk, ~T 181 ° I BHGT 137°, TT = Batch Mix + 3.5 hrs Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCG. Surface Interval- BOPE Maximum anticipated BHP Maximum suñace pressure Kick tolerance Planned BOP test pressure 13-3/8" Casing Test pressure Intermediate Interval- BOPE Maximum anticipated BHP Maximum suñace pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test pressure Integrity Test Production Interval- BOPE Maximum anticipated BHP Maximum suñace pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing/7" Liner Test Integrity Test Planned completion fluids PSI-07 Permit to Drill 21-1/4", 2M Diverter (Hydril- MSP) 2035 psi (8.6 ppg @ 4550' TVDss) 1580 psi (.10 psi/ft gas gradient to surface) N/A Function test 3500 psi surface pressure 13-3/8", 5M, 3 Gates with Annular (Hydril- GK) 3670 psi (8.6 ppg @ 8206' TVDss) 2849 psi (.10 psi/ft gas gradient to surface) 133 bbls with a 12.0 ppg FIT Rams test to 4,000 psi/250 psi. .,/ Annular test to 2,500 psi/250 psi 3500 psi surface pressure 12.0 ppg FIT 13-3/8", 5M, 3 Gates with Annular (Hydril- GK) 3837 psi (8.6 ppg @ 8581' TVDss) 2979 psi (.10 psi/ft gas gradient to surface) Infinite with a 10.0 ppg FIT , Rams test to 4,000 psi/250 psi. /' Annular test to 2,500 psi/250 psi 4000 psi surface pressure 10.0 ppg FIT 8.4 ppg Seawater I 6.8 ppg Diesel Page 4 e e Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Mise · East Dock is a 'Fee Simple Pad'. A Land use permit is not required. · The BHL of PSI-O? is 20,091' from the unit boundry line at the closest point. · The closest well to PSI-O? is PSI-08, which is 24' away at 594' MD. PSI-O? Permit to Drill Page 5 e e Drill and Complete Procedure Summary Pre-Riq Work: 1. Install 20" insulated conductor. 2. Weld an FMC landing ring for the FMC Big Bore wellhead on the 20" conductor. Install two 4" side outlet valves on the conductor pipe for surface cementing operations. Riq Operations: 1. MIRU Doyon 141. / / 2. Nipple up and function test Ivert~r/sýstem. PU 5" DP to drill surface hole and stand back in derrick. 3. MU 16" drilling assembly w ~.. D/GR and directionally drill surface hole to approximately 5,629' MD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 13-3/8", 68# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter system and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 12-1/4" drilling assembly with MWD/GR/PWD and RIH to float collar. Test the 13-3/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.0 ppg LSND drilling fluid. Drill new formation to 20' below 13-3/8" shoe and perform Formation Integrity Test. 8. Drill ahead as per directional plan. Increase mud weight to 10.5 ppg prior to entering the CM2. Short trip as required. 9. TD the 12-1/4" interval in the Base of the HRZ. Control drill the BHRZ to aid in picking TD. 10. Run and cement the 9-5/8", 40# and 47# intermediate casing to 500' above the CM2. Displace the 9-5/8" casing with 10.5 ppg LSND drilling mud during cementing operations and freeze protect the 13-3/8" X 9-5/8" annulus as required. 11. MU 8-1/2" drilling assembly with MWD/GR/Res/Dens/Neu and RIH to float collar. Test the 9-5/8" casing to 4000 psi for 30 minutes. 12. Drill out shoe joints and 20' of new formation. Perform Formation Integrity Test to 10.0 ppg EMW. Displace hole over to 9.0 ppg Flo-Pro NT fluid. 13. Drill ahead as per directional plan to proposed TD at 11,200' MD. The actual TD of the well will extend +/-60' TVD below the BSAD, but no deeper than 50' TVD above the TLSB. Short trip as required and condition hole for running the 7" liner. 14. RU E-line. Run USIT log to determine bond quality and TOC. 15. Run and cement the 7", 26# liner. The liner will extend up into the 9-5/8" casing -100' MD and will be fully cemented to the liner top. Displace cement with mud. POOH. 16. RIH with 9-5/8" and 7" casing scrapers. Tag PBTD, circ hole clean. Displace wellbore over to seawater. 17. Test wellbore to 4000 psi for 30 minutes. POH laying down drill pipe. 18. Run 7-5/8", Flush-joint, injection string with packer and tailpipe. 19. Set packer with tubing tail at least 30' above liner hanger top. 20. Sheer out of PBR. PU and space out. Make up tubing hanger. 21. Circulate Freeze protection. Allow diesel to U-Tube in annulus. 22. Land Tubing hanger/sting back into PBR. 23. Pressure test tubing and annulus to 4000 psi for 30 mins. 24. Set TWC. Test to 1000 psi. 25. ND BOPE. NU tree and test to 5000 psi. 26. Set BPV, Secure well. RDMO. Post-Riq Work: 1. Clean-up location as required. 2. Perforate and stimulate Ivishak intervals as required. 3. POI. PSI-07 Permit to Drill Page 6 e e PSI-07 Drilling Program Job 1: MIRU Hazards and Contingencies Þ- The rig move will involve no surface close approach hazards with adjacent wells. The PSI-O? well will be drilled from an existing pad with six (6) other wells on the location: PSI-06, PSI-09, PSI-01, PSI-10, PSI- OB, and East Bay State #1, an exploration well drilled in 11/74. EBS#1 was DST'd and then suspended with a CIBP @ 9300' MD and 100sx of cement. Þ- Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~ H2S is not expected to be encountered during the planned drilling operations. Offset wells are not productive from the Ivishak and therefore are not relevant. Nevertheless, Standard Operating Procedures for H2S precautions should be followed at all times. Reference RPs .:. "Drilling/Workover Close Proximity Surface and Subsurface Wells Procedure" SOP .:. "Hydrogen Sulfide" SOP -M~-.r ~-=~¥- Job 2: Drill Surface Hole Hazards and Contingencies Þ- No fault crossing are expected in the surface interval. Þ- The nearest well is PSI-OB, which is 24' center to center at -594'MD. Þ- Gas hydrates have not been observed at the other wells on the pad: PSI-06, PSI-09, PSI-01, PSI-10, PSI- OB, and East Bay State #1. Gas hydrates are not expected at PSI-O? ~ Two offset wells on the West Beach pad have experienced deeper gravel beds below the Permafrost. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) ~ Abnormally pressured shallow gas has NOT been observed at other wells on the pad: PSI-06, PSI-09, PSI-01, PSI-10, PSI-OB, and East Bay State #1. Abnormally pressured shallow gas is not expected at PSI-05. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" Job 3: Install 13-3/8" Surface CasinQ Hazards and Contingencies Þ- It is critical that cement is circulated to surface for well integrity. 400% excess cement through the permafrost zone (and 50% excess below the permafrost) is planned. As contingency, a port collar will be run in the casing at -1000' MD to allow circulating cement to surface if the single stage is unsuccessful. Þ- Hole cleaning will be difficult in the 16" hole with 5" DP. Maintain adequate viscosity and high flow rates. Short trip as required. PSI-O? Permit to Drill Page? e e > Cementing practices on the surface casing should meet the below criteria. 1. Pipe reciprocation during cement displacement 2. Cement - Top of lead to surface 3. Cement - Top of tail >1000' MD above shoe using 50% excess. 4. Casing Shoe Set approximately -100'TVD below SV-1 sand. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar" Job 4: Drilllntermediate/Production Hole Hazards and Contingencies > Fault crossings are not expected along the PSI-07 wellpath in the intermediate hole. > No close approach issues. The nearest well is PSI-08, which has a center to center distance of -24' at 594' MD. > Lost circulation is not expected in the intermediate hole section. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures if LC is encountered. > Drill Site 4 is located approximately 3.5 miles to the SE. Cretaceous injection has the potential for raising the pore pressure to 9.5 ppg EMW in the Ugnu. No increase in pore pressure was observed at PSI-06, PSI-09, or PSI-01, PSI-08, and is not expected at PSI-OS. Check for flow after cutting the Ugnu. > Gas cut mud was experienced on three of the five PSI wells drilled in 2002. All gas cut mud happened while cutting the CM2. Maximum expected pore pressure is 10.0 ppg. Raise MW to 10.5 ppg prior to cutting the CM2. > The directional plan has been built to minimize directional work and tangent angle in the HRZ. With the current directional plan, a minimum MW of 10.0 ppg is required to aid in HRZ hole stability. > Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and West Sak intervals. Minimize the time the pipe is left stationary. > For adequate hole cleaning flow rates should be maintained in the 850 gpm range, particularly while drilling with higher RaP's (200'/hr). > The kick tolerance for the 12-1/4" open hole section would be 133 bbls assuming a kick while at the section TO (-10,461' MD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 13-3/8" shoe, gauge hole, and 10.0 ppg mud in the hole. > Picking the 9-5/8" casing point is critical. Every attempt should be made to hit the BHRZ. If too much HRZ is left open while drilling the Ivishak, hole problems can be encountered due to the HRZ sloughing. If too much of Zone 3 is drilled, LC could be encountered due to the low pore pressure in Zone 3 (7.3 ppg). Reference RPs and SOPs .:. "Leak-off and Formation Integrity Tests" SOP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP PSI-07 Permit to Drill Page 8 e e Job 6: Install 9-5/8" Intermediate/Production Casinq Hazards and Contingencies þ> Differential sticking is a concern across the Ugnu and West Sak sand intervals. Communicate individual responsibilities to all members of rig team and review connection / tripping practices to minimize the time the pipe is left stationary. þ> Verify the floats are holding prior to continuing operations. If floats are not holding, hold pressure and wait on cement. ~ Run USIT log to determine cement bond quality and TOC. State must approve cement integrity to allow injection. Reference RPs .:. "Freeze Protecting an Outer Annulus" RP .:. "Intermediate Casing Cementing Guidelines" RP ,<~~~ ~:>-- Job 7: Drill 8-1/2" Production Hole Hazards and Contingencies þ> Fault crossings are not expected along the PSI-07 wellpath in the production hole. þ> Lost circulation is considered to be a moderate risk because of the low pore pressure in the Ivishak. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. þ> KICK TOLERANCE: The kick tolerance for the 8-1/2" open hole section would be infinite assuming a kick from the Ivishak. This is a worst case scenario based on a 8.6 ppg pore pressure gradient, a fracture gradient of 10.0 ppg at the 9-5/8" shoe, and 9.0 ppg mud in the hole. þ> Extra vigilance is required to avoid swabbing. The Ivishak will be highly permeable and gas bearing. þ> PSI-07 passes BP's anti-collision against L3-01 when minor risk based at 1/200. The closest center to center distance is 258' at 11,188' MD. Reference RPs .:. "Standard Operating Procedure for Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Job 8: Loq 8-1/2" Hole Hazards and Contingencies þ> Differential sticking is a concern in the Ivishak due to the low pore pressure. Keep tools moving at all times and monitor line tension. -~:_~_-_r-".Y_~____________,-______;;:,-,-____,-,-»<J»!<,~ Job 9: Install 7" Production Liner Hazards and Contingencies þ> Differential sticking could be a problem. Minimize the time the pipe is left stationary while running the liner. þ> Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. Reference RPs .:. "Production Interval Cementing" RP .:. "Running and Cementing a Liner Conventionally" RP _'~~A^__ PSI-07 Permit to Drill Page 9 e e Job 12: Run Completion Hazards and Contingencies };.> Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. };.> The injection tubing will be large diameter with flush joint connections. This job will be non-routine. Ensure all personnel are briefed of the potential hazards. Review all aspects of the operation with all rig team members prior to starting the job. };.> Ensure personnel are clear of rig floor during packer setting and when shearing out of the PBR. There will be the potential for a sudden release of stored energy with the string to jump at surface. ).- Freeze protection operations will also be non-routine without a RP Shear valve in the injection string. Freeze protection will be done through the BOP stack and choke manifold. Take extra precaution to avoid spills. Ensure all lines are blown down to vac truck. Reference RPs .:. "Completion Design and Running" RP .:. "Tubing connections" RP .:. "Freeze Protecting Inner Annulus" RP Job 13: ND/NUlRelease Riq Hazards and Contingencies };.> The rig move will involve no surface close approach hazards with adjacent wells. The PSI-05 well will be drilled from an existing pad with six (6) other wells on the location: PSI-06, PSI-09, PSI-01, PSI-10, PSI- 08, and East Bay State #1, an exploration well drilled in 11/74. EBS#1 was DST'd and then suspended with a CIBP @ 9300' MD and 100sx of cement. ).- Identify hazards in a pre move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. PSI-O? Permit to Drill Page 10 e e PSI-07 Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates were not observed at the other 6 wells on this pad, and are not expected at PSI-a? . Shallow gas was not observed at the other 6 wells on this pad, is not expected at PSI-a? · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Intermediate Hole Section: · Fault crossings are not expected along the PSI-a? wellpath in the intermediate hole. · Lost circulation is not expected in the intermediate hole section. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures if LC is encountered. · Drill Site 4 is located approximately 3.5 miles to the SE. Cretaceous injection has the potential for raising the pore pressure to 9.5 ppg EMW in the Ugnu. This has not seen at other PSI wells and is not expected at PSI-a? · Gas cut mud was observed at 3 of the other PSI wells on this pad. Raise MW to 10.5 ppg prior to cutting the CM2. · The directional plan has been built to minimize directional work and tangent angle in the HRZ. With the current directional plan, raise MW to 10.0 ppg before entering the HRZ to aid in hole stability. · Differential sticking will be a problem if the drill string is left stationary for an extended period of time across the long permeable sections of the Ugnu and West Sak intervals. Minimize the time the pipe is left stationary. · The kick tolerance for the 12-1/4" open hole section would be 133 bbls assuming a kick while at the section TD (-10,461' MD). This is a worst case scenario based on a 10.0 ppg pore pressure gradient, a fracture gradient of 12.0 ppg at the 13-3/8" shoe, gauge hole, and 10.0 ppg mud in the hole. · Picking the 9-5/8" casing point is critical. Every attempt should be made to hit the BHRZ. If too much HRZ is left open while drilling the Ivishak, hole problems can be encountered due to the HRZ sloughing. If too much of Zone 3 is drilled, LC could be encountered due to the low pore pressure in Zone 3 (?3 ppg). Production Hole Section: · Lost circulation is considered to be a moderate risk because of the low pore pressure in the Ivishak. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. · PSI-a? passes BP's anti-collision against L3-01 when minor risk based at 1/200. The closest center to center distance is 258' at 11,188' MD. · The kick tolerance for the 8-1/2" open hole section would be infinite assuming a kick from the Ivishak. This is a worst case scenario based on a 8.6 ppg pore pressure gradient, a fracture gradient of 10.0 ppg at the 9-5/8" shoe, and 9.0 ppg mud in the hole. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. H2S is not expected during the planned drilling operations. Offset wells are not productive from the Ivishak and therefore are not relevant. Nevertheless, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PSI PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION PSI-a? Permit to Drill Page 11 ~-07 Proposed Cwnpletion I Seawater Injection: 100,000 bblslday @ 2700 psi I Wellhead: 13-5/8", 5K, Big Bore, FMC Tree: 6-318" bore x 7-1/6", 5K, 625 Inlay, CIW 80' MD :- ~,~ 5629' MD / 9508' MD 10304' MD 'I (' 10614' MD ~ L---J 10704' MDI 10804' MD Date 08-25-03 20" x 34" Insulated Conductor 13-3/8" TAM Port Collar 7" Camco DB Nipple (6" ID) Required Tubing Crossovers: #1 7" TCII Pin X 7-5/8" STL Pin Tubing Hanger to Tubing #2 7 -518" STL Box X 7" TCII Pin Tubing to SSSV #3 7" TCII Box X 7-5/8" STL Pin SSSV to Tubing #4 7 -5/8" STL Box X 7" TCII Pin Tubing to Seal Assembly 13-3/8",68#, L-80, BTC 7-5/8",29.7#, ST-L, IPC, Injection Tubing with 7", TCII tailpipe and accessories TOC 9-5/8",40#, S-95, BTC-MI 7" x 5.963" HES R Nipple 7" x 9-5/8" Baker Seal Assy 7" x 9-5/8" SABL-3 packer with 20' PBR 7" x 5.963" HES R Nipple 7" x 5.77" HES RN Nipple 7" WLEG 7" x 9-5/8" Baker HMC Liner Hanger, ZXP Liner Top packer, and tieback sleeve 9-5/8",47#, L-80, BTC-M 7", 26#, L-80, BTC-M Rev By Comments RBT Anadril Plan #9 PROJECT: GCWSI WELL: PSI-05 API NO: GPB Rotary Drilling LOCATED WITHIN PROTRACTED SEC. 15, T. 11 N., R. 15 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS PSI-5 Y= 5,966,138.53 N= 9,999.95 70"18'39.066" 70.3108517" 17.3' 3,838' FSL X= 707,939.85 E= 5,029.97 148"18'53.444" 148.3148456" 4,465' FEL PSI-7 Y=5,966,158.98 N= 9,999.85 70"18'39.251" 70.3109031" 17.4' 3,857' FSL X= 707,996.33 E= 5,090.04 148"18'51.870" 148.3143833" 4,408' FEL e PRUDHOE BAY o o à p o N ~(Q j t3 "- r -,...- I WF11NJECTlON / WELL FACILITY (EAST DOCK WEST PAD) -' -' L() '" w 0 :;: í I <D I 00 0> <:> U) I U) I I I ëñ ëñ ëñ ëñ ëñ z Cl. a... Cl. a... Cl. Cl. Cl. F -+ -+ UJ . . . . . x w . g OJ ~ g; NOTES: 1. DATE OF SURVEY: AUGUST 7, 2003. 2. REFERENCE FIELD BOOK: PB03-03 PAGES 74-75. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD27. 4. GEODETIC COORDINATES ARE NAD-27. 5. EAST DOCK FACILITY AVERAGE SCALE FACTOR IS 0.999949103. 6. HORIZONTAL CONTROL ESTABLISHED BY GPS STATIC OBSERVATIONS BASED ON DRILLSITE OPERATOR MONUMENT "DS-11A". 7. ELEVATIONS ARE ARCO MLLW BASED ON DRILLSITE 11 OPERATOR MONUMENT "DS-11A". ~ " ,..: I If) I ¡;; "- .. '5 -" I · <I · C o t , " c o u "- :> -Ii ,g .. · o w I o '" w ~ '" "- ,/ g OJ ::. r.:: ~ "- g .. · o w ,/ <I o ~ g 0 8/08/03 ISSUED FOR INFORMATION ~ NO. DATE REVISION _RUDHOE an - EAST DOCK PROJECT AREA . ' I L"'~_. - '-' LISBURNE DRILL SITE 3 21 22 I VICINITY MAP N.T.S. LEGEND -+ AS-BUILT CONDUCTOR . EXISTING CONDUCTOR SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF AUGUST 7, 2003. ~œoil DRAINN: Obp COTTON CHECKED' O'HANLEY DATE: 8/08/03 DRAWING: SHEET: FRB03 EO 01-01 GPB EAST DOCK WFl PAD ¡ ffi~~rnœD JOB NO: SCALE: AS-BUILT CONDUCTORS EHGlNEERSNroLANDSUR'ÆYORS WELLS PSI-5, & PSI- 7 1 OF 1 JJC LOH 1101 WESf FlREWŒO LAN£ 1"= 120' BY CHK ~OAAŒ. AlASKA 1Ii~ KBE KOP Bid 1/100 Bid 1.5/100 End Bid Base Perm Bid 2/100 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWI/API#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: Location Lat/Long: Location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: Comments Measured Depth (ft) 0.00 693.90 700.00 800.00 900.00 Schlumberuer PSI-07 (P9) Proposal ~ Survey I DLS Computation Method: Vertical Section Azimuth: 3/3 Vertical Section Origin: TVD Reference Datum: 81 TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: Magnetic Declination Model: North Reference: Total Corr Mag North .> True North: Local Coordinates Referenced To: August 13, 2003 BP Exploration Prudhoe Bay Unit· Lisburne East Dock (PSI) / PSI-7 d ~~::~~ APpro". 50029 PSI-07 (P9) / August 13, 2003 80.717" /526178206.95 ft/10.741/60996.274 NAD27 Alaska State Planes, Zone 04, US Feet N 70.31090311, W 148.31438346 N 5966158.980 ftUS, E 707996.330 ftUS +1.58711851° 0.99994915 Inclination (deg) 0.00 0.00 0.06 1.06 2.06 8.59 10.09 11.59 13.09 14.59 15.46 15.46 15.46 15.46 16.23 Azimuth (deg) 326.76 326.76 326.76 326.76 326.76 3.06 4.00 4.09 5.59 7.09 326.76 326.76 326.76 326.76 326.76 1000.00 1093.90 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1857.97 1900.00 1909.85 1961.73 2000.00 326.76 326.76 326.76 326.76 326.76 326.76 326.76 326.76 326.76 326.76 Version DO 3.1RT (d031rt_546) 3.1RT-SP3.03 TVD (ft) 0.00 693.90 700.00 799.99 899.96 999.85 1093.58 1099.66 1199.30 1298.69 1397.75 1496.42 1594.63 1692.32 1789.41 1845.40 1885.91 1895.40 1945.40 1982.22 Sub·Sea TVD (ft) -45.40 648.50 654.60 754.59 854.56 954.45 1048.18 1054.26 1153.90 1253.29 1352.35 1451.02 1549.23 1646.92 1744.01 1800.00 1840.51 1850.00 1900.00 1936.82 Vertical Section (ft ) 0.00 0.00 0.00 0.98 3.71 8.17 13.96 14.39 22.83 33.87 47.52 63.75 82.56 103.93 127.85 142.88 154.09 156.71 170.54 180.99 NS (ft) 0.00 0.00 0.00 0.82 3.10 6.84 11.67 12.03 19.09 28.33 39.74 53.31 69.04 86.92 106.93 119.50 128.87 131.06 142.63 151.37 EW (ft) 0.00 0.00 0.00 -0.54 -2.03 -4.48 -7.65 -7.89 -12.51 -18.57 -26.05 -34.95 -45.26 -56.97 -70.09 -78.33 -84.47 -85.91 -93.49 -99.22 PSI-7\PSI-07\PSI-07\PSI-07 (P9) Minimum Curvature / Lubinski 326.750° N 0.000 ft, E 0.000 ft KB 45.4 ft relative to MSL 17.600 ft relative to MSL 25.732° 57593.064 n T 80.907" October 05, 2003 BGGM 2003 True North +25.732° Well Head DLS (deg/100 ft) 0.00 0.00 1.00 1.00 1.00 Tool Face (deg) -33.24M -33.24M -33.24M -33.24M -33.24M 1.00 1.00 1.50 1.50 1.50 -33.24M -33.24M -33.24M O.OOG O.OOG 1.50 1.50 1.50 1.50 1.50 O.OOG O.OOG O.OOG O.OOG O.OOG 1.50 0.00 0.00 0.00 2.00 90.00G O.OOG O.OOG O.OOG O.OOG Northing (ftUS) 5966158.98 5966158.98 5966158.98 5966159.79 5966162.02 5966165.69 5966170.44 5966170.79 5966177.72 5966186.78 5966197.98 5966211.30 5966226.74 5966244.28 5966263.92 5966276.26 5966285.45 5966287.61 5966298.96 5966307.54 Easting (ftUS) 707996.33 707996.33 707996.33 707995.77 707994.21 707991.66 707988.36 707988.11 707983.29 707976.98 707969.19 707959.92 707949.18 707936.97 707923.31 707914.73 707908.33 707906.83 707898.93 707892.96 - Latitude Longitude N 70.31090311 W 148.31438346 N 70.31090311 W 148.31438346 N 70.31090312 W 148.31438347 N 70.31090536 W 148.31438782 N 70.31091158 W 148.31439992 N 70.31092179 W 148.31441977 N 70.31093500 W 148.31444545 N 70.31093599 W 148.31444736 N 70.31095527 W 148.3.85 N 70.31098051 W 148.3 91 N 70.31101168 W 148.31459451 N 70.31104876 W 148.31466661 N 70.31109174 W 148.31475015 N 70.31114057 W 148.31484509 N 70.31119523 W 148.31495135 N 70.31122957 W 148.31501811 N 70.31125517 W 148.31506788 N 70.31126117 W 148.31507954 N 70.31129277 W 148.31514098 N 70.31131664 W 148.31518739 Generated 8/13/2003 11: 16 AM Page 1 of 3 Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical NS EW DLS Tool Face Northing Easting Latitude Longitude Depth Section (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (deg ) (ftUS) (ftUS) 2100.00 18.23 326.76 2077.73 2032.33 210.60 176.14 -115.45 2.00 O.OOG 5966331.84 707876.05 N 70.31138430 W 148.31531893 2200.00 20.23 326.76 2172.15 2126.75 243.53 203.68 -133.51 2.00 O.OOG 5966358.87 707857.24 N 70.31145954 W 148.31546520 2300.00 22.23 326.76 2265.36 2219.96 279.74 233.95 -153.35 2.00 O.OOG 5966388.59 707836.56 N 70.31154226 W 148.31562602 2400.00 24.23 326.76 2357.25 2311.85 319.17 266.94 -174.97 2.00 O.OOG 5966420.95 707814.04 N 70.31163236 W 148.31580119 2500.00 26.23 326.76 2447.71 2402.31 361.79 302.58 -198.34 2.00 O.OOG 5966455.93 707789.70 N 70.31172973 W 148.31599050 Bid 3/100 2554.54 27.32 326.76 2496.40 2451.00 386.35 323.12 -211.80 ./ 2.00 O.OOG 5966476.10 707775.67 N 70.31178586 W 148.31609963 2600.00 28.68 326.76 2536.54 2491.14 407.70 340.97 -223.50 3.00 O.OOG 5966493.61 707763.48 N 70.31183462 W 148.31619443 2700.00 31.68 326.76 2622.97 2577.57 457.96 383.01 -251.06 3.00 O.OOG 5966534.87 707734.77 N 70.31194947 W 148.31641773 2800.00 34.68 326.76 2706.65 2661.25 512.69 428.78 -281.06 3.00 O.OOG 5966579.79 707703.52 N 70.31207450 W 148.31666082 2900.00 37.68 326.76 2787.36 2741.96 571.72 478.15 -313.42 3.00 O.OOG 5966628.24 707669.81 N 70.31220936 W 148.31692305 3000.00 40.68 326.76 2864.87 2819.47 634.89 530.98 -348.05 3.00 O.OOG 5966680.09 707633.73 N 70.31235370 W 148.3a68 3100.00 43.68 326.76 2938.96 2893.56 702.03 587.14 -384.86 3.00 O.OOG 5966735.20 707595.38 N 70.31250710 W 148.31750195 3200.00 46.68 326.76 3009.43 2964.03 772.96 646.46 -423.74 3.00 O.OOG 5966793.42 707554.87 N 70.31266915 W 148.31781705 End Bid 3286.56 49.28 326.76 3067.37 3021.97 837.26 700.24 -458.99 3.00 O.OOG 5966846.20 707518.14 N 70.31281606 W 148.31810271 SV4 3942.68 49.28 326.76 3495.40 3450.00 1334.54 1116.13 -731.60 0.00 O.OOG 5967254.36 707234.13 N 70.31395219 W 148.32031203 SV3 4571.16 49.28 326.76 3905.40 3860.00 1810.87 1514.51 -992.73 0.00 O.OOG 5967645.33 706962.09 N 70.31504044 W 148.32242852 SV2 4877.74 49.28 326.76 4105.40 4060.00 2043.22 1708.83 -1120.11 0.00 O.OOG 5967836.05 706829.38 N 70.31557129 W 148.32346103 SV1 5475.57 49.28 326.76 4495.40 4450.00 2496.32 2087.78 -1368.50 0.00 O.OOG 5968207.95 706570.60 N 70.31660642 W 148.32547459 13-318" Csg pt 5628.85 49.28 326.76 4595.40 4550.00 2612.50 2184.94 -1432.19 0.00 O.OOG 5968303.30 706504.25 N 70.31687183 W 148.32599092 UG4 6246.61 49.28 326.76 4998.40 4953.00 3080.70 2576.52 -1688.86 0.00 O.OOG 5968687.60 706236.85 N 70.31794144 W 148.32807186 UG3 6628.30 49.28 326.76 5247.40 5202.00 3369.98 2818.46 -1847.45 0.00 O.OOG 5968925.04 706071.63 N 70.31860230 W 148.32935771 UG1 7601.68 49.28 326.76 5882.40 5837.00 4107.71 3435.45 -2251.88 0.00 O.OOG 5969530.57 705650.29 N 70.32028758 W 148.33263727 West Sak 2 8427.90 49.28 326.76 6421.40 6376.00 4733.91 3959.17 -2595.17 0.00 O.OOG 5970044.55 705292.65 N 70.32171804 W 148.33542144 West Sak 1 8714.55 49.28 326.76 6608.40 6563.00 4951.17 4140.87 -2714.27 0.00 O.OOG 5970222.87 705168.57 N 70.32221431 W 148.33638747 CM3 9030.33 49.28 326.76 6814.40 6769.00 5190.49 4341.03 -2845.47 0.00 O.OOG 5970419.31 705031.88 N 70.32276099 W 148.33745170 Drp 2/100 9185.89 49.28 326.76 6915.88 6870.48 5308.39 4439.64 -2910.10 0.00 180.00G 5970516.08 704964.54 N 70.32303031 W 148.33797600 9200.00 49.00 326.76 6925.11 6879.71 5319.07 4448.56 -2915.95 2.00 180.00G 5970524.84 704958.45 N 70.32305469 W 148.3.46 9300.00 47.00 326.76 6992.03 6946.63 5393.37 4510.71 -2956.69 2.00 180.00G 5970585.83 704916.01 N 70.32322442 W 148.3. 91 9400.00 45.00 326.76 7061.49 7016.09 5465.30 4570.86 -2996.12 2.00 180.00G 5970644.87 704874.93 N 70.32338872 W 148.33 378 9500.00 43.00 326.76 7133.43 7088.03 5534.76 4628.96 -3034.20 2.00 180.00G 5970701.88 704835.26 N 70.32354738 W 148.33898268 9600.00 41.00 326.76 7207.74 7162.34 5601.67 4684.91 -3070.87 2.00 180.00G 5970756.80 704797.05 N 70.32370021 W 148.33928023 9700.00 39.00 326.76 7284.34 7238.94 5665.94 4738.67 -3106.11 2.00 180.00G 5970809.55 704760.34 N 70.32384702 W 148.33956607 9800.00 37.00 326.76 7363.14 7317.74 5727.50 4790.15 -3139.86 2.00 180.00G 5970860.08 704725.18 N 70.32398764 W 148.33983984 9900.00 35.00 326.76 7444.04 7398.64 5786.27 4839.30 -3172.08 2.00 180.00G 5970908.32 704691.61 N 70.32412188 W 148.34010123 10000.00 33.00 326.76 7526.95 7481.55 5842.18 4886.06 -3202.73 2.00 180.00G 5970954.21 704659.68 N 70.32424960 W 148.34034990 CM2 10008.88 32.82 326.76 7534.40 7489.00 5847.01 4890.10 -3205.37 2.00 180.00G 5970958.17 704656.92 N 70.32426061 W 148.34037135 10100.00 31.00 326.76 7611.75 7566.35 5895.17 4930.38 -3231.77 2.00 180.00G 5970997.70 704629.42 N 70.32437062 W 148.34058555 CM1 10156.43 29.87 326.76 7660.40 7615.00 5923.75 4954.28 -3247.44 2.00 180.00G 5971021.16 704613.10 N 70.32443591 W 148.34071267 Version DO 3.1RT (d031rL546) 3.1RT-SP3.03 PSI-7\PSI-07\PSI-07\PSI-07 (P9) Generated 8/13/2003 11: 16 AM Page 2 of 3 Comments Measured Inclination Azimuth TVD Sub-Sea TVD Vertical NS EW DLS Tool Face Northing Easting Latitude Longitude Depth Section (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg/100 ft) (deg) (ftUS) (flUS) 10200.00 29.00 326.76 7698.35 7652.95 5945.16 4972.19 -3259.18 2.00 180.00G 5971038.73 704600.87 N 70.32448481 W 148.34080790 10300.00 27.00 326.76 7786.64 7741.24 5992.10 5011.45 -3284.91 2.00 18D.OOG 5971077.26 704574.06 N 70.32459203 W 148.34101667 10400.00 25.00 326.76 7876.52 7831.12 6035.93 5048.10 -3308.94 2.00 180.00G 5971113.24 704549.02 N 70.32469215 W 148.34121162 10500.00 23.00 326.76 7967.87 7922.47 6076.60 5082.11 -3331.23 2.00 180.00G 5971146.62 704525.80 N 70.32478504 W 148.34139249 10600.00 21.00 326.76 8060.59 8015.19 6114.05 5113.44 -3351.77 2.00 180.00G 5971177.36 704504.41 N 70.32487059 W 148.34155907 Drp 0.5/100 10600.68 20.98 326.76 8061.22 8015.82 6114.29 5113.64 -3351.90 2.00 180.00G 5971177.56 704504.27 N 70.32487114 W 148.34156016 Top HRZ 10600.87 20.98 326.76 8061.40 8016.00 6114.36 5113.70 -3351.94 0.50 180.00G 5971177.61 704504.23 N 70.32487130 W 148.34156046 10700.00 20.49 326.76 8154.11 8108.71 6149.46 5143.05 -3371.18 0.50 180.00G 5971206.42 704484.19 N 70.32495146 W 148.34171656 Target 10797.11 20.00 326.76 8245.22 8199.82 6183.06 5171.15 -3389.60 0.50 -176.65G 5971234.00 704465.00 N 70.32502821 W 148.3.01 10800.00 19.98 326.75 8247.94 8202.54 6184.04 5171.98 -3390.14 0.54 -176.65G 5971234.81 704464.43 N 70.32503046 W 148.3 40 Base 10803.68 19.96 326.75 8251.40 8206.00 6185.30 5173.03 -3390.83 0.54 -176.64G 5971235.84 704463.71 N 70.32503334 W 148.34187600 HRZILCUlTZ31TCGL 9-518" Csg pt 10803.69 19.96 326.75 8251.41 8206.01 6185.31 5173.03 -3390.83 0.54 -176.64G 5971235.85 704463.71 N 70.32503335 W 148.34187602 TZ2C I BCGL 10856.83 19.68 326.70 8301.40 8256.00 6203.33 5188.10 -3400.72 0.54 -176.60G 5971250.63 704453.41 N 70.32507449 W 148.34195623 10900.00 19.45 326.66 8342.07 8296.67 6217.78 5200.18 -3408.66 0.54 -176.56G 5971262.48 704445.14 N 70.32510748 W 148.34202066 TZ2B I 23SB 10914.13 19.37 326.65 8355.40 8310.00 6222.48 5204.10 -3411.24 0.54 -176.54G 5971266.33 704442.45 N 70.32511820 W 148.34204160 TZ2A I 21TS 10999.87 18.92 326.56 8436.40 8391.00 6250.60 5227.58 -3426.72 0.54 O.OOG 5971289.37 704426.33 N 70.32518232 W 148.34216719 11000.00 18.92 326.56 8436.52 8391.12 6250.64 5227.61 -3426.74 0.54 -176.46G 5971289.41 704426.30 N 70.32518241 W 148.34216738 TZ1B 11037.90 18.71 326.52 8472.40 8427.00 6262.86 5237.81 -3433.48 0.54 -176.43G 5971299.41 704419.28 N 70.32521027 W 148.34222206 11100.00 18.38 326.46 8531.27 8485.87 6282.62 5254.28 -3444.39 0.54 -176.36G 5971315.57 704407.93 N 70.32525524 W 148.34231054 BSAD 11148.57 18.12 326.40 8577.40 8532.00 6297.83 5266.96 -3452.80 0.54 -176.31G 5971328.01 704399.17 N 70.32528986 W 148.34237880 TO I 7" Lnr 11200.09 17.85 326.34 8626.40 8581.00 6313.73 5280.20 -3461.61 0.54 O.OOG 5971341.00 704390.00 N 70.32532603 W 148.34245027 LeQal Description: NorthinQ (Y) fftUSl EastinQ ¡X) fftUSl Surface : 3856 FSL 4408 FEL S15 T11N R15E UM 5966158.98 707996.33 Target: 3747 FSL 2507 FEL S9 T11N R15E UM 5971234.00 704465.00 BHL: 3856 FSL 2579 FEL S9 T11N R15E UM 5971341.00 704390.00 e Version DO 3.1RT (d031rC546) 3.1RT-SP3.03 PSI-7\PSI-07\PSI-07\PSI-07 (P9) Generated 8/13/2003 11 :43 AM Page 3 of 3 ~ ~ e e Schlumberger WEll PSI-07 (P9) FIELD Prudhoe Bay Unit - Lisburne STRUCTURE East Dock (PSI) Magnetit; Patametefs Model: BGGM 2003 Dip: 80.907' MagDec: +25.732' I Suffaœ Location Date: Octobar05, 2003 lat N701839.2S1 FS: 57593.1nT Lon: W1481851.780 NA027 Alaska State Planes, Zone 04, US Feet Northing: 5966158.98ftUS GridCOflv: +1.58711851' Easting 707996.33 ftUS Scale Fact: 0,9999491456 MiscaUanaous Slot: PSI-7 Plan" PSI-07(P9) TVD Rat: KB (45.40 ft above MSL) SN~ Date: August 13, 2003 o 1200 2400 3600 4800 6000 o o KOP Bid ---- ~Bld1.5/100 1200 1200 2/100 2400 2400 ¢? 3600 3600 0 0 C\ ~ g ~ II Q) ro <.> (/) 4800 4800 0 ç 8400 6000 6000 7200 7200 ./ 8400 o 1200 2400 3600 4800 6000 Vertical Section (ft) Azim = 326.75°, Scale = 1 (in): 1200(ft) Origin = 0 N/-S, 0 E/-W WELL PSI-07 (P9) Ma~Pantmeters Model: BGGM 2003 Dip' 80.907' MagDec: +25.732' ^ ^ ^ Z ~ o o ~ I ~ II ( ) õi o (f) (f) v v v e FIELD e Schlumberger Prudhoe Bay Unit - Lisburne STRUCTURE East Dock (PSI) · . .......0<......».....................,...........,.._............................... · . · . · . · . · . · . I SurfaceLocalion Date: October 05, 2003 La!: N701839.251 FS: 57593.1 nT Lon: W1481851.780 -4000 -3200 5600 · . · . ¡~SI'7F~1'1 ¡ · . · . · . · . · . ........·............·............"..._...........H...... ¡ ..~...... . ................. . TDfC_~~~.'CSgPt ! PSI·07 (P9 \...........~...... ¡ Target : \.~ ..: ! " ~ " ¡ Drp 0.51100 4800 ..,.............................. ....H.........................H~.............H.... · . · . · . · . ··..t....,····....···..···········..,..··~..·..···..··......···..·H........ ..t>....... 4800 NAD27 Alaska State Planes, Zone 04, US Feet Northing' 5966158.98ftUS GtidConv: +1.58711851' Easting: 707996.33fl:US Scale Fact: 0.9999491456 -2400 -1600 Mis<:aIlaneous Slot: PSI-7 Plan: PSI-07(P9) TVD Ref: KB (45.40 ft above MSL) SfvyDate: August13,2003 -800 o ~.................................:N... ~........................ .1...... ..c:< -_,--: ~." ., ; . í : 5600 4000 · . · . .......................................""..... · . , . · , · , · , · . · , · . . · . . · . > . , . . > ·....····¡..········....······················t··..·······'..······...··....·······¡---····..·..·.....··..·'···..·..··..r····· 4000 · . · . · . · . . · . . · . . ¡mmm m.mrm .m.¡. .m 3200 . . . . ·..·..·····..············..···r··················...·,········..T...·.. 3200 2400 · . · . >. · > >. ··I····..········..······...·..·...····¡-..······...·········..············r..··..··..··..·················..· .·····..·······..·····..·...·..····r···.....·.......·····...··....·..T..··· 2400 · . · . · . · . I-m_-rrm- 1600 800 ...........-...,-...... o · . · . · . · . ".........······....·..·······......·'v · . · . · . · . · . · . · . · . ............,....................... -4000 -3200 · . · . .......................«...........,............-.. · . · . · . · . · . · . · . · . ,..................................'" -2400 -1600 <<< W Scale = 1(in):800(ft) E >>> T 1600 800 rdBld ¡Bid 31100 ¡ Bid 21100 ¡ End Bid ,...................."..............,..........."....-.. : Bid 1.51100 ¡ KOP Bid 11100 , KBE o -800 o e e Oilfield Services, Alaska Schlumberger Drilling & Measurements IbePIIIP 3940 Arctic Blvd, Site 300 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8357 VVednesday, August 13, 2003 Robert Tirpack Prudhoe Bay PSI-07 (P9) BP Exploration Alaska Doyon 141 Close Approach Analysis VVe have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analvsis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. VVells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey ProQram: Instrument Type GYD-GC-SS MVVD - IFR - MS Start Depth 28.00'md 1,000.00'md End Depth 1,OOO.00'md 11,200.09'md Close Approach Analvsis results: Under method (2): l3-01 fails the conventional flowing rules in the depth range of 11 040'md to TD on the planned well, and 13420'md to 13,600'md on the offset well. Closest point being at TD of the planned well, center to center distance is 259' with an allowable deviation of -105'. This well passes the risk based rule of 1 :200, with the allowable deviation being the same distance as the center to center distance, at TD. All other wells may flow. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach DrillinQ Aids to be provided: A drilling map, with any offset wells on the plan view, and a traveling cylinder, will be provided. Checked by: Scott Delapp 08/13/03 e BPX AK Anticollision Report e NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.00 to 11200.09 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/30/2001 Validated: No Planned From To Survey ft ft 28.00 1000.00 Planned: Plan #9 V1 1000.00 11200.09 Planned: Plan #9 V1 Version: 11 Toolcode Tool Name GYD-GC-SS MWD+IFR+MS Gyrodata gyro single shots MWD + IFR + Multi Station Casing Points 5628.85 10803.68 11200.09 4595.40 8251.40 8626.40 13.375 9.625 7.000 17.500 12.250 8.750 133/8" 9 5/8" 7" Summary East Dock (PSI) PSI-01 PSI-01 V8 1752.43 1750.00 196.82 25.95 170.87 Pass: Major Risk East Dock (PSI) PSI-OS Plan PSI-OS V9 Plan: P 1000.98 1000.00 63.17 19.14 44.03 Pass: Major Risk East Dock (PSI) PSI-06 PSI-06 V14 594.57 600.00 31.87 10.08 21.78 Pass: Major Risk East Dock (PSI) PSI-08 PSI-08 V22 593.93 600.00 24.44 12.59 11.85 Pass: Major Risk East Dock (PSI) PSI-09 PSI-09 V6 994.27 1000.00 62.32 15.93 46.39 Pass: Major Risk East Dock (PSI) PSI-10 PSI-10 V12 544.71 550.00 95.04 11.43 83.61 Pass: Major Risk EX EBAYST-01 EBAYST-01 EBAYST-01 V4 1295.01 1300.00 268.26 25.00 243.26 Pass: Major Risk Lis OS 03 L3-0 1 L3-01 V1 11187.56 13600.00 258.65 0.00 258.65 Pass: Minor 1/200 Lisburne East Dock (PSI) PSI-07 Plan PSI-07 Field: Site: Well: Wellpath: e e (PSI-09 ')0 -147 100 27G PSI-OS 50 100 -0 50 o Centre Separation [50ft/in 4 Azimuth (TFO+AZn ldeg] vs Centre 80 TraveUing Cyhode -147 <= :¡¡ Ë d o .~ e. '" ß ð ¡¡ ~ u - PSI-Q/ «5 PSI-08~8) ----- ----- - 70- ...... . .. . . ,meld, -Lisbume Þi:1I 7V .... : ~ - . : Site: East Dock (PSI) . \ ....... ... .... : Well: PSI-07 : - .................. ........... .. ........ . ..... ....... . - ..................... . - ------- : 60- '..... , ,." - 1 / i - .... .............. . .................... : ............................. . / / '. : ¡ 11---1 .-' ...... ............. ... /. ................. . ........... - / 7 . : . '. :. # '. . - 1 ./._./.~/ :It - ·······1 .... ......... i ... .//~ - ..... ..// .. ......... ................. - ... : v/' I....: . IV : /// . : 40- . I /4ÎF l// : : - (/~ - - I ....... .. i I ..J .... - ... . ............. .. .,/' .>/ eJ] . : .~;.- I . , .. : .1. : 1 30-···· ------ -. !j\/r /.. - // -. ~ // - - - i 1 1 ............... ............... i ....................... ... . . /// : 1 .v /// i: - - - ,. . ì .. i . · : ................. ....... ...... : ............ i .... . . : · . ì . 1 : . · - .. .. . ......... ..11 .. .. ............... ................... .. .......... ....... ............. ................... ...... .......... . .. i ì . - - - 0 , , , , , , , , , , , , , , , , , . , , , , , , , I , , I , , , 0 2)0 4ÒO 6"0 8' ,0 j(100 1::00 1':00 1600 1800 Measured Depth [200ft/in] Target: PSI-07 Poly Polygon 1 2 3 4 Site: East Dock (PSI) Drilling Target Conf.: 956 Description: ., Map Northing: 5971341.00 ft Map Easting : 704390.00 ft Latitude: 70019'31.174N Xft -247.43 199.82 192.01 -102.90 yft 168.93 62.50 -219.41 -211.23 Well: PSI-07 _ased on: Planned Program .. ertical Depth: 8581.00 ft below Mean Sea Level Local +N/-S: 5280.19 ft Local +E/-W: -3461.59 ft Longitude: 148°20'32.821 W Map E ft 704138.00 704588.00 704588.00 704293.00 Map N ft 5971503.00 5971409.00 5971127.00 5971127.01 lOO 5500 5500 54-00 5300 5200 5100 5000 4-900 0 0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 0 0 0 o ~ ~ I LD Ln -=I- (I) ('.J 0 (I) (I) (I) (I) (I) (I) (I) (I) ~ ~ I I I I I I I I ~ , rfJ p055119 DATE INVOICE / CREDIT MEMO 7/14/2003 INV# PR0710031 DESCRIPTION PERMIT TO DRILL FEE GROSS THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 995'1 Ø-6612 PAY: TOTAL ~ tf· ''I''. 11I11 ¡lIlh, :.:l,,I,. (".,) ('11I" ?5 \ ..07 NATIONAL CITY BANK Ashland, Ohio r' DATE I I CHECK NO. 7/14/2003 055119 VENDOR DISCOUNT NET H e 56-389 412 No.P 055119 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT July 14,2003 I>;. .>1.. . ***t~r$1ÖO,00******1 NOT vALll;fAF:te.R-.12Ö·.~*:r;¡¡,:;,,,,,,;;,,,,,,;:"".;J.,.~;'··.':..:.....;i;.:~ ::'. '.·.\.·.·.:.·:....;·.:...;.....,.:;n~. '\. :\. :'". ;:1 ~~;(.,!,:·~:,~,;:~~~:t~~~2¡:! TO THE ORDER OF: AL,i\$KA ~IL &<:3,i\5 GONSERVfHION 333 W 7TH AVENUE SUITE 100 ANCHORA(3E, ÃK 9$501-3539 1110 5 5 1 ~ g III I: 0 ... . 20 3, 8 g 5 I: O. 2 ? 8 g b IIØ e PTD#: 2031480 Administration Unit Appr Date RPC 8/26/2003 Engineering Appr Date WGA 8/27/2003 Geology Appr RPC Date 8/26/2003 Geologic Commissioner: {)\J 1 2 3 4 5 6 7 I 8 9 10 11 12 13 14 15 16 17 Company _lie. EXPLORATION (ALASKA) INC Field & Pool PRUDHOE BAY. PRUDHOE OIL - 640150 Initial ClasslType Pe(mit fe~ attaçhed ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yes ~ 1easenµmb~rappropriate~ ~ ~ ~ Yes ~ ~ ~ ~U~niqµfH'Vell~ n~a[T1e ~a[1c! ol!mb~e( ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yes ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ W~lIlocated[nadefine~dpool ~~~~~~ ~~~Yes~ ~~~~~~~~ ~~~~~~ W~lIlocated prop~rdista[1ce from driJling unitbound~a(y~ ~ ~ ~ ~ Yes ~ W~II located prop~r ~distance from oth~r welJs ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yes ~ ~ ~ ~ ~ ~ ~ ~ ~ SutfiçienLacrea~eaYail.<lble [ndJilliog unjL ~ ~ ~ ~ ~ ~ Yes ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Jfdeviated, js~ weJlbore platJncJuded ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~No~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ _ . . . . . . ~ . . . . . . . ~Operator onlY' affeçted party _ . . . . . Y.es . ~ . . . . . ~ ~ . . . . ~ ~ ~ ... ~ ~ ~ .... ~ ~ . ~ . . . . . ~ ~ . . . . . ~ ~ _ . . . . . ~ . . ~Qpe~ator bas~appropr[aleJ~_ond inJorce. ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . . ~ ~ ~ ~ ~ . ~ Yes ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ Pe(mit c.a[1 Þe iSSl!ed without COMe.rvation ord~r. . . ~ . ~ _ . . . . . ~ ... Yes ~ . . . . . . ~ ~ . . . . ~ ~ . . . . . ~ . ~ . . . . . ~ . . ~ ~ . . . . . . _ ..... ~ ~ . Pe(mit ca[1 Þe [sSl!ed without administ(atÌ\le~apprpvaJ ~ ~ . . . . . ~ ~ No . . . ~ ~ . Can permit be approved before 15-day wait Yes We.ll Jocated within area andßtrataauthor[zed by Injectioo Orde( # (pµ!l0# in.comm.ents) (For YeL 4C . . . . ~ ~. ..... ~ ~ . . . . . ~ ~ .... ~ ~ . . ~AJlwelJs-'l....it]1inJl4JDile~are.a~of(eyiew id~eotified (Fp($efVjc~ewell onlyL ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Yes ~ ~ ~ ~ ~ ~ 1,.3~-Qt(Confirrr (~d~with~oper¡¡tpr).~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ _ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Pre.-produ.cec! i[1jector; dur.<ltio~n~of pre-productiçm less~ than 3. months (For~servLce well onJy) . . NA ~ .... ~ ~ . . . . . ~ ~. .... ~ _ . . ~ ~ ~ ~ .... ~ ~ ~ . . . . ~ ~ ~ .... ~ ~ ~ . ACMPJ=indingof Çon~sLstency has Þ~en jssµ~d forJhis projeçt . . . . . . . ~ ~ . NA ~ . . . . ~ ~... ~ ~ ..... ~ ~ ~ . . . . ~ ~ ~ . ~ . . . . . ~ ~ ~ . . . . _ ~ ~ ~ . o Well Name: PRUDHOE BAY UNIT SER 11WINJ GeoArea PSI-07 Well bore seg Annular Disposal Program SER 11650 On/Off Shore ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - e Yes. . Yes. . . . ~ ~ ~ ~ ~ . . . . . ~ ~ ~ . Yes ~ . . . . . . ~ ~ ~ . . . . ~ ~ ~ .N.o. . . ~ ~ ~ . 18 .C.ondu~cto( st(ingpJov[ded. ... ~ ~ ~ ~ ~ ~ . . ~ ~ ~ ~ . 19 Surface ~c¡¡$ingpJotect$ alLknown USDWs . . . ~ ~ ~ . . 20 .CMT vol adequ~ate~ to çircul.ate~oJl ~conduçtor. 8< SUJfcsg . 21 .CMT v~ol adeql!aleJo li~-Lnlongstring to surf csg. ~ ~ . . 22 ~CMTwilJ coYer~aJl knowJlpro~dµctiy~ borizon~s~ ~ ~ 23 ~Casing de.signs adeç¡ua.le. fp( CJ, B& perl1Jafr.ost 24 ~Adequ.<lte tankage~ OJ re.serve pit ~ ~ ~ ~ ~ . . ~ . ~ ~ 25 JfaJe-d(ilt hasa 10A03 for .<IbandonmeJlt beeo apPJoved . 26 ~Adequ.<lte we[lbore. $eparatioJl-Pfoposed ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 27 Jtdiver:terreq~uired, dQes it meet reguJations. ~ ~ ~ . . . ~ ~ ~ ~ . ~ ~ ~ ~ ~ ... ~ ~ ~ 28 ~DJiUiog fluid. program schematic~& eq.uip listadequate ~ ~ ~ . . ~ ~ ~ ~ . 29 BOPEs, d~o they meelJeguJation . . . . . . ~ ~ . . ~ ~ ~ . . ~ 30 ~BOPEpre.ss raJing approp(iate;.Iesl to (put psig in.comments) .. . ~ ~ ~ 31 ~C~hokel1Janifold çompJie$ w/API. Rf>-53 (May 64) 32 Work wiJl oCC~U( withoutoperation ~Shutdown~ .... ~ ~ ~ . 33 J$ pre$ence~ of H2S gas. proQaÞle. . . . . ~ ~ ~ . . . . ~ ~ ~ 34 Meçha~nicaLCÇJnc!it[o[1 p{ we.lIs within AOR verifiec! (fors.ervice well only) . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - · . ~Y.es ~ . . . . . ~ ~ _ . Yes. ....~~ ...~~. ~ . Yes . . . Doypn 141. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - " - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - ~ NA - - - - - - -- - - - - - - - - - - - - - - ~ ~ ~ ~ Yes ~ . ~ _ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ ~ ~ ~ ~ ~ . . ~ ~ ~ ~ ~ ~ ~ Xes~.~~_~_ · . Yes ~ .. ~ ~ ~ Max MW~ 10.5ppg. . ~ ~ .. ~ ~ ~. ... ~ ~ ~ ~ . . . . ~ ~ ~ .Yes . ~ . . . . ~ ~... ~ ~ ~ . . . . . ~ ~ ~ ~ . . ~ ~ ~ ~ . . . . ~ ~ . . Yes ~ ... ~ ~ Te.stt040QO~RSi.MSf>29]9psi. ~ ~ ~ ... ~ ~ ~ · Yes. Yes.~~~~~ · ~ No · . Yes ~ ~ ~ . . . . L3~-Q1 (within AOR)aband9ned, . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - e - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - 35 Pe(mit cao be iSSl!ed wlo hyd(ogen sulfide meaS.!J(es ~ . . . . . ~ ~ 36 ~D~atapJeseoted on Rote.ntial PveJRressuœ .zones ~ ~ . . . . ~ ~ ~ ~ 37Seism[c~analysjs of sbaJlow gaszone.s~ ~ ~ . . . . ~ ~ ... ~ . ~ ~ ~... ~ ~ ~ 38Seabedcondjljpo Sl!rvey .(if off-$hoœ) . . . . . _ ~ ~ . . . . ~ ~ ~ ~ . 39 . Conla~ct namelp]1oneJQrwee~ly progress reports [explorato(y ~only] . No. - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA ~....~~~.NA.~~~~. ~ ~NA ....~~~ ..NA~~~~..~~~~ - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- Date: Engineering Commissioner: / ~ ~'"'...¡;..¡ Public Commissioner Date Date ! 127D