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Home My WebLink About203-139David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250602 (IGB 25-001) Well API #PTD #Log Date Log Company Log Type Format AOGCC E-Set# KTU 43-6XRD2 50133203280200 205117 07/14/2014 POLLARD CBL PDF MPU C-15A 50029213580100 216070 07/06/2016 HALLIBURTON RCBL PDF LAS PPTX PBU L-103 50029231010000 202139 08/06/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-108 50029230900000 202109 06/30/2002 SCHLUMBERGER USIT/TEMP/GR PDF PBU L-111 50029230690000 202030 03/02/2002 SCHLUMBERGER USIT/TEMP/GR PDF TIF PBU S-104 50029229880000 200196 02/02/2001 SCHLUMBERGER USIT PDF PBU V-212 50029232790000 205150 12/14/2005 SCHLUMBERGER USIT PCU 04 50283201000000 201193 11/04/2001 SCHLUMBERGER USIT/CBL PDF TIF Please include current contact information if different from above. T40515 T40516 T40517 T40518 T40519 T40520 T40521 T40522 PBU L-103 50029231010000 202139 08/06/2002 SCHLUMBERGER USIT/TEMP/GR PDF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.03 08:26:36 -08'00' MEMORANDUM 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-05 PRUDHOE BAY UNIT PSI-05 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/24/2025 PSI-05 50-029-23174-00-00 203-139-0 W SPT 8028 2031390 2007 2148 2150 2150 2150 4 438 427 420 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-05 Inspection Date: Tubing OA Packer Depth 67 2915 2883 2877IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH241119160711 BBL Pumped:4.4 BBL Returned:4.4 Friday, January 24, 2025 Page 1 of 1 9 9 9 9 999 99 99 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.01.24 15:31:26 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Re DATE: Thursday, November 12, 2020 � P.I. Supervisor 1� I , — I � SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC PSI -05 FROM: Guy Cook PRUDHOE BAY UNIT PSI -05 Petroleum Inspector Src: Inspector Reviewed B P.I. Supry J NON -CONFIDENTIAL Comm I Well Name PRUDHOE BAY UNIT PSI -05 Insp Num: mitGDC201108063150 Rel Insp Num: API Well Number 50-029-23174-00-00 Inspector Name: Guy Cook Permit Number: 203-139-0 Inspection Date: 11/8/2020 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI-05,Type Inj w- TVD 8028 - Tubing 2116 2116 211721I7 PTD 2031390 ' Type Test SPT Test psi 2007 IA 80 2699 2680 2676 BBL Pumped: 4.4 BBL Returned: 3.9 OA 145 - 538 530 527 Interval 4YRTST WF P Notes: Testing completed with a triplex pump, a bleed tank and calibrated gauges. Thursday, November 12, 2020 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: - ❑ 2. Operator Name: BP Exploration (Alaska), Inc 14, Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number 203-139 3. Address: P.O. Box 198812 Anchorage, AK 99519-6612 Stratigraphic ❑ Service RI 1 6. API Number: 50-029-23174-00-00 7. Property Designation (Lease Number): ADL 028322 8 034631 8. Well Name and Number: PBU PSI -05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Total Depth. measured 10982 feet Plugs measured None feet true vertical 8680 feet Junkmeasured None feet Effective Depth: measured 10939 feet Packer measured 10309 feet true vertical 8638 feet Packer true vertical 8028 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 28-108 28-108 1490 470 Surface 5516 13-3/8" 28-5544 28-4603 3450 / 5020 1950/2260 Intermediate 10487 9-5/8" 25-10512 25-8223 5750 / 6870 3090 / 4760 Production Liner 593 7" 10389 - 10982 8105-8680 7240 5410 Perforation Depth: Measured depth : 10640 - 10865 feet True vertical depth: 8347-8567 feet Tubing (size, grade, measured and true vertical depth) 7-5/8" 29.7# x 7' 26#, L-80 23-10353 23-8070 Packers and SSSV (type, measured and 7" Baker SABL-3 Packer 10309 8028 true vertical depth) 7' Camco Al Injection Valve 2208 2196 12. Stimulation or cement squeeze summary. Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13_ Representative Daily Average Production or Injection Data Oil-BDI Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 100668 334 1800 Subsequent to operation: 0 0 80025 18 1800 14.Attachments:(Mgwmdper20MC25.07025.071.&252e3) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stretigraphic ❑ Copies of Lags and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ 0 WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NIA Authorized Name: Richards, Meredyth Contact Name: Richards Meredyth Authorized Title: Petroleum Engineer Contact Email: Meredyth.Richards0bp,com Authorized Signature: Data: 8 I2� I Contact Phone: +1 9075644867 Form 14404 Revised 0412017 R'0111 ,R' /2 11 • 'ter � r { "A MSS-' AUG 3 0 2019 Submit Original Only Daily Report of Well Operations PBU PSI -05 'WELL INJECTING ON ARRIVAL***(perforating) RAN 6.05" G -RING, TAG A-1 SSSV @ 2196' SLM (2208' MD) PULLED 7" A-1 SSSV FROM 2196' SLM (2208' MD). DRIFT W/ 12'x 3.16" DMY GUN, 12'x 3.66" DMY GUN, 7" TEL & S -BAILER (OAL 28' 6") & LOC PROBABLE T.T. @ 10,322' SLM (10,353' MD). RAN 40 ARM CALIPER FROM 10,326' SLM TO SURFACE. 7/13/2019 ***WELL LEFT S/I ON DEPATURE*** **'WELL INJECTING ON ARRIVAL*** (SLB ELINE ADPERF) INITIAL T/I/O = 0/150/350. MIRU & PT TO 3300 PSI. 'TR9TA=GHT PERFORATE 10,650'- 10,680' W/ 2-7/8" POWERJET OMEGA, 6 SPF, 60 DEG PHASE GUN. AND TEST TU 1OU HSI. 8/3/2019 CAP ON ***JOB CONTINUED ON 04 -AUG -2019*** ***JOB CONTINUED FROM 03 -AUG -2019*** (SLB El -INE ADPERF) STANDBY FOR WIND. STANDBY FOR STARTER TO BE REPLACED IN LOGGER. PERFORATE 10,640'- 10,650'W/ 2-7/8" POWERJET OMEGA, 6 SPF, 60 DEG PHASE GUN. LOGS CORRELATED TO SLB TEMPERATURE WARMBACK SURVEY DATED 03-U(; I - ALL 2009 RDMO. WELL S/I ON DEPARTURE. PAD OP NOTIFIED TO BRING ON INJECTION. 8/4/2019 ***JOB COMPLETE ON 04 -AUG -2019'** MME 7-1/16" 5K CW WffLF—E D =13 5/8" SK FMC ACTUATOR = 10/28/03RIGINAL Kg. gam/ = 45.30' BF: E -EV = 22.60' KDp= 1305' Max AnglB = 51 @ 3530' Datum MD = 10844' Datum TVTD= 85W SS PSI -05 13-018" CSG, 68#, K55, D =12.415' 1016' FROM 28' TO 1016' 13-3/8" CSG, 68#, L-80, D - 12.415- 5G CONTNUATION FROM 1016' TO 5544' F-518* TBG, 29.7#, L-80, .0459 bpi, D = 6.875" 10237' - Minimum ID = 5.770" @ 10340- 7" HES RN NIPPLE 9-5/8" CSG, 474H FT, S-95, D = 8.681" - 17" TBG, 26#, .0383 bpf, D = 6.276" 1 9-5/8" CSG, 47#, L-80, E = 8.681"10512' PERFORATION SUMMARY REF LOG: RST ON 10/25/03 ANGLE AT TOP PERF: 14^ @ 10640' 3-318^ 1 6 1 10826 - 10866 1 O 1 08/16104 FaTD 10939' ------------ 7' LNR 26#. L-80, .0383 bpf, D = 6276" 10982' SAI -t: l T NU I tJ: WtLL KC WUIKtS A JSS V- 13-3/8" CSG: 68# / K55 FROM 28' - 1016'; awe / 1 .an FRnM 1n11a "- fq' 22�-113-3/8" IAM FV KI I 207' XXO 208' 7" CAMCO DB NP, 1 21W 7" X 7-5/8" XO, D = 10237' 10248' 7" HES R NP, D = 5.963" 10270' PBR, D = 6.oso" 10309' 9-5/8" X 7' BKR SABL-3 PKR D = 10329' 7° HES R NP, D = 5.963" 10340' 7" HES RN NP, D = 5.770' 10353' 7'WLEG,D=6.276" BMD TT NOT LOGGED DATE COMMENTS DATE REV BY COMMENTS 10/28/03RIGINAL COMPLETION 1025103DD PERF 12/01/0413-3/8"CSGCORRECTION rCJSrrLP 0529/06SG CORRECTIONS (1124/04) 02110/11DDED SSSV SAFETY NOTE 08107/19ADPERFS (08/04119) PRUDHOE BAY UNIT WELL: PSI -05 PERMIT No: 12031390 API No: 50-029-23174 BP Exploration (Alaska) ~ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,November 21,2016 P.I.Supervisor 1 l q �C` (r� SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. PSI-05 FROM: Bob Noble PRUDHOE BAY UNIT PSI-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry�5rz NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT PSI-05 API Well Number 50-029-23174-00-00 Inspector Name: Bob Noble Permit Number: 203-139-0 Inspection Date: 11/15/2016 Insp Num: mitRCN161115135929 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well PSI-o5 7 Type Inj w-TVD 8028 ' Tubing 695 694 • 693 - 694 - PTD 2031390 - Type Test SPT Test psi I 2007 i IA 57 2597 - 2580 - 2576 Interval 4YRTST P/F P � OA 88 468 _ I 461 , 458 Notes: 17-T-0 fte-cLikx_5- TO-k- al4d-cite.d SCANNED JUN 0 72017 Monday,November 21,2016 Page 1 of 1 • M fJ M s`og18 off �I Q_ c. 1 'g fn / 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, March 17, 2016 6:15 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C WL Completions Superintendent; AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers,Jessica; Dickerman, Eric; Pettus, Whitney; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg, James B (DOA) Subject: OPERABLE:Injector PSI-05 (PTD #2031390) MIT-IA Passed All, Injector PSI-05 (PTD#2031390) was showing anomalous inner by outer annulus pressure trends while on water injection. A subsequent MIT-IA passed on March 14, 2016 indicating two competent barriers with no signs of inner annulus x outer annulus communication. The well has been reclassified as Operable and may remain on line as needed. Please call with any questions or concerns. Thank you, Kevin Parks SCANNED APR 0 4 2016 (Alternate: Whitney Pett, BP Alaska-Well Integrity Coordinator GW' Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, March 11, 2016 2:22 PM To: AK, OPS FS2 OSM; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS2 Field OTL; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C WL Completions Superintendent; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti 3; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Morrison, Spencer; Munk, Corey; Odom, Kristine; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION: Injector PSI-05 (PTO (31390) Inner by Outer Annulus Communication All, '\�� Injector PSI-05 (PTD#2031390) inner annulus (IA) pressure was increased to 750 psi on March 09, 2016. The final pressures after a 30 minute monitor period post increase were TBG/IA/OA= 1480/745/170 psi. On March 11, 2016 the pressures were confirmed to be TBG/IA/OA=430/760/400 psi indicating an outer annulus° rease of 230 psi.The well has been reclassified as Under Evaluation for additional diagnostics. 1 • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Friday, March 11, 2016 2:22 PM To: AK, OPS FS2 OSM;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS PCC EOC IL; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent;AK, D&C WL Completions Superintendent;AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Phillips, Patti J;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; Pettus, Whitney; Morrison, Spencer; Munk, Corey; Odom, Kristine; Regg,James B (DOA) Subject: UNDER EVALUATION:Injector PSI-05 (PTD #2031390)Inner by Outer Annulus Communication All, Injector PSI-05 (PTD#2031390) inner annulus (IA) pressure was increased to 750 psi on March 09, 2016. The final pressures after a 30 minute monitor period post increase were TBG/IA/OA= 1480/745/170 psi. On March 11, 2016 the pressures were confirmed to be TBG/IA/OA=430/760/400 psi indicating an outer annulus increase of 230 psi.The well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: MIT-IA to 2500 psi 2. Downhole Diagnostics: Monitor pressures for 3 to 5 days 3. Well Integrity Engineer:Additional diagnostics as needed Please call with any comments or concerns. Thank you, Whitney Pettus SCANNED APR 0 4 2016 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ () ~ - t ~ ç¡ Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 ~CAN DIGITAL DATA Color Items: ~iskettes, No. I ~reyscale Items: \ ~ o Other, NofType: o Poor Quality Originals: o Other: NOTES: BY: ~ Date: c¡ I J g / t) ft:; Project Proofing BY: ~ Date: q II f6 / {)fP r Scanning Preparation ¿ x 30 = 1(1() + BY: ~ Date:Cf II ~ 100 Production Scanning Stage 1 (oJ (Count does include cover sheet) VVES NO Page Count from Scanned File: BY: Page Count Matches Number in Scanning Preparation: .~ Date: q / IB /Dfp Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Date: Maria Comments about this file: o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: vvtP 151 1111111111111111111 151 MP = TOTAL PAGES far? (Count does not include cover sheet) 151 MP 111111111111111111I 151 MP YES NO 151 1111111111111111111 11111111111I11 1111I 151 Quality Checked 11I111111111111111I 10/6/2005 Well History File Cover Page. doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 ; 444 ' * $ Anchorage, Alaska 99519 -6612 December 21, 2010 14 J A fir` ", Mr. Tom Maunder Oil and Gas Conservation Commission :tJ 333 West 7 Avenue Anchorage, Alaska 99501 44, "-" , Pn. 2 13%" `AmSA 'r SiOfl ' 91 re- tit~ Subject: Corrosion Inhibitor Treatments of GPB PSI Dear Mr. Maunder, ps1-06 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 gal PSI -01 2021450 50029231040000 NA 1 NA 5.10 10/25/2010 P SI - 05 2031390 50029231740000 NA 1 NA 5.95 10/24/2010 PSI -06 2020790 50029230820000 NA 12.3 NA 45.90 10/25/2010 PSI -07 2031480 50029231770000 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 Alaska VII at u cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date BL Color CD MPI -13 AWJI- 00055I 6 10/18/09 1 1 MPC -07 AXBD -00057 MEM PROD PROFILE –i 1 MIPS,. 10/24/09 1 1 04 -11A AWL8 -00040 11:1140i[01:11:1: N4144 vragrL miy J�+ iyea 10/24/09 1 1 V -220 AYS4 -00100 INJECTION PROFILE T alie 4 10/04/09 1 1 L -220 B1JJ -00035 MEM INJ PROFILE REVISED I; 07/30/09 1 1 V- 221 AXBD -00037 MEM INJ PROFILE REVISED .0 ac -6/3 /09 „G 07/28/09 1 1 L -214A AP30 -00064 INJ PROFILE/RST (fro a(s(o nab 9, n 10/06/09 1 1 S -22B AYTU -00052 INJECTION PROFILE ii i 10/27/09 1 1 14 -07 B581-00016 PROD PROFILE i r M�1111.1.111.11 10/27/09 1 1 07 -05 AYS4 -00105 SCMT ZEMKIIIIIIIIIIIJTrZFA 10/28/09 1 1 R -28 AWL8 -00041 ®jjpErm jC 10/26/09 1 1 2- 08/K -16 AZCM -00046 PRODUCTION PROFILE Of /199e" 10/30/09 1 1 PSI -05 B14B -00080 TEMP WARMBACK SURVEY (1ZC a03 /1 .5 11/03/09 1 1 C -128 B2WY -00030 MCNL 0 09/19/09 1 1 U-05A 09AKA0074 1d :1 S S% /101 1)14)I aggi' -D ram 08/19/09 2 1 01 -18A 09AKA0151 OH MWD/LWD EDITMP=�, 08127/09 4 1 ill H -09 ANHY -00110 RST t f' r I_ 09/20/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 /1 P T r r i' w 200' .1( f • • ~~ Date: 08-27-2009 Transmittal Number:93091 ~ ~ ~ .s BPXA WELL 17ATA TR AN~MTTTA i. HUGHES MONITOR GASVIEW SATURATION ANALYSIS BAKER INTERPRETATION OF RPM M-04 08-25-2008 HUGHES DATA CD-ROM - RPM/GSA PRM BAKER META, LAS, AND PDF M-04 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE R-12 08-20-2008 HUGHES f iQ200 10800 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW R-12 01-28-2009 HUGHES 1 10295 10818 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM R-12 08-20-2009 HUGHES DATA CD-ROM - RPM/GSA PRM BAKER META, LAS, AND PDF R-12 08-19-2009 HUGHES FORMAT BAKER RESERVOIR PERFORMANCE PSI-05 08-23-2008 HUGHES 1 10450 10886 MONITOR RESERVOIR PERFORMANCE BAKER MONITOR GASVIEW PSI-05 01-29-2009 HUGHES 1 10552 10870 SATURATION ANALYSIS BAKER INTERPRETATION OF RPM PSI-05 08-23-2008 HUGHES DATA CD-ROM - RPM/GSR PRM ~ BAKER META, LAS, AND PDF PSI-05 08-19- 9 HUGHES FORMAT ~ ~' / yj Please Sign an eturn one copy of this transmittal. Thank You, Joe Lastufka Petrotechnical Data Center ~ , ~~~. v wa~;..r . - ~ ~ ~~ ~ `~ ConocoPhillips Exxon DNR AOGCC Sandy Lemke File Room Corazon Manaois Christine Mahnken Petrotechnical Data Center LR2- l 900 E. Benson Slvd. PO Box 196612 Anchorage, AK 99519-6612 ~~ . • BP Alaska Interpretation of RPM Data Well: PSI-05 Field: Prudhoe Bay Report Status: Final Report Authors: Yonghwee Kim and Rafay Ansari Reviewed: David Chace Logged Date: 23rd Au ust 2008 Report Date: rd August 2009 ri~~ BAKER HUGHES Baker Atlas ~ ~ti~~i ~~~. . ~ ,~ .~f~ ~ ~~ _= z~~~ , , ~~; ~ ~ ~~~~~~~ t r >-~~ ~~~ ti~ : ~ ~~ ~m~~~ }~~~ ~ ~~ ~~ ~;~;~;~ : ~ ~: ~: ~ .~t ~~ ~. ~ ~~ . ,;tls ~ - t' ~''~'`'~.`~. . .. ._ "a ; ~, ~ (.) `s~ 2~3 - ~13 i ~ ~ ~ . ~ IN MAKING INTERPRETATIONS OF LOGS OUR EMPLOYEES WILL GIVE THE CUSTOMER THE BENEFIT OF THEIR BEST JUDGEMENT, BUT SINCE ALL INTERPRETATIONS ARE OPINIONS BASED ON INFERENCES FROM ELECTRICAL OR OTHER MEASUREMENTS WE CANNOT AND DO NOT GUARANTEE THE ACCURACY OR THE CORRECTNESS OF ANY INTERPRETATION. WE SHALL NOT BE LIABLE OR RESPONSIBLE FOR ANY LOSS, COST, DAMAGES, OR EXPENSES WHATSOEVER INCURRED OR SUSTAINED BY THE CUSTOMER RESULTING FROM ANY INTERPRETATION MADE BY ANY OF OUR EMPLOYEES. ~ ~ BP Alaska - Prudhoe - Well PSI-05- RPM Satu n Analysis ~ Page i CONTENTS 1 INTRODUCTION 1 1.1 Objectives 1 1.2 Results 1 1.3 Data Set 1 1.4 Sequence of Events 1 2 ANALYSIS AND INTERPRETATION 2 2.1 RPM Overview 2 2.2 GasView Analysis Methodology 2 ~ 3 DATA DISCUSSION 5 3.1 GasView Analysis and Discussion 5 RPM REFERENCES 8 LIST OF TABLES AND FIGURES Table 2.1 Parameters Used for Input to GasView Modelling Figure 2.1 GasView Response Chart Figure 2.2 Example of GasView Results Figure 3.1 Processed GasView Results ~ ~ Baker Hughes Inc. ~ BP Alaska- Prudhoe - Well PSI-05- RPM Satu-n Analysis - Page 1 1 INTRODUCTION (Source: BP Logging Program) PSI-05 is a gas cap water injector in the gas cap area. • Current Status: Gas Cap Water Injector • Last Test: 102,596 BWPD at 1921 psig on 07/30/08 • Deviation: Max deviation is 51 °@ 3530' MD Angle at top perfs = 13° @ 10826' MD • Last TD Tag: 07/28/2005 @ 10897' MD • Last Well Op.: 07/30/2008; Test Event. Inj. Pressure 1,921 psi; SW Vol: 102,596 • Min. Restriction: 5.770" ~ 10,340'; 7" HES RN Nipple • H2S Info: Not available • Tie In Log: RST on 10/25/2003 1.1 Objectives ~ This RPM surveillance will provide a quantitative estimate of the gas saturation after water flood, which will help the Major Gas Sale project planning and the Prudhoe Full Field Model calibration. Through comparison with the historical log data of the well, we will have a better understanding of the capacity and limitation of this improved pulsed neutron log tool. 1.2 Results • The RPM data was of very good quality and repeatability, and an analytical resuit of good confidence has been achieved. • By utilizing GasView methodology, a gas saturation curve (Sg) has been calculated while two water saturation curves (Sw and Sw_HT) provided by BP have been displayed for comparison. • In ivishak interval, analysis shows low gas saturations around (20-40%) indicating that the formation is mostly filled with liquid. 1.3 Data Set This well was logged on 23rd Aug 2008. The RPM data has been recorded through 7inch casing and 8.5inch borehole section. Three passes were recorded at 10 ft/min. The GasView passes were recorded with a source output of 800,000 cps (counts per second). ~ 1.4 Sequence of Events • Log was correlated to SWS/RST (reference log) DATE 25th Oct 2003. • Log started at 17:30 on 23rd Aug 2008 and finished at 22:30 on the same day. • The top logged interval was 10,450 ft and the bottom logged interval was 10,888 ft. • Baker Hughes Inc. ~ BP Alaska - Prudhoe - Well PSI-05- RPM Satur ion Analysis Page 2 2 ANALYSIS AND INTERPRETATION 2.1 RPM Overview The Baker Atlas RPM is a pulsed neutron instrument capable of acquiring data in several modes. PNC (Pulsed Neutron Capture) data is used to evaluate the formation saturation in known high salinity formations and to identify gas, while C/O (Carbon/Oxygen) is used to evaluate the formation saturation in low- or unknown-salinity formations. Further to the water saturation calculation modes the tool can also be operated in AFL (Annular Flow Log) mode to quantify water velocity in both continuous passes and stations. Also, borehole holdup can be calculated utilizing the PNHI (Pulsed Neutron Holdup Indicator) mode; this is particularly useful in horizontal or highly deviated wells where the accuracy of conventional production logging instruments is greatly reduced. More recently, the modified RPM-C tool has allowed us to carry out gas saturation analysis ( GasViews"" ) analysis from three detector PNC data. ~ 2.2 GasView Analysis Methodology ~ Baker Atlas has enhanced the Reservoir Performance Monitor (RPM) service by introducing three features: improved instrumentation, a new characterization, and advanced interpretive techniques. The GasView service utilizes the improved resolution of the RPM-C tool, a new gas response characterisation, and a new petrophysical algorithm to deliver a better method for identifying gas and measuring gas saturation. The three detector RPM-C instrument allows gas detection ratios to be taken over longer spacing than conventional instruments. These new measurements are substantially more sensitive to the change in neutron-gamma distribution that indicates a change from liquid to gas-filled porosity. This improved sensitivity allows the instrument to resolve the presence of gas where conventional instruments cannot, and it provides better resolution in the gas saturation calculation. Characterization of tool response allows more accurate quantification of saturation. A global tool response characterization database has been constructed for standard open hole and cased hole completions. This includes varying combinations of mineralogy, fluid density, and gas pressure/density. The following table states the parameters which have been used in the modelling of the predicted curve response for Prudhoe well PSI-05. Table 2.1 Parameters used in GasView modelling of well PSI-05 Parameter Value Borehole Size 8.5 inch Casin Size 7.0 inch Borehole Fluid Water Matrix T e Sandstone Gas Densit 0.26 /cc Oil Densit 0.8 /cc Water Densit 1.00 /cc A GasView job planner is available to design optimal logging programs. The following chart shows the expected response of the RIN13 curve (this chart is an example only and not relevant to this specific case of well PSI-05. I • Baker Hughes Inc. ~ ~ Della Sigma vs Formation Porosiry ~ DePa Sigma vs Formation Wa1ea Salinity ~ Gas CoeFfiaent File Inpul Gas Chart I Ratio: Pbt DUectac degreed R - gas chatls ~ 1~3 ~ I" ~ B j Badnb 14ad dxrciUy Famation IAid dansiry. Fo~rtalcn pu densip~ [Q 9 0.10 0.69 0.69 ~~ 10^ Pm1/E~rl i RIN wet I • ~ BP Alaska - Prudhoe - Well PSI-05- RPM Satura ion Analysis Page 3 ~ gas Porosity 0.00 0.05 0 10 0.15 0.20 025 0.30 0 35 0.40 OK Cancal _J Figure 2.1 GasView Response Chart The Dynamic Gas Envelope (DGE) interpretation explicitly accounts for variations in porosity and shale volume in the saturation result. While these effects must be removed from the saturation solution, they are included in the visual DGE representation for greater insight into the processing. See example GasView results below. For results of well PSI-05, see section 3.1. I ~ Baker Hughes Inc. ~ BP Alaska- Prudhoe - Well PSI-05- RPM Saturation Analysis Page 4 EXAMPLE We t side of DG E Gas side Measured curve of DGE used fo r gas analysis i GAS-Curve departure from the wet side f the DGE indi th n t f e prese o ca es ce o gas, and the degree of departure indicates ~ the gas saturation. , WET-The measured curve moving along the wet side of the emelope indicates h b f e a sence o gas. t ~ r , i ~ I, The correspondence of the measured curve and the OGE water line in wet zones is an I indicator of the integrity of the interpretation , and the validiry of the porosity ca~ulations. i ~ -- __ __ . . Figure 2.2 Example of GasView Results Baker Hughes Inc. ~ BP Alaska - Prudhoe - Well PSI-05- RPM Saturation Analysis Page 5 3 DATA DISCUSSION 3.1 GasView Analysis and Discussion A GasView analysis has been carried out using the three passes logged on the 23rd Aug 2008. All passes were recorded at 10 ft/min with a source output of 800,000 cps. All the passes have been shifted on depth using open hole GR provided by BP. All data looks to be of good quality and repeatability. Curves from three recorded passes have been averaged to create one final data set to be used for analysis. A result of good confidence has been achieved. The pre-modelling software for GasView uses a number of lab test calibration points, these lab tests are carried out using pure quartzite for a sandstone environment and tombstone marble for limestone environment. It is very unlikely that this type of matrix would be present down hole therefore a single value calibration is made to the RIN13 curve to correct for material differences in the matrix. This parameter should be used to normalize the RIN13 curve in a zone of known saturation. ~ In the process of the GasView analysis, RIN13 normalization value was used as -1 and the shale calibration value was 75. Also, note that the pick up depth is 10,870ft based on the BKS change (BKS- short spaced background countrate). The results of this analysis can be observed on Figure 3.1. The presented results are analyzed with formation gas density of 0.26 g/cc and volumetrics provided by BP. The results show the Dynamic Gas Envelop (DGE explained in section 2.2) overlaid with the normalized RIN13 curve. The position of the RIN13 curve between the Gas line (red) and the Liquid line (blue) of the DGE determines the gas saturation. The figure shows how the measured curve moves between the liquid and gas lines and the resulting gas saturation curve (Sg). The open perforation interval (10,826-10,864 ft) was used for wet zone normalization since the well was under injection while logging. Shale calibration was performed using the tool response from 10,820- 10,826 ft. As seen on Figure 3.1, gas saturation for sand intervals ranges from 20-40%. The RIN13 value drops at 10703 ft resulting in higher gas saturation. However, this increase of gas may not be real since it is located right on the bed boundary and the volume of siderite is spiking. There is a casing collar at 10,701 ft as well. ~ • Baker Hughes Inc. ~ BP Alaska - Prudhoe - Well PSI-05- RPM Saturation Analysis Page 6 ~~ I • FLUID H'Ef-G~5 EM+ELaPE FLU16 G4S ~ ,•G~'= IFJG1~:,=SI~7hJ. ..SAN6~ PduRM CbNG SI D ' V5H ..+~ ~.. r..w..~.~y.,,.~ CB~ i~AIAMA R,'~Y j0,%H ~ n :-~ CCL Gas Saturation u~ uNE ENV~~FE ~ ic;, - -~'. ~ -_ . . - T~TAL POROSffY G4~1h1A RAY fRPM-C3 r F ~~ 5we: BP 'NET LJNE ENVELQPE EFFECTIVE POROSITY i;~"-kPl i E~fECIhfI~iC91Y ~ ;~_J-+T, BJ NORbt4uZEC ~'~c~, ;~ ' (cps} ~ - 0 a 4 I ~ Baker Hughes Inc. BP Alaska - Prudhoe - Well PSI-05- RPM Saturation Analysis Page 7 .. _ .. ......... ........ ........ ......... ...... ....., - .•?~ :.i . .•~ .:'~ _-- ---- _ :.~ ! S =_ = =-= = - _ ~ ~ •. ..... :.i ::"i _ ~,~ Figure 3.1 Processed GasView Results Baker Hughes Inc. • BP Alaska - Prudhoe - Well PSI-05- RPM Satu~ n Analysis ~ Page 8 RPM References Chace, D.M., Trcka, D.E., and Dawe, B.A., "Application and interpretation of continuous oxygen activation logs for measuring complex water flow profiles in injection wells," SPE 69th Annual Technical Conference and Exhibition, New Orleans, Louisiana, Paper 28412, 1994. Trcka, D., van den Berg, F., Manan, W.A., Peeters, M., and Mickael, M., "Measuring three-phase holdups in horizontal wellbores using pulsed neutron instruments," SPE Annual Technical Conference and Exhibition, Denver, Colorado, Paper 36561, 1996. Gilchrist, W.A. Jr., Prati, E., Pemeper, R., Mickael, M.W., and Trcka, D., "Introduction of a New Through- Tubing Multifunction Pulsed Neutron Instrument," SPE paper 56803, Annual SPE Technical Conference and Exhibition, Houston, Texas, Oct. 1999. Trcka, D.E., and Chace, D.M., "Improved method for measuring annular water flow in injection wells ~ using continuous oxygen activation logging," SPE 68th Annual Technical Conference and Exhibition, Houston, Texas, Paper 26450, 1993. Chace, D.M., Trcka, D.E., Wang, J., Bousche, O., van der Spek, A., al Nasser, H., "A new production logging service for horizontal welis," SPWLA 39th Annual Symposium, Keystone, CO, 1998, Paper N. Mickael, M.W., Trcka, D.E., Pemper, R., "Dynamic Multi-Parameter Interpretation of Dual-Detector Carbon/Oxygen Measurements", SPE Annual Technical Conference and Exhibition, Houston, Texas, Oct. 1999. Chace, D., Trcka, D., Georgi, D., Wang, J., Bousche, O., van der Spek, A., al Nasser, H., "New instrumentation and methods for production logging in multiphase horizontal wells," SPE MEOS, Bahrain, Paper 53220, 1999. David Chace, Jianrong Wang, Roman Mirzwinski, Jorge Maxit, and Darryl Trcka, "Applications of a New Multiple Sensor Production Logging System for Horizontal and Highly-Deviated Multiphase Producers", SPE paper 63141, Annual SPE Technical Conference and Exhibition, Dallas, Texas, October, 2000. Trcka, D., Oliver, D., Mickael M., Chace, D., Georgi, D., and Wang, J., "Reservoir performance monitoring in the new millennium", Proceedings of the Tunisian Oil Conference, April, 2000. Riley, S., Guivarch, B., Chace, D.M., Trcka, D.E., Clark, J., "Production logging in horizontal gravel- packed highly viscous oil producers in the North Sea", SPE Annual Technical Conference and Exhibition held in Denver, Colorado, Oct. 2003. ~ ~ Baker Hughes Inc. I~EIVI® ~~ ~ State ®~' Alaska • Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, November 26, 2008 Jim Regg P.LSupervisor ~ 2C-c7 (~/~~~`t~SUBJECT: Mechanical Integrity Tests t BP EXPLORATION (ALASKA) INC PSI-OS FROM: C11UC1{ SC11eVe PRUDHOE BAY LNIT PSI-OS Peh•oleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~;= Comm Well Name: PRUDHOE BAY UNIT PSI-OS Insp Num: mitCS08 1 12507 1 221 Rel Insp Num: API Well Number: 50-029-23174-00-00 Permit Number: 203-139-0 Inspector Name: Chuck Scheve Inspection Date: 11/24/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I Pst-os Type Inj ~ `N ~ TVD I eo2g ~ IA ~~ o ~ ztzo y zloo zloo P T 2os I39o TypeTest I SPT I Test psi '_ zoo? p sso 900 ~ 900 ~ 90o j _ _ __ Interval dYRTST P/F P / Tubing ` tz6o 2 ~ Iz6o ! Iz6o - Notes: _ Wednesday, November 26, 2008 Pale I of 09/16/08 l ~~r~Ml'mb~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Woll Inh ~ ~. ~ NO.4881 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 14-186 11978479 MEM GRADIOMANOMETER LOG _I g. 08/24/08 1 04-28 11968951 LDL (REVISED) /~ = 06/29/08 1 1 R-12 12066544 MEM FLUID PROPERTIES LOG ~ 1(c o8/2oio8 1 1 PSI-05 12103673 MEM DENSITY LOG 08/23/08 1 1 05-35 11962620 USIT j .. (p 08/26/08 1 1 B-36 12017516 USIT j ~ 09/03/08 1 1 V-207 12057639 USIT D - 08/11/08 1 1 Z-19A 40013908 OH MWD/LWD EDIT - - - / 09/10/06 3 1 12-28A 11962607 RST - U 07/01/08 1 1 B-12A 11998993 RST v 03/05/08 1 1 V-207 12057639 CH EDIT (USIT) 08/11/08 1 DI CACC Al~IlLif1\1111 CI'\/~C 11C /~CInT n _-_____.__...._..___~.~..~~~.. ~. v........... .-...v IIGI VI11~ll~u VI~G VVrI Gl1Vfl IV: BP Exploration (Alaska) Ina ~ ,,k Petrotechnical Data Center LR2-1 ~ FI ~f~ ~ y' 900 E. Benson Blvd. ~' Anchorage, Alaska 99508 ~; `;~ .,i Date Delivered: •-- ~~ ~ ~~ '~7(1i§ 1.~rll ~.. ~,~~ G , ,~C,I~, ~';~. Alaska Data & Consulting Services 2525 Gambell Street, to 400 Anchorage, AK 950 - 38 ATTN: Beth Received by: C i3 • -~-°~ -- ,~ ~' ~. ~~ ~: ;; ~~~ "r MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc I~ v¡r DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2031390 Well Name/No. PRUDHOE BAY UNIT PSI-OS Operator BP EXPLORATION (ALASKA) INC -~----~ MD 10982/ TVD 8680 ,,/ Completion Date 8/16/2004"'-- Completion Status 1WINJ-= Current Status 1WINJ REQUIRED INFORMATION Mud Log No s.,~ /).l¡J~.> API No. 50-029-23174-00-00 ~ ~_.,~m..__~_ Samples No Directional Survey ~~___ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, PWD, US IT, RES, NEU, DEN Well Log Information: Log/ Electr Data Digital Dataset Type"" Med/Frmt Number Name Ie C.....Ú I 128"" Re,e",,;, S,,",,t;," I~ Temperature I ~g Cement Evaluation ~g Casing collar locator ~ D Directional Survey \ ~t Directional Survey ~ /fog 12392 -'Reservoir Saturation Log Reservoir Saturation ~og Temperature ,/ Log 12392 /Reservoir Saturation I ,V" C Las 1239Y Reservoir Saturation / I =D C Pds 12391 Reservoir Saturation I (data taken from Logs Portion of Master Well Data Maint OH/ CH Received Comments Case 10/22/2004 RST FOR SIGMA MODE/GRlCCUDSN 12835 7980 10895 Case 3/28/2006 Temperature Warmback Survey PBMS/GR/CCLITEMPERA TURE/PRESSURE 28 July 2005 Log Log Run Scale Media No 1 Interval Start Stop 10480 10881 Blu 5 Col 9490 10499 Case 10/18/2003 9490 10499 Case 10/18/2003 213 10908 10/24/2003 213 10908 10/24/2003 0 10882 Case 1/30/2004 0 1 0882 Case 1/30/2004 0 10882 Case 1/30/2004 0 10882 Case 1/30/2004 10500 1 0883 Case 1/30/2004 10500 1 0883 Case 1/30/2004 5 COI Blu 25 Blu 25 Blu 5 . --1 Ultra Sonic Imaging Tool Gamma Ray/CCL Ultra Sonic Imaging Tool Gamma Ray/CCL Schlumberger & Anadrill reports Schlumberger & Anadrill reports . RST Sigma Log, Temperature Survey & Jewelry Log RST Sigma Log, Temperature Survey & Jewelry Log RST Sigma Log Temperature Survey & Jewelry Log Reservoir Saturation Tool RST-C/Sigma Mode Reservoir Saturation Tool RST-C/Sigma Mode DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Permit to Drill 2031390 Well Name/No. PRUDHOE BAY UNIT PSI-OS Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23174-00-00 MD 10982 TVD 8680 Completion Date 8/16/2004 Completion Status 1WINJ Current Status 1WINJ UIC y I~ Reservoir Saturation 5 Blu 10500 10883 Case 1/30/2004 Reservoir Saturation Tool I RST-C/Sigma Mode ¡ I ED C Las 12393 ~ Density 10500 10982 Case 1/30/2004 Vision Density Neutron i 12393'" Neutron Case 1/30/2004 Vision Density Neutron ~ C Las 10500 10982 : ED C Pds 1239:Y Density 25 10500 10982 Case 1/30/2004 Vision Density Neutron I ED C Pds 12393' Neutron 25 10500 1 0982 Case 1/30/2004 Vision Density Neutron . I ci !1(g Density 25 Blu 10500 10982 Case 1/30/2004 Vision Density Neutron ):'Óg Neutron 25 Blu 10500 10982 Case 1/30/2004 Vision Density Neutron lED C Las 12393 - Induction/Resistivity 25 10500 10982 Case 1/30/2004 Vision Resistivity ~ C Las 12393-- Rate of Penetration 25 10500 10982 Case 1/30/2004 Vision Resistivity C Pds 12393- Induction/Resistivity 25 10500 10982 Case 1/30/2004 Vision Resistivity ED C Pds 12393<' Rate of Penetration 25 10500 10982 Case 1/30/2004 Vision Resistivity -j..e( Induction/Resistivity 25 Blu 10500 10982 Case 1/30/2004 Vision Resistivity Log Rate of Penetration 25 Blu 10500 1 0982 Case 1/30/2004 Vision Resistivity -t'ê'g Cement Evaluation Blu 9490 10499 Case 5/3/2004 ULTRASONIC IMAGING TOOLlGRlCCL ¡'::D C 12749 /Reservoir Saturation 10486 10883 Case 1 0/15/2004 LDWG RST SIGMA MODE /"Log 12749/ Reservoir Saturation Blu 10550 10883 Case 1 0/15/2004 LDWG RST SIGMA MODE ED C Pds 12835 Reservoir Saturation 1 0480 10881 Case 1 0/22/2004 RST FOR SIGMA ~ MODE/GRlCCLlDSN 12835 . ~ Reservoir Saturation 5 Blu 10480 10881 Case 1 0/22/2004 RST FOR SIGMA MODE/GR/CCLlDSN 12835 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments Permit to Drill 2031390 MD 10982 TVD 8680 ADDITIONAL INFORMATION Well Cored? Y /~ ~ Chips Received? Y / N ~ Analysis Y / N Received? Comments: --~.._.. Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 9/11/2006 Well Name/No. PRUDHOE BAY UNIT PSI-OS Operator BP EXPLORATION (ALASKA) INC Completion Date 8/16/2004 Completion Status 1WINJ Daily History Received? Formation Tops ~ API No. 50-029-23174-00-00 Current Status 1WINJ ú:J/N é}N Date: UIC Y I) ~C-~-~ . . " . STATEOFALASKA . ALAS~ AND GAS CONSERVATION COM ION 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: 3838' NSL, 4465' WEL, SEC. 15, T11N, R15E, UM Top of Productive Horizon: 2520' NSL, 3293' WEL, SEC. 09, T11N, R15E, UM Total Depth: 2591' NSL, 3348' WEL, SEC. 09, T11N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 707940 y- 5966139 Zone- ASP4 TPI: x- 703716 y- 5969986 Zone- ASP4 Total Depth: x- 703659 y- 5970056 Zone- ASP4 18. Directional Survey 181 Yes 0 No 21. Logs Run: MWD, GR, PWD, USIT, RES, NEU, DEN 22. One Other Gas Cap Injection 5. Date Camp., Susp., or Aband. 8/16/2004 6. Date Spudded 9/12/2003 7. Date T.D. Reached 9/25/2003 8. KB Elevation (ft): 45.3' 9. Plug Back Depth (MD+ TVD) 10898 + 8598 10. Total Depth (MD+TVD) 10982 + 8680 11. Depth where SSSV set 2208' MD 19. Water depth, if offshore N/ A MSL WT.PËR FT. 91.51# 68# 40# /47# 26# CASING, liNER AND CEMENTING RECORD SETTINGDEf>THMD SETTING DEPTH TVD HPL,E BOTTOM I OP BOTTOM SIZE 114' Surface 114' 42" 5544' 28' 4603' 16" 10512' 25' 8223' 12-1/4" 10981' 8104' 8679' 8-1/2" CASING SIZE 20" x 34" 13-3/8" 9-5/8" H-40 L-80 L-80 L-80 Surface 28' 25' 10388' 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3-3/8" Gun Diameter, 6 spf MD TVD MD TVD 10826' - 10866' 8528' - 8567' 26. Date First Production: November 19,2004 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ........ Press. 24-HoUR RATE""" 24. SIZE 7",29.7#, L-80 Revised: 12/02/04, Put on Injection 1b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 203-139 13. API Number 50- 029-23174-00-00 14. Well Name and Number: PBU PSI-OS 15. Field I Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 034631 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMEN1'II(3RECORO 260 sx Arctic Set (Approx.) 1436 sx ArcticSet "' Lite, 600 sx 'G" 435 sx Class 'G', 585 sx Class 'G' 168 sx Class 'G' TUBING RECORD DEPTH SET (MD) 10353' PACKER SET (MD) 10309' 25. AClD,F'RACTURE, CEMENT$('.IUEgE,ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 144 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oll-Bsl GAs-McF WATER-Bsl Oll-Bsl 27. GAs-McF W A TER-BSl 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 chips; if none, state "none". None Form 1 0-407 Revised 12/2003 OR!GIf~AL CONTINUED ON REVERSE SIDE RBDMS BFl DEC 0 7 2004 , l:t( ú ,2'8. GEOLOGIC MARKER. 29. .RMATION TESTS 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". HRZ 10338' LCU / Top Sadlerochit 10552' Zone 3 10592' Zone 2C 10628' Zone 2B 10682' Zone 2A 10765' Zone 1 B 10820' Zone 1A 10854' Base of Sadlerochit / TKVK 10925' 8056' None 8262' 8301' 8336' 8388' 8469' 8522' 8555' 8625' 30. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ ~ Title Technical Assistant Date 'J.j Q:::t(DL{ PBU PSI-05 203-139 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Rob Tirpack, 564-4166 Permit No. / 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 Submit Original Only MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 0' tt)(), \ vi I \D 4' P.I. Supervisor I \é -ll \ DATE: Monday, November 29, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC PSI-05 PRUDHOE BAY UNIT PSI-05 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .:JB.e.. Comm Well Name: PRUDHOE BAY UNIT PSI-OS Insp Num: mitJCr041129093 123 ReI Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-23174·00-00 Permit Number: 203-139-0 Inspector Name: John Crisp Inspection Date: 11/26/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well PSI-05 IType Inj. P TVD 8028 IA 0 2100 2050 2050 P.T. 2031390 TypeTest SPT Test psi 2007 OA 260 560 560 560 Interval INITAL P/F P Tubing 2050 1740 1820 1970 Notes: I monitored the IA pressure for an hour while well was injecting. The IA remained 0 while monitoring. I didn't think a higher than required test pressure on IA was necessary due to the stable pressure of 0 while well was injecting. The tubing pressure was swinging during MIT because of injection rates. Monday, November 29, 2004 Page I of 1 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Icf-'.· 15-13A <il- _ E-20 ')'II-D 1918-33A ?:., ..{~SI-05 \L2032 '7 ... L2-32 ~ 7 L2-32 L2-32 ~ _<;-400 fA W-400 -400 Well f Job # 10913854 10866600 10861918 10830793 10687661 10672377 10912982 10687650 40009731 10621738 10621779 2¿ì3 .J 13 ? 10/21/04 NO. 3238 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 10/04/08 1 10/01/04 1 06/21/04 1 1 04/25/04 1 1 01/02/04 1 1 04/28/04 1 1 09/06/04 1 1 09/22/03 1 1 10/21-26/03 2 1 10/28/03 6 1 05/05/04 1 SCMT US IT MCNL RST-SIGMA RST-SIGMA RST -SIGMA RST-SIGMA RST·SIGMA OH EDIT MWD DATA OH EDIT AIT/BHC/PEXl6 ARM CALIPER USIT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ~~~rn::£, ';%: /. / r Reœ"e~ .~ /~~.¡ Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . m.''if,¡DS 15-13A I Vl- . E-20 ~df-() ð>18-33A }lJ'!J~.. . SI-05 L2-32 Mi ~ L2-32 I '!I 1 L2-32 L2-32 Zrß ~<;-400 I fA W-400 -400 Well Job# 10913854 10866600 10861918 10830793 10687661 10672377 10912982 10687650 40009731 10621738 10621779 10/21/04 NO. 3238J..D3-".~ Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay - Log Description Color Date Blueline Prints CD 10/04/08 1 10/01/04 1 06/21/04 1 1 04/25/04 1 1 01/02/04 1 1 04/28/04 1 1 09/06/04 1 1 09/22/03 1 1 10/21-26/03 2 1 10/28/03 6 1 05/05/04 SCMT USIT MCNL RST-SIGMA RST-SIGMA RST -SIGMA RST -SIGMA RST-SIGMA OH EDIT MWD DATA OH EDIT AIT/BHC/PEXl6 ARM CALIPER US IT . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /~~1 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 :'-:":£K ';7;:/ /r Reœ"e~ .~ · STATE OF ALASKA , ALASKA OiL AND GAS CONSERVATION COMMIsSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~ J 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ B 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: 3838' NSL, 4465' WEL, SEC. 15, T11N, R15E, UM Top of Productive Horizon: 2520' NSL, 3293' WEL, SEC. 09, T11N, R15E, UM Total Depth: 2591' NSL, 3348' WEL, SEC. 09, T11N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 707940 y- 5966139 Zone- ASP4 TPI: x- 703716 y- 5969986 Zone- ASP4 Total Depth: x- 703659 y- 5970056 Zone- ASP4 18. Directional Survey BYes 0 No 21. Logs Run: MWD, GR, PWD, USIT, RES, NEU, DEN 22. One Other Gas Cap Injection 5. Date Camp., Susp., or Aband. 8/16/2004 6. Date Spudded 9/12/2003 7. Date T.D. Reached 9/25/2003 8. KB Elevation (ft): 45.3' 9. Plug Back Depth (MD+ TVD) 10898 + 8598 10. Total Depth (MD+TVD) 10982 + 8680 11. Depth where SSSV set 2208' MD 19. Water depth, if offshore N/A MSL GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MP SeTTING DeþTH TVO lOP BOTTOM Top BOTTOM Surface 114' Surface 114' 28' 5544' 28' 4603' 25' 10512' 25' 8223' 10388' 10981' 8104' 8679' 20" x 34" 13-3/8" 9-5/8" 91.51# 68# 40# 147# 26# 7" 23. Perforations op'en to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 3·3/8" Gun Diameter, 6 spf MD TVD MD TVD 10826' - 10866' 8528' - 8567' 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 42" 16" 12-1/4" 8-1/2" 24. SIZE 7",29.7#, L-80 25. 1 b. Well Class: o Development 0 Exploratory o Stratigraphic B Service 12. Permit to Drill Number 203-139 13. API Number 50- 029-23174-00-00 14. Well Name and Number: PBU PSI-05 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 034631 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) CEMEI\I1'ING RECORD 260 sx Arctic Set (Approx.) 1436 sx ArcticSet III Lite, 600 sx 'G" 435 sx Class 'G', 585 sx Class 'G' 168 sx Class 'G' AMOUNT PUllED DEPTH SET (MD) 10353' PACKER SET (MD) 10309' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 144 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl GAs-McF WATER-Bsl CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presenc. e.. O.f. Oil,.9.. ...a. s or water (attach ~¡pt.. ~~Hf ~~ssary). Submit core chips; if,none, state "none". ~ (, 'W\, It t"( r:: V t: I V t: D None Oll-Bsl 27. í ¡ . 02)j1t~ Form 10-407 ~e&l3 GAs-McF W A TER-Bsl OR!GIN;4L CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) SEP 1 6 2004 Alaska Oil & a.s Cons. Commissioo.-- Ansnorag9 li?V C7 , 5 e GEOLOGIC MARKERS 29. . 28,' FORMATION TESTS 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". HRZ 10338' LCU / Top Sadlerochit 10552' Zone 3 10592' Zone 2C 10628' Zone 2B 10682' Zone 2A 10765' Zone 1 B 10820' Zone 1A 10854' Base of Sadlerochit / TKVK 10925' 8056' None 8262' 8301' 8336' 8388' 8469' 8522' 8555' 8625' RECEI\/ED SEP I ß ~004 Ala$k~ Qij ¿f¡ OÄIS C901mila~iQn M¡¡Þ~';"U¡:¡ 30. List of Attachments: Summary of Daily Drilling Reports and Post-Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~; 0 ft ~ Title Technical Assistant Date DC¡ -l~ -() Cf PBU PSI-05 203-139 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Rob Tirpack, 564-4166 Permit No. / 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 -~ " Submit Original Only " Legal Name: PSI-OS Common Name: PSI-OS 9/18/2003 9/24/2003 FIT FIT 5,544.0 (ft) 10,512.0 (ft) 4,615.0 (ft) 8,223.0 (ft) 9.00 (ppg) 9.00 (ppg) 720 (psi) 428 (psi) 2,878 (psi) 4,273 (psi) 12.00 (ppg) 10.00 (ppg) - e Printed: 10/6/2003 1 :51 :55 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OS PSI-OS DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 9/11/2003 9/30/2003 141 Spud Date: 9/12/2003 End: 9/30/2003 9/9/2003 04:00 - 00:00 20.00 MOB P PRE Rig released from Phillips @ 04:00 Hrs. Prepare for Rig Move: Lay Down Torque Tube, Top Drive, Wind Walls & Cattle Chute RID & prepare Derrick for Crane to Lift Off. 9/10/2003 00:00 - 12:00 12.00 MOB PRE Move Rig from Kuparuk 1 B Pad to Prudhoe Bay PSI Pad. 12:00 - 14:00 2.00 RIGU PRE Spot Sub, Pits, Pump Room, Boiler Moduals. 14:00 - 20:30 6.50 RIGU PRE Remove & Repair Brakes on top drive, Rig up Steam, Air & Water lines. Move Shop, Derrick, Rockwasher & Cranes to PSI Pad. 20:30 - 21 :30 1.00 RIGU PRE Prepare to pin Derrick, Weld Anadrill MWD pressure sensor fitting to stand pipe in Derrick. 21 :30 - 00:00 2.50 RIGU PRE Rig Cranes to Derrick, Position & pin Derrick to Sub, Anchor Dead line. 9/11/2003 00:00 - 12:00 12.00 RIGU P PRE Install Drilling line to Drawworks, Connect Bridle lines to Derrick, Lower Stabbing board, Set Iron Roughneck & derrick dog house on rig floor, Raise Derrick, Set Drilling line spool, Install wind walls & Cattle chute, Rig down Bridle lines & Hang same, Lower 'C' Section., Set MWD shack on rig w/ crane. 12:00 - 19:00 7.00 RIGU P PRE Pick up & Install top drive torque tube rail, Rig up Iron roughneck, Rig up pipe shed, Rock washer, Pipe skate, Work on rig acceptance check list., Add mud to mud pits. Note: Accepted Rig @ 1300 hrs. 9/11/03 19:00 - 00:00 5.00 RIGU P PRE Load pipe shed with drill pipe, Fill pits with Spud mud 9/12/2003 00:00 - 01 :00 1.00 RIGU P PRE Cut Drilling line 117' & Load pipe shed w/ 5" drill pipe 01 :00 - 02:30 1.50 RIGU P PRE Continue loading pipe shed w/ 5" drill pipe 02:30 - 07:30 5.00 RIGU P PRE Pick up 5" drill pipe & stand back in derrick 07:30 - 08:30 1.00 BOPSURP PRE Function test 21-1/4" Diverter, Witnessed & approved by AOGCC Lou Grimaldi 08:30 - 09:30 1.00 RIGU P PRE Finish picking up 5" drill pipe & stand back in derrick 09:30 - 12:00 2.50 RIGU P PRE Pick up 8 stands 5" HWDP, 1 stand 8" D.C.'s & stand back in derrick. 12:00 - 14:00 2.00 RIGU P PRE Change saver sub to 5", Rig up 5" handling tools 14:00 - 17:00 3.00 DRILL P SURF Rig & pick up BHA #1 17:00 - 17:30 0.50 DRILL P SURF Fill conductor and check for leaks, Test mud lines, Test MWD-OK 17:30 - 00:00 6.50 DRILL P SURF Spud well @ 1730 hrs. 9/12/03, Drill f/114' to 637' ART= 3.7 hrs. AST= 0 hrs., PU 117K, DN 117K, ROT 117K, Torque 2K on Btm /1 K off Btm, 750 GPM @ 1000 psi, WOB 5/20K, 80 RPM 9/13/2003 00:00 - 01:15 1.25 DRILL N DFAL SURF Repair Head connection on Gyro/data Gyro, Run Gyro @ 637' (Reseat Gyro several times due to inconsistent readings on tool face) 01:15 - 02:15 1.00 DRILL P SURF Drill slide f/ 637' to 727' 02:15 - 03:00 0.75 DRILL P SURF Run Gyro @ 727' 03:00 - 04:00 1.00 DRILL P SURF Drill slide f/727' to 818' (Unable to achieve any dogleg response), Running all possible WOB of 40-45K, Ranging pump GPM from 500 to 700 04:00 - 05:30 1.50 DRILL P SURF Run Gyro @ 818' (Reseat Gyro several times due to inconsistent readings on tool face) 05:30 - 06:15 0.75 DRILL P SURF Drill slide f/818' to 848' (Unable to achieve any dogleg response), Running all possible WOB of 40-45K, Ranging pump GPM from 500 to 700 06:15 - 06:45 0.50 DRILL P SURF Run Gyro @ 848' Printed: 10/6/2003 1:52:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OS PSI-OS DRILL +COMPLETE DOYON DOYON 141 Start: 9/11/2003 Rig Release: 9/30/2003 Rig Number: 141 Spud Date: 9/12/2003 End: 9/30/2003 9/13/2003 06:45 - 07:30 0.75 DRILL P SURF Drill slide f/ 848' to 908' (Unable to achieve any dogleg response), Running all possible WOB of 40-45K, Ranging pump GPM from 500-700 07:30 - 08:00 0.50 DRILL P SURF Run Gyro @ 908' 08:00 - 09:15 1.25 DRILL P SURF Drill slide f/ 908' to 1001' (Unable to achieve any dogleg response), Running all possible WOB of 40-45K, Ranging pump GPM f/500-700 09:15 - 09:45 0.50 DRILL P SURF Run Gyro @ 1001' 09:45 - 12:00 2.25 DRILL P SURF Drill & slide f/1 001' to 1187' (Unable to achieve any dogleg response), Running all possible WOB of 40-45K, Ranging pump GPM f/500-750 12:00 - 12:30 0.50 DRILL P SURF Survey on btm @ 1187' w/ MWD- OK, Circ. btm's up w/ 750 GPM @ 1500 psi 12:30 - 14:00 1.50 DRILL P SURF POOH, Handle BHA & Break out and grade bit - broken teeth on inner rows. Check orientation scribe marks. 14:00 - 15:00 1.00 DRILL P SURF Make up new hughes MX-C1 Bit, Change motor bend from 1.5 to 1.83 deg., RIH w/ BHA 15:00 - 15:30 0.50 DRILL P SURF RIH w/ Drill pipe, Hole in good shape- No fill 15:30 - 00:00 8.50 DRILL P SURF Slide from 1187' to 1466' building 2 Deg to 4 Deg. per hundred. Drill & slide f/1466' to 2023' ,AST= 5.91 hrs, ART= .20 hrs ADT= 6.11 hrs, UP 115K, DN 108K, ROT 114K, WOB 20-45K, GPM 630 to 700 9/14/2003 00:00 - 04:30 4.50 DRILL P SURF Drill & Slide from 2023' to 2577' (Building 2 to 4 Deg. per hundred-Very soft formation and hard to keep WOB, ROP's 250 to 400 ftlhr- Circulating 10 to 15 min. per stand to clean up hole- but hole still loading up), UP 180K, DN 108K, ROT 114K, WOB 20-40K, GPM 630 to 750 at 1700 psi 04:30 - 05:30 1.00 DRILL P SURF Circ. hole clean w/ 900 GPM at 2600 psi & 80 RPM 05:30 - 11 :30 6.00 DRILL P SURF Drill & Slide from 2577' to 3134' UP 128K, DN 114K, ROT 121 K, WOB 10-30K, RPM 80, Torque 7K on 6K off, GPM 900 at 2600 psi 11:30-13:00 1.50 DRILL P SURF Circ. hole clean 2 btm's up w/ 900 GPM at 2600 psi & 80 RPM 13:00 - 14:30 1.50 DRILL P SURF Wiper trip to 911' (Hole in good condition) 14:30 - 00:00 9.50 DRILL P SURF Drill f/ 3134' to 4340' ART= 5.1 hrs AST= .69 hrs ADT= 5.79 hrs UP 175K, DN 120K, ROT 136K, TO on 10K off 9K, WOB 5-25K, RPM 80, 850 GPM @ 2725 psi 9/15/2003 00:00 - 19:30 19.50 DRILL P SURF Drill f/4340' to 5563' (TVD 4615') Surface hole TD, ART= 13.52 hrs, AST= .97 hrs, ADT= 14.49 hrs, UP 190K, DN 127K, ROT 151 K, TO 12K on btm, TO off btm 11 K, WOB 20/30K RPM 80, 900 GPM @ 3200 psi 19:30 - 22:00 2.50 DRILL P SURF Circ. 2-1/2 times btm's up at rate of 900 GPM @ 3000 psi, 100 RPM 22:00 - 00:00 2.00 DRILL P SURF POOH to 2,765 for Wiper trip, Pulling 30 to 45K, Had 40K drag @ 4890',3840',3310', & 50K drag @ 3550', Drill pipe displacement 3 to 5 bbls over calculated 9/16/2003 00:00 - 00:15 0.25 DRILL P SURF Monitored well at 2,750', mud loss ave 12 bph 00: 15 - 02:00 1.75 DRILL P SURF TIH from 2,750 to btm at 5,563' with no problems or fill 02:00 - 03:45 1.75 DRILL P SURF Circ & Cond hole for csg, added 25 sxs of med-nut plug for mud losses, circ at 900 gpm at 3,000 psi, 100 rpm's, string up wt 185K, dn wt 125K with 12K ft-Ibs off btm torque, circ hole clean 03:45 - 04:00 0.25 DRILL P SURF Monitored well- static and no mud loss 04:00 - 07:00 3.00 DRILL P SURF POOH from 5,563' to 186' with no problems, monitored Printed: 10/612003 1:52:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OS PSI-OS DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 9/11/2003 9/30/2003 141 Spud Date: 9/12/2003 End: 9/30/2003 9/16/2003 04:00 - 07:00 3.00 DRILL P SURF well-static 07:00 - 09:30 2.50 DRILL P SURF POOH from 186' & LD BHA #2 and cleared rig floor 09:30 - 09:45 0.25 CASE P SURF Made dummy run with 133/8" Landing jt and hanger 09:45 - 11 :00 1.25 CASE P SURF RU Doyon's 13 3/8" 350 ton csg equipment and MU Franks fill up tool 11:00 -11:15 0.25 CASE P SURF Held PJSM with rig crew on running 133/8" csg 11:15 -20:15 9.00 CASE P SURF Ran 133/8" 68#, L-80 BTC Csg to 5,544' with no problems, ran HES 13 3/8" float shoe, 2 jts 13 3/8" csg, HES 13 3/8" float collar, thread locked conn below float collar and checked float equip, cont running 133/8" csg, ran 108 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 5,544' and float collar at 5,459', ran a total of 133 jts of 13 3/8" csg, 2 pup jts, Tam port collar, float equip and hanger = 5,516.34', ran 27 Bow spring centralizers per program, circ btms up at 2,000', and circ at 4,000' for 2,000' of open hole cap, no mud loss while RIH with csg 20: 15 - 20:45 0.50 CASE P SURF LD Franks fill up tool & MU Dowell cement head 20:45 - 00:00 3.25 CEMT P SURF Circ & Cond mud for cementing, staged pump rate up to 10 bpm at 575 psi, attempted to reciprocate csg with no success, PU to 450K Ibs string wt with no movement,circ & lowered YP from 59 to 30 with 9.4+ ppg mw in 9/17/2003 00:00 - 02: 15 2.25 CEMT P SURF Fin circ & cond mud for cementing 133/8" csg, lowered YP from 30 to 13 with 9.3 ppg mw in & out, final circ rate of 12 bpm at 725 psi with no pipe movement 02: 15 - 05:45 3.50 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 5.2 bpm at 110 psi, shut down and dropped btm plug, mixed & pumped 1,095 bbls, 1,400 sxs of Arctic set Lite at 10.7 ppg and 4.28 yield with additives, pumped at an ave of 7.3 bpm at 165 psi, followed with 125 bbls, 620 sxs of class "G" tail cmt with additives at 15.8 ppg and 1.17 yield, Note: After 35 bbls of Mudpush was thru shoe lost returns for remainder of 40 bbls mudpush out of shoe, regained circ with cement out of shoe, cont cementing with full returns, Shut down 05:45 - 07:00 1.25 CEMT P SURF Dropped top plug and Dowell pumped 10 bbls FW behind plug, turned over to rig and displaced cement with 9.3 ppg mud, initial rate of 12 bpm at 700 psi, max pressure while displacing cmt was 1,700 psi, slowed rate and bumped plug on calc displacement, pressured up on plugs to 2,400 psi, checked floats and held, had good returns during displacement with 500 bbls of 10.7 ppg cement back at surface, CIP at 07:00 hrs 07:00 - 09:00 2.00 CEMT P SURF Flushed out diverter system and RD Doyon's Csg handling equipment and changed out elevator bales 09:00 - 12:00 3.00 DIVRTR P SURF ND 21 1/4" Diverter and set out 12:00 - 13:00 1.00 WHSUR P SURF NU FMC 13 5/8" 5M Big Bore Wellhead, tested seals to 1,000 psi for 10 min & ck ok 13:00 - 15:00 2.00 BOPSUR P SURF NU 135/8" 5M BOP stack with 5" rams on btm and 3 1/2" x 6" VBR's on top 15:00 - 20:30 5.50 BOPSUR P SURF Installed test plug, RU & tested BOPE, valves, choke manifold, rams and Annular to 250 psi low and 4,000 psi high Chuck Scheve with AOGCC witnessed test, RD & Installed wear bushing Printed: 10/612003 1:52:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-05 PSI-05 DRILL +COMPLETE DOYON DOYON 141 Start: 9/11/2003 Rig Release: 9/30/2003 Rig Number: 141 Spud Date: 9/12/2003 End: 9/30/2003 9/17/2003 20:30 - 21 :30 1.00 DRILL P INT1 Slip & cut 78' of drilling line 21 :30 - 22:30 1.00 DRILL P INT1 PU & RIH with 33 jts of 5" DP, POOH & stood back 22:30 - 00:00 1.50 DRILL P INT1 PU & MU 12 1/4" Bit #3 on 9" Power Drive steerable motor and tested same 9/18/2003 00:00 - 02:30 2.50 DRILL P INT1 Fin PU & MU 12 1/4" BHA #3 with Anadril Steerable assembly with 12 1/4" Ghost Reamer 02:30 - 03:00 0.50 DRILL P INT1 TIH with BHA #3 PU 5" DP to 1,430' 03:00 - 03:30 0.50 DRILL P INT1 Shallow tested MWD and rotary steerable assembly 03:30 - 07:00 3.50 DRILL P INT1 Cont TIH with BHA #3 PU 5" DP to 5,400' 07:00 - 07:15 0.25 DRILL P INT1 Circ hole for csg test 07:15 - 08:15 1.00 CASE P INT1 RU & tested 133/8" csg to 3,500 psi for 30 min, good test 08:15 -12:00 3.75 CEMT P INT1 RIH from 5,400' & tagged float collar at 5,460', drilled plugs, float collar, hard cement in shoe track and float shoe at 5,544', began displacing spud mud with new 9.0 ppg LSND mud, drilled cmt at 3-7K wob, 55 rpm's, 180 spm, 760 gpm, 2,100 psi, rot wt 147K, up wt 185K, dn wt 125K with 12K ft-Ibs torque. 12:00 - 12:30 0.50 DRILL P INT1 Drilled 20' of new formation from 5,563' to 5,583', ADT .26 hrs 12:30 - 12:45 0.25 DRILL P INT1 Fin displacing out spud mud with new 9.0 ppg LSND mud, 9.0 ppg mw in & out for FIT 12:45 -13:15 0.50 DRILL P INT1 Performed FIT to 12.0 ppg EMW with 9.0 ppg mw at 5,544' MD/4,615' TVD with 720 psi 13:15 -13:30 0.25 DRILL P INT1 Perfomed PDW baseline test with 9.0 ppg mw at 900 gpm at 2,400 psi, clean hole ECD 9.5 ppg, rot wt 156K, up wt 172K, dn wt 132K 13:30 - 00:00 10.50 DRILL P INT1 Drill 12 1/4" hole with rotary steerable assembly from 5,583' to 6,568' MD/5,266' TVD (985') ADT 7.01 hrs, 10-15K wob, 110 rpm's, 212 spm, 900 gpm, off btm press 3,000 psi, on btm 3,050 psi, off btm torque 7K ft-Ibs, on btm 10K ft-Ibs, rot wt 160K, up wt 176K, dn wt 142K, 9.5 mw, ECD ave 10.25 ppg, ave bgg 60 units, pumping weighted every 3-500' with 0-10% increase in cuttings from sweeps. Note: Drilled hard spot in Ugnu at 6,036', took 1 hr to dill thru. 9/19/2003 00:00 - 12:00 12.00 DRILL P INT1 Drill 12 1/4" hole with rotary steerable assembly from 6,568' to 7,495' MD/5,905' TVD (927') ADT 8.5 hrs, 10-20K wob, 110- 120 rpm's, 210 spm, 890 gpm, off btm press 3,000 psi, on btm 3,050 psi, off btm torque 17K ft-Ibs, on btm 21 K ft-Ibs, rot wt 165K, up wt 220K, dn wt 139K, 9.7 mw, ECD ave 10.35 ppg, ave bgg 60 units, max gas 184 units from 7,025', pumping weighted every 3-500' with 0-10% increase in cuttings from sweeps. 12:00 -14:15 2.25 DRILL P INT1 Drilled 12 1/4" hole from 7,495' to 7,635' MD/6,010' TVD (140') ADT 1.14 hrs 1 0-25K wob, 110 rpm's, 205 spm, 870 gpm, off btm press 2,950 psi, on btm 3,000 psi, off btm torque 17K ft-Ibs, on btm 20K ft-Ibs, rot wt 175K, up wt 220K, dn wt 145K, Note: Top drive blower motors shorting out 14:15 - 15:30 1.25 DRILL P INT1 Pumped Weighted (2# over mw) hi vis sweep and circ out with no increase in cuttings, circ clean at 870 gpm at 3,000 psi, monitored well-static, pumped dry job 15:30 - 16:30 1.00 DRILL P INT1 POOH from 7,635' to 7,200' and hole did not take proper fill. (Minor overpulls with intermittent swabbing.) 16:30 - 19:00 2.50 DRILL P INT1 Backreamed out of hole from 7,200' to 6,650. Pull one stand without pumps to 6,550 with no swabbing. The next stand Printed: 101612003 1:52:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OS PSI-OS DRILL +COMPLETE DOYON DOYON 141 Start: 9/11/2003 Rig Release: 9/30/2003 Rig Number: 141 Spud Date: 9/12/2003 End: 9/30/2003 9/19/2003 16:30 - 19:00 2.50 DRILL P INT1 pulled without swabbing but required 30 to 40K overpulls. Ran back in to 6,550 and backreamed out to 13 3/8 casing shoe. (5,516). RPM==100 GPM==850 19:00 - 22:00 3.00 DRILL N RREP INT1 Changed out service loop on top drive to due short in wiring and serviced top drive, circ btms up while changing out service loop, max gas 58 units 22:00 - 23:00 1.00 DRILL P INT1 TIH from 5,516' to 7,591', washed 44' to btm, no problems RIH 23:00 - 00:00 1.00 DRILL P INT1 Drill 12 1/4" hole from 7,635' to 7,680' MD/6,040' TVD, (45') ADT .38 hrs, 1 0-25K wob, 110 rpm's, 205 spm, 870 gpm, 3,000 psi, off btm torque 17K ft-Ibs, on btm 20K ft-Ibs, rot wt 175K, up wt 220K, dn wt 145K, ave bgg 60 units, max gas at btms up from trip 243 units, 9.7 mw, ave ECD 10.1 ppg, maintaining 3% lubricants in mud. 9/20/2003 00:00 - 12:00 12.00 DRILL P INT1 Drill 12 1/4" hole with rotary steerable assembly from 7,680' to 8,607' MD/6,682' TVD, (927') ADT 9.3 hrs, 1 0-20K wOb, 110 rpm's, 204 spm, 865 gpm, 3,100 psi, off btm torque 19K ft-Ibs, on btm 22K ft-Ibs, rot wt 182K, up wt 250K, dn wt 144K, ave bgg 50 units, max gas 65 units, 9.7 ppg mw, ave ECD 10.1 ppg, maintaining 3% lubricants in mud. 12:00 - 00:00 12.00 DRILL P INT1 Drill 12 1/4" hole from 8,607' to 9,555' MD/7,375' TVD, (948') ADT 7.8 hrs, 15-25K wob, 110 rpm's, 189 spm, 800 gpm, 3,300 psi, off btm torque 21 K ft-Ibs, on btm 25K ft-Ibs, rot wt 205K, up wt 260K, dn wt 163K, ave bgg 225 units, max gas 593 units.( raised mw to 10.5 ppg and added resinex prior to drilling CM2 formation) 10.5 ppg mw ECD ave 10.96 ppg. 9/21/2003 00:00 - 04:15 4.25 DRILL P INT1 Drill 12 1/4" hole with rotary steerable system from 9,555' to 9,863' MD/7,626' TVD, (308') ADT 3.6 hrs, 2" nipple on discharge line on #2 mud pump washed out 04:15 - 06:15 2.00 DRILL N RREP INT1 Replaced washed out 2" nipple on discharge line on mud pump #2, Circ hole at 336 gpm at 900 psi and 110 rpm's, stood back 1 std after 45 min & cant to circ hole 06:15 -12:00 5.75 DRILL P INT1 Drill 12 1/4" hole from 9,863' to 10,070' MD/7,806' TVD, (207') ADT 4.7 hrs, 15-25K wob, 110 rpm's, 185 spm, 780 gpm, off btm press 3,300 psi, on btm 3,350 psi, off btm torque 21 K ft-Ibs, on btm 25K ft-Ibs, increased lubricants in mud to 4%, 10.5 ppg mw, ave ECD 10.9 ppg, ave bgg 250 units, max gas 640 units 12:00 - 20:00 8.00 DRILL P INT1 Drill 12 1/4" hole from 10,070' to 10,517' MD/8,228' TVD, 9 5/8" csg point, (447') ADT 6.45 hrs, 20-23K wob, 110 rpm's, 185 spm, 780 gpm, off btm press 3,375 psi, on btm 3,425 psi, off btm torque 21 k ft-Ibs, on btm 26K ft-Ibs, maintaining 4% lubricants in mud, mw 10.5 ppg, ave ECD 11.0 ppg, ave bgg 300 units, max gas 605 units 20:00 - 22:30 2.50 DRILL P INT1 Pumped weighted hi vis sweep, (2# over mw), circ out with 0-10% increase in cuttings, circ a total of 2X btms up, circ at 175 spm 745 gpm at 3,050 psi and 110 rpm's 22:30 - 22:45 0.25 DRILL P INT1 Monitored well- static 22:45 - 00:00 1.25 DRILL P INT1 POOH wet (16 stds) from 10,517' to 9,064' with no problems, hole taking calc fill, drag ave 10-20K Ib's Printed: 10/6/2003 1:52:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-05 PSI-05 DRILL +COMPLETE DOYON DOYON 141 Start: 9/11/2003 Rig Release: 9/30/2003 Rig Number: 141 Spud Date: 9/12/2003 End: 9/30/2003 9/22/2003 00:00 - 02:30 2.50 DRILL P INT1 Monitored well @ 9,065' - Static, Pumped dry job and POOH to 5,450', (Inside 133/8" Csg Shoe) with no problems 02:30 - 03:00 0.50 DRILL P INT1 Serviced Top Drive at shoe 03:00 - 05:30 2.50 DRILL P INT1 TIH to 10,374', washed 143' to btm with no problems 05:30 - 09:00 3.50 DRILL P INT1 Pumped weighted hi vis sweep (2# over mw) and circ hole clean, max gas at btms up from wiper trip was 1,580 units, circ at 760 gpm at 3,400 psi and 110 rpm's, no increase in cuttings from sweep, circ & cond mud for csg, circ a total of 3X btms up and clean at shakers, 10.5 mw in & out with 10.8 ppg ECD, bgg down to 200 units 09:00 - 09: 15 0.25 DRILL P INT1 Monitored well-static 09:15 -14:00 4.75 DRILL P INT1 POOH 10 stds wet, hole taking calc fill, pumped dry job and POOH to 900' (BHA #3), no problems POOH 14:00 - 17:00 3.00 DRILL P INT1 LD ghost reamer & stood back HWDP, LD remaining BHA 17:00 - 17:30 0.50 DRILL P INT1 Pulled wear bushing & installed test plug 17:30 - 18:45 1.25 CASE P INT1 Changed out top set of 3 1/2" x 6" VBR rams over to 9 5/8" csg rams & tested door seals to 3,500 psi 18:45 - 20:00 1.25 CASE P INT1 RU Doyon's 350 ton 9 5/8" csg equipment, Frank's fill up tool & changed out elevator bales 20:00 - 20:15 0.25 CASE P INT1 Held PJSM with rig crew & tong operator on running of 95/8" csg 20:15 - 00:00 3.75 CASE P INT1 Began running 95/8" 47# L-80 & 40#, S-95 BTC-M Csg to 3,318' 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 13 jts of 9 5/8" 47# L-80 BTC-M csg, (15 total) cont running 95/8" 40# S-95 BTC-M csg to 3,318' (80 jts of 253 in hole) 9/23/2003 00:00 - 02:30 2.50 CASE P INT1 Cant RIH with 9 5/8" csg from 3,318' to 5,542' (13 3/8" csg shoe) 134 jts total in hole 02:30 - 03:15 0.75 CASE P INT1 Circ 1 csg cap at shoe, circ at 420 gpm at 825 psi, string wt up 215K, Dn wt 173K 03:15 - 09:15 6.00 CASE P INT1 Fin running in hole with 9 5/8" csg with no problems, MU hanger and landed 9 5/8" csg with float shoe at 10,512' and float collar at 10,426', Ran a total of 253 jts and 1-20' pup jt, ran 15 jts of 9 5/8" 47# L-80 BTC-M and the remainder 9 5/8" 40# S-95 BTC-M, Total pipe ran with float equipment & hanger 10,487.33' 09:15 - 10:30 1.25 CEMT P INT1 Circ 1 btms with Franks fill up tool, staged pump up to 12 bpm at 1,500 psi, reciprocated pipe with a string wt of 415K up wt and 215K dn wt, max gas at btms up 150 units 10:30-11:00 0.50 CEMT P INT1 LD Franks fill up tool and MU Dowell's cement head and lines 11 :00 - 14:00 3.00 CEMT P INT1 Circ & Cond mud for cementing, initial mw 11.0 ppg with 55 PV and 65 YP, lowered mw to 10.5 ppg with 12 PVand 11 YP, Held PJSM with rig crew, Dowell and Veco vacuum truck drivers on cementing 9 5/8" csg, batch mixed tail cement while circ & cond mud, reciprocated pipe with 430K up wt and 220K dn wt 14:00 - 15:30 1.50 CEMT P INT1 Turned over to Dowell, pumped 5 bbls CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, pumped additional 70 bbls (80 total) of CW 100 at 7.25 bpm at 400 psi, pumped 50 bbls of MudPush II spacer at 11.0 ppg at 7 bpm at 375 psi, shut down & dropped btm plug, mixed & pumped lead cement on the fly, pumped 216 bbls, 439 sxs of Premium "G" cmt at 11.5 ppg and Printed: 10/6/2003 1:52:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-05 PSI-05 DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 9/11/2003 9/30/2003 141 Spud Date: 9/12/2003 End: 9/30/2003 9/23/2003 14:00 - 15:30 1.50 CEMT P INT1 2.79 yield with additives, ave 7 bpm at 325 psi, pumped batch mixed tail cement, pumped 125 bbls, 630 sxs of Premium "G" cement with additives at 15.8 ppg and 1.20 yield, ave 6.5 bpm at 275 psi, reciprocated pipe, up wt 435K, dn wt 230K, shut down 15:30 - 17:00 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 11 bpm at 600 psi, max pressure while displacing cmt was 900 psi, slowed rate and bumped plug on calc displacement, pressured up on plugs to 1,400 psi, checked floats and held, had good returns during job, reciprocated pipe till CW 100 was at shoe, after CW 100 was past shoe attempted to reciprocate pipe, PU to 500K with no movement, final up while working pipe, 485K, dn wt 240K, CIP at 16:45 hrs, est TOe at 6,544' 17:00 -19:30 2.50 CEMT P INT1 RD cement head and csg equipment, LD landing jt & cleared rig floor 19:30-21:00 1.50 WHSUR P INT1 Installed FMC 9 5/8" Big Bore pack-off and tested to 5,000 psi for 10 min, good test 21 :00 - 22:00 1.00 CASE P INT1 Installed test plug and changed out top set of 95/8" csg rams back over to 3 1/2" x 6" VBR's Note: Pumped 5 bbls of 10.5 ppg mud down 13 3/8" X 9 5/8" Annulus, pumped at .5 bpm and pressured up to 1,100 psi and dropped to 810 psi 22:00 - 00:00 2.00 BOPSURP INT1 RU and began testing BOPE to 250 psi low and 4,000 psi high, Note: Chuck Scheeve with AOGCC waived witnessing of test Est injection rate down 133/8" x 9 5/8" Ann at 2 bpm at 1,500 psi, pumped at total of 20 bbls (25 total bbls pumped down Ann) Compressive strength of tail cement 700 psi 9/24/2003 00:00 - 03:15 3.25 BOPSUR P INT1 Fin testing BOPE, tested rams, valves and manifold to 250 psi low and 4,000 psi high, tested annular to 250 psi low and 2,500 psi high. Note: Chuck Scheeve of AOGCC waived witnessing of test 03: 15 - 03:45 0.50 BOPSURP INT1 Pulled test plug and installed FMC 8 3/4" ID wear bushing 03:45 - 05:30 1.75 DRILL P PROD1 PU & MU Bit #4 on BHA #4, Mud Mtr with 1.5 deg bend, MWD and oriented same 05:30 - 05:45 0.25 DRILL P PROD1 Held PJSM on loading of Radiaoctive sources 05:45 - 07: 15 1.50 DRILL P PROD1 Loaded Radioactive source and finished TIH to 896' with BHA #4, shallow tested MWD and ck ok 07:15 - 10:45 3.50 DRILL P PROD1 RIH to 10,360, pu wt 290K, dn wt 145K 10:45 - 12:00 1.25 DRILL P PROD1 Slip & cut 106' of drlg line and serviced Top Drive, adjusted drawworks brakes, circ hole at 30 spm and 600 psi while servicing rig and preparing to test csg 12:00 - 14:00 2.00 CASE P PROD1 RU & Tested 9 5/8" csg to 4,000 psi for 30 min, good test 14:00 - 16:00 2.00 CEMT P PROD1 Drilled plugs, float collar at 10,426', firm cement in shoe track, float shoe at 10,512' and cleaned out to TD at 10,517', Drilled with 5-15K wob, 60 rpm's, 120 spm, 510 gpm at 2,300 psi 16:00 -17:30 1.50 DRILL P PROD1 Pumped 35 bbl spacer and displaced 10.5 ppg LSND mud with new 9.0 ppg FloPro mud with 3% lubricants, circ at 510 gpm 2,300 psi, torque with 10.5 ppg mud in hole was 25K ft-Ibs and after displacing hole torque decreased to 14K ft-Ibs 17:30 - 18:00 0.50 DRILL P PROD1 Drilled 20' of new formation from 10,517' to 10,537', ADT .42 hrs Printed: 10/6/2003 1 :52: 12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OS PSI-OS DRILL +COMPLETE DOYON DOYON 141 Start: 9/11/2003 Rig Release: 9/30/2003 Rig Number: 141 Spud Date: 9/12/2003 End: 9/30/2003 9/24/2003 18:00 - 18:30 0.50 DRILL P PROD1 Circ btms up for FIT test, 9.0 ppg mw in & out, rot wt 227K, up wt 275K, dn wt 185K 18:30 - 19:30 1.00 DRILL P PROD1 Performed FIT to 10.0 ppg EMW with 9.0 ppg mud at 10,512' MD/8,223' TVD with 428 psi, held for 10 min with no pressure loss 19:30 - 00:00 4.50 DRILL P PROD1 Drilled 8 1/2" hole from 10,537' to 10,732' MD/8,463' TVD (195') ADT 3.05 hrs, 30-35K wob, 100 rpms, 140 spm, 600 gpm, off btm pressure 2,450 psi, on btm 2,600 psi, off btm torque 25K ft-Ibs, on btm 24K ft-Ibs, rot wt 225K, up wt 315K, dnwt180K 9/25/2003 00:00 - 07:15 7.25 DRILL P PROD1 Drilled 8 1/2" hole from 10,732' to 10,982' MD/8,680' TVD (250'), well TD, ADT 6.45 hrs, 10-35K wob, 100 rpm's, 140 spm, 600 gpm, off btm press 2,300 psi, on btm 2,375 psi, off btm torque 19K ft-Ibs, on btm 20K ft-Ibs, rot wt 216K, up wt 290K, dn wt 190K 07:15-08:15 1.00 DRILL P PROD1 Circ hole for wiper trip, circ 1 3/4 btms up, circ at 590 gpm at 2,400 psi and 110 rpm's, off btm torque 20k ft-Ibs 08: 15 - 09:45 1.50 DRILL P PROD1 Wiped hole 6 stds to shoe at 10,512', had 35K drag from 10,825 to 10,640', wiped thru, cant POOH to shoe with no problems, TIH to btm with no problems 09:45 - 13:00 3.25 DRILL P PROD1 Circ btms up then pumped hi vis sweep and circ hole clean, circ a total of 4X btms up, circ at 630 gpm at 2,475 psi at 120 rpm's, off btm torque 12K ft-Ibs 13:00 -13:15 0.25 DRILL P PROD1 Monitored well-static 13:15 - 17:00 3.75 DRILL P PROD1 POOH wet 6 stds to shoe with no problems, monitored well at shoe-static, pumped dry job and dropped rabbit on wire down DP for liner run, POOH to BHA at 896' 17:00 - 19:30 2.50 DRILL P PROD1 POOH LD HWDP, jars & NM dc's, held PJSM then removed radioactive sources, LD remaining BHA and cleared rig floor 19:30 - 19:45 0.25 EVAL P PROD1 Held PJSM with rig crew and Schlumberger wireline on RU to run USIT Bond log 19:45 - 21 :45 2.00 EVAL P PROD1 Spot in & RU Schlumberger wireline unit and MU US IT logging tool 21:45 - 00:00 2.25 EVAL P PROD1 RIH and ran USIT bond log from 10,499' to 9,490' and started POOH. Log shows 100% bond from 10,499' to 9,878' and 60-80% bond from 9,878' to 9,490' 9/26/2003 00:00 - 01 :30 1.50 EVAL P PROD1 Fin POOH with USIT bond log & RD Schlumberger wireline 01 :30 - 02:00 0.50 CASE P PROD1 RU Doyons 7" handling tools & Held PJSM on runnin9 of 7" liner 02:00 - 03:00 1.00 CASE P PROD1 PU & ran 14 jts of 7" 26#, L-80 BTC-M liner, 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 568.89' 03:00 - 03:30 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, 250 9pm at 150 psi, liner wt 15K, 50K with blocks 03:30 - 10:30 7.00 CASE P PROD1 Run 7" liner on 5" Dp from 602' to 10,450', (60' f/csg shoe) good returns while RIH 10:30-11:00 0.50 CASE P PROD1 Circ 1 DP & Liner cap at shoe, circ at 336 9pm at 775 psi, up wt 225k, dn wt165K 11 :00 - 12:00 1.00 CASE P PROD1 PU & RIH 2 jts 5" DP to space out, PU 1 jt of DP and MU to Bakers plug dropping head and set on skate 12:00 - 12:30 0.50 CASE P PROD1 RIH with 7" liner to 10,966', MU plug droppin9 head and est circ Printed: 10/612003 1 :52: 12 PM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OS PSI-OS DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 9/11/2003 9/30/2003 141 Spud Date: 9/12/2003 End: 9/30/2003 9/26/2003 12:00 - 12:30 0.50 CASE P PROD1 and tagged btm at 10,892', no problems RIH 12:30 - 14:30 2.00 CASE P PROD1 Circ btms up prior to cementing liner, staged pump rate up to 80 spm, 336 gpm at 1,000 psi, reciprocated pipe, up wt, 235K dn 135wt. While circ held PJSM with Dowell and rig crew on cementing liner and batch mixed cement. 14:30 - 15:00 0.50 CEMT P PROD1 Dowell pumped 5 bbls FW and tested lines to 4,000 psi, then pumped 30 bbls CW 100 at 8.3 ppg followed with 30 bbls of MudPush at 11.0 ppg, pumped 36 bbls, 168 sxs of class "G" cement with additives at 15.8 ppg and 1.2 yield, pumped cement at 5 bpm at 580 psi, reciprocated pipe, shut down and washed up lines to cement head 15:00 - 15:30 0.50 CEMT P PROD1 Dropped DP wiper dart and displaced cement with 9.0 ppg floPro mud, initial rate of 8 bpm at 1,000 psi, slowed rate and saw Liner Wiper plug shear at 1,200 psi, cant displacement slowing to 2 bpm and bump plug on calc displacement to 1,250 psi, bumped plug at 15:30 hrs, reciprocated pipe throughout job with full returns 15:30 - 15:45 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 hanger with 15 turns to right, press up to 1,000 psi and PU out of hanger, circ 20 bbls at 10 bpm after 10 bbls slowed to 6 bpm, set 70K wt down and set ZXP pkr. PU off Liner, 7" liner set at 10,892' with landing collar at 10,898' and top of liner at 10,388'. No problems running, cementing and setting of liner 15:45 - 16:30 0.75 CEMT P PROD1 Circ hole clean at top of liner, at btms up had 170 bbls of spacer/cement contaminated FloPro mud and 12 bbls of 15.8 ppg cement back to surface, circ hole clean at 17 bpm at 2,500 psi, st wt after releasing liner 21 OK up wt, 165K dn wt 16:30 - 21 :00 4.50 CASE P PROD1 POOH & LD Baker liner running tool 21 :00 - 22:00 1.00 CASE P PROD1 PU 61/8" Clean out BHA, 6 1/8" bit, 7" csg scraper, XO, 16 jts 3 1/2" DP and RIH to 514' 22:00 - 00:00 2.00 CASE P PROD1 MU XO, 95/8" csg scraper on bit sub and TIH with clean out assembly on 5" DP to 4,240' 9/27/2003 00:00 - 02:30 2.50 CASE P PROD1 Fin RIH with 6 1/8" Bit, 7" & 9 5/8" csg scrapers, tagged up on Landing Collar at 10,898', no problem going thru top of liner at 10,388'. 02:30 - 09:30 7.00 CASE N FLUD PROD1 Attempted to circ hole clean prior to displacing with seawater, began getting back contaminated mud, had to adjust circ rate due to screens blinding off, ave 5 bpm at 800 psi, eventually was able to increase pump rate to 18 bpm at 2,500 psi, rotated at 30-40 rpm's and reciprocated pipe, contaminated mud stop coming over shakers, pumped 120 bbls seawater/drilling detergent sweep at btms up had no significant change and hole clean 09:30 -10:15 0.75 CASE N PROD1 POOH with bit & scrapers to 9,065' 10:15-11:00 0.75 CASE N PROD1 Circ btms up at 9,065' at 18 bpm and 2,275 psi, hole clean no increase in contaminated mud at btms up 11 :00 - 12:00 1.00 CASE N PROD1 TIH with bit & scrapers to btm at 10,898' 12:00 - 12:30 0.50 CASE N PROD1 Circ btms up at 18 bpm and 2,500 psi and hole's clean, rotated pipe 30-40 rpm's while reciprocating pipe, st up wt 230K, dn wt 165K 12:30 - 14:30 2.00 CASE P PROD1 Pumped 32 bbl high vis sweep and displaced out 8.8 ppg FloPro LSND mud with 8.5 ppg seawater, displaced at 18 bpm Printed: 10/6/2003 1:52:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-OS PSI-OS DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 9/11/2003 9/30/2003 141 Spud Date: 9/12/2003 End: 9/30/2003 9/27/2003 12:30 - 14:30 2.00 CASE P PROD1 at 2,600 psi, st wt up 250K, dn wt 175K 14:30 - 15:30 1.00 CASE P PROD1 RU and tested 9 5/8" & 7" csg to 4,000 psi for 30 min, good test 15:30 - 21 :30 6.00 CASE P PROD1 POOH with bit and scrapers to 525'. Stopped & circ btms up every 25 stds on trip out as precaution, hole clean. 21 :30 - 22:30 1.00 CASE P PROD1 POOH LD 9 5/8" & 7" csg scrapers, LD 16 jts 31/2" DP and 6 1/8" bit 22:30 - 00:00 1.50 RUNCOtvP COMP Held PJSM on 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 and setting tool overall toollenght 92.06' 9/28/2003 00:00 - 00:30 0.50 RUNCOtvP COMP RIH with Tbg tail & Pkr assembly on 5" DP to 1,020' 00:30 - 02:00 1.50 RUNCOtvP COMP Slip & cut 65' of drlg line, serviced top drive & blocks 02:00 - 06:15 4.25 RUNCOtvP COMP Fin RIH with Tbg tail & Pkr assembly, tagged TOL at 10,388', dropped ball & rod & PU 35' to put Pkr on depth, string up wt 220K, dn wt 181 K 06:15 - 07:30 1.25 RUNCOtvP 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 10,353', SABL-3 Pkr at 10,310' and PBR at 10,274'. 07:30 - 14:00 6.50 RUNCOtvP COMP POOH, stood back 30 stds of 5" DP and LD 246 jts of 5" DP and Baker setting tool 14:00 - 16:00 2.00 RUNCOtvP 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 16:00 - 17:00 1.00 RUNCOtvP COMP Made dummy run with 75/8" Tbg hanger. Install tubing hanger XO and lay down same. 17:00-17:15 0.25 RUNCOtvP COMP Held PJSM with rig crew, Tbg thread reps, and Doyon csg on RU & running 7" & 7 5/8" completion 17:15-18:30 1.25 RUNCOtvP COMP RU Doyon's 7" & 7 5/8" handling equipment with torque turn to run completion 18:30 - 00:00 5.50 RUNCOtvP 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 2,258' (53 jts of 252) 9/29/2003 00:00 - 15:00 15.00 RUNCOtvP COMP Fin TIH with 7" seal assembly and PU 7 5/8" 29.7# L-80 ST-L tbg, RIH with 252 jts to 10,250' 15:00 - 17:00 2.00 RUNCOtvP COMP MU 2 add jts of 7 5/8" tbg circ slowly and located top of PBR with seal assembly, LD jts and spaced out 7 5/8" tbg string with btm of seal assembly at 10,298', 3' off of No Go, st wt up 325K, dn 195K (block wt 35K) 17:00 - 19:30 2.50 RUNCOtvP COMP MU hanger on 5" jt of DP for landing jt, pulled seals from hanger and RIH to verify space out and ck ok & POOH with hanger, re-installed seals 19:30 - 23:00 3.50 RUNCOtvP COMP Reverse circ 200 bbls of treated seawater with COREXIT corrosion inhibitor. RU Little Red and followed with 144 bbls of Diesel for freeze protection. Connected tbg and annulus and allowed to U-tube 23:00 - 23:30 0.50 RUNCOtvP COMP Landed 7 5/8" tbg in hanger with end of seals at 10,298', top of PBR set at 10,274', RILDS, st wt up 285K, dn wt 210K (block wt 35K) 23:30 - 00:00 0.50 RUNCOtvP COMP RU and began testing 75/8" tbg to 4,000 psi, 15 min into test Printed: 10/612003 1:52:12 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: PSI-05 PSI-05 DRILL +COMPLETE DOYON DOYON 141 Start: 9/11/2003 Rig Release: 9/30/2003 Rig Number: 141 Spud Date: 9/12/2003 End: 9/30/2003 9/29/2003 23:30 - 00:00 0.50 RUNCOI'vP 9/30/2003 00:00 - 02:00 2.00 RUNCOI'vP 02:00 - 02:30 0.50 RUNCOI'vP 02:30 - 03:30 1.00 RUNCOI'vP 03:30 - 04:45 1.25 RUNCOI'vP 04:45 - 07:30 2.75 RUNCOI'vP 07:30 - 09:00 1.50 RUNCOI'vP COMP COMP COMP COMP COMP COMP COMP at report time. NOTE: John Crisp with AOGCC waived witnessing of test on tbg & annulus Continue testing tubing to 4000 psi, Pressur test annulus to 4000 psi- OK, Test waived by AOGCC John Crisp. Lay down landing joint, Set two way check, Remove fluid from BOP stack, Test two way check to 1000 psi. Change top pipe rams to 3-1/2" x 6", Change out saver sub & bails on top drive. Nipple down BOPE Nipple up Tree adapter flange & Tree, Test same to 5000 psi f/ 10 min.- OK Rig up lubricator, Pull two check, Set BPV, Rig down lubricator, Secure well Note; Released rig to move to PSI-07 @ 0900 hrs 9/30/03 Printed: 10/6/2003 1:52:12 PM - e PSI-OS Prudhoe Bay Unit 50-029-23174-00-00 203-139 Accept: Spud: Release: 09/11/03 09/12/03 09/30/03 141 POST RIG WORK 10/23/03 PULLED BALL & ROD FROM 10325' SLM. PULLED RHC FROM 10329' SLM. PULLED RBX FROM "R" NIPPLE @ 10329'MD. DRIFT W/3 3/8" DUMMY GUN, SAMPLE BAILER, TO 10,892' SLM. BAILER HAD SAMPLE OF DRILLING MUD & FINES. 10/25/03 LOGGED TEMP SURVEY FROM SURFACE TO TO @ 100 FPM & FROM 8000' TO TD @ 40 FPM. LOGGED THREE RST SIGMA PASSES FROM TO (10896') TO 10500'. 12/20/03 RST SIGMA LOG TO MONITOR WATER MOVEMENT IN RESERVOIR. RAN FOUR SIGMA PASSES FROM 10986' TO 10500', TAGGED BOTTOM AT 10896'. 04/25/04 RUN RST SIGMA LOG TO MONITOR WATER MIGRATION IN FORMATION FROM PSI WATER FLOOD PROJECT. LOGGED THREE RST SIGMA PASSES FROM TO (10895') TO 10500' AS PER PROGRAM. LOGGED IN SANDSTONE MATRIX, NO PUMPING NEEDED, NEW WELL WITH NO PERFS LOADED WITH COMPLETION FLUIDS. 08/15/04 CORRELATED TO SWS RST LOG RAN 8/25/03. SINCE 8/25/03 GOG HAS MOVED FROM 10780' TO 10770'. THERE ARE ALSO NOTICABLE FLUID CHANGES FROM 10625' TO 10550'. TAGGED TD AT 10896'. LEAVE WELL SHUT IN. 08/16/04 CORRELATED TO SWS RST-SIGMA LOG RAN 8/25/03. PERFORATED INTERVAL: 10826' - 10866' WI 3.375" HSD, 60 PHASE, 6 SPF, 3406 PJ, HMX. TAG TD AT 10896'. LEAVE WELL SHUT IN. 08/19/04 RAN SBHPS, SEE LOG FOR TIMES & STOPS. SET 7" A-1 ISSSV DB-6 LOCK. (SERIAL # HVS-430) NOTIFIED DSO OF WELL STATUS. SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay Unit Well. . . . . . . . . . . . . . . . . . . . .: PSI-OS API number...............: 50-029-23174-00 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.......: 17.30 ft KB above permanent.......: N/A - Top Drive DF above permanent.......: 45.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: N 70.3108515 Departure (+E/W-)........: W 148.314845 Azimuth from rotary table to target: 314.19 degrees 25-Sep-2003 10:30:04 Spud date. . . . . . . . . . . . . . . . : Last survey date. . . . . . . . . : Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 12-Sep-2003 25-Sep-03 121 0.00 ft 10982.00 ft e ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2002 Magnetic date............: 12-Sep-2003 Magnetic field strength..: 1151.36 HCNT Magnetic dec (+E/W-).....: 25.94 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 1151.36 HCNT 80.88 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees e ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.94 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.94 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 -------- ------ ------- -------- ------ ------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (de g) 25-Sep-2003 10:30:04 Page 2 of 5 ------ -------- -------- ---------------- --------------- ------ -------- -------- ---------------- --------------- Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- ( ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 1 2 3 4 5 0.00 213.41 300.79 387.78 478.56 6 7 8 9 10 552.00 642.00 758.00 817 . 00 910.00 11 12 13 14 15 1026.51 1119.45 1212.53 1305.44 1397.42 16 17 18 19 20 1491.28 1583.66 1676.09 1767.74 1860.50 21 22 23 24 25 1955.03 2048.09 2140.80 2233.44 2325.90 26 27 28 29 30 2418.55 2510.46 2602.44 2694.67 2786.58 0.00 0.27 0.30 0.23 0.35 0.33 0.04 0.37 0.43 0.79 1.18 1. 85 1. 74 0.46 3.02 6.59 7.53 7.88 8.68 9.38 10.08 12.03 13.76 15.48 20.07 20.87 23.30 30.03 36.40 40.61 0.00 280.33 337.02 1. 55 347.27 314.30 11.63 103.74 115.99 111.12 116.35 126.49 127.97 241.31 293.93 309.11 311.49 314.12 316.00 317.71 314.99 314.28 312.66 312.38 313.89 316.11 316.84 315.46 313.94 313.13 0.00 213 .41 87.38 86.99 90.78 73.44 90.00 116.00 59.00 93.00 116.51 92.94 93.08 92.91 91.98 93.86 92.38 92.43 91. 65 92.76 94.53 93.06 92.71 92.64 92.46 92.65 91.91 91.98 92.23 91.91 0.00 213.41 300.79 387.78 478.56 551.99 641.99 757.99 816.99 909.99 1026.48 1119.39 1212.42 1305.32 1397.25 1490.77 1582.45 1674.04 1764.74 1856.35 1949.52 2040.84 2131.21 2220.85 2308.87 2395.67 2480.83 2562.99 2640.11 2712.02 0.00 0.42 0.80 1.13 1. 48 1. 88 2.16 1. 86 1. 48 0.56 -1. 32 -3.72 -6.61 -7.90 -5.52 2.17 13.49 25.88 39.07 53.61 69.58 87.42 108.10 131.47 159.69 192.08 226.60 267.83 318.33 375.53 0.00 0.09 0.34 0.72 1.17 1. 54 1. 75 1. 70 1. 56 1.18 0.36 -0.96 -2.72 -3.77 -2.97 1. 44 8.79 17.21 26.56 37.19 48.74 61. 27 75.48 91. 28 110.61 133.53 158.59 188.30 223.77 263.16 0.00 -0.49 -0.79 -0.87 -0.93 -1.13 -1.31 -0.93 -0.55 0.36 2.19 4.25 6.57 7.36 4.82 -1. 62 -10.27 -19.36 -28.67 -38.62 -49.65 -62.36 -77.39 -94.62 -115.18 -138.08 -161.87 -190.49 -226.42 -267.90 0.00 0.50 0.86 1.13 1. 50 1.91 2.19 1. 94 1. 66 1. 23 2.21 4.36 7.11 8.27 5.66 2.17 13.52 25.90 39.08 53.62 69.58 87.42 108.10 131.48 159.69 192.08 226.61 267.84 318.34 375.53 0.00 2'80.33 293.24 309.66 321.72 323.80 323.29 331.24 340.57 17.05 80.76 102.75 112.52 11 7.15 121.62 311.48 310.55 311.64 312.81 313.92 314.47 314.49 314.29 313.97 313.84 314.04 314.41 314.67 314.66 314.49 DLS (deg/ 100f) 0.00 0.13 0.31 0.15 0.15 0.26 0.34 0.32 0.18 0.39 0.34 0.77 0.13 2.12 3.01 4.01 1. 07 0.54 0.92 0.81 0.89 2.10 1.91 1. 86 4.99 1. 20 2.66 7.35 6.96 4.61 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ TIE-IN POINT MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA GYRO GYRO GYRO GYRO GYRO e MWD IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA e MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA SCHLUMBERGER Survey Report 25-Sep-2003 10:30:04 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth ( ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 32 33 34 35 2880.10 2972.83 3066.33 3158.68 3251.53 36 37 38 39 40 3344.07 3437.01 3529.56 3623.01 3714.64 41 42 43 44 45 3806.77 3900.60 3993.79 4087.69 4179.49 46 47 48 49 50 4271.75 4364.73 4458.37 4551.25 4644.18 51 52 53 54 55 4737.47 4829.70 4922.24 5015.15 5108.12 56 57 58 59 60 5201.61 5292.59 5386.61 5478.11 5491.83 45.37 47.51 43.84 41.78 43.95 46.33 49.62 50.57 49.31 47.37 47.74 47.29 46.49 45.76 46.84 46.81 45.63 46.00 46.05 46.42 46.39 46.90 47.16 46.49 46.08 48.08 47.88 48.16 48.69 48.69 312.18 313.08 315.05 314.90 314.49 315.52 315.01 316.07 314.95 313 .02 312.43 312.96 313.68 314.07 313.97 314.18 314.29 312.07 312.32 312.47 312.46 312.86 312.59 312.56 311.99 312.26 312.96 313.34 313.51 313.07 93.52 92.73 93.50 92.35 92.85 92.54 92.94 92.55 93.45 91.63 92.13 93.83 93.19 93.90 91.80 92.26 92.98 93.64 92.88 92.93 93.29 92.23 92.54 92.91 92.97 93.49 90.98 94.02 91.50 13.72 2780.41 2844.30 2909.63 2977.37 3045.42 3110.70 3172.91 3232.28 3292.42 3353.33 3415.51 3478.88 3542.57 3607.65 3671.07 3734.20 3798.53 3863.80 3928.29 3992.57 4056.89 4120.21 4183.29 4246.86 4311.11 4374.77 4435.67 4498.56 4559.28 4568.33 439.25 506.42 573.29 636.04 699.20 764.78 833.80 904.77 976.27 1044.72 1112.68 1181.85 1249.88 1317.56 1383.93 1451.21 1518.34 1585.47 1652.27 1719.35 1786.89 1853.92 1921.61 1989.34 2056.50 2124.92 2192.48 2262.36 2330.80 2341.11 306.34 351.85 398.33 442.69 487.11 533.50 582.53 633.21 684.23 731.78 777.90 824.82 871.50 918.41 964.53 1011.33 1058.16 1104.10 1148.99 1194.24 -314.80 -364.23 -412.31 -456.70 -501.60 -547.97 -596.56 -646.28 -696.39 -745.63 -795.57 -846.43 -895.93 -944.72 -992.45 -1040.78 -1088.88 -1137.85 -1187.36 -1236.93 1239.86 -1286.77 1285.30 -1336.08 1331.24 -1385.83 1377.08 -1435.72 1422.29 -1485.44 1468.21 -1536.22 1513.97 -1585.96 1561.77 -1636.95 1608.82 -1686.66 1615.89 -1694.17 439.25 506.42 573.29 636.04 699.20 764.78 833.80 904.78 976.29 1044.73 1112.69 1181.85 1249.88 1317.56 1383.93 1451.21 1518.34 1585.47 1652.28 1719.36 1786.90 1853.95 1921. 65 1989.39 2056.56 2124.99 2192.57 2262.46 2330.91 2341.21 314.22 314.01 314.01 314.11 314.16 314.23 314.32 314.41 314.50 314.46 314.36 314.26 314.21 314.19 314.18 314.18 314.18 314.14 314.06 313.99 313.94 313.89 313.85 313.81 313.76 313.70 313.67 313.65 313.65 313.65 DLS (deg/ 100f) 5.14 2.41 4.20 2.23 2.36 2.69 3.56 1. 35 1. 63 2.64 0.62 0.64 1. 03 0.83 1.18 0.17 1. 27 1. 75 0.20 0.41 0.03 0.64 0.35 0.72 0.63 2.15 0.61 0.42 0.60 2.41 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD I FR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA e MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA e MWD_IFR_MSA MWD_IFR_MSA MWD_IFR,---MSA MWD_IFR_MSA MWD_IFR_MSA SCHLUMBERGER Survey Report 25-Sep-2003 10:30:04 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 62 63 64 65 5579.23 5671.72 5764.81 5858.38 5951.07 66 67 68 69 70 6042.90 6136.17 6228.69 6322.54 6414.91 71 72 73 74 75 6507.84 6601.14 6694.74 6786.62 6880.49 76 77 78 79 80 6972.89 7066.90 7159.71 7251.69 7345.16 81 82 83 84 85 7435.58 7528.78 7621.20 7713.24 7806.26 86 87 88 89 90 7897.81 7990.69 8082.71 8176.66 8270.08 50.00 49.92 49.93 50.02 50.13 49.95 49.45 48.81 49.17 49.59 49.22 48.46 47.77 47.35 46.97 46.62 46.04 45.64 45.01 44.68 44.11 44.00 44.60 44.94 45.37 45.87 46.48 46.85 46.71 46.63 312.87 313.06 312.11 312.04 313.30 313.20 314.42 314.84 314.85 315.12 314.85 314.54 313.33 313 .52 313.16 313.09 311.82 311.33 310.90 310.87 311.47 312.52 314.76 315.19 316.79 316.51 316.49 317.49 316.89 316.95 87.40 92.49 93.09 93.57 92.69 91.83 93.27 92.52 93.85 92.37 92.93 93.30 93.60 91.88 93.87 92.40 94.01 92.81 91.98 93.47 90.42 93.20 92.42 92.04 93.02 91.55 92.88 92.02 93.95 93.42 4625.27 4684.78 4744.71 4804.88 4864.37 4923.35 4983.68 5044.22 5105.80 5165.94 5226.41 5287.81 5350.31 5412.31 5476.14 5539.39 5604.31 5668.97 5733.64 5799.91 5864.52 5931. 50 5997.64 6062.99 6128.59 6192.62 6256.93 6320.08 6384.42 6448.52 2407.40 2478.19 2549.39 2621.00 2692.05 2762.43 2833.56 2903.52 2974.33 3044.44 3115.00 3185.24 3254.92 3322.72 3391. 54 3458.88 3526.85 3593.36 3658.67 3724.48 3787.64 3852.40 3916.94 3981. 75 4047.67 4113 . 04 4179.99 4246.84 4315.21 4383.09 1661.08 -1742.68 1709.34 -1794.50 1757.54 -1846.94 1805.55 -1900.13 1853.73 -1952.39 1901.96 -2003.66 1951.20 -2054.99 2000.35 -2104.78 2050.29 -2154.99 2099.85 -2204.58 2149.74 -2254.49 2199.14 -2304.43 2247.49 -2354.60 2294.10 -2403.85 2341.34 -2453.91 2387.38 -2503.06 2433.29 -2553.23 2477.47 -2603.04 2520.48 -2652.31 2563.62 -2702.15 2605.27 -2749.77 2648.62 -2797.93 2693.17 -2844.63 2738.98 -2890.48 2786.42 -2936.30 2834.00 -2981.22 2882.60 -3027.34 2931.54 -3073.00 2981.77 -3119.52 3031.41 -3165.94 2407.51 2478.32 2549.54 2621.17 2692.24 2762.63 2833.76 2903.71 2974.51 3044.60 3115.14 3185.37 3255.05 3322.86 3391.69 3459.04 3527.02 3593.56 3658.91 3724.75 3787.96 3852.74 3917.28 3982.08 4047.96 4113.30 4180.22 4247.03 4315.37 4383.22 313.63 313.61 313.58 313.54 313 .52 313.51 313 .52 313.54 313.57 313.61 313.64 313.66 313.67 313.66 313.66 313.65 313.62 313.58 313.54 313 .49 313.45 313 .43 313 .43 313.46 313.50 313.55 313.60 313.65 313.71 313.76 DLS (deg/ 100f) 1. 51 0.18 0.78 0.11 1. 05 0.21 1.13 0.77 0.38 0.51 0.46 0.85 1. 21 0.48 0.49 0.38 1.16 0.57 0.76 0.35 0.78 0.79 1. 81 0.49 1. 30 0.59 0.66 0.89 0.49 0.10 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA e MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD IFR_MSA e MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA SCHLUMBERGER Survey Report 25-Sep-2003 10:30:04 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- Seq Measured # depth (ft) 96 97 98 99 100 101 102 103 104 105 106 107 108 109 110 111 112 113 114 115 116 117 118 119 120 Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Displ +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 91 92 93 94 95 8363.04 8455.32 8547.59 8640.33 8732.60 8825.45 8919.00 9011.09 9105.05 9198.18 9290.72 9383.68 9414.23 9475.32 9569.08 9662.27 9754.73 9847.44 9940.91 10033.66 10126.18 10219.56 10310.95 10405.02 10456.36 10565.60 10657.86 10752.40 10845.57 10908.97 121 10982.00 46.43 46.21 46.17 45.78 45.62 45.46 44.89 44.19 43.83 43.22 41.11 39.58 39.16 38.00 37.13 36.43 34.59 33.00 30.14 26.92 23.46 20.96 18.28 16.31 15.25 14.12 13.74 13.33 13.08 12.86 316.26 316.63 316.46 316.10 315.43 314.72 313.54 312.36 311.60 311.22 310.90 310.77 311.34 311.97 313.74 314.43 313.74 312.78 313.11 314.69 316.78 317.72 317.64 317.81 317.59 321.59 321.07 322.43 321.35 323.86 12.86 323.86 92.96 92.28 92.27 92.74 92.27 92.85 93.55 92.09 93.96 93.13 92.54 92.96 30.55 61.09 93.76 93.19 92.46 92.71 93.47 92.75 92.52 93.38 91.39 94.07 51. 34 109.24 92.26 94.54 93.17 63.40 73.03 6512.48 6576.21 6640.09 6704.54 6768.98 6834.02 6899.96 6965.60 7033.18 7100.71 7169.29 7240.14 7263.76 7311.52 7385.84 7460.48 7535.74 7612.78 7692.41 7773.89 7857.60 7944.04 8030.12 8119.93 8169.33 8275.01 8364.55 8456.47 8547.17 8608.96 8680.15 4450.49 4517.18 4583.71 4650.35 4716.36 4782.62 4848.97 4913 .54 4978.78 5042.84 5104.86 5164.94 5184.29 5222.34 5279.48 5335.28 5388.98 5440.54 5489.46 5533.75 5573.10 5608.34 5638.97 5666.88 5680.82 5708.38 5730.41 5752.35 5773.44 5787.51 3080.43 -3212.29 3128.79 -3258.27 3177.13 -3304.07 3225.32 -3350.15 3272.64 -3396.22 3319.56 -3443.02 3365.76 -3490.64 3409.77 -3537.91 3453.44 -3586.44 3495.86 -3634.54 3536.66 -3681.38 3576.01 -3726.91 3588.74 -3741.52 3614.06 -3769.98 3652.93 -3811.89 3691.74 -3851.97 3729.11 -3890.54 3764.45 -3928.09 3797.78 -3963.91 3828.47 -3995.84 3856.63 -4023.35 3882.54 -4047.32 3905.23 -4067.98 3925.92 -4086.79 3936.24 -4096.19 3957.29 -4114.16 3974.64 -4128.03 3992.01 -4141.73 4008.75 -4154.87 4020.06 -4163.51 4450.60 4517.26 4583.78 4650.40 4716.40 4782.66 4849.01 4913.59 4978.83 5042.91 5104.95 5165.05 5184.40 5222.47 5279.62 5335.41 5389.12 5440.68 5489.60 5533.89 5573.24 5608.47 5639.08 5666.98 5680.91 5708.46 5730.48 5752.40 5773.48 5787.54 313.80 313.84 313.88 313.91 313.94 313.95 313.96 313 .94 313.92 313.89 313.85 313.82 313.81 313.79 313.78 313.78 313.79 313.78 313.77 313.77 313.79 313.81 313.83 313.85 313.86 313.89 313.92 313.95 313.97 314.00 5803.53 4033.18 -4173.09 5803.56 314.02 DLS (deg/ lOaf) 0.58 0.38 0.14 0.50 0.55 0.57 1. 08 1.18 0.68 0.71 2.29 1. 65 1. 81 2.00 1. 48 0.87 2.04 1. 81 3.07 3.57 3.86 2.70 2.93 2.09 2.07 1. 39 0.43 0.55 0.38 0.95 0.00 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA e MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA e MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA MWD_IFR_MSA Projected to TD 1; PSI-05 Survey Report Schlu berDer Report Date: 25-Sep-03 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Vertical Section Azimuth: 314.190° Field: Prudhoe Bay Unit - Lisburne Vertical Section Origin: N 0.000 It, E 0.000 It Structure I Slot: East Dock (PSI) 1 PSI-5 TVD Reference Datum: KB Well: PSI-05 TVD Reference Elevation: 45.30 It relative to MSL Borehole: PSI-05 Sea Bed I Ground Level Elevation: 17.30 It relative to MSL UWVAPI#: 500292317400 Magnetic Declination: 25.735' Survey Name I Date: PSI·051 September 25, 2003 Total Field Strength: 57592.802 nT Tort I AHD I DDII ERD ratio: 144.759' 15828.59 It 16.0281 0.671 Magnetic Dip: 80.907° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 02, 2003 e Location LatILong: N 70.31085154, W 148.31484551 Magnetic Declination Model: BGGM 2003 Location Grid NlE Y!X: N 5966138.530 ftUS, E 707939.850 ftUS North Reference: True North Grid Convergence Angle: +1.58668292' Total Corr Mag North·> True North: +25.735' Grid Scale Factor: 0.99994912 Local Coordinates Referenced To: Well Head Measured Inclination Azimuth Course TVD Sub·Sea TVD Vertical NS EW Closure Closure DLS Northing Easting Latitude Longitude Depth Length Section Azimuth (It) (deg) ( deg) (ft) (It) (It) (ft) (ft) (ft) (It) (deg) (deg/100 ft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 -45.30 0.00 0.00 0.00 0.00 0.00 0.00 5966138.53 707939.85 N 70.31085154 W 148.31484551 213.41 0.27 280.33 213.41 213.41 168.11 0.42 0.09 ·0.49 0.50 280.33 0.13 5966138.61 707939.35 N 70.31085178 W 148.31484952 300.79 0.30 337.02 87.38 300.79 255.49 0.80 0.34 -0.79 0.86 293.24 0.31 5966138.85 707939.05 N 70.31085246 W 148.31485189 387.78 0.23 1.55 86.99 387.78 342.48 1.13 0.72 -0.87 1.13 309.66 0.15 5966139.23 707938.96 N 70.31085351 W 148.31485257 478.56 0.35 347.27 90.78 478.56 433.26 1.48 1.17 ·0.93 1.50 321.72 0.15 5966139.68 707938.89 N 70.31085475 W 148.31485302 552.00 0.33 314.30 73.44 551.99 506.69 1.88 1.54 -1.13 1.91 323.80 0.26 5966140.04 707938.68 N 70.31085575 W 148.31485465 642.00 0.04 11.63 90.00 641.99 596.69 2.16 1.75 ·1.31 2.19 323.29 0.34 5966140.25 707938.50 N 70.31085633 W 148.31485610 758.00 0.37 103.74 116.00 757.99 712.69 1.86 1.70 -0.93 1.94 331.24 0.32 5966140.21 707938.87 N 70.31085619 W 148.31485309 817.00 0.43 115.99 59.00 816.99 771.69 1.48 1.56 -0.55 1.66 340.57 0.18 5966140.08 707939.26 N 70.31085580 W 148.31484998 910.00 0.79 111.12 93.00 909.99 864.69 0.56 1.18 0.36 1.23 17.05 0.39 5966139.72 707940.18 N 70.31085475 W 148.3148_ 1026.51 1.18 116.35 116.51 1026.48 981.18 ·1.32 0.36 2.19 2.21 80.76 0.34 5966138.95 707942.02 N 70.31085251 W 148.31482781 1119.45 1.85 126.49 92.94 1119.39 1074.09 -3.72 ·0.96 4.25 4.36 102.75 0.77 5966137.69 707944.12 N 70.31084891 W 148.31481109 1212.53 1.74 127.97 93.08 1212.42 1167.12 -6.61 -2.72 6.57 7.11 112.52 0.13 5966135.99 707946.49 N 70.31084410 W 148.31479227 1305.44 0.46 241.31 92.91 1305.32 1260.02 -7.90 -3.77 7.36 8.27 117.15 2.12 5966134.96 707947.31 N 70.31084123 W 148.31478592 1397.42 3.02 293.93 91.98 1397.25 1351.95 -5.52 -2.97 4.82 5.66 121.62 3.01 5966135.70 707944.75 N 70.31084344 W 148.31480649 1491.28 6.59 309.11 93.86 1490.77 1445.47 2.17 1.44 -1.62 2.17 311.48 4.01 5966139.92 707938.19 N 70.31085546 W 148.31485868 1583.66 7.53 311.49 92.38 1582.45 1537.15 13.49 8.79 -10.27 13.52 310.55 1.07 5966147.03 707929.34 N 70.31087555 W 148.31492874 1676.09 7.88 314.12 92.43 1674.04 1628.74 25.88 17.21 -19.36 25.90 311.64 0.54 5966155.20 707920.02 N 70.31089856 W 148.31500235 1767.74 8.68 316.00 91.65 1764.74 1719.44 39.07 26.56 ·28.67 39.08 312.81 0.92 5966164.29 707910.46 N 70.31092410 W 148.31507782 1860.50 9.38 317.71 92.76 1856.35 1811.05 53.61 37.19 -38.62 53.62 313.92 0.81 5966174.63 707900.22 N 70.31095314 W 148.31515843 1955.03 10.08 314.99 94.53 1949.52 1904.22 69.58 48.74 -49.65 69.58 314.47 0.89 5966185.87 707888.87 N 70.31098468 W 148.31524783 Version DO 3.1 RT ( d031 rt_546) 3.1 RT-SP3.03 PSI-5\PSI-05\P SI-05\PSI-05 Generated 10/2/2003 4:26 PM Page 1 of 4 Measured Inclination Azimuth Course rVD Sub-Sea rVD Vertical NS EW Closure Closure DLS Northing Easting Latitude Longitude Depth Length Section Azimuth (It) ( deg) ( deg) (It) (It) (It) (It) (It) (It) (It) ( deg) (degf100 It) (flUS) (ltUS) 2048.09 12.03 314.28 93.06 2040.85 1995.55 87.42 61.27 -62.36 87.42 314.49 2.10 5966198.04 707875.82 N 70.31101891 W 148.31535077 2140.80 13.76 312.66 92.71 2131.21 2085.91 108.10 75.48 -77.39 108.10 314.29 1.91 5966211.84 707860.41 N 70.31105775 W 148.31547252 2233.44 15.48 312.38 92.64 2220.85 2175.55 131.47 91.28 -94.62 131.48 313.97 1.86 5966227.15 707842.74 N 70.31110092 W 148.31561217 2325.90 20.07 313.89 92.46 2308.87 2263.57 159.69 110.61 -115.18 159.69 313.84 4.99 5966245.90 707821.66 N 70.31115371 W 148.31577875 2418.55 20.87 316.11 92.65 2395.67 2350.37 192.08 133.53 -138.08 192.08 314.04 1.20 5966268.17 707798.13 N 70.31121632 W 148.31596429 2510.46 23.30 316.84 91.91 2480.83 2435.53 226.60 158.59 -161.87 226.61 314.41 2.66 5966292.57 707773.66 N 70.31128478 W 148.31615703 2602.44 30.03 315.46 91.98 2562.99 2517.69 267.83 188.30 -190.49 267.84 314.67 7.35 5966321.47 707744.23 N 70.31136594 W 148.31638893 2694.67 36.40 313.94 92.23 2640.11 2594.81 318.33 223.77 -226.42 318.34 314.66 6.96 5966355.93 707707.34 N 70.31146285 W 148.31668006 2786.58 40.61 313.13 91.91 2712.02 2666.72 375.53 263.16 -267.90 375.53 314.49 4.61 5966394.16 707664.78 N 70.31157046 W 148.31701622 2880.10 45.37 312.18 93.52 2780.41 2735.11 439.25 306.34 -314.80 439.25 314.22 5.14 5966436.02 707616.70 N 70.31168842 W 148.317. 2972.83 47.51 313.08 92.73 2844.30 2799.00 506.42 351.85 -364.23 506.42 314.01 2.41 5966480.14 707566.04 N 70.31181275 W 148.317 3066.33 43.84 315.05 93.50 2909.63 2864.33 573.29 398.33 -412.31 573.29 314.01 4.20 5966525.27 707516.69 N 70.31193972 W 148.3181 3 3158.68 41.78 314.90 92.35 2977.37 2932.07 636.04 442.69 -456.70 636.04 314.11 2.23 5966568.38 707471.09 N 70.31206090 W 148.31854605 3251.53 43.95 314.49 92.85 3045.42 3000.12 699.20 487.11 -501.60 699.20 314.16 2.36 5966611.54 707424.98 N 70.31218224 W 148.31890990 3344.07 46.33 315.52 92.54 3110.70 3065.40 764.78 533.50 -547.97 764.78 314.23 2.69 5966656.63 707377 .35 N 70.31230896 W 148.31928562 3437.01 49.62 315.01 92.94 3172.91 3127.61 833.80 582.53 -596.56 833.80 314.32 3.56 5966704.29 707327.42 N 70.31244290 W 148.31967938 3529.56 50.57 316.07 92.55 3232.28 3186.98 904.77 633.21 -646.28 904.78 314.41 1.35 5966753.57 707276.32 N 70.31258133 W 148.32008231 3623.01 49.31 314.95 93.45 3292.42 3247.12 976.27 684.23 -696.39 976.29 314.50 1.63 5966803.18 707224.82 N 70.31272072 W 148.32048843 3714.64 47.37 313.02 91.63 3353.33 3308.03 1044.72 731.78 -745.63 1044.73 314.46 2.64 5966849.34 707174.28 N 70.31285060 W 148.32088744 3806.77 47.74 312.43 92.13 3415.51 3370.21 1112.68 777.90 -795.57 1112.69 314.36 0.62 5966894.07 707123.08 N 70.31297659 W 148.32129218 3900.60 47.29 312.96 93.83 3478.88 3433.58 1181.85 824.82 -846.43 1181.85 314.26 0.64 5966939.56 707070.95 N 70.31310476 W 148.32170433 3993.79 46.49 313.68 93.19 3542.57 3497.27 1249.88 871.50 -895.93 1249.88 314.21 1.03 5966984.84 707020.18 N 70.31323225 W 148.32210545 4087.69 45.76 314.07 93.90 3607.65 3562.35 1317.56 918.41 -944.72 1317.56 314.19 0.83 5967030.38 706970.11 N 70.31336039 W 148.32250089 4179.49 46.84 313.97 91.80 3671.07 3625.77 1383.93 964.53 -992.45 1383.93 314.18 1.18 5967075.16 706921.13 N 70.31348637 W 148.32288767 4271.75 46.81 314.18 92.26 3734.20 3688.90 1451.21 1011.33 -1040.78 1451.21 314.18 0.17 5967120.60 706871.52 N 70.31361421 W 148.32327942 4364.73 45.63 314.29 92.98 3798.53 3753.23 1518.34 1058.16 -1088.88 1518.34 314.18 1.27 5967166.08 706822.14 N 70.31374213 W 148.32366924 4458.37 46.00 312.07 93.64 3863.80 3818.50 1585.47 1104.10 -1137.85 1585.47 314.14 1.75 5967210.64 706771.93 N 70.31386761 W 148.32406605 4551.25 46.05 312.32 92.88 3928.29 3882.99 1652.27 1148.99 -1187.36 1652.28 314.06 0.20 5967254.15 706721.19 N 70.31399024 W 148.3244_ 4644.18 46.42 312.47 92.93 3992.57 3947.27 1719.35 1194.24 -1236.93 1719.36 313.99 0.41 5967298.00 706670.40 N 70.31411384 W 148.3248 4737.47 46.39 312.46 93.29 4056.90 4011.60 1786.89 1239.86 -1286.77 1786.90 313.94 0.03 5967342.22 706619.31 N 70.31423843 W 148.32527305 4829.70 46.90 312.86 92.23 4120.21 4074.91 1853.92 1285.30 -1336.08 1853.95 313.89 0.64 5967386.28 706568.76 N 70.31436256 W 148.32567275 4922.24 47.16 312.59 92.54 4183.29 4137.99 1921.61 1331.24 -1385.83 1921.65 313.85 0.35 5967430.82 706517.77 N 70.31448804 W 148.32607592 5015.15 46.49 312.56 92.91 4246.86 4201.56 1989.34 1377.08 -1435.72 1989.39 313.81 0.72 5967475.26 706466.63 N 70.31461325 W 148.32648032 5108.12 46.08 311.99 92.97 4311.11 4265.81 2056.50 1422.29 -1485.44 2056.56 313.76 0.63 5967519.07 706415.68 N 70.31473671 W 148.32688332 5201.61 48.08 312.26 93.49 4374.77 4329.47 2124.92 1468.21 -1536.22 2124.99 313.70 2.15 5967563.56 706363.65 N 70.31486214 W 148.32729485 5292.59 47.88 312.96 90.98 4435.67 4390.37 2192.48 1513.97 -1585.96 2192.57 313.67 0.61 5967607.92 706312.66 N 70.31498712 W 148.32769806 5386.61 48.16 313.34 94.02 4498.56 4453.26 2262.36 1561.77 -1636.95 2262.46 313.65 0.42 5967654.29 706260.37 N70.31511767 W148.32811137 5478.11 48.69 313.51 91.50 4559.28 4513.98 2330.80 1608.82 -1686.66 2330.91 313.65 0.60 5967699.95 706209.38 N 70.31524619 W 148.32851433 5491.83 48.69 313.07 13.72 4568.34 4523.04 2341 .11 1615.89 -1694.17 2341.21 313.65 2.41 5967706.80 706201.68 N 70.31526549 W 148.32857513 Version DO 3.1 RT ( d031 rC546 ) 3.1 RT-SP3.03 P SI-5\PS -05\PS 1-05\PS 1-05 Generated 10/2/2003 4:26 PM Page 2 of 4 Measured Inclination Azimuth Course TVD Sub-Sea TVD Vertical NS fW Closure Closure DLS Northing fasting Latitude Longitude Depth Length Section Azimuth (It) ( deg) ( deg) (It) (It) ( It) (It) (It) (It) (It) ( deg) (deg/100 It) (ltUS) (ltUS) 5579.23 50.00 312.87 87.40 4625.28 4579.98 2407.40 1661.08 -1742.68 2407.51 313.63 1.51 5967750.63 706151.94 N 70.31538892 W 148.32896840 5671 .72 49.92 313.06 92.49 4684.78 4639.48 2478.19 1709.34 -1794.50 2478.32 313.61 0.18 5967797.44 706098.81 N 70.31552073 W 148.32938842 5764.81 49.93 312.11 93.09 4744.71 4699.41 2549.39 1757.54 -1846.94 2549.54 313.58 0.78 5967844.17 706045.05 N 70.31565238 W 148.32981354 5858.38 50.02 312.04 93.57 4804.89 4759.59 2621.00 1805.56 -1900.13 2621.17 313.54 0.11 5967890.69 705990.56 N 70.31578352 W 148.33024467 5951.07 50.13 313.30 92.69 4864.37 4819.07 2692.05 1853.73 -1952.39 2692.24 313.52 1.05 5967937.40 705936.98 N 70.31591510 W 148.33066832 6042.90 49.95 313.20 91.83 4923.35 4878.05 2762.43 1901.96 -2003.66 2762.63 313.51 0.21 5967984.18 705884.40 N 70.31604681 W 148.33108391 6136.17 49.45 314.42 93.27 4983.68 4938.38 2833.56 1951.20 -2054.99 2833.76 313.52 1.13 5968031.98 705831.73 N 70.31618130 W 148.33150004 6228.69 48.81 314.84 92.52 5044.22 4998.92 2903.52 2000.35 -2104.78 2903.71 313.54 0.77 5968079.73 705780.60 N 70.31631553 W 148.33190368 6322.54 49.17 314.85 93.85 5105.80 5060.50 2974.33 2050.29 -2154.99 2974.51 313.57 0.38 5968128.26 705729.03 N 70.31645193 W 148.33231073 6414.91 49.59 315.12 92.37 5165.94 5120.64 3044.44 2099.85 -2204.58 3044.60 313.61 0.51 5968176.43 705678.09 N 70.31658729 W 148.33271 6507.84 49.22 314.85 92.93 5226.41 5181.11 3115.00 2149.74 -2254.49 3115.14 313.64 0.46 5968224.91 705626.82 N 70.31672353 W 148.33311 7 6601.14 48.46 314.54 93.30 5287.81 5242.51 3185.24 2199.14 -2304.43 3185.37 313.66 0.85 5968272.91 705575.54 N 70.31685846 W 148.33352217 6694.74 47.77 313.33 93.60 5350.31 5305.01 3254.92 2247.49 -2354.60 3255.05 313.67 1.21 5968319.85 705524.05 N 70.31699051 W 148.33392896 6786.62 47.35 313.52 91.88 5412.31 5367.01 3322.72 2294.10 -2403.85 3322.86 313.66 0.48 5968365.08 705473.53 N 70.31711780 W 148.33432820 6880.49 46.97 313.16 93.87 5476.14 5430.84 3391.54 2341 .34 -2453.91 3391.69 313.66 0.49 5968410.91 705422.19 N 70.31724681 W 148.33473405 6972.89 46.62 313.09 92.40 5539.39 5494.09 3458.88 2387.38 -2503.06 3459.04 313.64 0.38 5968455.57 705371.78 N 70.31737255 W 148.33513258 7066.90 46.04 311.82 94.01 5604.31 5559.01 3526.85 2433.29 -2553.23 3527.02 313.62 1.16 5968500.06 705320.36 N 70.31749790 W 148.33553930 7159.71 45.64 311.33 92.81 5668.97 5623.67 3593.36 2477.47 -2603.04 3593.56 313.58 0.57 5968542.85 705269.35 N 70.31761856 W 148.33594312 7251.69 45.01 310.90 91.98 5733.64 5688.34 3658.67 2520.48 -2652.31 3658.91 313.54 0.76 5968584.47 705218.91 N 70.31773602 W 148.33634262 7345.16 44.68 310.87 93.47 5799.91 5754.61 3724.48 2563.62 -2702.15 3724.75 313.49 0.35 5968626.22 705167.90 N 70.31785383 W 148.33674665 7435.58 44.11 311.47 90.42 5864.52 5819.22 3787.64 2605.27 -2749.77 3787.96 313.45 0.78 5968666.52 705119.15 N 70.31796754 W 148.33713272 7528.78 44.00 312.52 93.20 5931.50 5886.20 3852.40 2648.62 -2797.93 3852.74 313.43 0.79 5968708.53 705069.81 N 70.31808595 W 148.33752322 7621.20 44.60 314.76 92.42 5997.65 5952.35 3916.94 2693.17 -2844.63 3917.28 313.43 1.81 5968751.76 705021.89 N 70.31820759 W 148.33790188 7713.24 44.94 315.19 92.04 6062.99 6017.69 3981.75 2738.98 -2890.48 3982.08 313.46 0.49 5968796.29 704974.79 N 70.31833271 W 148.33827368 7806.26 45.37 316.79 93.02 6128.59 6083.29 4047.67 2786.42 -2936.30 4047.96 313.50 1.30 5968842.43 704927.68 N 70.31846224 W 148.33864520 7897.81 45.87 316.51 91.55 6192.62 6147.32 4113.04 2834.00 -2981.22 4113.30 313.55 0.59 5968888.75 704881.47 N 70.31859218 W 148.33900941 7990.69 46.48 316.49 92.88 6256.93 6211.63 4179.99 2882.60 -3027.34 4180.22 313.60 0.66 5968936.05 704834.01 N 70.31872492 W 148.3393_ 8082.71 46.85 317.49 92.02 6320.08 6274.78 4246.84 2931.55 -3073.00 4247.03 313.65 0.89 5968983.71 704787.03 N 70.31885858 W 148.3397 8176.66 46.71 316.89 93.95 6384.42 6339.12 4315.21 2981.77 -3119.52 4315.37 313.71 0.49 5969032.63 704739.13 N 70.31899574 W 148.34013092 8270.08 46.63 316.95 93.42 6448.53 6403.23 4383.09 3031.41 -3165.94 4383.22 313.76 0.10 5969080.96 704691.36 N 70.31913128 W 148.34050730 8363.04 46.43 316.26 92.96 6512.48 6467.18 4450.49 3080.43 -3212.29 4450.60 313.80 0.58 5969128.67 704643.68 N 70.31926515 W 148.34088315 8455.32 46.21 316.63 92.28 6576.21 6530.91 4517.18 3128.79 -3258.27 4517.26 313.84 0.38 5969175.74 704596.37 N 70.31939723 W 148.34125607 8547.59 46.17 316.46 92.27 6640.09 6594.79 4583.71 3177.13 -3304.07 4583.78 313.88 0.14 5969222.79 704549.26 N 70.31952922 W 148.34162745 8640.33 45.78 316.10 92.74 6704.54 6659.24 4650.35 3225.32 -3350.15 4650.40 313.91 0.50 5969269.69 704501.86 N 70.31966083 W 148.34200119 8732.60 45.62 315.43 92.27 6768.98 6723.68 4716.36 3272.64 -3396.22 4716.40 313.94 0.55 5969315.70 704454.50 N 70.31979003 W 148.34237477 8825.45 45.46 314.72 92.85 6834.02 6788.72 4782.62 3319.56 -3443.02 4782.66 313.95 0.57 5969361.31 704406.42 N 70.31991816 W 148.34275429 8919.00 44.89 313.54 93.55 6899.97 6854.67 4848.97 3365.76 -3490.64 4849.01 313.96 1.08 5969406.17 704357.54 N 70.32004431 W 148.34314047 9011.09 44.19 312.36 92.09 6965.60 6920.30 4913.54 3409.77 -3537.91 4913.59 313.94 1.18 5969448.86 704309.07 N 70.32016449 W 148.34352383 Version DO 3.1 RT ( d031 rC546 ) 3.1 RT-SP3.03 PS 1-5\P S 1-05\PS 1-05\PSI-05 Generated 10/2/2003 4:26 PM Page 3 of 4 · .. Measured Inclination Azimuth Course TVD Sub-Sea TVD Vertical NS EW Closure Closure DLS Northing Easting Latitude Longitude Depth Length Section Azimuth (II) (deg) ( deg) (II) (It) (It) (It) (It) (It) (It) ( deg) (deg/100 It) (flUS) (ltUS) 9105.05 43.83 311.60 93.96 7033.18 6987.88 4978.78 3453.44 -3586.44 4978.83 313.92 0.68 5969491.16 704259.36 N 70.32028372 W 148.34391737 9198.18 43.22 311.22 93.13 7100.71 7055.41 5042.84 3495.86 -3634.54 5042.91 313.89 0.71 5969532.23 704210.10 N 70.32039955 W 148.34430744 9290.72 41.11 310.90 92.54 7169.30 7124.00 5104.86 3536.66 -3681.38 5104.95 313.85 2.29 5969571.72 704162.16 N 70.32051096 W 148.34468724 9383.68 39.58 310.77 92.96 7240.14 7194.84 5164.94 3576.01 -3726.91 5165.05 313.82 1.65 5969609.79 704115.56 N 70.32061840 W 148.34505648 9414.23 39.16 311.34 30.55 7263.76 7218.46 5184.29 3588.74 -3741.52 5184.40 313.81 1.81 5969622.11 704100.60 N 70.32065315 W 148.34517499 9475.32 38.00 311 .97 61.09 7311.52 7266.22 5222.34 3614.06 -3769.98 5222.47 313.79 2.00 5969646.63 704071.45 N 70.32072228 W 148.34540583 9569.08 37.13 313.74 93.76 7385.84 7340.54 5279.48 3652.93 -3811.89 5279.62 313.78 1.48 5969684.32 704028.48 N 70.32082841 W 148.34574569 9662.27 36.43 314.43 93.19 7460.48 7415.18 5335.28 3691.74 -3851.97 5335.41 313.78 0.87 5969722.01 703987.34 N 70.32093440 W 148.34607075 9754.73 34.59 313.74 92.46 7535.74 7490.44 5388.98 3729.11 -3890.54 5389.11 313.79 2.04 5969758.29 703947.76 N 70.32103642 W 148.34638357 9847.44 33.00 312.78 92.71 7612.78 7567.48 5440.54 3764.45 -3928.09 5440.68 313.78 1.81 5969792.58 703909.25 N 70.32113293 W 148.346. 9940.91 30.14 313.11 93.47 7692.41 7647.11 5489.46 3797.79 -3963.91 5489.60 313.77 3.07 5969824.91 703872.52 N 70.32122394 W 148.346 10033.66 26.92 314.69 92.75 7773.89 7728.59 5533.75 3828.47 -3995.84 5533.89 313.77 3.57 5969854.70 703839.75 N 70.32130773 W 148.3472 1 10126.18 23.46 316.78 92.52 7857.60 7812.30 5573.10 3856.63 -4023.35 5573.24 313.79 3.86 5969882.08 703811.47 N 70.32138462 W 148.34746074 10219.56 20.96 317.72 93.38 7944.04 7898.74 5608.34 3882.54 -4047.32 5608.47 313.81 2.70 5969907.31 703786.80 N 70.32145536 W 148.34765515 10310.95 18.28 317.64 91.39 8030.12 7984.82 5638.97 3905.23 -4067.98 5639.08 313.83 2.93 5969929.42 703765.52 N 70.32151731 W 148.34782272 10405.02 16.31 317.81 94.07 8119.93 8074.63 5666.88 3925.92 -4086.79 5666.98 313.85 2.09 5969949.58 703746.14 N 70.32157381 W 148.34797532 10456.36 15.25 317.59 51.34 8169.34 8124.04 5680.82 3936.24 -4096.19 5680.91 313.86 2.07 5969959.64 703736.46 N 70.32160200 W 148.34805153 10565.60 14.12 321.59 109.24 8275.01 8229.71 5708.38 3957.29 -4114.16 5708.46 313.89 1.39 5969980.19 703717.92 N 70.32165948 W 148.34819729 10657.86 13.74 321.07 92.26 8364.56 8319.26 5730.41 3974.64 -4128.03 5730.48 313.92 0.43 5969997.14 703703.57 N 70.32170684 W 148.34830986 10752.40 13.33 322.43 94.54 8456.47 8411.17 5752.35 3992.01 -4141.73 5752.40 313.95 0.55 5970014.12 703689.39 N 70.32175428 W 148.34842100 10845.57 13.08 321.35 93.17 8547.18 8501.88 5773.44 4008.76 -4154.87 5773.48 313.97 0.38 5970030.50 703675.80 N 70.32180001 W 148.34852754 10908.97 12.86 323.86 63.40 8608.96 8563.66 5787.51 4020.06 -4163.51 5787.54 314.00 0.95 5970041.55 703666.85 N 70.32183087 W 148.34859765 10982.00 12.86 323.86 73.03 8680.16 8634.86 5803.53 4033.18 -4173.09 5803.56 314.02 0.00 5970054.41 703656.91 N 70.32186672 W 148.34867542 Leqal Description: Northinq (Y) [nUS] Eastinq (X) [nus] Surface: 3838 FSL 4465 FEL S15 T11N R15E UM 5966138.53 707939.85 BHL: 2589 FSL 3350 FEL S9 T11 N R15E UM 5970054.41 703656.91 - Version DO 3.1RT (d031rt_546) 3.1RT-SP3.03 P SI-5\PSI-05\PSI-05\P SI-05 Generated 10/2/2003 4:26 PM Page 4 of 4 , /13-3IS" CSG, 68#, L-BO, ID = 12.41S" H PSI-OS J. -h ! t J ~ ~ ~NOttS' e " .. 1REE= 7-1/16"SKCIW WELLHEAD = 13-5/8" SK FMC ACTlJII. TOR = KB.-î:Lê/;;-' -.--" ""45,30; SF. ÉL EV-;;' --Q22'. 60' ~i<ÖP;'~ "."....~-,-- ,- ,- ,~~ '130-5' rlÍìixÅnglë ;;-'--Sf@'3530' -DJtum'Mj"; "''''-~10844'7 i'iitumTi7Ö;" ~" -"85b~ä'ss 1004' H13-3IS" TAM PORT COLLAR / 2207' H7-S/S" X7" XO, ID =6.276"1 2208' H7" CAMCO œ NIP, ID =6.000" , 2210' H7" X 7-5IS" XO, ID = 6.276" , 5544' r 7" TBG, 26#, .0383 bpf, ID = 6.276" H 10353' I 10237' H7-S/S" X 7" XO,ID = 6.276' I 10248' H7" HES RNIP, ID= S.963" / J 10270' HA3R, ID =6.060'" Z--i 10309' H 9-S/S" X 7" BKR SABL-3 A<R, ID = 6.0" / I 10329' Hr'HESRNIP,ID=S.963" , 1 10340' H r' HES RN NIP, ID = S. 770" 1 10353' H 7" WLEG, ID = 6.276" I I H B..MD TT NOT LOGGED 17-S/S" ìBG, 29.7#, L-BO, .04S9 bpf, D = 6.87S" H 10237' '. Minimum 10 = 5.770" @ 10340" 7" HES RN NIPPLE 19-518" CSG, 47#1 FT, S-9S, ID=8.681" ~ 1 Z I ÆRFORA TON SUM\1ARY REF LOG: RST ON 10/2S/03 A NGLE AT TOP ÆRF: 13 @ 10826' Note: Refer to Production DB for historical perf data SIZE SPF INfERv' AL Opn/Sqz DA TE 3-3/S" 6 1 0826 - 1 0866 0 OS/16/o4 ð" 8r---1 10389' H9-S/S" X 7" BKRZXP LNRTOPPKR WI llEBACK SLV 9-S/S"CSG,47#,L-SO,ID=S.681" H 10512' r--J ~ ~ 10939' 17" Lf\IR, 26#, L-BO. .0383 bpf, ID = 6.276" H 10982' ~ [)ð. TE REV BY COMIVENTS 10/28/03 DACITLI- ORIGINAL COMPLETION 10/25103 CJS/1LP A 00 ÆRF DATE REV BY COMrvENfS PRUDHOE BAY lJo.JlT WELL: PSI-OS PERMT fob: 2031390 API fob: SO-029-23174 SEC 1S, T11 N, R1SE, 1441' FNL & S1S' FWL BP Exploration (Alaska) Sc~bn~epg8l' NO. 3098 01/23/04 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: ~tate of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Prints PSI-OS 40009587 OH EDIT LWD ARC & ADN (PDC) 09/25/03 PSI-OS 40009587 MD VISION RESISTIVITY 09/25/03 1 PSI·05 40009587 TVD VISION RESISTIVITY 09/25/03 1 PSI-OS 40009587 MD VISION DENINEUTRON 09125/03 1 PSI-OS 40009587 TVD VISION DENINEUTRON 09125/03 1 PSI-OS 10703940 RST·SIGMA 10/25/03 1 PSI-05 10679041 RST-SIGMA 12/20/03 1 D-18A fn\ '- \('Á~ 10564487 RST-SIGMA 06/19/03 1 05-08 ~I -o~ 10674406 RST-SIGMA 12/31/03 1 02-04A ~o - \ g 10728382 MCNL 12/08/03 1 E-08A . --rF-{...... ...., 10728384 PRODUCTION PROFILE 01/01/04 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 CD . 1 //1 ~ 9. '"3 1 1 1 1 1 ~~~rA.', ~'3~ ?'2,,~qq $390 . Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Beth -.,,, t' ,->-, \<...f'; '\ Si. A N'-.-"') 1.Sl.~ ;..~~ Received by: Date Delivered: ~6~\\"\ ~ RECEIVED JAH30~ A,¡~~a Oil & Gas Cons. Commisaioo fIt·.f'W~. 8""i-~i\1'J~~Y . . &03-):3/ MWDILWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Usa Weepie Well No PSI-OS Date Dispatched: 28-Sep-03 Installation/Rig Doyon 141 Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 . ''"-~ . '. . Please sign and return to: James H. Johnson Received By: '~l"'-"i¥'\~ ,,Ç c..'--~~ BP Exploration (Alaska) Inc. -.- Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 ~~, c ".u'D\Y\~-:> . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~(JIL \Z\\\ø \03 Email to:Winton_Aubert@admin.state.ak.us;BobJleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us ~ OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay I PBU I PSI 09/30103 Ferguson Packer Depth Pretest Initial 15 Min. 30 Min. wellPSI-05 Type Inj. Is TVD I 8,028' TUbingl 01 3,1501 3,1501 3,150lnterval P.T.D. 2031390 Type test P Test psi 2,007 Casing ° 4,000 3,995 3,990 P/F Notes: Pre-injection MITIA. An AOGCC witnessed MITIA will be performed once the well is POI. o P weill I Type Inj. I I TVD I I TUb~ngl I,nterval P.T.D. Type test Test psi Casing P/F Notes: weill Type Inj. I TVD I I TUb~ngl ,nterval P.T.D. Type test Test psi Casing PIF Notes: well Type Inj. I TVD I TUb~ng Interval P.T.D. Type test Test psi Casing PIF Notes: weill Type Inj. I TVD I I TUb~ngl ,nterval P.T.D. Type test Test psi Casing P/F Notes: Test Details: Pressure readings taken from a chart 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 T emperature 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-05 9-30-03-1.xls ,- / ,/ í FRANK H. MURKOWSKI, GOVERNOR ¡ / AI4ASIiA OIL AND GAS CONSERVATION COMMISSION / Lowell Crane . Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 f / 333 W. P" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit PSI-OS BP Exploration (Alaska), Inc. Pennit No: 203-139 Surface Location: 3838' NSL, 4465' WEL, Sec. 15, TIIN, RI5E, UM Bottomhole Location: 2664' NSL, 3401' WEL, Sec. 09, TIIN, RI5E, UM Dear Mr. Crane: Enclosed is the approved application for pennit to drill the above referenced development well. This pennit to drill does not exempt you from obtaining additional pennÍts or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennÍt 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. 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, 6i£:Lvt Commissioner BY ORDER OF THE COMMISSION DATED thisL~ay of August, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section . STATE OF ALASKA .. ALASKA (!J. AND GAS CONSERVATION CO_SSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test B Service 5. Bond: a Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 10898' TVD 8665' 7. Property Designation: ADL 034631 B Drill 0 Redri" 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: 3838' NSL, 4465' WEL, SEC. 15, T11N, R15E, UM Top of Productive Horizon: 2564' NSL, 3299' WEL, SEC. 09, T11N, R15E, UM Total Depth: 2664' NSL, 3401' WEL, SEC. 09, T11 N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-707940 y-5966139 Zone'ÂSP4 16. Deviated Wells: Kickoff Depth 18.. .Casingprogråm Sizé Casinç¡ 20" x 34" 13-3/8" 9-518" 650 ft Maximum Hole Angle Hole 42" 16" 12-114" 8-1/2" Coupling Welded BTC BTC-M BTC-M 7" Weight Grade 91.51# H-40 68# L-80 40# 147# S-95 I L-80 26# L-80 vJ61t ~ll~ll-Or.')! Qfi,'dl.· V ... v "{( 11 o Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU PSI-OS ..,./ 12. Field I Pool(s): Prudhoe Bay Field I Prudhoe Bay Pool 8. Land Use Permit: NIA 9. Acres in Property: 2560 13. Approximate Spud Date: 09/01/03 / 14. Distance to Nearest Property: 21,183 / 46° 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool (Height above GL): 45 feet PSI-06 is 3D' away at surface / 17. Anticipated pressure (see 20 MC 25.035) Max. Downhole Pressure: 3852 psig. Max. Surface Pressure: 2991 tpsig Length MD TVD MD TVD (includinç¡ stage data) 80' Surface Surface 113' 113' 260 sx Arctic Set (Approx.) 5460' Surface Surface 5488' 4583' 1273 sx ArcticSet III Lite, 603 sX 'G" 10433' Surface Surface 10461' 8252' 629 sx Class 'G' 587' 10361' 8158' 10898' 8665' 140 sx Class 'G' 19. PRESENTWELL..cQNDITIONSUMMARY(Tóbecórnpl~ted.fOrR~ÔllANPR$+entrYOp~'"ªtiqos) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD Junk (measured): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Title Senior Drilling Engineer Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments a Filing Fee 0 BOP Sketch a Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): a Drilling Program 0 Time vs Depth Plot o Seabed Report 0 Drilling Fluid Program o Shallow Hazard Analysis a20 MC 25.050 Requirements Date: ¡¡:c¡o- it. ~~ Contact Rob Tirpack, 564-4166 Phone API Number: Permit Ap¡;¡c.oya) I D ~ See cover letter for Number: 2. <:)..;> -I. ? '9' 50- C> 2- 9 -- .2.1 J 7 L./ Date: t:3 / I B oJ other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required 0 Yes ~ No Hydrogen Sulfide Measures RI Yes 0 No Directional Survey Required ~ Yes 0 No Other: T~st ßoPE to 4ft/Of:> pii. ,vU:IJ Q/iI-\.(M..t. 7¡'¿4;:~ tc~ ~u.lv-.eJ . ç(.ý ~o ÞrA<... l.S. '+12.. Cb), p~e..r ~i-ê- Y'tÕV<..tK.t.~~'f ,^~ W~\fe..cl. ~ /:J / \ BY ORDER OF Æ'~8. /03 Approved By: '^ / ~~ ~O~~\rSAOiER THE COMMISSION Date 1///. Y 4 Form 10-401 Revised 3/2003 0 K ! t:; I ì ~ 1-\ ubmit In Duplicate e I Well Name: I e PSI-OS Drill and Complete Summary I Type of Well (producer or injector): 1 Injector - Water Surface Location: (As Staked) Target Location: Bottom Hole Location: x = 707,940 / Y = 5,966,139 1441' FNL, 815' FWL, Sec. 15, T11N, R15E X = 703,709 / Y = 5,970,030 2716'FNL, 1981'FWL, Sec. 09, T11N, R15E X = 703,604 / Y = 5,970,127 2616'FNL, 1879'FWL,Sec.09, T11N, R15E / ,/ ,/ I AFE Number: 1 PBD4P1902 I Estimated Start Date: 109/01/03 I Rig: I Doyon 141 I Operating days to complete: 123.3 / [MD: 110,898' 1 I TVD: 18,665' I I GL: 117.4' 1 I KB: 127.6' I I KBE: 1 45.0' 1 I Well Design (conventional, slim hole, etc.): 1 Big Bore ,/ I Objective: 1 High rate water injection into Ivishak Gas Cap, Zones 3 through 1 Formation Markers Formation Tops MD TVD TVDss Comments Base PF 1919' 1902' 1850' 8.6 ppg SV4 3922' 3496' 3444' 8.6 ppg SV3 4507' 3902' 3850' 8.6 ppg SV2 4792' 4100' 4048' 8.6 ppg SV1 5344' 4483' 4431' 8.6 ppg UG4 6077' 4992' 4940' 8.6 ppg UG3 6416' 5228' 5176' 8.6 ppg UG1 7358' 5882' 5830' 8.6 ppg West Sak 2 8104' 6400' 6348' 8.6 ppg West Sak 1 8369' 6584' 6532' 8.6 ppg CM3 8649' 6778' 6726' 8.6 ppg CM2 9480' 7382' 7330' 10.0 ppg HC Bearing CM1 9826' 7672' 7620' 10.0 ppg HC Bearing THRZ 10257' 8061' 8009' 8.6 ppg BHRZ/LCUrrZ4 10461' 8252' 8200' 8.6 ppg TZ3 10511' 8299' 8247' 7.3 ppg; HC Bearing TZ2 10554' 8339' 8287' 7.3 ppg; HC Bearing TZ2B 10624' 8406' 8354' 7.3 ppg; HC Bearing TZ2A 10710' 8487' 8435' 7.3 ppg; HC Bearing TZ1 B 10750' 8525' 8473' 7.3 ppg; HC Bearing BSAD 10831' 8602' 8550' 7.3 ppg; HC Bearing TD (Kavik) 10898' 8665' 8615' 7.3 ppg TLSB N/ A N/ A 8687' Not Penetrated Surface TD Criteria: Based on -100' TVD below SV1 Top Intermediate TD Criteria: Casing to be set above the BHRZffZ3 transition TD Criteria: Based upon 50' TVD above TLSB PSI-05 Permit to Drill I to.s 1~ Page 1 e e CasinglTubing Program Hole Size CsglTbg O.D. WtlFt Grade Conn Length Top MDITVD Btm MDITVD 42" Insulated 20" 91.51# H-J0 W1ed 80' GL -113'/113' (34" 00) 16" 13-318" 68# L-80 BTC 5,460' GL 5,488'/4,583' 12-114" 9-518" 40# S-95 BTC-M 9,933' GL 9,961 '/7,790' 12-1/4" 9-518" 47# L-80 BTC-M 500' 9,961 '/7,790' 10,461 '/8,252' 8-1/2" 7" 26# L-80 BTC-M 587' 10,361 '/8,158' 10,898'/8,665' Tubing 7-5/8" 29.7# L-80 STL 10,233' GL 10,261 '/8,064' jt" Pipe 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 KOP: I 650' MO Maximum Hole Angle: Close Approach Well: Closest Well: Survey Program: -460 In intermediate section from 3,140' to 9,006' No Close Approach Issues / / PSI-06: 30' at surface and 1,776' at TO. / MWO Surveys with IFR and MS from surface to TO. 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/10ote) (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 YP tauo 10' Gel API HTHP FL pH LGS tM2... (ppg) (cp) (lb/100ft2) (lb/100ft2) (mls/30min) % vol Initial to~ 9.~' 1 0-15 25-30 4-7 10 6-10 8.5-9.5 <5 ~ to TZ4 9.8 .!y 1 0-15 20-30 4-7 10 4-6/<12.0 8.5-9.5 <5 '-All L J o<j \L.(;¡A- y 8-1/2" Production Hole I Flo-Pro NT From Intermediate Casing Shoe to TO Interval Density Plastic Viscosity YP tauo 10' Gel API HTHP FL pH LGS (ppg) (cp) (lb/100ft2) (lb/10ote) (mls/30min) % vol Ivishak 8.8 10-15 17-25 3-5 10 4-6<12.0 8.5-9.5 <5 PSI-05 Permit to Drill Page 2 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 (-4487' MD) I Fluid Sequence & Volumes: Pre None Flush Spacer Lead Tail 75 bbls MudPUSH Vis 0 oed Spacer weighted to 10.0 ppg 10079ØfJ. 5654 fe 1 27 sks of Dowell ArticSET III-Lite at 10.7 ppg and Wcf/sk, BH 5° 1 BHCT 52°, TT = 6.0 hrs ~t 1 700 ft3 h 60 sks of Dowell Premium 'G' at 15.8 ppg and ~_.7cf/sk, BHST ° 1 BHCT 86°, TT = 4 hrs ~: r Casing Size 1 9-5/8" Intermediate Bas~: Lead: None Tail: Open hole volume + 50% excess + 82' shoe track volume Tail TOC: 500' above CM2 (-8,980' 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 1~bl 1 730fe ~sks of Dowell Premium 'G' at 15.8 ppg and f,19"'cf/sk, BHST fio~ 1 BHCT 131°, TT = Batch Mix + 4.0 hrs <..:/ PSI-05 Permit to Drill Page 3 e e I Liner Size I 7" Production Bas~: Lead: None Tail: Open hole volume + 50% Excess + 82' shoe track + 100' liner lap + 200' of 9-5/8" x 5" DP annulus volume. Tail TOC: -10,361' MD - Linerto::J. I Fluid Sequence & Volumes: Pre 30 bbls Chemical wash at 8.3 ppg Flush Spacer Lead Tail 40 bbls MudPUSH Viscosified Spacer weighted to 11.0 ppg None ~ 30 b~68 fe / 4 sks of Dowell Premium Latex 'G' at 15.8 ppg and dÇf/Sk, ST 1810/ BHCT 13r, 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 AOGCC. Surface Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 13-3/8" Casing Test pressure Intermediate Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casing Test pressure Integrity Test Production Interval- BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9-5/8" Casingl7" Liner Test Integrity Test Planned completion fluids PSI-05 Permit to Drill 21-1/4", 2M Diverter (Hydril- MSP) 2026 psi (8.6 ppg @ 4530' TVDss) 1573 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) 3667 psi (8.6 ppg @ 8200' TVDss) 2847 psi (.10 psi/ft gas gradient to surface) 133 bbls with a 12.0 ppg FIT / Rams test to~si/250 psi. /t.JOOCl ~ 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) 3852 psi (8.6 ppg @ 8615' TVDss) 2991 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 / 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-05 is 21,183' from the unit boundry line at the closest point. · The closest well to PSI-05 is PSI-06, which is 30' away at surface and 1,776' at TO. PSI-05 Permit to Drill Page 5 e e Drill and Complete Procedure Summary Pre-RiCl 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. RiCl Operations: 1. MIRU Doyon 141. 2. Nipple up and function test diverter system. ~U 5" DP to drill surface hole and stand back in derrick. 3. MU 16" drilling assembly with MWD/GR and directionally drill surface hole to approximately 5,488' 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 casingj)âel(1o 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~ psi. ~.I.6¡f: 6. MU 12-1/4" drilling assembly with MWD/GR/PWD and RIH to float collaf.- 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" t' 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 tò 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 11,898' 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-RiCl Work: 1. Clean-up location as required. 2. Perforate and stimulate Ivishak intervals as required. 3. POI. PSI-OS Permit to Drill Page 6 e - PSI-OS Drilling Program ./ Job 1: MIRU tsr-ol, -o(,} -o{¡ -o~) -/1:'/ L3 -01.) - o-r-) éß~ -, Hazards and Contingencies 0 t\.-l'1 L ') - 0 I I"k- M f2- . ~ The rig move will involve no surface clOse approach hazards with adjacent wells. The PSI-OS 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. / )0> 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 W._W:,-,n-;m.-»:<.. Job 2: Drill Surface Hole Hazards and Contingencies ~ No fault crossing are expected in the surface interval. ~ The nearest well is PSI-06, which is 30' center to center at surface and -680' center to center at surface casing point. ~ Gas hydrates have not been observed at the other wells on the pad: PSI-06, PSI-Q9, PSI-01, PS,I-10, PSI- 08, and East Bay State #1. Gas hydrates are not expected at PSI-OS. )0> 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-08, and East Bay State #1. Abnormally pressured shallow gas is not expected at PSI-OS. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" Job 3: Install 13-3/8" Surface Casinq Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 400% excess cement through the permafrost zone (and SO% 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. ~ Hole cleaning will be difficult in the 16" hole with S" DP. Maintain adequate viscosity and high flow rates. Short trip as required. PSI-OS Permit to Drill Page 7 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-05 well path in the intermediate hole. ~ No close approach issues. The nearest well is PSI-06, which has a center to center distance of -680' at the surface casing shoe and over 1500' at the intermediate casing point. ~ 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-05. 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 ROP'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 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 (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-05 Permit to Drill Page 8 e e Job 6: Install 9-5/8" Intermediate/Production Casinq Hazards and Contingencies )- 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. )- 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 _~, _,.,z.c1r''-;';';'';;'-=~,"""., Job 7: Drill 8-1/2" Production Hole Hazards and Contingencies )- Fault crossings are not expected along the PSI-05 wellpath in the production hole. )- 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. )- 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. )- Extra vigilance is required to avoid swabbing. The Ivishak will be highly permeable and gas bearing. 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 )- Differential sticking is a concern in the Ivishak due to the low pore pressure. Keep tools moving at all times and monitor line tension. Job 9: Install 7" Production Liner HazardsandContingencres )- Differential sticking could be a problem. Minimize the time the pipe is left stationary while running the liner. )- 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 ,=_.--¡¡!~,~ PSI-05 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 1000 F. Diesel vapor pressure is- 0.1 psia at 1000 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. , ·,>x~-",,-;(1:=;;;)':<1tJ(k_""-X'~ PSI-05 Permit to Drill Page 10 e e PSI-OS .Summarv of DrillinQ 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-OS. · Shallow gas was not observed at the other 6 wells on this pad, is not expected at PSI-OS. · 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-OS 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-OS. · 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 (7.3 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. · 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-OS Permit to Drill Page 11 P 05 Proposed C pletion I Seawater Injection: 100,000 bbls/day @ 2700 psi I Wellhead: 13-5/8", 5K, Big Bore, FMC Tree: 6-3/8" bore x 7-1/6", 5K, 625 Inlay, CIW 80'MD 5488' MD 8980' MD 9961' MD 10261' MD ~ r ~ 10361' MD 10461' MD Date Rev 04- i 6-03 RBT 04-24-03 RBT 05-07-03 RBT )3 ì "" ( "'Ij 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 7-5/8" 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 Comments PROJECT: GCWSI PSI-OS Proposed Completion hanger crossover 9-5/8" from 47 to 40# GPB '¡j \-o~<?- s,<-O ~ þ.O r -~- I "-- -- ~. '~'r-U~BU:NE . ~D~ILLSITE3 21 22 PROJECT AREA ~ _UDHOE '" - EAST DOCK PRUDHOE BAY o .0 o o o C\J 1-'0 Z _ :5 f3 0... WF1 INJECTION / WELL FACILITY (EAST DOCK WEST PAD) VICINITY MAP N.T.S. .....J .....J L() f'. w 0 3= ~ I co I co 0> ~ <..? I (/) I (/) I I I ëï5 ëï5 ëï5 ëï5 ëï5 z 0.. D- o.. D- o.. 0.. 0.. ¡::: 4- 4- (/) . . . . . x w . LEGEND ~ AS-STAKED CONDUCTOR . EXISTING CONDUCTOR LOCATED WITHIN PROTRACTED SEC. 15, T. 11 N., R. 15 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC APPROX. SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) GND. ELEV. OFFSETS PSI-5 y= 5,966,138.59 N=10,000.00 70'18'39.066" 70.3108517" 17.4' 3,838' FSL X= 707,939.86 E= 5,030.00 148'18'53.444" 148.3148456' 4,465' FEL PSI-7 y= 5,966,159.11 N=10,OOO.00 70'18'39.252" 70.3109033' 17.4' 3,857' FSL X= 707,996.24 E= 5,090.00 148'18'51.783" 148.3143842' 4,408' FEL o 6/27/03 ISSUEO FOR INFORMATION NO. OA 1£ REV1S1ON F. Robert DRAWN: Obp JJC }rn- CHECKED: RFA DATE, 6/27/03 DRAWING: SHEET: FRBOJ ED 02-00 GPB EAST DOCK WFI PAD i ffigs~[IJœo JOB NO: SCALE: AS-STAKED CONDUCTORS JJC RFA ENGlNEERSANDI..ANDSUR\'EYORS WELLS PSI-5 & PSI- 7 1 OF 1 801 WEST FlREW£EO lNfE 1"= 100' BY CHK ANCHORAGE:. ALASICA gg503 COMPANY DETAILS REFERENCE INFORM·\ TION BP Amoco CASING DET ArLS No TVD MD Name Size 1400 1 4582.50 5487.56 - 2 S25L50 1046 LOS - 3 8664.99 10898.13 - Start Dir 11100' . 650' MD 650'TVD - V '. FORMATION TOP DETAILS - V Start Dir 1.5/1 00' : 950' MD, 949.86TVD - No. TVDPath MDPath Formation - HI 1 190150 j ~~ g" 2 3495.50 3 390150 ¡ - 4 4099.50 If' EudDir 1820' TVD 5 448250 - : 1938.73' MD, 1920'TVD 6 499150 - 7 522750 - 8 588150 - 9 6399.50 ~ 10 6583.50 - ....... Start Dir 3JWO' . 2568,,)6' MD, 2500TVD ¡¡ 6777.50 - . ~ 12 738150 13 767150 - ¡ .: 14 806050 EudDir : 3140.36' MD. 2952.7' TVD 15 825150 - "', 16 8298,50 reGL - 17 833850 - 18 840550 J:Úfš - 19 8486.50 20 8524.50 - 21 860150 ..... - ; , ¡ , - : , ! - - ... r I-~t ¡ - :. .... ,¡, .¡...... - ... 1 ,1 - ... , - J0- vv ~ 1:' - - t+1- ...... - .......... - ! L.. -.' : - - 1!1 .......... ¡...... ! - . ..... ,: - .......... ! Start Dir 2/100' : 900 l , - - .. .. - ..... III···· ....... - " - ..... ?.~o Start - : 95/8' ..... =lii ! ¡ it ...;t1 ! ¡ ! - , 1\ it! I ¡. I ! 1···1 I , I I I I I I I I , f , I 2800 0- 2800 " ~ '" ; t 4200 " Q -a " 'E " > " ;:: f- 5600 7000 8400 SURVEY PROGRAM Plan: PSI 5 wp06 (PSf Si'PJan PSI 5) DCj)lll Pm Depm To Survey/Plan 34.00 1200.00 ¡lOG.on !08%J4 Tool CB-GYRQ.SS MWD+IFR+MS Created By: Ken Allen Checked: Date: 2/2612003 Date Reviewed: DAte WELL DETAILS N=, +-NJ-S +-EJ~W NoM"" fuming LatillJde Longitude Slot PSJ5 94.22 18154 5966138.59 707939.&6 7(t'"IW}91/66N !48"J8'53.444W N!A TARGET DEI AILS w,,,,,, TVD ~N!-S +E!·W Northing Enstillg Shape 824150 4007J7 -4121.79 703708.91 866650 4034.08 4371.16 703458.90 SECTION DET AlLS Sec MD Inc Azì TVD +NI-S +E/-W Dug TFace I 34.00 0,00 0.00 2 650.00 0.00 0.00 3 949.86 1.00 314.19 4 1820.00 150 0.00 5 1920.00 0.00 0.00 6 2500.00 /2.00 0.00 7 2952.70 ,/ 3.00 0.01 8 7025.47 0.00 0.00 9 8060.50 2.00 -180.00 10 8247.50 0.50 J80.00 Jl 8665.00 0.50 J80.00 VSec Target PSI 5 TU 5.89' MD, 7025.47'TVD Dir O.5IJOO' : 10257. J8' MD. 8060,S'TVD 7' t I II1I f I COMPANY DETA1LS SURVEY PROGRAM Depth Fm Depth To S~}'/P!an 34.00 1200.00 !200.00 !089!U4 Too' CB,.,:ßYRO-SS MWD-.;.lFR+MS REFERENCE lNFORMA nON HI' Amoco CASING DETAILS N&hJe <"N!..S rF.j..W Depth: J0898. J4' MD, 8665' TVD No TVD MD Name Size Created By: Ken AJIen Cheáed: Plan: PSJ S wp06 (PSI SIPJan PSI 5) Date Reviewed: \VElL DETAILS Northing ßwti:t\g LatilUde Date: 2/26/2-003 Date PSI" 94 T) 18154 596613839 707939.86 70"!8'39JJ66N !48"j&'53A44W NlA Longitude SkI! '2 â "" "" t:. +' f2 ~ ~ ~ I .- - I I J 4582.50 5487.56 13.3 75 200 - ,n . I PSJ 5 wp06 2 8251.50 10461.08 9.625 N_ Tvt 3 8664.99 10898.13 7.000 _, I: " 9518" 82473 ~~. PSJ5TJ J 8666, -; -- 10257 J 8' MD. 8060 5'TVD See MD Jnc Azi T .... /5 -, ¡. J 34.00 0.00 0.00 34. 2 650.00 0.00 0.00 650. -, > ¡rt Dir2/Joo' 9005.89' MD. 7025.47'TVD 3 950.00 3.00 3J4.19 949. 500 =If ,.. 4 1&34.56 16.27 314.19 1820. .... 5 J938.73 16.27 3J4.J9 1920. \, 6 2568.06 28.&6 314.19 250R "00 ~ttt 1+ 7 3140.36 46.02 3J4.19 2952. 8 9005.89 46.02 314.19 7025. ,,' 9 10257.18 21.00 314.19 8060. ¡ 10 10456,83 20.00 314.19 824L fJi!Ii ¡¡ 1089&.14 17.79 314.19 8665. ,+ 'k!' /~t>, i"-, .... "- .... ......1\ /./1/1.................... -,,¡..... ..... .... /:::.//....... ......... .. I' + ~/' Vi/< - : i·· I ';; ./ I' './ .//;I ......... .......... .......... - ii i",J "[/L/::'·" .......... ..IL>· - , J1~j~f ...... l/r,,:I' L::' >< ........ 100 . .¡jo I'" ,'! - L ······iliii!1 ..1 I. 1 ilb<L[:,j ......... ......... ,/ " L - ,..... ........... i/l/ i/!/ '",- .. ... -'I ; ;/;:'/./'V i f /I·'V -. , I , i.,¿' ,>;V - .... .. . ... j I 400 ' , i'-l , , :1=Ff i M=! ,.. 'jjl m~1 -.. - , ~~1 - ..... f . . ... ..... ftr -' -.... i .... I ....... ! I , : ! , 1"": i -.... .1 Al. I' .... : 3140.36' MD, 2 ...... ..... -' Â RKRR .'.. .... ....... -' , .. .. ...... . , ¡ , , ! ··Il , ! I , , ! i , , , DIr , ¡.... I 1Sta!'! - ...... I , . 0-:: -SI - .... ...... ,.. , I: ! , : 'IT ¡ : : ! " j I I I I I I ¡ I , I I I , , , I ¡ I I I I , , , , i ì ¡ I ¡ ¡ ; ; ; ¡ ¡ I , I , , I , I , I I I I I J ! ¡ ¡' , , 4 .1400 West(-)/East(+) [7oofllinj -700 o T ARGBT DETAILS o 00 +Nf...s 'i"El-W Northing Eastíng Shape 4001.17 4121.79 5970029.9ú 703708.91 4034.08 437LJ6 5970049.89 703458.90 SECTION DETAILS +NI·S +EI·W DLeg TFace 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5.47 -5.63 1.00 314.19 108.43 ·1 1!.54 !.50 0.00 128.77 ·132,47 0.00 0.00 296.74 -305.25 2.00 0.00 53&.35 -553.78 3.00 0.01 3480.71 ·3580.25 0.00 0.00 3958,44 ·4071.66 2.00 ·180.00 4007.11 -4121.79 0.50 180.00 4106.79 -4224.27 0.50 180.00 VD 00 00 86 00 00 00 70 47 50 '0 00 VSec Target PSI 5 TLl No. TVDPath MDPath Formatioo FORM'" TION TOP DETAILS I 2 3 4 5 6 7 8 9 10 l! 12 13 14 15 16 17 18 19 20 21 952.7' TVD 2568.06' MD, 25OO'TVD 00': 1938.73' MD, 1920'TVD : 1834.56'MD, 1820'TVD Dir 1.51100': 950' MD, 949.86'TVD art Dir 11100' : 650' MD,650'TVD , I ' 700 ! ! ! ! ¡ ! ¡ ¡ 1919.46 BPRF 3922.09 SV4 4506.80 SV3 4791.96 SV2 5343.55 SVI 6076.60 UG4 6416.48 UG3 7358.36 UG! 8104.38 WS2 8369.37 WSI 8648.76 CM3 94&0.20 CM2 9826.49 CMI 10257.1& THRZ 10461.08 TSADILCUITZ4 10511.05 TZ3ITCOL 10553.52 TZ2C¡BCGL 10624.53 TZ2BI23SB 10710.17 TZ2A12JTS 10750.27 TZIB 10831.38 BSAD ¡ ¡ ¡ ! ¡ ¡ e BP KW A Planning Report MAP Company: Field: Site: WeD: WeDpath: BP Amoco Lisbume East Dock (PSI) PSIS Plan PSI 5 Date: 2/2612003 Time: 16:34:58 Page: 1 Co-ordiDate(NE) Reference: Well: PSI 5, True North Vertieal(TVD) Reference: 51.SO' 51.5 Section (VS) Reference: Well (0.00N,0.ooE,314.19Az1) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Lisbume North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: East Dock (PSI) Site Position: From: Map Position Uncertainty: Ground Level: 5966039.39 ft 707761.01 ft Latitude: 70 18 Longitude: 148 18 North Reference: Grid Convergence: Northing: Easting: 0.00 ft 20.00 ft WeD: PSI 5 Slot Name: Well Position: +N/-S 94.22 ft Northing: 5966138.59 ft Latitude: +E/-W 181.54 ft Easting: 707939.86 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: Plan PSI 5 Drilled From: Tie-on Depth: Above System Datum: DecUuation: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 51.50' 8/30/2001 57538 nT Depth From (TVD) ft 0.00 Height 51.50 ft +N/-S ft 0.00 Plan: PSI 5 wp06 Date Composed: Version: Tied-to: Principal: Yes Casing Points e Alaska, Zone 4 Well Centre BGGM2002 38.139 N 58.739 W True 1.59 deg 70 18 39.066 N 148 18 53.444 W Well Ref. Point 0.00 ft Mean Sea Level 26.71 deg 80.86 deg Direction deg 314.19 2/19/2003 13 From Well Ref. Point MD TVD DIameter Hole Size Name ft ft in in 5487.56 4582.50 13.375 16.000 133/8" 10461.08 8251.50 9.625 12.250 9 5/8" 10898.13 8664.99 7.000 8.500 7" Formations MD TVD Formations Lithology ft ft 1919.46 1901.50 BPRF 0.00 0.00 3922.09 3495.50 SV4 0.00 0.00 4506.80 3901.50 SV3 0.00 0.00 4791.96 4099.50 SV2 0.00 0.00 5343.55 4482.50 SV1 0.00 0.00 6076.60 4991.50 UG4 0.00 0.00 6416.48 5227.50 UG3 0.00 0.00 7358.36 5881.50 UG1 0.00 0.00 8104.38 6399.50 WS2 0.00 0.00 8369.37 6583.50 WS1 0.00 0.00 8648.76 6777.50 CM3 0.00 0.00 9480.20 7381.50 CM2 0.00 0.00 9826.49 7671.50 CM1 0.00 0.00 10257.18 8060.50 THRZ 0.00 0.00 10461.08 8251.50 TSAD/LCUrrZ4 0.00 0.00 10511.05 8298.50 TZ3rrCGL 0.00 0.00 10553.52 8338.50 TZ2C/BCGL 0.00 0.00 10624.53 8405.50 TZ2B/23SB 0.00 0.00 10710.17 8486.50 TZ2AI21TS 0.00 0.00 10750.27 8524.50 TZ1B 0.00 0.00 10831.38 8601.50 BSAD 0.00 0.00 e BP KW A Planning Report MAP e Company: Field: Site: WeD: Wellpatb: BPAmoco Lisburne East Dock (PSI) PSI 5 Plan PSI 5 Date: 2/2612003 Time: 16:34:58 Page: 2 Co-ordinate(NE) Reference: Well: PSI 5, True North Vertieal (TVD) Reference: 51.SO' 51.5 Section (VS) Reference: Well (0.ooN,O.ooE,314.19Azi) Survey Cakulation Metbod: Minimum Curvature Db: Oracle Formations MD TVD Formations Lltboløgy ft ft 0.00 TLSB 0.00 0.00 Targets Name Description !\fap MttP TVD +EI-W Nort.....g Easting Dip. Dir. ft ft ft ft PSI 5 T1.1 8247.50 4007.17 -4121.79 5970029.90 703708.91 70 19 18.465 N 148 20 53.734 W -Plan hit target PSI 5 Poly 8666.00 4034.08 -4371.16 5970049.89 703458.90 70 19 18.729 N 148 21 1.012 W -Polygon 1 8666.00 4034.08 -4371.16 5970049.89 703458.90 70 19 18.729 N 148 21 1.012 W -Polygon 2 8666.00 3863.06 -3975.72 5969889.89 703858.90 70 19 17.049 N 148 20 49.469 W -Polygon 3 8666.00 4311.91 -3963.29 5970338.89 703858.91 70 19 21.463 N 148 2049.113 W -Polygon 4 8666.00 4322.98 -4363.16 5970338.89 703458.90 70 19 21.570 N 148 21 0.783 W Plan Section Information MD Incl Azim TVD +N/-S +EI-W DLS BuDd Turn TFO ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 0.00 650.00 0.00 0.00 650.00 0.00 0.00 0.00 0.00 0.00 0.00 950.00 3.00 314.19 949.86 5.47 -5.63 1.00 1.00 0.00 314.19 1834.56 16.27 314.19 1820.00 1 08.43 -111.54 1.50 1.50 0.00 0.00 1938.73 16.27 314.19 1920.00 128.77 -132.47 0.00 0.00 0.00 0.00 2568.06 28.86 314.19 2500.00 296.74 -305.25 2.00 2.00 0.00 0.00 3140.36 46.02 314.19 2952.70 538.35 -553.78 3.00 3.00 0.00 0.01 9005.89 46.02 314.19 7025.47 3480.71 -3580.25 0.00 0.00 0.00 0.00 10257.18 21.00 314.19 8060.50 3958.44 -4071.66 2.00 -2.00 0.00 -180.00 10456.83 20.00 314.19 8247.50 4007.17 -4121.79 0.50 -0.50 0.00 180.00 PSI 5 T1.1 10898.14 17.79 314.19 8665.00 4106.79 -4224.27 0.50 -0.50 0.00 180.00 Survey MD Inc) Azim TVD Sys TVD MapN MapE VS J)LS.. .... .... DO ft deg deg ft ft ft ft ft deg/100ft deg 34.00 0.00 0.00 34.00 -17.50 5966138.59 707939.86 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 48.50 5966138.59 707939.86 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 148.50 5966138.59 707939.86 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 248.50 5966138.59 707939.86 0.00 0.00 0.00 CB-GYRO-SS 400.00 0.00 0.00 400.00 348.50 5966138.59 707939.86 0.00 0.00 0.00 CB-GYRO-SS 500.00 0.00 0.00 500.00 448.50 5966138.59 707939.86 0.00 0.00 0.00 CB-GYRO-SS 600.00 0.00 0.00 600.00 548.50 5966138.59 707939.86 0.00 0.00 0.00 CB-GYRO-SS 650.00 0.00 0.00 650.00 598.50 5966138.59 707939.86 0.00 0.00 0.00 CB-GYRO-SS 700.00 0.50 314.19 700.00 648.50 5966138.74 707939.70 0.22 1.00 0.00 CB-GYRO-SS 800.00 1.50 314.19 799.98 748.48 5966139.92 707938.41 1.96 1.00 0.00 CB-GYRO-SS 900.00 2.50 314.19 899.92 848.42 5966142.28 707935.85 5.45 1.00 0.00 CB-GYRO-SS 950.00 3.00 314.19 949.86 898.36 5966143.91 707934.08 7.85 1.00 0.00 CB-GYRO-SS 1000.00 3.75 314.19 999.78 948.28 5966145.90 707931.91 10.80 1.50 0.00 CB-GYRO-SS 1100.00 5.25 314.19 1099.46 1047.96 5966151.21 707926.14 18.64 1.50 0.00 CB-GYRO-SS 1200.00 6.75 314.19 1198.91 1147.41 5966158.28 707918.45 29.09 1.50 0.00 MWD+IFR+MS 1300.00 8.25 314.19 1298.06 1246.56 5966167.12 707908.84 42.15 1.50 0.00 MWD+IFR+MS 1400.00 9.75 314.19 1396.82 1345.32 5966177.71 707897.33 57.79 1.50 0.00 MWD+IFR+MS 1500.00 11.25 314.19 1495.14 1443.64 5966190.04 707883.91 76.01 1.50 0.00 MWD+IFR+MS 1600.00 12.75 314.19 1592.96 1541.46 5966204.11 707868.61 96.80 1.50 0.00 MWD+IFR+MS 1700.00 14.25 314.19 1690.19 1638.69 5966219.92 707851.43 120.15 1.50 0.00 MWD+IFR+MS 1800.00 15.75 314.19 1786.78 1735.28 5966237.43 707832.38 146.03 1.50 0.00 MWD+IFR+MS 1834.56 16.27 314.19 1820.00 1768.50 5966243.89 707825.37 155.56 1.50 0.00 MWD+IFR+MS 1900.00 16.27 314.19 1882.82 1831.32 5966256.29 707811.87 173.89 0.00 180.00 MWD+IFR+MS 1919.46 16.27 314.19 1901.50 1850.00 5966259.98 707807.86 179.34 0.00 180.00 BPRF e BP e KW A Planning Report MAP Company: BP Amoco Date:.·. .212612003 Time: 16:34:58 Pagè: .3 Field: Lisbume Co-ordinate(NE) Reference: Well:.PSI5,True North Site: East Dock Vertk:al (fVD) Reference: 51.50' 51.5 Well: PSI 5 Section (VS) Reference: VV~II.(Ø.!>9N·O·00E,~14.19Azj) Wellpath: Plan PSI 5 Survey CaleuJationMethOd: MinimUmCul'\latOre Db: Ora¢le Survey MD Ine! Azim TVD Sys TVD MapN MapE VS DLS DO ft deg deg ft ft ft. ft ft deg/1ooftdeg 1938.73 16.27 314.19 1920.00 1868.50 5966263.64 707803.89 184.74 0.00 180.00 MWD+IFR+MS 2000.00 17.49 314.19 1978.63 1927.13 5966275.68 707790.79 202.53 2.00 0.00 MWD+IFR+MS 2100.00 19.49 314.19 2073.46 2021.96 5966297.15 707767.45 234.25 2.00 0.00 MWD+IFR+MS 2200.00 21.49 314.19 2167.13 2115.63 5966320.85 707741.68 269.26 2.00 0.00 MWD+IFR+MS 2300.00 23.49 314.19 2259.51 2208.01 5966346.74 707713.52 307.52 2.00 0.00 MWD+IFR+MS 2400.00 25.49 314.19 2350.51 2299.01 5966374.80 707683.01 348.97 2.00 0.00 MWD+IFR+MS 2500.00 27.49 314.19 2440.00 2388.50 5966405.00 707650.18 393.58 2.00 0.00 MWD+IFR+MS 2568.06 28.86 314.19 2500.00 2448.50 5966426.75 707626.52 425.72 2.00 0.00 MWD+IFR+MS 2600.00 29.81 314.19 2527.84 2476.34 5966437.34 707615.01 441.36 3.00 0.01 MWD+IFR+MS 2700.00 32.81 314.19 2613.27 2561.77 5966472.52 707576.76 493.33 3.00 0.01 MWD+IFR+MS 2800.00 35.81 314.19 2695.85 2644.35 5966510.67 707535.28 549.69 3.00 0.01 MWD+IFR+MS 2900.00 38.81 314.19 2775.38 2723.88 5966551.70 707490.67 610.30 3.00 0.01 MWD+IFR+MS 3000.00 41.81 314.19 2851.62 2800.12 5966595.49 707443.05 674.99 3.00 0.00 MWD+IFR+MS 3100.00 44.81 314.19 2924.37 2872.87 5966641.92 707392.57 743.58 3.00 0.00 MWD+IFR+MS 3140.36 46.02 314.19 2952.70 2901.20 5966661.38 707371.41 772.33 3.00 0.00 MWD+IFR+MS 3200.00 46.02 314.19 2994.11 2942.61 5966690.43 707339.83 815.25 0.00 180.00 MWD+IFR+MS 3300.00 46.02 314.19 3063.55 3012.05 5966739.14 707286.86 887.21 0.00 180.00 MWD+IFR+MS 3400.00 46.02 314.19 3132.99 3081.49 5966787.85 707233.90 959.17 0.00 180.00 MWD+IFR+MS 3500.00 46.02 314.19 3202.42 3150.92 5966836.57 707180.94 1031.14 0.00 180.00 MWD+IFR+MS 3600.00 46.02 314.19 3271.86 3220.36 5966885.28 707127.97 1103.10 0.00 180.00 MWD+IFR+MS 3700.00 46.02 314.19 3341.29 3289.79 5966933.99 707075.01 1175.06 0.00 180.00 MWD+IFR+MS 3800.00 46.02 314.19 3410.73 3359.23 5966982.70 707022.04 1247.03 0.00 180.00 MWD+IFR+MS 3900.00 46.02 314.19 3480.16 3428.66 5967031.42 706969.08 1318.99 0.00 180.00 MWD+IFR+MS 3922.09 46.02 314.19 3495.50 3444.00 5967042.18 706957.38 1334.88 0.00 180.00 SV4 4000.00 46.02 314.19 3549.60 3498.10 5967080.13 706916.11 1390.95 0.00 180.00 MWD+IFR+MS 4100.00 46.02 314.19 3619.04 3567.54 5967128.84 706863.15 1462.92 0.00 180.00 MWD+IFR+MS 4200.00 46.02 314.19 3688.47 3636.97 5967177.56 706810.19 1534.88 0.00 180.00 MWD+IFR+MS 4300.00 46.02 314.19 3757.91 3706.41 5967226.27 706757.22 1606.84 0.00 180.00 MWD+IFR+MS 4400.00 46.02 314.19 3827.34 3775.84 5967274.98 706704.26 1678.81 0.00 180.00 MWD+IFR+MS 4500.00 46.02 314.19 3896.78 3845.28 5967323.70 706651.29 1750.77 0.00 180.00 MWD+IFR+MS 4506.80 46.02 314.19 3901.50 3850.00 5967327.01 706647.69 1755.66 0.00 180.00 SV3 4600.00 46.02 314.19 3966.21 3914.71 5967372.41 706598.33 1822.73 0.00 180.00 MWD+IFR+MS 4700.00 46.02 314.19 4035.65 3984.15 5967421.12 706545.37 1894.69 0.00 180.00 MWD+IFR+MS 4791.96 46.02 314.19 4099.50 4048.00 5967465.92 706496.66 1960.87 0.00 180.00 SV2 4800.00 46.02 314.19 4105.08 4053.58 5967469.84 706492.40 1966.66 0.00 180.00 MWD+IFR+MS 4900.00 46.02 314.19 4174.52 4123.02 5967518.55 706439.44 2038.62 0.00 180.00 MWD+IFR+MS 5000.00 46.02 314.19 4243.96 4192.46 5967567.26 706386.47 2110.58 0.00 180.00 MWD+IFR+MS 5100.00 46.02 314.19 4313.39 4261.89 5967615.97 706333.51 2182.55 0.00 180.00 MWD+IFR+MS 5200.00 46.02 314.19 4382.83 4331.33 5967664.69 706280.54 2254.51 0.00 180.00 MWD+IFR+MS 5300.00 46.02 314.19 4452.26 4400.76 5967713.40 706227.58 2326.47 0.00 180.00 MWD+IFR+MS 5343.55 46.02 314.19 4482.50 4431.00 5967734.61 706204.52 2357.81 0.00 180.00 SV1 5400.00 46.02 314.19 4521.70 4470.20 5967762.11 706174.62 2398.44 0.00 180.00 MWD+IFR+MS 5500.00 46.02 314.19 4591.13 4539.63 5967810.83 706121.65 2470.40 0.00 180.00 MWD+IFR+MS 5600.00 46.02 314.19 4660.57 4609.07 5967859.54 706068.69 2542.36 0.00 180.00 MWD+IFR+MS 5700.00 46.02 314.19 4730.01 4678.51 5967908.25 706015.72 2614.33 0.00 180.00 MWD+IFR+MS 5800.00 46.02 314.19 4799.44 4747.94 5967956.97 705962.76 2686.29 0.00 180.00 MWD+IFR+MS 5900.00 46.02 314.19 4868.88 4817.38 5968005.68 705909.80 2758.25 0.00 180.00 MWD+IFR+MS 6000.00 46.02 314.19 4938.31 4886.81 5968054.39 705856.83 2830.22 0.00 180.00 MWD+IFR+MS 6076.60 46.02 314.19 4991.50 4940.00 5968091.71 705816.26 2885.34 0.00 180.00 UG4 6100.00 46.02 314.19 5007.75 4956.25 5968103.10 705803.87 2902.18 0.00 180.00 MWD+IFR+MS 6200.00 46.02 314.19 5077.18 5025.68 5968151.82 705750.90 2974.14 0.00 180.00 MWD+IFR+MS 6300.00 46.02 314.19 5146.62 5095.12 5968200.53 705697.94 3046.10 0.00 180.00 MWD+IFR+MS e BP e KW A Planning Report MAP Company: BP Amoco J>ate:2/261?OO.3 Tùne: 16:34;:5.8 Pagê; .4 Field: Lisburne Co-oJ'dinltt~):··It~rerenee: Well: PSI5,;Trl/e~~~. Site: East Doclc(PSI) Verti~('fVD)Rererenee: 5.1.50' 51.5. WeD: PSIS ~n (VS) Reference: Well·(Q;OON,O.OOES;~~4.;~~AzI) WeDplttb: Plal'l PSI 5 Survey CaleldatioD~etb~} Minimum Curvature Db: Oracle Survey MD Inel Azim TV» Sys TVD MapN MapE VS ~I,.S... ::»rJ'fO ft deg deg ft ft ft ft ft deg/100ft .deg 6400.00 46.02 314.19 5216.06 5164.5.6 5.968249.24 705644.98 3118.07 0.00 180.00 MWD+IFR+MS 6416.48 46.02 314.19 5.227.50 5.176.00 5968257.27 705636.25 3129.93 0.00 180.00 UG3 6500.00 46.02 314.19 5285.49 5233.99 5.968297.96 705592.01 3190.03 0.00 180.00 MWD+IFR+MS 6600.00 46.02 314.19 5354.93 5.303.43 5968346.67 7055.39.05 3261.99 0.00 180.00 MWD+IFR+MS 6700.00 46.02 314.19 5424.36 5.372.86 5.968395..38 705486.08 3333.96 0.00 180.00 MWD+IFR+MS 6800.00 46.02 314.19 5493.80 5442.30 5.968444.10 705433.12 3405.92 0.00 180.00 MWD+IFR+MS 6900.00 46.02 314.19 5.563.23 5511.73 5.968492.81 705380.15. 3477.88 0.00 180.00 MWD+IFR+MS 7000.00 46.02 314.19 5.632.67 5.581.17 5.968541.52 705327.19 3549.85. 0.00 180.00 MWD+IFR+MS 7100.00 46.02 314.19 5702.11 565.0.61 5.968590.23 705274.23 3621.81 0.00 180.00 MWD+IFR+MS 7200.00 46.02 314.19 5.771.54 5720.04 5968638.95 705221.26 3693.77 0.00 180.00 MWD+IFR+MS 7300.00 46.02 314.19 5.840.98 5789.48 5.968687.66 705168.30 3765.74 0.00 180.00 MWD+IFR+MS 7358.36 46.02 314.19 5881.5.0 5.830.00 5968716.09 705137.39 3807.73 0.00 180.00 UG1 7400.00 46.02 314.19 5910.41 5858.91 5.968736.37 705115.33 3837.70 0.00 180.00 MWD+IFR+MS 7500.00 46.02 314.19 5979.85 5928.35 5968785.09 705062.37 3909.66 0.00 180.00 MWD+IFR+MS 7600.00 46.02 314.19 6049.28 5997.78 5.968833.80 705009.41 3981.62 0.00 180.00 MWD+IFR+MS 7700.00 46.02 314.19 6118.72 6067.22 5968882.51 704956.44 4053.59 0.00 180.00 MWD+IFR+MS 7800.00 46.02 314.19 6188.16 6136.66 5968931.23 704903.48 4125..55 0.00 180.00 MWD+IFR+MS 7900.00 46.02 314.19 6257.5.9 6206.09 5968979.94 704850.51 4197.51 0.00 180.00 MWD+IFR+MS 8000.00 46.02 314.19 6327.03 6275.53 5969028.65 704797.55 4269.48 0.00 180.00 MWD+IFR+MS 8100.00 46.02 314.19 6396.46 6344.96 5969077.36 704744.58 4341.44 0.00 180.00 MWD+IFR+MS 8104.38 46.02 314.19 6399.50 6348.00 5969079.50 704742.27 4344.59 0.00 180.00 WS2 8200.00 46.02 314.19 6465.90 6414.40 5969126.08 704691.62 4413.40 0.00 180.00 MWD+IFR+MS 8300.00 46.02 314.19 6535.33 6483.83 5969174.79 704638.66 4485.37 0.00 180.00 MWD+IFR+MS 8369.37 46.02 314.19 6583.50 6532.00 5969208.58 704601.92 4535.29 0.00 180.00 WS1 8400.00 46.02 314.19 6604.77 6553.27 5.969223.5.0 704585.69 4557.33 0.00 180.00 MWD+IFR+MS 8500.00 46.02 314.19 6674.20 6622.70 5.969272.22 704532.73 4629.29 0.00 180.00 MWD+IFR+MS 8600.00 46.02 314.19 6743.64 6692.14 5969320.93 704479.76 4701.26 0.00 180.00 MWD+IFR+MS 8648.76 46.02 314.19 6777.50 6726.00 5969344.68 704453.94 4736.35 0.00 180.00 CM3 8700.00 46.02 314.19 6813.08 6761.5.8 5969369.64 704426.80 4773.22 0.00 180.00 MWD+IFR+MS 8800.00 46.02 314.19 6882.51 6831.01 5969418.36 704373.84 4845.18 0.00 180.00 MWD+IFR+MS 8900.00 46.02 314.19 695.1.95 6900.45 5969467.07 704320.87 4917.14 0.00 180.00 MWD+IFR+MS 9005.89 46.02 314.19 7025.47 6973.97 5969518.65 704264.79 4993.35 0.00 180.00 MWD+IFR+MS 9100.00 44.14 314.19 7091.92 7040.42 5969563.76 704215.74 5059.99 2.00 180.00 MWD+IFR+MS 9200.00 42.14 314.19 7164.88 7113.38 5969610.05 704165.42 5128.36 2.00 180.00 MWD+IFR+MS 9300.00 40.14 314.19 7240.19 7188.69 5969654.58 704117.00 5.194.15 2.00 180.00 MWD+IFR+MS 9400.00 38.14 314.19 7317.74 7266.24 5969697.31 704070.54 5257.27 2.00 180.00 MWD+IFR+MS 9480.20 36.54 314.19 7381.50 7330.00 5969730.23 704034.74 5305.91 2.00 180.00 CM2 9500.00 36.14 314.19 7397.45 7345.95 5969738.18 704026.10 5317.65 2.00 180.00 MWD+IFR+MS 9600.00 34.14 314.19 7479.22 7427.72 5969777.14 703983.74 5375.21 2.00 180.00 MWD+IFR+MS 9700.00 32.14 314.19 7562.95. 7511.45 5.969814.14 703943.5.0 5429.88 2.00 180.00 MWD+IFR+MS 9800.00 30.14 314.19 7648.53 7597.03 5.969849.15 703905.44 5481.59 2.00 180.00 MWD+IFR+MS 9826.49 29.61 314.19 7671.50 7620.00 5.969858.08 703895..73 5494.78 2.00 180.00 CM1 9900.00 28.14 314.19 7735.87 7684.37 5969882.11 703869.60 5530.28 2.00 180.00 MWD+IFR+MS 10000.00 26.14 314.19 7824.85 7773.35. 5969912.99 703836.03 5.5.75..90 2.00 180.00 MWD+IFR+MS 10100.00 24.14 314.19 7915..37 7863.87 5969941.74 703804.76 5.618.38 2.00 180.00 MWD+IFR+MS 10200.00 22.14 314.19 8007.32 795.5.82 5969968.35. 703775.84 5.65.7.68 2.00 180.00 MWD+IFR+MS 10257.18 21.00 314.19 8060.50 8009.00 5969982.5.7 703760.36 5678.71 2.00 180.00 THRZ 10300.00 20.78 314.19 8100.50 8049.00 5.969992.91 703749.13 5693.97 0.50 180.00 MWD+IFR+MS 10400.00 20.28 314.19 8194.15 8142.65 5970016.65 703723.31 5729.05 0.50 180.00 MWD+IFR+MS 10456.83 20.00 314.19 8247.5.0 8196.00 5970029.90 703708.91 5748.62 0.50 180.00 PSI 5. T1.1 10461.08 19.98 314.19 8251.50 8200.00 5.970030.88 703707.83 575.0.07 0.50 180.00 TSADILCUITZ4 105.00.00 19.78 314.19 8288.10 8236.60 5970039.84 703698.09 5763.31 0.50 180.00 MWD+IFR+MS 10511.05 19.73 314.19 8298.5.0 8247.00 5970042.37 703695.34 5767.04 0.50 180.00 TZ3ITCGL e BP KW A Planning Report MAP . Company: BPAmoco Field: Usbume Sitê: East Doc~ (PSI) WeD: PSI 5 ,WeDpatb: Plan PSIS Survey MD IlIel Azim TVD Sys TVD MapN MapE ft deg deg ft ft ft ft 10553.52 19.52 314.19 8338.50 8287.00 5970052.02 703684.85 5781.31 0.50 180.00 TZ2C/BCGL 10600.00 19.28 314.19 8382.34 8330.84 5970062.47 703673.48 5796.75 0.50 180.00 MWD+IFR+MS 10624.53 19.16 314.19 8405.50 8354.00 5970067.94 703667.54 5804.82 0.50 180.00 TZ2B/23SB 10700.00 18.78 314.19 8476.87 8425.37 5970084.55 703649.48 5829.36 0.50 180.00 MWD+IFR+MS 10710.17 18.73 314.19 8486.50 8435.00 5970086.76 703647.07 5832.63 0.50 180.00 TZ2A121TS 10750.27 18.53 314.19 8524.50 8473.00 5970095.43 703637.64 5845.44 0.50 180.00 TZ1B 10800.00 18.28 314.19 8571.69 8520.19 5970106.07 703626.08 5861.15 0.50 180.00 MWD+IFR+MS 10831.38 ;18.13 314.19 8601.50 8550.00 5970112.70 703618.87 5870.95 0.50 180.00 BSAD 10898.14 17.79 314.19 8665.00 8613.50 5970126.64 703603.72 5891.53 0.50 180.00 MWD+IFR+MS e pOSS111 DATE 7/14/2003 INV# PR071003A INVOICE / CREDIT MEMO HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 AK99519-6612 PAY: TO THE ORDER OF: DESCRIPTION GROSS PERMIT TO DRill FEE f)S I-OS TOTAL ~ NATIONAL CITY BANK Ashland, Ohio ALASKA Oil & GAS CONSERVATION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 e DATE I I CHECK NO. 7/14/2003 055111 VENDOR DISCOUNT NET 56-389 412 No..P 055111 CONSOLIDATED COMMERCIAL ACCOUNT AMOUNT July 14,2003 j I *******$100.00******1 NOT VALlQr[T.~..te~.gMtQ";""""H..H ....~...-)~..:'.....¡j....;,g ·-L:·::, ~:~:..'. .:.'" ". ::"': ':~'::¡(:::.:.~~"::..:~~!~:~{:.~::~{:.:' :~i i'{i:')'~;~¡Jt~~;:'~1::;~1;;;t: :J 1110 5 5 L ~ ¡. III I: 0 ~ ¡. 2 0 ~ B ~ 5 I: 0 ¡. 2 7 B ~ b III PTD#: 2031390 Administration 1 2 3 4 5 6 7 8 9 10 11 Appr Date 12 RPC 8/12/2003 13 14 15 16 17 Engineering 18 19 20 21 22 23 24 25 26 27 Appr Date 28 WGA 8/14/2003 29 30 31 32 33 34 Geology 35 36 Appr Date 37 RPC 8/12/2003 38 39 Geologic Commissioner: Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT PSI-05 Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial ClasslType SER 11WINJ GeoArea P.!3rmitfee attacheJJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Lease_number _apprORriate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.!3$ _ _ _ _ _ _ _ _ _ _ _ _ _U_nique weltnaO'l.!3_aoQ lJl!mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.!3$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ WelUQcat.!3d in_a_ d_efioeJJ _pool _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ WeIUQC<lt.!3d pr_oper _distance_ from QriJling uoitb_ouod_ary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ WellJQcat.!3d pr_operdistance from Qtber welJs_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.!3$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _S_utficieotacrea~e_aYailable in_drilJiog unjt _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.!3$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Jtd.!3viated, js weJlbQre platiocJu_ded _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Oper_ator ooly affected Party _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.!3$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Qperator bas_appropriateJ).ond inJQrce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y.!3$ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Permit cao be issued wjtbQut co_n$ervatioo Qrder _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes P.!3rmit cao be issued wjtbQut admioistratilleapprovaJ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Xes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Can permit be approved before 15-day wait Yes WelUQcat.!3d withio area and_strata _authQrized by_lojeçtioo Ord.!3r # (putlOtl in_comO'l.!3ot$) (FQr Y.!3S _ _ _ _ _ AIOAC _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ AJI W.!3ljs_withln Jl4JlJile_area_of reyi.!3W jd.!3lJtified (For $ervjCj3)v.eU OOly!- _ _ _ _ _ _ _ _ _ _ . _ _ _ XeL _ _ _ _ _ _ PSI:OJ P_SI-OQ,PSI:oapS!-09.J'SI:10,_L3-P1 ,l-3-05,I;AS'( SAY: STATE:t _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ Pre-prOQu_ced iojector; JJuratiQnof pr.!3-proJ:luctioo te$S_ than_ 3 mooths (fQr_s.!3rvice wel! QnJy) _ _ NA _AÇMP fiodjng.of ÇQn,sisteocy has been i$sued_ for tbi$ project NA Unit Program SER On/Off Shore ~ Well bore seg Annular Disposal D D - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - e" - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - _C_ooductor stringprQvid.!3d _ _ . . . . . . . . _ . _ . . . . . . . . . . Y.!3$ _........... _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _S.urfaC.!3C<1$jog.pJQtect$ all known USDWs . _ . . . . . . . . . . . . Xes _ . . . . . . . . . . . . . . . . . . . . . . . . . CMT vol ad.!3qu.ate.to circ.utateoncooductor. & $urfc,sg . . . . . . .. _ _ . . . . . . . . . . . . . Y.!3$ . . . . . . . Ade~uate eXCE!$S, . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . .CMTvotad.!3quate.totie-inJQng.striogtosurf~g.. _ No. ........... .............. ............ CMT wilJ çoyer.aH J<oownpro.duçtiye bQri;?:Qns _ . . . . . . . . . . . . . _ . . Y.!3$ . . . . . . . . . . . . . _ . . . . . . . . . . . . . _ C.asilJg de.sigos adecuate for C,T" B.&.perruafrost . . . . . . . . . . . . . . _ . . . . Xes. _ . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . AdequatetankageoJ re.serve pit. . . . . . . . _ . . . . . . . . . . . . . . Xes . . . . . . . DQyolJ 141. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . JtaJe-J:lriIL basa 10-403 fQr abandonment be.!3O apPJQv.!3d _ . . . . . . . NA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .. ............. .Mequate.weHbore $epar¡:ttjo.n.proposed. . . . . _ _ . . . . . . . . . . . . . . . _ . . . . . . . . . . Y.!3$ . . . . . . . . . .. ............ _ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Jfdjv.!3r:ter Jeq.uired, dQes jt me.!3t r.!3guJatioos. _ . . . . . . . . . . . . . . . . . . . .. _... Y.!3$ . . . . . . _ . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . _ .DJiUilJgf]ujd.RlQgram$c.hematic&eq.uipJistadequ¡:tt.!3......... ............... Y.!3s...... MaxMW105.ppg... _ ............... _ _..............._ .B.OPEs,_dpthey me.!3tr.!3guJatioo . Y.!3s. . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . .. _ . . . . . . . . . . . _ .BOPEpress ratilJg approPriate; test to.(pu.t psig lncommeots). . . . . . Y.!3s. . . . . . . Test to 40QO. psi. .MSF' 299"1 psi. . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . . _Chokeruanjfold cQmpJies. w/APt RF'-53 (May 134) . . . . . . . . . . . . _ . Y.!3S . _ . . . . . . . . . . . . . . . . . . . . . . . . . . _ WQrk wiH Oçc.ur withoutoperatjonsbutdQwn. . . . . . . . . . . .. ........ _ . _ . . . Xes. _ . . . . . . . _ . . . . . . . . . . . .. .......... . . . . . . . . . . . .. . . . Js. pres.ence. Qf H2S gas prQbabl.!3 . . . . . . . . . . . . . _ . . . No. . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . _ Mecba.nlc¡:tlcoodjtioo of well$ withio AOB. verified (For.s_ervjCj3 W.!31J onJy). . . . . . Y.!3$ . . . . . . . L3-Q1. actu¡:tlJywithin AOR .L3-.0"l ¡:tPRdJQr.abodmt jn. 1994,bµt nO to:4P7 filed yeL Mt iodiçate.d.by PM.. . . e - - - - - - - - P.!3rmit c_ao be issued wlo. hydrogen sulfide meas.ures. . . . . . . . . . . . . _ No .D.ata.PJes.!3oted Qn. pote.ntial oveJpres.sur.!3 .zooe,s. . . . . . . . . . _ . . . . . . . . . . . . .NA S.!3i,smic.analysjs Qf sbaJlow QaS.zooes. . . . . . . . . . _ . . . . . . . .NA . .S.!3abedcooditioo survey -Of off-shore) . . . . . . . . . . . . . . . . . . . . . . _ _ . . . NA . CQnta.ct oamelphoneJor.we.!3lsly progressreport$ [expIQr¡:ttoryooly). _ . . . . . . . . . NA . . . . . . . . . . . . . - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Date Public comm;,,;ðP dwS ~ I~~ ð