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BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 WELL NAME 01-32A 900 E. Benson Blvd. Anchorage,Alaska 99508 or AKGDMINTERNAL@bp.com FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY PRUDHOE BAY LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska LOG DATE February 14,2018 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(@,bhge.com TODAYS DATE May 3,2018 Revision STATUS Final Replacement: No Details: Rev. Requested by: FIELD/ COMPANY FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS CGM,Final Surveys) (Compass) P ) PERSON ATTENTION #OF PRINTS #UI-1-KIN I S #OF COPIESn #OF COPIES #OF COPIES V 1 BP North Slope. 0 1 1 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99501 3 ExxonMobil,Alaska 0 0 I 1 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4''State of Alaska -AOGCC 0 1 1 1ttn:Natural Resources Technician II • 333 W.7th Ave,Suite 100 • 5(2-310 Anchorage,Alaska 99501 �/ 5 DNR-Division of Oil&Gas *** I 0 0 1 Attn:Garret Brown 550 West 7th Avenue,Suite 1100 • Anchorage,Alaska 99501 SCANNED MAY 2 4 2018 ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. I Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:David Itter 0 TOTALS FOR THIS PAGE: 0 2 5 0 0 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11, 2012 Mr. Jim Regg 51,MPIED q" Alaska Oil and Gas Conservation Commission �- 333 West 7 Avenue Anchorage, Alaska 99501 01- Subject: Corrosion Inhibitor Treatments of GPB DS -01 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator II • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS-01 0112W12 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 qal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -17B 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -198 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 01 -22B 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -254 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA STATE OF ALASKA • ALASKA AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate ❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development IO Exploratory ❑ . 202 -1850 3. Address: P.O. Box 196612 Stratigraphic El Service ❑ 6. API- Number: Anchorage, AK 99519 - 6612 50- 029 - 21622 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028329 PBU 01 -32A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10040 feet Plugs (measured) 9399 feet true vertical 9068.95 feet Junk (measured) 9947 feet Effective Depth measured 9953 feet Packer (measured) 3884 8436 8473 feet true vertical 9062.7 feet (true vertical) 3879 8378 8414 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 94# H-40 29 - 139 29 - 139 1530 520 Surface 40' 13 -3/8" 68# K -55 28 - 68 28 - 68 3450 1950 Surface 2445' 13- 3/8 "72# L -80 68 - 2513 68 - 2513 4930 2670 Production 8599' 9 -5/8" 47# L -80 27 - 8626 27 - 8561 6870 4760 Liner 4742' 7" 26# L -80 3884 - 8626 3879 - 8561 7240 5410 Liner 1570' 4 -1/2" 12.6# 13CR80 8470 - 10040 8411 - 9069 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ - True Vertical depth: _ - "1'Vit s - u Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 25 - 8470 25 - 8411 Packers and SSSV (type, measured and true vertical depth) 7" Too Packer 3884 3879 4 -1/2" Baker S -3 Perm Packer 8436 8378 4 -1/2" BAKER LINER TOP HGR/PKR 8473 8414 RFCE1VED' 12. Stimulation or cement squeeze summary: 9 4 Intervals treated (measured): OCT 0 7 �9 20 ` t Treatment descriptions including volumes used and final pressure: *aka Oil & Gas Cons. Commission (whorl? 13. Representative Daily Average Production or Ind tion Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 932 32,657 2,275 331 Subsequent to operation: 464 19,183 2,500 682 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 , Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , 1 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - •e Lastui t Title Petrotechnical Data Technologist I Signatu - ant i Phone 564 -4091 Date 10/6/2011 Nri RSDMS OCT 17 all ciArt � O,r � !( Submit ri i y Form 10-404 Revised 10/2010 t �� /i Original Onl 01 -32A 202 -185 PERF ATTACHMENT Sw Name 'Operation Date 'Pelf Operation Code Meas Depth Top Meas Depth Base I Depth Top Tvd Depth Base 01 -32A 12/20/02 PER 9,610. 9,660.', 9,045.88 9,048.49 01 -32A 1 12/20/02 PER 9,750. 9,775. 9,052.05 9,052.94 01 -32A 12/20/02 PER 9,825. 9,850. 9,054.72 9,055.86 01 -32A 12/20/02 PER 9,875. 9,900. 9,057.26 9,058.9 01 -32A 12/20/02 PER _ 9,928. 9,953. 9,060.91 9,062.7 01 -32A 5/7/05 SQZ 9,610. 9,660. 9,045.88 9,048.49 01 -32A 5/29/05 APF 9,900. ! 9,925. 9,058.9 9,060.69 01 -32A I 5/29/05 APF 9,850. 9,875. 9,055.861 9,057.26 01 -32A ± 5/30_/05 APF 9,775. 9,825. 9,052.94', 9,054.72 - --- 9 048.01 9,048.49 01 -32A 4/23/071APF 9,650. 9,660. 01 -32A 6/18/071APF _ 9,610. 9,650. 9,045.88 -- - 9,048.01 01 -32A 2/29108 BPP _ 8,447. 9,953.; 8,389.01 9,062.7 • 01 -32A 2/20/08 BPS 1 8,447. 9,953.1 8,389.01 9,062.7 01 -32A 9/14/11 APF ./ 9,360. 9,370. 8,988.99 8,992.95 01 -32A 9/16/11 BPS , - 9,399. 9,953.1I 9,003.98 9,062.7 AB APF ABANDONED PER PERF ADD PERF 1 RPF REPERF _ -I BPP BRIDGE PLUG PULLED SL ;SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED - - FCO FILL CLEAN OUT 1 SPS SAND PLUG SET FIL FILL MIR MECHANICAL ISOLATED SQF (SQUEEZE FAILED 1 OLATED RE MOVED I SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • • • O1 -32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY �k'at2:p ,�x %' °" " a m��� �' `;`S "k; �3 :`a$ ^` �^F � � --. .''..i�;. ... ?5..�,x.- :��;::; :.d »i;-" - ���%- 7°:'�.Ga'.h����` 9/14/2011 Assist E- Line /Pump as needed to push perf guns downhole (Profile Mod) Job postponed, EL on well upon departure, Pad Op notified. FWHP= 2100/0/0 9/14/2011 ** *WELL SHUT IN ON ARRIVAL * ** (E -LINE AD -PERF, PLUG) INITIAL T /I /0 2120/ 0/0 'STOPPED DUE TO DEVIATION AT 9500'. PERFORATED 9360' -9370' DEPTH ;CORRECTED TO SLB MEMORY CNL LOG DATED 18- DEC -02. SHOT 2.88" HSD 6 SPF, 60 DEGREE PHASED PJOMEGA 2906 GUN. CLOSED GROVE VALVE BEHIND WELLHOUSE AS PER DSO REQUEST, VALVE IS FLAGGED. HAND OVER WITH DSO PRIOR TO DEPARTURE. LEFT WELL ;SHUT -IN. `FINAL T /I /O 2100/0/0. ** *JOB COMPLETE * ** 9/16/2011; ** *WELL SHUT -IN ON ARRIVAL * ** INITAL T /I /O 2100/0/P SSV CLOSED ON ARRIVAL ?SET HALLIBURTON CIBP AT 9400' MID - ELMENT DEPTH, TOP OF PLUG AT 9399 ;CORRECTED TO SLB MCNL LOG DATED 18- DEC -02. TAGGED PLUG AFTER SETTING TO CONFIRM. HAND OVER WITH DSO PRIOR TO DEPARTURE, WELL ;READY TO POP. FINAL T /I /O 2000/0/0. SSV CLOSED. ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL TREE i= , • CIW 0 SAFETY S: WELL ANGLE > 70° @ 9350' WELLHEAD = FMC " k ROME LNR & TBG*** ACTUATOR = BAKER C 01 -32A , *** 4 KB. ELEV = 70" BF. ELEV = ? 13-3/8" CSG, 68#, — 69' FFN KOP = 7000 K-55 BUTT, Max Angle = 88° @ 9809' ID = 12.415" Datum WD = 8800' SS 20" CONDUCTOR, 110' 2207' H4-1/2" HES X NIP, ID = 3.813" 1 Datum MD = 9060' 0 --I 91.5#, H-40, ID = 19.125" GAS LIFT MANDRELS 1 13-3/8" CSG, 72#, L-80 BUTT, ID = 12.347" H 2515' STI MD 1 TVD I D I TYPE VLV LATCH PORT DATE 4 3575 3571 5 KBG-2 DMY BK 0 06/04/11 19-5/8' X 7" TIEBACK SLV, D = 7.50" H 3884' 1 ir 3 5964 5956 3 KBG-2 DMY BK 0 06/04/11 19-5/8" X 7" BKR LTP w / HGR, ID = 6.29" 1-1 2 7512 7482 16 KBG-2 DMY BK 0 01/16/87 1 9-5/8" CSG, 47#, L-80 NSCC XO TO BUTT I — I 5131' I—X 1 8388 8332 14 KBG-2 DMY _ BK _ 0 01/16/87 Minimum ID = 3.813" @ 2207' I 1 8416' H 4_1/ 2" HES X NIP, ID = 3.813" I 4-1/2" HES X NIPPLE E c 1 8436' I X 4-1/2" BKR S-3 PKR, D = 3.875 I I 1 8460' H4-1/2" HES X NIP, ID = 3.813" I 8465' H " TIEBACK SLV, ID = 5.250" I 4-1/2" TBG, 12.6#, 13CR-80 VAM ACE. -- 8472' H4-1/2" WLEG, ID = 3.958" I I 8472' I .0152 bpf, ID = 3.958" ..." - I i n 8. 3' 7" X 5-1/2" BKR LTP w / LNR HGR, ID = 4.390" I 8485' H5-1/2" X 4-1/2" X0, D = 3.930" I 17" WHIPSTOCK (11/24/02) I — I 8635' 1 MILLOUT WINDOW (01-32A) 8626' - 8639' 1 9-5/8" CSG, 47#, L-80 BUTT, ID = 8.681" I— -1 !""■.----\___ 0 9400' H4-1/2" HES CIBP (09/16/11) 17" LNR, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" I — I 8779' V PERFORATION SUMMARY 1 9947' — FISH- FASDRILL DEBRIS REF LOG: MEM-CNL ON 12/18/02 RIG MILLED ANGLE AT TOP PERE: 67° @ 9360' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9360 - 9370 0 09/14/11 ' AVAWAV 2-7/8" 6 9610 - 9650 C 06/18/07 • ..4 X i 3-3/8" 6 9610 - 9660 S 12/20/02 Alum 2-7/8" 6 9650 - 9660 C 04/23/07 9953 Ala, 1 PBTD 1 ' Amy 3-3/8" 6 9750 - 9775 C 12/20/02 2-7/8" 4 9775 - 9800 C 05/30/05 2-7/8" 4 9800 - 9825 C 05/30/05 3-3/8" 6 9825 - 9850 C 12/19/02 4-1/2" LNR, 12.6#, 13CR-80 BTC-M, .0152 bpf, ID = 3.958 1-1 10040' I 2-7/8" 4 9850 -9875 C 05/30/05 3-3/8" 6 9875 - 9900 C 12/19/02 2-7/8" 4 9900 - 9925 C 05/30/05 3-3/8" 6 9928 - 9953 C 12/18/02 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/16/87 PKR 141 ORIGINAL COMPLETION 06/13/11 WEC/ PJC GLV 0/0 (06/04/11) WELL; 01-32A . . 01/30/02 N22S SIDETRACK (01-32A) 09/17/11 TTW/ PJC ADPERF/ CIBP (9/14-16/11) PERMIT No: F 2021850 02/10/07 KSB/PAG GLV 0/0 (02/06/07) 09/18/11 PJC DRAWING CORRECTIONS API No: 50-029-21622-01 02/25/07 KSB/TLH GLV C/0 SEC 8, Ti ON, R15E, 368' FNL & 678' FWL 06/18/07 RLM/PJC PERFORATIONS 03/07/08 JJL/PJC PULL PXN PLUG (02/29/08) BP Exploration (Alaska) OPERABLE: Producer 01 -32A (PTD #2021850) Tubing Integrity Restored • Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] \ y Z /(a(U Sent: Sunday, June 05, 2011 9:03 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Yeager, Kevin E Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Stechauner, Bernhard Subject: OPERABLE: Producer 01 -32A (PTD #2021850) Tubing Integrity Restored All, Producer 01 -32 (PTD #2021850) passed a MIT -IA to 3000 psi on 06/04/2011 after installing dummy gas lift valves. The passing MIT -IA confirms the presence of two competent barriers in the welrbore. fhe well is reclassified as Operable. The current plan is to leave the dummy gas lift valves in the completion. In the event Operations would like to flow the well, please be aware of the potential for annular fluid expansion due to the fluid packed annuli. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) ��; Well Integrity Coordinator '"'' Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, May 27, 2011 8:12 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Yeager, Kevin E Cc: King, Whitney; Stechauner, Bernhard Subject: UNDER EVALUATION: Producer 01 -32A (PTD #2021850) Sustained casing pressure on the IA All, Producer 01 -32A (PTD #2021850) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA = SSV/2200NAC on 5/25/2011. A TIFL failed on 5/26/2011 confirming that tubing integrity is compromised. The well has been reclassified as Under Evaluation while work is conducted to restore integrity. The plan forward is: 1. DHD: TIFL - Failed 2. Slickline: DGLVs and MIT -IA. A TIO plot and wellbore schematic have been included for reference. 6/6/2011 OPERABLE: Producer 01 -32A (PTD • 21850) • Tubing Integrity Restored • Page 2 of 2 Thank you, Mehreen Vazir t e rho re: Ger,;;Ild Mu r hy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 6/6/2011 UNDER EVALUATION: Producer O14A (PTD #2021850) Sustained casing,ssure on the IA Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @ bp.com] ' l ej 6/1/11 Sent: Tuesday, May 31, 2011 1:42 PM To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Producer 01 -32A (PTD #2021850) Sustained casing pressure on the IA Attachments: 01 -32 TIO Data 5- 31- 11.xls Jim, Attached is the requested tabular data. On 03/13/2011 the IA pressure was reported as 2075 psi. On 3/16/2011 a passing TIFL was achieved verifying competent tubing. On 04/18/2011 the IA pressure was reported as 2100 psi. On 4/20/2011 a passing TIFL was achieved verifying competent tubing. On 05/25/2011 the IA pressure was reported as 2100 psi. A TIFL was conducted on 5/27/2011 that failed after which notification was made to the AOGCC for Sustained Casing Pressure on the IA. Please let me know if you have further questions. Thank you, Mehreen Vazir (Alternate: Gerald urphy) " � JUN (1 2, 2011 Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, May 31, 2011 10:27 AM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Producer 01 -32A (PTD #2021850) Sustained casing pressure on the IA According to the TIO Plot you have provided, the IA pressure exceeded AOGCC notification threshold (2000psi per Conservation Order 492) in mid - March, and again in mid - April; I do not find any records of the Commission being notified of these events. Provide table of IA pressures for March 1 through May 31. Also provide any evaluations performed during the same timeframe (TIFL, MIT, etc.). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, May 27, 2011 8:12 PM 5/31/2011 UNDER EVALUATION: Producer 014A (PTD #2021850) Sustained casing ,ssure on the IA Page 2 of 2 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Yeager, Kevin E Cc: King, Whitney; Stechauner, Bernhard Subject: UNDER EVALUATION: Producer 01 -32A (PTD #2021850) Sustained casing pressure on the IA All, Producer 01 -32A (PTD #2021850) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA = SSV/2200NAC on 5/25/2011. A TIFL failed on 5/26/2011 confirming that tubing integrity is compromised. The well has been reclassified as Under Evaluation while work is conducted to restore integrity. The plan forward is: 1. DHD: TIFL - Failed 2. Slickline: DGLVs and MIT -IA. A TIO plot and wellbore schematic have been included for reference. «01- 32A.pdf» «01 -32A TIO 05- 27- 11.doc» Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 5/31/2011 PBU 01 -32A PTD #2021850 5/27/2011 TIO Pressures Plot Welk 01 -32 I i 4,000 - — 3 } 3,000 - Tbp —�— IA 2,000 - —�— OA ociA • —�— OOOA • 0 n 1,000 - 03/05/11 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 05/14/11 05/21/11 I • PBU 01 -32A (PTD 2021850) IA Pressures I Reading Date (Flow Line Pressure 'Inner Annulus Pressure 'Outer Annulus Pressure 3/1/2011 0 1,560 20 3/2/2011 0 1,560 20 3/3/2011 0 1,160 20 3/4/2011 0 1,160 20 3/5/2011 0 1,740 20 3/6/2011 0 1,740 20 3/8/2011 0 1,740 20 3/9/2011 0 1,800 20 3/10/2011 0 1,850 20 3/11/2011 0 1,950 20 3/12/2011 0 1,980 20 3/13/2011 0 2,075 20 3/14/2011 0 2,100 20 3/15/2011 0 2,160 20 3/16/2011 0 1,275 20 TIFL Passed 3/17/2011 0 1,275 20 3/18/2011 0 1,350 20 3/19/2011 0 1,375 20 3/20/2011 0 1,425 20 3/21/2011 0 1,475 20 3/22/2011 0 1,525 20 3/23/2011 0 1,525 20 3/24/2011 0 1,600 20 3/25/2011 0 1,600 20 3/26/2011 0 1,600 20 3/27/2011 0 1,600 20 3/28/2011 0 1,700 20 3/29/2011 0 1,700 20 3/30/2011 0 1,700 20 3/31/2011 0 1,700 20 4/1/2011 0 1,700 20 4/2/2011 0 1,980 20 4/3/2011 0 1,980 20 4/4/2011 0 1,980 20 4/5/2011 0 1,980 20 4/6/2011 0 1,980 20 4/7/2011 0 1,980 20 4/8/2011 252 880 100 4/9/2011 252 550 120 4/10/2011 202 600 120 4/11/2011 202 600 120 4/12/2011 202 550 120 4/13/2011 202 550 120 4/14/2011 202 550 80 4/15/2011 202 550 80 4/16/2011 0 550 80 4/17/2011 0 1,850 80 4/18/2011 0 2,100 80 4/19/2011 0 2,100 80 • • (Reading Date (Flow Line Pressure 'Inner Annulus Pressure 'Outer Annulus Pressure 4/20/2011 0 1,050 10 TIFL Passed 4/21/2011 0 1,080 10 4/22/2011 0 1,080 10 4/24/2011 0 1,160 800 4/25/2011 0 1,160 800 4/26/2011 0 1,160 50 4/27/2011 0 1,240 50 4/28/2011 0 1,240 50 4/29/2011 0 1,280 50 4/30/2011 0 1,280 50 5/1/2011 0 1,320 50 5/2/2011 0 1,320 50 5/3/2011 0 1,320 50 5/4/2011 0 1,400 50 5/5/2011 0 1,450 50 5/6/2011 0 1,450 50 5/7/2011 0 1,500 50 5/8/2011 0 1,500 50 5/9/2011 0 1,525 50 5/10/2011 0 1,550 50 5/11/2011 0 1,600 50 5/12/2011 0 1,600 50 5/13/2011 0 1,640 50 5/14/2011 0 1,660 50 5/15/2011 0 1,700 50 5/16/2011 0 1,700 50 5/17/2011 0 1,725 50 5/18/2011 0 1,725 50 5/19/2011 0 1,725 50 5/20/2011 0 1,825 50 5/22/2011 0 1,825 50 5/23/2011 0 1,825 50 5/24/2011 0 1,300 220 5/25/2011 0 2,100 220 5/26/2011 0 2,120 220 5/27/2011 0 2,280 20 TIFL Failed 5/28/2011 0 2,280 20 5/29/2011 0 2,280 20 5/30/2011 0 2,280 20 UNDER EVALUATION: Producer 042A (PTD #2021850) Sustained casing essure on the IA Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) 1� 5 l i I t� Sent: Tuesday, May 31, 2011 10:27 AM l To: 'AK, D &C Well Integrity Coordinator' Subject: RE: UNDER EVALUATION: Producer 01 -32A (PTD #2021850) Sustained casing pressure on the IA According to the TIO Plot you have provided, the IA pressure exceeded AOGCC notification threshold (2000psi per Conservation Order 492) in mid- March, and again in mid - April; I do not find any records of the Commission being notified of these events. Provide table of IA pressures for March 1 through May 31. Also provide any evaluations performed during the same timeframe (TIFL, MIT, etc.). Jim Regg AOGCC 333 W.7th Avenue, Suite 100 t (1 Anchorage, AK 99501 " JUN 0 1 2 011 907- 793 -1236 From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, May 27, 2011 8:12 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Yeager, Kevin E Cc: King, Whitney; Stechauner, Bernhard Subject: UNDER EVALUATION: Producer 01 -32A (PTD #2021850) Sustained casing pressure on the IA All, Producer 01 -32A (PTD #2021850) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA = SSV/2200NAC on 5/25/2011. A TIFL failed on 5/26/2011 confirming that tubing integrity is compromised. The well has been reclassified as Under Evaluation while work is conducted to restore integrity. The plan forward is: 1. DHD: TIFL - Failed ' 2. Slickline: DGLVs and MIT -IA. - A TIO plot and wellbore schematic have been included for reference. «01- 32A.pdf» «01 -32A TIO 05- 27- 11.doc» Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com 5/31/2011 PBU 01 -32A PTD #2021850 5/27/2011 TIO Pressures Plot Well: 01 -32 4,000 - • 3,000 - ��s Zcx��P9' • elL> • Tbg --II– IA 2,000 - — Ak — OA 00A —4— 000A On 1,000 - • 03/05/11 03/12/11 03/19/11 03/26:11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 05/07/11 05/14/11 05/21/11 TREE = ? WELLHEAD = FMC e SA TES: * 4 13 CHROME LNR & ACTUATOR = AXELSON 01 -32A TBG* KB. ELEV = 67.7' BF. ELEV = ? ' KOP = 7000' Max Angle = 88 @ 9809' Datum MD = 9060 2207' 1-14-1/2" HES X NIP, ID = 3.813" 1 ' Datum TV D = 8800 SS 0 I [ 1 13-3/8" CSG, 68# / 72#, K-55 / L-80, ID = 12.347" H 2515' I--A 3884' H 7" SCAB LNR HGR / TIEBACK SLV 1 GAS LIFT MANDRELS - 1ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.813" @2207' 71 4 3575 3571 5 KBG-2 DOME BK 16 02/25/07 4-1/2" HES X NIPPLE 3 5964 5956 3 KBG-2 SO BK 20 02/25/07 2 7512 7482 16 KBG-2 DMY BK 0 1 8388 8332 14 KBG-2 DMY BK 0 I I ( 8416' H4-1/2" HES X NIP, ID = 3.813" 1 , 8436' H7" X 4-1/2" BKR S-3 PKR, ID = 3.875 1 I • • 8460' -14-1/2" HES X NIP, ID = 3.813" 4-1/2" TBG. 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 1--1 8470' I ... 8470' H 4-1 / 2" WLEG, ID = 3.958" 8473' 1-17" BKR LNR TOP HGR/PKR, ID = 4.390" 1 MIL LOUT WINDOW @ 8626' - 8639' WHIPSTOCK (SET 11/24/02) H 8635' 1 --. 3 17" SCAB LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 8779' 1 I L ., 9947' - ASH- FASDRILL DEBRIS RIG MILLED FISH - 120' OF MILLED PACKER/TAILPIPE H 8779' 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9344' A AT, V T • v O Y V 0 41,■ "v. PERFORATION SUMMARY Alm REF LOG: MEM-CNL ON 12/18/02 , PBTD 1 9953' Ar ANGLE AT TOP PERE: 87 @ 9610' Note: Refer to Production DB for historical perf data 14-1/2" LNR, 12.6#. 13-CR-80„0152 bpf, ID = 3.958 H 10040' SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 DATE REV BY COMMENTS , DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/18/86 ORIGINAL COMPLETION 02/10/07 KSB/PAG GLV C/O (02/06/07) WELL: 01-32A 01/16/87 LAST WORKOVER 02/25/07 KSB/TLH GLV C/O PERMIT No: F 2021850 12/01/02 DCR/TLH SIDETRACK (01-32A) 06/18/07 RLM/PJC PERFORATIONS API No: 50-029-21622-01 12/20/02 TMN/tlh ADD PERFS 03/07/08 JJUPJC PULL PXN PLUG (02/29/08) SEC 5, T1ON, R15E, 5179.21' FEL & 5087.29' FNL 05/11/05 KDC/PJC GLV C/O 05/30/05 MCD/PJC_ PERES BP Exploration (Alaska) TREE= ? • • WELLHEAD = FMC ACTUATOR = AXELSON KB. ELEV = 67.7' 0 1 -32A BF. ELEV = 2 KOP = 7000' Max Angle = 88 @ 9809' Datum MD = 9060' Datum TV D = 8800' SS [ _A Min I 2 ■70,1 I PERFORATION SUMMARY REF LOG: MEM-CNL ON 12/18/02 ANGLE AT TOP PERF: 87 © 9610' Note: Refer to Production DB for historical perf data NI SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9610 - 9650 0 06/18/07 3-3/8 6 9610 - 9660 S 12/20/02 2-7/8 6 9650 - 9660 0 04/23/07 1 , 3-3/8 6 9750 - 9775 0 12/20/02 2-7/8" 4 9775 - 9800 0 05/30/05 2-7/8" 4 9800 - 9825 0 05/30/05 3-3/8" 6 9825 - 9850 0 12/19/02 2-7/8" 4 9850 -9875 o 05/30/05 3-3/8" 6 9875 - 9900 o 12/19/02 2-7/8" 4 9900 - 9925 o 05/30/05 1111 3-3/8" 6 9928 - 9953 0 12/18/02 Il k A. . . . •• • •••,. AV, AV ovir 4■1•■•• ' •C DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT .. . 08/18/86 ORIGINAL COMPLETION 1 02/10/07 KSB/PAG GLV C/0 (02/06/07) WELL: 01-32A 01/16/87 LAST WORKOVER 02/25/07 KSB/TLH GLV C/O PERMIT No: F 2021850 12/01/02 DCR/TLH SIDETRACK (01-32A) 06/18/07 RLM/PJC PERFORATIONS API No: 50-029-21622-01 12/20/02 TMN/tIh ADD PERFS I 03/07/08 JJL/PJC PULL PXN PLUG (02/29/08) SEC 5, PION, R15E, 5179.21' Fa & 5087.29' FNL 05/11/05 KDC/PJC GLV C/O 05/30/05 MCD/PJC PERFS 1 BP Exploration (Alaska) u~~I~m~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: Received by: P . '~ °j -'' pp~(1€ ~' ',fir +~~y f~: N0.5020 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 12/29/08 Well Job # 4-20/M-35 12014059 STATIC SURVEY/PERFo Descri lion Date gL 12/11/08 Color CD W-18 11988978 PRODUCTION PROFILE 1 1 Y-07A 12103704 INJECTION PROFILE ~ 12/20/08 1 1 P2-35 12031533 SCMT 12/18/08 1 1 M-16 12111931 SCMT _ , L~ 12/18/08 1 1 P2-15A 40015006 OH MWD/LWD EDIT 12/19/08 1 1 P2-15APB3 40015006 OH MWD/LWD EDIT ~`~ 04/01/07 2 1 P2-15APB2 40015006 OH MWD/LWD EDIT _ a 9 03/27/07 2 °~~ a- t' OD 03/24/07 2 1 P2-15AP81 40015006 OH MWD/LWD EDIT 1 W-31A 40017846 OH MWD/LWD EDIT ~- ( 03/22/07 2 1 W-29 11549353 CH EDIT (USIT) _' _ ~ 09/27/08 2 1 H-05A AXBD-00002 MCNL 12/18/06 1 11/20/08 1 1 U- ~ g PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH T0: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 • • 11/10/08 ~/~ ~chlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh S k' w+:la'L1 L~~'' 1 t, . i ..., ne~~ ..~:..., N0. 4967 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnkeri 333 West 7th Ave, Suite '100 Anchorage, AK 99501 F-38 12014048 LDL - 09/07/08 1 1 P2-13 11999047 PRODUCTION PROFILE (~ 09/15/08 1 1 Z-09A 12034928 USIT - /Y ( 10/14/08 1 1 01-32A 12103689 RST - 10/16/08 1 1 V-207L2 40017442 OH MWD/LWD EDIT O _ 08/15/08 3 1 ~~ . __..__ ..~..........~.....~ ...-...-.. . .... ...w........,.v nu a~n.Ym~a VIYC VVr ~ ch~.n ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~j, Alaska Data & Consulting Services 2525 Gambell Street, Suite 400.. Anchorage, AK 99503-2838 ATTN: Beth Received by: . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOOCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / M1T) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1] EDE Disk 2) 3] 4] 5] 6] 7] 1 - 32A Coil Flag 17-Jun-07 SCANNED jUL 0 5 2007 dO d -{?is -¡f /5'(;Y-('? Signed: (LJj~ RECEIVED Print Name: ~.i4. ('ï~.{...¡ IA ~ f1¡\ ~ IA IA lL ~ '1 Date: IJUL 0 2 Z007 ,'\!aska Oil & Gas Cons. Commission And10rage PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANcHORAGE, AK 99518 PHoNE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEasITE: WWW.MEMORYLOG.COM D:lMaster_ Copy _00 ]DSANC-2Oxx\Z_ WoollDistribution\Trans11IitlaC Sheets\Trnnstnit_ Original.doc ~ Kt:.vL-1 ,¡ .....- ... STATE OF ALASKA A /~p.(lb' EC 1 9 2006 ALASWOIL AND GAS CONSERVATION COMM~N 0 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. commission D Stimulate 0 Other D nc or D WaiverD Time ExtensionD D Re-enter Suspended Well D 5. Permit to Drill Number: 202-1850 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 67.7 KB , 8. Property Designation: ADLO-028329 11. Present Well Condition Summary: Total Depth measured 10040 feet true vertical 9068.95 feet Effective Depth measured 9953 feet true vertical 9062.7 feet Casing Length Size SURFACE 40 13-3/8" 68# K-55 CONDUCTOR 110 20" 94# H-40 SURFACE 2445 13-3/8" 72# L-80 PRODUCTION 8599 9-5/8" 47# L-80 LINER 4742 7" 26# L-80 LINER 1570 4-1/2" 12.6# 13Cr80 Perforation depth: Measured depth: 9610 - 9660 True Vertical depth: 9045.88 - 9048.49 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9719'-9917' Treatment descriptions including volumes used and final pressure: T/IIO 1350/180NAC 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic Exploratory Service 6. API Number: 50-029-21622-01-00 9. Well Name and Number: PBU 01-32A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool· Plugs (measured) None Junk (measured) 9947 (S') ce· 2 f! fqë: (~ tJ .' vud MD TVD Burst Collapse 28 - 68 28 - 68 3450 1950 29 - 139 29 - 139 1530 520 68 - 2513 68 - 2512.96 4930 2670 27 - 8626 27 - 8561.21 6870 4760 3884 - 8626 3878.81 - 8561.21 7240 5410 8470 - 10040 8411 .28 - 9068.95 8430 7500 9750 - 9775 9825 - 9850 9875 - 9900 9052.05 - 9052.94 9054.72 - 9055.86 9057.26 - 9058.9 4-1/2" 12.6# 13Cr80 25 - 8470 4-1/2" X Nipple 2207 7" Top Packer 3884 4-1/2" Baker S-3 Perm Packer 8436 4-1/2" BAKER LINER TOP HGR/PKR 8473 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after Droposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG Tubing pressure o o Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. WINJ Contact Gary Preble Signature Title Data Engineer Phone 564-4944 Date 12/19/2006 Form 10-404 Revised 04/2004n R \ G \ N A L Submit Original Only . . 01- 3 2A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 12/16/2006 T/I/O=1300/25010 Injectivity test (Pre acid) - Pump 350 bbls crude down IA taking returns up tubing to FL, Line up to pump down tubing, Pump 85 bbls crude (40 bbls used to pressure up) down tubing to establish injection rate of .6 bpm @ 3000 psi . ***Freeze protected Flowline w. 10 bbls 60/40 meth and 70 bbls crude. *** Final WHP's= 7001010 12117/2006 CTU #5 ***Continue job from 12/16/2006*** Drift 1.75" String w. 1.25" MU/RIH 2.50" SJSN tag btm at 9927'ctm - conduct injectivity test at 0.4 bpm I 2945 psi with 3%NH4CL - PJSM with SLB/ASRC ...Job in 12/17/2006 ASRC Post Acid flowback with CTU ,-----,---,-,-----'---""nNm'.w'=hw·'·-' 7/2006 CTU #5 ***Continue job from 12/16/2006*** Drift 1.75" CT String w.1.25" ball- MU/RIH 2.50" SJSN tag btm at 9927'ctm - conduct injectivity test at 0.4 bpm I 2945 psi with 3% NH4CL - PJSM with SLB/ASRC Pump down CT while recip across perfs 9717-9917' Acid ***Continue job on 12/18/2006*** 12/18/2006 CTU #5 ***Continue job 12/17/2006*** Continue reciprocations w. CT across perforations from 9717'-9927' pumping the following: 24 bbls 12% DAD (12 % HCL w. 10% Xylene) 24 bbls 12% HCL, 43 bbls 9:1 HCL-HF 150 bbls NH4CL Flush Injectivity pre Acid Treatment 0.4 bpm/3000 WHP Injectivity post Acid Treatment 1.0 bpm/2000 WHP (During over flush) Turn well over to ASRC Testing Unit for flow back. *** Job Complete*** FLUIDS PUMPED BBLS 264 NH4CL 41 60/40 METHANOL 305 TOTAL . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ hlSerts\Microfilm _ Marker.doc ) ) ECEI\/E:[) OCT 2 6 Z005 WELL LOG TRANSMITTAL tU«~$ka Oil ð~ Gas G[m:t Cornî'ni£3km To: State of Alaska Febnlarý~g¡{"2004 Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Fonnation Evaluation Logs: 01-32A, AI(-MW-22186 0l-32A: if: /)3 S-O Digital Log Images: 50-029-21622-01 1 CD ROIn 5ÇANNEI) NO" 0 22005 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob I(alish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ) AJðv Ma \- Signed: ÛaJ;J ~ð^~l¿!- rP:1L 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D -) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~ECE'VED Stimulate D J U L ttl~rE905 WaiverD Alaska (}i~~f1MnComm. . lTl'I'&;;J '$S'Or Re-enter SuspeA-m'rHWtJã] Repair Well 0 Pull TubingD Operation Shutdown 0 Pluç PerforationsD Perforate New Pool 0 Perforate [XI 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ŒI ExploratoryD 5. Permit to Drill Number: 202-1850 6. API Number 50-029-21622-01-00 P.o. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 67.70 8. Property Designation: ADL-028329 11. Present Well Condition Summary: StratigraphicD ServiceD 9. Well Name and Number: 01-32A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Total Depth measured 10040 feet true vertical 9069.0 feet Effective Depth measured 9953 feet true vertical 9062.7 feet Plugs (measured) None Junk (measured) 9947 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 94# H-40 29 139 29.0 139.0 1530 520 SURFACE 2445 13-3/8" 72# L-80 68 - 2513 68.0 - 2513.0 4930 2670 SURFACE 40 13-3/8" 68# K-55 28 68 28.0 68.0 3450 1950 PRODUCTION 8599 9-5/8" 47# L-80 27 - 8626 27.0 - 8561.2 6870 4760 SCAB LINER 4742 7" 26# L-80 3884 - 8626 3878.8 - 8561.2 7240 5410 LINER 1570 4-1/2" 12.6# 13Cr80 8470 - 10040 8411.3 - 9069.0 8430 7500 Perforation depth: Measured depth: 9750 - 9775,9775 - 9800, 9800 - 9825, 9825 - 9850,9850 - 9875,9875 - 9900, 9900 - 9925,9928 - 9953 True vertical depth: 9052 - 9053, 9053 - 9054, 9054 - 9055, 9055 - 9056,9056 - 9057, 9057 - 9059,9059 - 9061, 9061 - 9063 Tubinç ( size, qrade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 25 8470 Packers & SSSV (type & measured depth): 7" Top Packer @ 3884 4-1/2" Baker S-3 Perm PKR @ 8436 4-1/2" BKR LNR Top HGR/PKR @ 8473 4-1/2" X Nipple @ 2207 SCl-\NNED JUl 1. 4 2005 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Fl JUL 13 2005 13 Prior to well operation: Subsequent to operation: Oil-Bbl SHUT-IN 740 Representative Dailv Average Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 36605 76 Tubing Pressure 828 183 14. Attachments: ~ 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil[!] GasD DevelopmentŒ] Service D Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature ,ð( ~- .~.9f...Jlc1L ~ Title Petroleum Engineer Phone 564-5174 Date 7/12/05 Form 10-404 Revised 4/2004 !(~)~NAL ) 01-32A ) DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 05/06/05 MIRU CTU #5. MU BHA WITH 3.62511 DRIFT AND CARRIER FOR MEMORY TOOLS. OAL = 21.361 RUN MEMORY LOGS FROM 99001 TO 84001. PAINT FLAG AT 9620.41 FOR TIE IN. SET HALLIBURTON FASDRILL PLUG @ 9700'....... 05/07/05 ACIDIZE PERFS 9610-9660 WITH 20 BBLS 12% HCL. PUMP 30 LATEX CEMENT. WELL LOCKED UP WITH 2 BBLS OUT OF NOZZLE. LAY IN CEMENT 1:1 TO TO 7700'. PRESSURE UP ON SQUEEZE TO 4000#. PULL UP TO 65001. HOLD PRESSURE AT 3500 PSI. AFTER HOLDING 3500 PSI FOR ONE HOUR PRESSURE SUDDENLY BROKE TO 0 PSI. NO SURFACE LEAKS OF OPEN VALVES. NO COMUNCIATION TO IA. RE-BUMP PRESSURE TO 2500 PSI OVER 2 HOUR TIME FRAME IN 500 PSI INCREMENTS. AT 2500 PSI, PRESSURE BLED TO 2428 PSI IN 17 MINUTES. CLEAN- OUT CEMENT TO 95501 WITH BIOZAN. RETURN INITIALLY 1:1, DECREASING TO 1.2:1 NEAR END OF CLEANOUT. TRAP 500 PSI WHP. RDMO. OS/27/05 CTU #5, MILL CMT/FASDRILL; MIRU DS CTU #5. RIH WITH BAKER 2 7/811 PDM WITH 3.7511 CONCAVE 5 - BLADE JUNK MILL. START MOTOR WORK AT 95701 CTMD. CONTINUOUS MOTOR WORK DOWN TO 9697' CTMD. SEVERAL MOTOR STALLS AT 97001 CTMD. PUMP SEVERAL FLOPRO PILLS TO HELP LIFT CEMENT RETURNS TO SURFACE. CONTINUE MILLING AHEAD. MINIMAL MATERIAL IN RETURNS. AVERAGE ROP 37 FT/HR. OS/28/05 CTU #5, MILL CMT / ADPERF; MILLED TO 99471 CTMD. PUMPED 37 BBL FLOPRO SWEEP ON BTM. CHASED OOH AT 80%. POOH. FP WELL WITH 50/50 FROM 25001. BLOW DOWN COIL W/ N2. RDMO. ... JOB INCOMPLETE... OS/29/05 CTU#5, JEWELRY LOG / ADPERF; MIRU CTU #5. PUMP GAUGE BALL. BOP TEST. RIH WITH PDS MEMORY GAMMA RAY/CCL WHILE CIRCULATING KCL W/ 1.5% LUBETEX. SAT DOWN AT 99581 CTMD. LOG FROM 99441-93001 CTMD. PAINT WHITE FLAG AT 98601 CTMD. GOOD DATA. TIE-IN TO SLB BORAX CNL LOG DATED 02/02/2003 (+2 FT CORRECTION). MU AND RIH WITH SLB 2-7/8" PJ2906 GUN. PERFORATE 251 INTERVAL, 4 SPF, FROM 9900'-99251 CORRECTED. POOH. MU AND RIH WITH 2ND SLB 2-7/811 PJ2906 GUN. PERFORATE 251 INTERVAL, 4 SPF, FROM 98501-98751 CORRECTED. POOH. MU AND RIH WITH 3RD SLB 2-7/811 GUN. 05/30/05 CTU #5, ADPERF,... RIH WITH 3RD SLB 2-7/811 PJ2906 GUN. PERFORATE 25' INTERVAL, 4 SPF, FROM 98001-98251 CORRECTED. POOH. MU AND RIH WITH 4TH SLB 2-7/811 PJ2906 GUN. PERFORATE 251 INTERVAL, 4 SPF, FROM 9775'-98001 CORRRECTED. POOH. FREEZE PROTECT TUBING TO 13001 WITH 20 BBLS METHANOL. FLOWLINE IS NOT FREEZE PROTECTED. DSO OPERATOR NOTIFIED WELL IS READY TO POP. DSO CONFIRMS HE POP IMMEDIATELY AFTER RIG DOWN. *** JOB COMPLETED*** FLUIDS PUMPED BBLS 102 60/40 METHANOL WATER 182 50/50 METHANOL WATER 153 DIESEL 40 FRESH WATER 353 1% KCL WATER 2289 1 % EXTRA SLICK KCL WATER 78 FLOPRO 20 12% HCL ACID 94 BIOZAN 332 1 % KCL WATER WITH 1.5% LUBETEX & FLOVIS 3643 TOTAL Page 1 ( TREE = WELLHEAD = - ACTUATOR= w KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = ? FMC AXELSON 67.7' ? 7000' 88 @ 9809' 9060' 8800' SS -~) 01-32A ct 113-3/8" CSG, 68# / 72#, K-55 / L-80, 10 = 12.347" l-i 2515' ~ Minimum ID = 3.813" @ 2207' 4-1/2" HES X NIPPLE 14-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" l-i I WHIPSTOCK (SET 11/24/02) l-i 8635' 7" SCAB LNR, 26#, L-80, .0383 bpf, 10 = 6.276" l-i l-i I 120' OF MILLED PACKERlTAILPIÆ I 9-5/8" CSG, 47#, L-80, 10 = 8.681" l-i ÆRFORA TION SUMMARY REF LOG: MEM-CNL ON 12/18/02 ANGLEATTOP ÆRF: 87 @ 9610' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE DATE 08/18/86 01/16/87 12/01/02 12/07/02 12/20/02 06/11/03 SEE PAGE 2 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER DCR/TLH SIDETRACK (01-32A) JM/tlh GL V C/O TMN/tlh A DO ÆRFS CMO/TLP KB ELEVATION CORRECTION 8779' 8779' 9344' DATE 08/18/03 09/22/04 11/29/04 05/11/05 05/30/05 ~ I L S )rY NOTES: * 4·1/2" 13 CHROME LNR & Tbv" 2207' 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 ~ 3884' l-i 7" SCAB LNR HGR / TIEBACK SLV I GAS LIFT MANDRELS DEV ìYÆ VLV LATCH PORT DATE 5 KBG-2 DOME BK 16 05/11/05 3 KBG-2 S/O BK 20 05/11/05 16 KBG-2 DMY BK 0 14 KBG-2 DMY BK 0 } I ST MD TVD 4 3575 3571 3 5964 5956 2 7512 7482 1 8388 8332 I I 8416' 1-1 4-1/2" HES X NIP, 10 = 3.813" 1 :g ~ 8436' l-i 7" X 4-1/2" BAKER S-3 PKR, ID = 3.875 I I 8460' 1-1 4-1/2" HES X NIP, ID = 3.813" 1 8470' j ~ il4:¡ ~ ~~ ~ ~ ~ 8470' 8473' 1-1 4-1/2" WLEG, ID = 3.958" 1 1--1 7" BAKER LNR TOP HGRlPKR, 10 = 4.390" 1 MILLOUT WINDOW @ 8626' - 8639' I 9947' FISH- POSSIBLE DEBRIS FROM MILLED FASDRILL I PBTD 1-1 9953' REV BY COMMENTS CMO/TLP DATUM MD CORRECTION CAO/TLP GLV C/O DFRlTLP 13-3/8" CSG CORRECTION KDClPJC GL V C/O MCD/PJC ÆRFS 1 4-1/2" LNR, 12.6#, 13-CR-80, .0152 bpf, 10 = 3.958 l-i 10040' I PRUDHOE BAY UNIT WELL: 01-32A ÆRMIT No: '2021850 API No: 50-029-21622-01 SEC 5, T10N, R15E, 5179.21' FEL & 5087.29' FNL BP Exploration (Alaska) TREE = WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumiVD = ) ? FMC AXELSON 67.7' ? 7000' 88 @ 9809' 9060' 8800' SS Minimum ID = 3.813" @ 2207' 4·1/2" HES X NIPPLE ÆRFORA TION SUMMARY REF LOG: MEM-CNL ON 12/18/02 ANGLEATTOPÆRF: 87 @ 9610' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 9610 - 9660 S 12/20/02 3-3/8" 6 9750 - 9775 0 12/20/02 2-7/8" 4 9775 - 9800 0 05/30/05 2- 7/8" 4 9800 - 9825 0 05/30/05 3-3/8" 6 9825 - 9850 0 12/19/02 2-7/8" 4 9850 -9875 0 05/30/05 3-3/8" 6 9875 - 9900 0 12/19/02 2- 7/8" 4 9900 ~ 9925 0 05/30/05 3-3/8" 6 9928 - 9953 0 12/18/02 DATE 08/18/86 01/16/87 12/01/02 12/07/02 12/20/02 06/11/03 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER DCRlTLH SIDETRACK (01-32A) Jrvvtlh GL V C/O TMN/tlh ADD ÆRFS CMO/TLP KB ELEVATION CORRECTION DATE 08/18/03 09/22/04 11/29/04 05/11/05 05/30/05 ~ 'lTY NOTES: * 4·1/2" 13 CHROME LINER * ~ 01-32A - ~ ~ ~ I J I L I I 8 8 I I .1;.., ""'" I"}" ~ L ~ . ~ ~ ~ REV BY COMMENTS CMO/TLP DATUM MD CORRECTION CAO/TLP GLV C/O DFRlTLP 13-3/8" CSG CORRECTION KDClPJC GL V C/O MCD/PJC ÆRFS PRUDHOE BAY UNIT WELL: 01-32A ÆRMIT No: "2021850 API No: 50-029-21622-01 SEC 5, T10N, R15E. 5179.21' FEL & 5087.29' FNL BP Exploration (Alaska) Permit to Drill 2021850 ! '¡{ .J u- J-t.J \ \ DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Jp (,l ¿ ~ J-1If 0 V ~tk1 PL API No. 50-029-21622-01-00 Well Name/No. PRUDHOE BAY UNIT 01-32A Operator BP EXPLORATION (ALASKA) INC MD 10040 --," TVD 9069 ,," Completion Date 12/18/2002 ~. CompletionStatu$ 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION DATA INFORMATION Mud Log No Samples No Directional Survey --~. MWD ASI DIR, GR, RES, Memory CNL (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Type Med/Frmt ED C d!Óg Rpt fiD (ff'/ Rpt Rpt ~< pO æ6/~ ~D (ED' C Pdf /" ED C Pdf ED C Lis vED C Lis y/ ---~--- Electr Dataset Number Name 11735 Neutron ~utron -......,,' . Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 1 8348 9960 Case 3/25/2003 25 Blu 8348 9960 Case 3/25/2003 8597 10040 Open 12/13/2002 8597 1 0040 Open 12/13/2002 8597 1 0040 Open 12/13/2002 MWD 8515 9983 Open 4/17/2003 8515 9983 Open 4/17/2003 8597 10040 Open 12/13/2002 MWD 8697 9499 Case.. 1/21/2003 Coil Flag 25 3 8626 10040 Open 2/26/2004 Rap, DGR, EWR- Horizontal Presentation - MWD 25 3 8626 1 0040 Open 2/26/2004 Rap, DGR, EWR - --,' Horizontal Presentation - MWD 8626 1 0040 Open 2/26/2004 Rap, DGR, EWR - Horizontal Presentation - MWD 3 8626 1 0040 Open 2/26/2004 Rap, DGR, EWR - Horizontal Presentation - MWD Blu 8382 9960 REVISED MEM INJECTION PRO MEMORY GRlCCUSTP Directional Survey ¿,Ðírectional Survey Directional Survey LIS Verification [r(697 LIS Verification ~ctional Survey 01613 LIS Verification "'2427 Rate of Penetration 12427 Induction/Resistivity 12427 Rate of Penetration ....-12427 Induction/Resistivity ¿HIjection Profile DATA SUBMITTAL COMPLIANCE REPORT 1/6/2005 Permit to Drill 2021850 Well Name/No. PRUDHOE BAY UNIT 01-32A Op~ratpr BP EXPLORATION (ALASKA) INC API No. 50-029-21622-01-00 MD 10040 TVD 9069 Completion Date 12/18/2002 Completion Status 1-01L Current Status 1-01L UIC N Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Well Cored? ADDITIONAL INFORMATION yG) Daily History Received? ~: .~ Chips Received? Y l-N - Formation Tops Analysis Received? -rrfiJ" Comments: Compliance Reviewed By: !~ Date: ~.to. ~J~ M~ \----' ~ ) ) eðd~'S6 1 C);Lf <91-- WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 J\nchorage,Alaska 99501 February 23, 2004 RE: MWD Formation Evaluation Logs: 01-32~ AK-MW-22186 01-32A: Digital Log Images: 50-029-21622-01 1 CD Rom 1!)~Jd 1- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECI::IVED Sign~\~ ~"c~ F-[~~P ?6 ?D; 114 ._..,) '- ..... v ,¡~aska Oi! & Gas Cons. Commission Af1chorage ~~~~ ') ) ô1oa-/'DS ( I b9 Î WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska April 07, 2003 RE: MWD FormationEvaluationLogs 01-32^ AK-MW-22 186 1 LDWG formatted Disc with verification listing. ~I#: 50-029-21622-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: s~m~(z-~ RECEIVED APR 1 7 2003 Ai.a on & Gas Cons. Commi8eion AnooClage ids ~ II' ) WELL LOG TRANSMITTAL ) j' , 'I' " 'i ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7111 Street Suite # 700 Anchorage. Alaska 99501 aOd-/~S )JI.oJ3 RE: Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR COLOR Open Hole 1 Res. Eva!. CH 1 1 1 1-32a 12/20/02 Mech. CH 1 Caliper Survey Signed: 0- GJJoop,----, Date: Print Name: PRoACTivE DiAGNOSTic SEltVicES, INC., } 10 K STREET SuirE 200, ANChonAGE, AK 99~0 1 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.memorylog.com z - :;,..- Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2772 Company: 05/08/03 State 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 E-02A í 'I '1 ,... ; .~2 MEMORY PROD PROFILE 03/15/03 1 E-31A . ;l.jry - 'iJ, MEMORY PROD PROFILE 08/08/02 1 M-29A rJl?-- L: PDC & TEMPERATURE 04/15/03 1 F-04A. . ... /" 23097 MCNL 03/02/03 1 H-21 r. -7 . 23074 RST-SIGMA 01/30/03 1 D.S. 1-32AO,,,"- J 8!) 23083 MCNUBORAX 02/02/03 1 D.5. 5-0SA '~1)-0r! 23056 RST-SIGMA 01/23/03 1 D.S. 7-29B ì jr- ».. .' 23096 MCNL 02/15/03 1 0.5. 15-38A I '1. ~ QJ 23089 LINER TOP TIE-IN MGRlCCL 02/10/03 1 .D.S. 15-48A '15"""-' ~~ 23098 MCNL 02/19/03 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: P;C~C:J\ J.t:~'") J 1.. ~ ~!1. ~~}1, 11 ... "\ ~~ ~ ~ J..: ;'"1P82 ~ P'~'{ .., - ,..1"'''' IVìi\ I j LvU,) A¡8j~2 Ç;1 ;~ ~:.:j)::Î:.' Cümm~~n I"'!¡ í \,;tj t;r:!:!.; d CD 1 1 1 1 1 1 1 ~# Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Receiv¡¡;;2ß;~j~ 2- SCblumbepgel' Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# 2-64/U-10 J qn -n'1 'f L2-28 ~ >515 ~ OI.~CJ 22516 L3-19 } ~ 5 - ~.:n3 (I" 23011 R-29A l~ t - In -t 22337 D.S. 1-32A ~Or~ .... ,'&.1:""7 23016 D.S. 3-09 }'Tc, - 0';;).:;t.... 22517 03/25/03 NO. 2717 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott Log Description Color Date Blueline Prints CD 03/08/03 1 11/13/03 1 1 11/17/02 1 1 0720/02 1 1 12/18/02 1 1 11/12/02 1 1 ,~/ INJECTION PROFILE RST (PDC) RST MCNL MCNL RST "~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth RE(;Ei\JE~:J Received~6 (1~ . ì 2:::~ .¡ r¡f"~ .)1 t\lîi\h V L.\'¡v~ Ajaôt.a Œ'¡ & Gas CQn~¡. C(;rnrf1r3~Œ! MctnJr~9:3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well 1m Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 368' SNL, 6781 EWL, SEC. 08, T10N, R15E, UM At top of productive interval 3291 NSL, 1171 EWL, SEC. 05, T10N, R15E, UM At total depth 11581 NSL, 298' EWL, SEC. 05, T10N, R15E, UM x = 697574, Y = 5942052 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB = 67. T ADL028329 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 11/25/2002 l 11/27/2002 ,., 12/18/2002 . 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10040 9069 FT 9953 9063 FT 1m Yes 0 No 22. Type Electric or Other Logs Run MWD ASI DIR, GR, RES, Memory CNL Classification of Service Well 7. Permit Number 202-185 8. API Number 50- 029-21622-01 9. Unit or Lease Name Prudhoe Bay Unit x = 698000, Y = 5940537 x = 697418, Y = 5941219 10. Well Number 01-32A 11. Field and Pool Prudhoe Bay Field I Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 220T MD 19001 (Approx.) 'í/¡#~tnJ 8t,."zt" m£> fÏ6b I /' TV/:) 23. CASING SIZE 20" 13-3/8" 9-5/8" 7" Scab 4-1/2" WT. PER FT. 91.5#' 68# 172# 47# 26# 12.6# GRADE H-40 K-55 I L-80 L-80 L-80 L -80 /13CrSO CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 1101 30" Surface 2515' 17-1/2" 2000 sx CS III, 400 sx CS II Surface 8626' 12-1/4" 705 sx Class IGI, 300 sx CS I 38841 8626' 9-5/8" 745 sx Class IGI 8465' 10040' 6-1/8" ~06 sx Class IGI AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD 9610' - 9660' 9046' - 9048' 9750' - 9775' 9052' - 9053' 9825' - 9850' 9055' - 9056' 9875' - 9900' 9058' - 9059 9928' - 9953' 9061' - 9063' SIZE 4-1/2", 12.6#, 13Cr80 TUBING RECORD DEPTH SET (MD) 84721 PACKER SET (MD) 8436' 25. MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 150 Bbls Diesel 27. Date First Production December 21,2002 Date of Test Hours Tested 1/21/2003 6 Flow Tubing Casing Pressure Press. 872 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 1,009 OIL-BBL CALCULATED 24-HoUR RATE GAs-McF 30,224 GAs-McF WATER-BBL 228 WATER-BBL CHOKE SIZE 470 GAS-OIL RATIO 29,960 OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit ck1 ~i(S: )1 'iI-.'",. .", No core samples were taken. > t""- f t' Y' v Form 10-407 Rev. 07-01-80 RBOMS BFl 2 Submit In Duplicate ) 29. Geologic Markers Marker Name Measured Depth Sag River 86221 Shublik A 86511 Shublik 8 8680' Shublik C 86951 Sadlerochit 87381 Zone 3 9030' Zone 2C 91601 Zone 28 92371 HOT 9930' ) 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8557' 85841 8610' 86241 8661' 88521 8911' 8940' 90611 & 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~~ ~ Title Technical Assistant Date 0 1'~4'D~ 01-32A Well Number 202-185 Permit No. / Approval No. Prepared By Name/Number: Terrie Hubb/e, 564-4628 Drilling Engineer: Phil Smith, 564-4897 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 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: 01-32 Common Name: 01-32A Test Date 11/25/2002 Test Type FIT Test Depth (TMD) 8,626.0 (ft) BP EXPLORATION Leak-Off Test Summary Test Depth (TVD) 8,561.0 (ft) AMW 8.50 (ppg) Surface Pressure 1 ,114 (psi) Leak Off Pressure (BHP) 4,894 (psi) Page 1 of 1 EMW 11.00 (ppg) 'L-'" ~ Printed: 12/6/2002 1 :57:52 PM ') ,) BPEXPLORAT10N O.pØJ7~~iOra$. ..$~rnmêifyRJ!PQtt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-32 01-32A REENTER+COMPLETE NABORS DRILLING CO. NABORS Start: 11/16/2002 Rig Release: 11/30/2002 Rig Number: 2ES Spud Date: 11/16/1986 End: 11/30/2002 Fröm- To HoUrs Täsk Cöde NPT 11/15/2002 15:00 - 00:00 0.00 MOB P PRE 11/16/2002 00:00 - 08:00 8.00 MOB P PRE 08:00 - 17:00 9.00 RIGU P PRE 17:00 - 17:30 0.50 BOPSUR P DECaMP 17:30 - 18:30 1.00 BOPSURP DECaMP 18:30 - 19:00 0.50 BOPSUR P DECaMP 19:00 - 19:30 0.50 BOPSUR P DECaMP 19:30 - 20:30 1.00 WHSUR P DECaMP 20:30 - 21 :30 1.00 BOPSURP DECaMP 21 :30 - 22:00 0.50 WHSUR P DECaMP 22:00 - 00:00 2.00 BOPSURP DECaMP 11/17/2002 00:00 - 03:30 3.50 BOPSUR P DECaMP 03:30 - 08:30 5.00 BOPSUR P DECaMP 08:30 - 09:00 0.50 BOPSUR P DECaMP 09:00 - 10:30 1.50 WHSUR P DECaMP 10:30 - 11 :30 1.00 PULL P DECaMP 11 :30 - 12:00 0.50 PULL P DECaMP Rig Down Nabors 2ES Pit Complex And Disconnect Lines - Move Camp Unit And Stage On Pad - Move Pit Complex And Load Truck Shop - Leave Drill Site 14 Location At 19:00 Hours With Above Units - Lay Over Mast And Leave Location With Sub Base At 23:30 Hours - Unload Trucks And Stage Equipment On OS 1 Hold Pre-Job Safety Meeting - Move Sub Base And Mast To DS-1 Location And Stage On Pad - Clear Snow Around Well No.32A And Lay Herculite - Spot Sub Base And Raise Mast Hold Pre-Job Safety Meeting - Spot Pump Room / Pit Complex - Spot Cuttings Tank, Truck Shop, Electrical Shop, Mud Man Shack, And Geoligist Office Unit - Rig Up Floor And Remove Bridal Lines - Hook Up Interconnecting Lines To Pit Complex - Prepare Rig And Location For Acceptance *NOTE* Nabors Rig 2ES Accepted For Well Work On OS 1-32A At 17:00 Hours 11/16/2002 Hold Pre-Spud Safety Awareness Meeting With All Personal Install Secondary Annulus Valve And Rig Up Circulating Lines And Equipment Hold Pre-Job Safety Meeting - Test Circulating Lines To 3,500 Psi. Open Up Well To Choke Manifold 40 Psi. On Back Side - Bleed Off Annulus To Cuttings Tank - Very Little Diesel Freeze Protect To Tank Hold Pre-Job Safety Meeting - Pick Up Lubricator And Pull BPV - 0 Psi. On Tubing Install Tree Cap Pump In Adapter And Install Circulating Hose - Pump 47 Barrels Down Back Side To Displace 5 Barrels Diesel From Tubing - Switch Lines And Pump 47 Barrels Down Tubing With Very Little Or "NO Returns" To Cuttings Tank - Tubing And Annulus On Vacuum Install BPV Test From Below Verify Seated - Blow Down Surface Equipment Hold Pre-Job Safety Meeting - Nipple Down FMC Adapter Flange And Tree - Remove From Cellar - Verify That Tubing Hanger Threads Are 9" Left Hand ACME And Inspect Threads For Corrosion Or Damage (Good Shape) - Install Blanking Plug Over Back Pressure Valve - Cap Control Lines And Secure - Prepare To Install DSA And 13 5/8" 5M BOP Stack Hold Pre-Job Safety Meeting - Install Double Studded Adapter - Nipple Up 13 5/8 5M BOP And Related Equipment Rig Up BOP Testing Equipment And Fill With Water - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector John Crisp - Test Annular, Upper Pipe Rams, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Test Pit PVT System And Perform Accumulator Test Rig Down Testing Equipment - Blow Down Surface Equipment Pull Blanking Plug - Rig Up Lubricator And Pull BPV - Lay Down Lubricator And Clear Rig Floor Make Up Landing Joint - Back Out Lock Down Studs Rig Up Equipment To Pull 4 1/2" Tubing - Rig Up Camco Printed: 12/6/2002 1:57:59 PM ') , ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-32 01-32A REENTER+COMPLETE NABORS DRILLING CO. NABORS Start: 11/16/2002 Rig Release: 11/30/2002 Rig Number: 2ES Spud Date: 11/16/1986 End: 11/30/2002 Hours Task Code NPT Phase 11/17/2002 11 :30 - 12:00 0.50 PULL P DECOMP Spooling Unit 12:00 - 12:30 0.50 WHSUR P DECOMP Replace (1) Lock Down Stud In Tubing Spool 12:30 - 13:30 1.00 PULL P DECOMP Pull Hanger To Rig Floor Unseated At 115K-lnitial Pull200K Maximum Pull 250K - Fill Annulus With 115 Barrels Fresh Water And Tubing With 25 Barrels 9.8 PPG Brine 13:30 - 14:00 0.50 PULL P DECOMP Lay Down Tubing Hanger - Rig Up Cameo Spooling Unit To Control Lines 14:00 - 16:30 2.50 PULL P DECOMP POH Laying Down 55 Joints 4 1/2" Tubing - 120K Drag For 250' Start To Pull Free Up Weight Reduced To 121K 16:30 - 17:30 1.00 PULL P DECOMP Lay Down SSSV - Recovered 31 Total Stainless Steel Bands- Rig Down Cameo Unit 17:30 - 18:00 0.50 PULL P DECOMP Clear Rig Floor Of Control Line Spool And Associated Equipment 18:00 - 20:30 2.50 PULL P DECOMP Fluids Out Of Balance - Pump 50 Barrel LCM Pill Followed By 9.4 PPG Brine - *NOTE* Fluids Circulated Thru GLM At 1,300 Feet Below Surface 20:30 - 21 :00 0.50 PULL P DECOMP Monitor Well (Static) - Blow Down Surface Equipment 21 :00 - 22:30 1.50 PULL P DECOMP Continue To POH Laying Down 20 Joints 41/2" Tubing - Gas Bubble To Surface Stab Safety Valve And Shut In Well - Check Tubing And Hanger For "NORM" Of 75 Joints Checked 7 Are Deemed To Be Hot (60 To 150 On Meter) 22:30 - 00:00 1.50 PULL P DECOMP Record Pressures SlOP 30 Psi. - SICP 30 Psi. - Weight Up Mud System To 9.8 PPG Brine 11/18/2002 00:00 - 03:00 3.00 PULL P DECOMP Continue To Raise Weight In Mud System To 9.8 PPG And Mix 50 BBL LCM Pill 03:00 - 04:30 1.50 PULL P DECOMP Bull Head 50 BBL. (PPB) LCM Pill And 380 BBLS 9.8 Fluid To Cretaceous Formation 04:30 - 05:00 0.50 PULL P DECOMP Monitor Well Fluid Level Down - Fill Back Side With 9.4 PPG Took 24 BBS To Top Off - Establish Loss Rate Losing Fluid At 120 Barrels Per Hour - POH With 41/2" 12.6 lb. L-80 Tubing From 5,075' To 4,925' (3) Joints And GLM With Hole Thru Side 05:00 - 06:00 1.00 PULL P DECOMP Continue To Fill Back Side With 9.4 PPG Brine - Mix LCM Pill (60 PPB) And Prepare To Spot Same - Reduce 9.8 PPG Brine Weight To 9.4 PPG In Mud Pit System - At 06:00 Hours Losses Have Slowed To 60 Barrels Per Hour 06:00 - 07:00 1.00 PULL P DECOMP Blow Down Surface Equipment - Lay Down 4 1/2" Tubing From 4,925' To 4,430' 07:00 - 08:30 1.50 PULL P DECOMP Spot Third 60 BBL LCM Pill (60 PPB) At Tubing Tail - 4 BPM At 160 Psi. - Well U-Tubing Mix Dry Job And Monitor Well Bore 08:30 - 14:00 5.50 PULL P DECOMP Continue To Lay Down 41/2" Tubing From 4,430' - While Monitoring Fluid Losses With Pipe Displacement - Estimated Top Of Fish At 8,134' - Recovered (194) Joints Of 41/2" 12.6 lb. L-80 Tubing, (1) SSSV, (5) GLM, And Cut Off Section On Joint No. 195 (4.22 Long) 14:00 - 15:00 1.00 PULL P DECOMP Rig Down Tubing Pulling Equipment - Clear Rig Floor And Clean Same - Loss Rate At 12 BPH 15:00 - 15:30 0.50 BOPSUR P DECOMP Make Up FMC Test Plug And Install- Rig Up BOP Testing Equipment 15:30 - 16:30 1.00 BOPSUR P DECOMP Pressure Test Annular, Upper And Lower Pipe Rams At 250 Psi. Low And 3,500 Psi. High 16:30 - 17:00 0.50 WHSUR P DECOMP Rig Down Testing Equipment - Pull Test Plug And Install Test Joint 17:00 - 19:00 2.00 FISH P DECOMP Pick Up Fishing Assembly NO.1 And RIH To 319' Printed: 12/6/2002 1:57:59 PM ') ') Legal Well Name: 01-32 Common Well Name: 01-32A Spud Date: 11/16/1986 Event Name: REENTER+COMPLETE Start: 11/16/2002 End: 11/30/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 11/30/2002 Rig Name: NABORS Rig Number: 2ES Date From ~ To Hours Task Code NPT DescriþtiÞnofOperations 11/18/2002 19:00 - 20:00 1.00 FISH P DECOMP Service Can-Rig Top Drive, Traveling Blocks, And Crown Sheaves 20:00 - 00:00 4.00 FISH P DECOMP Change Out Elevators To Accept 4" Drill Pipe - Pick Up 4" Drill Pipe From 319' To 4,520' 11/19/2002 00:00 - 04:30 4.50 FISH P DECOMP Continue To Pick Up 4" Drill Pipe And RIH To 8,001' - Stand Back (2) Stands - Install Blower Hose 04:30 - 05:00 0.50 FISH P DECOMP Connect Top Drive And Break Circulation 4 BPM With 170 Psi. - Circulate And Wash Down From 8,001' To 8,121' - Up Weight 175K Down Weight 165K Rotating Weight 170K 05:00 - 06:30 1.50 FISH P DECOMP Circulate Bottoms Up 9.4 PPG Brine - Gas Breaking Out In Bell Nipple At Bottoms Up - During This Time Phase Cut Back Mud Weight (10.5 PPG) From Mud Recieved From Nabors 9ES To 9.4 PPG 06:30 - 09:00 2.50 FISH P DECOMP Start Displacement Of 50 BBL LCM Pill Followed With 30 BBL Fresh Water Spacer And 9.4 PPG LSND Mud At 7 BPM With 880 Psi. 09:00 - 10:30 1.50 FISH P DECOMP Circulate At 1.2 BPM With 390 Psi. - Engage Top Of Fish At 8,121' Set Down 35K And Pick Up 25K Above Normal Upward Drag To 200K - Fish Moving Up Hole Drag At 60K Over Normal Upward Drag In Spots - Pump Out Of The Hole 5 Stands And Pulled 2 Stands Dry With No Problem To 7,506' - Connected Top Drive And Broke Circulation 10:30 - 13:00 2.50 FISH P DECOMP Circulate Bottoms Up And Condition Mud At 6 BPM With 700 Psi. - Monitor Well Bore (Static) - Pump Dry Job - Blow Down Can-Rig Top Drive And Surface Equipment 13:00 - 15:30 2.50 FISH P DECOMP POH With 4" Drill Pipe Standing Back In Mast From 7,506' To 319' 15:30 - 16:00 0.50 FISH P DECOMP Stand Back BHA No.1 - Pull Fish To Surface And Secure 16:00 - 16:30 0.50 FISH P DECOMP Rig Up Power Tongs And 41/2" Tubing Equipment 16:30 - 18:00 1.50 FISH P DECOMP Lay Down Fish - Recovered (3) Joints Of 4 1/2" Tubing, (3) GLM, Top And Bottom Cut Off Joints - Total Fish Recovered 267.60' - Estimated Top Of Fish At 8,395' *NOTE* Bottom Cut Recovered Length Was 21.52' Leaving 19.48' Stub Looking Up To Fish 18:00 - 18:30 0.50 FISH P DECOMP Rig Down Power Tongs And 4 1/2" Tubing Equipment 18:30 - 19:00 0.50 FISH P DECOMP Break Down And Redress 8 3/8" Over Shot With New 4 1/2" Grapple - Make Up Over Shot 19:00 - 19:30 0.50 FISH P DECOMP Make Up BHA Run NO.2 And RIH With Same 19:30 - 20:30 1.00 FISH P DECOMP Pick Up 27 Joints Of 4" Drill Pipe And RIH 20:30 - 23:30 3.00 FISH P DECOMP RIH With 4" Drill Pipe From Mast To 7,918' (Starting To Take Weight) - Break Circulation And Fill Fishing String At 3,100' And 5,900' On Trip In Hole 23:30 - 00:00 0.50 FISH P DECOMP Connect Can-Rig Top Drive And Break Circulation 5 BPM With 540 Psi.- Circulate And Wash Down From 7,918' To 7,973' - Up Weight 175K Down Weight 150K Rotating Weight 160K 11/20/2002 00:00 - 01 :30 1.50 FISH P DECOMP Continue To Circulate And Wash Down From 7,973' To 8,395' At 5 BPM With 540 Psi. - Up Weight 175K - Down Weight 150K- Rotating Weight 160K - 40 RPM And 5K Torque 01 :30 - 03:00 1.50 FISH P DECOMP Circulate Bottoms Up 8.5 BPM With 1,360 Psi. - Reduce Rate To 6 BPM At 880 Psi. Due To Shaker Screen Blinding With LCM 03:00 - 03:30 0.50 FISH P DECOMP Circulate At 1.2 BPM With 390 Psi. - Engage Top Of Fish At Printed: 12/6/2002 1:57:59 PM ) ): Legal Well Name: 01-32 Common Well Name: 01-32A Spud Date: 11/16/1986 Event Name: REENTER+COMPLETE Start: 11/16/2002 End: 11/30/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 11/30/2002 Rig Name: NABORS Rig Number: 2ES Date From'-To Hours Task Code NPT Phase Description of Operati<ms 11/20/2002 03:00 - 03:30 0.50 FISH P DECOMP 8,395' (Pump Pressure Went To 720 Psi.) Shut Down Pump And Set Down 40K - Pick Up 50K Above Normal Upward Drag With No Movement From Fish - Stage Up Pulling Weight To 300K And Jar On Fish - Fish Came Free Pull Up Hole And Establish Circulation - Reduce Pumping Rate And Slack Off Verify That Fish In Over Shot 03:30 - 04:30 1.00 FISH P DECOMP Circulate Bottoms Up While Working Pipe 30' - 8.5 BPM With 1,360 Psi. 04:30 - 05:00 0.50 FISH P DECOMP Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive And Surface Equipment 05:00 - 08:00 3.00 FISH P DECOMP POH With 4" Drill Pipe Standing Back In Mast From 8,395' To 319' 08:00 - 08:30 0.50 FISH P DECOMP POH With BHA No.2 - Pull Fish To Rig Floor And Secure 08:30 - 09:30 1.00 FISH P DECOMP Lay Down Over Shot And Fish NO.2 - Recovered Cut Off Top Joint, Pup Joint, Cross Over, Seal Assembly - Total Length Of Fish Recovered 31.10 - Estimated Top Of Packer At 8,426' 09:30 - 10:30 1.00 EVAL P DECOMP Hold Pre-Job Safety Meeting - Rig Up Schlumberger Wire Line Services And Make Up USIT Logging Tools 10:30 - 17:00 6.50 EVAL P DECOMP RIH With Schlumberger USIT Tools - Logging To 8,400' (WLM) POH - Do Repeat Of USIT Log To 6,500' (WLM) - POH With Logging Tools 17:00 - 17:30 0.50 EVAL P DECOMP Rig Down Schlumberger USIT Logging Tools And Clear Rig Floor 17:30 - 18:30 1.00 EVAL P DECOMP Cut 59 Feet 1 1/4" Drilling Line 18:30 - 19:00 0.50 EVAL P DECOMP Pick Up And Make Up Haliburton 95/8" RTTS Tool 19:00 - 20:00 1.00 EVAL P DECOMP Pick Up And Drift 21 Joints Of 5" HWDP And RIH 20:00 - 21 :15 1.25 EVAL P DECOMP RIH With 4" Drill Pipe From Mast To 4,000' 21 :15 - 22:00 0.75 EVAL P DECOMP Record Up And Down Weights - Break Circulation Thru Kill Line And Shut Upper Pipe Rams - Set 9 5/8" Haliburton RTTS Tool At 4,000' - Monitor Drill Pipe Returns And Pressure Up Down Back Side To 3,000 Psi. And Hold For 10 Minutes (Test Good) - Bleed Pressure To 0 Psi. Open Top Set Of Pipe Rams - Pick Up To Open RTTS By Pass And Relax Packer Elements 22:00 - 22:30 0.50 EVAL P DECOMP Monitor Well Bore (Static) - Pump Dry Job - Blow Down Can-Rig Top Drive And Surface Lines 22:30 - 23:30 1.00 EVAL P DECOMP POH With 4" Drill Pipe Standing Back In Mast From 4,000' To 660' 23:30 - 00:00 0.50 EVAL P DECOMP Change Elevators To Accept 5" HWDP - POH Stand Back 5" HWDP In Mast 11/21/2002 00:00 - 00:30 0.50 EVAL P DECOMP Lay Down Haliburton 9 5/8" RTTS Tool And Clear Rig Floor 00:30 - 02:00 1.50 FISH P DECOMP Pick Up Baker Packer Milling Assembly - RIH With 5" HWDP From Mast To 963' 02:00 - 03:00 1.00 FISH P DECOMP Change Elevators And Iron Ruffneck Jaws To Accept 4" Drill Pipe - Pick Up 42 Joints Of 4" Drill Pipe From Pipe Shed And RIH To 1,309' 03:00 - 05:00 2.00 FISH P DECOMP Continue To RIH With 4" Drill Pipe From Mast To 7401' 05:00 - 05:30 0.50 FISH P DECOMP Service Can-Rig Top Drive And Traveling Blocks 05:30 - 06:00 0.50 FISH P DECOMP Continue To RIH To 8,355' With 4" Drill Pipe - Connect Top Drive And Break Circulation 06:00 - 14:30 8.50 FISH P DECOMP Wash And Ream From 8,335' To 8,428' Top Of Packer - Mill 9 5/8" X 5 1/2" Baker SB-3 Packer - 5.8 BPM With 575 Psi. - Up Weight 21 OK, Down Weight 175K, Rotating Weight 190K, Torque 7K To 14K Printed: 12/6/2002 1 :57:59 PM ) ) PageS of 11 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-32 01-32A REENTER+COMPLETE NABORS DRILLING CO. NABORS Start: 11/16/2002 Rig Release: 11/30/2002 Rig Number: 2ES Spud Date: 11/16/1986 End: 11/30/2002 Date From~To Hours Task CÖdé NPT Phase Døscriptionof Operations 11/21/2002 14:30 - 15:00 0.50 FISH P DECaMP Shut Down Pumps With Packer Milled Up And Monitor Well Bore (Static) - Blow Down Top Drive And Surface Equipment- Push Packer From 8,432' To 8,720' 15:00 - 16:00 1.00 FISH P DECaMP Rotate And Push Packer From 8,720 To 8,779' - Pump Rate 6 BPM At 640 Psi. - 100 RPM Torque 7K To 14K - Monitor Returns See Increase In Flow Show (WELL FLOWING) Shut In Well At 8,771' 16:00 - 18:30 2.50 KILL P DECaMP Record Shut In Pressures - SlOP At 20 Psi. And SICP At 180 Psi. - Circulate Out Gas Bubble Thru Super Choke And Poor Boy Degasser At 3 BPM With 240 Psi. 18:30 - 20:00 1.50 FISH P DECaMP Shut Down Mud Pumps And Shut In Choke Verify That Gas Bubble Circulated Out - Open Choke And Kill Line - Clear Rig Floor And Open Top Set Rams - Monitor Well Minimual Amounts Of Gas Breaking Out At Surface - Circulate 1 1/2 Bottoms Up At 8 BPM 1050 Psi. - Monitor Well (Static) - Attempt To Push Packer Further Down Hole (No Good) Top Of Packer At 8,779' 20:00 - 20:30 0.50 FISH P DECaMP Spot 20 Barrel 17 PPG Weighted Pill At 8,779' - Pump Dry Job - Blow Down Top Drive And Surface Equipment 20:30 - 00:00 3.50 FISH P DECaMP Drop 2.375 Rabbit - POH (SLM) With 4" Drill Pipe Standing Back In Mast From 8,779' To 964' - Change Elevators And Equipment To Accept 5" Drill Pipe *NOTE* Steel Line Measurement 6.81 Long ( May Account For Fish Depths 7' High) 11/22/2002 00:00 - 03:00 3.00 FISH P DECaMP Continue To POH From 964' - Lay Down (21) Joints Of 5" HWDP, (9) 6 1/2" Drill Collars, Oil Jars, Bumper Sub, (3) Junk Baskets, And Packer Mill - Clean Junk Out Of Boot Baskets And Clear Rig Floor 03:00 - 05:00 2.00 BOPSUR P LNR1 Pull Wear Ring And Install Test Plug -Change Rams In Top BOP Gate To 7" And Test To 3,500 Psi. - Rig Down Test Equipment And Install Wear Bushing 05:00 - 07:30 2.50 CASE P LNR1 Rig Up 7" Casing Tools And Equipment 07:30 - 11 :00 3.50 CASE P LNR1 Run 7" Casing Per Well Program - Pick Up Shoe Track And Verify Floats Holding - Continue To Pick Up And RIH With 53 Joints 7" BTC-M 26 lb. L-80 Casing To 2,177' 11 :00 - 12:00 1.00 CASE P LNR1 Rig Up Single Joint Compensator For Chrome Casing 12:00 - 19:00 7.00 CASE P LNR1 Continue To Pick Up And RIH With 12 Joints 7" 26 lb. NT13CR80 NSCC Casing And 54 Joints Of 7" 26 lb. 13CR80 VAM TOP Casing - Change Out Elevators To Accept 5" Drill Pipe - Pick Up Baker Packer Assembly - Verify 7" Liner Wiper Plug Attached - Make Up Baker 7" X 9 5/8" Flex Lock Liner Hanger And 7" X 95/8" ZXP Liner Top Packer 19:00 - 20:00 1.00 CASE P LNR1 Rig Down Casing Tools And Equipment - Clear Rig Floor- Install Can-Rig Top Drive Saver Sub 20:00 - 21 :30 1.50 CASE P LNR1 Install Cross Over To Baker Running Tool - Change Elevators And Equipment To Accept 4" Drill Pipe - RIH With (1) Stand Of 4" Drill Pipe From Mast - Connect Top Drive And Break Circulation - Circulate Liner Volume At 6 BPM With 235 Psi. - When Full Of 9.4 PPG Mud Liner Up Weight At 138K And Down Weight At 120K - Blow Down Top Drive And Surface Lines 21 :30 - 00:00 2.50 CASE P LNR1 RIH With 7" Liner And Hanger Assembly On 4" Drill Pipe To Printed: 12/6/2002 1:57:59 PM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 01-32 01-32A REENTER+COMPLETE NABORS DRILLING CO. NABORS From-'-To Hours TaSk Code NPT Phase 11/22/2002 21 :30 - 00:00 11/23/2002 00:00 - 00:30 00:30 - 02:45 02:45 - 04:00 04:00 - 04:30 04:30 - 04:45 04:45 - 05:30 05:30 - 06:00 06:00 - 08:30 08:30 - 09:00 09:00 - 12:30 12:30 - 13:30 13:30 - 14:00 14:00 - 14:30 14:30 - 15:30 15:30 - 16:00 2.50 CASE P 0.50 CASE P 2.25 CASE P 1.25 CEMT P 0.50 CEMT P 0.25 CASE P 0.75 CASE P 0.50 CASE P 2.50 CASE P 0.50 CASE P 3.50 CASE P 1.00 CASE P 0.50 CASE P 0.50 CASE P 1.00 CASE P 0.50 CASE P LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 Start: 11/16/2002 Rig Release: 11/30/2002 Rig Number: 2ES Spud Date: 11/16/1986 End: 11/30/2002 De~Cri ptiOh. of Operations 8,764' - Monitor Returns And Fill Drill Pipe Every Ten Stands Pick Up Baker Plug Droping Head - Install Cement Manifold And Circulating Lines - Connect Top Drive And Torque Connections - Break Circulation And Lower 7" Liner In Hole Tag Up On Milled Packer At 8,779' Circulate And Condition Mud For Cement Job - Stage Up Pump Rate To 8 BPM With 960 Psi. With No Losses Shut Down And Turn Over To Dowell - Pump 5 BBL Fresh Water - Pressure Test Surface Equipment At 4,000 Psi. (Test Good) - Reciprocate Liner - Pump 5 Fresh Water - 10 BBLS 11.5 PPG Mud Push XL Spacer - 154 BBLS 15.8 PPG Class "G" Cement Slurry - Shut In Plug Droping Head And Flush Cement Lines Drop Drill Pipe Wiper Dart And Displace With 9.4 PPG LSND Mud At 8 BPM With Rig Pumps - Slow Rate And Did "NOT" Observe Latch Up Of Liner Wiper Plug - Continue To Displace Did "NOT" Bump Plug With 226 BBLS Away - Cement In Place At 04:32 Hours Set 7" Liner On Bottom - Bleed Pressure To 0 Psi. And Check Floats (OK) - Rotate 15 Turns The Right And Pick Up On Liner 8 Feet Liner Did "NOT" Release - Set Back On Bottom And Put 12 Turns To The Right - Pick Up On Liner And Liner Released - Observe Pressure Drop Kick In Both Mud Pumps And Pump At 8 BPM - Set Down All String Weight And Attempt Set ZXP Packer - Only Able To Set Down 50K Appears That Packer Not Set NOTE - Top Of 7" Liner Tie Back At 3,884' Top Of 7" Landing Collar At 8,692' Bottom Of 7" Float Shoe At 8,779' Circulate 1.5 Times Annular Volume At 3,884' (35 BBL Contaiminated Mud And Cement Back To Surface) Pump Dry Job - Rig Down Cement Head And Circulating Lines - Blow Down Surface Equipment -Lay Down (2) Joints Of 4" Drill Pipe POH With 4" Drill Pipe Standing Back In Mast - Lay Down Baker Liner Running Tool Service Can-Rig Top Drive And Traveling Blocks Pick Up BHA NO.3 - 6 1/2" Drill Collars - 5" HWDP - 4 3/4" Drill Collars - 31/2" HWDP With Dummy Seal Assembly And Rotating Dog Sub To Weight Set 7" ZXP Packer Change Out Elevators And Iron Ruffneck Equipment To Accept 4" Drill Pipe - Continue To RIH To 3,884' - Up Weight At 130K And Down Weight At 125K - Connect Top Drive And Break Circulation - Sting Into 7" Liner Tie Back Sleeve Set Down On ZXP Packer With 50K To Set - Very Good Surface Indication Of Packer Setting - Test Back Side To 3,000 Psi. For 15 Minutes (Test Good) Pump Dry Job - Blow Down Top Drive And Surface Lines POH With 4" Drill Pipe Standing Back In Mast From 3,884' To 1,821' POHWith 31/2" HWDP And 4 3/4" Drill Collars Standing Back In Mast From 1,821' To 992' Printed: 12/6/2002 1 :57:59 PM ') ) Bp.EXPtORATION Qp~r~tiØn~<$l.Jrnrnary ..R,pØrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-32 01-32A REENTER+COMPLETE NABORS DRILLING CO. NABORS Start: 11/16/2002 Rig Release: 11/30/2002 Rig Number: 2ES Spud Date: 11/16/1986 End: 11/30/2002 Date FrOIT1-" To Hours Task Code NPT [)éscri ptiOnof (:>perations 11/23/2002 16:00 - 17:30 1.50 CASE P 17:30 - 18:30 1.00 EVAL P 18:30 - 20:00 1.50 EVAL P LNR1 WEXIT WEXIT 20:00 - 23:00 3.00 EVAL P WEXIT 23:00 - 00:00 1.00 EVAL P WEXIT 11/24/2002 00:00 - 01 :30 1.50 DRILL P WEXIT 01 :30 - 03:00 1.50 DRILL P WEXIT 03:00 - 04:00 1.00 EVAL P WEXIT 04:00 - 04:30 0.50 DRILL P WEXIT 04:30 - 07:00 2.50 DRILL P WEXIT 07:00 - 08:30 1.50 DRILL P WEXIT 08:30 - 09:00 0.50 DRILL P WEXIT 09:00 - 10:00 1.00 DRILL P WEXIT 10:00 - 12:30 2.50 DRILL P WEXIT 12:30 - 13:00 0.50 DRILL P WEXIT 13:00 - 13:30 0.50 DRILL P WEXIT POH Laying Down 5" HWDP And 6 1/4" Drill Collars - Lay Down Baker Dummy Seal Assembly And Rotating Dog Sub Clear Rig Floor Of Excess Cross Overs Etc. - Bring BHA To Rig Floor No.4 To Rig Floor And Prepare To Pick Up Pick Up And Make Up BHA No.4 And RIH To 380' - Surface Check MWD Tool At 320 GPM With 1,340 Psi. - Continue To Pick Up BHA To 862' - Change Out Elevators And Equipment For 4" Drill Pipe RIH With 4" Drill Pipe From Mast From 862' To 3,884' (Top Of Liner) - Connect Top Drive And Break Circulation Travel Thru Liner Top Tie Back Sleeve With No Cement Or Problems- Disconnect Top Drive And Blow Down - Continue To RIH With 4" Drill Pipe To 8,612' - Break Circulation And Record Up Weight At 175K Down Weight At 150K Logging With Sperry Sun Tools From 8,612' To 8,631' At 100 Feet Per Hour - Tag Liner Wiper Plug And Cement At 8,631' *Note* 61 Feet High From Landing Collar Drill Liner Wiper Plug And Cement While Logging With Sperry Sun From 8.,631' To 8,650' Displace 9.4 PPG LSND Mud To 8.5 PPG Flo Pro Mud System At 8 BPM With 3100 Psi. While Rotating And Reciprocating String Break Circulation Thru Kill Line - Shut In Annular - Pressure Test Casing To 3,000 Psi. For 30 Minutes (Test Good) - Bleed Off Pressure to 0 Psi. And Open Annular - Clean Possom Belly And Shaker Under Flow Area During Testing Operation Pump Dry Job - Blow Down Can-Rig Top Drive And Surface Lines POH With 4" Drill Pipe Standing Back In Mast From 8,650' To 863' - Test Choke Manifold On Trip Out Of The Hole At 250 Psi. Low And 3,500 Psi. High Stand Back BHA Assembly No.4 - Break Off Bit And Clear Rig Floor - Remove Wear Bushing And Set Test Plug - Rig Up BOP Testing Equipment Change Ram Blocks In Top Gate Remove 7" And Install 3 1/2" X 6" Variables *NOTE* During This Phase Of Operation Bridge Crane Hook Caught HCR Valve Fitting And Broke Fitting Which Resulted In 5 Gallon Hydraulic Oil Spill - All Oil Was Contained In Duck. Pond Around Well Head "NONE" Got On Pad - See LCIR No. 2002-1 R-374432 Fill BOP With Water - Test BOP And Related Equipment - Witness Of BOP Test Waived By AOGCC Inspector John Spaulding - Test Annular, Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Lines, Floor Safety Valve, Dart Valve, Top Drive Upper And Lower IBOP Valves At 250 Psi. Low And 3,500 Psi. High - Test Pit PVT System And Perform Accumulator Test Rig Down Testing Equipment - Pull Test Plug - Set Wear Bushing And Energize Lock Down Studs Blow Down Surface Lines And Equipment Related To Testing Printed: 12/6/2002 1 :57:59 PM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-32 01-32A REENTER+COMPLETE NABORS DRILLING CO. NABORS Date Start: 11/16/2002 Rig Release: 11/30/2002 Rig Number: 2ES Spud Date: 11/16/1986 End: 11/30/2002 From""To Hours Task COde NPT Descri ptionofQþerations 0.50 DRILL P WEXIT 11/24/2002 13:00 -13:30 13:30 - 15:30 2.00 STWHIP P WEXIT 15:30 - 20:00 4.50 STWHIP P WEXIT 20:00 - 20:30 0.50 STWHIP P WEXIT 20:30 - 00:00 3.50 STWHIP P WEXIT 11/25/2002 00:00 - 03:15 3.25 STWHIP P WEXIT 03:15 - 04:30 04:30 - 05:00 1.25 STWHIP P 0.50 EVAL P WEXIT WEXIT 05:00 - 05:30 0.50 STWHIP P WEXIT 05:30 - 08:00 2.50 STWHIP P WEXIT 08:00 - 09:00 1.00 STWHIP P WEXIT 09:00 - 10:00 1.00 STWHIP P WEXIT 10:00 - 10:30 0.50 DRILL P PROD1 10:30 - 13:30 3.00 DRILL P PROD1 Operation - Clear Rig Floor - Prepare To Pick Up Whipstock Assembly Pick Up Bottom Trip 7" Whip Stock - Make Up Starter Mills And Single Of 31/2" HWDP - Pick Up MWD Tool And Orient Same - RIH With Bumper Sub And (9) 4 3/4" Drill Collars - RIH With (1) Stand Of 31/2" HWDP - Surface Test MWD Tool- Blow Down Top Drive - And Continue To RIH With HWDP To 937' RIH With 4" Drill Pipe From Mast - Travel Very Slow Thru 7" Liner To 8,592' Connect Top Drive And Break Circulation - Orient Whip Stock Slide To (8) Degrees Left Of High Side And Record Up Weight At 165K And Down Weight At 160K - Lower Whip Stock From 8,592' To 8,650' (PBTD) And Trip Bottom Anchor With 15K Down Weight - Pick Up To 170K Verify Anchor Set - Slack Back Down And Shear Bolt With 28K Additional Down Weight - Pick Up Mill To Top Of Slide And Record Slow Pump Rates Mill Casing 7" 26 Ib And 9 5/8" 47 lb. Top Of Window At 8,626' And Bottom Of Window Upon Completion At 8,639' *NOTE* Top Of Window 7 Feet Below Top Of Sag River Formation Mill Casing 7" 26 Ib And 95/8" 47 lb. Top Of Window At 8,626' And Bottom Of Window Upon Completion At 8,639' - Continue To Drill Formation To 8,651' To Get Portion Of Upper Mill Out Of Window - Recovered 80 Ibs. Metal From Milling Operation Pump Sweep Around And Condition Mud At 8,651' Pull Millln7" Casing At 8,624' - Closed Pipe Annular And Performed FIT Strokes Pmp'd 9 18 27 33 Pressure 248 psi 552 psi 815 psi 1114 psi Held Test F/10 minutes w/ 25 Psi. Pressure Loss. MW 8.5 PPG Window Top At TVD 8,561' Pressure psi = 11.0 PPG EMW. Bleed Pressure To 0 Psi. - Opened Annular Monitor Well Bore (Static) - Pump Dry Job - Blow Down Top Drive And Surface Lines POH With Milling Assembly From 8,624' To 937' - Standing Back 4" Drill Pipe In Mast Stand Back 31/2" HWDP In Mast - Lay Down Window Milling Assembly Pick Up Johnny Wacker Tool And Flush BOP Stack - Function Rams Reflush And Lay Down Tool Service Can-Rig Top Drive, Traveling Blocks, And Crown Sheaves Pick Up 61/8" Drilling Assembly - Pick Up Sperry Sun Mud Motor, Float Sub, MWD Tool And Orient - Make Up Bit And RIH - Pick Up (3) Flex Collars, Circulating Sub, And Drilling Jars - Surface Test MWD Tool And Blow Down Surface Equipment - Continue To RIH With 31/2" HWDP From Mast Printed: 12/6/2002 1:57:59 PM ) ) Legal Well Name: 01-32 Common Well Name: 01-32A Spud Date: 11/16/1986 Event Name: REENTER+COMPLETE Start: 11/16/2002 End: 11/30/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 11/30/2002 Rig Name: NABORS Rig Number: 2ES Hours Task Cbde NPT 11/25/2002 10:30 - 13:30 3.00 DRILL P PROD1 To 726' - Change Out Elevators And Equipment To Accept 4" Drill Pipe 13:30 - 16:30 3.00 DRILL P PROD1 RIH With 4" Drill Pipe From Mast From 726' To 8,569' - Fill Drill String At 3,440' And 6,325' During Trip In Hole 16:30 - 17:00 0.50 DRILL P PROD1 Remove Top Drive Blower Hose And Prepare To Change Out 17:00 - 18:00 1.00 DRILL P PROD1 Orient Mud Motor And Bit 14 Degrees Right Of High Side- Shut Down Mud Pumps - Slide Thru Window From 8,626' To 8,639' - Tag Under Gage Hole At 8,644' - Wash Down To Bottom From 8,644' To 8,651 18:00 - 00:00 6.00 DRILL P PROD1 Obtain Slow Pump Rates - Directional Drill Ahead From 8,651' To 8,741' - Weight On Bit 7K To 20K - With Pump Rate At 122 Strokes Or 300 GPM - Off Bottom Pump Pressure At 1760 Psi. & On Bottom Pump Pressure At 1911 Psi. - Top Drive RPM At 0 To 80 - Off Bottom Torque At 5K & On Bottom Torque At 8K - String Rotating Weight At 157K - With Pump Off Drag Up At 165K And Drag Down At 150K 11/26/2002 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill w/1.5 degree motor and survey w/ ABI-Dir-GR-Res from 8,741' To 9,465'. AST- 11.85 hrs, ART- 6.15 hrs. Oriented Depth Inc. Azi. TF. Rap. 8,721' - 8,771' 38.86 340.28 15R 62 8,805' - 8,849' 48.38 345.94 HS 38 8,869' - 8,908' 54.27 346.99 HS 38 8,908' - 8,930' 57.37 346.58 HS 55 9.035' - 9,060' 61.07 350.65 20R 38 9,060' - 9,087' 64.22 352.49 20R 55 9,128' - 9,154' 67.76 351.68 20R 65 9,218' - 9,222' 67.74 352.40 90R 45 9,222' - 9,250' 66.78 356.81 90R 45 9,250' - 9,255' 66.42 1.24 90R 45 9,265' - 9,284' 66.42 1.24 90R 45 9,284' - 9,300' 66.27 4.83 90R 45 9,312' - 9,343' 66.62 9.27 80R 45 9,343' - 9,347' 66.70 13.46 80R 20 9,373' - 9,379' 77.00 14.00 30R 65 Lithologies encountered: 8,950' - 9,030' Lower zone 4. Pred. clean fine to med gr sand with minor shale stringers. 9,030' - 9,160' Zone 3 (CongL). Pred. disaggregated fine to med. gr sand with abdt. chert pebble clasts. 9,360' - 9,390' 25N shale. Lt. tan siltstone, very hard, conglomeratic. Slow Rap, -10 fph sliding, 25 fph rotating. 9,390' - 9,425' 25P sand. Fine to cse gr sand, poorly sorted, locally silty, common chert clasts. 9,425' - 9,440' 24N shale. Pred. hd, sandy siltstone. 20 - 30 fph rotating. 11/27/2002 00:00 - 16:30 16.50 DRILL P PROD1 Drill with 1.5 deg motor, survey with MWD-ABI-GR-RES from 9,465' to 10040' at 7 BPM, 300 GPM, 2200-2400 psi, RPM 80-100, Torque 3,000-5,000 FT*LBS, WOB 10-20K, PU WT Printed: 12/6/2002 1:57:59 PM ") ) BP EXPLORATION Qperéltion~ ..S\.ImlTlélrY .~epQrt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-32 01-32A REENTER+COMPLETE NABORS DRILLING CO. NABORS Page 10 of 11 Start: 11/16/2002 Rig Release: 11/30/2002 Rig Number: 2ES Spud Date: 11/16/1986 End: 11/30/2002 Däte From-To HoUrs Task Code NPT 11/27/2002 00:00 - 16:30 16.50 DRILL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 20:00 1.00 DRILL P PROD1 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 21 :30 1.00 DRILL P PROD1 21 :30 - 23:30 2.00 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 11/28/2002 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 06:00 3.00 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 07:30 1.00 CASE P COMP 07:30 - 08:00 0.50 CASE P COMP 08:00 - 10:00 2.00 CASE P COMP 10:00 - 10:30 0.50 CASE P COMP 10:30-11:00 0.50 CASE P COMP 11 :00 - 15:00 4.00 CASE P COMP 15:00 - 15:30 0.50 CASE P COMP 15:30 - 16:30 1.00 CASE P COMP 16:30 - 17:00 0.50 CASE P COMP 17:00 - 19:00 2.00 CASE P COMP 19:00 - 20:00 1.00 CEMT P COMP 20:00 - 21 :00 1.00 CASE P COMP 180K SO WT 150K, Rot WT 160K. AST=4.5, ART=8.8. Oriented depths TF ROP 9450' - 9476' HS 22 9476' - 9487' HS 52 9503' - 9530' HS 52 9542' - 9575' 10R 33-52 9729' - 9,747' .20R 50-70 9781' - 9797' LS 66 9876' - 9890' LS 66 Circulate high vis sweep at 7 bpm, 2,150 psi. Rotate and reciprocate. POH from 10,040' to 8,565'. Take surveys for JORPS at 8,910' and 8,880'. Tight spots at 9,901',20 K over, and 9,394', 25K over. Slip and cut drilling line. Service top drive. RIH to 10,040'. Circulate high vis sweep at 7 bpm, 2,100 psi. Spot 50 bblliner running pill. POH from 10,040' to 9,222'. Hole in good condition. POH from 9,222'. Drop circulating sub dart at 8 stands out. Pull into casing. Open circulating sub. Sub sheared at 3,140 psi. Pump dry job. POH to 4,056' bit depth. Circulating sub at 3,884'. CBU at 10 bpm with sub at 7" x 9 5/8" liner top. POH. LD HWDP and BHA. Down load MWD. Clear rig floor. RU to run 4 1/2" liner. RU torque turn equipment. MU float equipment and check floats. Run 4.5",12.6 #, 13Cr-80, VAM ACE liner. Change out handling equipment. PU Baker HMC liner hanger and ZXP packer assembly. PU one stand of DP and RIH. Circulate one liner volume at 5 bpm, 110 psi. PU=45K, SO=45K. RIH from 1,678' to 8,585' filling pipe every 10 stands. Circulate one DP and liner volume at 5 bpm, 590 psi. PU=155K, SO=148K. RIH from 8,585' to 10,019'. Hole in good condition. PU cement head. Wash down and tag at 10,040'. PU=165K, SO=152K. Stage pumps up to 6 bpm, 1,065 psi. Reciprocate pipe. Hold PJSM. Pump 5 bbls CW-100. Test cement lines to 4,000 psi. Pump 10 bbls CW-100, 30 bbls 10.0 ppg mud push spacer, 43 bbls 15.8 ppg class G latex cement. Drop DP wiper plug. Displace with 40 bbl perf pill followed by 67 bbls of flo-pro mud with cement unit. Bump plug and pressure up to 3,500 psi to set liner hanger. CIP 19:47. Bleed off pressure and check floats, ok. Rotate 20 turns to release from liner. Pressure up to 1,000 psi. Pick up enough to circulate and circulate out excess cement at 11 bpm. Circulated approximately 15 bbls of cement off the top of the liner. Slow pump to 3.5 bpm and pick up to expose Printed: 12/6/2002 1: 57: 59 PM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-32 01-32A REENTER+COMPLETE NABORS DRILLING CO. NABORS Daté From.~ To Hours Task Code NPT Phasé 11/28/2002 20:00 - 21 :00 1.00 CASE P COMP 21 :00 - 22:30 1.50 CASE P COMP 22:30 - 23:00 0.50 CASE P COMP 23:00 - 00:00 1.00 CASE P COMP 11/29/2002 00:00 - 05:30 5.50 CASE P COMP 05:30 - 06:00 0.50 CASE P COMP 06:00 - 06:30 0.50 WHSUR P COMP 06:30 - 08:30 2.00 RUNCONP COMP 08:30 - 09:00 0.50 CASE P COMP 09:00 - 20:30 11.50 RUNCONP COMP 20:30 - 21 :00 0.50 RUNCONP COMP 21 :00 - 21 :30 0.50 RUNCONP COMP 21 :30 - 22:00 0.50 RUNCONP COMP 22:00 - 00:00 2.00 RUNCONP COMP 11/30/2002 00:00 - 01 :30 1.50 RUNCONP CaMP 01 :30 - 02:00 0.50 RUNCONP CaMP 02:00 - 03:30 1.50 RUNCONP CaMP 03:30 - 04:00 04:00 - 05:30 05:30 - 07:30 07:30 - 08:30 08:30 - 11 :00 0.50 RUNCONP 1.50 WHSUR P 2.00 WHSUR P 1.00 WHSUR P 2.50 WHSUR P COMP COMP CaMP COMP COMP 11 :00 - 13:00 2.00 WHSUR P COMP Start: 11/16/2002 Rig Release: 11/30/2002 Rig Number: 2ES Spud Date: 11/16/1986 End: 11/30/2002 packer setting lugs. Slack off 70 K to set liner top packer. Good indication of packer set. Set down 60 K and rotate to confirm packer set. Top of liner tie back at 8,465'. Float shoe at 10,040'. Displace well to seawater at 8 bpm, 1,200 psi. Pump dry job. POH to 8,465'. LD cement head and surface equipment. POH and LD DP from 8,465' to 7,013'. POH and LD DP from 7,013' to 1,800', RIH to 3,296' with DP from derrick and LD same. LD liner running tool. Pull wear bushing. RU torque turn and tubing running equipment. Test casing to 3,000 psi for 30 minutes. Run 4.5",12.6#, 13Cr-80, Vam Ace, gas lift completion. Tag inside liner tie back. Space out tubing. WLEG will be stung into tie back recepticle 4'. Change handling equipment. Land tubing. RILDS. Reverse circulate annulus volume of clean seawater at 3 bpm. Reverse circulate clean seawater with corrosion inhibitor. Drop ball/rod to land on top of RHC-M Plug in X nipple at 8459'. RD DP landing joint. Pressure up to 4,000 psi and set packer at 8436'. Test tubing to 4,000 psi for 30 minutes. Bleed tubing pressure to 1,500 psi. Test inner annulus to 3,000 psi for 30 minutes. Bleed tubing pressure and shear DCK valve at 3574'. RD hoses. Set TWC. NO BOP. NU Tree and adpater, test to 5000 psi, ok Pull TWC w/ Lubricator RU Hot Oil, Test lines, Freeze Protect well wI 150 bbls diesel down backside at 2.5 bpm, 900 psi, u-tube back to tbg wI 33 bbls, 2200', leaving 117 bbls , 2200' of diesel freeze protect in annulus Install BPV, Test to 3000 psi, RD lines, remove secondary annulus valve, secured tree, RELEASED RIG at 1300 Hours on 11/30/2002 Printed: 12/6/2002 1 :57:59 PM -') ') Well: Field: API: Permit: Date 01-32A Prudhoe Bay Unit 50-029-21622-01 202-185 Accept: Spud: Release: Rig: 11/16/02 11/25/02 11 /30/02 Nabors 2ES POST RIG WORK 12107/02 PULL BALL & ROD. PULLED DCKV-BEK GLV FROM STA. # 4 & DGLV FROM STA. # 3. SET GENERIC LGLV IN STA. # 4. SET GENERIC SIO GLV IN STA. # 3. PULL RHC PLUG BODY. 12108/02 DRIFTED WI 3.54" CENT, & 3-3/8" DG TO 8896' SLM (STOPPED DUE TO DEVIATION). LEFT WELL SHUT IN. 12117/02 DRIFT/MCNUPERF. RIH WITH 33/8" DUMMY GUN TO 9947'CTM. TAG AND POOH 12118/02 MU SWS MCNL LOGGING TOOLS, RIH TO-9955' CTM. TAG AND MAKE 3 LOGGING PASSES UP AT 30 FPM FROM TD TO 8350' CTM. ON LAST PASS UP STOP AND FLAG PIPE AT 9800' CTMD. CONTINUE LOGGING UP TO 8350', THEN POOH. PU 25' GUN. RIH, CORRECT AT FLAG. TAG PBTD AT 9960'. PU AND SHOOT 9928' TO 9953' 6 SPF. POH. MU AND RIH WITH MEMORY GRICCL. 12119/02 LOG TIE IN MEMORY GRICCL FROM 9600 TO 8550. FLAG PIPE AT 9600. POH. RIH WITH GUN #2 (25'). PERFORATE 9875' TO 9900' W/3-318" GUN 6 SPF. REPAINT FLAG. POH. RIH WITH GUN #3 (25'). PERFORATE 9825' TO 9850' WI 33/8" GUN 6 SPF. REPAINT FLAG. POH. RIH WITH GUN #4 (25') PERFORATE 9750-9775. POH. ALL SHOTS FIRED. MU NEW MHA. 12120/02 MU AND RIH WITH MEMORY GRICCL TOOLS. LOG 9500 TO 8700 AT 30 FPM. POH. NEW FLAG @ 9500'. CORRECT COIL DEPTHS TO CORRECTED LOG AND PERFORATE 9610'- 9660' IN TWO RUNS WI 25' X 3 3/8" GUNS LOADED: 6 SPF, RAND ORIENT, 60 DEG PHASE, PJ3406 CHARGES. AT SURFACE WI ALL SHOTS FIRED. FREEZE PROTECT TO 2100'. BLOW DOWN COIL WI N2 FOR REEL SWAP. TURN WELL BACK TO PAD OPER TO BOL. ') Õ<Od-'/?S 08-Dec-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 01-32A Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 8,597.70' MD Window / Kickoff Survey 8,626.00' MD (if applicable) Projected Survey: 10,040.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 01 01-32 - 1-32A' )EF' ~T'VE Job No. AKZZ22186, Surveyed: 27 November, 2002 Survey Report 6 December, 2002 Your Ref: API 500292162201 Surface Coordinates: 5940536.50 N, 697999.50 E (70014' 29.9861" N, 148024' 02.9232" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 - Surface Coordinates relative to Project H Reference: 940536.50 N, 197999.50 E (Grid) Surface Coordinates relative to Structure Reference: 1414.01 S, 722.52 E (True) Kelly Bushing: 67.70ft above Mean Sea Level Elevation relative to Project V Reference: 67. 70ft Elevation relative to Structure Reference: 67. 70ft speI'I'Y-su" t)RILLING SEæAVICEæS A Halliburton Company Survey Ref: svy11384 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 01 - 01-32 - 1-32A Your Ref: AP/500292162201 Job No. AK1122186, Surveyed: 27 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/1 OOft) 8597.70 17.020 325.700 8466.50 8534.20 320.74 N 467.64 W 5940844.84 N 697523.60 E 287.08 Tie On Point AK-6 BP _IFR-AK -. 8626.00 17,740 328.300 8493.51 856121 ... 327.83 N 472.24 W 5940851.81 N 697518.82 E 3.741 293.83 Window Point 8721.28 31.270 341 .180 8580.06 8647.76 363.78 N 487.92 W 5940887.33 N 697502.19 E 15.189 328.59 8816.38 41.630 344.000 8656.46 8724.16 417.65 N 504.64 W 5940940.75 N 697484.06 E 11.033 381.16 8846.56 46.100 346.150 8678.21 8745.91 437.86 N 510.01 W 5940960.81 N 697478.17 E 15.610 400.93 8876.49 48.380 346.130 8698.53 8766.23 459.19 N 515.27 W 5940982.00 N 697472.34 E 7.618 421.84 8907,79 54.270 346.590 8718.08 8785.78 482.93 N 521.03 W 5941005.58 N 697465.97 E 18.853 445.12 8936.04 57,370 346.370 8733.95 8801.65 505.65 N 526.49 W 5941028.15 N 697459.91 E 10.992 467.40 8969.69 57.450 346.780 8752.08 8819.78 533.23 N 533.08 W 5941055.54 N 697452.60 E 1.054 494.44 8999.54 57.180 346.250 8768.20 8835.90 557.66 N 538.93 W 5941079.81 N 697446.10 E 1.747 518.40 9029.50 57.290 345.990 8784.41 8852.11 582.11 N 544.98 W 5941104.10 N 697439.42 E 0.817 542.37 9060.01 61.070 349.940 8800.05 8867.75 607.73 N 550.42 W 5941129.56 N 697433.31 E 16.644 567.55 9094.40 64.220 351.820 8815.85 8883.55 637.88 N 555.25 W 5941159.58 N 697427.68 E 10.366 597.28 9125,13 64.420 351.330 8829.16 8896.86 665.28 N 559.31 W 5941186.86 N 697422.91 E 1.578 624.33 9156.43 67.760 352.470 8841.85 8909.55 693.60 N 563.34 W 5941215.07 N 697418.14 E 11.178 652.30 9190.56 67.940 351,260 8854.72 8922.42 724.90 N 567.81 W 5941246.23 N 697412.84 E 3.326 683.20 9221,68 67.740 352.260 8866.46 8934.16 753.42 N 571.94 W 5941274.64 N 697407.96 E 3.045 711.36 9250.48 66.780 356.790 8877.59 8945.29 779.85 N 574.48 W 5941300.99 N 697404.73 E 14.884 737.55 9283.76 66.420 1.505 8890.82 8958.52 810.38 N 574.94 W 5941331.50 N 697403.48 E 13.047 767.97 9315.20 66.270 4,190 8903.43 8971.13 839.14 N 573.51 W 5941360.28 N 697404.15 E 7.837 796.76 9343.27 66.620 8.760 8914.66 8982.36 864.70 N 570.60 W 5941385.91 N 697406.38 E 14.975 822.46 9373.35 66.700 11.420 8926.57 8994.27 891.88 N 565.77 W 5941413.22 N 697410.50 E 8.124 849.92 9404.78 69.280 13.600 8938.35 9006.05 920.33 N 559.45 W 5941441.81 N 697416.07 E 10.427 878.73 - 9437.52 71.730 13.740 8949.28 9016.98 950.31 N 552.16 W 5941471.98 N 697422.57 E 7.494 909.16 9476,26 76.270 15.530 8959.95 9027.65 986.33 N 542.74 W 5941508.23 N 697431.04 E 12.532 945.75 9498,85 77.850 15,350 8965.01 9032.71 1007.55 N 536.88 W 5941529.60 N 697436.34 E 7.037 967.33 9530.75 80.920 17,070 8970.89 9038.59 1037.65 N 528.13 W 5941559.92 N 697444.30 E 10.986 997.97 9559.95 85.000 17.4 70 8974.47 9042.17 1065.32 N 519.53 W 5941587.81 N 697452.17 E 14.039 1026.18 9624.22 86,930 17,650 8978.99 9046.69 1126.44 N 500.19 W 5941649.41 N 697469.90 E 3.016 1088.50 9715.66 87,910 17.460 8983.11 9050.81 1213.53 N 472.63 W 5941737.20 N 697495.15 E 1.092 1177.32 6 December, 2002 ~ 13:37 Page 20f4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 01 - 01-32 - 1.32A Your Ref: API 500292162201 Job No. AKZZ22186, Surveyed: 27 November, 2002 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9808.82 88.030 16.510 8986.41 9054.11 1302.57 N 445.44 W 5941826.92 N 697520.00 E 9902.85 85.880 14.530 8991.40 9059.10 1393.04 N 420.31 W 5941918.02 N 697542.74 E 9972.95 85.880 14.610 8996.44 9064.14 1460.71 N 402.73 W 5941986.12 N 697558.55 E 10040.00 85.880 14.610 9001.25 9068.95 1525.42 N 385.86 W 5942051.26 N 697573.71 E '- All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 4.030° (True). Magnetic Declination at Surface is 26.154°{25-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 10040.00ft., The Bottom Hole Displacement is 1573.47ft., in the Direction of 345.805° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8597.70 8626.00 10040.00 320.74 N 327.83 N 1525.42 N Tie On Point Window Point Projected Survey 467.64 W 472.24 W 385.86 W 8534.20 8561.21 9068.95 6 December, 2002 - 13:37 Page 3 0'4 BPXA Dogleg Rate (0/100ft) 1.027 1268.05 3.106 1360.05 0.114 1428.79 0.000 1494.53 Projected Survey Vertical Section Comment --.' DrillQl1est 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA OS 01 - 01-32 - 1-32A Your Ref: AP/500292162201 Job No. AKZZ22186, Surveyed: 27 November, 2002 BPXA North Slope Alaska Survey too/prOgram for 01-32 - 1-32A From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 8597.70 0.00 8597.70 8534.20 10040.00 8534.20 Good Gyro{01-32) 9068.95 AK-6 BP _IFR-AK{1-32A) -~? 6 December, 2002 - 13:37 Page 4 0'4 DrillQuest 3.03.02.004 ') ) 08-Dec-02 AOGCC Lisa Weepie 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 01-32A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: 8,597.70' MD Window / Kickoff Survey 8,626.00' MD (if applicable) Projected Survey: 10,040.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager '. CEIVED DEC 13 2002 Alaska o¡.¡ & Gas Cons. CommiSSion Anchorage Attachment(s) c9C8~ I~ 5 Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 01 01-32 - 1-32A MWD --" Job No. AKMW22186, Surveyed: 27 November, 2002 Survey Report 6 December, 2002 Your Ref: API 500292162201 Suñace Coordinates: 5940536.50 N, 697999.50 E (70014' 29.9861" N, 148024'02.9232" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 '--- Suñace Coordinates relative to Project H Reference: 940536.50 N, 197999.50 E (Grid) Suñace Coordinates relative to Structure Reference: 1414.01 S, 722.52 E (True) Kelly Bushing: 67. 70ft above Mean Sea Level Elevation relative to Project V Reference: 67.70ft Elevation relative to Structure Reference: 67. 70ft speI'I'Y-SUf1 DRILLING SSAVIC:SS A Halliburton Company Survey Ref: svy11385 Sperry-Sun Drilling Services Survey Report for PBU_EOA OS 01 - 01-32 - 1-32A MWD Your Ref: API 500292162201 Job No. AKMW22186, Surveyed: 27 November, 2002 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 8597.70 17.020 325.700 8466.50 8534.20 320.74 N 467.64 W 5940844.84 N 697523.60 E 287.08 Tie On Paint MWD Magnetic 8626.00 17.740 328.300 8493.51 8561.21 327.83 N 472.24 W 5940851.81 N 697518.82 E 3.7 41 293.83 Widow Point 8721.28 31.270 342.600 8580.08 8647.78 363.97 N 487.34 W 5940887.55 N 697502.77 E 15.409 328.82 8816.38 41.630 344.460 8656.47 8724.17 418.11 N 503.23 W 5940941.25 N 697485.46 E 10.954 381.71 8846.56 46.100 346.550 8678.23 8745.93 438.35 N 508.45 W 5940961.35 N 697479.72 E 15.568 401.54 --j 8876.49 48.380 345.940 8698.54 8766.24 459.70 N 513.67 W 5940982.54 N 697473.93 E 7.763 422.46 8907.79 54.270 346.990 8718.10 8785.80 483.44 N 519.38 W 5941006.13 N 697467.60 E 18.999 445.75 8936.04 57.370 346.580 8733.96 8801.66 506.19 N 524.72 W 5941028.74 N 697461.66 E 11.039 468.06 8969.69 57.450 347.430 8752.09 8819.79 533.82 N 531.10 W 5941056.18 N 697454.56 E 2.142 495.17 8999.54 57.180 346.700 8768.21 8835.91 558.30 N 536.72 W 5941080.51 N 697448.30 E 2.248 519.20 9029.50 57.290 346.600 8784.42 8852.12 582.82 N 542.54 W 5941104.86 N 697441.84 E 0.462 543.25 9060.01 61.070 350.650 8800.06 8867.76 608.49 N 547.69 W 5941130.40 N 697436.02 E 16.833 568.50 9094.40 64.220 352.490 8815.86 8883.56 638.70 N 552.16 W 5941160.48 N 697430.76 E 10.318 598.32 9125.13 64.420 351.980 8829.17 8896.87 666.14 N 555.90 W 5941187.81 N 697426.30 E 1.631 625.43 9156.43 67.760 351.680 8841.86 8909.56 694.46 N 559.97 W 5941216.02 N 697421.49 E 10.707 653.39 9190.56 67.940 351.680 8854.73 8922.43 725.74 N 564.54 W 5941247.16 N 697416.09 E 0.527 684.27 9221.68 67.740 352.400 8866.47 8934.17 754.28 N 568.53 W 5941275.59 N 697411.35 E 2.237 712.46 9250.48 66.780 356.810 8877.60 8945.30 780.72 N 571.03 W 5941301.95 N 697408.16 E 14.510 738.66 9283.76 66.420 1.240 8890.83 8958.53 811.25 N 571.55 W 5941332.46 N 697406.84 E 12.264 769.07 9315.20 66.270 4.830 8903.44 8971.14 840.00 N 570.03 W 5941361.24 N 697407.60 E 10.470 797.86 9343.27 66.620 9.270 8914.67 8982.37 865.53 N 566.87 W 5941386.84 N 697410.09 E 14.553 823.55 9373.35 66.700 13.460 8926.59 8994.29 892.60 N 561.43 W 5941414.04 N 697414.82 E 12.792 850.93 9404.78 69.280 14.370 8938.37 9006.07 920.88 N 554.42 W 5941442.50 N 697421.08 E 8.636 879.64 ~,,/ 9437.52 71.730 14.700 8949.29 9016.99 950.75 N 546.67 W 5941472.56 N 697428.04 E 7.543 909.98 9476.26 76.270 16.41 0 8959.97 9027.67 986.61 N 536.69 W 5941508.68 N 697437.09 E 12.463 946.46 9498.85 77.850 15.990 8965.03 9032.73 1007.75 N 530.54 W 5941529.97 N 697442.67 E 7.225 967.98 9530.75 80.920 17.470 8970.90 9038.60 1037.78 N 521.52 W 5941560.22 N 697450.91 E 10.649 998.56 9559.95 85.000 17.740 8974.48 9042.18 1065.39 N 512.75 W 5941588.06 N 697458.94 E 14.003 1026.72 9624.22 86.930 18.080 8979.00 9046.70 1126.39 N 493.04 W 5941649.55 N 697477.05 E 3.049 1088.96 9715.66 87.910 18.010 8983.12 9050.82 1213.25 N 464.74 W 5941737.12 N 697503.05 E 1.074 1177.58 6 December, 2002 - 13:39 Page 2 of4 DrillQuest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 01 - 01-32 - 1-32A MWD Your Ref: AP/500292162201 Job No. AKMW22186, Surveyed: 27 November, 2002 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 9808.82 88.030 16.960 8986.42 9054.12 9902.85 85.880 14.790 8991.41 9059.11 9972.95 85.880 14.660 8996.45 9064.15 10040.00 85.880 14.660 9001.27 9068.97 Local Coordinates Northings Eastings (ft) (ft) 1302.04 N 1392.35 N 1459.97 N 1524.67 N 436.77 W 411.09 W 393.32 W 376.39 W All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 4.030° (True). Magnetic Declination at Surface is 26.154°(25-Nov-02) Based upon Minimum Curvature type calculations, at a Measured Depth of 10040.000., The Bottom Hole Displacement is 1570.44ft., in the Direction of 346.133° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8597.70 8626.00 10040.00 320.74 N 327.83 N 1524.67 N Tie On POint Widow Point Projected Survey 8534.20 8561.21 9068.97 467.64 W 472.24 W 376.39 W 6 December, 2002 - 13:39 Page 3 of4 Global Coordinates Northings Eastings (ft) (ft) 5941826.62 N 5941917.57 N 5941985.64 N 5942050.76 N 697528.68 E 697551.98 E 697567.97 E 697583.19 E Dogleg Rate (o/100ft) BPXA Vertical Section Comment 1 .134 1268.13 3.246 1360.02 0.185 1428.72 0.000 1494.45 Projected Survey .~ Dril/Quest 3.03.02.004 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 01 w 01w32 w 1w32A MWD Your Ref: API 500292162201 Job No. AKMW22186, Surveyed: 27 November, 2002 BPXA North Slope Alaska Survey tool proaram for 01-32 - 1-32A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth (ft) (ft) Survey Tool Description 0.00 8597.70 0.00 8597.70 8534.20 10040.00 8534.20 Good Gyro(01-32) 9068.97 MWD Magnetic(1-32A MWD) ~/ ~' 6 December, 2002 - 13:39 Page 4 of 4 DrillQuest 3.03.02.004 ~~~~! TI~ ) !Æ~!Æ~~~ } AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 w. ¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 01-32A BP Exploration (Alaska), Inc. Permit No: 202-185 Surface Location: 4912' NSL, 4601' WEL, Sec. 08, T10N, R15E, UM Bottomhole Location: 1113' NSL, 4988' WEL, Sec. 05, T10N, R15E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaskél Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~tiJvÅ ~ Cammy O~hsli Taylor Chair BY ORDER or THE COMMISSION DATED this~ day of September, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work 0 Drill aI Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 4912' NSL, 4601' WEL, SEC. 08, T10N, R15E, UM At top of productive interval 516' NSL, 5229' WEL, SEC. 05, T10N, R15E, UM At total depth 1113' NSL, 4988' WEL, SEC. 05, T10N, R15E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028326, 4166' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8633' MD Maximum Hole Angle 18. Casin~ Program Specifications $17e Hole Ç~sinQ YVeioht ~rad~ ÇQIJPlinQ 9-5/8" 7" Scab 26# L-80 BTC-Mod 6-1/8" 4-1/2" 12.6# 13Cr-80 Yam Ace '\ STATE OF ALASKA"'\ ALASKA ',-.L. AND GAS CONSERVATION COMMI_SION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test aI Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned RKB = 68.5' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL028329 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / 01-32A 9. Approximate spud date 09/13/02 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10046' MD /9064' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} , 0 86 Maximum surface 2400 psig, At total depth (TVD) 8800' / 3280 psig Setting Depth Top Botom ~nQth Mn NO MO NO 5020' 4000' 3995' 9020' 8930' 1387' 8470' 8343' 10046' 9064' V-t(}A 'Iq./o,- dIP' ~/c¡(~ 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantity of Ceme{1t (il1clude ~t~~ QataJ Unccn'ðntefJ I '31 b bl $ 189 sx Class 'G' w~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Su rface Intermediate Production Liner 9350 feet 9239 feet 9344 feet 9233 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD To Surface 110' 110' 2000 sx CS III, 400 sx CS II 2515' 2515' 705 sx Class 'G', 300 sx CS I 9344' 9233' 110' 2515' 20" 13-3/8" 9344' 9-5/8" Perforation depth: measured 20. Attachments Open: 9114' - 9126', 9144' - 9158' Sqzd: 9093' - 9098' true vertical Open: 9019' - 9030', 9047' - 9060' Sqzd: 9000' - 9004' aI Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch aI Drilling Program aI Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Phil Smith, 564-4897 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that thùe fO\tgOi~g's true and correct to the best of my ~nowl~~ge . Signed Bill Isaacson "''''4 1\, " ~ Title Senior Dnlllng Engineer Date 8/ z,q 101. , ' ," " ":,~:~~,~,;':'":";:<,' Permit Number API Number ? ð 2... - / ~ tiÇ 50- 029-21622-01 Conditions of Approval: Samples Required 0 Yes ..81 No Hydrogen Sulfide Measures ø Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: 'T~;ærlylof1S'OO pst. Commissioner App,rqval-Date See cover letter L11l) .0 ~ for other reQuirements Mud Log Requi"ed 0 Yes BI No Directional Survey Required 81 Yes 0 No D4K D5K D10K D15K 0 3.5K psi for CTU Approved Bv Form 10-401 Rev. 12-01-85 by order of the commission Date q t '«'62 Submit' n Triplicate O. n' ~~~\~ f' ~ I 1~\~lJil~~AI ) ) I Well Name: IDS 1-32A Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Sidetrack Horizontal Producer I AFE Number: 1 PBD- 4P2005 1 I Estimated Start Date: 1 09/13/02 I I MD: 110,046' I 1 TVD: 19064' 1 Surface Location: Estimated Target Location: Sadlerochit Zone 2 Bottom Hole Location: x = 697,999.50 Y = 5,940,536.50 3681 FNL , 678' FWL Sec. 8, T10N, R15E Umiat X = 697,345.2800 Y = 5,941,403.360 TVDss 8928 516' FSL , 50' FWL Sec. 5, T10N, R15E Umiat X = 697,568.73 Y = 5,942,006.67 TVDss 8995 1113' FSL, 292' FWL Sec. 5, T10N, R15E Umiat I Rig: 1 Nabors 2ES / 1 Operating days to complete: 116.0 1 BF/MS: 139.2' 1 I RKB: 168.5' 1 Well Design (conventional, slim hole, etc.): Horizontal Sidetrack I Objective: I Zone 2, Sadlerochit CasingITubing Program Hole Size Csgl WtlFt Grade Conn Length Top Btm Tbg O.D. MDITVD MDITVD 9 5/8" csg 7" Scab 26# L -80 / BTC-mod 5020' 4000 / 3995' 9,020/8930' 61/8" 4 Y2" 12.6# 13Cr-80 Vam Ace 1387' 8,470' / 8343' 10,046' / 9064' Tubing 4 Y2" 12.6# 13Cr-80 Vam Ace 8435' GL 8,4 75' / 8348' Directional KOP: 18,633' MO (18° incl) Maximum Hole Angle: Close Approach Well: Survey Program: OS1-32A Sidetrack Up to 86° in the target section 18° @ planned KOP The closest wellbore is OS1-17 at 1128' center-center distance at planned 9388' MO. This and all other wells pass major risk criteria. Standard MWO kick-off to TO. Page 1 ) ) Mud Program Window Milling Mud Properties: Flo-Pro Density (ppg) Viscosity PV 8,4 --:8.6 50 - 70 5 - 6 I Whipstock Window in 7" YP tauO 30 - 35 5 - 8 I MBT <3 pH API FI 8.5 - 9.0 N/C pH API FI 8.5 - 9.0 N/C Production Mud Properties: Flo-Pro Density (ppg) Visco~ity PV 8.4 - 8.6 / 45 - 55 5 - 8 YP 20 - 25 I 6 1/8" hole section tauO 5-8 I MBT <3 Logging Program 61/8" Production: Sample Catchers - Two, at Company man call out Drilling: MWD ABI Dir/GRlRes - Real time GRlRES throughout entire interval to help geosteer Open Hole: None Cased Hole: Memory CNL post rig (slickline conveyed) Cement Proc ram .. Casing Size 4 %" Production Liner Basis: Lead: None Tail: Based on 1413' of 6 1/8" open hole with 40% excess, 150' of 4 %" x 7" liner lap, plus 200' of 4" DP x 7" casing annulus. Tail TOC: -8470' MD (8410' TVDbkb).- Liner top. Fluid Sequence & Volumes: Pre 10 bbls KCI Water Flush Spacer Lead Tail 30 bbls Alpha Spacer at 9.5 ppg None ,,- 40 bbl/ 225 fe /189 sks of Halliburton 'G' at 15.6 ppg and 1.19 cf/sk, BHST 2090 @ 8800' TVDss TT = Batch Mix 4 to 4.5 hrs Well Control Well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. / / This well will require rams capable of closing on the 7" casing string while running * same. Install 4 Y2" X 7" VBRs at a convenient time prior to running casing. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Producti.on Section- . Maximum anticipated BHP: 3280 psi @ 8800' TV'?JS - Ivishak . Maximum surface pressure: 2400 psi @ surface (based upon BHP and a full column of gas from TO @ 0.10 psi/ft) . Planned BOP test pressure: Planned completion fluid: 3500 psi / 8.6 ppg seawater / 7.2 ppg Diesel . . 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. . DS 1-32A Sidetrack Page 2 ) ) . Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. Markers Forrnation Tops (Wp#5) CM1 THRZ BHRZ TJB TJA TSGR KOP AT OR NEAR TSGR TSHU TSAD TZ4BL (45SB) TZ4A (42SB) TZ3 (TCGL) TZ2C (BCGL) TZ2B/23SB 25P SAND 24N SHALE 22TS/24P SAND 23P SAND HOT TZ2A (21TS) PTD TVDss -7693 -8103 -8294 -8336 -8397 -8498 MDbkb Comments -8530 -8603 -8650 -8731 -8785 -8846 -8917 -8925 -8940 -8952 -8971 -8884 -8991 -8995 3283 psi @ 8800' SSTVO 7. t P pj ~ .to TD Criteria: TO with sufficient rathole to log the POWC (if present) or top of prognosed HOT with LWO resistivity, OS 1-32A Sidetrack Page 3 ") ) Sidetrack and Complete Procedure Summary Ria ODerations: 1. MIRU Nabors 2ES. 2. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. ,,/ 4. Pull 4 %" tubing from cut. 5. Run USIT in 9 5/8" casing from 8000' to surface. /" 6. Change out 9 5/8" casing packoff if necessary. 7. Mill and recover 9 5/8" production packer. r- ~ 8. Run and cement 7" scab liner from top of fill (-9020' MD) to top of damaged casing (-4000' MD expected) -- 9. MU window milling BHA drift down to the 7" landing collar. Test the casing to 3000 psi for 30 minutes. 10. Orient and set bottom trip whipstock such that KOP is at 8633' MD. Change well over to milling fluid. Mill window ,in casing at:t 8300' MD. Perform FIT to 10.0 ppg. POOH. ,,- 11. Kick-off and' drill the 6 1/8" production hole as per directional plan to TD well at :t10,046' MD. 12. Short trip, CBU, spot liner running pill, POH. /' 13. Run and cement a 4 %", 12.6#, L-80 production liner to TD. Displace with perf pill and seawater. Circulate the well to clean seawater at the liner top, POOH. /' 14. Run 4 %", 12.6# 13Cr-80 completion tying into the 4 %" liner top. 15. Set packer and test the tubing and annulus to 3000 psi for 30 minutes. 16. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 17. Freeze protect the well. 18. Rig down and move off. Post-Ria Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. DS t~32A Sidetrack Page 4 ') ') Job 1: MIRU Hazards and Contingencies ~ No wells will require shut-in for the rig move to OS1-32. Wells OS1-16 to the north and OS1-15A to the south are the two closest wells, each at 60' center to OS1-32. ~ DS1 is a designated as an H2S site: Standard Operating Procedures for H2S precautions should be followed at. all times. Recent H2S data from the pad is as follows: ~djacent producers at Surface: Closest BHL Wells " 01-15A No recorded H2S 01-16 0 ppm 4/10/1998 01-16 0 ppm 4/10/1998 01-33 No recorded H2S The maximum level recorded of H2S on the pad was 146 ppm on 4/252001. 01-32 measured 0 ppm in April, 2000. >- Post Permit to Orill and Summary of Orilling Hazards in the dog house and camp prior to spud Job 2: De-complete Well Hazards and Contingencies ~ The perforated intervals and lower section of this well are covered with fill and dump-bailed sand. Monitor the well to ensure the fluid column is static, prior to pulling the completion. ~ NORM test all retrieved well head and completion equipment. Job 3: Run Whipstock Hazards and Contingencies >- Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Job 6: Install 7" ScabiDfilHna Liner Hazards and Contingencies ~ Ensure rams areihstalled to cover both the 7" casing and the drillpipe in use during this phase. Job 7: Drill 61/8" Production Hole Hazards and Contingencies ~ Northern and Western boundaries of the polygon are hardlines due to faults. A 15-20' E-W trending, OTN fault is located approx. 140' North of the northern polygon boundary. A 5-10' N-S trending OTW fault is located approx. 300' west of the western polygon boundry. ~ One fault is prognosed to be crossed: 10-15' throw at 9645' MD. The fault is not expected cause problems, though lost circulation has been an issue in the area. See the pad data sheet. ~ Kick tolerance is infinite in this hole section under any reasonable circumstance. Job 9: Install 4Y2" Production Liner OS 1-32A Sidetrack Page 5 ) Hazards and Contingencies ~ Differential sticking is a concern. The 8.5 ppg Quickdril will be -600 psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. Job 1:2: Run Comøletion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Job 13: ND/NU/Release Ria Hazards. and Contingencies ~ Though there are' no close proximity surface issues, identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig about the pad and while positioning on the hole. DS 1-32A Sidetrack Page 6 . TREE= . WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= _? FMC AXELSON 70' ? 7000' 21 @ 9350' 8454' 8800' SS ) 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2515' ~ Minimum ID = 3.725" @ 8540' 4-1/2" 01"IS XN NIPPLE 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1-1 8553' PERFORA TION SUMMARY REF LOG: BHCS ON 08/15/86 ANGLE AT TOP PERF: 20 @ 8742 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9093 - 9098 S 10/20/93 3-318" 4 9114-9126 0 10/31/93 3-3/8" 4 9144 - 9158 0 10/31/93 DATE 08/18/86 01/16/87 11/09/00 02/08/01 02/16/01 9-5/8" CSG, 47#, L-80, 10 = 8.681" l-t [!£]-t REV BY COMMENTS ORIGINAL COMPLEllON LAST WORKOVER CONVERTED TO CANVAS FINAL CORRECTIONS SIS-LG SIS-MD TP 01-32 8 L :8: f 1 9344' ~ i 935œ I - DA TE REV BY ~ , I COMMENTS ..~ )AFETY NOTES: FISH DEPTH UNKNOWN LOST 8{1-1/2 x 3/4) PRS DOGS 2191' 1-1 4-1/2" CAMeo BAL-O SSSV NIP, 10 = 3.813" I ~ ST MD TVD 1 3193 3190 2 5467 5460 3 6272 6264 4 7198 7180 5 8111 8062 6 8179 8128 7 8292 8238 8 8361 8306 GAS LIFT MANDRELS DEV TYPE VLV LATCH 5 MMG RK 3 MMG RK 2 MMG RK 15 MMG RK 13 MMG RK 12 MMG RK 12 MMG RK 13 MMG RKP PORT DATE 8433' 1-1 9-5/8" X 4-1/2" BAKER SB-3 PKR 1 8540' 8553' 8558' 1-1 4-1/2" OTIS XN NIP, 10 = 3.725" I 1-1 4-1/2" TUBING TAIL 1 1-1 ELMO TT LOGGED 02122/87 1 PRUDHOE BAY UNIT WELL: 01-32 PERMIT No: 1861270 API No: 50-029-21622-00 SEC 5 T10N R15E 5179.21 FEL 5087.29 FNL BP Exploration (Alaska) . TREE= . WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= _? FMc AXELSON 70' ? ) 8633' 8800' SS 13-3/8" CSG, 72#, L-80, 10= 12.347" 1-1 25151 ~ I 7" Scab Liner ~ex-Lock hanger I ZXP 1-1 -40001 I Minimurt:lID = 3.813" @ 2200' 4-1/2" X NIPPLE 14-1/2" VamAce, 12.6#, 13Cr-80, 10 = 3.958" 1-1 84751 I PERFORATION SUMMARY REF LOG: BHCS ON 08/15/86 ANGLE A T TOP PERF: Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1 7" CSG, 26#, L-80 I top of fill in 9-5/8-1 -90201 I I Abandon Perfs 1-19093-915811 9-5/8" CSG, 47#, L-80, 10 = 8.681" l-f 93441 ~-f 93501 I DATE 08/18/86 01/16/87 11/09/00 02/08/01 02/16/01 08/28/02 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER SIS-LG CONVERTED TO CANVAS SIS-MD FINAL TP CORRECTIONS PGS PROPOSED SIDETRACK 01-32A l I ~ / I I / / f I ~ I I I~ \!!I, iI ~ / ,I , )sAFETY NOTES: 8 22001 1-1 4-1/2" X Nipple, 10 = 3.813" ~ " I 3: / L I I ST MD 1 2 3 4 5 / ~6~ I . / 18,3701 g aD . / 8,1b~' ~ I 18,4701 I; 18,4801 18,6331 " iflll. DATE REV BY COMMENTS 41/2" x 1" GAS LIFT MANDRELS lVD DEV TYÆ VLV LATCH PORT DATE I 4-1/2" X 3.813" 10 1 9-58' x 4-1f2' Fh" 4-1/2" X 3.813" ID I 41/2" Liner Top 1 1 4-1/2" Hanger/A<r I I 7" x 9-5/8" window I 4-1/2" 12.6 #/ft 13Cr-80 Yam Ace Well TO 10,046' MD PBTD 9,960' MD PRUDHOE BAY UNIT W8...L: 01-32A ÆRMIT No: 1861270 API No: 50-029-21622-01 SEe 5 T10N R15E 5179.21 F8... 5087.29 FNL BP Exploration (Alas ka) ö 8400- 8600 '2 ~ 0 0 t!. .s 0. ~ 8800 ~ '€ ~ ë E-< 9000 9200 COMPANY DETAILS REFERENCE INFORMATION SURVEY PROGRAM Plan: 01.32A wp05 (01.321P1an 01-32ALateraI) BP Amoco Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Wsmin~ Metbod: Rules Based Co-ordinate (NIE) Referen<:e: Well Centre: 01-32, True North Vertical (TVD) Reference: 68.50' 68.50 Section (VS) Reference: Slot - 32 (O.OON,O.OOE) Measured Depth Reference: 68.50' 68.50 Calculation Method: Minimum Cwvature Depth Fm Depth To SurveylPlan 8633.00 10046.02 Planned: 01.32A wp05 V6 Tool Created By: Ken Allen Checked: Date: Date: 8/13/2002 MWD Reviewed: Date: CASINO DETAILS WELL DETAILS Name +N/.S +FJ.W Northing Easting Latitude Longitude Slot 01.32 .1415.67 724.64 5940536.00 697999.00 70"14'29.98IN 148"24'02.938W 32 TARGET DETAILS Name TVD +N/-S +FJ-W Northing Easting Shape 01-32A TIB 8996.50 886.90 -629.96 5941406.00 697346.00 Point 1.32A Poly 9004.50 482.81 .708.60 5941000.00 697278.00 Polygon 01.32A 1"2B 9053.50 1343.33 -448.90 5941867.00 697515.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFace VSee Target 1 8633.00 17.90 328.83 8567.91 329.44 -473.23 0.00 0.00 439.41 2 9046.32 67.43 333.53 8862.51 569.84 -599.11 12.00 5.71 703.99 3 9062.81 67.43 333.53 8868.84 583.47 -605.90 0.00 0.00 718.91 4 9399.83 70.00 17.00 8996.50 886.90 -629.96 12.00 94.78 1018.41 01-32A TlB 5 9570.11 86.15 22.55 9031.60 1043.02 -573.58 10.00 19.23 1154.94 6 9896.02 86.15 22.55 9053.50 1343.33 -448.90 0.00 0.00 1413.43 01-32A T2B 7 10046.02 86.15 22.55 9063.58 1481.55 -391.51 0.00 0.00 1532.41 "-'" No. TVD Name Size MD 9063.58 10046.01 4 112" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Formation I ~",. 7.91 8633.00 TSOR 2 ~"!s.50 8665.53 TSHU 3 S'.:1.50 8747.33 TSAD 4 ~)\1I_~.50 8925.33 TZ4A 5 S)o'. \.50 9024.07 TZ3(TCOL) 6 )\' 1-.50 9177.51 TZ2C(BCOL) 7 ~.,~ ';.50 9368.23 TZ2B(25N shale) 8 S""~.50 9396.91 25P Sand 9 "'"1".50 9441.88 24N Shale 10 "":11.50 9487.86 24P Sand/22TS II '1IIiri.50 9643.04 23N Shale 12 ''''\''.50 9687.68 23P Sand 13 "'-'~.'..50 9881.14 HOT All TVD depths are ssTVD plus 68. 50' for RKBE. Start Dir 12/100' : 8633' MD, 8567.9l'TVD TSCR/ I~U ~ ')þ<° /~ /A~ i~/ ~ ~/M~ I ¡JJ - 61// ¡ß/ ,I ,I , --'" End Dir : 9046.32' MD, 8862.51' TVD Start Dir 12/100' : 9062.81' MD, 8868.84'TVD Start Dir 10/100' : 9399.83' MD, 8996.5'TVD \ \ TZ2B(25N shale) ~:..:.. ~ 25P Sand I / 24N ;hale 24P 3and/22TS , /1 -<I :-JOT 10000 -1'- 4 1/2" Total Depth: 10C46.02' MD, 90H58' TVD ~~ End Dir : 9570.11' MD, 9031.6' TVD / ..9000 ~OOO /000 23N Shale / I 23P Sand '" 00 400 600 WO 1000 Vertical Section at 345.200 [200ft/in] 1200 1400 I 1600 ~ '/. ~ 000 ö 1400 1200 1000 :s 4:¡ 0 0 ~ +' f ~ ;Š 800 =' 0 Vl COMPANY DETAILS BP Amoco Calculation Method: Minimum CUlvature Enor System: ISCWSA Scan Method: Trav Cylinder North Enor Surlàce: Elliptical + Casing Wamltl 1; Method: Rules Based (' REFERENCE INFORMATION SURVEY PROGRAM Tool Depth Fm Depth To SurveylPlan 8633.00 10046.02 Planned: 01-32A "J'05 V6 MWD C<H>roinate (NÆ) Reference: Well Centre: 01-32, True North Vertical (1VD) Reference: 68.50' 68.50 Seetioo (VS) Reference: Slot. 32 (O.OON,O.OOE) Measured Depth Reference: 68.50' 68.50 Calculation Method: Minimum Curvature ¡ 1/2" Total DCJth: 10046.0Z' MD, 9063.58' TVD 01-32A wp05 ) End Dir : 9570.11' \1D, 9(131.6' TVD ff I ~tart Dir 10/11)0': 9~99Jn' VfD,8996.5'TVO 'WI Ji, 121100' , 9062.8" MD. "68'8~~ ~nJ Dir : 9046.:12' MD, 8862.51' 1'/ / \-....... 01-32 (01-:;2) 95%ccnf. / All TVD depths are ____H2~Pol,- \ ssTVD plus 68.5'for RKBE. 600 400 200 -800 -600 Stall Dir 121' 00' . 8:}33' M:J, 85Cr7.91'TVD -400 -200 West( - )/East( +) [200ft/in] 0 200 Name +N/-5 +FJ-W Northing 01-32 -1415.67 724.64 5940536.00 Plan: 0 1-32A wp05 (0 1-32lP1an 01- 32A Lateral) Created By: Ken Allen Checked: Date: 8/13/2002 Dale: Reviewed: Date: WELL DETAILS Easting Latitude Longitude Slot 697999.00 70'14'29.98IN 148'24'02.938W 32 TARGET DETAILS Name 1VD +N/-5 +FJ-W Nonhing 01.32A TlB 8996.50 886.90 -629.96 5941406.00 1-32A Poly 9004.50 482.81 .708.60 5941000.00 01-32A 118 9053.50 134333 448.90 5941861.00 Easting Shape 697346.00 Point 697278.00 Polygon 697515.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S 1 8633.00 17.90 328.83 8567.91 329.44 2 9046.32 67.43 333.53 8862.51 569.84 3 9062.81 67.43 333.53 8868.84 583.47 4 9399.83 70.00 17.00 8996.50 886.90 5 9570.11 86.15 22.55 9031.60 1043.02 6 9896.02 86.15 22.55 9053.50 1343.33 7 10046.02 86.15 22.55 9063.58 1481.55 CASING DETAILS No. TVD MD Name Size 9063.58 10046.01 4 1/2" 4.500 ~~ ,I ,I II III '/000 "»000 ~OOO 4' /~~ +E/-W DLeg TFace VSee Target -473.23 0.00/ 0.00 439.41 -599.11 ~ 5.71 703.99 -605.90 .0 0.00 718.91 -629.96 12.00 94.78 1018.41 01-32A TlB -573.58 10.00 19.23 1154.94 -448.90 0.00 0.00 1413.43 01-32A T2B -391.51 0.00 0.00 1532.41 ~. FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 8567.91 8633.00 TSGR 2 8598.50 8665.53 TSHU 3 8671.50 8747.33 TSAD 4 8802.50 8925.33 TZ4A 5 8853.50 9024.07 TZ3(TCGL) 6 8913.50 9177.51 TZ2C(BCGL) 7 8985.50 9368.23 TZ2B(25N shale) 8 8995.50 9396.91 25P Sand 9 9009.50 9441.88 24N Shale 10 9020.50 9487.86 24P Sand/22TS 11 9036.50 9643.04 23N Shale 12 9039.50 9687.68 23P Sand 13 9052.50 9881.14 HOT ~ ') BP My Planning Report MAP ') Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: Map Zone: Coordinate System: Geomagnetic Model: PB OS 01 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5941932.14 ft 697237.60 ft Latitude: Longitude: North Reference: Grid Convergence: 01-32 01-32 Well Position: Well: Slot Name: +N/-S -1415.67 ft Northing: 5940536.00 ft +E/-W 724.64 ft Easting : 697999.00 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan 01-32A Lateral Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: 68.50' 8/8/2002 57544 nT Depth From (TVD) ft 0.00 +N/-S ft 0.00 Height 68.50 ft Plan: 01-32A wp05 Date Composed: Version: Tied-to: Principal: Yes Casing Points MD TVD Diåintiut ft ft in 10046.01 9063.58 4.500 6.125 41/2" Formations MD . TVD Fon.ïatlons ft . 'ft 8633.00 8567.91 TSGR 8665.53 8598.50 TSHU 8747.33 8671.50 TSAD 8925.33 8802.50 TZ4A 9024.07 8853.50 TZ3(TCGL) 9177.51 8913.50 TZ2C(BCGL) 9368.23 8985.50 TZ2B(25N shale) 9396.91 8995.50 25P Sand 9441.88 9009.50 24N Shale 9487.86 9020.50 24P Sand/22TS 9643.04 9036.50 23N Shale 9687.68 9039.50 23P Sand 9881.14 9052.50 HOT Targets Alaska, Zone 4 Well Centre BGGM2002 70 14 43.905 N 148 24 24.004 W True 1.50 deg 32 70 14 29.981 N 148 24 2.938 W 01-32 8633.00 ft Mean Sea Level 26.27 deg 80.81 deg Direction deg 345.20 8/13/2002 6 From: Definitive Path DiPA.tlgl~ . (ièg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ijiífpii:'~c1;iòn :(i~g , 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 'Map l\{aiP '. <~ Latitude ~ <-Longitude-> Name Description TV» '+Nf-"S ,'+EI~W . Northing' EaSting Deg' MiD See DegMin "See Dip~ Dir. ft ..ft . eft ft ft 01-32A T1B 8996.50 886.90 -629.96 5941406.00 697346.00 70 14 38.704 N 148 24 21.253 W -Plan hit target 1-32A Poly 9004.50 482.81 -708.60 5941000.00 697278.00 70 14 34.729 N 148 24 23.539 W -Polygon 1 9004.50 482.81 -708.60 5941000.00 697278.00 70 14 34.729 N 148 24 23.539 W ) BP My Planning Report MAP ') -polygon 2 9004.50 956.62 -770.18 5941472.00 697204.00 70 14 39.389 N 148 2425.330 W -Polygon 3 9004.50 1347.66 -765.91 5941863.00 697198.00 70 14 43.235 N 148 24 25.207 W -Polygon 4 9004.50 1367.25 163.98 5941907.00 698127.00 70 14 43.428 N 148 23 58.170 W -Polygon 5 9004.50 475.41 -312.64 5941003.00 697674.00 70 14 34.657 N 148 24 12.027 W .Plan out by 435.00 at 9004.50 909.28 -622.93 5941428.56 697352.44 70 14 38.924 N 148 24 21.049 W 01-32A T2B 9053.50 1343.33 -448.90 5941867.00 697515.00 70 14 43.193 N 148 24 15.990 W Plan Section Information 'l\JD', 'Iud . Aiiíri . TV}) .' ',fNI';S +~PW' ULS' 'Bùild'" " ,1'ût" WO 1ãrget ,-ft ' deg dØg -ft ft ft , d$'9f1,()0ij:'d~/:'Ø9ft'degI'1QØJt ,~g 8633.00 17.90 328.83 8567.91 329.44 -473.23 0.00 0.00 0.00 0.00 9046.32 67.43 333.53 8862.51 569.84 -599.11 12.00 11.98 1.14 5.71 9062.81 67.43 333.53 8868.84 583.47 -605.90 0.00 0.00 0.00 0.00 9399.83 70.00 17.00 8996.50 886.90 -629.96 12.00 0.76 12.90 94.78 01-32A T1B 9570.11 86.15 22.55 9031.60 1043.02 -573.58 10.00 9.48 3.26 19.23 9896.02 86.15 22.55 9053.50 1343.33 -448.90 0.00 0.00 0.00 0.00 01-32A T2B 10046.02 86.15 22.55 9063.58 1481.55 -391.51 0.00 0.00 0.00 0.00 Survey MD TOoJlCommënt ft 8633.00 17.90 328.83 8567.91 8499.41 5940852.88 697517.31 439.41 0.00 TSGR 8650.00 19.93 329.43 8583.99 8515.49 5940857.54 697514.36 444.71 12.00 MWD 8665.53 21.79 329.88 8598.50 8530.00 5940862.23 697511.44 450.04 12.00 TSHU 8675.00 22.92 330.12 8607.26 8538.76 5940865.30 697509.56 453.51 12.00 MWD 8700.00 25.92 330.66 8630.02 8561.52 5940874.15 697504.22 463.50 12.00 MWD 8725.00 28.91 331.09 8652.21 8583.71 5940884.06 697498.36 474.66 12.00 MWD 8747.33 31.58 331.41 8671.50 8603.00 5940893.77 697492.69 485.57 12.00 TSAD 8750.00 31.90 331.45 8673.77 8605.27 5940894.99 697491.99 486.94 12.00 MWD 8775.00 34.90 331.75 8694.64 8626.14 5940906.91 697485.13 500.31 12.00 MWD 8800.00 37.89 332.01 8714.76 8646.26 5940919.81 697477.80 514.74 12.00 MWD 8825.00 40.89 332.24 8734.08 8665.58 5940933.63 697470.02 530.20 12.00 MWD 8850.00 43.89 332.44 8752.54 8684.04 5940948.35 697461.81 546.63 12.00 MWD 8875.00 46.89 332.62 8770.10 8701.60 5940963.91 697453.19 563.99 12.00 MWD 8900.00 49.88 332.79 8786.70 8718.20 5940980.29 697444.19 582.24 12.00 MWD 8925.00 52.88 332.94 8802.30 8733.80 5940997.43 697434.83 601.32 12.00 MWD 8925.33 52.92 332.94 8802.50 8734.00 5940997.66 697434.70 601.57 12.00 TZ4A 8950.00 55.88 333.08 8816.86 8748.36 5941015.29 697425.13 621.18 12.00 MWD 8975:00 58.88 333.21 8830.33 8761.83 5941033.81 697415.13 641.77 12.00 MWD 9000.00 61.87 333.33 8842.69 8774.19 5941052.95 697404.85 663.03 12.00 MWD 9024.07 64.76 333.44 8853.50 8785.00 5941071.92 697394.71 684.08 12.00 TZ3(TCGL) 9025.00 64.87 333.44 8853.89 8785.39 5941072.66 697394.32 684.90 12.00 MWD 9046.32 67.43 333.53 8862.51 8794.01 5941089.87 697385.16 703.99 12.00 End Dir : 9046.32' MD, 8862.5 9062.81 67.43 333.53 8868.84 8800.34 5941103.33 697378.02 718.91 0.00 Start Dir 12/100' : 9062.81' M 9075.00 67.32 335.11 8873.53 8805.03 5941113.33 697372.88 729.95 12.00 MWD 9100.00 67.13 338.36 8883.21 8814.71 5941134.25 697363.22 752.75 12.00 MWD 9125.00 67.01 341.62 8892.96 8824.46 5941155.67 697354.78 775.68 12.00 MWD 9150.00 66.96 344.88 8902.73 8834.23 5941177.52 697347.57 798.67 12.00 MWD 9175.00 66.97 348.14 8912.52 8844.02 5941199.73 697341.62 821.66 12.00 MWD 9177.51 66.98 348.46 8913.50 8845.00 5941201.98 697341.09 823.97 12.00 TZ2C(BCGL) 9200.00 67.05 351.39 8922.28 8853.78 5941222.26 697336.94 844.60 12.00 MWD 9225.00 67.20 354.65 8932.00 8863.50 5941245.04 697333.54 867.42 12.00 MWD 9250.00 67.41 357.89 8941.65 8873.15 5941268.00 697331.44 890.05 12.00 MWD 9275.00 67.69 1.12 8951.20 8882.70 5941291.09 697330.63 912.43 12.00 MWD ) BP My Planning Report MAP ') 9300.00 68.03 4.34 8960.62 8892.12 5941314.23 697331.13 934.51 12.00 MWD 9325.00 68.44 7.54 8969.90 8901.40 5941337.38 697332.92 956.22 12.00 MWD 9350.00 68.90 10.72 8978.99 8910.49 5941360.45 697336.01 977.50 12.00 MWD 9368.23 69.28 13.03 8985.50 8917.00 5941377.20 697339.08 992.72 12.00 TZ2B(25N shale) 9375.00 69.42 13.88 8987.89 8919.39 5941383.40 697340.39 998.29 12.00 MWD 9396.9.1 69.93 16.63 8995.50 8927.00 5941403.36 697345.28 1016.08 12.00 25P Sand 9399.83 70..00 17.00 8996.50 8928.00 5941406.00 697346.00 1018.41 12.00 01-32A T1 B 9424.62 72.34 17.86 9004.50 8936.00 5941428.56 697352.44 1038.26 10.00 1-32A Poly 9441.88 73.98 18.44 9009.50 8941.00 5941444.39 697357.17 1052.12 10.00 24N Shale 9450.00 74.74 18.71 9011.69 8943.19 5941451.86 697359.46 1058.65 10.00 MWD 9487.86 78.33 19.95 9020.50 8952.00 5941486.90 697370.73 1089.12 10.00 24P Sand/22TS 9500.00 79.49 ,- 20.34 9022.84 8954.34 5941498.19 697374.54 1098.88 10.00 MWD 9550.00 84.23 21.92 9029.91 8961.41 5941544.79 697391.16 1138.94 10.00 MWD 9570.11 86.15 22.55 9031.60 8963.10 5941563.53 697398.26 1154.94 10.00 End Dir : 9570.11' MD, 9031.6 9600.00 86.15 22.55 9033.61 8965.11 5941591.36 697408.96 1178.65 0.00 MWD 9643.04 86.15 22.55 9036.50 8968.00 5941631.44 697424.38 1212.78 0.00 23N Shale 9687.68 86.15 22.55 9039.50 8971.00 5941673.01 697440.37 1248.19 0.00 23P Sand 9700.00 86.15 22.55 9040.33 8971.83 5941684.48 697444.78 1257.96 0.00 MWD 9800.00 86.15 22.55 9047.05 8978.55 5941777.59 697480.61 1337.28 0.00 MWD 9881.14 86.15 22.55 9052.50 8984.00 5941853.14 697509.67 1401.63 0.00 HOT 9896.02 86.15 22.55 9053.50 8985.00 5941867.00 697515.00 1413.43 0.00 01-32A T2B 9900.00 86.15 22.55 9053.77 8985.27 5941870.71 697516.43 1416.59 0.00 MWD 10000.00 86.15 22.55 9060.49 8991.99 5941963.83 697552.25 1495.91 0.00 MWD 1.0046.02 86.15 22.55 9063.58 8995.08 5942006.67 697568.73 1532.41 0.00 41/2" DS 1-32A P&A Cement volume ') ) Subject: DSl-32A P&A Cement volume Date: Tue, 3 Sep 2002 18:31:57 -0500 From: "Smith, Phil G (FAIR)" <SmithPGl@BP.com> To: "Winton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Winton, As per our phone conversation, the P&A of existing perfs in DSl-32A will be performed as part of the 7" scab liner installation with the rig. A fully cemented 9 5/8" x 7"annulus from -9020' MD to -4000' MD plus at least 80' of cement in the 7" shoe will isolate the perforations. A minimum of 131 bbls of cement will be placed, based on 5000' of 7" x 9 5/8" annulus + 80' of 7" 26#/ft shoe volume. More cement may be required if damaged casing is found higher than 4000' MD and/or if losses occur through the casing leak while running the 7" liner. Regards, Phil Smith Operations Drilling Engineer 564-4897 H 207039 DATE INVOICE I CREDIT MEMO 8/01/02 CKO'73102F IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY DESCRIPTION GROSS Permit To Dril~ Fee d,3?-A- Pls contactSo~draStewrnan X4750 for check pick.lp TOTAL ~ DATE 8/01/02 CHECK NO. H207039 VENDOR DISCOUNT NET $100.00 $100.00 No. H2O] 03/9 ARSTNA~ONALBANKOFASHLAND AN AFFIUATEOF NATIONAl CITY BANK CLEVElAND, OHIO 56-389 412 B' P '.',.,.,.',.,r:, .~', " Itß, ,",',.".,',",',' ,Im.!¡ "m,t/ .{,..", '..,O'di. _..> f t (' , ,..-, .... ' If" .' .:::::-,-,;.J. .<:- ,'u,' 'uittl ,'Ul?' '-""". '..:tP TO THE Alaska oil & Gas Conservätion ORDER '333 W7th.Ave, Ste'100 ' OF A'l1chorage,~ AI<. ' ,99501 III 2 0 ? 0 ~ q III I: 0 ~ . 2 0 ~ a q 5 I: 00 a ~ ~ . q II. CONSOLIDATED COMMERCIAL ACCOUNT *** * * $100.00* * **./f,~ NOTVALlD AFTER 12Ci, DAYS , , ~~{;;~:::~r~~;~f~t;;~~~i H ') ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME¡p£a /-32. A PTD# 202.- /<?s CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\j ody\templates "CLUE " The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated. above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANYÂI'X WELLNAME~ßClI-!j2A PROGRAM: Exp- Dev.){ Redrll~ Re-Enter- Serv- Wellboreseg- FIELD & POOL t:..<¡ðl-~ð INITCLASS JJ.// /-,.// GEOLAREA a',?'" UNIT# Ilb.ÇO ON/OFFSHORE ðv ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 'Y N 2. Lease number appropriate. . . .. . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 'f N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . V N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N -'p~ oj.. - t., 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N ~ ¥Jo/G>-- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . .. . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #, - 'V. ,IV. A . (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ~ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ø~ ~~: 6~~~1 ~":~~~~I~~~C~r~~II~t:O: C~~~~t~r & ~urt ~~g: : : :: ~~/A- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . 'Y:* 19. CMT will cover all known productive horizons. . . . . . . . . . ~ N 20. Casing designs adequate for C, T, B & permafrost. . .. . . . N . I. I' .., I~ (' . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . ' N /U/NP e-r $ t- t-- ~ 22. If a re-drill, has a 10-403 for abandonment been approved. .. ~ Y N 23. Adequate wellbore separation proposed.. . . . . . . . . . . . éP N 24. If diverter required, does it meet regulations. . . . . . . . . . ~¥-N- /II./'Jr; . 25. Drilling fluid program schematic & equip list adequate. . . . . éi2 N fIIl£u.¡ M \"-.-Î 1. ú> f pc¡ . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . @ N 'J 27. BOPE press rating appropriate; test to '3500 psig. æ N ¡uç¡ Z"Oo p.( ¿ . 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . i5i2 N 29. Work will occur without operation shutdown. . . . . . . . . . . 1YJ N 30. Is presence of H2S gas probable... . . . . . . . . . . . . . . "'7 @ 31. Mechanical condition of wells within AOR verified. . . . . . . . .¥-N- ¡..i/A- vdIJ. if v.~. APPR DATE APPR DATE 'v-i~ /Jr 'I. /4-/0 ;.,. (Service Well Only) GEOLOGY APPR DATE m - ~Z- , ('Exploratory Only) Rev: 07/12/02 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . 36. Contact namelphone for weekly progress reports. . . . . . . . GEOLOGY: RPC'~ PETROLEUM ENGINEERING: TEM RESERVOIR ENGINEERING JDW-<.nr UIC ENGINEER JBR SFD- WGA VJ4k MJW G:\geology\perm its\checklist.doc COMMISSIONER: COT 01S 0 <¡' J 0 <ç { 0 è Commentsllnstructions: ) ) Well H ¡story File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpHfy finding information. information of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. ) \) ¡¡(P9f aW-/~5 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Apr 03 08:42:29 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 03/04/03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD / MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1-32A 500292162201 BP Exploration Sperry Sun 03-APR-03 (Alaska) Inc. JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 3 AK-MW-22186 J. SACK R. BORDES # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 8 iON 15E 368 678 MSL 0) .00 67.70 39.20 # WELL CASING RECORD 1ST STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.125 7.000 8639.0 ') ) 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. WELL KICKED OFF FROM 1-32 WITH TOP OF WHIPSTOCK SET AT ABOUT 8628' MD, 8563' TVD. 4. MWD RUN 1 WAS DIRECTIONAL WITH GAMMA MODULE (GM) I UTILIZING GEIGER-MUELLER TUBE DETECTORS. NO FORMATION WAS DRILLED, THIS RUN WAS FOR TIE-IN PURPOSES ONLY. TIE-IN DATA (SGRC) ARE INCLUDED WITH RUN 3 DATA. 5. MWD RUN 2 WAS DIRECTIONAL ONLY. NO DATA IS PRESENTED. 6. MWD RUN 3 WAS DIRECTIONAL WITH GAMMA MODULE (GM) I UTILIZING GEIGER-MUELLER TUBE DETECTORS. 7. MWD DATA WAS DEPTH SHIFTED TO THE SCHLUMBERGER DEPTH CONTROL LOG OF 18 DECEMBER 2002, PER THE 4/1/2003 E-MAIL FROM D. SCHNORR (BP EXPLORATION). LOG HEADER AND RUN INFORMATION DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 8. MWD RUN 3 REPRESENTS WELL 1-32A WITH API # 50-029-21622-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10040' MD / 9069' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING SGRC = SMOOTHED GAMMA RAY COMBINED $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/03 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.OOO Corrnnent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 8515.0 8530.0 8619.5 8619.5 8619.5 8619.5 8619.5 STOP DEPTH 9983.0 10033.0 9990.0 9990.0 9990.0 9990.0 9990.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 8515.0 8517.5 8519.5 8523.5 8528.0 8542.5 8562.5 8563.5 8574.5 8576.5 8584.0 8586.0 8596.0 8611.0 8633.0 8638.5 8652.5 8662.0 8666.5 8668.5 8669.5 8671.5 8674.5 8684.0 8685.5 8689.0 8692.5 8695.0 8702.0 8704.5 8716.0 8718.0 8719.5 8728.0 8732.5 8736.0 8740.0 8742.5 8746.5 8751.5 8756.0 8758.0 8764.5 8766.0 8771.5 8779.0 8816.0 8823.5 8828.0 8829.5 8831.0 8838.5 8860.0 8865.0 8867.0 8870.5 8873.5 8878.0 8881.5 8882.5 8891.5 8894.0 8899.5 DEPTH ') GR 8503.0 8505.5 8507.5 8512.0 8516.5 8531.5 8551.5 8553.0 8563.0 8564.5 8572.0 8575.0 8585.0 8599.0 8621.5 8627.0 8642.0 8652.0 8657.0 8659.5 8660.5 8662.0 8664.5 8674.5 8675.5 8679.5 8682.5 8685.5 8691.5 8694.0 8703.0 8706.0 8708.0 8717.0 8721.5 8725.0 8728.5 8730.5 8734.5 8740.0 8744.0 8746.5 8752.0 8753.0 8757.5 8765.5 8802.5 8811.0 8816.0 8817.5 8820.0 8827.0 8846.5 8851.0 8853.5 8857.5 8859.5 8865.0 8868.0 8869.5 8878.0 8881.0 8885.5 ) 8902.5 8910.0 8915.0 8919.0 8921.0 8924.5 8930.5 8939.0 8949.0 8956.5 8958.5 8965.5 8967.0 8968.0 8974.0 8983.0 8992.5 9002.0 9010.5 9014.0 9016.0 9022.0 9031.5 9040.0 9042.0 9050.0 9072.0 9081.0 9086.0 9172.0 9202.0 9268.0 9302.0 9307.5 9312.0 9353.5 9363.5 9375.0 9377.0 9378.5 9382.5 9387.0 9392.0 9400.0 9409.5 9413.5 9416.5 9422.0 9424.5 9440.5 9448.0 9452.5 9461.0 9489.5 9497.5 9538.0 9546.0 9564.5 9595.0 9599.5 9640.5 9667.5 9670.0 9672.0 8888.5 8896.5 8901.5 8905.0 8907.5 8911.0 8917.0 8926.0 8935.5 8942.5 8944.5 8952.5 8954.0 8955.0 8961.0 8969.0 8978.5 8988.0 8998.0 9001.5 9003.0 9010.5 9020.0 9028.0 9030.5 9040.0 9064.5 9072.0 9078.0 9159.0 9191.0 9261.5 9291.0 9296.0 9300.5 9341.5 9351.0 9362.5 9365.0 9368.0 9371.5 9376.5 9380.5 9390.5 9397.5 9400.5 9404.0 9409.0 9412.0 9428.5 9435.5 9442.5 9452.0 9477.0 9486.0 9525.0 9534.0 9552.5 9582.5 9588.0 9629.0 9657.5 9660.0 9662.0 ) 9683.5 9686.5 9692.0 9700.5 9704.0 9716.5 9773.0 9777.5 9816.0 9856.0 9915.0 9947.5 10033.0 $ 9671.0 9673.5 9680.5 9689.0 9692.5 9704.5 9771.5 9775.0 9814.5 9857.5 9918.5 9953.5 10039.0 # MERGED DATA PBU TOOL MWD $ SOURCE CODE BIT RUN NO MERGE TOP 3 8503.0 MERGE BASE 10039.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8515 10033 9274 3037 8515 10033 ROP MWD FT/H 0.31 509 70.2198 2968 8530 10033 GR MWD API 14.78 543.91 45.3131 2937 8515 9983 RPX MWD OHMM 0.61 1816.17 26.0938 2742 8619.5 9990 RPS MWD OHMM 0.65 1793.96 39.5441 2742 8619.5 9990 RPM MWD OHMM 0.14 2000 50.0175 2742 8619.5 9990 RPD MWD OHMM 2.82 2000 75.1386 2742 8619.5 9990 FET MWD HOUR 0.4673 79.2533 3.33523 2742 8619.5 9990 First Reading For Entire File.. ...... ..8515 Last Reading For Entire File.......... .10033 File Trailer ') Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/03 Maximum Physical Record. .65535 File Type.. . . .. .. . ... . .. .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/03 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPM RPD FET ROP $ 2 ) header data for each bit run in separate files. 3 .5000 START DEPTH 8503.0 8607.5 8607.5 8607.5 8607.5 8607.5 8651.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9989.0 9996.0 9996.0 9996.0 9996.0 9996.0 10039.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # 27-NOV-02 Insite 66.37 Memory 10040.0 8503.0 10040.0 17.0 88.0 TOOL NUMBER 91360 62356 6.125 8639.0 ) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing... ................. .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999.25 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Water 8.60 48.0 9.5 11800 5.8 Based .340 .150 .300 .400 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR Min 8503 0.31 14.78 0.59 0.58 0.14 2.82 0.4673 Max 10039 201.76 543.91 1816.17 1793.96 2000 2000 79.2533 First Reading For Entire File........ ..8503 Last Reading For Entire File......... ..10039 Mean 9271 48.101 45.3088 25.8373 39.1487 49.4834 74.8507 3.34637 Nsam 3073 2776 2973 2778 2778 2778 2778 2778 ') 68.0 167.0 68.0 68.0 First Reading 8503 8651.5 8503 8607.5 8607.5 8607.5 8607.5 8607.5 Last Reading 10039 10039 9989 9996 9996 9996 9996 9996 ) ) File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/04/03 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 03 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 04/ 03 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
