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Home My WebLink About199-056MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC A-31A PRUDHOE BAY UNIT A-31A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 A-31A 50-029-21383-01-00 199-056-0 W SPT 8328 1990560 2082 963 967 964 965 14 18 20 24 4YRTST P Josh Hunt 6/21/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT A-31A Inspection Date: Tubing OA Packer Depth 36 2389 2302 2282IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250622110013 BBL Pumped:4.4 BBL Returned:4.1 Thursday, July 24, 2025 Page 1 of 1           MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Adam Earl Petroleum Inspector Well Name PRUDHOE BAY UNIT A -31A Insp Num: mitAGE210627182935 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 7, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC A -31A PRUDHOE BAY UNIT A -31A Src: Inspector Reviewed By:� P.I. Suprv. �' F NON -CONFIDENTIAL Comm API Well Number 50-029-21383-01-00 Inspector Name: Adam Earl Permit Number: 199-056-0 Inspection Date: 6/25/2021 Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8328 Tubing! 457 - 472 - 499 ' 525 - 2082 IAO 2310. 2244 - 2229-- 2.5 - OA 4 5 5 - 6 ' P Wednesday, July 7, 2021 Page I ol' I Packer Well A -31A Type Inj W ' TVD PTD 1990560 r Type Test SPT Test psi BBL Pumped: 2.5 BBL Returned: Interval 4YRTST P/F Notes: MIT IA Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8328 Tubing! 457 - 472 - 499 ' 525 - 2082 IAO 2310. 2244 - 2229-- 2.5 - OA 4 5 5 - 6 ' P Wednesday, July 7, 2021 Page I ol' I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,July 20,2017 TO: Jim Regg P.I.Supervisor ,� f // 7 SUBJECT: Mechanical Integrity Tests +( BP EXPLORATION(ALASKA)INC. A-3I A FROM: LOU Laubenstein PRUDHOE BAY UNIT A-31 A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry .1617 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT A-31A API Well Number 50-029-21383-01-00 Inspector Name: Lou Laubenstein Permit Number: 199-056-0 Inspection Date: 7/18/2017 ✓ Insp Nam: mitLOL170718143737 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A-31A Type Inj W' TVD 5328 Tubing 733 734 734 - 734 PTD 1990560 Type Testl SPT Test psi 2082 IA 40 2499 - 2462 - 2453 - BBL Pumped: 3.4 ' 1-BBL Returned: 3 • OA 27 13 17 - 2 —01 — ------ --- Interval 4YRTST P/F P Notes: SCANNED f)EP 2 121 a,.r Thursday,July 20,2017 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, March 25, 2016 2:15 PM To: AK, OPS GC3 Facility OTL; AK, OPS GC3 Operators; AK, OPS GC3 Field OTL; AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead;AK, OPS Well Pad AB; Glasheen, Brian P;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Sayers, Jessica; Dickerman, Eric; Morrison, Spencer; Munk, Corey; Odom, Kristine Subject: OPERABLE: Injector A-31A (PTD #1990560) Possible Inner by Outer Annulus Communication Attachments: Injector A-31A (PTD #1990560)TIO Plot.docx All, Injector A-31A (PTD#1990560) is showing anomalous inner by outer annulus pressure trends while on water injection.The inner annulus pressure was increased to 1000 psi on March 17, 2016. The inner annulus pressure was monitored for 7 days with no signs of inner annulus by outer annulus communication. The well is reclassified as Operable. A copy of the TIO plot has been included for reference. Thank you, Kevin Parks (Alternate: Whitney Pettus' BP Alaska-Well Integrity Coordinator Glnbai Wells G vv Organization SCANNED JUN 2 8 2016 Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From:.AK, D&C Well Integrity Coordinator Sent: Tues a , March 15, 2016 4:17 PM To: AK, OPS GC3 FacilitybIL AK, OPS GC3 Operators; AK, OPS GC3 Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel.,,Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; AK, OPS Well Pad AB; Glasheen, Brian P; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Sayers, Jessic , ickerman, Eric; Morrison, Spencer; Pettus, Whitney; Munk, Corey; Odom, Kristine Subject: UNDER EVALUATION: Injector A-31A (PTD #1990560) Possible Inner by Outer Annulus Communication All, Injector A-31A(PTD#1990560) is showing anomalous inner by outer annulus pressure trends while water injection. The inner annulus (IA) pressure was increased to 200 psi on March 10, 2016.The final pressures after a 30 1 • • Injector A-31A(PTD#1990560)TIO Plot 30,13 1003 • .ate_ .. • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, March 15, 2016 4:17 PM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators;AK, OPS GC3 Field OTL;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS PCC Ops Lead;AK, OPS Well Pad AB; Glasheen, Brian P;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Sayers,Jessica; Dickerman, Eric; Morrison, Spencer; Pettus,Whitney; Munk, Corey; Odom, Kristine Subject: UNDER EVALUATION: Injector A-31A (PTD#1990560) Possible Inner by Outer Annulus Communication Attachments: Injector A-31A (PTD #1990560) TIO and Injection Plot.docx All, Injector A-31A (PTD#1990560) is showing anomalous inner by outer annulus pressure trends while on water injection. The inner annulus (IA) pressure was increased to 200 psi on March 10, 2016.The final pressures after a 30 minute monitor period post increase were TBG/IA/OA= 560/200/10 psi with a well head temperature (WHT) of 116 degrees. On March 12, 2016 the pressures were confirmed to be TBG/IA/OA= 570/140/10 with a WHT of 131 degrees indicating an IA decrease of 60 psi despite a 15 degree temperature change.The well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Increase IA pressure to 1000 psi 2. Downhole Diagnostics: Monitor pressures for 7 to 10 days 3. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO and injection plot has been included for reference. Please call with any comments or concerns. Thank you, :CANNED MAR Y 1 2016 Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday,May 06,2015 11:34 AM To: AK, OPS GC3 Facility OTL; AK, OPS GC3-Operators; AK, OPS GC3 Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS ��-1 • • Injector A-31A(PTD#1990560) TIO Plot March 15, 2016 Well A 31 —0—T t M - 00 004 0006 On C 12.*51 122215 122415 014Yf6 5012.16 011416 012616 020216 000416 916116 022316 03+0116 60ce10 031516 Injection Plot Weil n 31 51: K0 / \/ IW I ID Ip IW 30D 360 NO320 900 301) i600 3 —i.e IND 16D )00 _ 0 6W _M 240 -DI 1 400 - 220 1300 d 200 11D 140 1 100 W 1GW 140 600 120 200 100 6a; ID SCO ID 300 tl 200 23 100 111515 112115 1212915 010516 01112-16 01'1516 012616 9013E 0:09 I6 021610 0023!6 090110 030416 033416 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, May 06, 2015 11:34 AM To: AK, OPS GC3 Facility OTL;AK, OPS GC3 Operators;AK, OPS GC3 Field OTL;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM;Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; Wallace, Chris D (DOA); AK,OPS Well Pad AB; Glasheen, Brian P Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA) Subject: OPERABLE:Injector A-31A (PTD#1990560) MIT-IA Passed Attachments: image001.png; image002.png;Injector A-31 TIO and Injection plot 05-06-15 .docx; MIT PBU A-31A 04-26-15.xls All, Injector A-31A(PTD#1990560) passed a positive pressure pack off test on the inner casing hanger(PPPOT-IC) and a Non witnessed MIT-IA on April 26, 2015. During the MIT-IA there were no signs of communication between the inner x outer annulus. The passing test indicates two competent barriers in the well.The well is reclassified as Operable. A copy of the injection and TIO plot and MIT-IA form has been included for reference. Thank you, �E1MAX t 6 2 15 Kevin Parks (/It(!fl tc 111iitncy Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From. D&C Well Integrity Coordinator Sent: Satur April 25, 2015 9:30 PM To: AK, OPS GC3 ''ty OTL; AK, OPS GC3 Operators; AK, OPS GC3 Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, ug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RE -•: West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; 'chris.wallace@alaska.gov'; AK, OPS - •.d AB; Glasheen, Brian P Cc: AK, D&C Well Integrity Coordinator; AK, D: s D Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Res•, .mes B (DOA) (jim.reog@alaska.gov); Pettus, Whitney; Hidalgo, Ramon Subject: UNDER EVALUATION: Injector A-31A (PTD #1990560) IAxO' :4i munication All, 1 Injector A-31A(PTD#1990560) has begun to exhibit inner annulus by outer annulus communication.The well has been reclassified as Under Evaluation and may remain online for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Perform MIT-IA 2. Wellhead: PPPOT-IC 3. Downhole Diagnostics: Monitor TIO pressures for 7 to 14 days 4. Well Integrity Engineer:Additional diagnostics as needed A copy of the injection and TIO plot has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP yAllasska-Well Integrity Coordinator �VV ~ �•y.r�zat n•i WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 Injector A-31 A(PTD#1990560) Injection plot 05-06-15 ,e11.11 '1'+ 5000 40.3 1111111 4.0 4 KO 660 500 GOO 516 32,66 Sw ` 4660 S00 SAO WO 510 1100 SOO YO 3. 460 1100 4519 : 1500 OW 1400 310 2200 -per 310 1000 260 1 K 240 1600 m0 200 t 400 102 20 140 110 1 000 130 1p0 10 00 600 60 100 40 200 20 02,0616 Th213115 01/015 01/715 019515 031315 01 1S 014115 049315 04'10'15 05'1115 042415 0591,15 Injector A-31A(PTD# 1990560)TIO plot 05-06-15 Well•AI 000 2000 OS --111- 00 0 o0ol 41 r , " •\- 0204 5 021115 02,2215 60,27 15 010615 0313215 UYp15 oil.. 01018 W 9.5 0,-V 60435 040115 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, April 25, 2015 9:30 PM To: AK, OPS GC3 Facility OTL; AK, OPS GC3 Operators;AK, OPS GC3 Field OIL;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; Wallace, Chris D (DOA);AK, OPS Well Pad AB; Glasheen, Brian P Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R;AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Pettus, Whitney; Hidalgo, Ramon Subject: UNDER EVALUATION:Injector A-31A(PTD #1990560)IAxOA communication Attachments: image001.png;Injector A-31A(PTD#1990560)110 and Injection Plot 04-25-15.docx All, Injector A-31A(PTD#1990560) has begun to exhibit inner annulus by outer annulus communication.The well has been reclassified as Under Evaluation and may remain online for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Perform MIT-IA 2. Wellhead: PPPOT-IC 3. Downhole Diagnostics: Monitor TIO pressures for 7 to 14 days 4. Well Integrity Engineer:Additional diagnostics as needed A copy of the injection and TIO plot has been included for reference. Please call with any questions or concerns. Thank you, sokt, ,ECS APR 2 7 Z015 Whitney Pettus (Ahernate•Kevin Parks) BP Alaska-Well Integrity Coordinator GWc,CYgan:at.on WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com 1 Injector A-31A (PTD#1990560) 90 day TIO Plot April 25, 2015 won A-31 4300 3000 -.-1h t A 2 W -04 004 -r-0004 —00 ___ 022515 039415 33'i'5 M+415 032515 001 15 040y1S 041515 042215 Injection Plot w..411 2., 5 AO AC 920' ........ lelpik 1111110yeast .-- . AO <500 640 4 AM AV 5410 yp AO 540 530 soO 400 „00 .A A5 '2W 420 AS 420 AO _94 380 zle00; —.4 :no3 -o. m —0. 2D :no no zx 200 440 ¶. 300 tp _430140 120 220 w Sx CO 420 2200 150 002515 010415 031115 93'1310 032515 040115 440011 041515 042455 XHVZE .? Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA ~ Diskettes, No.'~'' n Other, No/Type OVERSIZED .13' Logs'of various kinds , , ' ,., Other COMMENTS: Scanned by: ianna Vincent Nathan Lowell _ 13 TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 May 18, 2012 Mr. Jim Regg A AUG t 2.O1� Alaska Oil and Gas Conservation Commission _ 333 West 7 Avenue 1 Anchorage, Alaska 99501 3' I t Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A 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 • • BP Exploration (Alaska) Inc. j Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off I Report of Sundry Operations (10 -404) A -Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A -03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A -04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA _ 0.3 NA 1.70 7/19/2009 _.-. A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 ~ MEMORANDUM To~ Jim Regg ~ P.L Supervisor ~ ~Q 7I ~ ~ J t FROM: Lou Grimaldi Petroleum Inspector ~J State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 29, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC A-31 A PRUDHOE BAY LJNIT A-31A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv .~~P~-- Comm Well Name: PRUDHOE BAY LTNIT A-31A Insp Num: mitLG090726121440 Rel Insp Num: API Well Number: 50-029-21383-01-00 Permit Number: 199-056-0 / Inspector Name: Lou Grimaldi Inspection Date: ~/26/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~] A-31A Type Inj. ~/ T~ 8328 IA 340 2500 2440 2430 P.T.D 1990560 TypeTest SPT Test psi 2500 ~.~ 0 10 10 10 Interval 4YRTST P~' P ~ Tubing 6l0 610 610 610 Notes: 2•9 barrels pumped, good solid test. ~~,~ ~ ~~~ P~~s~~,~ z~ ~ z .~s ; ,~ ~ 2. ~, ~w _ ,; ,`(l " °"a A-~ I , , , . , f./ ~.J ;,' Wednesday, July 29, 2009 Page 1 of 1 STATE OF ALASKA A OIL AND GAS CONSERVATION COM ION REP T OF SUNDRY WELL OPEIONS 6 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing , ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 199-056 3. Address: ®Service - ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21383-01-00 - 7. KB Elevation (ft): 81 17' - 9. Well Name and Number: . PBU A-31A 8. Property Designation: 10. Field /Pool(s): ADL 028286 &047472 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary 11, f~~ 1 ~/ Total depth: measured 10593' - feet true vertical 9080' - feet Plugs (measured) 10450' .~ ~.~ N ~ ~; ~,(~~~ Effective depth: measured 10523' feet Junk (measured) None ' s~a Di{ ~ ~~~ 4f1~. ~~tnRtisSiaO ~1 true vertical 9036 feet 8 Casing Length Sixe MD TVD B~s~hpfp~~ Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2668' 13-3/8" 2668' 2668' 4930 2670 Intermediate 9513' 9-5/8" 9513' 8784' 6870 4760 Production Liner 339' 7" 9248' - 9587' 8552' - 8847' 7240 5410 Liner 1313' 2-7/8" 9270' - 10590' 8572' - 9078' 13450 13890 Scab Liner 6335' 7" 7240 5410 2862' - 9197' 2862' - 8507' t/~ tt~; _ ~s r;~p g{~ ~{ ~~~ 61 ~ ~ ~ V 4 ~.. Nd b ~r~" Perforation Depth MD (ft): Above Plug: 10010' - 10374' Perforation Depth TVD (ft): 8907' - 8941' 4-1/2", 12.6# & L-80 9087' Tubing Size (size, grade, and measured depth): 41/2" 17 fi# NT1~rrR0 - Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer; 9001 ; ~~ 9222' 9-5/8" x 4-1/2" TIW'HBBP' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pulled tubing from 9193'. Run 7" scab liner and cement w/ 186 Bbls Class 'G' (Yield 1.16). Cut, pull and mill9-5/8" to _1971'. Run 9-5/8" tieback to 1974' and cement w/ 142 Bbts Class 'G' field 1.16. Ran tubin RDMO. Pulled WRP st ri . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: [] Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ^ Oil ^ Gas ^ WAG ^ GINJ ®WINJ ^ WDSPL 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: Contact David Bjork, 564-5683 309-107 Printed Name Terrie Hubble Title Drilling Technologist ff~V!~~ Prepared By Neme/Number. Signature Phone 564-4628 Date W ~ Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~ ,,J Submit Original Only C~ A-31 A, Well History (Pre Rig Workover) Date Summary 5/8/2009 WELL SI ON ARRIVAL. DRIFT TO 9 251' SLM W/ 3 70" CENT 3.50" LIB. (IMPRESSION OF 4-1/2" W RP SHEAR STUD) RIH W/ 3.50 DUMP BAILER, UNABLE TO PASS STA.4 C 6775' MD/6770' SLM. OOH W/ EMPTY D. BAILER, RIH W/ 4 1/2" BL BRUSH 3.25" G. RING. 5/9/2009 BRUSHED FROM 6,770' SLM TO 9,247' SLM W/ 4-1/2" BLB & 3.25" G-RING. RAN 3.50" x 10' D. BAILER, 2.80" SWEDGE & DUMPED SLUGGITS C~3 9,247' SLM. RAN 3.70" CENT., 10' D. BAILER, 2.80" SWEDGE DUMP SLUG ITS ~ 9.243' SI_M. LEFT WELL SI, PAD OP NOTIFIED. 5/10/2009 WELL SI ON ARRIVAL. INITIAL T/I/0=350/150/0 C~l1T d .~,"_TI IRIN(, T BELOW THE BOTTOM GAS LIFT MANDREL AT 9193' USING A 3.65" POWERCUTTER. GOOD INDICATION OF FIRING SEEN. WELL LEFT SHUT IN, WING, SWAB CLOSED; MASTER, SSV OPEN; CASING VALVES OPEN TO GAUGES. DSO NOTIFIED. FINAL T/I/0=900/150/0 JOB COMPLETE. 5/11/2009 T/I/O = 870/100/25. Temp = SI. Bleed WHPs to 0 psi (RWO prep). TBG FL C~3 surface. Bled TP to production using well A-15 from 870 psi to 350 psi in 5.5 hrs, during bleed IAP decreased 90 psi. IA FL near surface, bled IAP from 10 psi to 0+ psi in 15 min. OA FL near surface, bled OAP from 25 psi to 0 psi in 2 min. IA & OA FL unchanged. Monitored for 30 min, TP increased 10 psi. Final WHPs= 360/5/0+. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 5/11/2009 OA Flange replacement. T/I/O = 350/150/5 Removed 3 1/8 ANSI flange and replaced with 3 1/8 5K API flange. Torqued studs and nut to spec and pressure tested flange to 5000 psi for 15 min. Test passed. 5/12/2009 T/I/0= 580/60/20 Temp=S/I Circ out. CMIT TxIA FAILED to 1000 psi CMIT TxIA PASSED to 500 osi ,r, 4RW(1 ~?„n)- Pumped 5 bbl neat meth spear, 968 bbls 9.8 Brine, 2 bbls neat meth, 35 bbl 90° DSL F/P & 2 bbls neat meth, down TBG. Taking returns up IA, down hardline jumper to well #15. Pumped 3 bbl DSL flush down jumper line to well #15. U-tube DSL from TBG to IA. CMIT-TxIA to 1000 psi, Pumped 1.5 bbls diesel down TBG to reach TBG/IA pressures of 1000/750 psi. TBG/IA lost 420/250 psi in the 1st 15 mins, Bumped pressures and let pressures equalize. TBG/ IA equalized at 680 psi. Pumped TBG/IA back to 1000/790 psi with 2.6 bbls. TBG/IA lost 440/340 during the 1st 15 mins. Pumped down TBG again to reach TBG/IA was 1100/1000 psi IA pressure began to fall off immediatly. TBG/ IA lost 560/540 psi in 15 mins. CMIT-TxIA to 500 psi Attempted test 3 timers Passed oer PE 3rd test. Pumped 0.8 bbls to bump TBG/IA pressures to 540/500 psi. TBG/IA lost 20/30 psi in the 1st 15 mins and 20/30 psi in the 2nd 15 mins Carried test additional 15 min with aTBG/IA loss of 40 j. Bleed WHPs to 0.. FWHPs= 0/0/0 5/13/2009 T/I/O=SSV/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Opened slotted bleeder screw to verify 0 psi in void, bled to 0 psi. Removed internal check, installed Alemite external check. Functioned LDS, all moved freely (2.5"). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Opened slotted bleeder screw to verify 0 psi in void, bled to 0 psi. Removed internal check, installed Alemite external check. Functioned LDS, found 1 blank and 2 stuck LDS. Removed blank LDS, nose of pin has been removed. Tapped threads and installed new LDS assembly, Freed up 2 stuck LDS and installed new assembly's. Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 5/13/2009 T/I/0= SSV/0/0. Temp= SI. Assist Cameron with PPPOT-T & IC. Change out 3 LDS and pack off~est , SV, WV, SSV =Closed. MV =Open. IA, OA = OTG. NOVP. Page 1 of 1 • BP EXPLORATION Page 1 of 14 Operations Summary Report Legal Well Name: A-31 Common W ell Name: A-31 Spud Date: 6/30/1985 Event Nam e: WORKO VER Start : 5/14/2009 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 5/31/2009 Rig Name: DOYON 16 Rig Number: Date ' From - To Hours Task ! Code NPT Phase Description of Operations 5/14/2009 17:00 - 18:30 1.50 MOB P PRE Bridal Up, R/D Floor, R/D Slop Tank. 18:30 - 19:30 1.00 MOB P PRE Move Rig off of well Y-16 and stage on pad. 19:30 - 21:30 2.00 MOB P PRE Install BOP stack onto traveling stand. Lower Derrick. 21:30 - 00:00 2.50 MOB P PRE Install front and rear booster wheel assemblies. 5/15/2009 00:00 - 06:30 6.50 MOB P PRE Move around corner to front side of Y-pad. Haul mats from behind rig. Having problems with booster wheel system, troubleshoot system. Unable to get rear booster wheels to lower to the ground. Check jack pressure and able to safely move without rear boosters. 06:30 - 08:00 1.50 MOB P PRE Wait on Security to get approval to move rig at the same time Nordic 1 is moving. 08:00 - 00:00 16.00 MOB P PRE Begin moving rig from Y-pad to A-pad. Snow drifts on either side of road from Y-pad to H-pad are too hardened to allow rig to pass safely. Bring out equipment and remove snow drifts. Resume moving to A-pad. Rig on A-pad at 23:30 hour. 5/16/2009 00:00 - 01:00 1.00 MOB P PRE Lay mats on access road to back side of A-pad and move rig to back side of A-pad. 01:00 - 02:30 1.50 MOB P PRE Transfer BOP Stack from traveling stand to BOP pedestal in cellar. Remove booster wheel assemblies. 02:30 - 03:30 1.00 MOB P PRE Inspect derrick. Raise derrick and pin in place. 03:30 - 05:00 1.50 MOB P PRE Spot rig over well A-31 ai. Notified A-pad operator before backing over well, BP WSL and Doyon Toolpusher were present while spotting over well. 05:00 - 08:30 3.50 MOB P PRE Spot Cuttings tank. Install secondary annulus valve on IA. RU OA to bleed to slop tank. RU cellar circulating manifold. RU suction line from slop tank to Vac Truck. Begin taking on 9.8-ppg brine to pits. Rig Accented at 0800-hrs. 08:30 - 09:30 1.00 WHSUR P DECOMP PJSM on pulling BPV PU DSM lubricator and test to 500-osi. Good test. Pull BPV. LD lubricator and BPV. 09:30 - 10:00 0.50 WHSUR P DECOMP RU to circulate out freeze protection and kill well. PJSM with rig crew and CH2MHill truck drivers about circulation. Assign monitor to Slop tank. 10:00 - 13:00 3.00 WHSUR P DECOMP Test lines to 3500-psi. Good test. Pump 20-bbl Hi Vis sweep at 2-BPM with 430-psi. Chase at 6-BPM with 1990-psi. Circulate 1-wellbore volume plus a tubing volume. See minimal crude returns for OA while circulatin .Did not see sweep come back. After getting 9.8-ppg brine back and taking returns back to pits, see some fine, white, sand-like material across shakers. 13:00 - 13:30 0.50 WHSUR P DECOMP Monitor well -Static. RD circulating lines. Drain tree. 13:30 - 15:30 2.00 WHSUR P DECOMP rep t-bar in TWC RU to test TWC AttemptlQl~t Cameron _ below to TWC to 1000-psi. Unable to test. Keep pump rolling at 1.6-BPM and hold 870-psi for 10-charted minutes. Pump a total of 15-bbls over course of test. Test TWC above to 4000-psi. Good test. RD Test Equipment. 15:30 - 16:00 0.50 WHSUR P DECOMP RD test equipment, cellar manifold and blow down lines. 16:00 - 18:00 2.00 WHSUR P DECOMP Hold PJSM on ND tree with rig crew and Cameron reps. RU to pull tree with blocks. ND tree and remove from cellar. Two barriers for ND are Weatherford Plug at 9259' and tested TWC in tubing hanger. 18:00 - 20:30 2.50 BOPSU P DECOMP Hold PJSM on N/U BOPE. N/U BOPE, N/U Choke and Kill lines, N/U Koomey Lines, Hook up turnbuckles and adjust. Install flow riser and function test BOPE. Nnnted: eisizous 11:3 /:3S AM • BP EXPLORATION Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Event Name: WORKOVER Start: 5/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 5/31/2009 Rig Name: DOYON 16 Rig Number: pate I From - To !Hours Task Code I NPT I Phase 5/16/2009 20:30 - 00:00 3.50 BOPSU P 5/17/2009 00:00 - 02:00 2.00 BOPSU P 02:00 - 03:00 ~ 1.00 ~ BOPSUF{ P 03:00 - 03:30 ~ 0.50 ~ PULL ~ P 03:30 - 04:30 I 1.001 PULL I P 04:30 - 05:00 0.50 PULL P 05:00 - 14:30 9.50 PULL P 14:30 - 16:00 I 1.501 PULL I P 16:00 - 16:30 I 0.501 CLEAN I P 16:30 - 19:30 I 3.00 I CLEAN I P 19:30 - 00:00 ~ 4.50 ~ CLEAN ~ P 5!18/2009 00:00 - 05:00 5.00 CLEAN P 05:00 - 05:30 0.50 CLEAN P 05:30 - 07:30 I 2.00 {CLEAN I P Page 2 of 14 Spud Date: 6/30/1985 End: Description of Operations __ _ _ - _ _ - DECOMP ~ Perform initial BOPE test per BP procedures and AOGCC re s. Test 3-1/2" x 6" VBRs using 4" & 4-1/2" test jts. Test to 250-psi low and 4,000-psi high. Test annular to 250 psi low and 3,500 psi high using the 4" test jt. Hold and chart each test for 5-minutes. AOGCC witness of test was waived by Chuck Scheve, test was witnessed by BP WSL and Doyon Toolpusher. DECOMP Perform initial BOPE test per BP procedures and AOGCG regs. Test 3-1/2" x 6" VBRs using 4" & 4-1/2" test jts. Test to 250-psi low and 4,000-psi high. Test annular to 250 psi low and 3,500 psi high using the 4" test jt. Hold and chart each test for 5-minutes. Perform Koomey test. AOGCC witness of test was waived by Chuck Scheve, test was witnessed by BP WSL and Doyon Toolpusher. DECOMP M/U DSM lubricator and test t 500 si. Pull Cameron 4" T e H TWC. 0 psi on tbg and IA. R/D DSM lubricator. DECOMP M/U landing joint and screw into hanger 7-1/2 turns. Back out lock down screws, Pull hanger to rig floor. Came off seat at 140K, P/U 155K. DECOMP Circulate bottoms up at 10 bpm with 550 psi. R/U tubing handling equipment, R/U schlumberger control line spooler. DECOMP UD landing joint, UD hanger. DECOMP POOH laying down 4-1/2" completion and dual encapsulated control line. At 0830-hrs, RD schlumberger control line spooler. Recover 25-protector clamps and 3-SS bands of reported 25-protector clamps and 4-SS bands. Missing 1-SS band. Encapsulation in good shape, none left in well. Continue POH & LD 4-1/2" completion. At timesLs_eeina white residue on exterior of i e. Connections appear to be in good condition, but do not take much torque to break. Recover 231-jts of 4-112" tubing, 1-SSSV asst', 5-GLMs, and 1- 4-1/2" tubing cut jt. Cut Jt = 2.04' long and 5" OD with a fairly clean cut. DECOMP Function rams and annular to check for missing SS-band. Did not see it. RD all 4-1/2" handling equipment and power tongs. Clean and Clear rig floor. Install wear bushing. DECOMP Bring BHA #1 components to rig floor. Hold PJSM on PU BHA #1 and PU DP from pipe shed. DECOMP MU BHA #1 t2dress off 4-1/2" tubing stub and scrape 9-5/8" casin .BHA consists of Dress off shoe, Washpipe extension, Internal Mill, Washover Boot Basket, 9-5/8" Casing Scraper, Bumper Sub, Oil Jar, 9 (ea) 4-3/4" DCs and Pump Out sub. Total length = 319.94' DECOMP RIH with Dress-Off BHA #1 picking up 4" HT-38 drill pipe from pipe shed from 319' to 3,929'. Scrape packer setting area from 2,839' to 2,965' three times. DECOMP RIH with Dress-Off BHA #1 picking up 4" HT-38 drill pipe from pipe shed from 3,929' to 9,144' DECOMP M/U Top Drive and establish parameters: P/U 190K, S/O 152K, Rotating weight 170K, 5 bpm at 570 psi, 60 rpm with 5,000 Wlbs of torque. Wash from 9,144', tag u at 9,193' DECOMP Dress tubing stub to 9,193 (shoe epth , WOM 2K, 60 rpm with 6,000 ft/Ibs of torque, 5 bpm with 570 psi, dress off assembly Printed: 6/8/2009 11:37:35 AM i ! BP EXPLORATION Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING 1NC Rig Name: DOYON 16 Start: 5/14/2009 Rig Release: 5/31 /2009 Rig Number: Date From - To Hours Task I Code NPT Phase 5/18/2009 05:30 - 07:30 2.00 CLEAN ~ P 07:30 - 10:30 I 3.001 CLEAN I P 10:30 - 13:00 ~ 2.50 ~ CLEAN ~ P 13:00 - 15:00 ~ 2.00 ~ CLEAN, ~ P 15:00 - 16:00 ~ 1.00 ~ EVAL ~ P Page 3 of 14 ~ Spud Date: 6/30/1985 End: Description of Operations DECOMP has 5.31' of swallow over tubing stub. PU off of tubing stump and see 15K-Ib overpull 5' above where dressing, indicating that the dress off shoe had passed over the tubing stump without tagging. Repeat PU and slide over x2 with same results. This puts the tubing stump at 9188'. Appear to dress off 6 - 8 inches. DECOMP Pump 20-bbl Hi Vis Sweep. Chase at 10-BPM with 1960-psi. Seeing heavy returns of cretaceous leak sgeezing material. Pump another 20-bbl Hi Vis Sweep and chase at 12-BPM with 2660-psi. Circulate until returns clean up, with minimal material across shakers. DECOMP Monitor well -Static. Blow down Top Drive. POH. LD 2-jts of DP to pipe shed and then stand back 93-stds of DP in derrick. DECOMP Stand back 3-stds of 4-3/4" DCs. LD BHA #1. No wear on tattle-tales below inner dress off mill. Wear on stinger and on dress off shoe indicating the shoe passed over the stub and the stinger was inside the stub. Appears that when attempting to dress the top of the stub, the K-anchor began spinning, Discuss situation with RWO engineer and decide to move ahead, as a mill will be run through the tubing stub during drill out. Finish LD BHA #1. Recover 1-SS band and -1-cup of Scale/ Stopleak mix (all SS-bands recovered) in boot basket. DECOMP PU HES 9-5/8" 47# RTTS dressed with circ valve. MU tailpipe below RTTS using Johnny Wacker and 2-XOs to catch DP drift. 16:00 - 17:30 1.50 EVAL P DECOMP RIH with 9-5/8" RTTS on 3-stds of 4-3/4" DCs and 29-stds of 4" DP from derrick. 17:30 - 18:30 1.00 EVAL P DECOMP Set 9-5/8" HES RTTS at 3042'. RU to test 9-5/8" csg above RTTS. Test surface lines. Good test. Test 9-518" casin o 4000-psi for 30-minutes. Good test. 18:30 - 19:00 0.50 EVAL P DECOMP Release RTTS and circulate bottoms up at 10 bpm with 760 19:00 - 20:30 I 1.50 I EVAL I P 20:30 - 21:00 I 0.50 I EVAL I P 21:00 - 22:00 1.00 CLEAN P 22:00 - 00:00 2.00 CLEAN P 5/19/2009 100:00 - 01:00 1.001 CLEAN ~ P 01:00 - 02:00 1.00 CLEAN P 02:00 - 04:00 2.00 CLEAN P 04:00 - 05:30 I 1.501 CLEAN I P 05:30 - 08:30 I 3.001 CLEAN I P DECOMP Break out and blow down Top Drive and POOH standing back 4" HT-38 drill pipe in derrick. DECOMP Break out and L/D HES 9-5/8" 47# RTTS. All slips and sealing element were intact. DECOMP M/U BHA #2, Dress Off assembly. DECOMP RIH with Dress Off BHA #2 on 4" HT-38 drill pipe from 312' to 4,682' DECOMP RIH with Dress Off BHA #2 on 4" HT-38 drill pipe from 4,682' to 9,137' DECOMP Slip and cut 75' of drilling line. DECOMP M/U Top drive and establish parameters. P/U 190K, S/O 150K, Rotating weight 170K, 5 bpm at 540 psi, 50 rpm with 5,000 ft/Ibs of torque. Tag top of tubing stub at 9,193'. Work over top of stub. 60 rpm at 5,000 - 7,500 ft/Ibs of torque, 2-4K WOM, Vary pump rate from 3 bpm to 6 bpm. Wash over stub to 9,198', 5' of swallow on assembly. Mill 3-4" off of too of stub at 9,193'. Slide over stub several times to insure that we can et Unique overshot over stub. DECOMP Circulate 20 bbl sweep around at 11 bpm at 2,270 psi. No noticeable increase in returns. DECOMP Break out and blow down Top Drive, POOH standing back 4" Printed: 6/8/2009 11:37:35 AM • BP EXPLORATION Page 4 of 14 Operations Summary Report Legal Well Name: A-31 Common W ell Name: A-31 Spud Date: 6/30/1985 Event Nam e: WORKO VER Start : 5/14/2009 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 5/31/2009 Rig Name: DOYON 16 Rig Number: Date i i From - To I Hours Task I Code' NPT it Phase Description of Operations 5/19/2009 05:30 - 08:30 3.00 CLEAN P DECOMP HT-38 drill pipe in derrick. At std #44, drop DP rabbit. 08:30 - 09:30 1.00 CLEAN P DECOMP Stand back 3-stds of 4-314" DCs. LD BHA #2. Recover 2-cups of metal shavings and scale in boot basket. Recov_e_r DP rabbit with no problem._ 09:30 - 10:00 0.50 CLEAN P DECOMP Clean & Clear rig floor. 10:00 - 14:00 4.00 CASE P TIE61 Load, Strap and drift 6-1/8" DCs. Load and tally 7" Scab liner jewelry. RU to run 7" 26# L80 BTC-M Scab liner. Hold PJSM on running scab liner with rig crew, Doyon Casing rep and Baker liner rep. Discuss hazards, positions of people, repetitive tasks and running order. External EMS auditors visit the rig and interview WSL & motorman. 14:00 - 15:00 1.00 CASE P TIEB1 RIH with 7" Scab tailpipe. Tailpipe consists of Unique Overshot, 4-1l2 x 7" XO, 1-jt of 7" 26# L80 BTC-M csg, HES float collar, 1-jt of 7" 26# L80 BTC-M csg and Baker Insert landing collar in the pin end of another full jt of csg. BakerLok all connections below the insert landing collar. MU BTC-M connections to the mark. Check floats -good. 15:00 - 22:30 7.50 CASE P TIEB1 RIH with 154-'ts of 7" 26# L80 BTC-M scab liner. Use Best-O-Life 2000 thread compound. MU BTC-M connections to mark. Install one free-floating centralizer perjoint. Fill casing "on the fly" and top off every 5-jts. 22:30 - 23:30 1.00 CASE P TIEB1 RIH with liner on 11-jts of 6-1/8" DCs. RU to circulate. 23:30 - 00:00 0.50 CASE P TIEB1 Circulate liner volume at 5-bpm with 290-psi. 5/20/2009 00:00 - 00:30 0.50 CASE P TIEB1 Finish circulating liner volume at 5-bpm with 370-psi. 00:30 - 01:30 1.00 CASE P TIEB1 RIH with 7" Scab liner and 11-jts DCs on 26-stds of 4" DP_from derrick. PU wt = 255K-Ibs, SO wt = 206K-Ibs. 01:30 - 02:30 1.00 CASE P TIE61 PU std #27 and RIH. Tag tbg stub at 9193'. Travel 2' and set down 30K-Ibs. Observe shear. Continue RIH and no go at 9200'. PU off of stub and run back in to confirm no-go with 30K-Ibs down at 9200'. Calculate space out. Stand back std #27. PU single jt of DP &RIH. MU cement head. RIH and s ace out mouth of OS at 9198' 2' off of no- o . 02:30 - 03:30 1.00 CEMT P TIEB1 Hold PJSM on cementing with Schlumberger cementers, CH2MHill truck drivers & pusher, Rig Crew, Baker liner rep, BP WSLs and Doyon tourpusher. Discuss cementing plan, hazards, assign people to positions. Circulate at 5-BPM with 270-psi during safety meeting. Schlumberger prime up their pumps. 03:30 - 04:00 0.50 CEMT P TIEB1 Troubleshoot stroke counter malfunction. 04:00 - 06:30 2.50 CEMT P TIEB1 Turn over to Schlumberger. Pump 5-bbls of water to PT lines to 4500 psi & check stalls. Good tests. Start pumping 15.8-ppg Class G cement (1.16 cu ft/sk yield) downhole at 0415-hrs at 5-BPM with 600-psi. At 50-bbls away, pumping at 5-BPM with 600 psi. At 100-bbls away, pumping at 5 BPM and 650 psi. At 150 bbls away pumping 5 BPM Cu? 650 psi 1~^86~ bbls awa full 'ob . Pump 5 bbls water to flush Dowell lines, swap lines & pump 10 bbls to drop plug. Visual indication plug fell. Bring pumps on at 8-BPM and catch lu w'th 1 1- I dis acement um ed. Slow pumps to 5-BPM, then to 2-BPM and finally to .75-BPM to keep pressure below 3100-psi. Bump plug at 3012-stks pumped with 3000-psi. Slack off 20K-Ibs over string weight and confirm liner hanger is set. CIP at 0603-hrs. Pressure up to 4000-psi and set packer. Bleed Printed: si~zooa n:~rssann BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Spud Date: 6/30/1985 Event Name: WORKOVER Start: 5/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/31/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours ' Task Code', NPT ' Phase Description of Operations 5{2012009 04:00 - 06:30 2.50 CEMT P TIE61 pressure off and check floats -floats holding. Release running tool. 06:30 - 07:00 0.50 CEMT P TIE61 Pump 50-bbls at 14-BPM with 1270-psi. Confirm packer set. 07:00 - 08:00 1.00 CEMT P 08:00 - 09:30 1.50 CEMT P 09:30 - 10:00 0.50 CEMT P 10:00 - 10:30 0.50 CEMT P 10:30 - 11:30 1.00 CEMT N 11:30 - 12:00 0.50 CEMT P 12:00 - 13:30 1.50 CEMT P 13:30 - 14:30 1.00 CEMT P 14:30 - 15:00 0.50 CEMT P 15:00 - 16:00 1.00 DRILL P 16:00 - 18:30 2.50 DRILL P 18:30 - 19:30 1.00 DRILL P 19:30 - 21:30 2.00 WHSUR P 21:30 - 22:00 ~ 0.50 ~ WHSUR ~ P 22:00 - 00:00 I 2.001 WHSUR I P 5!21!2009 { 00:00 - 01:00 { 1.00 {WHSUR { P 01:00 - 01:30 I 0.501 WHSUR I P 01:30 - 03:00 1.50 BOPSU P 03:00 - 04:30 1.50 WHSUR P 04:30 - 06:00 1.50 BOPSU P 06:00 - 09:30 3.50 WHSUR P Circulate citric sweep out of hole, monitoring for cement returns. See approximately 20-25 bbls of good cement at surf c TIE61 LD cement head. TIEB1 POH w/liner running tool. Stand back 26-stds of DP and 3-stds of 6-1/8" DCs to pipe shed. TIE61 Flush BOP stack, Choke & Kill lines with Citric pill. TIEB1 Hold meeting with Doyon Board members and Tower crew. RREP TIEB1 Repair hose reel on pipe skate. TIE61 LD 2-jts of 6-1/8" DCs and Liner Running tool to pipe shed. TIEB1 RIH with 3-stds of 6-1/8" DCs. POH, laying down same to pipe shed. TIEB1 PU BOP stack washer and RIH, washing BOP stack. Drain stack and pull riser. Clean as needed and check air boots. TIEB1 PU cement head and break out all rig equipment (TIW valve, pup & XOs). TIEB1 PJSM on MU BHA #3 BHA consists of: 6.125" tricon it, two (2) 4.75" boot baskets, casing scraper (7"), bumper sub, nine (9) 4.75" spial collars. TIEB1 RIH with BHA #3 to 8368' TIE61 PU storm acker and set same 1 stand below rota 175k# up wt, 140k# down. Packer tested to 1000 psi for 10 charted minutes. LD running tool w/diaper TIEB1 Pull wear bushing and pull 9.625" mandrel packoff throwtl BOPs. Packoff came free with approximately 25k#. ca^ sing started to grow as final lock down pins were being backed out. Old packoff showed old (not shiny internal damage) and new (shiny) scars frm several LDS. Unable to seat new packoff as casing relaxed from compression =4r Set too drive down on packoff running tool unable to see any part of new packoff ~eerinq through open LDS hole. TIEB1 Discuss options with Driller/Tour Pusher/Halliburton/Cameron. Decision made to unseat storm packer, SB 4 stands drill_piLe, PU 11 6" drill collars and reset storm packer for -20k net wei ht ain to attem t to force casin back down w/o breakin P ck. TIEB1 Unseat storm packer & break circulation to ensure circulating valve clear prior to LD same. SB 4 stands drill pipe, PU 11 6" collars. TiEBi PU storm packer and set 1 stand below rotary table. Still una a to set man re pac o wit top nve weight on running tool & -20k# more weight. Decision made to ND BOPs and reassess. TIE61 Pressure test acker to 1000 si for 10 ch rt s 2 tested barriers are WRP/ acker & storm ac TIEB1 ND BOPs & tubing spool. New Packoff seals damaged. T1EB1 Re-dress packoff seals. Attempt to force packoff down by setting stack weight on it without success. Remove packoff. TIEB1 NU BOP stack. TIEB1 Consult w/ town reaardinq plan forward. Ord .r rnld lake water Nrinted: tics/zuua 11:3 /:3D AM • BP EXPLORATION Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To Hours .Task 'Code, NPT 5/21/2009 06:00 - 09:30 3.50 WHSUR P 09:30 - 15:00 ~ 5.50 ~ WHSUR ~ P 15:00-15:30 ~ 0.50~WHSUR~P Start: 5/14/2009 Rig Release: 5/31/2009 Rig Number: Page 6 of 14 ~ Spud Date: 6/30/1985 End: Phase Description of Operations TIEB1 trucks and locate sufficient drill colt - off of storm packer. Perform light maintenance and housekeeping throughout rig. TIE61 MU Storm Packer retrieving tool and RIH. Engage packer, check for PSI and break circulation. Set Storm packer. minutes. When pressured up, gettin fluid returns from OA. Returns increase when pressure is applied and continue even after multiple pressure cycles. Install gauge and sensor on OA and chart test pressure and OA at same time. Chart shows OA tracking exactly with area bein tested. Drain B sac an observe as test pressure is applied. See returns from the 13-3/8" around the 9-5/8" casing and mandrel hanger. 9.625" leaking. Notify RWO engineer of situation. TIEB1 Release storm packer. Allow elements to relax. Close annular preventer and test BOP stack, flange break, 9-5/8" casing, 7" scab to float a ui ment and OA to 2000- si for 10-chartetl minutes. Good test 15:30 - 16:00 0.50 WHSUR P TIE61 POH. Stand back 1-std & inspect storm packer. Packer elements are in "like new" condtion. LD storm packer to pipe shed. 16:00 - 19:00 3.00 WHSUR P TIEB1 PU 1-std of DP. MU to string and RIH. MU to Top Drive and CBU at 10-BPM with 1800-psi. Get large amount of crude and gas breaking out in returns. Continue to circulate at 10-BPM with 2000-psi and then reduce rate to 6-BPM with 700-psi. Pressure on OA while circulating = 0-psi. 19:00 - 19:30 0.50 WHSUR P TIEB1 Monitor well -Static. Discuss plan forward with town to cut and pull 9-5/8" casing to repair leak. Close annular preventer and test BOP stack, flange break, 9-5/8" casing, 7" scab to float equipment and OA to 2500 psi for 10-charted minutes as MASP is 2440 si. Good test. 19:30 - 23:30 4.00 WHSUR P TIEB1 POOH LD 11-jts of 6" collars. Stand back 4" DP in derrick. 23:30 - 00:00 0.50 WHSUR P TIEB1 LD BHA #3 - 7" drill out. 5/22/2009 00:00 - 00:30 0.50 DRILL P TIEB1 Finish LD BHA #3. 00:30 - 01:30 1.00 EVAL C TIEB2 PU & MU 9-5/8" RTTS. RIH and set at 1052' (COE). 01:30 - 02:30 1.00 EVAL C TIEB2 RU to pressure test below RTTS. Pressure test below to 1000-psi for 5-minutes. Bring pressure up to 4000-psi and hold for 30-charted minutes -Good test. 02:30 - 03:00 0.50 EVAL C TIEB2 Release RTTS. POH. Stand back DP in derrick. LD RTTS. 03:00 - 04:00 1.00 EVAL C TIEB2 Hold PJSM with Schlumberger and crew on RU E-line. RU Schlumberger E-line. 04:00 - 06:30 2.50 EVAL C TIEB2 Schlumberger USIT log from 2500' to surface. 06:30 - 07:00 0.50 EVAL C TIEB2 RD E-line unit. 07:00 - 08:00 1.00 DHB C TIE62 Wait for Halliburton to arrive with 9-5/8" RBP. 08:00 - 09:30 1.50 DHB C TIEB2 RIH with 9-5/8" HES RBP on 19-stds of DP. 09:30 - 10:00 0.50 DHB X WAIT TIEB2 Wait on USIT log to pick TOC and set depth for RBP. 10:00 - 11:30 1.50 DHB C TIEB2 RIH with 2-more stds of 4" DP to park RBP at -2100'. Confirm set depth with RWO engineer. Set RBP with COE at 2106 '(COE and 2101' (Top of RBP . Stand back 1-std of DP. RU and pressure test RBP to 1000-psi for 10-charted minutes - 11:30 - 16:00 4.50 DHB C TIEB2 Blow down Top drive. Dump 2200# (44-sks) of 20/40 mesh river sand down DP. Pump DP volume at 1-BPM to clear pipe. Printed: 6/8/2009 11:37:35 AM BP EXPLORATION Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 I Date From - To Hours I, Task Code NPT 5/22/2009 11:30 - 16:00 4.50 ~ DHB C 16:00 - 17:00 1.00 DHB C 17:00 - 18:00 1.00 FISH C 18:00 - 20:30 I 2.501 FISH I C 20:30 - 21:30 1.00 FISH C 21:30 - 22:30 1.00 FISH C 22:30 - 23:30 1.00 FISH C 23:30 - 00:00 0.50 FISH C 5/23/2009 00:00 - 01:30 1.50 FISH C 01:30 - 05:30 4.00 FISH C 05:30 - 06:00 0.50 FISH C 06:00 - 10:00 4.00 FISH C Page 7 of 14 Spud Date: 6/30/1985 Start: 5/14/2009 End: Rig Release: 5/31/2009 Rig Number: Phase ', Description of Operations TIEB2 Allow sand to settle for 1-hr. PU 1-std DP. RIH and tag TOS at 2083' 18' of sand on top of plug). Stand back 1-std DP. Allow sand to fall for 1/2-hr. PU 1-std DP and RIH. Tag TOS at 2068'. TIE62 POH. Stand back DP in derrick. LD HES RBP running tool. TIE62 Hold PJSM on MU Csg Cutter BHA, MU Csg Cutter BHA. BHA consists of: 8-1/4" Multi String Cutter, XO, 8-1/2" Stabilizer and XO back to DP. Total BHA length = 12.6'. TIE62 RIH w/ Csg Cutter BHA on 4" DPfro_m derrick to -1970', Locate collars and cut pipe C~? 1970'. Immediate fluid swap, open up to external tank through choke trailer. Circulate 133 bbls 9.8 ppg brine TIE62 Monitor well, stable. POOH to 1890' TIE62 Start to RU new 9-5/8 casing tongs. Move 3 stands of collars to other side of derrick to attempt to make room. Shut down and then RD tongs after determining they are too large for rig floor and a hazard to RU/RD. TIEB2 POOH from 1890' to surface and LD casing cutter assembly. TIEB2 MU 9.625" packoff and spear assembly TIEB2 Engage 9.625" casing and pull to floor. LD mandrel csg hanger. MU top drive to DP & 9-5/8" swedge. TIE62 RU LRS and hot brine to circ out arctic pack through choke trailer to open top tank. Pump 60 bbls 90 degree diesel, 40 bbl soap pill, and 50 bbls 120 degree 9.8 ppg brine to spot diesel just around corner in OA. Allow to soak for 30 minutes. Pump 60 more bbls 120 degree 9.8 ppg brine and soak upper half of OA for 30 minutes. Pump remaining 180 bbls hot brine out ~ 9 bpm. Brine looked very clean after soap pill hit surface. TIEB2 Blow down top drive. RU rig tongs, 9-5/8" elevators and casing tongs. TIEB2 POH & LD 9-5/8" casing to ~t R .over 4g-jts 1-r.~tjt t R 7d' long and 15-Turboclamps. Average breakout torque for BTC connections = 40K-Ibs. Cut flared to 10-5/8" with ragged_ 10:00 - 11:00 1.00 FISH C TIEB2 Clean and clear rig floor. 11:00 - 11:30 0.50 FISH C TIEB2 Bring BHA components to Rig floor. Strap 3 (ea) 6-1/4" DCs in pipe shed. 11:30 - 13:00 1.50 FISH C TIEB2 MU BHA #6 -Dress off 9-5/8" CscL BHA consists of 12-1/8" x 9-5/8" Dress off shoe, Washpipe Extension, Internal Dress off mill, Washover Boot Basket, Double Pin Sub w/float, 13-3/8" Csg scraper, Bumper Sub, 3(ea) 6-1/4" DCs and 3-stds 4-3/4" DCs. Total BHA length = 403.96'. 13:00 - 13:30 0.50 FISH C TIE62 RIH with BHA #6 on 4" DP from derrick. 13:30 - 16:00 2.50 FISH C TIEB2 Obtain milling parameters: PU wt = 83K-Ibs, SO wt = 85K-Ibs, Rot wt = 85K-Ibs. Rotate at 70-rpm with 2K-fUlbs of free torque. Pump at 6-BPM with 160-psi. Shut down rotation and RIH to tag 9-5/8" stub at 1970'_ PU and bring pump and rotation on at above rates. Continue RIH and no-go with inner mill at 1977'. Dress casing with above parameters and 5-10K-Ibs WOM with 2-8K-ft/Ibs of torque. Dress casing down to 1971'. Attempt to PU off of stub and see 20K-Ib overpull. Work mills until able to pass over stub with only 1/4-turn of rotation. Printed: 6/6/2009 11:37:35 AM • BP EXPLORATION Page 8 of 14 Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Spud Date: 6/30/1985 Event Name: WORKOVER Start: 5/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/31/2009 Rig Name: DOYON 16 Rig Number: Date From - To 'Hours Task ,Code NPT Phase 5/23/2009 16:00 - 17:00 1.00 FISH C TIEB2 17:00 - 19:00 2.00 FISH C TIEB2 19:00 - 20:30 1.50 BOPSU C TIEB2 20:30 - 22:30 2.00 BOPSU C TIEB2 22:30 - 00:00 1.50 BOPSU C TIEB2 5/24/2009 00:00 - 03:30 3.50 BOPSU C TIEB2 03:30 - 05:00 1.50 CASE C TIEB2 05:00 - 09:30 4.50 CASE C TIEB2 09:30 - 11:30 2.00 CASE C TIEB2 11:30 - 12:30 1.00 CEMT C TIEB2 12:30 - 14:30 2.00 CEMT C TIE62 14:30 - 15:00 0.50 CEMT C TIEB2 15:00 - 16:35 1.58 CEMT C TIEB2 Description of Operations Pump 20-bbl Hi Vis sweep and chase at 8-BPM with 400-psi. Light crude and scale returns from bottoms up through sweep. Metal millings seen on ditch magnets. Pump 20-bbl Safe Surf O sweep and chase at same rate. Monitor well -Static. Monitor well, blow down top drive. POOH & LD 9.625" dress off BHA. Lots of shavings in boot baskets Set test plug in 13-3/8" spool. RU to test BOPE PJSM to test 250 low/4000 high with 4" and 4-1/2" test joints. Lou Grimaldi w/ AOGCC waived witness. Leaking valve on tubing spool. DSM set VR plug in valve and leak shut off. Begin BOP test, details on next report. Continue BOP testing. Test annular preventer w/ 4" test joint 250 psi low/3500 psi high. Test remainder of BOPE to 250 psi low/4000 psi high with both 4" & 4.5" test joint. Test accumulator. Pull test plug RU to run 9.625" tieback, calibrate Torque-Turn. Run 9-5/8" 47# L80 Hydril 563 tieback casing. Use torque turn to MU connections to optimal MU torque of 15,200-ftlbs. Use Jet Lube Seal Guard thread compound on all connections. BakerLok connections below ES cementer. Install one free floating centralizer per joint. At 0530-hrs, shoe track RIH. Run a total of 50-jts with Bowen casing patch, Baker Isozone ECP and HES ES Cementer. PU wt = 120K-Ibs, SO wt = 125K-Ibs. MU XO from string to Top Drive. RIH. Tag Csg stub at 1971'. Slide over and set down 30K-Ibs. PU 30K-Ibs over. Set down 30K-Ibs and PU to 30K-Ibs again. Set down 50K-Ibs. PU to 50K-Ibs over. Slack off to 50K-Ibs again. PU and pull test casing patch to 250K-Ibs. Break out XO to Top Drive. LD short bails. RU long bails. RU scaffolding. MU HES cement head. Hold PJSM with all involved in cement job. PU on string to 100K-Ibs over string weight of 120K-Ibs. Hold overpull throughout cement job Pressure test rig lines to 4000-psi. Good test. Pressure up string to 1000-psi to pressure test patch for 10-charted minutes. Good test. Bring pressure up t_o 1300-psi and see ECP begin to inflate. Watch pressure drop to 900-psi and stabilize. Pressure back up to 1300-osi, taking .34-bbls to fill ECP. Pressure ug to 2000-osi and hold for 10-charted minutes. Good test. Bleed pressure to zero and then pressure up to 2900-psi to open ES cementer. Circulate heated 9.8-ppg brine at 5-BPM with 190-psi until return temperature is 80-degrees. Schlumberger pump 5-bbls of water and then pressure test their lines to 4000-psi. Pump 142.2-bbls of 15.8-ppg Class cement with 1.16 ft3/sk yield. Average pump rate of 3.2-BPM with 320-psi. Drop plug. Schlumberger kick plug out with 5-bbls of water. Swap over to rig pump and begin to displace at 6-BPM. Catch cement with 48.1-bbls displacement pumped. Continue at 6-BPM with max pressure of 1250-psi. Reduce rate to 4-BPM with 800-psi with 110-bbls pumped. Slow rate again to 2-BPM with 840-psi for final 18-bbls. Bumo gliin with 136.7-bbls displacement. Close ES cementer with 1700-psi and pressure up to 2100-psi. Hold for 2-minutes and then Printed: 6/8/2009 11:37:35 AM BP EXPLORATION Page 9 of 14 ~ Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To A-31 A-31 WORKO DOYON DOYON Hours VER DRILLIN 16 I Task INC Code . NPT Start Rig Rig Phase Spud Date: 6/30/1985 : 5/14/2009 End: Release: 5/31/2009 Number: Description of Operations 5/24/2009 15:00 - 16:35 1.58 CEMT C TIEB2 check floats -holding. CIP at 1631-hrs. Get 30-bbls of good cement returns to surface. 16:35 - 17:00 0.42 CEMT C TIEB2 Flush stack and OA line with 40-bbls of citric acid. 17:00 - 18:00 1.00 CEMT C TIEB2 LD cement head. Blow down choke and kill lines. Vac fluid out of 9-5/8" csg in preparation for Wachs cut. 18:00 - 18:30 0.50 BOPSU C TIE62 ND BOP stack. 2 barriers for ND are 1) tested RBP at 2101' and 2) tested 7" Shoe track. 18:30 - 20:00 1.50 WHSUR C TIEB2 PJSM. Set 9.625" emergency slips in 13-3/8 bowl, cut 9-5/8 casing and LD cut joint, 20:00 - 23:00 3.00 WHSUR C TIEB2 PJSM, install new tubing spool with seal installed. Torque bolts to recommended 2750 ft-Ibs. Cameron tested packoff to 3800 psi for 30 minutes, & pumped plastic. Test pressure based on 9.625" burst. Install riser and air up boots. 23:00 - 00:00 1.00 BOPSU C TIE62 Run test plug on test joint & set in tubing hanger. Run in 4 LDS. Test BOP break to 250 psi low, 4000 psi high for 5 minutes each. AOGCC rep Bob Noble waived witness of break test. RD test equipment, BOLDS, pull test plug 5/25/2009 00:00 - 00:30 0.50 BOPSU C TIEB2 RD test equipment, BOLDS, pull test plug. 00:30 - 02:00 1.50 DRILL C TIEB2 Install wear bushing & attempt to RILDS, LDS not seating. Try Examine test pluo. 4 obvious other LDS with same result. _ scars on metal, several marks on rubber seal. Call Cameron and inspect. 4 tips broken off, 2 still in bolt holes, 2 fell down hole. 02:00 - 04:30 2.50 BOPSU C TIEB2 PJSM, ND BOPs, Cameron rep tapped out nubs. PJSM & hot work permit to grind on tubing spool. Clean up spool. Install . Run new test plug on tugger and run in 4 LDS. Measure LDS in and out from flange (not gland nut). 04:30 - 06:00 1.50 BOPSU C TIEB2 NU BOPs, clear rig floor, prep to test 06:00 - 06:30 0.50 BOPSU C TIEB2 Set test plug. Test BOP break to 250- si low 4000- si hi h. o and chart each test for 5-minutes. 06:30 - 07:00 0.50 BOPSU C TIEB2 Pull test plug. Install wear ring. 07:00 - 07:30 0.50 FISH C TIEB2 RIH with 1-std 6-1/4" DCs and LD to pipe shed. 07:30 - 08:00 0.50 FISH C TIEB2 MU RCJB BHA to fish tips of 2-LDSs= BHA consists of 7-7/8" RCJB, 2(ea) 7" Boot Baskets, Bumper sub, Jar, Pump out sub, and 9(ea) 4-3/4" DCs. Total length = 316.04' 08:00 - 08:30 0.50 FISH C TIE62 RIH with RCJB BHA on 4" DP from derrick. 08:30 - 10:00 1.50 FISH C TIE62 MU top drive to std #17. Obtain parameters: PU wt = 75K-Ibs, SO wt = 77K-Ibs, Rot wt = 77K-Ibs. Rotate at 70-RPM with 2.5K-ftlbs of free torque. Pump on at 8-BPM with 590 psi.~RIH`- and tag soft cement at 1883'. Drop ball for RCJB and pump down at 3-BPM with 100-psi. Did not see ball seat. Continue to wash ahead. Shut down rotation and wash down at 9-BPM with 980-psi. Tag plug at 1917'. Drop dart to open pump out sub. Circulate bottoms up at 12-BPM with 1100-psi. See green cement and a few small chunks of ES cementer closing plug at bottoms up. 10:00 - 11:00 1.00 FISH C TIEB2 POH with RCJB BHA. Stand back 4" DP and 3-stds 4-3/4" DCs in derrick. 11:00 - 12:00 1.00 FISH C TIEB2 LD RCJB BHA. Recover 4" thick chunk of cement from RCJB. ecover Ball was on seat in RCJB when inspected at surface. R T both LDS tips in boot baskets along with a few small pieces of cement. 12:00 - 12:30 0.50 DRILL C TIE62 PU 9-5/8" tieback drill out BHA. BHA consists of 8-1/5" bit, Printed: 6/8/2009 11:37:35 AM BP EXPLORATION Page 10 of 14 Operations Summary Report ',Legal Well Name: A-31 'Common Well Name: A-31 Event Name: WORKOVER 'Contractor Name: DOYON DRILLI NG INC. Rig Name: DOYON 16 Date From - To Hours Task I Code NPT ! 5/25/2009 12:00 - 12:30 0.50 -- DRILL - C 12:30 - 13:00 0.50 DRILL C 13:00 - 17:00 4.00 DRILL C 17:00 - 19:00 2.00 DRILL C 19:00 - 22:00 3.00 FISH C 22:00 - 00:00 2.00 FISH C 5/26/2009 00:00 - 01:00 1.00 FISH C 01:00 - 04:30 3.50 FISH C 04:30 - 06:00 I 1.50 I CASE I C 06:00 - 07:00 1.00 DHB C 07:00 - 07:30 0.50 DHB C 07:30 - 09:00 1.50 DHB C 09:00 - 09:30 0.50 P 09:30 - 13:00 3.50 13:00 - 13:30 0.50 13:30 - 14:30 1.00 14:30 - 19:00 4.50 19:00 - 20:00 I 1.00 20:00 - 20:30 0.50 20:30 - 23:00 2.50 P P P P P P P Spud Date: 6/30/1985 Start: 5/14/2009 End: Rig Release: 5/31/2009 Rig Number: Phase Description of Operations TIEB2 2(ea) 7" boot baskets, Bumper sub, Jar, Pump out sub and 9(ea) 4-3/4" DCs. Total BHA length = 311.06'. TIEB2 Inspect grabber on top drive. Tighten bolt that had worked loose. TIEB2 RIH with drill out BHA on 4" DP from derrick to 1833'. Kelly up. PU 75k, SO 80k. 80k rotating C~ 60 rpm & 2k WOB. Drill from 1917'-1920' w/ 5-10k WOB. CO sand to 2050'. Pump 40 bbl high vis sweep and CBU @ 8 bpm. TIEB2 BD top drive, POOH. SB collars, LD 9.625" drill out BHA. 3 gallons sand, cement and aluminum cuttings in boot basket TIEB2 MU 7-7/8" RCJB 9-5/8" scra er two (ea) 7" boot baskets, bumper sub, oil jar, pump out sub & 9(ea) 4.75" collars. RIH to 1960', SO & PU 80k. Drop ball, & clean 10' of sand from 2065-2075' @ 10 bpm & 1220 psi. Pump 40 bbl sweep C~ 10 bpm & 1250 psi. POOH. Recovered 60% of landino rina in full RCJB. 1 allon sand/cement in boot basketswith an alien bolt and thumbnail sized iece of aluminum. TIEB2 LD 9.625 scraper, run RCJB again & make 10' from 2075-2085'. TIEB2 POOH w/ RCJB. Recovered additional aluminum and 3 brass plugs in RCJB, boot baskets empty. TIEB2 RIH w/ RCJB a third time to ed @ 20 '. Break circulation. .Wash to 2095' w/ no weight. CBU & POOH. RCJB & boots TIEB2 Clear floor & pressure test casing to 4000 psi for 30 charted minutes against blinds. RD test equipment. TIE62 MU HES RBP retrieving tool. RIH. Release RBPr TIEB2 CBU at 10-BPM with 650-psi. Monitor well. RIH below set de th of 2106' COE. Stand back 1-std DP. Blow down Top drive. TIE62 POH with RBP, standing back DP in derrick. LD RBP and retriewn tool. TIEB1 MU 7" Scab Drill out BHA. BHA consists of: 6-1/8" bit, 2(ea) boot baskets, 7" Csg scraper, Bumper sub, Oil jar, Pump out sub, and 9(ea) 4-3/4" DCs. Total BHA length = 316.55'. TIEB1 RIH with 7" Scab Drill out BHA on 4" DP from Derrick. TIEB1 Scrape the packer setting area with 3-passes from 8951' to 9046'. TIEB1 Slip and cut drilling line. TIEB1 M/U to top drive and get parameters: P/U wt 190K-Ibs, S/O wt=150K, ROT wt=60 RPM w/6K FT=165K, Pump Rate@ 8 BPM w/1200 psi, Tag cement at 905 'Wash and ream down thru cement with above parameters running 5K to 10K WOB, on bottom pressure 1250-1300psi, torque on bottom 6 to SK, continue to wash down and ream to locate wiper plug at 9064'. Continue to control drill w/above parameters. Locate landing collar C~3 9066'. Drilled thru landing collar at 9067'. Drilled cement from 9067' to 9107'. Float collar at 9109'. 7" x 4.5" crossover at 9156'. TIEB1 ump r is sweep followed by 454 bbls at 10 BPM w/2300 psi TIEB1 Monitor well, Pump dry job, blow down top drive TIEB1 POOH w/ BHA 10 From 9149' to 316' Printed: 6/8/2009 11:37:35 AM • • BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date 'From - To Hours Task Code NPT 5/26/2009 23:00 - 23:30 0.50 P 23:30 - 00:00 0.50 P 5/27/2009 00:00 - 01:30 1.50 CLEAN P 01:30 - 05:15 3.75 CLEAN P 05:15 - 06:30 ~ 1.25 ~ CLEAN ~ P Spud Date: 6/30/1985 Start: 5/14/2009 End: Rig Release: 5/31/2009 Rig Number: Phase Description of Operations TIE61 Set back drill collars and LD BHA TIEB1 Emptied Boot baskets- Collected aluminum parts from float and landing collars plus some cement .Clear rig floor. CLEAN MU 4-1/2" Drillout BHA #11 with 3.80" bladed mill. CLEAN RIH to 9072', breaking circulation every 30 stand. Parameters: 150K Down wt, 190K Up wt. 165K Rot wt at 30-RPM with 6K-Ib-ft torque at 4-BPM at 630-psi. CLEAN Tagged cement at 9153'. Drilling thru cement to 9193 ; continue washing down to 9235'. Find top of Sluggits at 9238'. Drv drill 2' into the sluggits without seeing any increase in 06:30 - 08:00 08:00 - 11:00 11:00 - 12:30 1.50 3.00 1.50 CLEAN CLEAN CLEAN P P P CLEAN CLEAN CLEAN P/U 50' and CBU while working pipe to ensure pipe is free. Circulate at 8-BPM, 2030-psi. shut down pumps and monitor well for 30-minutes; well fluid is static at flow line. POH and S/B DP in derrick. Stand back drill collars and la down 4.5" Clean out BHA. Empty the Boot Baskets and get 2-gallons of metallic debris mixed with assorted wellbore detritus. 12:30 - 13:30 1.00 CLEAN P CLEAN PU/MU Wetherford WRP retreival tool BHA: RBP retrieving tool, 2-ea crossovers, 6-ea 2-7/8" PAC DP- Lubricated Bumper sub, Oil Jars, Pump-out sub, and 9-ea 4-3/4" DCs. 13:30 - 16:30 3.00 CLEAN P CLEAN RIH retrieving tool and slow down with 2-stands remaining in derrick. Lightly tag up at 9218'. Call RWO Engineer to discuss the circulating regime and decide to circulate the long way. 16:30 - 18:00 1.50 CLEAN P CLEAN Get Parameters: POH one joint; P/U wt 190K-Ibs, S/O wt 148K-Ibs, Rot wt 150K-Ibs, 60-RPM, 4-BPM at 1600-psi. See thattpump pressure is higher than it should be and cpr? m~~- hv, gummy returns from previous sweeps across the shakers_ within a DP volume. Increase the rate to 7-BPM, 2450-psi and slowly wash down. See obstruction again at 9218'. Get through the obstruction and pump pressure drops to 2050-psi. Get down to 9240'. Work pipe up and down while circulating long wa 7-1/2-BPM 2050-psi. Getting black sand and some sluggits over shakers. At 1750-hrs see flow increase to 65% back to surface wit as rea in ou . 18:00 - 19:30 1.50 CLEAN P CLEAN Continue circulating and get surging gas returns to surface. Increase rate to 6-BPM at 1780-psi and gas continues. Call RWO Engineer and Superintendent and agree the plan to Bullhead two wellbore volumes of 8.5-opg seawater into the 19:30 - 21:00 I 1.501 CLEAN I P CLEAN ~ Closed annulars and bullhead 8.5 ppg seawater thru drill in and backside. ICP= 8 BPM with 1730 psi. FCP=10 BPM with 21:00 - 21:30 I 0.501 CLEAN I P 21:30 - 22:00 0.50 CLEAN P 22:00 - 00:00 2.00 CLEAN P 5/28/2009 ~ 00:00 - 07:00 ~ 7.00 ~ CLEAN ~ P CLEAN Open Annular and monitor well. Well taking 13.2 BPH. Blow down Choke and kill lines. CLEAN RIH to tag up with plug at 9229' CLEAN 6998'. Constant hole fill. Loss rate=l2 BPH. CLEAN Continue to pull out of the hole from 6998' to 1060' laying down drillpipe. Constant hole fill. Loss rate=l2 BPH. Retrieval tool to the Rig Floor with no WRP. Severe damage to the mouth of the tool and to the exterior of the tool, with no apparent indication of the WRP fishing neck having been inside. Printetl: 6/8/2009 11:31:35 AM • BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Spud Date: 6/30/1985 Event Name: WORKOVER Start: 5/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/31/2009 Rig Name: DOYON 16 Rig Number: Date ~ From - To Hours Task I 15/28/2009 07:00 - 09:30 2.50. CLEAN Code ! NPT ' Phase P 09:30 - 15:30 I 6.001 CLEAN I P 15:30 - 17:15 I 1.751 FISH I P 17:15 - 19:30 ~ 2.25 ~ FISH ~ P 19:30-21:30 I 2.OOIFISH IP 21:30 - 00:00 ~ 2.50 ~ FISH P 5/29/2009 100:00 - 01:00 I 1.001 FISH I P Description of Operations CLEAN Discuss options with RWO group--decide to R/U slickline with full pressure control and line wiper on Dutch Riser to make bailer and/or LIB runs to clean off top of WRP. Continue with hole fill with blinds closed. Loss rate is 11.2-BPH. R/U Dutch Riser to BOP Stack. Wait on slickline unit #2. CLEAN Spot and rig up slickline unit with full pressure control. Hold PJSM with rig crew Schlumberger crew, Toolpusher, and WSL for R/U slickline equipment. R/U slickline equipment: BOPs, Lubricator, and Line Wiper. The first Schlumberger crew had crew change day shortly after they arrived. Baker fisherman reported that the BHA tally was 25.9' short due to the omitted length of a short joint of 2-7/8" PAC DP, which means that the maximum depth reached for the top of the WRP is 9265.9' as shown in the original report for the slickline setting depth. However, there is debris on top of the V RP and the string was slowly worked down into the the top of the fill above the sluggits before contacting a hard tag. Subsequent operations for retagging put the maximum corrected depth at 9254'. DECOMP PJSM to RIH with Bailer. PT Schlumberger BOP and Lubricator to 2000-psi against closed D-16 BOP Blind Rams. Did not see the top of the 7" liner at 2862' while RIH. Found the 7" x 4-1/2" XO at 9155' SLM. At 1640-hours hit a restriction at 9168' SLM_ inside the 4-1/2" tubing. Work past it to another obstruction at 9207' SLM by repeatedly POH and RIH with the bailer, then get down to 9222' SLM at 1645-hrs. At 1700-hrs get to 9233' SLM, but can't get off the obstruction.- Set off jars 4-times and get off obstruction. Decide to POH to check bailer. DECOMP POH with Bailer. Break out Bailer from lubricator. No fish inside bailer, but find a ring mark inside the tapered bore of the bailer i entica in diameter to the diameter of the fishing neck of the WRP. There are also some small marks on the skirt of the bailer indicating debris probably near the top of where the equalizing sleeve would have been shoved to in order to open the ports. Confer with slickline coordinator, Baker fisherman, Night WSL and decide to use ashort-catch slickline-run WRP retrieving tool to get over the fishing neck of the WRP. Call RWO engineer and Superintendent and agree to RIH with the new retrieving tool. Wait on hot-shotted tool. DECOMP M/U Weatherford WRP retreival tool and fishing bait sub. RIH and tag up WRP at 9274' SLM. POOH. No fish. Marking on the nose of the retreival tool indicated contact with the fish neck. Tool Description: Rope Socket and Quick Connect, Stem, Oil Jars, Long Stroke Spangs, GR Tool, and Weatherford Pulling Tool. DECOMP Consult with Anchorage Engineer on plan forward. Run in the hole with 3.5" bailer. Tap bailer through 9208', set down at9274' and work bailer. 5001bs initial overpull after functioning bailer and one tight spot at 9196' SLM. Bailer returned to surfac with agprox 1.5 gallons sand with metalic and nickel sized cement DECOMP Redress 3.5" bailer and run in the hole for another clean out attempt. Losses at 8 BPH. Constant hole fill. Tool Description: Rope Socket, Quick Connect, Stem, Oil Jars, Long Stroke Printed: 6/8/2009 11:37:35 AM • BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Spud Date: 6/30/1985 Event Name: WORKOVER Start: 5/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/31/2009 Rig Name: DOYON 16 Rig Number: Date From - To ~', Hours Task 'i Code NPT Phase Description of Operations 5/29/2009 00:00 - 01:00 1.00 FISH P DECOMP Spangs, 3.5" Bailer. Work through tight spots at 9208' and 9224' SLM, set down and function bailer at 9270'. 01:00 - 03:30 2.50 FISH P DECOMP POOH and work through tight spot at 9208'. Bailer returned to .surface with a int of sand and a few small feces of rock. 03:30 - 04:30 1.00 FISH P DECOMP Make up Weatherford Overshot tool with "G" bait sub and run in the hole. 04:30 - 06:00 1.50 FISH P DECOMP Run in the hole with Weatherford Overshot tool and attempt to enq~ae the WRP. Tool Description: 3:35" OD WFD Releasable overshot, OAL 42". Unable to latch onto the WRP fishing neck. POOH to pick up bailer. 06:00 - 07:30 1.50 FISH P DECOMP M/U short-nosed Bailer (with flapper 3" inside muleshoe mouth) and RIH to bail off the top of the WRP. Get to 9274' and stroke bailer several times, then prepare to POH. 07:30 - 09:00 1.50 FISH P DECOMP Start to POH and bailer is stuck. Work the Jars three times to get unstuck. Get stuck twice in same spot and work jars -3-times each and POH. Empty bailer and get back 1-gallon of sluggits and 52-pieces of iron and brass "nuaaets" from what appears to be overshot colletts, a string shot or jet cutter, and possible packer. The top half of a ball-point pen was also in the returns. 09:00 - 10:15 1.25 FISH P DECOMP M/U short bailer after repairing flapper and RIH. Max depth was -9290'-SLM. Work bailer for -20-minutes. Also got stuck right above the max depth and worked the jars to get unstuck. 10:15 - 11:30 1.25 FISH P DECOMP POH and break off Lubricator to empty bailer.. Bailer~returned . 1-gallon of sand and 5 dime-sized metal chunks. Contact Anchorage team, decide to halt slickline and proceed with running a modified completion: The XN nipple will be removed from the string and the RHC plug body will be installed in the first X nipple allowing the WRP to be fished after the workover is com lete. 11:30 - 13:00 1.50 FISH P DECOMP PJSM with WSLs, slickline PE, SLB to R/D Schlumberger. R/D Schlumberger and load out BOP, Lubricator, and wiper from Pipe shed and Beavalator. 13:00 - 15:30 2.50 BUNCO P RUNCMP R/U to run 4-1/2", 12.6#, L-80, TCII tubing string. R/U Stabbing Board and conduct ul inspection o t e to ina Board and the Torque Turn power tongs. 15:30 - 00:00 8.50 BUNCO P RUNCMP PJSM. M/U W LEG to BakerLoked full joint at 1600-hrs. Continue RIH with completion torquing all joints to 3850-Ib-ft optimum torque using Jet Lube Seal Guard on all connections above the packer, Bakerloking all connections below the packer. Joint #10 RIH at 1700-hours. Joint #70 at 19:45 hrs. Parameters above 7" liner top: PUW=73K, SOW=75K. 5/30/2009 00:00 - 01:30 1.50 BUNCO P RUNCMP Continue running in the hole with 4.5" 12.6# TC-II L-80 completion using Jet Lube Seal Guard on all connections above the packer and torquing all connections to optumum torque of 3880 Ib-ft. 01:30 - 02:00 0.50 BUNCO RUNCMP Make up 4.5" tubing hanger. Pick up and slack off weights after making up hanger: P/U wt 147K-Ibs, S/O wt 127K-Ibs. Land the_ completion in the tubing spool and run in the lockdown screws. Make up drillpipe safety valve to landing joint and prepare to circulate completion fluids. 02:00 - 04:00 2.00 BUNCO P RUNCMP PJSM with rig crew, CH2M truckers, WSL and Toolpusher covering pressure test and circulating operations. Pressure Printed: 6!8!2009 11:37:35 AM • BP EXPLORATION Page 14 of 14 .Operations Summary Report Legal Well Name: A-31 Common Well Name: A-31 Spud Date: 6/30/1985 Event Name: WORKOVER Start: 5/14/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 5/31/2009 Rig Name: DOYON 16 Rig Number: Date From - To Hours Task 'Code NPT Phase Description of Operations 5/30/2009 02:00 - 04:00 2.00 BUNCO P RUNCMP circulating lines to 4000 psi. Reverse circulate 150 bbls of 120E seawater into inner annulus at 3 bpm / 120psi. 04:00 - 07:00 3.00 BUNCO P RUNCMP Circulate 275 bbls of 120E inhibited seawater at 3 bpm with 120 psi circulating pressure. 07:00 - 08:00 1.00 BUNCO P RUNCMP R/U Little Red; PT lines to 2500-psi. PJSM to pump freeze protect diesel. 08:00 - 09:30 1.50 BUNCO P RUNCMP Pump 140-Bbls of diesel freeze protect, 2-BPM, 500-psi at 90F. 09:30 - 10:00 0.50 BUNCO P RUNCMP U-tube freeze protect. Drop ball and rod at 1000 hrs 10:00 - 12:00 2.00 BUNCO P RUNCMP Line up pumps and set the packer. Pressure test tubing to 4000 psi for 30 minutes passing test. Bleed tubin pressures 1600 psi and pressure test inner annulus to 4000 si for 30 mins, passing test. 12:00 - 13:00 1.00 BUNCO P RUNCMP Rig down test equipment, L/D landing joint. 13:00 - 13:30 0.50 BOPSU P RUNCMP Cameron P/U TWC and dr rod into han er. Test from above to 3500- si for 10 charted m' 13:30 - 15:00 1.50 BOPSU P RUNCMP Blow down choke and kill lines. Break down the cellar circulating manifold and suck out stack to prepare to replace 3-1/2" x 6" VBRs with 7" fixed Rams for initial work on the A-35 RWO. R&R Rams. 15:00 - 16:00 1.00 BOPSU P RUNCMP N/D BOP and adaptor flange; clean out wellhead, prepare new DSA flange. 16:00 - 20:30 4.50 WHSUR P RUNCMP N/U new DSA and tree. Install tree cap and annular gauges. Test void to 5000-psi for 30 recorded minutes-passing test. Test tree to 5000-psi for 10-minutes. 20:30 - 22:00 1.50 WHSUR P RUNCMP RU DSM lubricator and test to 500 psi. Pull TWC. Well secure at 22:00 22:00 - 00:00 2.00 WHSUR P RUNCMP Bridle up. Rig down floor equipment. Install BPV. Secure the tree and cellar. RDMO. Rig Release at 24:00 Printed: 6/8/2009 11:37:35 AM A-31 A, Well History (Post Rig Workover) Date Summary 6/5/2009 WELL S/I ON ARRIVAL. RIG UP SWCP 4516 TO PULL B&R AND 4-1/2" RHC PLUG BODY C~ 9,035' MD. 6/6/2009 PULLED B&R AND 4-1/2" RHC PLUG BODY FROM C~ 9,035' MD. RAN 3.70" CENT, 3.30" L.I.B. SD Q 9247' SLM (impression of debris on sides, face clean). BAILED FROM 9,260' TO 9,268' SLM W/ 3.50" x 10' P-BLR. (recovered ~4 gals of sluggits). RAN 3.50" MAGNET TWICE TO 9,270' SLM & 9,272' SLM (small amount of metal debris). RAN 3.50" x 10' P-BAILER TO 9,270' SLM (metal marks on inside of btm -2.48" across). CURRENTLY RIH W/ 3.70" CENT, 3.25" L.I.B. TO 9,273' SLM. 6/7/2009 RAN 3.25" L.I.B. TO 9,273' SLM (impression of wrp shear stud w/ rig debris next to it). RAN 2.50" HYDROSTATIC BLR, 3.65" FLAT BTM FINGER BASKET TO 9,274' SLM. BAILER BOTTOM SWALLOWED TOP OF WRP BLOCKING ENTRY (no recovery). RAN 2.80" CENT, 2.70" MAGNET TO 9,273' SLM (no recovery). RAN 2.50" 3-PRONG WIRE GRAB. SD C~ 9267' SLM (no recovery, metal marks on grab, tips of 3 btm barbs broke off). RAN 3" OVERSHOT SD C~3 9269' SLM, UNABLE TO PLANT (metal marks on btm). PLANTED 2.875" OVERSHOT (2.25" collet) ON SAFETY SUB OF WRP ~ 9,273' SLM. JARRED ON WFD WRP Q 9,273' SLM FOR ~2 HOURS W/ 4-1/2" GS (no movement). 6/8/2009 PULLED BAIT SUB AND 2.875" OVERSHOT OFF WFD WRP C~ 9,266' SLM. COLLET FOR OVERSHOT WAS STRIPPED AND 2 DOGS WERE BROKE & GONE. RAN 3.60" OFFSET SUB W/ SPEAR AND 2-PRONG WIRE TO 9,269' SLM (no binds). RAN 3.50" MAGNET TO 9,257' SLM, NOT ABLE TO PASS (appear to be 12' high). RAN 3.70" LIB (slight taper) TO 9,255' SLM (impression of possible metal on tbg wall). RAN 2.70" CENTER SPEAR W/ 12 BARBS TO 9,269' SLM (metal marks on barbs & top sub). RAN 3.50" MAGNET TO 9,270' SLM (small debris recovered, center clear possible shear stud). PLANTED 4-1/2" WFD (shorty, oal = 21 ") WRP RETRIEVAL TOOL ON WRP C«~ 9,272' SLM. 6/9/2009 PULLED 4 1/2" WFD WRP FROM 9,270' SLM (intact, elements swollen to 4.07"). RAN 10 x 3.50" P-BLR UNABLE TO PASS 9,207' SLM (recovered 3 chunks of cement). RAN 3.50" MAGNET TO 9,211' SLM (nothing recovered). RAN 5' x 3.00" DD-BAILER TO 9211' SLM (recovered 1/4 cup of cement chunks). RAN 3.50" x 5' P-BLR TO 9,212' SLM (recovered 2 quarter size chunks of cement & 1/4 cup unset cement). RAN 3.25" G-RING TO 9,214' SLM, UNABLE TO MAKE ANY HOLE (cement film on g-ring). 6/10/2009 RAN 2.60" TAPERED STAR BIT TO 9,215' SLM, WORKED TOOLS 30 MIN (no hole gained). RAN K.JT, 3.00" x 5' P-BLR, TOOTHED MULE SHOE FLAPPER. SD C~3 9,213' SLM (no recoevery). RAN 5' x 2.25" DD-BLR,TOOTHED MULE SHOE FLAPPER. SD Q 9213' SLM (no recovery, broke 2 teeth off flp btm). RIH W/ 10 x 2.50" P-BLR W/ FINGER BASKET (sd Q 9212' slm, break thru 9217' slm tag liner top C~ 9273' slm). RIH W/ 10' x 3.50" P-BLR, MULE SHOE FLAPPER. TAG TOP OF LINER TOP Q 9273' SLM (no recovery). RAN 1.90" SWAGE, S-BLR TO 9675' SLM (-400' INTO LINER) sample of wet cement. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. Page 1 of 1 JELLHEAD= McEVOY CTUATOR= I BAKER C I, .B. EL~1/ = 81.1 T -_ '~ F. ELEV = I 52.19' ~ OP = 3450' lax Angle = 113° @ 9943' Datum MD = 9630' A 31 A *** WARNING: RADIO TRANSMITTER IN WEATHER MONITORING SHAT BE TURNED OFF BEFORE ANY WELL WORK INVOLV ""CHROME EXPLOSIVES CAN BEGIN. CONTACT PO. TBG & NIPPLES'"" 1917' 9-5/8" HES CEMENTER 1940' 13-3/8" X 9-5/8" BKR ECP 2007' 4-1/2" HES X NIP (9-C R), ID = 3.813" 2862' 9-5/8" X 7" BKR ZXP LTP w /FLEX LOCK HGR, ID = 6.300" $970' 4-1/2" HES X NIP (9-CR), ID = 3.813" 9001' 7" X 4-1/2" L-80 BKR S-3 PKR, ID = 3.875" 9035' 4-1/2" HES X NIP (9-CR), ID = 3.813" 9087' 4-1/2" WLEG, ID = 3.958" 9155' 7" X 4-1/2" XO, ID = 3.958" 9163' 4-1 /2" X 7" XO, ID = 3.958" 9197' 9-5/8" X 4-1/2" UNIQUE OVERSHOT 9210' 4-1/2" PKR SWS NIP, ID = 3.813" 9222' 9-5/8" X 4-1/2" TM/ HBBP PKR, ID = 3.875" Datum TVD = 8800' SSA 9-5/8" BOWEN CSG PATCH, 47#, 1974' L-80 BTGM, ID = 8.681" 13-3/8" CSG, 72#, L-80, ID = 12.347" 2668' Minimum ID = 2.37" @ 9285' TOP OF 2-7/8" LN R 4-1/2" TBG, 12.6#, L-80 TCII, ID = 3.958" I4-1/2" TBG STUB (05/18/09) I 9193' 7" CSG, 26#, L-80 BTGM, ID = 6.276" 9197' TOP OF 7" LNR 924$' BKR KB PKR W/ SEAL ASSY, ID = 2.56" I 13.75" BKR DEPLOY SLV, ID = 3.00" ~ 9277' TOP OF 2-7/8" LNR, ID = 2.37" 9285' 4-1/2" TBG, 12.6#, NT13CR-80 TDS, 9311' .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 9512' PERFORATION SUMMARY REF LOG: MWD GR/ROP 11/27/99 TI: BHCS/GR ANGLE AT TOP PERF: 109° @ 10010' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10010 - 10026 C 08/08/04 2" 6 10280 - 10290 C 08/08/04 2" 6 10310 - 10320 C 08/07/04 2" 6 10366 - 10374 C 08/05/04 2-7/8" 4 10491 - 10522 C 11/29/99 WHIPSTOCK (NO RA TAG) 9584' 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" 9277' --~ 3.0" BKR SEAL ASSY, ID = 2.40" 9279' 4-1/2" PKR SWS NIP, ID = 3.813" 9299' 4-1/2" PKR SWN NIP, ID = 3.80" 9311' -~4-1/2" WLEG, ID = 3.958" 9300' ELMD TT DATE NOT AVAILABLE MILLOUT WINDOW (A-31A) 9586' - 9593' 10450' -~ 2-7/8" BOT CIBP SET 08/05/04 PBTD ~-~ 10523' 10030' 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, iD = 2.441"`? 10590' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 07/18/85 ORIGINAL COMPLETION WELL: A-31A 08/31/91 RWO PERMff No: 1990560 11/29/99 CTD HORIZONAL SIDETRACK API No: 50-029-21383-01 05/31/09 D16 RWO SEC 35, T11N, R13E, 2316' FSL & 1012' FEL 06/10/09 DB/JMD DRLG DRAFT CORRECTIONS 06/10/09 DB/JMD WRPPLUG PULLED BP Exploration (Alaska) 06/08/09 • Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description N0.5271 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-35 AYTO-00018 CROSS FLOW CHECK j 05/09/09 1 1 14-35 ANHY-00087 INJECTION PROFILE _ 05/15/09 1 1 06-08A AViH-00012 IBP/FBS/CFS/GRADIO/PRESS/T P 05/11/09 1 1 A-44 AWLS-00017 SCMT 05/25/09 1 1 12-07A BOCV-00016 SBHP SURVEY 05/19/09 1 1 09-24 ANHY-00088 CROSS FLOW CHECKflBP q 05/17/09 1 1 H-29A AYOO-00027 PPROF/RST - 05/19/09 1 1 09-09 AYTU-00032 CROSS FLOW CHECK - `~ , 05/06/09 1 1 15-45B ANHY-00010 PRODUCTION PROFILE "~~ 05/09/09 1 1 13-13A AYTU-00033 USIT - ~ ~ 05/08/09 1 1 M-19B AY3J-00024 PRODUCTION PROFILE 05/14/09 1 1 Z-12 ANHY-00084 INJECTION PROFILE 05/07/09 1 1 E-36A BiJJ-00018 MEM CNUSTP 1 s 05/18/09 1 1 X-30A 62WY-00005 MEM PROD PROFILE ~ 05/10/09 1 1 12-23 AYKP-00021 USIT L - 05/08/09 1 1 W-34A AWJI-00031 MEM PROD PROFILE 05/19/09 1 1 Z-14B AZCM-00022 PROD PROFILE/JEWELRY LOG • (®- 05/20/09 1 1 Li-21 62NJ-00006 PRODUCTION PROFILE ~- 05/24/09 1 1 A-31A AZCM-00023 USIT = - Q {® L 05/22/09 1 1 H-19B' B2WY-00004 MEM PROD PROFILE [- 05/07/09 1 1 G-16 AYKP-00022 SCMT J / - 05/09/09 1 1 M-196 AY3J-00024 SCMT 05/15/09 1 1 12-37 AWL9-00032 PRODUCTION PROFILE ~ ~/~{ / 04/21/09 1 1 11-04A AYOO-00028 USIT J L(_ 05/21/09 1 1 18-30 B1JJ-00015 MEM PROD PROFILE JG/ 05/13/09 1 1 4-14A/S-37 AYKP-00024 PRODUCTION PROFILE ~ - ~ i 05/11/09 1 1 3-37/L-35 AWL9-00035 PROD/INJECTION PROFILE 05/22/09 1 1 3-37/L-35 AWL9-00035 TEMPERATURE SURVEY 05/20/09 1 1 V-217 AYOO-00024 INJ PROFILE/RST WFL %} /~/5 04/26/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE DOPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. c ._,.,,, ~~~~[~C# a Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A-31a RWO Change of Scope dry 309-127 PTD 199-056 • Page 1 of~~.., Maunder, Thomas E (DOA) From: Bjork, David (Northern Solutions) [David.Bjork@bp.com] Sent: Friday, May 22, 2009 11:46 AM To: Maunder, Thomas E (DOA) Subject: RE: A-31a RWO Change of Scope Sundry 309-127 PTD 199-056 Thank you and have a great long weekend! From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, May 22, 2009 11:30 AM To: Bjork, David (Northern Solutions) Cc: Hubble, Terrie L; Stewman, Sondra D; Reem, David C; Willingham, James M Subject: RE: A-31a RWO Change of Scope Sundry 309-127 PTD 199-056 Dave, et al, Thanks for the call and follow-up email I have advised Commissioner Foerster and she has given her oral approval for the change of operations. I will place a copy of this message in the file. No additional paperwork is needed at this time. The operations summary submitted with the 404 will capture the additional work. Call or message with any questions. Tom Maunder, PE AOGCC From: Bjork, David (Northern Solutions) [mailto:David.Bjork@bp.com] Sent: Friday, May 22, 2009 11:05 AM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L; Stewman, Sondra D; Reem, David C; Willingham, James M Subject: A-31a RWO Change of Scope Sundry 309-127 PTD 199-056 Mr. Maunder, As we discussed via telephone earlier this AM, we have encountered more problems with A-31a than originally expected. The original scope of work was. Proposed Procedure MIRU Nabors 4ES. ND tree. annular preventer to 3,500 psi through the cut. ~ F NU and test BOPE pipe rams, with 3-1/2" x 6" VBR, to 4,000 psi. Test . Circulate out freeze protection fluid and circulate well to kill weight fluid 2. Retrieve 4-1/2" tubing string down to the tubing cut. 3. Dress off tubing stub. 4. Fully cement 7" L-80 BTC-M scab liner from 2,900' to 9,192'. The 3-1 /2" x 6" VBR will NOT be changed to 7" as the barrier to the reservoir will be a tested 4-1 /2" WFD RBP at 9,259' MD and kill weight fluid. 5. Change out 9-5/8" pack-offs, clean out shoe tract and pressure test liner and casing to 4000psi. 6. Retrieve 4-1 /2" WFD RBP. 7. Run 4-%z" L-80 TC-II tubing with Baker S-3 packer and set at -9,060' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 4000psi. Freeze protect to 2200' MD. 5/22/2009 A-31 a RWO Change of Scope dry 309-127 PTD 199-056 ~ Page 2 of~~ 10. Set BPV. ND BOPE. NU and test tree. RDMO. The sequence of events during the RWO operation. After dressing off the tubing stub we ran a test packer to 3,000' and successfully pressure tested the wellbore from surface to 3,000' to 4,000psi for 30 charted minutes. The 7" scab liner was successfully installed from 9,197' to 2,881'. We picked up a drill out assembly and hung it off with a storm packer 1 std below the rotary table and tested it from above to 1,000psi for 10 charted minutes. We proceeded with the packoff change out operation, the mandrel hanger and 9-5/8' casing grew around 8". We pulled the storm packer and added additional weight below the packer. Reset and the packer 1 std below the rotary table, and tested from above to 1000psi for 10 charted minutes. We were unable to re-land the casing on the mandrel hanger. We then ND the tubing spool and BOPE to visually inspect the mandrel hanger (two tested mechanical barriers are the storm packer at -90' and the RBP at 9,259'). We were still unable to land the mandrel hanger. The tubing spool and BOPE were NU, we screwed back into the storm packer and were unable to pressure test from below. The stack was drained and flow was observed coming from behind the mandrel hanger, up the OA. The packer was released and the wellbore CMIT IA X OA to 2,500psi for 10 charted minutes. We pulled the storm packer and drill out BHA, then ran in with a test packer. The test packer was set at 1,000' and tested below to 4,000psi for 30 charted minutes. Confirming competency of the scab liner. A USIT log was ran and top of cement located at 2,025'. We proposed the following course of action 1. Run 9-5/8" RBP and set -2150'. Pressure test RBP to 1,000 psi. Place 50' of sand on RBP. 2. Cut and pull the existing 9-5/8" casing from 1,970'. Displace with diesel and heated seawater to remove Arctic Pack. 3. Run and fully cement 9-5/8" 47# L-80 HYD 563 casing with ECP, ES Cementer and casing patch. The 3- 1/2" x 6" VBR will NOT be changed to 9-5/8" as the barrier to the reservoir will be a tested 4-1/2" WFD RBP at 9,259' MD and a fully cemented and tested 7" liner and 9-5/8" RBP 2,150'. 4. Drill out the 9-5/8" shoe tract. Test the 9-5/8" casing to 4,000psi for 30 charted minutes. Retrieve the 9- 5/8" RBP. 5. Drill out the 7" shoe tract and test to 4,000psi for 30 charted minutes. 6. Retrieve 4-1 /2" RBP. 7. Run 4 %2" L-80 TC-II tubing with Baker S-3 packer and set at 9,060' MD. 8. Displace the IA to packer fluid freeze protect to 2200' MD and set the packer. 9. Test tubing and IA to 4000psi. Set BPV. ND BOPE. NU and test tree. RDMO. Attached are the last few morning reports and an updated schematic. Thank You for the assistance. Regards, 5/22/2009 n BP EXPLORATION Dail Operations Report Page 1 of 4 Operator: BP EXPLORATION Rig: DOYON 16 Report: 6 Weil: A-31 Event: WORKOVER date: 5/19/2009 Field: PRUDHOE BAY Well T e: DEVELOPMENT Current Well Status Depth MD: {ft} Casing Size: (in) Gosts in: USD Rig Accept: 08:00 5/16/2DD9 Est. TVD: {ft) Casing {MD}: (ft} Daily Mud: Rig Release; Progress: {ft) Next Casing Size: (in} Cum. Mud: Spud Date: 6/30/1985 Ruth Depth: {ft) Next Casing {MD): (ft) Daily well: WX Date: Hole Size: Next Casing (TVD}: (tt) Cum. Well: Elev Ref: MEAN SEA LEVEL DOUDFS/Target: /! Geologist: KB Elev: {ft} Engineer; Bjork Tot. Personnel: 34 Supervisor: Barker t Burson J Baca Program: Cost Ahead: D USD, Days Ahead: 0.00 Weather 3ti deg WC 29 E 13 MPH ....... ...... Current Status: Displacing cement. 24hr Summary: RIH w/ BHA #2. Slip & Cut. Dress Tbg stub. Pump sweep & Circ OOH. POH. RU to run ?" Scab. Run 7" 26# L80 BTC-M scab liner. 24hr Forecast: RU. Cemen# Scab. MU BHA #3. RIH. Set Storm Pkr. GO Packoff, Gomments: No Incidents. No Iri uries. 1 Leak See remarks). HSE & Well Control Days Since Last DAFWC: 4231 All Free Days: 4 ... Las# Csg Test Press.: (psi) Last Envir. Incident. 5/15/2009 Las# BOP Press. Test: 5/17!2009 Las# Trip Drill {Di ): 5/19!2009 Next BOP Press. Test: 5/24/2009 Last Safety Meeting: 511912009 Last Spill DriIL• 5/i 5/2009 No. Stop Cards: Regulatory Agency insp: N Non-compliance Issued: N FIRE: 511$/2009 Pump Slow Pump Rates (Circ) ;Slow Pump Rates {Ghoke) Slow Pump Rates (Kill) TVD: {it) j Stroke Rate Pressure() :Stroke Rate Pressure() :Stroke Rate Pressure() EMW: (Pp9) MAASSP: (psi) Test Pressure: (psf) Kick Tolerance: {ppg) Kick Volume: (bbl) O erational Parameters ROP Daily; Rotating Weight: Daily Bit Hrs: (hr) Pump Status Drillin and Riser 9 ROP Curn.: . Pick Up Wt.: Daily Sliding Hrs:0.00 {hr} :Pump,Type Eff. jStrokes Liner Stze ~ Circ. €iate WOB {min}: Slack Off W#.: Cum. Bit Hrs: WOB (max): Circ. Rate Riser: RPM Min.: Circe Rate Hole: Ann. Vel. Riser: (ft/min) RPM DH: Circ. Off Bottom: Ann. Vel. DC: (fUmin) 7orq. an Bottom: Circ. On Bottom: Ann. Vel. DP: {ftlmin) Torq. off Bottom: Jar Hrs since Inspect: {hr) BHA Bha No: 2 Depth In: 9,193.0 Bha Weight: Bha Type: DRESSING DOWNd?~h~t Dut: 9,193.0 Wt Below Jars: _ _ Component ; Companerit Detail _.. - _ - , Jis' Length ;Cum l.erigth: OD iD Blade OD Bend Angle; Gonnection ............ P!$ _...._..._. _ ..... ...... (ft} (in} Type {in} (in) Size {j~) ... . ..... : ~`> {~? i ; MILL ; Mi~L • DRESS _ ... .... _ . . . . .... ... . .. .. _ _ . .. __ . 1 4.30 : -4.30 1 8,500; 4.564: 8A00 TSWP.. ......_P SUB :EXTENSION 1 2.71 7.01 8.065 ` 7.315: 8.000 TSWP B SU8 W08007BASKET 1 4.32 ' 11.33 B.t25! 2.315 4.500 _. IF B MILL ;MILL - 70P DRESS 1 i 1.33 ' 6.250: 1.500; 4.500 IF B SUB 'XO 7 1.35 i 12.68 6.375' 2.250; 3.500 iF B SUB 'BUMPER SUB 1 7.90 ± 20.58 4,750 2.000; 3.500 IF B JAR FISHING JAR 1 11.11 31.89 4,750 2.000 ' 3.500 i IF B SU8 'GIRGULATION SUB 1 ` 1.71 ' 33.40 4.685; 1.815; 3.500 r IF B SUB ~ XO t 1.35: 34.75 ? 4.875 1.435 ! 4.000 i HT-3$ B GOLLAR ;:DRILL DOLLAR ! 9 ' 278.15 312.90 ? 4,750 ~ 2.250 4.000 HT-38 B Printed: 5/20af2009 7;11:37 AM • BP EXPLORATION Daily Operations Report Page 2 of 4 Operator: BP EXALORATION Rig: DOYON 16 Report: 6 We€I: A•31 Event: WORKOVER Date: 5!19!2009 Field: PRUDHOE BAY Weil Ty e: DEVELOPMENT I)riliin Fi~fit>7 Type: WATERJBRINE 10 sec gels: (Ib1100tt2} Ca: (mg/L) ES: (mV) TimelLoc: / i0 min gels: (Ibl100ftz) K+: {mglL) ~ Solids: (~°) Depth: {ft) , Fluid Loss: (CCi30min) CaC12: {°lo} Oi€: {%) Temp: {°F} HTHP Temp: (°F) ? NaCI; {°k} ;Water: (°to) Density: 9.80 {ppg} i HTHP WL: (cc/30rnin) CI-: {mgr'L} O€UWater: Funnel Visa: js/qtj : Cake: {/32"} :Sand: (%) :Daily Cuttings: (bb€) ECD: {ppg) MBT: (ppb} HG5: (ppb) I Cum. Cuttings: (bb€) PV: {cp) Lime: {ppb) LGS: (ppb) :Lost Downhole: (bbl) YP: {Ib/100ft~) PM: {mL} Pf/Mf: / (mUmL} :Lost Surface: {bbl} pH: O erations Summar From-To Hrs :Phase Task + Activity :Cade : NPT Operation Op _Depth :. {hr} :... _ . . 6:00.01:00: .00 DECOM CLEAN , RIH _ .. _. _ .. ........ _ __ ._..._ ._ . _. ~ P RIH with Dress Off BHA #2 on 4" H7-38 dri€€ pipe from 4,682' to 9,137 01:00-02:00: 1.00 DECOM,CLEAN RIGSER ................ ... P ~ Slip and cut 75' of drtlfing line. 02:00-04:00 . 2A0 DECOMCLEAid' MILL P tN/U Top drive and estab€ish parameters. P!U 190K, Si0 154K, ;Rotating weight 174K> 5 bpm at 540 psi, SO rpm with 5>000 ftlibs of ;torque. Tag top of tubing stub at 9>193". Work over top of stub. 60 rpm tat 5,000 - 7,500 f#!€bs of torque, 2-4K WOM, Vary pump rate from 3 !bpm to 6 bpm. Wash over stub to 9,198', 5' of swallow on assembly. Mill 3-4" off of tap of stub at 9,193'. Slide over stub severs! times to :insure that we can get Unique overshot over stub. 04:00.05:30 i.50 DECOMCLEAN i CIR P >Circulate 20 bbl sweep around at 11 bpm at 2,270 psi, No noticeable : increase m returns ; 05.3x08:30 ...__.._.. 3AO :DECOMCLEAN~ ..... ~ POH ... P '. Break out and blow down Top Orive, POOH sfanding back 4" tiT-38 drill p€pe in derrick. At std #44, drop DP rabbit. 08:30-09:30: 1.00 DECOM CLEAN : BHPULD P 'Stand back 3-stds of 4-3/4" DCs. LD BHA #2. Recover ~ 2-cups of metal shavings and scale in boo! basket. Recover DP rabbit with no ,. :_ ,Problem _.. .. . 09:30.10:00 : 0.50 DECOM;CLEAN : CLNRIG , P Clean & Glear rig floor. 10.0014:00 ; 4.00 . TIE81 . CASE "RU .._ f Load, Strap and daft fi-118 `DCs. Load and tally T' Scab Neer jewelry. RU to run 7" 26# L80 BTC-M Scab liner. Hold PJSM on running scab :liner with rig crew, Doyon Casing rep and Baker liner rep. Discuss :hazards, positions of peop€e, repetitive tasks and running order. ~ ~ Exfemal EMS auditors visit the rig and interview WSL & motorman. 14.00-15:00 1.00 , TjE61 CASE ` RU3V P RtH with 7" Scab tailpipe. Tailpipe oonsists of Unique Overshot, 4-112 x 7" XO, 1-jt of T 2fi# L80 BTC-M csg, HES float co€lar, 1-jt of 7" 2fi# L80 BTC-M csg and Baker Insert landing collar in the pin end of another full jt of csg. BakerLok all connections below the insert landing collar. MU BTC-M connections to the mark. Check floats - 15:00.22:30: 7.50 T€EBf :CASE RUN " P RIH with 154-jts of 7 26# L80 BTC-M scab liner. Use Best-O-Life :2000 thread compound. MU BTC-M connections to mark. Insta€€ one free-floating centralizer per joint. Fill casing "on the fly" and top off :every 5-jts. 22.30.23:30 1 A0 TIEB1 : CASE ' RUN ; P ? RlH with liner on 11-its of fi-11t3" DCs. RU to circulate. 23.30-00:00 j 0.50 ! TIEt31 : CASE' CR ~ P Circulate finer volume ai~5=bpm with 290-psi. as:oa u ate From-To Hrs :Phase Task I Activity Code NPT Operation Op. Depth {hr} 00:00.00:30 ', 0.50 TIE61 : CASE C€R P ;Finish circulating liner volume at 5-bpm with 370•psi. 00:30-01:30. t.00 . TIEB1 CASE RUN _ ..... _. P RIH with 7" Scab liner and 11 jts DCs On 26-stds of 4" DP from derrick. PU wt = 255K-Ibs, SO wt = 206K-Ibs. Prinlsd: 5/20/2009 T.1f;31 AM • 13P EXPLORATION Dail O erations Report Page s of 4 Operator: BP EXPLORATION Rig: DOYON 16 Report: 6 Well: A-31 Event: WORKOVER Date: SJf9/2009 Field: PRUDHOE BAY Well T e: DEVELOPMENT ©6'00 U date From-To Hrs ~ Phase ': Task Activity ;Code NPT Operation Op, Depth (hr) ' ' . . 01.30-02:30 ` 1.00 T-Ei31 CASE RUfV P Pil std #27 grid RlH. lag tbg stub of 9193'. Travel 2' acid set down 30K-Ibs. Observe shear. Continue RIH and no go ai 9200'. PU off of stub and run back in to confirm no-go with 3oK-Ibs down at 9200'. :Calculate space out. Stand back std #27, PU single jt of DP & RiH. MU cement head. RIH and space out mouth of OS at 9198' {2' off of ~ no-go). _ .... . 02.30-03:30 1.00 TIEB3 CEMT ~ SAFETY " P ;Hold PJSM on cementing with Schjumberger cemeniers, CH2MHi11 :truck drivers & pusher, Rig Crew, Baker liner rep, BP WSLs and Dayon tourpusher. Discuss Cementing plan, hazards, assign people to positions. Circulate at 5-BPM with 270-psi during safety meeting. _.... ...:_ ....:. .......: _.._ ....__! Schlumberger pnme up their.pumps..... . 03:30.04:00:0.50 TIEB1 CEMT ! RiGSER P iTroubleshoot stroke counter malfunction. 04.00.06:30 2.54 ~ TIEB1 CEMT CMT P - Tum over to SDirlumberger. Pump 5-bbis o€ water to PT lines to 4500 ;psi & check stalls. Good tests. Start pumping 15.8-ppg Class G :Dement (i.16 cu fUsk yield} downhole at 0415-hrs at 5-BPM with 600-psi. At 50-bbis away, pumping at 5-BPM with 600 psi. At 100-bbis away, pumping at 5 BPM and 650 psi, At 150 bbis away pumping 5 BPM (~ 650 psi, 186 bbis away (full job). Pump 5 bbis ;water to flush Dowell lines, swap lines & pump 10 bbis to drop plug. :Visual indication plug fell. Bring pumps on at 8-BPM and catch plug ;with 101-bbis displacement pumped. Slow pumps to 5-BPM, then to ':2-BPM and finally to .75-BPM io keep pressure below 3100-psi. ;Bump plug at 3012-stks pumped with 3000-psi. Slack off 20K-Ibs over !string weight and confirm Liner hanger is set. CIP at 0603-hrs. s Pressure up to 4000-psi and sat packer. Bleed pressure off and `check #loots -floats holding. Release rennin tool. Materials / Consum tion ........_... item _ ....:.. Units _.. Usage .: On Nand ... _ ............... Item _ _ ....,. _;..... Units Usage On Hand _ .. ULSDIESEL : 866: 10806 Personnel Company No. :Hours Company No. ;Hours : Company i No. ;Hours BP ...... _ ..... .. ...... ...... 1 12.00 FAIRWEATHER ..... _. ;.. 1. .._.12.00 Ia0YC7N_._.. _ ......, .. ...... ..2. 12.40 DOYON 24 12.00 DOYON 5' 12.00 BA 1 12.OD Weather Temperature H/L:! (°F} Windspeed: (Knts) Visibility: (nM) Precipitation: Bar. Pressure: {in} Wind Directi on: (°} Ceiling: (ft) Prec. Amount: {in} Wind Chill: Gust Speed: (Knis} Cumulative Phase Breakdown Planned Change of Scope Total ;Total Cost Phase Prod %Total; NPT ~oTotal, WOW %Total Prod °k Total: NPT %Totai; WOW %Total Hours USD PRE ..._.. _. .._...._.... 39.50 tD0.0% . ...._.._. _._..._ _.._. 39.50; 254,097.23 DECOMP 73.5D 1DOA% 73.50? 392,370.81 TIEBt 14.OD 100.0% 14.OD 3,850.00 .... TOTALS 127.00 100.D°!o 0.00 D O%i D.OD 0.0% 0.00 O.D%: 0.00 OA%; D.00 4.0°l0 127.00: 550,318.04 Remarks PJSM held before each operation. OAP = 0-psi Fluid foss today =-0 Bbis Fluid lost io date = 0 Bbls Diesel fuel used today = 866-gals STOPcards = THAs = Temporary Personnel =Robert Williams, Fill-in motorman on Tower crew New Employee =Darrel! Gallen, Derrickhand on Tower crew Printed: 5126/20Q9 7:77:31 AM BP EXpL,ORA710N Daily Operations Report Page 4 of 4 Operator: BP EXPLORATION Rig: DOYON 16 Report: 6 Well: A-31 Event: WORKOVER Date: 5/19/2009 Field: PRtJDHOE BAY Well Type: DEVELOPMENT Remarks 7 Leak - At 4am on 5/20109, the loader operator noticed same oil drips on the pad. Approximately 1-cup of engine oil was on the pad. The cause was the drip pan under the loader being over-full. 5700-was notified and the affected gravel was cleaned up. The drip pan was cleaned out and the loader will be Inspected by the mechanic prior to resuming operation. lR to follow. rnrnao; arzvr~uus ~:~~:a~ nM • C~ BP EXPLORATION Daily Operations Report Page 1 of 4 Operator: BP EXPLORATION Rig: DOYON 16 Report: 7 Well: A-31 Event: WORKOVER ,Date: 5!2012009 Field: PRUDHOE BAY Well Type: DEVELOPMENT Current Well Status Depth MD: (ft) Casing Slze; (in) Costs in: USD Rig Accept: 08:00 5N 6/2009 Est. TVD: {ft} Casing {MD}: (ft} Daily Mud: Rig Release: Progress: (ft) Next Casing Size: (in) Cum. Mud: Spud Date: 6130/1985 Auth Depth: (ft} Next Casing (MD}; {ft} Daily Well: WX Date: Hole Size: Next Casing (TVD}: {ft) Cum. Well: Elev Ref: MEAN SEA LEVEL DOUDFS(t•arget: tl Geologist: KB Elev: (ft) Engineer: Bjork Tot. Personnel: 33 Supervisor: Barker / Baca Program: Cost Ahead: 0 USD, Days Ahead: 0.00 Weather: 36 deg, WC 29,E 13 MPH Current Status: NU BOP Stack 24hr Summary: Cemented 7" Jiner, 20 bbls back, set liner hanger and packer. RIH w/ drill out BHA to 8480' & hang off qn storm packer. Pull 9.625° mandrel packof# through BOPs. 24hr Forecast: Replace packoff, drill out and test casing/liner to x000 psi Comments: No Incidents. No Injuries. 1-leak (see remarks) HSE & Well Control Days Since Last DAFWC: 4232 Ail Free Days 5 Last Csg Test Press.: {psi) Last Envir, Incident; 5/15/2009 Last H2S Drill: 5/20/2009 Last BOP Press. Test: 5/17/2009 Last Trip Drill (D1): St1912009 Next BOP Press. Test: 5/24/2009 Last Safety Meeting: 5/20!2009 Last Spill Drill: S/15/2009 No, Stop Cards: 5 Regulatory Agency Insp: N Non-compliance Issued: N FIRE: 5/18!2009 Pump Slow Pump Rates (Circ} ;Slow Pump Rates (Choke) Slow Pump Rates (Kill) TVD: (ft) 'Stroke Rate Pressure{) ;Stroke Rate Pressure{} ;Stroke Rate PressureO _ _ _ _ _ ,. _.._. _ ..._.. _ _. _ ..... . . .. EMW: (ppg} _ __. __.. _ _ _ ._ .. :_. _ _ . ._... MAASSP: (psi} _ _ _ _ __ _ . _ . Test Pressure: (psi} Kick Tolerance: (ppg) Kick Volume: {bbl} 4 erational Parameters ROP Daily: Rotating Weight: Daily Bit Hrs: {hr) Pump Status -Drilling and Riser ROP Cum.: Pick Up Wt.: Daily Sliding Hr5:0.00 {hr) Pump Type Eff. Shakes': Liner Siie ;Circ. Rate WOB (min): Slack Off Wt.: Cum. Bi# Hrs: {} () () (} WOB (max): Ciro. Rate Riser. __ _ _ ___ RPM Min.: Circ, Rate Hole: Ann. Vel. Riser: (fVmin) RPM DH: Ciro, Off Bottom: Ann. Vel. DC: {fUmin) Torq. on Bottom: Circ. On Bottom; Ann. Vel. DP: (iUmin} Torq. off Bot#om: Jar Hrs since Inspect: {hr} BHA Bha No: 3 Depth tn: 9,193.0 Bha Weight: Bha Type: DRILUDRESS CEMS~pTh Out: Wt Below Jars: Component ;Component Detail ! Jts ; Length Cum Length' OD ID Blade OD Bend Angle; Connection P/B __ _ (ft) (ft) {in) (in) {in) (°) :Size {in} Type .. .. . . _ .. .... . . _ . •.....3,500 _ ..;.._. REG P t3i~r-Mitt_ 7007H/r~.COivE _ _ _i_ . 0.65.: ..,,.0.85 6.125..... .. .__ ... BIT SUB 'BOOT BASKET 1 5.96 6.61 4.750 f .500 3.500 REG SUB BOOT BASKET 1 4.47 11.08: 4.750 1.5631 3.500 REG SCRAPER SCRAPER 1 ' 3.37 14.45: 5.375 1.2501 s 3.500 REG 5U6 BlTSUB 1 1.66 16.11 4.688: 1.563; ! 3.500 ` IF SUB BUMPER SUB 1 7.90: 24A1 ' 4.750: 2.000? 3.500 IF SUB x0 1 ' 1.35 ~ 25.36 ! 4.875 1.438; ? HT38 COLLAR DRILL COLLARS 9 278.15: 303.51 ' 4.750: 2.250 ? HT38 Printed: 5!21!2009 6:58:26 AM BP EXPLORATION Daily Operations Report Page 2 of 4 Operator: 8P EXPLORATION Rig: DOYON 16 Repoli: 7 Well: A-3 1 Event: WORKOVER Data: 5/20/2009 Field: PRl1DHOE BAY Weii T :DEVELOPMENT Drillin Fluid Type: WATERBRINE 10 sec gels: (Ib/100ft2) ' Ca: {mg/L} ES: (mV} Time/Loc: / 10 min gels: (Ib/100ft2} j K+: {mg/L) Solids: (~o} Depth: (ft) Fluid Loss: (cc/30min} CaCl2: (%} Oik {%} Temp: (°F) HTHP Temp: (°F) NaCI: (°lo) Water: {°k) Density: 9.80 (ppg} HTHP WL: {cc/30min) CI-: {mglL) ' Oil/Water: I Funnel Visc.: (sJgt) Cake: (/32") ;Sand: {%) Daily Cutkngs: (bbl) ECD: (ppg} MBT: (ppb) HGS: (ppb} :Cum. Cu#tings: {bbl) PV: (cp} . Lime: (ppbj LGS: (ppb} Lost Downhole: (bbl) YP: (Ib/tOpft2) PM: (mL) Pf/Mf: I (mLImL) LostSuRace: {bbl} H: O stations Summa From-To Hrs ;Phase ; Task Activity :Cade ' NPT Operation Op. Depth {hr} _ ' .... - 00:00-00:30 0.50 ° T1EB1 CASE CIR ; P Finish circulating liner volume at 5-bpm with 370-psi. 00.30-01:30 1.40 ; T1E81 , CASE ~ RUN ,.....P ~ RIH with T` Scab liner and 11-jfs DCs on 26-stds of 4'` DP from :derrick. PU wf = 255K-Ibs, SO wt = 206K-Ibs, 01.30-02:30 1.00 ; TIEBi CASE RUN P PtJ std #27 and RIH. Tag tbg stub at 9193'. Travel 2' and set down 30K-Ibs. Observe shear, Continue RIH and no go at 9200'. PU off of stub and run back in to confirm no-go with 30K-Ibs down at 9200'. Calculate space out. Stand back std #27. PU single jt of DP &RIH. MU cement head. RIH and space out mouth of OS at 9198' (2' off of .... ...... .._...._. no-go}..... . 02:30-03:30 1 AO TIEB1 CEMT SAFETY P 'Hold i'JSM on cementing with Schlumberger cementers, CH2MHiil :truck drivers & pusher, Rig Crew, Baker liner rep, BP W SLs and Doyon tourpusher. Discuss cementing plan, hazards, assign people to positions. Circulate ai 5-BPM with 270-psi during safety meeting. Schiumberger prime up their pumps. ._.. . 03.30.04:00 0.50 TIEi31 ,CEMT ° RIGSER P ~ Troubieshcot stroke counter malfunction. 44.0008:30 2.50 T1EB1 CEMT " ..... CMT '.. ~ ~ Tum over fo $chlusnberger. Pump S-bbis ofwater to PT lines fo 4500 :psi & check stalls. Good tests. Stag pumping 15.8-ppg Class G `cement (1.16 cu ftlsk yield) downhole at 0415-hrs at 5-BPM with 600-psi. At 50-bbis away, pumping at 5-BPM wlth 600 psi. At :100-bbis away, pumping at 5 BPM and 650 psi. At 150 bbis away ;pumping 5 BPM ~ 650 psi, 186 bbls away {full job}. Pump 5 bbis :water to flush Dowell lines, swap lines & pump 10 bbis to drop plug. :Visual indication piug fell. Bring pumps on at 8-BPM and catch plug with 101 •bbis displacement pumped. Slow pumps to 5-BPM, then to '.2-BPM and finally to .75-BPM to keep pressure below 3100-psi. ' !Bump piug at 3012-stks pumped with 3000•psi. Slack off 20K-Ibs over ', string weight and confirm liner hanger is set. GIP at 0603-hrs. Pressure up to 4000-psi and set packer. Bleed pressure off and check floats -floats holding. Release running tool, 06:30-07:00 ' 0.50 TIEB1 CEMT ! CIR P Pump 50-bbis at 14-BPM with 1270-psi. Confirm packer set. i Circulate citric sweep out of hole, monitoring for cement returns. See . - .. _ ._ ... . .......:...... ...... i. approximately 20-25,bbls of good cement at surface........ 07:00-08:00 i.00 TIEBi :CEMT ! LD P LD cement head. 08.00 09:30 1.50 TIEB1 CEMT ' POH P ~ ; POH w/ liner running tool. Stand back 26-stds of DP and 3-stds of 09.30-f4:40 d.b0 , TIE81 . CEMT 6-1/8" DCs to pipe shed. CLNRtG P Flush BOP stack, Choke & Kill lines with Citric pill, _ 10.04-10:30 0.50 ~ TIEB1 CEMT _. ~ SAFETY P ~ Hold meeting with Uoyon Board members and Tower crew. 10:30-i1i30 1.00 , TIEr3i CEMT S RIGREP ; ......N _._ _ . ' RREP 'Repair hose reel on pipe skate. 1 L30-12:40 0.50 TIEB1 'CEMT .. ...... LD .....P LD 2-jts of 6-1/8' DCs and Liner Running tool to pipe shed. Printed: 5/21/2009 6:58:26 AM 8P BXPLORATION Daily C3perations Report Page 3 of 4 Operator: BP EXPLORATION Rig: DOYON 16 Report: 7 Well: A-31 Event; WORKOVER Dafe: 5/20/2009 Feld: PRUDHOE BAY Well Type: DEVELOPMENT O eratians Summa From-Ta Hrs Phase i Task Activity ! Code ' NPT Operation Op Depth ( hr) " ...... 12.00-13:30 ; 9 .50 ~ TIESi ; CEMT ` LD P ~ RIH with 3-stds of 6-9/8" DCs, f'OH, Iay'ing down same to pipe shed; 13:30-14:30. 1 .00 . TIE81 ; CEMT : WASH `:. . P.. PU BbP stack washer and RIH, washing BOP stack. Drain stack and '. pull riser. Clean as needed and check air boats. 14.30 15:00 0.50 . TIE$1 ~ CEMT : ...~~. ! P PU cement head and break out all rig equipment (TIW valve, pup & _. _ .._ 15.00 16:00 ; 1 .00 ` TIEt31 DRILL" l3iiPULD `, P ;1'JSfN on MU BNA #3, t3HA consists of: 6.125" tr'icone bit, two (2) 4.75" boo# baskets, casing scraper (7"}, bumper sub, nine {9) 4.75" ;spiel collars. 16A0 18:30:"2 .50 TIE81 DRILL' RIH P ~ RIH with BHA #3 to 8368' -18.30-19:30 1 .00 TIEB1 DRILL PKRST .;. __ ... P PU storm packer and set same 1 stand below rotary. 17Sk# up wt, 140k# down. Packer tested to 1000 psi far 10 charted minutes. LD running #ool wl diaper ... _..... 19.30-23:30 2 _ .00 . TIEB1 WHSU ~ PUL P Pull wear bushing and pc+fl 9.625" mandrel paokoff through BOPS. Packoff came free with approximately 25k#. casing started to grow as fins] lock down pins were being backed out. Old packoff showed old (not shiny internal damage) and new (shiny) scars frm several LDS. Unable to seat new packoff as casing relaxed from compression ~4°. Set top drive down on packoff running tool, unable to see any part of new packoff, peering through open LDS hole: 29:30-22:00 0 .50 ; TiEB1 _ WHSU SAFETY P Dtscuss options with Driller/TOUr PusherlHalliliurtoNCameron. Decision made to unsemt storm packer, S8 4 stands drill pipe, PU 11 `6" drill collars and reset storm packer for -2pk net weigh# gain to attempt to force casing ,back down w/o breaking BOP stack. _. . 22:00-00:00' 2 .00 ° T1E81 ~ WHSIJ! POH . _ _ P ;Unseat storm packer & break circulation to ensure circulating valve ' clear prior to LD same. SB 4 stands drtEl pipe, PU 11 6" collars. 06.00 El date From-To !Hrs ;Phase ' Task Activity Code NPT Operation (hr) Op. Depth _. _. _. . _ 00:00-01:00 ; 1 .00 . TIE81 ~ WHSU ~ PKRST PlJ storm packer and set 1 stand below rotary table. Still unable to set ' mandrel packoff with top drive weighs on running tocl & -20k# more f !weight. Decision made to ND BOPs and reassess. .. _ 01:00-01;30 : 0.50 ~ TIEB1 WHSU' PKRST _ _ Pressure test packer to 1000psi for 10 charted minutes (2 #esied barriers are WRPipacker & storm packer}. 01.30-03:00 ~ 1 .50 TIEB1 BOPSU: ND ~ ND BOPs & tubing spoet. New Packoff seals damaged. 03:00.04:30 1 .50 TIEBi WHSU ; INSTAL ~ _... . Re•dress packoff seals. Attempt fo farce packoff down by set#ing '. stack weight on it without success. Remove packoff. 04.30.06:00: 1 .50 . TIE81 BOPSU NU ~ i NU BOP stack. Materials 1 Cansum tion I tem Units ; Usage On Hand Item Units Usa a On Hand :_ .... 9 _ ..... _ ... __. l)LSDIESEL _ _ 1941 8865 Personnel Gompany No. :Hours Company _ No. 'Hours _ _ ... ._ . Company No, Hours _ ... _ .. ._.. aP _ _ ... 1 12.00 BP 1 12.00 12.00 2: DOYON DOYON 24 12.00 DOYON 5 12.00 Weather Temperature H/L:I {°F) Wtndspeed: (Knts) Visibility: {nM) Precipitation: Bar Pressure: (in} Wind Direction: (°) Getting: {ft} Prec. Amount: {in} Wind Chtll: Gust Speed: (Knts) Cumulative Phase Breakdown Planned Sco a Change of P ... Total Total Gost Phase Prod % Total NPT °k Total i VYOW % Total . .. . _ q° Total Prod °l° Total: NPT °~ Total; WOW ..... Hours USD ....... PRE .......... .. ... ..._39.50 100A/°: ___..... _... 33.50: 254,097.23 DECOMP 73.50 100.0%! . . 73.50; 392,370.81 TOTALS 150.0© 99.3%° is _ t _00 ......0 7%! 0.00 i7.0°10 ..0,4%0 ; 0.00 0.0°fo 0.00 0 0% 0,00 _ . 151 00 ; t3s4,484.04 PnntOQ: 5/2t/2009 8:59:213 AM • BP EXPLQRA7i~N Dail O eratlons Report Page 4 of 4 Operator: BP EXPLORATION Rig: dOYON i6 Report: 7 Welt: A-31 Event: WORKOVER Date: 5/20/2009 Field: PRUJHOE BAY Well Type: DEVELOPMENT Cumulative Phase Breakdown Planned Change of Scope Total :Total Cost Phase Prod °lo Total: NPT 9'° Total WOW % Total Prod % Total NPT °~ Total; WOW °l° Total Hours USJ TIE63 37A0 97.4°l0 1.00 2.6% 38.00: 218,016.00 707ALS .. .. 150.40 983%; 1AQ 0.7% 0.00 O.Q% O.QO 0.0%` 0.00 dA°!o 0.00 0.0°!0 151.00 864,484.04 Remarks PJSM held before each operation. OAP = 0-psi Fluid loss today =0 Bbls Fluid lost to date = 0 Bbls diesel fuel used today = 1941-gals STOP cards = 5 THAs = 7 Temporary Personnel =Robert Williams, Fitl-in motorman on Tower crew New Employee = Jarrell Gallen, derrickhand on Tower crew 2 barriers to Nd BOP stack are i) WRP at 9259' and 2} Tested Storm Pkr and 3} 7" cement and float equipment. 1 Leak - At 4am on 5!20!09, the loader operator noticed some oil drips on the pad. Approximately 1-cup of engine oil was on the pad. The cause was the drip pan under the loader being over-full. 5700-was notified and the affected gravel was cleaned up. The drip pan was cleaned out and the loader was inspected prior to resuming operation. IR # 3077476. Printed; 5f21t2009 6:56:2& AM • BP ~XPLQRATION Dail ~ eratior~s Report Page 1 of 3 Operator BP EXPLORATION Rig: DOYON 16 Report: $ Well: A-3t Event: WORKOVER Date; 5!2//2009 Field: PRUDHOE BAY Well Type: DEVELOPMENT Curra3n# Welt Status Depth MD: {f#} Casing Size: {in) Costs in: USD Rig Accept: 08:00 5Ji 612009 Est. TVD: (ft) Casing (MD}: {ft) Daily Mud: Rig Release: Progress: (ft) Next Casing Siza: {in} Cum. Mud: Spud Date: 6/30!1985 Auth Depth: (ft} Next Casing (MD): (ft) Daily Well: WX Oate: Hole Size: Next Casing (TVD}: (ft) Gum. Well: Elav Ref: MEAN SEA LEVEL DOUDFS/Target: !! Geologist: KB Elev: (ft) Engineer: BJark Tat. Personnel 33 Supervisor: Barker / Baca Program: Cost Ahead: 0 USD, Days Ahead: 0.00 Weather: 24 deg, WG 11, E i7 MPH ..................... _. Current Ste#us: Rigging down Schlumberger E hne. 24hr Summary: Set, Test Storm packer. ND BOP stack. Attempt to install packaft. NU BOP stack. Test below Storm packer. Test Csg/Tbg spool break, Release Storm packer. CBU. Monitor well. Test break to 2500-psi. POH. LD DCs. Stand back DP. LD BHA #3 -Drill Out. 24hr Forecast: PU RTTS,Tast Csg. RU Eline. USIT log, RD Ellne. Set RBP. Comments: No Incidents. No Injuries. No Environmental Releases. HSE & Well Control Days Since Last DAFWG: 4233 Ali Free Days: S last Csg Test Press.. (psi} Last Envir. incident: 5!15/2009 Last BOP Press. Test: 5/17!2009 Last Trip Drill (Di): 5/19/2009 Next BOP Press. Test: 5!24/2009 Last Safety Meeting: 5/21/2009 Last Spill Drill: 5/21/2009 No. Stop Cards: 8 Regulatory Agency Insp: N Noncompliance Issued: N FIRE: 5/18/2009 _ _. Pump ': Slow Pump Rates (Circj ~ Slow Pump Rates (Choke} ' Slow Pump Rates (Killj TVD: {ft) s Stroke Rate Pressure(} :Stroke Rate Pressure(} 'Straka Raie PressureO (psi) Test Pressure: (psi} Kick Tolerance: {ppg) Kick Volume: {bbl} O rational Parameters ROP Deify: RataUng Weight: Daily Bit Hrs: {hr} Pump Status -Drilling and Riser ROP Cum.: Pick t1p Wt.: Daily Sliding Hrs:0.00 {hr) :Pump Type; Eft Strokes: Liner Srze Crrc. Rata WOB (min): Slack Off Wi.: Cum. Bit Hrs: WOB (max}: ........ Circ. Rate Riser: RPM Min.: Circ. Rate Hole: Ann. Vel. Riser: (#Umin) RPM DH: Circ. Off Bottom: Ann. Vel. DC: (ft/min) Torq. on Bottom: Circ, bn Bottom: Ann. Vel. DP: (iVmin} ; Torq. off Bottom: Jar Hrs since Inspect: (hr) BHA Bha Na: 3 Depth In: 8,400.0 Bha Weight: Bha Type: DRILUDRESS CEM1~bTh Out: Wt Below Jars: _. Gampanent Component €~etaii J#s' Length Cum Lengfti; ~pD 10 Bfada ~D Bend Angle; ~ Conn®ction P/B (in} {n) {ft) . _ eft) (in} __ (~) 'Size (in} TYPE . . : ~ _ . . _ . , .... ... BIT BIT-MILL70oTHlR.CONE i 0.65; 0.65 6./25 3.500 REG P SUB BOOT BASKET 1 5.96 6.61 4.750' 1.500; i 3.500 REG SUB ;BOOT BASKET 1 ' 4.47 1 t.08 i 4.750` 1.563 ~ i 3.500 ' REG SCRAPER ;SCRAPER 1 3.37: 14.45:. 5.375: 1.250; 3.500 ' REG SUB 81TSU8 1 i,66 16.11 i 4.588 1.583; 3.500 IF SUB BUMPER SU8 1 7.90 24.01 ' 4.750; 2.000; 3.500 IF SUB iX0 1 i,35 25.36 ! 4.875: 1.438: HT38 COLLAR DRILL COLLARS 9 i 278.15 ~ 303.51: 4,750: 2.250: I HT38 Printetl: SN22/2009 7:IS:59 AM BP EXPLORATfON Daily Operations Report Page 2 of s Operator: BP EXPLORATION Rig: DOYON 16 Report: $ Well: A-3i Event: WORKOVER Da#a: 5/21/2009 Field: PRUDHOE BAY Wei€ Typa: DEVELOPMENT Orillln Fluld Typa: WATER/BRINE 10 sec gels: (Ib/100ft~j i Ca: (mg(L) ES: {mV) TimelLoc: / 10 min gels: (Ib1100ft2} K+: (mg/L} Solids: (%} Depth: {ft) : Fluid Loss: (eel30min) CaCl2: {°!°} Oii: (°!°} Temp: (°F) HTHP Temp: (°F) ' NaCI: {%) :Water. (°~} Density: 9.80 (ppg) HTHP WL: {cc/30min}: CI-: {mg/L} OilANater: / Funnel V€so,: (s/qt) : Cake: {/32") Sand: {°l°) :Daily Cuttings: (bbl) ECD: (ppg} MBT: {ppb) HGS: (ppb} ;Cum, Cuttings: (bbl) PV; (ep) ` Lima: (ppb} LGS: {ppb) :Lost Downhole: (bbl) YP: {tb1100ftz} PM: (mL) Pf/Mf: ! (mL/mL) ;Lost Surface: (bbl) pH: O stations Summer From-To Hrs 'Phase Task Act€vity ;Code NPT Operation Op. Depth (hr) 00.00-01:40 1.00 TEE61 WHSU PKf35T P "' PU s4ortn packer and set 1 stand below rotary table. Still unable to set :mandrel packoff with tap drive weight on running tool & -20k# more i ! weight. Decision made to ND BOPs and reassess. _. __ - Oi.00-01:30 ; 0.50 TIEBi WHSU PKRST P Pressure 4est packer to IODOpsi for l0 charfed minutes {2 tasted ' . _ barriers are WRP/packer ,& storm packer): .. . ~ 01:30-03:00 t.50 T'IEB1 BOPSIJ ; ND P '. 'fVD BOPs & tubing spoof. €dew Packoff seals damaged. 03;00-04:30 1.50 TIEB1 :WHSU INSTAL P ' Re-dress packoff seals. Attempt to force packoff down by salting ' ' stack weight on it without success. Remove packoif. ~ 04.30-06.00 1.50 TIEB1 ~BOPSU~ NU P `NU B©P stack. 06:00.09;30 ' 3.50 ' TIE61 'WHSU WAIT P Consult w/ town regarding plan forward. Order cold €ake water trucks and locate sufficient drill callers for -300,000-Ibs to hang off of storm ., ;packer. Perform light maintenance and housekeeping throughout rig. _ 09.30 15:00 ' 5.50 T1E81 ' LVHSU : TSTPFiS P MU Storm Packer retrieving tootand RIH. Engage pac€cer, check for PSI and break circulation. Set Starm packer. Attempt to tesk below storm packer to 1000-psi for 10-charted minutes, When pressured up, getting f€uid retums from OA. Returns increase when pressure is applied and continua even after multiple pressure cyc€es. €nsta€i !gauge and sensor on OA and chart test pressure and OA at same time. Chart shows OA tracking exactly with area being tasted. Drain BOP stack and observe as test prassura is applied. See returns from the 13-318° around the 9-$/8" casing and mandrel hanger. 9.625" - Eeaking. Notify RWO engineer of situation. 15.00 15:30; 0.50 TIE61 WHSl3 TSTPRS P ~ Release storm packer. Allow elements to re€ax. Ctose annular ;preventer and test BOP stack, flange break, 9-518" casing, 7" scab to f€oat equipment and QA to 2000•psi for 10-charted minutes. Good :.test 15.30-16:00:0.50 ; i'IE81 WHSU'. _. LD _..P ' POH.-Stand back 1-std & inspect storrri packer. Packer a€ements are in "like new" condt€on LD storm packer to pipe shad. __ 16:00-19:00 3.00 TIE81 : WHSU CIR P PU f -std of I?P. MU to string and RIH. MU to Top Drive and CBU at 10-BPM with 1800•psi. Gat large amount of crude and gas breaking ' out in retums. Continua to c€rculate at 10-BPM with 2000-psi and then :reduce rate to 6-BPM with 700-psl. Pressure on OA while circa€ating = 0-psi. . _. _.. 19:00-19;30 ; 0.50 TIE61 . WHSU INSP P Monitor well -Static. Discuss tan forward with town to cut and uli p p 9-5i8" casing to repair teak. Close annular preventer and test BOP stack, flange break, 9-5/8" casing, 7" scab to float equipment and OA _. to 2500 psi for 10-charted minutes as MASP is 2440psi. Good test. ~ 19,30 23:30 ! 4.00 TIEBi ' WHSU POM P ; PO~Fi LD 11-jts of 6"collars, Stand back 4" DP in derrick, 23:30.00:00 0.50 i Tlf[31 :1NHSU' . ....... BHPl1lD , ,..P. ' Lf~ BHA fl3 - T` dri€f oiii. _ P~intetl: 5(22/2069 7a 6:53 AM • C~ BP EXPLORATfON Daily operations Report ~~~$ ~ Or ~ Operator: BP EXPLORATION Rig; DOYON 16 Report: 8 W011: A-31 Event: WORKOVER Date: 5/21!2009 Field: PRUDHOE BAY Well T pe: DEVELOPMENT 06.00 U date From-To Hrs :Phase . Task Activity Code ~ NPT Operation Op. Depth (hr} 00:00.00:30:0.50 TIEB1 DRILL LD P :Finish LD BHA #3. 00.30.01:30 1.00 : TIEB2 EVAL' RIH P PU & MU 9-518" RTTS. R3H and set at 1052' (COE). __. __ .... Oi.30 02130 ; 1.00 ~ 71E82 EVAL _ ........ ......... ;. ...... _._.._... ....P TSTPRS f' RU to ressure test below RT7S, Pressure test below fo 1000-psi for 5-minutes. Bring pressure up to 4000-psi and hold for 30-charted minutes -Good test. 02.30-03:00 0.50 : TIEB2 ,EVAL .. __ __. POH P ~ Release RTTS. POH. Stand back OP in derrick. LD RTTS. 03.00-04:00 , 1.00 ~ TI~82 . EVAL RU P ~ ;Hold PJSM with Schlumberger and craw on RU E-line. RU ! 04:00-06:30 ; 2.50 . T1~f32 : EVAL. _ Schlumber~er E-line. _. p1AG P ' Schiutnberger t1SIT log from 2500' to surface. Materiats / Consum #ion Item Uni#s Usage On Hand Item Units Usage On Hand ULSDIESEL ' 960; 7905 Personnel Company No. :Hours Company No. :Hours Company No. !Hours BP 1' 12.00 BP 1' 12.00 DOYON 2! 12.00 DOYON 24 12.00 DOYON 5; 12.00 Cumuia#ive Phase Breakdown Planned Change of Scape Total !Total Cost Phase Prod °k Total; N P7 °~6 Total WOW °lo Total Prod %o Total ~ NPT % Total ~ 1NO1N °Io To4a1 Hours USD PRE 39.50100.0°k. 39.50 254,097.23 DECOMP 73.50 100.0°k l 73.50 392,370.81 TlEBi 61.00 8$.4%' 1.00 1.6% 62.00; 28$,297.00 TOTALS 174.00 99.4°k 1.00 0.6°!0 0.00 OA°k 0.00 0.0% 0.00 OA% OAO 0.0% 175.00: 934,765,04 Remarks PJSM held before each operation. OAP = 0-psi Fluid lass today =-0 Bbls Fluid last to date = 0 Bbls Diesel fuel used today = 960-gals STOP cards = 8 THAS = 7 Temporary Personnel =Robert Williams, Fill-in motorman on Tower crew New Employee =Darrell Gallen, Derri ckhand on Tower crew 2 barriers to ND BOP stack are 1 } W RP at 9259' and 2} Tested Storm Pkr and 3} 7" cement and float equipment. Printed: 5t22/2009 7:38:59 AM SP EXPLORATION Dail O erations Report Page 1 of 2 Opera#ar: BP EXPLORATION Rig: DOYON 16 Report: 9 Well; A-31 Event: WORKOVER Date: 5/22!2009 Field: PRUDHOE BAY Well Type: DEVELOPMENT Current Welt Status Depth MD: {ft} Casing Size: {in) Costs in: USD Rig Accept: 08:00 5/16/2009 Est. TVp: {ft) Casing {MD}; {ft} Daily Mud: Rig Release: Progress: (ft} Next Casing Size: (in) Cum, Mud: Spud Date: 6130/1985 Auth Depth: (ft) Next Casing {MD): {ft) Daily Welt: WX Date: Hate Size: Next Casing {TVD): (ft) Cum, Welt: Elev Ref: MEAN SEA LEVEL DOUDFS/Target: !( Geologist: KB Elev: {ft} Engineer: Bjork Tot. Personnel: 33 Supervisor: Barker / Baca Program: Cost Ahead: 0 USD, Days Ahead: 0.00 Weather: 24 deg, WC 31 E 17 MPH Current Status: _.. ...._ .... 24hr Summary: LD BHA ##3. MU RTTS. RIH. Set at 1052'. Test below. POH. LD RTTS. RU E-line. USIT log far TOC in OA. RD E-line, MU 9-518" RBP. RIH. Set, Test RBP. 24hr Forecast: Comments: No Incidents. No Injuries. No Environmental Releases. HSE & Well Control Days Since Last DAFWC: 4234 A!1 Free Days: 7 , Last Csg Test Press.: (psi} l..ast Envir. Incident: 5/15/2009 Last BOP Press. Test: 5!1712009 Last Trip Drill {D3 }; 5/19/2009 Next BOP Press. Test: 5!2412009 Last Safety Meeting: 5/21/2009 last Spill Drill: 5/23/2009 No. Stop Cards: Regulatory Agency Insp: Non-compliance Issued: FIRE: 5(1812009 __ _ , ._ ........... Pump Slow F'usnp Rates (Circ} Siow Pump •Rates (Choke] Slaw Pump Rates (Kill) TVD: {ft} Stroke Rate Pressure{} Stroke Rate Pressure{} :Stroke Rate Pressure{) EMW: {ppg) MAASSP: _........... _ .. .. . . __ Test Pressure: (psi} Kick Tolerance: {ppg} Kick Volume: {bbl) O erational Parameters ROP Daily: Rotating Weight: Daily Bit Hrs: {hr} Pump Status -Drilling and Riser ROP Cum.: . _ .. Pick Up Wt.: Daily Sliding Hrs:0.00 {hr) Pump Type Eff :Strokes' Liher Size: Ciro. Rafe WOB (min}: Slack Off Wt.: Cum. Bit Hrs: O (} O {) WOB (max): Circ. Rate Riser: __ _ ., ,.... ,. __ .. ,_. _. . RPM Min.; Circ. Rate Hole: Ann. Vel. Riser: {fUmin) RPM DH: Circ. Off Bottom: Ann. Vef. DC: {ft/min} Torq. on Bottom: Circ. On Bottom: Ann. Vel. DP: {#Vmin} Torq. off Bottom: Jar Mrs since Inspect: {hr} BHA Bha No: 3 Depth In: 8,400.0 Bha Weight: Bha Type: DRILUDRESS CEMS~{b'f}1 Out: 8,400.0 W# Below Jars: Component .Component Detail _ . . Jts Length Gum Length OD ID Blade OD;Bend Angles ~ Cohneotion P/8 _ . {ft} (ft} (m? (m} {m} Size(in) Type ' {` ) _ : . ... . .. . ... ._... ... .~ _....... t3ir BiT=t~ii.L Tti0T~t1i~.CONE _ t 0.65 `~ 0.65. 6.125... 3,500 REG P SUB ;BOOT BASKET t 5.96 6.61 ! 4.750: 1.500: 3.500 REG SUB 'BOOT BASKET t 4.47 ' 11.08 ` 4.750'. 1.563 ! 3.500 REG SCRAPER SCRAPER 1 3.37 14.45 i 5.375 1.250: 3.500 REG SUB :BIT SUB 1 1.66 '; 16.11: 4.688: 1.563: 3.500 IF SuB :BUMPER SUS 1 7.90 ! 24.01 4.750' 2.000: 3.500 IF SUB 'XO t ! 1.35 25.36 4.875! 1.438' HT38 COLLAR :DRILL COLLARS 9 2X3.15 ' 303.51 4.750: 2.250: HT38 PrfMed: 5(22/2W9 7:18:14 AM BP EXPLORATION Daily Operations Re ort Page 2 of 2 Operator: BP E XPLORATION Rig: DOYON i6 Report: 8 Well: A-3i I~vent: WORKOVER Date: 5/22/2009 Fietd: PRUDHOE BAY Weil Type: DEVELOPMENT Drillin Fluid Type: WATER/BR1NE 10 sec gels: (IbI100ft2) _. Ca: (mg/L} , ES: {mV) TimelLoc: ! 10 min gels: {tb/100(t~} K+: (mg/L} :Solids: (%) Depth: {ft) Fluid Loss: {cc/30min}' CaCl2: (°k} Oil: {°~) Temp: (°F} HTHP Temp: (°F} NaCI: (%} :Water: (°!o) Density: 9.80 {ppg} HTHP WL: (cc/30min) CI-: (mg/L) Oil/Water. / Funnel Visc.: {s/qt) : Cake: (/32") :Sand: {°~} Daily Cuttings: (bbI) ECD: (ppg) MBT: (ppb} HGS: {ppb) ;Cum. Cuttings: (bbl) PV: {cp} L'sme: (ppb) LGS: {ppb} :Last Downhole: {bbi} YP: {Ibi100ftx) PM: (mL) Pf/Mf: i {mUmL) ;Lost Surface: (bbl} pH: O erations Sumrnar From-To Hrs 'Phase Task Activity Code NPT Operation _ dp. Depth .. _ ~!?~> . ; ....... 00:00-00:30 0.50 : TIEBi DRILL LD P. Finish LD BHA 1F3. 00:30-01:30 ; 1.00 ~ TIEB2 ; EVAL. : RIH P "" "° PlJ & MU 9-5/i3" RTTS. F11H and si;t af1052' (COE), 01:30-02:30 _ 1.00 ` TIEB2 EVAL ` TSTPRS P RU to pressure test below RTTS. Pressure test below to 1000-psi #or i 5-minutes. Bring pressure up to 4000-psi and hold for 30-charted ' 'minutes -Good test. ~ 02.30 03t00 . 0.50 TIE82 . EVAL . POH _....... P Release RTTS. POH. Stand back DP in derrick. LD RTTS. 03:00.04:00 1.00 ~ TIE62 , EVAL _ _ R11 ;.. . ..p .. ....... ..............:Mold PJSM with Schlumberger and-crew an RU E-line. RU_.._. _... _ , ,,_... ~ Schlumberger E-line. .. 04:00-06:30 2,50 !TIEB2' EVAL ' DIAG P Schlumberger USiT log from 2500' to surface, 06:30-07:00 0.50 TIEB2 EVAL . RD P . _ _ _ ._ RD E-Ifne unit. 07:00- 0.00 'TIEB2 DFiB VIiAIT P Wait for Halliburton to arrive with $-5113" RE3P. Materials / Consum tion Item Urnts Usage On Hand Item Units Usage '. do Hand ULSDIESEL _ ... ... . . 0 7905 . Personnel Company No. : Hours Company No. i ~ours No. Hours Company BP . ... . 1 12,00 ._ BP ... . . . ... ___ .. .. 1 ` 12.00 ...... ............. DOYON 2 12.00 DOYON 24' 12.00 DOYON 5; 12.00 Cumulative Phase Breakdown Planned Change of cope Total ;Total Cost Phase __ . _ ._ Prod °/° Total : NPT % Total : .. WOW °!° Total Prod % Total: NPT % Total. WOW °/, Total Haurs USD PRE 38,50 100.0%._ ... _. _.._ ...... . ........ ........_. ._. .. _._.. _. _ _ .. __ _ _.._38.50:...254,09723 DECOMP 73.50 100,0% 73.50; 382,370.81 TIEB1 61.50 98.4% 1A0 1.&°l0: 62.50: 288,287A0 TIEB2 6.50100.0°l0 6.50: 70,281.00 TOTALS 181.00 995%; 1.00 0.5%~ 4.00 0.0% 0.00 0.0% 0.00 0.0%, 0.00 0.0°l0 #82A0 #,005,046.4 Remarks Printed: 5r2212~9 7;18:14 AM ~~= 4'•~~ WELLHEAD= McEVOY ~ A 31 Y NOTES: CHROME TBG. WELL EXCEEDS 70° @ & GOES HORIZ@ 9805'.waRNING:RADlO A ~` ACTUATOR= BAK KB ELEV= 61 17' TRANSMITTER IN W FATHER MONITORING SHACK MUST . . BF.ELEV= 52.19' Propose BE TURNED OFF BEFORE ANY W ELL W ORK INVOLVING d EXPLOSIVES CAN BEGIN. CONTACT PO. "'"PROD CSG X KOP= 3450' FORMATION LEAK`"' Max Angle = 109 C 10053 DawmMD= ss3o• g_5/8" HES ES Cementer ' - 1920` Datum ND= 8800 SS °-5/8" BKR ECP 1950` 2000' =-° % Nip. Ir-, 9-5/8'` Bowen Casing Patch - 1970` 9-5/8" 47#, L-80, Hydril 563, ID=8.681" 1970` 13-318" CSG, 72#, L-80, ID = 12.347" 2668' - 2900' °-~~'~~ x 7" Z71P and Rexlock H~,~uier 7" CSG. 26#. L-80. BTC-M. ID = 6.276" 2900'-9192 8,933' d-112" HES 9G ? -Nip. ID=3 013 X 8,965' 7' S 3 Packer 4'~';>' TF~~~ '~„~I L s!,~ Tr, II ID ss~.~,~° -8,965' - ' 4-1/~ ~ Nip. ID=3.813 9,005 Minimum ID = 2.37" @ 9285' 9.077' 4-1;~~~ "E` `'c' xN-Nip. I°=a 72~ TOP OF 2-7/8" LNR 9210' 4-1/2" PARKER SWS NIP, ID = 3.813" TOP OF 7" LNR 9248' 9222' 9-5/8" X 4-1/2" TNV HBBP PKR, ID = 3.875" 4-1/2" TBG, 12.6#, NT13-CR, .0152 bpf, ID = 3.958" 9310' 3.75" BKR DEPLOY SLV, ID = 3.00" 9277' TOP OF 2-7/8" LNR, ID = 2.37" 9285' 9-5/8" CSG, 47#, L-80, ID = 8.681 " ~~ 9512' 9270' ~~TOP OF BKR KB PKR W/ SEAL ASSY, ID = 2.56" 9277' 3.0" BKR SEAL ASSY, ID = 2.40" 927$' 4-1/2" PARKER SWS NIP, ID = 3.813" 929 4-1/2" PARKER SWN NIP, ID= 3.80" 9311' --I4-1/2" WLEG, ID = 3.958" 9300' ELMD TT DATE NOT AVAILABLE MILLOUT WINDOW 9586' - 9593' PERFORATION SUMMARY REF LOG: MWD GR/ROP 11/27/99 TI: BRCS/GR ANGLE AT TOP PERF: 109 @ 10010' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10010 - 10026 C 08/08/04 2" 6 10280 - 10290 C 08/08/04 2" 6 10310 - 10320 C 08/07/04 2" 6 10366 - 10374 C 08/05/04 2-7/8" 4 10491 - 10522 C 11/29/99 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" ~~ 10030' 9584' TOP OF WHIPSTOCK NOTE NO RA TAG RUN 1~4$~ 2-7/8" BOT CIBP SET 08/05/04 PBTD I-i 10523' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.37" DATE REV BY COMMENTS DATE REV BY COMMENTS 07/18/85 ORIGINALCOMPLETION 03/23/06 RPWPJC WAVER UPDATE (3/8/06) 08/31/91 RWO 10/29/06 CJWPAG SET WFD PLUG @ 9259' 11/29/99 CTD HORIZONAL SIDETRACK 11/24/06 RDW/PAG WAVER SFTY NOTE DELETED 07/23/05 LWB/PJC GLV TVD CORRECTIONS 10/21/05 MORIPJC PULL TTP @ 9210' 11/21/05 LJL/PJC PERF CORRECTIONS PRUDHOE BAY UNrf WELL: A-31A PERMrf No: 1990560 API No: 50-029-21383-01 SEC 35, T11 N, R13E, 2316' NSL & 1012' WEL BP Exploration (Alaska) • • a 0 - SARAH PALIN, GOVERNOR ~~ OI~ ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSER~'A`1'IOI~T COMr-1ISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 David Reem FAX (907) 276-7542 Engineering Team header BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 ~. t~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-31A Sundry Number: 309-107 m~~~ MAR ~~ ~ 2009 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set -out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants .for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ sday of March, 2009 Encl. =~.~~~~ STATE OF ALASKA 3~,D9 O~ ~~ A OIL AND GAS CONSERVATION CO SION ~ ~ CV1~l~~ ~ ~~(19 ~ /~1 ~ APPLICATION FOR SUNDRY APOVAL ~}ti ~~•'~ 20 AAC 25.280 ~~la~~C~ ~~ c~ was ~~n~, Commissiar~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extens~flC~lOfa~ ®Alter Casing _ ®Repair Well _ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing _ ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 199-056 3. Address: ®Service - ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21383-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU A-31A , Spacing Exception Required? ^ Yes ®No 9. Property Designation: _ 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028286 &047472 • 81.17'- Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total. Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10593' 9080' ~ 10523' 9036' 9259 & 10450' None C in n i MD TV Bu II Structural r 11 11 ' Surf 26 8' 1 - / " 26 8' 68' 4 2 7 Interm diat 9513' - /8" 9 1 8784' 687 476 P in Liner 339' 7" 248' - 95 7' 8 52' - 47' 724 1 Liner 1313' 2-7/ " 9277 - 10 0' 8 78' - 9078' 13450 1 0 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Pluq: 10010' - 10522' 8907' - 9036' 4-1/2", 12.6# NT13Cr80 9311' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP' packer Packers and SSSV MD (ft): 9222' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: April 15, 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Bjork, 564-5683 Printed Name id Reem Title Engineering Team Leader Prepared By Name/Number: Signature ~~ Phone 5645743 Date 3~2o g Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: 3 Conditions of approval: Notify Commission so that a representative may witness w.i~~\ S~ ~~ ^ Plug Integrity ~, BOP Test Mechanical Integrity Test ^ Location Clearance ~ Other: yOOQYc,'~ ~r"~~CS~ t c~S'Qo~`,. v~ti~~'~v~vw-~atr~~~~.C9.~ ~~~ Subsequent Form Required: ~o J APPROVED BY ~ ~ ~` A roved B : COMMISSIONER THE COMMISSION Date Form 10-403 Re~s`ec~06/2006 ~ Submit In Duplicate • by c,~,~ A-31 ai: Expense Rig Workover • Scope of Work; Repair 9-5/8" casing leak to the Cretaceous. Pull old chrome 4-1/2" tubing, run and cement 7" scab liner, change 9-5/8" pack-offs, re-complete with new 4-1'/2" L-80 TC-II tubing and S-3 packer at 9,060' MD. MASP: 2444psi Well Type: Injector Estimated Start Date: April 15, 2009 Production Engineer: Megan Kimmet Intervention Engineer: David Bjork Pre-Rig Prep Work: S 1 Dum bail 25' of sand on to of 4-1/2"WFD RBP set at 9259' MD. F 2 MIT-OA to 1,OOOpsi CMIT-TxIA to 1,OOOpsi record LLR if necessary and re-test at 500 si if CMIT-TxIA leaks at 1,000 si. S 3 Pull station #1 at 9,181' MD and perform spinner log while pumping down the IA to rove the com etenc of the aaker and W FD RBP. E 4 PowerJet cut 4-1/2" 13Cr-80 tubing at 9192' MD, two feet below the bottom GLM Reference tubin tall 8-31-91 . F 5 Circulate well with 9.8 brine. W 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. Check the IC for lastic ack 'ob. W 7 Set a BPV in the tubin han er. O 8 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU Nabors 4ES. ND tree. NU and test BOPE pipe rams, with 3-1/2" x 6" VBR, to 4,000 psi. Test annular preventer to 3,500 psi. Circulate out freeze protection fluid and circulate well to kill weight fluid through the cut. 2. Retrieve 4-1/2"tubing string down to the tubing cut. 3. Dress off tubing stub. 4. Fully cement 7" L-80 BTC-M scab liner from 2,900' to 9,192'. The 3-1/2" x 6" VBR will NOT be changed to 7" as the barrier to the reservoir will be a tested 4-1/2" WFD RBP at 9,259' MD and kill weight fluid. 5. Change out 9-5/8" pack-offs, clean out shoe trac~and pressure test liner and casing to 4000psi. 6. Retrieve 4-1/2"WFD RBP. 7. Run 4-~/x" L-80 TC-II tubing with Baker S-3 packer and set at 9,060' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 4000psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. I TREE = 4" CNV WELLHEAD= McEVOY ACTIVATOR= BAKER KB. ELEV = 81.1 T BF. ELEV = 52.19' KOP = 3450' Max Angle = 109 @ 10053 Datum MD = 9630' Datum TV D = 8800' SS c: 13-3/8" CSG, 72#, L-80, ID = 12.347" i~ 2668' Minimum ID = 2.37" @ 9285' TOP OF 2-7/8" LNR Cretaceous Leak 5875` A-31 A 9774' TE3 ORHIZ ~ 80 WARNING CR~10 70° TRANSMnTER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY W ELL W ORK INVOLVING EXPLOSNES CAN BEGIN. CONTACT PO. ***PROD CSGX FORMATION LEAFC'** 2028' 4-1/2" CAMCO SSSV LAND NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3100 3099 5 MERLA RA 5 5164 4988 31 MERLA RA 4 6775 6339 32 MERLA RA 3 8347 7724 24 MERLA RA 2 9039 8363 23 MERLA RA 1 9181 8492 26 MERLA RA 9210' 4-1/2" PARKER SWS NIP, ID = 3.813" 9222' --(9-5/8" X 4-1/2" TNV HBBP PKR ID = 3.875" i TOP OF 7" LNR 924$' 9259' 4-1/2" WFD PLUG SET (10/29/06) 9270' TOP OF BKR KB PKR W/ SEAL ASSY, ID = 2.56" 3.75" BKR DEPLOY SLV, ID = 3.00" 9277' 9277' 3.0" BKR SEAL ASSY, ID = 2.40" ' TOP OF 2 7/8" LNR ID = 2 37" 9278' 4-1/2" PARKER SWS NIP, ID = 3.813" 9285 - , . 1/2" PARKER SWN NIP ID = 3 80" 9299' 4 - , . 4-1/2" TBG, 12.6#, NT13-CR, .0152 bpf, ID = 3.958" 9310' 9311' 4-1/2" WLEG, ID = 3.958" 9300' ELMD TT DATE NOT AVAILABLE 9-5/8" CSG, 47#, L-80, ID = 8.681" 9512' MILLOUT WINDOW 9586' - 9593' PERFORATION SUMMARY REF LOG: MWD GR/ROP 11/27/99 TI: BHCS/GR ANGLE AT TOP PERF: 109 @ 10010' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10010-10026 C 08/08/04 2" 6 10280-10290 C 08/08!04 2" 6 10310 - 10320 C 08/07/04 2" 6 10366 - 10374 C 08/05/04 2-7/8" 4 10491 - 10522 C 11 /29/99 95$4' TOP OF WHIPSTOCK NOTE NO RA TAG RUN 10450' 2-7/8" BOT CIBP SET 08/05/04 PBTD 1-~ 0 2-7/8" LNR 6.16#, L-80, .00579 bpf, ID = 2.37" i~ 10590' 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" ~-~ 10030' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/18/85 ORIGINAL COMPLETION 03/23/06 RPWPJC WAVER UPDATE (3/8/06) 08/31/91 RWO 10/29/06 CJN/PAG SET WFD PLUG @ 9259' 11/29/99 CTDHORIZONALSIDETRACK 11/24/06 RDW/PAG WAVERSFTYNOTEDELETED 07/23/05 LWB/PJC GLV TVD CORRECTIONS 10/21 /05 MOR/PJC PULL TTP @ 9210' 11/21/05 LJUPJC PERFCORRECTIONS PRUDHOE BAY UNff WELL: A-31A PERMfr No: 1990560 API No: 50-029-21383-01 SEC 35, T11 N, R13E, 2316' NSL 8~ 1012' WEL BP 13cploration (Alaska) TREE = 4" CNV WELLHEAD=• McEVOY ACTUATOR= BAKER KB. ~ 81.17' BF. ELEV = 52.19' KOP = 3450' Max Angle = 109 @ 10053 Datum MD = 9630' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" A 31 A SAFETY NOTES: CHROM E TBG. WELL EXCEEDS 70° ~ ~ 9774' 8 GOES HORIZ ~ 9805'. W ARNING: RADIO NSMITTER IN W FATHER MONITORING SHACK MUST TURNED OFF BEFORE ANY W ELL W ORK INVOLVING Prop086d ~LOSIVES CAN BEGIN. CONTACT PO. "'PROD CSG X FORMATION LEAK"' 2000' 4-1/2" HES 9Cr X-Nip, ID=3.813 I 2668' I 7" CSG, 26#, L-80, BTGM, ID = 6.276" 2900'-9192 4-112" TBG, 12.6#, L-80, TGII ID = 3.958" -9150' - Minimum ID = 2.37" @ 9285' TOP OF 2-7/8" LNR OF 7" LNR i-~ 9248' 4-1/2" TBG, 12.6#, NT13-CR, .0152 bpf, ID = 3.958" 9310' 3.75" BKR DEPLOY SLV, ID = 3.00" 9277' TOP OF 2-7/8" LNR, ID = 2.37" 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: MWD GR/ROP 11/27/99 TI: BRCS/GR ANGLE AT TOP PERF: 109 @ 10010' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10010 - 10026 C 08/08/04 2" 6 10280 - 10290 C 08/08/04 2" 6 10310 - 10320 C 08/07/04 2" 6 10366 - 10374 C 08/05/04 2-7/8" 4 10491 - 10522 C 11/29/99 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" i ~~' X T' ~Tc T~ ~iOdOC~C F'~T~- 9030' 4-1/2" HES 9Cr X-Nip, ID=3.813 9052' 7" x 4-1/2" Baker S-3 Packer 9077' -14-1/2" HES 9G X-Nip, ID=3.813 9141' 4-1/2" HES 9Cr XN-Nip, ID=3.725 14-1/2" PARKER SWS NIP, ID = 3.813" I 9-5/8" X 4-1/2" TNV HBBP PKR, ID = 3.875" I TOP OF BKR KB PKR W/ SEA L ASSY, ID = 2.56" II 9277' ~ 3.0" BKR SEAL ASSY, ID = 2.40" 927$' 4-1/2" PARKER SWS NIP, ID = 3.813" 9299' 4-112" PARKER SWN NIP, ID = 3.80" 9~ 311, i~4-1/2" WLEG, ID = 3.958" 9300' ELMD TT DATE NOT AVAILABLE MILLOUT WINDOW 9586' - 9593' 9554' ~TOPOFWHIPSTOCK NOTE NO RA TAG RUN 10450' 2-7/8" BOT CIBP SET 08/05/04 PBTD H 10523' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.37" i--i 10590' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/18/85 ORIGINALCOMPLETION 03/23/06 RPWPJC WANERUPDATE(3/8/06) 08131/91 RWO 10/29/06 CJWPAG SET WFD PLUG @ 9259' 11/29/99 CTD HORIZONAL SIDETRACK 11/24/06 RDW/PAG WANER SFTY NOTE DELETED 07/23/05 LWB/PJC GLV TVD CORRECTIONS 10/21 /05 MOR/PJC PULL TTP @ 9210' 11/21/05 LJL/PJC PERFCORRECTIONS PRUDHOE BAY UNfT WELL: A-31A PERMff No: 1990560 API No: 50-029-21383-01 SEC 35, T11 N, R13E, 2316' NSL 8 1012' WEL BP Exploration (Alaska) . . ò BP Exploration (Alaska) Inc. Attn: Well Integrity Engineer, PRB-24 Post Office Box 196612 Anchorage, Alaska 99519-6612 December 08, 2006 Subject: A-31 A (PTD 1990560) Application for Cancellation of Sundry #303-290 ,~ ..,%~. . .... . «'Ii ~ ~. ..,-~ O'~. «¿") ':/h t$,,-~ <¥ ~ ~~~C; ~ <:-> ~% <% ~ .~ , ~ ~ Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. ¡th Ave. Anchorage, Alaska 99501 Dear Mr. Aubert: Attached is Report of Sundry Well Operations form 10-404 to cancel sundry number 303-290. The well will remain shut in and is being evaluated for repair. If you require any additional information, please contact myself or Anna Dube at (907) 659-5102. Sincerely, jú-{ {1--~ Joe Anders P,E. Well Integrity Engineer ,~:," o.;~,IAí~f' C ~'~rþ~ ~.'~~~-' Attachments: Report of Sundry Well Operations form 10-404 _ STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI.N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 other 0 Cancel Sundry Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r Exploratory r 199-0560 ~ 3. Address: P.O. Box 196612 Stratigraphic r Service W 6. API Number: õ) Anchorage, AK 99519-6612 c" 50-029-21383-01~0 )II;" I» 7. KB Elevation (ft): 9. Well Name and Number: ß ~ 81.17 KB A-31A 120 ~ 8. Property Designation: 10. Field/Pool(s): ::::Jg' (J ~ ADL~28286 & ADL-047472 Prudhoe Bay Fieldl Prudhoe Bay Oil Pool g..CIJ ,.... QC"') 11. Present Well Condition Summary: II) ::: Iõ.I;;I ~ ~~ f',.,J n C) Total Depth measured 10593 feet Plug (measured) 27/8" CIBP @ 10450' ~ C) m C1J 0 true vertical 9080.19 feet Plug (measured) 4 1/2"WFD plug @ 9259' fñ" Junk (Measured) None en õ' Effective Depth measured 10523 feet == true vertical 9036.21 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 30 - 110 30 - 110 1490 470 Surface 2639 13-3/8" 72# L-80 29 - 2668 29 - 2667.9 5380 2670 Production 9484 9-5/8" 47# L-80 28 - 9512 28 - 8782.82 6870 4760 Li ner 338 7" 26# L-80 9248 - 9586 8552.13 - 8845.81 7240 5410 Liner 1320 2-7/8" 6.16# L-80 9270 - 10590 8571.69 - 9078.34 13450 13890 Closed Perforation depth: Measured depth: 10010 - 10026 10280 - 10290 10310 - 10320 10366 - 10374 10491 - 10522 True Vertical depth: 8907.14 - 8901.99 8895.63 - 8899.6 8908.26 - 8912.92 8936.38 - 8940.75 9014.82 - 9035.55 Tubing: (size, grade, and measured depth) 4-112" 12.6# 13Cr80 24 - 9310 Packers and SSSV (type and measured depth) 9 5/8" x 4 1/2" TIW HBBP 9222 2-7/8" Baker KB Packer 9270 41/2" Camco SSVLN 2028' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 0 100 0 Subsequent to operation: 0 0 0 100 0 14. Attachments: 15. Well Class after Droposed work: Copies of Logs and Surveys Run Exploratory r Development r Service W Daily Report of Well Operations 16. Well Status after proposed work: Oil r Gas r WAG r GINJ r WINJ w WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or NIA if C.O. Exempt: 303-290 Contact Anna Dube I Joe Anders Printed Name Joe Anders P.E. Title Well Integrity Engineer Signature IfJ>{. (L~ Phone 907-659-5102 Date 12/7/2006 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only RBDMS BFt A-31A (PTD #1990560) Internal Waiver Cancellation - Trouble Well . . éJ (J 1I1~4IÛ(¡, \ \t2q-( All, An internal waiver was issued for a PC Leak to formation on well A-31A (PTD #1990560) on 03/08/06. The well no longer passes waiver and sundry requirements for a passing MIT- T. Therefore the waiver for continued operation with a PC Leak is cancelled. The well is currently shut-in and secured with a TIP. The well is being evaluated for repair by rig work. Paperwork is also being submitted to cancel the Sundry with the AOGCC. The well is reclassified as a Trouble well. Please remove all waive red well signs and the laminated copy of the waiver from the wellhouse. Thank you, }fnna (j)u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~'!i'. ,. )J~~';'; A ) \;ti"4tr./i ,,'" .~'-' (1~: [ 1 of 1 11/24/2006 3 :34 PM SChlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth RECEIVED DEC 2 1 2005 AJaska Oil & Gas eons. CcmrdsÚ:n Anchorage Well Job # Log Description Date BL C-04A 10687728 SBHP SURVEY 01/07/05 1 L 1-15A 10715359 PROD PROFILE WIDEFT 11/04/03 1 S-29A 11087187 INJECTION PROFILE 10/04/05 1 09-33 N/A PROD PROFILE WIDEFT 07/16/05 1 D.S 18-03B 11057071 SBHP SURVEY 12/02/05 1 M-10 11072878 LDL 08/05/05 1 D.S 18-25A 11057072 SBHP SURVEY 12/03/05 1 A-31A 1'1'i-()5h 11072881 LDL 08/07/05 1 K-06A 11075903 MEM PROD & INJ PROFILE 07/30/05 1 L 1-27 11058255 PROD PROFILE W/DEFT 1 0/25/05 1 AGI-10 11087429 LDL 09/05/05 1 S-36 11152365 LDL 11/08/05 1 K-20B 11057076 SBHP SURVEY 12/06/05 1 M-18B 11072876 INJECTION PROFILE 08/02/05 1 2-18/L-16 11087185 LDL 10/01/05 1 2-62/0-17 11084325 INJECTION PROFILE 11/21/05 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 SCANNED JAN 2 5 2006 Date Delivered: 12/21/05 NO. 3630 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne pt. Color CD .-, --I Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Received bY~n STATE OF ALASKA . Al. Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS D D D 1. Operations Abandon D Repair Well [] Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 81.17 KB 8. Property Designation: ADL-047472 11. Present Well Condition Summary: Total Depth measured 10593 true vertical 9080.19 Effective Depth measured 10523 true vertical 9036.21 Casing Conductor Surface Production Liner Liner Length 80 2639 9484 338 1320 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-518" 47# L-80 7" 26# L-80 2-7/8" 6.16# L-80 Perforation depth: Measured depth: True Vertical depth: 5CANNED DEe 1 ~ 2005 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o SHUT-IN o 3765 50 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil [J Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: see attached fluids summary T/1/0=140/11 0010 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 Contact Sharmaine Vestal Printed Name Sharmaine Vestal I Signat~ ~ RECEIVED NOV 1 6 2005 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic [J Stimulate D Other~. . . Waiver D Ti~~E?tfeMHo s Con.. CemIRlSllOn Re-enter Suspended Well .chorage 5. Perl]iqo Prill Number: ...,.i':>f~ '1). Exploratory Service 6. API Number: 50-029-21383-01-00 9. Well Name and Number: A-31A 10. Field/Pool(s): Prudhoe Bay Fieldl Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) 10450 None feet feet MD 30 - 110 29 - 2668 ~~~8 - 9512.-.. 9248 - 9586 9270 - 10590 Collapse 470 2670 4760 5410 13890 TVD 30 - 110 29 - 2667.9 28 - 8782.82 8552.13 - 8845.81 8571.69 - 9078.34 Burst 1490 5380 6870 7240 13450 4-1/2" 12.6# 13Cr80 27 - 9311 4-1/2" TIW HBBP Packer 2-7/8" Baker KB Packer 9222 9270 RBDMS 8Ft 17 Tubing pressure 550 Service ~¡ WINJ ~: WDSPL Sundry Number or NIA if C.O. Exempt: 305-242 Title Data Mgmt Engr "__ Phone 564-4424 Date 11/14/2005 Form 1 0-404 Revised 04/2004 Submit Original Only L .,. e e . A-31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY'~; ·t. . y.~j·~1 10/12/2005 T/I/O= 600/0/0 Pumped Thermatek squeeze down the IA to ELM depth of ; 5876'. Pumped diagnostics stage of: 48 BBL's of 50/50 meth/water, 12 BBL's of crosslinked K-Max gel, 180 BBL's SW, 181 BBL's 50/50 meth water.(Displacement volume of 299 BBL's after the neat Thermatek was revised from 314 BBL's based on data from diagnostic stage of the job) Pumped treatment stage of: 5 BBL's crosslinked K-Max gel, 5 BBL fresh water spacer with Nitrogen, 15 BBL's Thermatek with Nitrogen, 5 BBL's neat Thermatek, 30 BBL's crosslinked K-Max gel, 5 BBL's fresh water, 264 BBL's diesel. Well left shut in. TTP in well. Final WHP's T/I/O= 140/1100/0 10/14/2005 TIO=430/950/20, temp=SI. Bleed IA (post Thermatek Squeeze). InitiallA FL @ surface. Bled IA from 950 psi to 0 psi in 45 minutes (4.5 bbls of fluid). Monitored for 15 minutes and the lAP went on a vac. Final WH Ps=430/vac/20. 10/15/2005 T/I/O=350/580/20. Temp=SI. Monitor(post Bleed). TBGP decreased 80 psi, lAP increased 580 psi. overnight. No change in OAP. 10/16/2005 Dispatched to MIT IAI Did Not Pump/ Pad Op had Hot Work and Lifting Ops in Progress on Pad. 10/17/2005 TIO = 375/605/20 Attempt to MIT-IA to 2500 PSI (FAILED) could not acheive test pressure without increasing rate more and more.Started injectivity test at 1.75 BPM at 2260 PSI, 2 BPM at 2400 PSI, 3.7 BPM at 2500 PSI, pressure was falling as we pumped. Shut down, LRS out of Diesel. Bleed back 6 bbls Diesel. Final WHP's T/I/O = 350/650/0 FLUIDS PUMPED BBLS 20 Thermatek 47 K-Max 264 Diesel 230 50/50 Meth/water 92 FW 180 SW 833 TOTAL ñ1 ,..~._. ~ - ......, .. ." ) ~.~;~ A ~,~ ~ ,-¡: Â ;",' K ~ C,,'" Ã QJJ _Ih.~ ~~ ~J b~~~b~c~Lßt~ ) ALASKA. OIL AlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI. GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Paul Bartel Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 A;,,,~. ,1""" ~;'I\(j \ ~C'J( ø Re: Prudhoe A-31A Sundry Number: 305-242 SCl\NNE~:'" AUG 3 0 2.005 Dear Mr. Bartel: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decisi, 0 Superior Court unless rehearing has been requested. DATED thiS~y of August, 2005 Enc!. · 1. Type of Request: ()('Zf 8 "-Z,b -05' \J,..jGf\- f Il'I2..~'OS- .. STATE OF ALASKA 0""\ //::22-/5 RECEIVEd D' AL lA OIL AND GAS CONSERVATION COMMI.....,.,{ON ..... "I '" 5 APPLICATION FOR SUNDRY APPROVAL AUG 1 9 2005 20 MC 25.280 Operational shutdown U Plug Perforations D Perforate New Pool D 4. Current Well Class: Development D / r.7I 6. API Number: Stratigraphic D Service c:!I Suspend U / Repair well 0 Pull Tubing 0 Perforate U Wai'1\f~a tm ~~t G<:ls:>øonlsJ!;ommi: Stimulate 0 Time Extension ~D' Anchorage Re-enter Suspended Well 0 5. Permit to Drill Number: Exploratory D Anchorage, AK 99519-6612 7. KB Elevation (ft): Abandon U Alter casing 0 Change approved program 0 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 8. Property Designation: ADL-047472 11. Total Depth MD (ft): 1 0593 Casing Conductor Liner Liner Production Surface Perforation Depth MD (ft): 10010 - 10026 10280 - 10290 10310 - 10320 10366 - 10374 Packers and SSSV Type: 9. Well Name and Number: 81.17 KB Total Depth TVD (ft): 9080.19 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 10523 9036.21 10450.00 Length Size MD TVD 80 20" 91.5# H-40 30 110 30 1320 2-7/8" 6.16# L-80 9270 / 10590 8571.69 338 7" 26# L -80 9248 ~ 9586 8552.1 9484 9-5/8" 47# L-80 28 /9512 28 2639 13-3/8" 72# L-80 29 / 2668 29 110 9078 8846 8783 2668 Perforation Depth TVD (ft): Tubing Size: Tubing Grade: 8907.14 - 8901.99 4-1/2" 12.6# 13Cr80 8895.63 - 8899.6 8908.26 - 8912.92 8936.38 - 8940.75 9-5/8" x 4-1/2" TIW HBBP Packer Packers and SSSV MD (ft): 9222 2-7/8" Baker KB Packer 9270 7" Liner Top Packer 9248 199-0560 /' 50-029-21383-01-00 / A-31A / Burst Junk (measured): None Collapse 1490 470 13450 13890 7240 5410 6870 4760 4930 2670 Tubing MD (ft): 27 - 9311 ...-/ 12. Attachments: Descriptive Sum m ary of Proposal ~ Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for ,I Commencing Operations: (~/~5 16. Verbal Approval: "¿. . Commission Representative: 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D Plugged 0 WAG D GINJ 0 / WINJ ~ Date: /' Service ~ Abandoned D WDSPL D Prepared by Sharmaine Vestal 564-4424 Paul Bartel 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Paul Bartel Title Production Engineer Signature Yo -SL. .~~ Phone 564-5402 Date COMMISSION USE ONLY 8/18/2005 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 30 s-~ ð- V.d-- Plug Integrity 0 Other: M I: T BOP Test 0 M' Location Clearance 0 Mechanical Integrity Test RBDMS BFL AUG 23 2005 COMMISSIONER APPROVED BY THE COMMISSION Form 10-403 Revised 11/2004 OR1Gr~,J^,r Date ~i £ Submit in Duplicate · ' bp .,. ,\It.'II, -.....~ ~.....- ~~- ~~-- ...~ -F....... ·I'~~I\· ". To: Jerry Bixby/Doug Cismoski, GPB Well Ops TL ') ) Date: July 25, 2005 From: Brian Carlson and Paul Bartel Subject: A-31Ai IA Thermatek Squeeze AFE PBAPDWL31-N Est. Cost: $200 M lOR: 0 BOPD Please perform a Halliburton Thermatek IA squeeze as per the attached program. 1 E Slone week. Temperature log while pumping down IA. 2 F Bullhead Thermatek and N2 with Halliburton down the IA. 3 F WOC. MITIA. Deviation: Last Downhole Ops: Latest H2S level: Produced water injector, 2200 BWPD @ 1600 psi. / Cretaceous leak at -5875'. 33 deg @ 5875' MD Loaded IA w/ 9.8 brine @ 3.5 BPM/1800 psi. Produced Water Iniector Status: Thermatek is a rigid setting ceramic type material licensed solely by Halliburton. Thermatek has a rapid right angle set and will go from a liquid to solid in a few minutes. The setting is activated by temperature, and is very controllable and repeatable. The rapid setting ensures the slurry will not swap out, slump, be impacted by crossflow, etc. It has been used successfully by Shell and BP in the North Sea to shut-off water in /' gravel packed completions. Thermatek has a wide density range and can be nitrified to lighter than water. It is easy to pump and can also tolerate about 500/0 contamination with wellbore fluids. / Thermatek has expansive qualities, and it is HCI soluble. A HAZID is required prior to this job. The job will be pumped with existing Halliburton equipment and crews. Additional lab testing and yard tests will be conducted prior to the job, and a Thermatek expert from the UK will be on location during the job. Schlumberger will provide N2, and they must also provide weak acid for wash-up of the Halliburton equipment. If you have any questions or comments regarding this procedure, please call Paul Bartel at (W) 564-5402, (H) 696-1682, (Cell) 240-8036. cc: w/a: B. Carlson wlo attachments: 8/18/2005 Page 1 of3 ) ') A-31Ai IA Thermatek Squeeze Prepared By: Paul Bartel Phone#: 564-5402(w), 696-1682(h), 240-8036 (c) Job PlanninQ Details: The 9-5/8" Cretaceous leak is at -5875' MD, 5600' TVD. /' Leak Deviation: 33°,135° azimuth IA Injectivity: The tubing is dummied off. The last MITT passed to 3000 psi on 8/15/04. /',. / ) .0535 · 5875 é~b'S. 1/14/05 Load with 315 bbls 9.8 brine at 3.5 BPM/1800 psi. ,ý 3/9/03 70 bbls DC at 5/1950. 1/6/02 350 bbls 9.8 brine at 2/2100. 11/29/00 Left over Marcit, 208 bbls seawater, 138 bbls dsl at 2.7/2850. 4/13/00 116 bbls dsl at 2.5/3000. 12/24/99 LDL, 85 bbls dsl at 0.5/2250. 12/23/99 MITIA, 33 bbls dsl at 0.52/2300. Gas Lift Design: IA bbls to the leak: OA status: The last MITOA passed to 2000 psi on 7/13/05. /' Static: -105°F at the casing leak. Prep Work: 1. Perform a HAZID with Halliburton and 8chlumberger personnel. 2. Provide representative fresh water samples to Halliburton for lab testing. A BP representative / should witness the lab testing. 3. 81 injection for one week and freeze protect the tubing. 4. RU EL and pump truck to the IA. Please note the date and time that injection was 81 on the W8R. 5. Perform a static baseline temperature pass down the tubing at 100 fpm from surface to 7000'. /~ Pull to 5000'. 6. Pump 345 bbls of lO°F diesel down the IA at a constant 3 BPM with a maximum IA pressure of / 3000 psi. Please note the actual diesel temperature in the W8R. Perform a down temperature pass from 5000' to 7000' after 300 bbls have been pumped. 7. 80 pumping and immediately perform another down pass from 5000' to 7000'. Perform additional warm-back passes after one, two, three and five hours. POOH and RD EL. Please present the warm-back overlays in the final log print. 8. Pump 320 bbls 9.8 ppg brine down the IA and return the well to injection. / Thermatek SQueeze: 9. Freeze protect the tubing and 81 injection for one week prior to the treatment. 10. RU Halliburton batch mixer and pump truck. Tee in 8chlumberger N2 unit to the foam generator. 8/18/2005 2 ) ) 11. Mix Thermatek solution and place a sample in a 105°F water bath. 12. Pump the following fluids down the IA at a constant 3 BPM with a maximum pressure of 3000 psi: ./ · 5 bbls · 5 bbls · 15 bbls K-Max crosslinked gel spacer 70°F fresh water with 900 scf/bbl N2 Thermatek with 900 scf/bbl N2 (will result in 22 bbls at downhole conditions) neat Thermatek ./ K-Max crosslinked gel spacer 70°F fresh water spacer Diesel · 5 bbls · 5 bbls · 5 bbls · 304 bbls Do not over-displace tfJe Thermatek. The well may lock-up when Thermatek hits the leak. 13. RD Halliburton. :'WOG" for 24 hours. ,/ 14. Attempt to pressure test the IA to 2500 psi. If unsuccessful then perform an injectivity test. 15. If the pressure test fails it will be necessary to reload the IA with 9.8 ppg brine prior to returning to injection. If injectivity is too low, it may be necessary to pull the DGLV at 5164' in order to spot the brine. The brine weight will have to be increased to approximately 10.3 ppg. ./ 16. Return to injection. 8/18/2005 3 TREE::: .. WELLHEA 0= ACTUA TQ.R= KB. ELEV ,; E'{f::., ELEV = KOP= Max Angle = Datum MD = Datum TVD = ') 4"CIW McEVOY BAKER 81.1 7' 52.19' 3450' 1 09 @ 10053' 9630' 8800' SS 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2668' Minimum ID = 2.37" @ 9285' TOP OF 2-7/8" LNR A-31A/ SAFETY )ES: CHROMETBG. WELL EXCEEDS 70° @ 9774' & GOES HORIZ @ 9805'. WARNING: RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PO. ***PROD CSG X FORMATION LEAK. OPERATING LIMITS: MAX lAP = 500 PSI, MAX OAP = 500 PSI (10/22/03 WAIVER)*** 2028' 1-14-1/2" CAMCO SSSV LAND NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3100 3099 5 MERLA RA 5 5164 4988 31 MERLA RA 4 6775 6339 32 MERLA RA 3 8347 7724 24 MERLA RA 2 9039 8363 23 MERLA RA 1 9181 8492 26 MERLA RA i 1'0\ V !fl I~ ~ <.... --. L ] z 1 TOP OF 7" LNR l-l 9248' ~ :;:- Ì' I 9210' 1-14-1/2"PARKERSWSNIP,ID=3.813" :g --{ 9222' 1-19-5/8" x 4-1/2" TIW HBBP PKR, 10 = 3.875" /' I,':';' Z' ~ I 9270' 1-1 TOP OF BKR KB PKR WI SEAL ASSY, 10 = 2.56" 13.75" BKR DEPLOY SLV, 10 = 3.00" 1-1 9277' ~\ I 9277' 1-13.0" BKR SEAL ASSY, 10 = 2.40" 1 TOPOF 2-7/8" LNR, 10 = 2,37" 1-1 9285' Jr /' 1 9278' 1-14-1/2" PARKER SWS NIP, ID = 3.813" 1 ~ 1 9299' 1-14-1/2" PARKER SWN NIP, ID = 3.80" 14-112" TBG, 12.6#, NT13-CR, .0152 bpf, 10 = 3.958" 1-1 9310' 1 9311' 1-14-1/2" WLEG, 10 = 3.958" I 1 9300' 1-1 ELMO TT DA TE NOT A V AILABLE I 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9512' ~ PERFORA TION SUMMARY REF LOG: MWD GR/ROP 11/27/99 TI: BHCS/GR ANGLEA T TOP PERF: 109 @ 10010' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 10010 - 10026 0 08/08/04 2" 6 10280 - 10290 0 08/08/04 2" 6 10310 - 10320 0 08/07/04 2" 6 10366 - 10374 0 08/05/04 2-7/8" 4 10491 - 10522; 0 11/29/99 I 7" LNR, 26#, L-80 1J4S, ,0383 bpf, 10 = 6.276" 1-1 10030' DATE 07f18f85 08f31f91 11 f29f99 07/03/01 02/22/03 11f16/03 REV BY COMMENTS ORIGINAL COM PLETION RWO CTD HORIZONAL SIDETRACK CH/KAK CORRECTIONS JMP/KK WANER SAFETY NOTE TJP/PAG WANER SAFETY NOTE .. MILLOUT WINDOW 9586' - 9593' 9584' 1-1 TOP OF WHIPSTOCK I I NOTE: NO RA TAG RUN I 10450' 1-12-7/8" BOT CIBP SET 08/05/04 PBTD 1-1 10523' 1 12-7/8" LNR, 6.16#, L-80, .00579 bpf, 10 = 2.37" 1-1 10590' I DA TE REV BY COMMENTS 08/05/04 KCF/TLP PERFS AND CIBP SET 03/02/05 JWDfTLH ÆRF CORRECTIONS 07/23/05 LWB/PJC GLV TVD CORRECTIONS PRUDHOE BA Y UNIT WELL: A-31A ÆRMIT No: "'1990560 API No: 50-029-21383-01 SEC 35, T11 N, R13E, 2316' NSL & 1012' WEL BP Exploration (Alaska) bp August 18, 2005 ) ) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 (l..Ó5~ l~-\ Winton Aubert Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, AK. 99501 Dear Winton: RECEI\I~F:~: AUG 1 9 2005 AlaslŒ Oil & Gas Cons. CtJ~. h, "i,;s;i~ir! Am;horage Re: Sundry notice for A-31A Thermatek IA squeeze to seal off Cretaceous leak. BP proposes to perform a Thermatek IA bullhead treatment on A-31 A. The treatment is a field trial aimed at repairing a casing leak opposite the Cretaceous zone. Background: A-31A is an injector with a production casing leak. The AOGCC has issued a Sundry #303-290 dated 9/11/03 for continued water injection only. A-31A is in compliance with the operating requirements of a passing MIT-T, passing LNFT-IA, and passing MIT-OA. The IA is currently loaded with 9.8 ppg brine. Diagnostics have located the casing leak at 5875'. BP proposes to test a new Halliburton product called Thermatek in order to seal off the leak. Thermatek is a rigid setting polymer with cement- like qualities. The setting is controlled by temperature, and very predictable and repeatable, even with significant contamination from wellbore fluids. Density can range from 8.5 ppg to -14 ppg. It develops compressive strength very quickly, and if properly designed will set up before it swaps out. Thermatek is also soluble in HCL. Job Design: The treatment will be placed by bullheading down the 4-1/2" x 9-5/8" annulus. The slurry will be completely displaced from the annulus and designed to set within an hour of placement. 1. RU Halliburton batch mixer and pump truck. Tee in Schlumberger N2 unit to the foam generator. 2. Mix Thermatek solution and place a sample in a 105°F water bath. 3. Pump the following fluids down the IA at a constant 3 BPM with a maximum pressure of 3000 psi: · 5 bbls · 5 bbls · 15 bbls · 5 bbls · 5 bbls · 5 bbls · 304 bbls K-Max crosslinked gel spacer 70°F fresh water with 900 scf/bbl N2 Thermatek with 900 sc.f/bbl N2 (will result in 22 bbls at downhole conditions) neat Thermatek K-Max crosslinked gel spacer 70° F fresh water spacer Diesel ) } :1" Do not over-displace the Thermatek. The well may lock-up when Thermatek hits the leak. 4. RD Halliburton. "WOC" for 24 hours. 5. Attempt to pressure test the IA to 2500 psi. If unsuccessful then perform an injectivity test. 6. If the pressure test fails it will be necessary to reload the IA with 9.8 ppg brine prior to returning to injection. If injectivity is too low, it may be necessary to pull the DGLV at 5164' in order to spot the brine. The brine weight will have to be increased to approximately 10.3 ppg. 7. Return to injection. If you have any questions concerning this Sundry Application, please contact Paul Bartel at 564- 5402. Sincerely, Paul Bartel Staff PE Alaska Drilling and Wells STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIO~ 0 fi 7004 1. Operations Performed: AbandonD Repair Well 0 PluQ Perforations[K] Stimulate ~aska Oil &>~å~ons. Commission Alter Casing 0 Pull TubingD Perforate New Pool 0 waiver[j' Time Exten~R~grage Change Approved Program 0 Operation Shutdown 0 Perforate [[J Re-enter Suspended Well 0 .I 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 4. Current Well Class: Development 0 81.17 8. Property Designation: ADL-0047472 11. Present Well Condition Summary: Stratigraphic 0 9. Well Name and Number: A-31 A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Exploratory 0 Service ŒJ 5. Permit to Drill Number: 199-0560 6. API Number 50-029-21383-01-00 Total Depth measured 10593 feet true vertical 9080.2 feet Effective Depth measured 10450 feet Plugs (measured) Junk (measured) 10450 None true vertical 8987.3 feet Casing Conductor Liner Liner Production Surface Length 80 338 1320 9484 2639 Size 20" 91.5# H-40 7" 26# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 MD TVD 30 - 110 30.0 - 110.0 9248 - 9586 8552.1 - 8845.8 9270 - 10590 8571.7 - 9078.3 28 - 9512 28.0 - 8782.8 29 - 2668 29.0 - 2667.9 Burst Collapse 470 5410 13890 4760 2670 1490 7240 13450 6870 4930 Perforation deDth: Measured depth: 10010 -10026,10280 -10290,10310 -10320,10336 -10374 True vertical depth: 8907.14 - 8901.99,8895.63 - 8899.6,8908.26 - 8912.92,8920.76 -8940.75 Tubing (size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 27 9311 Packers & SSSV (type & measured depth): 2-7/8" Baker KB Packer 4-1/2" TIW HBBP Packer @ 9270 @ 9222 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10010 -10374 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl 0 50 Bbls 7.5% HCL, 96 Bbls 9% HCU1% HF, 220 Bbls 3% NH4CL @ 3687 psig ReDresentative Daily Average Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure 0 -4104 45 Well Shut-In 250 Tubing Pressure 1560 0 13 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD ServiceŒ] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron 11~~ SCANNED OCT 0 9 2004 WAG D GINJD WINJI!I WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 304-144 Title Production Technical Assistant Signature Phone 564-4657 Date 9/30/04 Form 1 0-404 Revised 4/2004 ORIGINAL í~_f~fl OCT G), (t~ 0 ;' A-31 A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/04/04 CTU # 9. PERFORM WEEKLY BOP TEST. RU. «<JOB IN PROGRESS»> 08/04/04 CTU # 9. CIBP/MIT-T/ ADD PERF/STIM/SRT. MIRU. PERFORM WEEKLY BOP TEST. MU BOT 2.125" MHA W/PDS LOGGING STRING INSIDE 2.2" 00 CARRIER W/2.25" JSN AND RIH TO 10,500' AND MADE UP/ON PASSES FROM 10,500' TO 10,000' WHILE JETTING LINER AT MAX RATE W/l% KCL. SLOWED THROUGH CIBP INTERVAL TO PREP FOR CIBP. LOGGED FROM 10,500' CTM TO 10,330' CTM AND PAINTED FLAG. FINISHED LOGGING INTERVAL AND POOH. «< CONTINUED ON WSR 05-AUG-04 »> 08/05/04 CTU #9: CIBP/MIT-T/ ADD PERF/STIM/SRT. CONTINUED FROM WSR 04-AUG-04. POOH W/PDS LOGGING STRING AND MU BOT 2.22" CIBP (FOR 2-7/8" LINER) AND RIH. CORRECT TO CEL AT FLAG AND SET CEL OF CIBP AT 10450' (8987.6' TVD). COIL FLAG TIED INTO SPERRY SUN MWD 27-NOV-99. (-12FT CORRECTION TO PUT LOG ON DEPTH) MIT TUBING TO 3000 PSI W/l% KCL W/AOGCC WITNESS. PASSED MIT-T. RIH WITH GUN # 1. CORRECT TO CIBP DEPTH, SHOOT 10366' - 10374' (8') 6 SPF. SURFACE ALL SHOTS FIRED. CUT 200' OF PIPE OFF. MU BOT 2.125" MHA W/2" PERF GUNS. RIH WITH GUN #2. RIH TO 4759' AND INSPECT PIPE. UTIM ALARM SHOWS THIN AREA. PARK COIL, CLEAN AND INSPECT. ULTRASONIC TESTER SHOWS 0.109" ABOVE AND BELOW BAD SPOT, 0.065" TO 0.068" AT THE UTIM ALARM DEPTH. THIS REPRESENTS - 40% LOSS IN WALL THICKNESS AT THIS DEPTH. DECIDE TO SUSPEND GUN RUN #2. POOH W/GUN #2. «< CONTINUED ON WSR 06-AUG-04 »> 08/05/04 SET CIBP @ 10450' 08/07/04 CTU #9: CIBP/MIT-T/ ADD PERF/STIM/SRT. «< CONTINUED FROM WSR 6-AUG.04 AFTER PIPE SWAP AND INJECTOR SWAP »> MIRU, STAB ON WELL TO DRIFT COIL W/1.25" BALL. MAKE UP BOT 2.25" CTC AND GUN # 2. 2.00" 00 PERF GUNS. TIE IN TO CIBP @ 10,450'. SHOOT 10' - 6 SPF GUNS. PERFORATE INTERVAL 10,310' - 10,320' AND POOH. ALL SHOTS FIRED, LAY DOWN GUNS AND MU PDS LOGGING STRING W/2.2" CARRIER W/2.25 JSN AND RIH. «< CONTINUED ON WSR 08-AUG-04 »> 08/08/04 CTU #9: CIBP/MIT.T/ADD PERF/STIM/SRT. CONTINUED FROM WSR 07-AUG-04. RIH W /PDS MEMORY TOOLS TO CIBP AND LOG UP TO FLAG COIL AT 10,260' CTM, CONTINUE LOGGING UP FOR SECOND COIL FLAG AT AT 9,990' CTM AND CONTINUE LOGGING UP TO END OF LOGGING INTERVAL AND POOH. LAY DOWN PDS TOOLS AND MU GUN #3 - 10' OF 2" PJ2006HMX 6 SPF, 60 DEG PHZ TIE/CORRECT IN TO FLAG AND SHOOT 10,280' - 10,290' . ALL SHOTS FIRED. RIH W GUN # 4 161 OF 2" 6SPF, TIE IN TO FLAG/CORRECT AND SHOOT 10,010' -10,026'. ALL SHOTS FIRED. CUT 100' PIPE OFF. MU 2.2 JSN AND RIH. PRE INJECTIVITY WHILE RIH 715 PSI @ 0.3 BPM. RIH AND TAG CIBP AT 10466' CTM (10450' ELMD) PRE-INJECTIVITY TEST 1.0 BPM @ 2298 PSI W/l% KCL. SAW BREAK DOWN AT 2298 PSI. WHP FELL TO 1922 PSI. AT 1.0 BPM. PUMPED 35 BBLS FILTERED 30/0 NH4CL WHILE MAKING JET PASSES. FINAL PRE-ACID INJECTIVITY ON 3% NH4CL 2000 PSI @ 1.0 BPM. «< CONTINUED ON WSR 09-AUG-04 »>. . NOTE: ACID TITRATION DATA: HCL 7.90/0 HCL, IRON <22 PPM, HCL-HF 9.30/0 HCL, 1.1 % HF IRON <22 PPM SCANNED OCT 0 9 2004 Page 1 TREE = 4" a.N WELLI-EAD= MeEVOY ACTUATOR= - BÀKER KB~Eî.J:V-;~-- - ----sTir ~~~_B' ...: -- ~ KOP = 3450' Max Angle = 109 @ 10053 Òàtum M) = - 9630' Datum lV D = . 8000" S8 SAFElY NOTES: CHROME 18G. WELL EXCEEDS 70° @ 9774' & GOES HORlZ@ 9805'. WARNING: RADIO TRANSMITTER IN WEATHER MOMTORING SHACK MUST BE TURNED OFF BEFORE ANY WB..L WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PO. ***PROD CSG X FORMATION LEAK OPERATING LIMITS: MAX lAP = 500 PSI, MAX OAP = 500 PSI (1 0/22/03 WAIVER)*** 2028' H4-1/2" CA weo SSSV LAND NIp, ID = 3.813" I GAS LIFT Mð.t\OR8..S TVD DB' TYPE VLV LATCH FORT DATE 3018 5 rvER-A RA 4907 31 rvER-A RA 6258 33 rvER-A RA 7643 24 rvER-A RA 8281 23 rvER-A RA 8410 26 rvER-A RA A-31A CD ,,1 ~ ST MD 6 3100 5 5164 4 6775 3 8347 2 9039 1 91 81 I ~ 113-318" CSG, 72#, L-80, ID = 12.347" H 2668' L Minimu m ID = 2.37" @ 9285' TOP OF 2-7/8" LNR 9210' H4-1f2" PARKERSWS NIP, ID= 3.813" I 9222' H9-518" X 4-1/2" TIW HBBPPKR, [) = 3.875" 1 I ~ :8: 1 TOP OF 7" LNR H 9248' I---t I HTOP OF BKR KB PKR WI SEAL ASSY, ID = 2.56" 1 H3.0" BKRSEALASSY,ID =2.40" 1 H4-1/2" PARKERSWS NIP, [) =3.813" 1 H4-1/2" PARKERSWN NIP, [) =3.80" I H4-1/2" WLEG, ID = 3.958" 1 HELMDTTDATENOT AVAILABLE 1 1 I 1 1 1 9270' 9277' 9278' 9299' Z 13.75" BKRDEA.OY SLV, ID= 3.00" H 9277' 1---. 1 TOP OF 2-718" LNR, ID = 2.37" H 9285' 1 1 14-1/2" TBG, 12.6#, NT13-CR, .0152 bpf, ID= 3.958" H 9310' 9311' 9300' I MILLOUT WINDOW 9586' - 9593' ~ 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9512' ~ PERFORATION SUMMA RY REF LOG: rv1WD GRlROP 11/27/99 TI: BI-CSIGR ANGLEATTOPPERF: 109 @ 10010' I'bte: Refer to A'oduetion DB for historieal perf data SIZE SFF INTERVAL Opn/Sqz DATE 2" 6 10010 - 10026 0 08/08/04 2" 6 10280 - 10290 0 08/08/04 2" 6 10310-10320 0 08/07/04 2" 6 10366 - 10374 0 08/05/04 2-7/8" 4 10491 - 10522 0 11/29/99 H TOP OF WHIPSTOCK 1 I NOTE: NO RA TAG RUN 1 10450' H2-718" BOTCIBP SET 08/05/04 RHD H 10523' 1 9584' 12-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.37" H 10590' 1 1 7' LNR, 26#, L-80 U4S, .0383 bpt, ID = 6.276" H 10030' 1 COMrvENTS ORIGINAL COMPLETION RWO CTD HORlZONAL SIDETRACK a-J/KAK CORRECTIONS JMPiKK WA IVER SA ÆTY NOTE TJP/PAG WAIVERSAÆTY NOTE DATE 07/18/85 08/31/91 11/29/99 07/03101 02/22/03 11/16/03 REV BY DATE REV BY COMMENTS 08/05/04 KCF/TLP ÆRFS AND CIBP SET PRUDHOE BAY UNIT W8..L: A-31A ÆRMT No: 1990560 API No: 50-029-21383-01 SEC35, T11N, R13E, 2316' NSL& 1012'WEL 8P Exploration (Alaska) SCANNED OCT 0 9 2004 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg "'2, SIZ4/04 P.I. Supervisor I ~1 FROM: John Crisp Petroleum Inspector DATE: Wednesday, August 11, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC A-3IA PRUDHOE BAY UNIT A-3IA Src: Inspector Reviewed By: P.I. Suprv J£P- Comm Well Name: PRUDHOE BAY UNIT A-31A Insp Num: miUCr040810091502 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50-029-21383-01-00 Permit Number: 199-056-0 Inspector Name: John Crisp Inspection Date: 8/512004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A-3IA Type Inj. N TVD 9080 IA 50 144 157 167 P.T. 1990560 TypeTest SAm Test psi 2269.5 OA 0 0 0 0 Interval REQVAR P/F P Tubing 0 3093 3048 3021 Notes: I witnessed a bridge plug run & set @ 10450 MD in 2 7/8" liner. The BP was set 41' above exsiting perfs @ 10,491 MD. A following MITI was performed to 3000 psi successfully. Wednesday, August 11,2004 Page 1 of 1 ~ ,.-..... v-- -..., STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Development D Exploratory D StratigraphicD Service ŒJ / 9. Well Name and Number: A-31A ./ 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): 9080.2 10523 8955.0 S ze MD TVD top 30 9248 9270 28 29 ~ 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 Suspend 0 RepairWell 0 Pull Tubing 0 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519.6612 7. KB Elevation (ft): 81.17 KB 8. Property Designation: ADL-0047472 11. Total Depth MD (ft): 10593 Casing _ength Conductor Liner Liner Production Surface Perforation Depth MD (ft): 10491 - 10522 80 338 1320 9484 2639 20" 91.5# H-40 7" 26# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 Perforation Depth TVD (ft): 9015 9035.6 Packers and SSSV Type: 2-7/8" Baker KB Packer 4-1/2" TIW HBBP Packer 12. Attachments: Description Summary of Proposal ŒI Detailed Operations Program ŒI BOP?c, S.. ch 0 // 14. Estimated.Date for. A".tay 004 Commenclnç¡ Operation: ( IY~ 16. Verbal Approval: '~e: Commission Representative: Operation Shutdown D Plug Perforations Œ] Perforate New Pool D 4. Current Well Class: Perforate¡ WaiverD StimulateŒ Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill NulJ)ber: 199-0560 /' , I --I ,"-V"""õ Annular Disposal D OtherD 6. API Number / 50-029-21383-01-00 Plugs (md): None Burst bottom top bottom 110 30.0 110.0 1490 9586 8552.1 8845.8 7240 10590 8571.7 9078.3 13450 9512 28.0 8782.8 6870 2668 29.0 2667.9 4930 Tubing Size: Tubing Grade: Tubing MD (ft): 4.5 " 12.6 # 13Cr80 27 Packers and SSSV MD (ft): 9270 9222 13. Well Class after proposed work: Junk (md): None Collapse 470 5410 13890 4760 2670 9311 ExploratoryD DevelopmentD ServiceŒl /' 15. Well Status after proposed work: Oil D Gas 0 PluggedO IbandonedD WAG D GINJO WINJŒ WDSPLO Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Jennifer Watson ~\r_Ù~o- Contact Jennifer Watson Title Phone Petroleum Engineer 564-5764 Commission Use Only 4/20/04 I Sundry Number: dc>t/-IL/CjV Plug Integrity D Conditions of approval: Notify Commission so that a representative may witness Location Clearance D Form 10-403 Revised 12/2003 Mechanciallntegrity Test D RECEIVED APR 2 1 2004 BY ORDER OF THE COMMISSION Date: ffz/o Y ^16ska Oil & GiS C6nS. Conllnission Anchorage fIIlIfB BFL 11'22" ORIGINAL SUBMIT IN DUPLICATE ~ ~ - 0' bp - To: John Smart/Doug Cismoski GPB Well Ops Team Leaders Date: April 6, 2004 From: Jennifer Watson Production Engineer Subject: A-31A Perforation Request PBAPDWL31.C Capacity Sustainment Est. Cost: $175M lOR: 400 BOPD Type lOR PR N DS-WL AFE JOB DESCRIPTION PRIORITY COMMENTS/OTHER S 400 A-31A PBAPDWL31-C Pull TIP. Drift as deep as possible. 0 400 2 A-31A PBAPDWL31-C SBG Tie-in. Clean liner and set CIBP. APF 4B. Mud acid stimulation. Step rate C 400 3 A-31A PBAPDWL31-C test. See attached procedure Status: Shut in injector. Current perforations in Zone 4A. Waivered for water injection only due to production casing leak. / 109 degrees at 10,053' MD. horizontal 2.37" at 9,285' MD (top of 2-7/8" liner) no tags since CTD completed (11/99) TTP set 3/5103 Max Deviation: Perf deviation: Min. ill: Last TD tag: Well A-31A was drilled 11129/99 to recomplete this injector due to channels in the parent which prevented effective Zone 4B injection. The wellbore trajectory was designed with a toe in Zone 4A to be given a one time slug of MI, however a production casing leak was discovered before --- that was accomplished. The well injected water only into Zone 4A for a little over three years until it was shut in and a TTP was run 315/03. Evaluation of a waiver for MI injection showed that the casing would need to be tested to 4600 psi which is not recommended (86% of burst / rating). The purpose of this request is to return this well to water only injection in Zone 4B. A plug will be set at 10450' MD to isolate the existing Zone 4A perforations and planned / perforations (10,020 - 10,036', 10,280 - 10,290', 10,310 - 10,320' and 10,366 - 10,374' MD) will access Zone 4B. The well is currently waivered for PWI only injection. Contact Jennifer Watson at x5764, 248-8862(hm), 529-4702(cell) with any questions or comments. cc: w/a: A-31A Well File J. Watson D. Robertson ~ ,-...." ~ " A -31Ai Recompletion Program Prepared By: J. Watson Phone#: 564-5764(w), 248-8862(h), 529-4702(c) JOB PLANNING DETAILS: Current Perfs: 10,491' - 10,522' (angle at top perf = 48°) Proposed Perfs: 10,020' - 10,036' (angle at top perf = 109°) ~ 10,280' - 10,290' l: 4-l: 10,310' - 10,320' 10,366' - 10,374' Perf Deviation: Horizontal (max angle = 109° at 10,053' MD) Gas Lift Design: 6 GLMs with dummies installed. MIT - T to 3000 psi passed 3/9/03 ISSSV: None TD Tag History: no tags since well was drilled 11/29/99 Displacement bbls: 148 bbls (tubing = 141, liner to top perf = 7) Static: -3300 psi, 225°F NOTE: TTP set at 9,196' MD (3/5/03). Production Casing leak @ 5875' to cretaceous, 5 BPM @ 1950 psi PREP WORK: 1. Pull TTP at 9,196' MD. Drift as deep as possible. 2. Perform a bullhead SBG treatment with 148 bbls of SBG solution (123 bbls of hot water mixed with 25 bbls of concentrate). Pump at maximum pump rate with a maximum WHP of 3000 psi to the perfs and let soak for 3 hours. Overflush with 150 bbls of hot water at maximum pump rate. Return to water injection. 4/1412004 \-I "-" CT OPERATIONS: 3. MIRV CT. Rill with memory gauge carrier, jet nozzle and stingers as necessary to PBTD. Lay in ~5 bbls of filtered 7.5% HCV20% xylene from 10,500' to 10,000' MD. Soak 30 minutes. Jet 60 bbls of acid at maximum pump rate while making multiple passes from 10,000' - 10,500' MD, taking returns to the perfs. Overflush the acid with 50 bbls of filtered 3% NH4Cl (behind pipe) while making multiple passes. Please note the injectivity in the WSR. Note the potential for H2S in any returns taken to surface. 4. Run tie-in log and flag the coil. POOH. Tie-in to Sperry Sun MWD/GR (11/27/99). 5. Rill with CIBP for 2-7/8" liner and set at 10450' +/- 10'. Pressure test the CIBP to 3000 psi. POOH. / 6. MU 2" PJ, 6 SPF and perf from 10,020-10,036',10,280-10,290',10,310-10,320' and 10,366 - 10,374' MD (reference Sperry Sun MWD/GR, 11/27/99). Tag the CIBP for depth / ~. ' 7. Rill with jetting nozzle and pump the following while making multiple passes across the perfs: 25 bbls 3% NH4Cl with 10% U-66 and 0.2% F75N 50 bbls 7.5% HCl 100 bbls 9% - 1 % HCl-HF Pump the overflush while making multiple passes to PBTD: 150 bbls 3% NH4Cl overflush with 10% V-66 and 0.2% F75N Go to 3000 psi if necessary to establish injection. Once acid is at the perfs the maximum treating pressure should be 1500 psi. All fluids should be filtered to 3 microns. Don't add friction reducer. Please note the initial and final injectivity in the WSR. Please note the vitals in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the EXCEL treating report to the program author. 8. Tag the CIBP to confirm it is still there. POOH. At surface perform a step rate test wit~ maximum WHP of 2000 psi. 9. RDMO. Put on water injection at a target rate of 2900 bwpd. 4/14/2004 2 /"""'-, .. ., Treatment Design: 2100 gal 7.5% HCl 0.5% A261 0.5% A201 20 ppt L58 0.2% F1O3 0.5% W54 0.5% W35 2730 gal 7.5% HCl/20% Xylene 0.6% A261 4 ppt A179 8 ppt A153 20 ppt L58 0.2% F1O3 0.5% W54 0.5% W35 1.5% U-74 20% A26 ~ 4200 gal 9: 1 HCl:HF 0.5% A261 0.5% A201 0.2% F1O3 20 ppt L58 0.5% W54 0.5% W35 -225 bbls 3% NH4Cl water with 10% U-66 and 0.2% F75N Please note the acid titrations and iron ppm on the WSR. 4/14/2004 3 /""""\ .. - TREE = WB..LHEAD= ACTUð. TOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD = 4"CIW M::EVOY BAKER 81.17' 52.1g 3450' 109 @ 10053' 9630' 8800' SS 113-318" CSG, 72#, L-80, ID = 12.347" H 2668' ~ Minimum ID = 2.37" @ 9285' TOP OF 2-718" LNR I TOP OF 7" Lt--R H 9248' 13.75" BKRDEPLOY SLV,ID= 3.00" H TOPOF2-7/8" Lt--R, D =2.37" H 9277 9285' 14-112" TOO, 12.6#, NT13-CR, .0152 bpf, ID = 3.958" H ,--., SAFETY NOTES: CI-ROMETBG. WELL EXCEEDS 70o@ 'íT174' & GOES HORIZ @ 9805'. WARNI/IG: RADIO TRANSM rrTER IN WfA TI-ER MONITORING SHACK MUST æ TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. .. CONTACT PO. "'PRODCSG X FORMATION LfAK. OPERATING LIMITS: MAX lAP = 500 PSI, MAX OAP = 500 PSI (10122/03 WAIVER)'" A-31 A II ~l L :8: t----., ~ I ~~I 9310' f------' 19-518" CSG, 47#, L-80, D = 8.681" H 9512' I- PERFORATION SUMIv1A RY REF LOG: MWD GRIROP 11/27/99 TI: BHCS/GR ANGLEATTOPPERF: 47@ 10491' IIbte: Refer to A"oduction DB for historical perf data I SIZE I SA= I INTERVAL I Opn/Sqz I DATE I 2-7/8" 4 10491 - 10522 0 11/29/99 1 7' Lf'.R, 26#, L-80 U4S, .0383 bpf, ID = 6.276" H 10030' 1 2028' ST MD 6 3100 5 5164 4 6775 3 8347 2 9039 1 9181 H4-1/2"CAWCOSSSV LANDNIP,ID= 3.813" I GAS LIFT Iv1AI'-DRB..S TVD DBI TYPE VLV LATCH FORT DATE 3018 5 M:RLA RA 4907 31 M:RLA RA 6258 33 M:RLA RA 7643 24 M:RLA RA 8281 23 M:RLA RA 8410 26 M:RLA RA 9210' H4-112"PARKERSWSNIP,ID=3.813" 1 9222' H9-518" X4-1/2"TIW HBBPPKR, D =3.875" 1 9270' 9277' 9278' 9299' 9311' 9300' - TOP OF BKRKBPKRW/ SEALASSY,ID =2.56" 1 - 3.0" BKRSEALASSY,ID =2.40" I - 4-1/2" PARKER SWS t-.!P, D = 3.813" I H4-1/2" PARKERSWN t-.!P, D =3.80" 1 H4-1/2" WLEG, ID= 3.958" 1 HELMDTT I ~ I MILLOUTWINDOW 9586' - 9593' 9584' HTOPOFWHIPSTOCK I NOTE: NO RA TAG RUN 10523' I 2-7/8"LNR,6.16#,L-80,.OO579bpf,ID=2.37" H 10590' I REV BY DATE REV BY COIvtv18'JTS 11/16/03 TJFYPAG WAIVERSAFEfY NOTE DATE 07/18/85 08/31/91 11129/99 03/05101 07/03101 . 02/22103 COMM:NfS ORIGINAL COMPLETION RWO CTDHORIZONAL SIDETRACK SIS-LG FNAL Gi/KAK CORRECTIONS JMPiKK WAIVER SAFElY NOTE PRUDHOE BAY UNrr WELL: A-31A ÆRMTNo: 1990560 API lib: 50-029-21383-01 SB:: 35, T11 N, R13E, 2316' NSL & 1012' WEL BP Exploration (Alaska) BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp September 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: A-31A (PTD 1990560) AppliCation for Sundry Approval Dear Mr. Aubert: Attached is Report of Sundry Well Operations form 10-404 and Application for Sundry Approval form 10-403 for Well A-31A. This request is to cancel the current sundry and receive approval for a new sundry to continue produced water injection with a production casing leak. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or myself at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Coordinator Attachments STATE OF ALASKA Oi ALASK~ OIL AND GAS CONSERVATION C ~.,alSSlON APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon D Suspend D Operation Shutdown r-1 Perforate[--[ Variance[] Annuar Disposal[~ Alter Casing D Repair Well F'I Plug Perforations r-~ stimulated Time ExtensionD · ..O. ther[--I Re enter Suspended Wellr'''~ ~'~O Change Approved Program r-] Pull Tubing D Perforate New Pool [-I - I I~NJ VARIANCE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development D Expl°rat°ryD 199-056/''' 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 995'19-66'12 Stratigraphicr-1 Service~l 50-029-21383-01-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 81.00 A-31A / 8. Property Designation: 10. Field/Pool(s): ADL 028286 & ADL 047472 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):10593 ITota' Depth TVD (~): IEffect've Depth MD (~t): IE'e°tive Depth TVD Ct): IP'ugs (measured): I Junk (measu'ed):9080 10523 9036 None None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor '1 '10 20" 29' - '139' 29' - '139' 40K 520 Surface 2639 '13-3/8" 29' - 2668' 29' - 2668' 80K 2670 Intermediate 9483 9-5~8" 29' - 95'12' 29' - 8783' 80K 4760 Liner 338 7" 9248' - 9586' 8552' - 8846' 80K 7020 SideTrack Liner '1320 2-7/8" 9270' - '10590' 8572' - 9078' 80K '1 '1 '160 Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: [Tubing Grade: Tubing MD (ft): '1049'1 '-10522' 9015'-9036'I 4-1/2" '12.6#I NT13-CR 93'10 Packers and SSSV Type: Packers and SSSV MD (ft): 9-5/8"x 4-'1/2" TIW HBBP PKR, 4-'112"x 2-7~8" BKR KB PKR @ 9270'; 4-1/2" Camco SSSVLN. PKR's @ 9222' & 9270', SSSVLN @ 2028'. 12. Attachments: Description Summary of Proposal l~ 13. Well Class after proposed work: Detailed Operations Program [-1 BOPSketch D ExploratoryD DevelopmentD Service[] 14. Estimated Date for I 15. Well Status after proposed work: Commencin~l Operation: c~/ tl, D ~ OilD GasD PluggedD AbandonedD 16. Verbal Approval: Date: WAG I~1 GIN,ID WIN,ID WDSPLr'-I Commission Representative: Prepared by DeWayne R. Schnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joe Anders Printed Name Joe Anders Title GPB Well Inte~lrity Engineer Si.nature ,,o.. 07/SS -S 0 / Commission Use Only J Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity FI BOP TestFI Mechancial Integrity TestD Location clearanceFI Subsequent Form Required: Alask~ .0il & L~as Co~.s. Approved by: COMMISIONER THE COMMISSION Date: Form 10-403 Revised 2/2003 0 R IGINA SUBMIT IN DUPLICATE A-31A Description Summary of Proposal 09/12/03 Problem Injector with a production casing leak. Current Sundry requirements are not aligned with Sundry Matrix. Well History and Status Well A-31A (PTD 1990560) is an injector with a production casing leak. MIT-T's pass, demonstrating competent tubing. Current Sundry requirements are not aligned with the Sundry Matrix dated 5/13/03. This proposal updates the Conditions of Approval to the current requirements. Pertinent well events: > 01/10/00: AOGCC approved Sundry # 300-008 for produced water only injection > 01/26/03: MIT-OA Passed to 2000 psi > 03/05/03: SL set TTP > 03/09/03: MIT-T Passed to 3000 psi, LLR-IA = 5 bpm @ 1950 psi This request is to cancel the existing production casing Sundry and issue a new Sundry for a production casing leak using current Conditions of Approval. The following supports the request: · An MIT-T passed on 03~05~03 to 3000 psi, demonstrating competent tubing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a tubing leak. · An annual MIT-OA will be conducted to confirm surface casing integrity. · An MIT-T will be conducted every 2 years to confirm tubing integrity. Proposed Action Plan 1. Allow well to continue water-only injection. 2. Record wellhead pressures and injection rates daily. 3. Submit a monthly report of daily pressures and injection rate. 4. Perform an annual MIT-OA. 5. Perform MIT-T every 2 years. 6. Stop injection and notify the AOGCC if there is any indication the tubing has lost integrity. TREE = 4" CIW WELLHEAD= McEVOY ACTUATOR= BAKER KB. ELEV = , 81.17' BF. ELEV = 52.19' KOP = 345O' Max Angle = 109 @ 10053' Datum MD = 9630' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" Id 2668' A-31A SAFETY NOTES: CHROMETBG. WELL EXCEEDS 70°@ 9774' ~"' ES HORIZONTAL @ 9805'. WARNING: RADIO TRANS,. . TER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR. **'9-5/8" X FORMATION LEAK @ 5875' (02/22/03 WAIVE~)*** 2028' Jd4-1/2" CAMCO SSSV LAND NIP, ID = 3.813" GAS LIFT MANDRELS IMinimum ID = 2.37" @ 9285' TOP OF 2-7/8" LNR 921o' Id4-1/2" PARKER SWS NIP, ID= 3.813" I ITOPOF 7" LNR Id 9248' 9222' 9270' 9277' 9278' 9299' 9311' I-I 9-5/8" x 4-1/2" TIW HBBP PKR, tD = 3.875" 13.75" BKR DEPLOY SLV, ID = 3.00" Id 9277' ITOPOF 2-7/8" LNR, ID = 2.37" Id 9285' 4-1/2" TBG, 12.6#, NT13-CR, 0.0152 bpf, ID = 3.958" Id 9310' I 9-5/8" CSG, 47#, L-80, ID = 8.681" Id 9512' PERFORATION SUMMARY REF LOG: MWD GR/ROP 11/27/99 TI: BHCS/GR ANGLEATTOP PERF: 47@ 10491' Note: Refer to Production DB for historical perf data i iI 2-7/8"I 4I 10491-10522 11/29/99 9300' TOP OF BKR KB PKR W/SEAL ASSY, ID = 2.56" 3.0" BKR SEAL ASSY, ID = 2.40" 4-1/2" PARKER SWS NIP, ID= 3.813" Id4-1/2" PARKERSWN NIP, ID= 3.80" I Id4-1/2" WLEG, ID= 3.958"I MILLOUT WINDOW 9586' - 9593' 9584' Id TOP OF WHIPSTOCK INOTE: NO RA TAG RUN I 10523' I 12-7/8" LNR, 6.16#, L-80, 0.00579 bpf, ID= 2.37" Id 10590' I I 7" LNR, 26#, L-80 IJ4S, 0.0383 bpf, ID = 6.276" Id 10030' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/18/85 ORIGINAL COMPLETION 08/31/91 RWO 11/29/99 CTD HORIZONAL SIDETRACK 03/05/01 SlS-LG FINAL "0'~/03/01 CFI/KAK CORRECTIONS 02/22/03 JMP/KK WAIVER SAFETY NOTE PRUDHOE BAY UNIT WELL: A-31A PERMIT No: 1990560 APl No: 50-029-21383-01 SEC 35, T11N, R13E, 2316' NSL & 1012' WEL BP Exploration (Alaska) A-31 TIO Plot 4,000 ~ Tbg 3,000 2,000 1,000 0 ~ ~ 9/9/2002 11/9/2002 1/9/2003 3/9/2003 5/9/2003 7/9/2003 9/9/2003 ~ OA OOA ~ OOOA BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 bp September 12, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Subject: A-31A (PTD 1990560) Application for Sundry Approval Dear Mr. Aubert: Attached is Report of Sundry Well Operations form 10-404 and Application for Sundry Approval form 10-403 for Well A-31A. This request is to cancel the current sundry and receive approval for a new sundry to continue produced water injection with a production casing leak. A description summary of proposal and wellbore schematic is included. If you require any additional information or clarification, please contact either John Cubbon or myself at (907) 659-5102. Sincerely, Joe Anders, P.E. Well Integrity Coordinator Attachments ~OANN~.D SEP 2, ~ 2003 ORIGINAL i" STATE OF ALASKA il ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE] Suspend[~ Operation Shutdownr"~ Perforate[--~ Variancer-] Annuar DisposalE~ After Casing[-'] RepairWellE] Plug Pedorations~ Stimulate~ Time Extension~ Other~ Change Approved Program~ Pull Tubing~ Pefiorate New Pool~ Re-enter Suspended Well~ CANCEL 10~03 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement ~ Explorato~ 199-056 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic~ Se~ice~ 50-029-21383-01-00 7. KB Elevation (fi): 9. Well Name and Number: 81.00 A-31A 8. PropeAy Designation: 10. Field/Pool(s): ADL 028286 & ADL 047472 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summa~: Total Depth measured 10593 feet true vertical 9080 feet Plugs (measured) Effective Depth measured 10523 feet Junk (measured) true vertical 9036 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 139' 139' 40K 520 S u dace 2639' 13-3/8" 2668' 2668' 80 K 2670 Intermediate 9483' 9-5/8" 9512' 8783' 80K 4760 Liner 338' 7" 9248'-9586' 8552'-8846' 80K 7020 SideTrack Liner 1320' 2-7/8" 9270'-10590' 8572'-9078' 80K 11160 Pedoration depth: Measured depth: Open Peals 10491'-10522' Tubing: ( size, grade, and measured depth) 4-1/2" 12.6~ NT13-CR TBG ~ 93!~0'.. ,.,- ~ ., ..... Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" TIW HBBP Packer ~ 9222'. 4-~i~' BKR KB PKR w/ Seal ASSY ~9270'. 4-1/2" Camco SSSV Landing Nipple ~ 2028'. 12. Stimulation or cement squeeze summa~: Inte~als treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: ,x, or o D Oev .o,m .tD S ic.B Copies of Logs and Surveys run __ 16. Well Status after proposed work: Oil~ Gas~ WAG~ GINJ~ WINJ~ WDSPL~ Daily Report of Well Operations ~ 17. I hereby ceAi~ that the foregoing is true and correct to the best of my knowledge. ~Sundry Number or N/A if C.C. Exempt: Contact Joe Anders ~ ~300-008 Printed Name Joe Anders Title GPB Well Integrity Engineer ~/~ 10-404 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate_ GEL SQUEEZE IA Pull tubing _ Alter casing _ Repair well _X Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2960' FNL, 1010' FEL, Sec. 35, T11N, R13E, UM At top of productive interval 5050' FNL, 1011' FEL, Sec. 36, T11 N, R13E, UM At effective depth 422' FNL, 3737' FEL, Sec. 01, T10N, R13E, UM At total depth 413' FNL, 3680' FEL, Sec. 01, T10N, R13E, UM 5. Type of Well: Development __ Explorato~._ Stratigraphic_ Service__X 'X (asp's 654395, 5947483) (asp's 656981, 5944802) (asp's 657007, 5944798) (asp°s 657062, 5944806) 12. Present well condition summary Total depth: measured true vertical 10593 feet 9080 feet Plugs (measured) 6. Datum elevation (DF or KB feet) RKB 81 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-31A 9. Permit number / approval number 199-056 / 303-015 10. APl number 50-029-21383-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Oil Pool Effective depth: measured 10523 feet true vertical 9036 feet Casing Length Size Conductor 110' 20" Surface 2639' 13-3/8" Intermediate 9483' 9-5/8" Liner 338' 7" SideTrack Liner 1320' 2-7/8" Perforation depth: measured Open Perfs 10491 '-10522' Junk (measured) Cemented Measured Depth True Vertical Depth 72 cf Concrete 139' 139' 3254 cf PFE, 465 cf PF 2668' 2668' 1971 cf Class 'G' 9512' 8783' 278 Class 'G' 9248'- 9586' 8552'- 8846' 208 cf Class 'G' 9270'- 10590' 8572'- 9078' true vertical Open Perfs 9015'-9036' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2" 12.6#, NT13-CR TBG @ 9310'. 9-5/8" x 4-1/2" TIW HBBP PKR @ 9222'. 4-1/2" x 2-7/8" Baker KB PKR w/Seal ASSY @ 9270'. 4-1/2" Camco SSSV Landing Nipple @ 2028' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 03/07/2003 Subsequent to operation 04/22/2003 OiI-Bbl Representative Daily Avera.qe Production or Iniection Data Gas-Mcr Water-Bbl 4300 3700 Casing Pressure Tubing Pressure 1524 1256 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil__ Gas_ Suspended_ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. -D~W - ~ ~ ~ - ''''''' -e ayneR. Schnorr ...... O'R"IGINAL Date April 23, 2003 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE A-31A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/27/2003 GEL TREATMENT: AC-MONITOR 03/04/2003 ANN-COMM (UIC PROGRAM): TUBING TAIL PLUG 03/04/2003 GEL TREATMENT: TUBING TAIL PLUG 03/05/2003 GEL TREATMENT: BRUSH / BROACH; HOT OIL TREATMENT 03/05/2003 ANN-COMM (UIC PROGRAM): TUBING TAIL PLUG 03/09/2003 GEL TREATMENT: AC-LLRT; MIT-T 04/22/2003 TESTEVENT--- INJECTION PRESSURE, PSI: 1,256 TYPE: PW VOLUME: 3,700 BWPD. EVENT SUMMARY 01/27/03 T/I/O = 860/440/270. TEMP = 144. (MONITOR POST MITOA). 03/04/03 PUMPED 40 BBLS 60/40 DOWN TUBING, 20 BBLS 60/40 DOWN FLOWLINE TO FREEZE PROTECT. 03/04/03 DRIFT W/3.80 SWEDGE TO 9182' WLM, RIH W/PXN PLUG BODY TO 3577' WLM, SAT DN, POOH, MUNG ON TOOL, START BRUSH AND FLUSH WITH DIESEL. 03/05/03 HOT OIL BRUSH & FLUSH. PUMPED 170 BBLS OF 190 DEGREE F DIESEL DOWN TUBING WHILE HES BRUSHED TUBING. 03/05/03 B & F TBG TO SWS NIP @ 9210' WLM. SET PXN PLUG BODY (29" OAL) @ 9196' WLM. SET PRONG @ 9196' WLM ( 98" LONG, 1 3/4" FN, 2 1/8 STEM) BLED WELL FROM 500 PSI TO ZERO PSI. <<< LEFT WELL SHUT IN >>> 03/O9/O3 MIT-TUBING PASSED @ 3000 PSI. PUMPED 70 BBLS OF CRUDE DOWN THE IA, LLR OF 5 BPM @ 1950 PSI. FINAL PRESSURES 50/500/20. 04/22/2003 TESTEVENT --- INJECTION PRESSURE, PSI: 1,256 TYPE: PW VOLUME: 3,700 BWPD. FLUIDS PUMPED BBLS 5 DIESEL PUMPED FOR PRESSURE TEST. (2 TESTS) 3 NEAT METHANOL 60 60/40 METHANOL WATER 150 ,DIESEL 70 CRUDE 288 TOTAL Page 1 bp BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 17,2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for A-31A GEL IA SQZ to seal off Cretaceous leak. BP Exploration Alaska, Inc. proposes to perform a MARA-SEAL Gel IA bullhead treatment on A-31Ai. This treatment is a field trial aimed at eliminating a Cretaceous leak so that this well can be placed on MI. Currently the well is restricted to water f injection only. A-31A is a horizon, n,n~l injector that was sidetracked in November 1999. The well passed a 3500 psi MITIA just prior to the sidetrack; however,_.~it failed a post sidetrack Diagnostics have identified a 2.5 BPM (at 3000 .p,,,:.si) Cretaceous leak around 90~~_ ' ~ d. The chrome tubing has passed a 3000 psi MITT, and the wellhead also test§ OK. A-31A was completed in lower Z~_, 4A for the purpose of injecting a deep MI slug prior to recompleting as a 4B injector. The MI slug has yet to be injected, and the surrounding 4B producers have no in-zone injection support. The procedure includes the following major steps: 1. S 2. O 3. 0 4. 0 5. S Set plug in nipple @ 9210' md. Pressure test tubing to 3000 psi, establish injection rate of at least 1.5 bpm down IA. Pump MARA-SEAL treatment. Wait 3 days, perform MITIA to 3000 psi. Remove plug @ 9210' md and return to injection. Maximum Deviation: Annular Displacement: Minimum ID: Last Downhole Ops: Latest H2S Value: 34 degrees @ 2700' md 314 bbls (to estimated leak point of 5,875' md) 2.37" (liner ID) 12/25/01 - SET PX TT PLUG. TEST TBG. PULL PX TT PLUG n/a If you have any questions concerning this Sundry Application, please call Paul Bartel 564-5402 or Mike Martin 229-6012. $C/ANNED FEB 0 & 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request:., Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ /' Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate GEL IA SQZ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other_ 6.Datum elevation (DF or KB feet) RKB 81.2 feet 2, Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2960' FNL, 1010' FEL, Sec. 35, T11N, R13E, UM At top of productive interval 5050' FNL, 1011' FEL, SEC 36, T11N, R13E, UM At effective depth 422' FNL, 3737' FEL, Sec. 01, T10N, R13E, UM At total depth 413' FNL, 3680' FEL, Sec 01 T10N, R13E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic Service._X (asp's 654395, 5947483) (asp's 656981, 5944802) (asp's 657007, 5944798) (asp's 657062, 5944806) 7. Unit or Property name Prudhoe Bay Unit 8. Well numbs/ A-31A 9. Permitnumber/approvalnumber 199-056 /' 10. APInumber 50-029-21383-01 11. Field/Pool Prudhoe Bay Field/Prudhoe Bay OilPool 12. Present well condition summary Total depth: measured 10593 feet Plugs (measured) true vertical 9080 feet Effective depth: measured 10523 feet Junk (measured) true vertical 9036 feet Casing Length Size Cemented Conductor 110' 20" 72 cf Concrete Surface 2639' 13-3/8" 3254 cf PFE, 465 cf PF Intermediate 9483' 9-5/8" 1971 cf Class 'G' Liner 338' 7" 278 Class 'G' Sidetrack Liner 1320' 2-7/8" 208 cf Class 'G' Measured Depth Trueve~icalDepth 139' 139' 2668' 2668' 9512' 8783' 9248'-9586' 8552'-8846' 9270'-10590' 8572'-9078' Perforation depth: measured Open Perfs 10491'-10522' true vertical Open Perfs 9015'-9036' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) RECEIVED ./AN 1 7 2005 4-1/2" 12.6# NT13-CR TBG @ 9310'. L~aska 0il & Gas Cons. Commission 9-5/8" x 4-1/2" TIW HBBP PKR @ 9222'. 4-1/2" x 2-7/8" Baker KB PKj~I~{~t~J~ASSY @ 9270'. 4-1/2" Camco SSSV Landing Nipple @ 2028'. 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation January, 2003 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Service WAG INJECTOR Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Paul Bartel @ 564-5402. Paul Bartel Title: Production Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Date January 17, 2003 Prepared b}' DeWe)/ne R Schnorr 564-5174 ]Appr°val n°',~O 3- (.) @lug integrity __ ~B?P Test__ Location clearance __ ~.IL ~) /~ Mechanical Integrity Test .~ Subsequent form required 10- ORIGINAL SIGNED BY Commissioner Date Approved by order of the Commission M L SCANNED FEB 2003 Form 10-403 Rev06/15/88. [¢,¢ ~ ~ .... ~ ~ ~ '~ ;'-~ SUBMIT IN TRIPLICATE A-31A: Bullhead MARA-SEAL Gel Cretaceous Leak shut off OBJECTIVES/COMMENTS The primary operation will be to pump MARA-SEAL gel into the cretaceous leak, obtain a squeeze pressure, and leave MARA-SEAL in the annulus and then pressure test the IA to a successful C.I.T. The procedure is to set a plug in the tubing tail in order to hold pressure on / the tubing during the squeeze operations. Currently the IA has 9.8 ppg brine on the backside. A bullhead treatment of 7% polymer will be pumped down the IA and out the cretaceous leak(s). Pump time is estimated to last between 3 and 6 hours depending on injection rate. On 4/13/00 an injectivity test was performed at 2.5 bpm at 3000 psi for 30 minutes. / Planned treatment volume is 100 bbl of 7% MARA-SEAL gel, followed by a spacer of 50 bbls of polymer w/o crosslinker. Annulus is then displaced with 2% KCI water spacer and hydrocarbon (diesel or crude) to leave well freeze protected, -110 bbls. The goal is to place approximately 70 bbls of Cross-linked MARA-SEAL into the formation. This would represent a 4 foot radial penetration over 20 feet (a guess as the linear extent of the holes in the 9-5/8" casing is unknown). Have Dowell lab determine Crosslinker requirement for a 7% MARA-SEAL fluid that results in 5-7 time at 100 F/estimated BHST at 5875' MD) 1. Set plug in 4-1/2 SWS Nipple (3.813" ID) @ 9210' MD 2. Pressure test tubing to 3000 psi 3. Confirm injectivity into IA of at least 1.5 bpm, report results to design engineer prior to pumping treatment "'STE~: ~tTreatment.~. ,~ ,~,~,~, 1. MIRU equipment required to pump a bullhead treatment down the IA. 2. Pressure up tubing to 3000 psi to prevent collapse during injection down IA. 3. Bullhead MAR-SEAL treatment down the IA as per the following: · 25 bbls of 2% KCI + 0.2% F103 surfactant to water wet formation and establish injection · 25 bbls 7% MARA-SEAL spacer · 100 bbls of 7% MARA-SEAL w/XL additive · 50 bbls 7% MARA-SEAL spacer · 20 bbls 2% KCI spacer · 214 bbls diesel or dead crude (for freeze protection) Slow rate to 1BPM when XL MARA-SEAL reaches 5875' to try building squeeze pressure. NOTE: This schedule will place 70 bbls of MARA-SEAL behind pipe and leave 30 bbls in the IA 1. Ensure that well remains shut in for 3 days for gel to completely cure. 2. PERFORM MITIA to 3000 psi / 3. Remove plug from SWS Nipple 26.3 Ib/bbl J491 Gelling Agent 0.72 Ib/bbl J492 Crosslinker/actual concentration to be determined by Dowell lab) Sincerely, SCANNED FEB 2.0133 Paul Bartel Production Engineer TREE = 4" CIVV WFI LHEAD= McEVOY A CTUA TOR= BAKER KB. F_LEV = 81.17' BF. ELEV = 52.1~ KOP = 3450' Max Angle = 109 @ 10053 Datum MD = 9630' Datum TVD = 8800' SS 13-3/8" CSG, 72~, L-80, ID: 12.347" H Minimum ID = 2.37" @ 9285' I I TOP OF 2-7/8" LNR 2668' ITOP OF 7" LNR H 9248' A-31A SAFETY NOTES: CI-ROMETBG. WELL EXCEEDS 70°@ 9774' & GOES HORIZONTAL @ 9805'. WARMNG: RADIO TRANSMITTER IN WEATHI~ M OMTORING SHACK MUST BETUI~Ii~ OFF BEFORE ANY WI=IL WORKINVOLVlNG EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR. 2028' H4-1/2"CAMCOSSSV LANDNIP, ID: 3.813" GAS LIFT rv~ NDRELS 9210' 9222' 9270' 9277' 9278' H4-1/2" PARKER SWS NIP, ID= 3.813" H9-5/8" X 4-1/2" TIW HBBP PKR, D = 3.875" 3.75" BKR DEPLOY SLV, ID = 3.00" H 9277' ITOPOF2-7/8"LNR, D=2.37" H 9285' 4-1/2" TBG, 12.6/¢, NT13-CR, 0.0152 bpf, ID= 3.958" H 9310' 9-5/8"CSG, 47#,L-80, D=8.681" H 9512' PERFORATION SUMMA RY REF LOG: MWD GR/ROP 11/27/99 TI: BHCS/GR ANGLEATTOP PI~F: 47@ 10491' Note: Refer to Produclion DB for historical perf data I S, EISEPI INTERVAL I O../S. z l DATEI 2-7/8"I 4 11O491-1O522I O 141/29/99I 9299' 9311' I 9300' I MILLOUT WINDOW 9586' - 9593' I TOP OF BKR KB PKR W/SEAL ASSY, ID = 2.56" 3.0" BKR SEAL ASSY, ID: 2.40"I 4-11Z' PARKERSWS NiP, D =3.813" I H4-1/Z'PARKERSWNNIP, D=3.80" I H4-1/Z' WLEG, ID= 3.958"I 9584' I--ITOP OF WHIPSTOCK 10523' 12-7/8" LNR, 6.16#,L-80, 0.00579bpf, ID:2.37" H 10590' 7" LNR, 26#, L-80 U4S, 0.0383 bpf, ID = 6.276" H 10030' 0 DATE57/18/8 REV BY COk/IVlENTS DATE ~ BY COMIVENTS ORIGINAL COMPLETION 07/03/01 CH/KAK CORRECTIONS 08/31/91 RWO 11/29/99 CTD HORIZONA L SIDETRACK 02/05/O1 SIS-IVI-I CONVERTEDTOCANVAS 03/05/01 SIS-LG FINAL PRUDHOE BAY UNIT WELL: A-31A PERI~,tT No: 99-0560 APl No: 50-029-21383-01 2316' NSL & 1012' WEL, Sec. 35, T11N, R 13E BP Exploration (Alaska) 8,CANNED FEB 0 ,-1 2.003 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1990560 Well Name/No. PRUDHOE BAY UNIT A-31A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-21383-01-00 MD 10593 TVD 9080 Completion Date 11/29/1999 Completion Status WAGIN Current Status WAGIN U1C Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey~~N~/.~ , DATA INFORMATION (data taken from Logs Portion of Master Well Data Maint) Types Electric or Other Logs Run: Well Log Information: Log/ Data Type D D Digital Digital Log Log Run Interval OH / · Dataset Media Format ..Na9~/~ - Scale Media No Start Stop CH Received Number ...................... ~ ' ~tGP-'I-VD ............... 25 ........ i=iN'~,~ ......... 8~/8 ......85~ -oH 31i4)2000 /. ~ IL 25 FINAL 9410 10578 OH 12/1/1999 T iD T 0 Comments UIC 12/1/199~~71 9410-10578 ....~-. 3/9/2000 ~ 9580-10562 ~ L ~LEAK-SPIN/TEM/ 5 FINAL 50 9290 CH 1/11/2000 PRES 12/24/99 / ~t// SRVY LSTNG 10 10593 OH 1/6/2000 BFII 9509.. Lo.LEAK 5 FINAL 50 9290 CH 1/11/2000 LJ.~' NGP-MD 25 FINAL 8763 10593 OH 3/14/2000 UIC Well Cores/Samples Information: Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/(~ Chips Received'? Analysis Received? Daily llistory Received? ~____~N Formation Tops Receuived? '~/N Comments: Permit to Drill No. 1990560 MD 10593 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Well Name/No. PRUDHOE BAY UNIT A-3 lA Operator. BP EXPLORATION (ALASKA) INC 9080 Completion Date 11/29/1999 Completion Status WAGIN Current Status Date: API No. 50-029-21383-01-00 WAGIN UIC Y STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface / ¢'/ v~ 2960' FNL, 1010' FEL, Sec. 35, T11 N, R13E, UM At top of productive interval 5050' FNL, 1011' FEL, SEC. 36, T11N, R13E, UM At effective depth At total depth 413' FNL, 3680' FEL, Sec. 1, T10N, R13E, UM 5. Type of Well: Development __ Exploratory _ Stratigraphic __ Service__X (asp's 654395, 5947483) (asp's 656981, 5944802) (asp's 657062, 5944806) 6. Datum elevation (DF or KB feet) RKB 81.2 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-31Ai 9. Permit number/~eproval number 199-O56 10. APl number ~ 50-029-21383-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary v/ Total depth: measured 10593 feet Plugs (measured) true vertical 9080 feet v'/ Effective depth: measured 10523 feet Junk (measured) true vertical 9036 feet Casing Length Size Cemented Measured Depth Conductor 110' 20" 8 cubic yards concrete 110' Surface 2587' 13-3/8" 3254 cuft PFE & 465 cuft PF 2668' Intermediate 9432' 9-5/8" 1971 cuft Class G 9513' Production 339' 7" 278 cuft Class G 9587' Liner 1313' 2-7/8" 208 cuft C~ass G 10590' True verticalDepth 110' 2668' 8784' 8846' 9078' Perforation depth: measured 10491' - 10522'. true vertical 9015' - 9036'. Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4-1/2", 12.6#, NT13-CR Tubing @ 9300' MD. RECEIVED JI N Z 2001 Alaska Oil & Gas Cons. Oomrniss/on Ar~'horage 9-5/8" x 4-1/2" TIW HP-BP Packer @ 9222' MD. 4-1/2" Camco SSSV Nipple @ 2028' MD. 13. Attachments Description summary of proposal ___X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operation JanuaryS7, 2001 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas __ Suspended __ Service __(WAG __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed %.._,.-¢--¢4 ~ Title: BPA Workover Stimulation Eng,neer Ted Cahalane FOR COMMISSION USE ONLY Questions? Call Ted Cahalane @ 564-5596. y/5'//~/Date Prepared by Paul Rauf @ [;64-5799. Conditions of approval: Notify Commission so representative may witness Plug integrity ~ ~Op Test ~ LocatiOn clearance' Mechanical Integr~ Test~ ~ ~~% Subsequenl fo~ required lO- Approved by ordor of the Oommission ~ Tagtor .~:¢c~::~, ~ Approval no. Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE bp January 11, 2001 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Julie Heusser, Dan Seamount, & Cammy Oechsli Taylor Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276-7542 Dear Commissioners: Re: A-31Ai Injector Backside Squeeze Enclosed for your review is a Sundry Application 10-403 for a backside squeeze to seal off a Cretaceous leak for Prudhoe Bay Well A-31Ai. Primary_ Objective Isolate a Cretaceous leak by circulating cement up the tubing x casing annulus with 11 ppg LiteCrete cement from the production packer up to a depth of 3600'. This will allow the well to return to MI injection. Background A-3 lA is an injector currently waivered for water only injection due to a Cretaceous leak at 5900' MD. We propose placing 11.0 ppg LiteCrete cement in the 9-5/8" x 4-1/2" tubing annulus from the packer at 9222' MD up to a depth of 3600' MD. 10 bbls of LiteCrete will also be squeezed into the Cretaceous leak. The squeeze will be performed with coil pumping through an EZSV squeeze retainer and circulating through the bottom GLM. This injector was sidetracked in November 1999. It passed an MITIA pre sidetrack, however it failed the post sidetrack MITIA performed before putting the well on MI injection. A 2.5 BPM leak at 3000 psi has been located in the 9-5/8" casing around 5900' MD. A 5/99 Kinley caliper survey showed the chrome tubing to be in excellent condition. The tubing passed an MIT to 3000 psi in December 1999 and it has a functional SSSV. Following the squeeze, a bond log will be run to evaluate the quality and location of the cement. Both the IA and the tubing will be tested to 2000 psi. Once all the test have been successfully completed, the well will be put on MI injection. We also propose requiring a plug to be set in the 2-7/8" liner and the tubing pressure tested to 2000 psi once every four years in the future. RECEIVED Page 1 J/~N 1 1 Alaska Oil & Gas Cons. Commiss~ Anchorage Major Steps 1. RU slickline. Drift tubing and liner. 2. RU CTU. Clean out liner to TD and set CIBP at 9320'. 3. RU slickline. Pull bottom GLV from mandrel at 9181' 4. Load tubing and IA. Circulate up IA to clean up annulus. 5. RU E-Line. Set EZSV squeeze retainer at 9160'. 6. RU CTU. Stab into EZSV and circulate 301 bbls of 11.0 ppg LiteCrete cement up the IA. Squeeze 10 bbls LiteCrete into the Cretaceous leak at 5900'. Final cement top will be 3600'. 7. RU CTU. Mill out EZSV and cement to 2-7/8" liner. PT tubing to 2000 psi. Continue cleaning out cement and CIBP. Push plug to bottom. 8. MITIA to 2000 psi. 9. Run SCMT cement bond log to evaluate cement quality in annulus. 10. RU slickline. Run SSSV. Put well on MI injection at recommended injection rate. If you have any questions concerning this sundry application, please don't hesitate to call me at 564-5596. Sincerely, Ted Cahalane BP Wells Engineer Alaska Drilling & Wells Group Page 2 RECEIVED d/lt 1 1 001 Alaska 0/I & Gas Co~s. Commiss/on Anchorage A-31A Injector Backside Squeeze SSSV 2028' 13-3/8" Casing 2668' · I I 2200' Freeze Protect Capacity 9-5/8 x 4-1/2 0.0535 bbls/ft 4-1/2 tubing 0.0152 bbls/ft 3600' Cement Top Cretaceous Leak 5875' 2.5 BPM @ 3000 psi 9-5/8" x 4-1/2" Packer 9222' 9161' EZSV Retainer (=20' above GLM ) 9181' GLM #1 7" Liner top 9248' 2-7/8" Liner top 9270' 9320' ClBP 9-5/8" Liner 9512' 7" Liner window 9587' Peals 10,491' to 10,522' 2-7/8" Liner 10,590' RECEIVED Alaska Oil & Gas Cons, Commissiorl Anchorage 6 5 4 3 2 i CO]LED TUBINt~ UNIT BOP EOU ! PMENT 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAJAS 3. 5000 PSI 4 1/6" I'fYD~L~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAIDS 6. 5000 PSI 4 1/16" STUFFING BOX RE. CE VED Al~ka 0/I & Gas Cons. C,~r~n ! 3 i m 2 HIREL ]NE BOP EOUIPHENT J 1. 5000 PSI 7" WELLHCAD CONN£CIOR IrLANC;E ~. 5000 PSI WIRELIN[ RAIDS (VARIABLE SIZE) .3. 5000 PSi 4 1/6" LUBRICATOR , 4. 5000 PSI 4 1/$" FLOW TUBE PACK-OFF Subject: A-31A Annulus Squeeze Date: Tue, 30 Jan 2001 19:33:18 -0600 From: "Cahalane, Ted W" <CahalaTW@BP.com> To: "Tom Maunder (E-mail)" <Tom_Maunder@admin.state.ak. us> CC: "Frankenburg, Amy" <FrankenA@BP.com> Tom, You've expressed three concerns in your memos about the A-31A backside squeeze. Here's my response. 1) You pointed out that we set a liner top packer dudng the sidetrack but have not run a bond log. You wanted to know if we have plans to see if the liner top packer was holding. On November 29, 1999 a KB production packer was set on top of the 2-7/8" liner top. It was then successfully pressure tested to 2200 psi for 30 minutes. 2) You asked if we evaluated the effect of temperature changes from PW! to MI on the shortened 3000' of tubing. ! performed a tubing movement analysis on the post squeeze case and did not see a problem swapping from M! at 60°F to PWI at 160°F. i'd be happy to discuss with you in more detail if you'd like. 3) You asked what options are available if the well fails a future MIT. That will depend on what is wrong. If the well fails an MITIA, I'd set a plug in the tubing and see if there is a T x IA problem above the cement. If so, this could be patched. On the other hand if the tubing passed MIT, then the problem is IA x OA or IA x formation. One option in this case is to cut and pull tubing, scab the casing, and re-run tubing with some type of bottom packer near the top of cement. With good tubing, a second option is to run a coil inner string. A less desirable option is more cement in the IA. A tubing leak below the cement top would be harder to correct, in this case the leak would be through the tubing, past the cement in the annulus, and out a hole in the casing. I would think that a tubing leak would be at a collar (corrosion in chrome tubing in injection service shouldn't be a problem), if the leak point is known it could be patched. We could also look at squeezing the leak in a more conventional fashion. Certainly cement up the backside will complicate any future repairs, but there are still options. Please let me know if you have any other concerns. 1 of 1 2/3/01 7:21 AM Subject: Re: Injector Backside Squeeze Date: Wed, 24 Jan 2001 13:04:45 -0900 From: Julie Heusser <jutie_heusser@admin.state.ak. us> To: Tom Maunder <tom_maunder@admin,state.ak.us> Tom, Thanks for the quick evaluation. I feel more comfortable with the proposal now. A general philosophical question to consider: On those injection wells where we have granted a waiver to continue operations (and specifically those that have/had casing problems) - should we routinely (every 4 years?, every 2 years) require that an operator demonstrate fluid is remaining within zone? Admittedly it could be costly to the operator if we were to require a periodic pump in temperature surveys o these wells but it may be something we want to consider. Tom Maunder wrote: :> :> :> :> >. > ;> ;> > > > > > > > > > :> > > > Julie, i have checked the records we have. Blair completed an assessment regarding cement isolation June 3, 1994. We do not have the bond log in the file. He was provided a copy and notes, "CBL shows good bonding above 9-5/8" shoe. Tested liner lap OK (also csg) 8/30/91." and concludes, MI is indicated." ! checked the sepia log fi/es and there are a number of production and injection profile logs in there. I did a quick scan and in the presented intervals above the perforations, the curves (especially temperature) did not appear anomalous although the presented intervals above the perfs were not of great length. ! attempted to contact Kevin and Joe, who were not there. ! spoke with one of their associates and he provided the following information. In their records on 12/24/99 the MIT failure is noted. In that same entry, it states that a tailpipe plug was run and the tubing successfully tested to 3000 psi. On 1/6/2000 the record notes verbal approval from Blair. Sundry 300-008 was approved 1/27/00 to provide a waiver to continue water injection with a casing leak. Daily monitoring and monthly reporting of rates and pressures was required. I have checked the latest monitoring information provided and the data points do not indicate a change in the pressure versus rate envelope. Based on the currently available information, ! do not see any evidence that the injection fluids are not confined within the intended injection strata. In their proposal, they plan to do a bond log of the tubing after the backside squeeze, perform an MIT on the remaining annulus and set a plug in the tubing nipple to perform a MITT. i think with acceptable results from these "tests" would allow us to approve MI injection. They propose to do subsequent MITs on the normal 4 year .~ehedu)e. I~ may be appropriate to shorten the interval to 2 years to allow more 1 of 3 1/24/01 2:15 PM information to be gathered on a well repaired this way. Lets discuss further. Tom Julie Heusser wrote: :>:> :>~ Hi Tom, Have they demonstrated satisfactorily that the injected fluids are remaining "in zone" ? Given that further remedial operations may not be an option for this well - should we require periodic demonstration that fluids are going where they think they're going or is it your opinion that a simple M/T is sufficient to satisfy the intent of 20AAC 25.402 ? Thanks Julie Tom Maunder wrote: Thanks for the note, ! was planning on getting a message to you. We have discussed your proposal and do have a couple of questions. Again, while your solution should repair the leak, but it is a little drastic. Has there been an analysis of how the reduced tubing length will react to the changes in temperature between injection water and MI?? Also, what options will remain to repair a future MIT failure?? We look forward to your comments. Tom Maunder AOGCC "Cahalane, Ted W" wrote: Any word from your side concerning our A-31A backside squeeze proposal? ----Original Message .... From: Tom Maunder [mailto:tom maunder~,,adm/n, state, ak. us/ Sent: Friday, January 12, 2001 10:22 AM To: Cahalane, Ted W Subject: Re: A-31A (199-056) Injector Backside Squeeze << File: Card for Tom Maunder >> Ted, i am looking at your proposal for A-31A. What you propose should eliminate the casing leak. Next week, I wi//review this with the Commissioners. i know we have approved cementing operations of this type on some EOA wells, but t am not sure if they were Mi injectors, i have read our file material on the we//and noted in the completion report that inside integrity was achieved by setting a liner top packer, it does not look tike any bond log was run when the well was dr#led, have there been profile 2 of 3 1/24/01 2:15 PM logs run to assure the water is going where you want it?? i'il get back with you next week. Tom Maunder "Cahalane, Ted W" wrote: > Tom, > As we discussed this morning, I'm sending you an outline of the work > proposed for A-31A. This is an injector currently waivered for water only > injection due to a Cretaceous leak around 5gO0' MD. We propose placing 1t.0 > ppg LiteCrete cement in the 9-5/8" x tubing annulus from the packer at 9222' > MD up to a depth of 3600' MD. 10 bbts of LiteCrete will aisc be squeezed into the Cretaceous leak. The squeeze will be performed with coil pumping through an EZSV squeeze retainer and circulating through the bottom GLM. This injector was sidetracked in November 199~). It passed an MITIA pre sidetrack, however it failed the post sidetrack MITIA performed before putting the well on MI injection. A 2.5 BPM leak at 3000 psi has been > located in the 9-5/8" casing around 5900' MD. A 5/99 Kinley caliper survey > showed the chrome tubing to be in excellent condition. The tubing passed an > MIT to 3000 psi in December 1999 and it has a functional SSSV. Following the squeeze, a bond log will be run to evaluate the quality and location of the cement. Both the IA and the tubing will be tested to 2000 psi. Once all the test have been successfully completed, the we//will be put on MI injection. We also propose requiring a plug to be set in the 2-7/8" liner and the tubing pressure tested to 2000 psi once every four years in the future. The attached spreadsheet contains a sketch of the well and the key steps that wi//be performed. Feel free to send back any comments or questions. < <A-31A Backside Squeeze Out/ine,xls> > > Name: A-31A Backside Squeeze Out/ine.xis > A-31A Backside Squeeze Out/ine. x/s Type: Microsoft Excel Worksheet (application/vnd. ms.excel) > Encoding: ba~e64 3 of 3 1/24/01 2:15 PM RE: A-31A (.199-O56) Injector Backside Squeeze Subject: RE: A-31A (199-056) Injector Backside Squeeze Date: Fri, 12 Jan 2001 22:23:42 -0000 From: "Cahalane, Ted W" <CahalaTW@BP.com> To: '"Tom Maunder'" <tom_maunder@admin.state.ak. us> CC: "Frankenburg, Amy" <FrankenA@BP.com> Tom, We have approved sundries to pump cement up the backside in two other injectors 13-17 and 13-20. Both these wells are waivered for water injection only and the backside squeezes were being done to get the vtells on MI service. We have not done either of the backside squeezes yet. I don't believe that a log has been run to verify the liner top is isolated. I'!1 ask the pad engineer what the surveillance plans are before going to MI. A borax PNL would show the perfs are isolated as well as the liner top. Give me a call next week to discuss. ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak, us] Sent: Friday, January 12, 2001 10:22 AM To: Cahalane, Ted W Subject: Re: A-31A (199-056) Injector Backside Squeeze << File: Card for Tom Maunder >> Ted, I am looking at your proposal for A-31A. What you propose should eliminate the casing leak. Next week, I will review this with the Commissioners. I know we have approved cementing operations of this type on some EOA wells, but I am not sure if they were MI injectors. I have read our file material on the well and noted in the completion report that inside integrity was achieved by setting a liner top packer. It does not look like any bond log was run when the well was drilled, have there been profile logs run to assure the water is going where you want it?? I'll get back with you next week. Tom Maunder "Cahalane, Ted W" wrote: > Tom, > As we discussed this morning, I'm sending you an outline of the work > proposed for A-31A. This is an injector currently waivered for water only > injection due to a Cretaceous leak around 5900"MD. We propose placing 11.0 > ppg LiteCrete cement in the 9-5/8" x tubing annulus from the packer at 9222' > MD up to a depth of 3600' IVD. 10 bbls of LiteCrete will also be squeezed > into the Cretaceous leak. The squeeze will be performed with coil pumping > through an EZSV squeeze retainer and circulating through the bottom GLM. ~ This injector was sidetracked in November 1999. It passed an MITIA pre > sidetrack, however it failed the post sidetrack MITIA performed before > putting the weft on MI injection. A 2.5 BPM leak at 3000 psi has been 1 of 2 1/18/01 3:42 PM RE: A-31A ~.199-056) Injector Backside Squeeze > located in the 9-5/8" casing around 5900' MD. A 5/99 Kinley caliper survey > showed the chrome tubing to be in exceflent condition. The tubing passed an > MIT to 3000 psi in December 1999 and it has a functional SSSV. Following the squeeze, a bond log veil be run to evaluate the quality and location of the cement. Both the IA and the tubing uill be tested to 2000 psi. Once all the test have been successfully completed, the weft will be put on MI injection. We also propose requiring a plug to be set in the 2-7/8" liner and the tubing pressure tested to 2000 psi once every four years in the future. The attached spreadsheet contains a sketch of the well and the key steps that well be performed. Feel free to send back any comments or questions. <<A-31A Backside Squeeze Outline.x/s>> > Outline.xls > A-31A Backside Squeeze Outline.xls (application/vnd.ms-excel) > Enoding: base64 Nare: A-31A Backside Squeeze Type: Microsoft Excel Worksheet 2 of 2 1/18/01 3:42 PM To: W~ELL LOG TRANSMITTAL State of Alaska Alaska Oil amd Cm.s Comqervadion Comm.. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs' A-3 lA,. March 14, 2000 AK-~MW-90195 A-3!A: 2"x 5" b/fi) C-ea?~ Ray Logs' a0-u2v-zl~o~-ui 2" x 5" TVD Gamma Ray Logs' 50-029-21383-01 1 Blueline i Rolled Sepia 1 Blueline 1 Rolled Sepia PLEA..SE ACICNO~EDGE' ~.~IPT BY S!GNLNG A_.ND RE. TL~INLNG A COPY OF _THE TRANSM1TrAL LETrER TO THE ATTEN'rION OF: Sperry-Sun Drilling Services Attn: .Van Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Date: ~'.~}'~ '1 4 200~ Alaska 0il & Gas Cons. Commissior. Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way. Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 A Halliburton Company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs A-31A, AK-MW-90195 March 08, 2000 1 LDWG formatted Disc with verification listing. API#: 50-029-21383-01 PLEASE ACKNOWLEDGE RECELPT BY SIGNENG A_ND RE. TURNLNG A COPY OF THE TRANSMITTAL ~.LE. TTER TO ~THE ATTE_~.N_TION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchor~e, Alaska 99519-6612 RECEIVED Date: ~^o ~ 9 ~000 Naska Oil & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 A Halliburton Company GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. 121054 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 12/30/99 Well Job # Log Description Date Blueline Sepia Color CD Prints A-31A LEAK DETECTION 991224 1 1 F-06 LEAK DETECTION 991222 1 1 ,, N-18 PRODUCTION PROFILE 991225 1 1 ,~-r~.. ~.-.,u ........ ~ ---4-- ~ W-18 LEAK DETECTION 991223 1 1 ...... ,,, . ., ,,. .. . . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E, Benson Bivd, Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED · '1 1 1 2000 A1aaka Oil & Gas Coas. comm'mion Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage.AK 99503-5711 A TrN: SherrieReceiv~ '~ )', r',~~.,~, , ,,' ' 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well I-~ Oil [] Gas I--I Suspended r-iAbandoned [~ Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 199-056 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21383-01 4. Location of well at surface ': - 9. Unit or Lease Name 2962' SNL, 1014' WEL, SEC. 35, T11 N, R13E, UM ,; , . , :" '?' .... ~~~~'~.~.~? ~ Prudhoe Bay Unit At top of productive interval,///~~ ~. '..~'~ ....I 10. Well Number 417' SNL, 1516' EWL, SEC. 01, T10N, R13E, UM ~~ ! A-31Ai At total depth '~:' ~ '"~~.., !~;~v.. ~~.-~r ,'11. Field and Pool 413' SNL, 1596' EWL, SEC. 01 T10N, R13E, UM ' Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 81.2' AMSLI ADL 047472 12' Date Spudded11/24/99 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'115' Wat~'r depth' if °ffsh°re 116' N°' °f c°mpleti°nsl 1/27/99 11/29/99 N/A MSL One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey V0. Depth where SSSV set 121. Thickness of Permafrost 10593 9080 FTI 10523 9036 FTI [] Yes [] No (Nipple) 2028' MD 1900' (Approx.) 22. Type Electric or Other Logs Run Memory GR, RES, MWD GR, ReP 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulated Conductor Surface 110' 36" 8 cu yds concrete 13-3/8" 72# L-80 Surface 2668' 17-1/2" 3254 cu ft PF 'E', 465 cu ft Permafrost I-, 9-5/8" 47# L-80 Surface 9513' 12-1/4" 1971 cu ft Class 'G' 7" 26# L-80 9248' 9587' 8-1/2" 278 cu ft Class 'G' 2-7/8" 6.16# L-80 9277' 10590' 3-3/4" 208 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, NT13-Cr 9310' 9222' MD TVD MD TVD 10491' - 10522' 9015' - 9036' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 30 Bbls MeOH 27. PRODUCTION TEST 0RIG"'*' [~'a'te"'FirstDecemberPr°ducti~nl 1, 1999 IMeth°dWater°f InjectionOperati°n (Flowing, gas lift, etc.) I1 ! R L Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF IWATER-BBL CHOKE SIZE [GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCULATE OIL-BBL GAS-MCF WATER-BBL OIL GRAViTY-APl (CORR) Press. D 24-HOUR 28. RATE CORE DATA ..... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED · JA 'I A~,_~a Oil & Gas Cons. Comrni~ Form 10-407 Rev. 07-01-80 Sul~l~~plicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. 45P 9616' 8870' 44P 9658' 8901' 42N 9740' 8949' 42P / Zone 4A 9748' 8952' Invert 44P 9821' 8966' 45P 9892' 8948' 45N 9958' 8925' 46P 10010' 8907' Shublik 10063' 8890' Revert 10246' 8885' Sadlerochit / 46P 10267' 8891' 45P 10378' 8943' 44P 10456' 8991' 42N 10488' 9013' 42P / Zone 4A 10542' 9048' HOT 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Te~rieHubb,e '~.~_//~,'~ ,~..]..]..]..]..]..~~ Title TechnicalAssistantll, Date A-31Ai 199-056 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL.' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 §.' 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 (DF, 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 Well: A-31Ai Accept: 11/22/99 Field: Prudhoe Bay Spud: 11/24/99 APl: 50-029-21383-01 Release: 11/29/99 Permit: 199-056 CTD Unit: Nordic #1 11/22/99 1 Move rig from N pad to A pad. Derrick down rig move. Raise derrick. Pick old reel with Peak crane. Install new reel bushings. Set in new reel. Position rig over well. Grease tree and open SSV. Accept rig on A-31Ai at 04:00 hrs, 11/22/99. MIRU equipment. N/U BOPE. 1/23/99 2 Finish RU BOPE. PU injector. Installed gooseneck. Stabbed new pipe into injector. Stood injector back. Tested BOPE. Changed out CT pack-off. M/U hardline inside reel. Pump dart thru CT. M/U Cementing BHA #1. RIH. Tag Whipstock at 9607 ft and correct CTD to 9588 ft. Bullhead 150 bbls seawater to liquid pack well. Held Safety Meeting. Press test lines. Bullhead 52 BBLs of 13.8 PPG, G Cement slurry with 8% Bentonite. Added 20 PPB crushed brick to middle 30 bbls of slurry. Displace with seawater. Squeezed 43 bbls cement to perfs and laid in last 9 bbls. Held 1500 psi squeeze pressure for 50 min. Jetted out cement to 9575 ft. POOH jetting across each GLM. 1 1/24/99 3 9586' POH w/cmt stinger. Washed stack. LD cmt assy. PU dimple mill assy. RIH. Tagged XN nipple @ 9289'. Milled through XN nipple. RIH. Tagged cmt @ 9575'. Washed cmt f/9575-9586.5'. Milled window f/9586.5- 9587.7 ft. Very slow progress with a total of 35 stalls. POOH to check mill and motor. Mill had normal wear and BHA showed no other noticeable problems. Change mill and motor. RIH with milling assy #2 (3.80" dimple mill). Mill window from 9587.7-9592.5' and drill open hole to 9595'. POOH. LD dimple mill. RIH with milling assy #3 (3.625" formation mill and 3.80" string reamer). Dress window with string reamer and drill formation to 9599'. 11/25/99 4 9825' Drill to 9603 ft with formation mill. Ream window area. Clean rig pits. Circulate in new FIoPro mud. POOH with window milling BHA. L/O milling BHA. M/U DS CTC, press / pull test. M/U MWD drilling BHA with 3.0 Deg. motor and M09 Bit #1. RIH with BHA#5. Orient TF above window. RIH clean thru window. Correct to TD at 9603 ft. Drill from 9603 - 9748 ft. Build rate dropped during last 2 surveys. Needed higher build rate to land well near well plan. POOH for short radius motor. LD 3.0 deg motor. RIH with BHA #6 (3.7° short radius motor, same M09X bit). RIH thru window, clean. Precautionary ream to TD. Drill from 9748-9825' building angle. Lost 0.5 bpm at 9810' and additional 1.0 bpm at 9821' (near planned fault). Landed at 8881' TVD (21' deeper than plan) at 9800' MD. POOH for lesser bend motor to drill invert section. Change bit, motor. RIH with BHA #7 (1.4° motor, DS49 bit). 11/26/99 5 10125' Finish RIH with drilling BHA #7 (1.4° motor, DS49 bit). Tie-in with GR at 9515.5ft. Add 5.5 ft. Drill inverted hole at 110° from 9825 - 9855 ft. losing 0.6 bpm. Re-survey thru high DLS interval. Drill inverted to 9909 ft. Pull to window to orient. RIH to TD and hole was clean. Drilled inverted from 9909 - 9963 ft. and losses increased to 2.0 bpm. Drill with seawater and FIoPro sweeps. Ream shale at 9950 ft. Pull to window to orient TF. Drill inverted from 9963 o 10043 ft. at 108°. Short trip to window, clean. Drill inverted to 10100' (8800' TVD) and had trouble A-31Ai, Coil Tubing Drilling Page 2 getting surveys. Wiper trip to window was clean. Attempt to Icg tie-in and had poor GR data. POOH to change MWD. Change out bad MWD probe. RIH with BHA #7rr. Tie-in to BHCS at 9516', no corr. Drill ahead from corrected TD of 10107-10125' while breaking build to crest at 10170' MD at 8792' TVD. Unable to make hole. Circ mud to bit and leave in open hole. POOH to check BHA. 1/27/99 6 10593' POOH to check BHA. Change out motor, bit, MWD probe and DS MHA. Cut off 50 ft of CT. M/U DS CTC and press / pull test. RIH with Drilling BHA #8 with 1.4 deg. motor and DS49 bit #3. Tied-in with BHCS/GR. RIH to TD. Hole was clean. Orient TF to Iowside. Drill ahead to drop out of Shublik using seawater with FIo Pro sweeps with average 1.3 bpm loss. Drill from 10125 - 10246' cresting at 10166' (8792' TVD). Wiper trip to window, clean. Drill from 10246- 10382' using 100% FIo Pro and dropping as planned. Wiper trip to window, clean. Drill from 10382-10500' (8940' TVD). Wiper trip to window, clean. Tie-in, add 6.0'. Drill rathole from 10506-10590' (8997' TVD) which is TD. Wiper trip to window prior to POOH for logs. 1/28/99 7 POOH with drilling BHA. Tied-in with BHCS/GR. Final corrected TD is 10,590 ft BKB. POOH. L/O Drilling BHA. Safety Meeting. P/U PDS Memory Induction / GR Open Hole logging tools. RIH with logging BHA #9. Correct CTD at flag. RIH. Log down at 30 FPM from 9400 - TD at 10589' CTD. Log out at 30 FPM to 9400 FT. POOH. L/O PDS logging tools. Safety Meeting. Run 2 7/8", STI_ Liner. Safety Meeting. M/U Baker 6' running sleeve and CTLRT. M/U Baker CTC, pull / press test. RIH with 2 7/8" Liner on CT to TD. Release from liner. Displace FIo Pro to 2% KCI water losing 2/3 of returns. DS pump 37 bbls (250% excess) 15.8 ppg Class G cement with latex. Displace with 2% KCI water to latch collar and got 1/3 of returns after cement was at shoe. Unsting from liner and continued to lose fluid. POOH while WOC. LD CTLRT. MU 2.25" mill and motor. PU 40 CSH workstring singles. RIH on CT thru TOL, clean. Circ, WOC. 11/29/99 8 Wait on Cement. Run inside 2 7/8" liner with 2.25" mill and motor with full returns. Clean trip to PBTD of 10,523 ft. POOH. Attempt pressure test of liner lap. Pumped away at 0.9 BPM at 980 PSI. Full returns with zero WHP. POOH. Stand back 20 Stds of CSH workstring. L/O milling BHA. M/U Baker 4.5" KB Production Packer and 3.0" seal assembly with running tools. RIH with Packer assembly at 50 FPM. Sting into seal assembly at 9278 ft. Set KB Packer with top at 9270' ELMD. POOH, LD packer setting tool. Pressure test wellbore to 2200 psi for 30 minutes, solid. MU SWS 2" CTC perf guns on 20 stands CSH workstring. RIH on CT to PBD. Perforate 10491-10522'. POOH with CT. LD 40 CSH singles. LD perf guns-all shots fired. RIH with nozzle and freeze protect wellbore to 2000' with MECH. POOH. SI swab. Vac pits and WO N2. 11/30/99 9 R/U DS N2 pumper and press test line. Purge CT with N2. Bleed off CT pressure. Clean rig pits and green tank. N/D BOPE. R/D injector head. Pressure test tree cap. Released Nordic 1 rig at 12:00 hrs, 11-29-99. Total time on well was 7 days and 8 hours. 8400 - 8500 8600 8700 -~ ~o 8800 ~- 8900 I-- 9000 I 9100 9200 B.P. Exploration (True) Structure : Pod A Ffeld : Prudhoe Bay Well : A-31AI, 50-029-21383-01 Location : North Slope, Alaska East (feet) -> Dote plotted : 18-Dec-1999 Plot Referenc~ ;s A-51AI. Coordlnatee ore Ir~ feet reference A-51. True Vertfcal Depths are reference RKB - MSL = 81.2 ft. BHj Potnis 267-6613 --- $oker Hughes INTEO --- 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 I I I I I I .,I I I ,I t I I I I,,I I I I I I I I I,,I Projected to TD I A-51N Casel05o Plan i i i i i i i i i i i i i i i i ! i i i ii i i i i i i i i i 1 200 100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 Vertical Section (feet) -> Azimuth 140.00 wifh reference 2096.52 S, 2009.34 E from A-31 Projected to TD 1900 2OOO 2100 2200 2300 2400 2500 I 2600 V 27OO 2800 29OO 5000 B.P. Exploration (True) Pad A A-31AI A-31 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : A-31AI Our ref : svy263 License : 50-029-21383-01 Date printed : 16-Dec-1999 Date created : 16-Dec-1999 Last revised : 16-Dec-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 655456.073,5945187.217,999.00000,N Slot location is nT0 15 48.321,w148 45 6.205 Slot Grid coordinates are N 5947483.000, E 654395.000 Slot local coordinates are 2317.36 N 1013.54 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad A,A-31AI Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : A-31AI Last revised : 16-Dec-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing' 9509.10 31.13 143.10 8699.14 2096.52S 2009.34E 2.12 0.00 656447.04 5945428.55 9584.10 31.84 143.23 8763.10 2127.87S 2032.82E 0.95 39.11 656471.16 5945397.69 9628.50 41.22 140.92 8798.73 2148.65S 2049.09E 21.35 65.49 656487.85 5945377.25 9664.13 49.40 139.59 8823.77 2168.10S 2065.29E 23.11 90.80 656504.45 5945358.15 9707.40 55.56 138.32 8850.11 2193.96S 2087.83E 14.42 125.09 656527.51 5945332.76 9744.94 60.58 138.47 8869.96 2217.77S 2108.97E 13.38 156.93 656549.14 5945309.39 9774.96 72.27 133.72 8881.95 2237.52S 2128.05E 41.54 184.32 656568.62 5945290.04 9805.12 90.62 136.20 8886.42 2258.51S 2149.05E 61.38 213.90 656590.05 5945269.48 9823.74 101.34 139.19 8884.48 2272.18S 2161.50E 59.74 232.38 656602.78 5945256.07 9873.59 106.81 149.36 8872.33 2311.34S 2189.72E 22.62 280.51 656631.80 5945217.52 9904.14 107.42 154.13 8863.34 2337.04S 2203.54E 15.05 309.09 656646.14 5945192.10 9943.49 113.20 149.34 8849.68 2369.54S 2220.98E 18.60 345.18 656664.25 5945159.98 9976.57 110.52 146.31 8837.36 2395.51S 2237.33E 11.74 375.59 656681.13 5945134.35 10019.74 108.64 150.84 8822.89 2430.21S 2258.52E 10.80 415.80 656703.03 5945100.09 10052.71 109.08 153.73 8812.23 2457.83S 2273.03E 8.40 446.28 656718.11 5945072.78 10081.26 105.66 152.89 8803.71 2482.17S 2285.27E 12.30 472.79 656730.84 5945048.70 10115.29 99.67 151.32 8796.25 2511.50S 2300.80E 18.17 505.24 656746.97 5945019.70 10144.34 94.48 148.50 8792.67 2536.43S 2315.25E 20.30 533.63 656761.94 5944995.08 10176.24 88.15 147.45 8791.94 2563.45S 2332.15E 20.11 565.19 656779.39 5944968.41 10207.01 81.74 147.98 8794.65 2589.35S 2348.52E 20.90 595.55 656796.28 5944942.86 10237.56 74.97 146.04 8800.81 2614.43S 2364.79E 23.02 625.23 656813.07 5944918.12 10274.49 68.29 142.18 8812.45 2642.82S 2385.30E 20.63 660.16 656834.17 5944890.16 10304.99 63.54 136.02 8824.90 2663.86S 2403.50E 24.13 687.97 656852.79 5944869.50 10334.49 59.85 129.70 8838.90 2681.53S 2422.50E 22.63 713.72 656872.15 5944852.23 10363.42 57.74 125.48 8853.89 2696.63S 2442.10E 14.45 737.88 656892.05 5944837.54 10400.89 53.09 119.85 8875.16 2713.30S 2468.02E 17.52 767.31 656918.31 5944821.41 10434.29 49.92 112.12 8895.97 2724.77S 2491.46E 20.44 791.17 656941.99 5944810.43 10465,19 47.81 103.33 8916.32 2731.87S 2513.58E 22.47 810.83 656964.24 5944803.79 10495.06 47.46 96.47 8936.46 2735.66S 2535.30E 17.00 827.69 656986.03 5944800.44 10526.79 49.13 88.91 8957.59 2736.75S 2558.93E 18.54 843.72 657009.68 5944799.84 10566.86 52.12 80.65 8983.03 2733.89S 2589.72E 17.59 861.32 657040.40 5944803.34 10593.00 52.12 80.65 8999.08 2730.54S 2610.08E 0.00 871.84 657060.68 5944807.11 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from A-31 and SSTVD from RKB - MSL = 81.2 ft. Bottom hole distance is 3777.35 on azimuth 136.29 degrees from wellhead. vertical section is from tie at S 2096.52 E 2009.34 on azimuth 140.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad A,A-31AI Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 2 Your ref : A-31AI Last revised : 16-Dec-1999 MD SSTVD 9509.10 8699.14 10593.00 8999.08 Comments in wellpath Rectangular Coords. Comment 2096.52S 2009.34E Tie-in Point 2730.54S 2610.08E Projected to TD NO Targets associated with this wellpath North Slope Alaska Alaska State Plane 4 PBU WOA A Pad A-31A Surveyed: 27 November, 1999 SURVEY REPORT 4 January, 2000 Your Ref: API-500292138301 Surface Coordinates: 5947482.10 N, 654394.28 E (70° 15' 48.3119" N, 148° 45' 06.2263" W) Kelly Bushing: 81.17ft above Mean Sea Level DRILLING ~ERVIC:E5 Survey Ref: s vy9569 Sperry-Sun Drilling Services Survey Report for A-31A Your Ref: A PI-500292138301 Surveyed: 27 November, 1999 North SloPe Alaska Measured Depth (ft) Incl. 9509.10 9584.10 9628.50 9664.13 9707.40 9744.94 9774.96 9805.12 9823.74 9873.59 9904.14 9943.49 9976.57 10019.74 10052.71 1 OO81.26 10115.29 10144.34 10176.24 10207.01 10237.56 10274.49 1 O3O4.99 10334.49 10363.42 31.130 31.840 41.220 49.4OO 55.560 60.580 72.270 90.620 101.340 106.810 107.420 113.200 110.520 108.640 109.080 105.660 99.670 94.480 88.150 81.740 74.970 68.290 63.540 59.850 57.740 Azim. 143.107 143.230 140.920 139.590 138.320 138.470 133.720 136,200 139.190 149.340 154.130 149.340 146.310 150.840 153.730 152.890 151.320 148.500 147.450 147.980 146.040 142.180 136,020 129.700 125,480 Sub-Sea Depth (ft) 8699,17 8763.13 8798,76 8823.80 8850.14 8869.99 8881.98 8886.45 8884.51 8872.36 8863.37 8849.71 8837.39 8822.92 8812.26 8803.74 8796.28 8792.7O 8791.97 8794.68 8800.84 8812.48 8824.93 8838.93 8853.92 Vertical Depth (ft) 8780.34 8844.30 8879.93 8904.97 8931.31 8951.16 8963.15 8967.62 8965.68 8953.53 8944.54 8930.88 8918.56 8904.09 8893.43 8884.91 8877.45 8873.87 8873.14 8875.85 8882.01 8893.65 8906.10 8920.10 8935.09 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 2096.76 S 2009.09 E 5945426.98 N 656445.94 E 2128.11S 2032.57 E 5945396.12 N 656470.06 E, 2148.90 S 2048.84 E 5945375.67 N 656486.75 E 2168.34 S 2065.03 E 5945356.56 N 656503.34 E 2194.20 S 2087.57 E 5945331.17 N 656526.41 E 2218.02 S 2108.72 E 5945307.79 N 656548.04 E 2237.76 S 2127.79 E 5945288.44 N 656567.51 E 2258.76 S 2148.80 E 5945267.88 N 656588.94 E 2272.43 S 2161.24 E 5945254.47 N' 656601.67 E 2311.58 S 2189.47 E 5945215.91N 656630.69 E 2337.28 S 2203.30 E 5945190.49 N 656645.04 E 2369.77 S 2220.73 E 5945158.37 N 656663.14 E 2395.75 S 2237.08 E 5945132.73 N 656680.02 E 2430.45 S 2258.28 E 5945098.47 N 656701.92 E 2458.07 S 2272.78 E 5945071.16 N 656716.99 E 2482.41S 2285.02 E 5945047.07 N 656729.73 E 2511.73 S 2300.55 E 5945018.07 N 656745.86 E 2536.67 S 2315.00 E ' 5944993.44 N 656760.81 E 2563.69 S 2331.91 E 5944966.77 N 656778.27 E 2589.59 S 2348.27 E 5944941.21N 656795.16 E 2614.67 S 2364.55 E 5944916.47 N 656811.95 E 2643.06 S 2385.06 E 5944888.51N 656833.04 E 2664.10 S 2403.25 E 5944867.84 N 656851.66 E 2681.77 S 2422.26 E 5944850.57 N 656871.02 E 2696.87 S 2441.85 E 5944835.88 N 656890.92 E Dogleg Rate (°/100ft) 0.951 21.349 23.110 14.425 13.377 41.539 61.378 59.740 22.584 15.117 18.599 11.742 10.802 8.401 12.304 18.168 20.296 20.114 20.902 23.016 20.626 24.128 22.626 14.450 Alaska State Plane 4 PBU_WOA A Pad Vertical Section (ft) Comment 2893.07 2932.22 2958.61 2983.92 3018.19 3050.00 3O77.35 3106.87 3125.32 3173.52 3202.22 3238.46 3268.95 33O9.27 3339.88 3366.52 3399.10 3427.58 3459.24 3489.67 3519.42 3554.39 3582.19 3607.87 3631.92 Tie-on Survey Window Point Continued... z~ . I~nl ~Rrv. 2000.8:59 - 2 - DrillQuest 1.05. 04e Sperry-Sun Drilling Services Survey Report for A-31A Yo ur Re f: A PI-500292138301 Surveyed: 27 November, 1999 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) Alaska State Plane 4 PBU_WOA A Pad 0400.89 53.090 119.850 8875.19 8956.36 2713.54 S 2467.77 E 0434.29 49.920 112,120 8896.00 8977.17 2725.01 S 2491.22 E 0465.19 47.810 103.330 8916.35 8997.52 2732.11 S 2513.34 E 0495,06 47.460 96.470 8936.49 9017.66 2735.90 S 2535.05 E 0526.79 49.130 88.910 8957.62 9038.79 2736.99 S 2558.68 E 0566.86 52.120 80.650 8983.06 9064.23 2734.13 S 2589.47 E 0593.00 52.120 80.650 8999,11 9080.28 2730.78 S 2609.83 E Global Coordinates Dogleg . Vertical Northings Eastings Rate Section (fi) (fi) (°/lOOff) (ft) 5944819.74 N 656917.18 E 5944808.75 N 656940.85 E 5944802.11 N 656963.11 E 5944798.76 N 656984.90 E 5944798.16 N 657008.55 E 5944801.65 N 657039.27 E 5944805.42 N 657059.56 E All data is in feet 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. Magnetic Declination at Surface is 27.211° (27-Nov-99) ..~ The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 141.180° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10593.00ft., The Bottom Hole Displacement is 3777.35ft., in the Direction of 136.297° (True). Comment 17.515 3661.15 20.439 3684.79 22.474 3704.19 17.005 3720.76 18.543 3736.42 17.585 3753.49 0.000 3763.64 Projected Survey Continued... 4 January, 2000 - 8:59 -3- DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for A-31A Your Ref: API-500292138301 Surveyed: 27 November, 1999 North Slope Alaska Alaska State Plane 4 PBU_WOA A Pad Comments Measured Depth (ft) 9509.10 9584.10 10593.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8780.34 2096.76 S 2009.09 E 8844.30 2128.11 S 2032.57 E 9080.28 2730.78 S 2609.83 E Comment Tie-on Survey Window Point Projected Survey 4 January, 2000 - 8:59 - 4 - DriliQuest 1.05.04e Re: A-31,Ai Subject: Re: A-31Ai Date: Thu, 20 Jan 2000 11:08:24 -0900 From: Blair Wondzell <blair_wondzell@admin.state.ak. us> Organization: State of Alaska, Dept of Admin, Oil Ex Gas To: Tom Maunder <tom_maunder@admin.state.ak. us> Tom, Thanks for the info. Blair Tom Maunder wrote: > Deidre, > Thanks for returning my call. This confirms our request for the > activity report of the diagnostic work done on A-31Ai and a smafl (1 > sheet if possible) presentation of the relevant log interval. This is > not a request for a log copy. Please also include the activity report > when the MITT was conducted. > I will pass on the sundry recommending approval to continue injection as > you continue to troubleshoot the leak and determine the suitability of > the bottomhole location for injection. > Our normal requirements when approving continued injection in a well > without IA integrity are demonstrated tubing integrity (previously > accomplished), daily monitoring of tubing and IA pressures, daily > monitoring of injection volume and monthly reporting of this information > to the A OGCC. If the rn2nitoring indicates further problems with the > well, it should be SI and the information forwarded to us. Under > separate cover I will forward a report format used by the ARCO problem > wells group for email reporting of the information on their variance > wells. > If you have any questions or need further information, please call. > Tom Maunder Internal 1 of 1 1/26/00 11:12AM PRUDHOE BAY, ALASKA TO: FROM' P.E. REPORT GROUP SNOW, YEAGER DATE: 112/14/99 WELL NAME: /A-31 MAIN CATEGORY: MAINT SUB CATEGORY C.I.T. OPERATION DATE [ 12/14/99 OPERATION: CASING INTEGRITY TEST FOR UPCOMING AOGCC ST.TEST INITIAL PRESSURES: INJWHP=80 TEMP=133 IA=860 OA=150 Time lAP OAP Fluid BPM Total COMMENTS Type Bbl's 1405 860 150 MIRU HB&R TO IA & PT LINES. HOLD SAFETY MEETING 1411 860 150 DIESEL 1.5 0 START DOWN IA 1425 2200 150 DIESEL 1.0 16 SHUT DOWN START TEST 1431 1950 150 DIESEL 1.0 16 BUMP WELL 1437 2200 150 DIESEL .200 18 INJECT INTO WELL AT .150 BPM /START ITEST AGAIN 1507 1400 150 DIESEL 18 STOP TEST/RIGDOWN/M.O.L. Final Pressures WHP=80 TEMP=138 IA=1340 OA=120 Fluid Summary: PUMPED A TOTAL OF 18 BBLS DIESEL / DID NOT BLEED BACK ANY FLUIDS CONCLUSION: A-31 LOST 800 PSI IN 30 MINUTE TEST AND WAS STILL DROPPING ESTABLISHED .150 BPM INJECTION RATE AT 2150 PSI PRUDHOE BAY, ALASKA TO: PE REPORT GROUP FROM: PAULSBERG YEAGER WELL NAME: MAIN CATEGORY: SUB CATEGORY OPERATION. DATE IA-31 MAINT CIT 12/23/99 DATE: J12/23/99 OPERATION: ATTEMPT TO PRRESSURE TEST IA TO 2200 psig INITIAL PRESSURES: WHP=50 PSIG, TEMP=130°, lAP=650 PSIG, OAP=100 PSIG. Time TBG lAP OAP Fluid BPM Total TEMP COMMENTS 1300 ...... MIRU HB&R TO IA, PT LINES AND HELD SAFETY MEETING 1316 50 650 100 DSL .3 0 130° START PUMPING DOWN IA WITH HEATED DSL 1319 50 1000 100 DSL 1.1 3 130° CONTINUE PUMPING 1322 50 1800 100 DSL 1.5 6 130° CONTINUE PUMPING 1326 50 2200 100 DSL .4 9.75 130° S/D, IA AT TEST PRESSURE, BEGIN 30 TEST 1337 50 1800 100 DSL .5 10 130° BUMPING IA BACK UP TO TEST PRESSURE 1343 50 2200 100 DSL .3 12.5 130° .SD, RE-START 30 TEST 1403 50 1750 100 DSL .7 12.5 130° '#2500" NEW TEST PRESSURE" START PUMPING DOWN IA TO ESTABLISH INJECTIVITY RATE 1406 50 2050 100 DSL .50 14 130° CONTINUE PUMPING 1418 50 2350 100 DSL .48 20 130° CONTINUE PUMPING 1436 50 2350 100 DSL .52 29 130° CONTINUE PUMPING 1445 50 2300 100 DSL .52 33 130° S/D, END OF INJECTIVITY TEST 1450 50 2300 100 DSL BLEED IA BACK 1458 50 650 100 - 7 - IA BLED BACK, R/D AND MOL Final Pressures: WHP=50 PSIG, TEMP=130°, lAP=650 PSIG, OAP=100 PSIG. Fluid Summary: 33 BBLS DIESEL PUMPED AND 7 BBLS BLED BACK CONCLUSION: WELL FAILED CIT, AN INJECTIVITY RATE OF .52 BPM FOR 40 MINUTES WAS ESTABLISHED AT 2200 PSI. IA TAGGED AND PAD OPERATOR NOTIFIED. A LEAK HUNT LOG IS REQUIRED TO IDENTIFY LOCATION OF PROBLEM AND FOR STATE AOGCC DIAGNOSTIC WORK. To: Anchorage Produudon Engineering Lvcation: A-31ai From: Walker Date: December 24, 1999 Operation: Leak Detect Cost Code: Job Id: Detail Code: F55A31 - xxx Maint/Leak Detect. etc. Summary MIRU SWS and HB&R. SI wing and begin pumping diesel down IA at 0.5 BPM and 2,250 psi. RIH logging to 9,350'. Note fluid level at 500'. No sign of tubing leak. Perform stop count at 9,250' and see slight spinner response. Suspect well taking fluid. PUH logging. Note temperature inflection at 5,875' but no spinner change or caliper activity. Log repeat over this section and confirm temperature deflection. Perform stop count at 5,682' and 6,057' with temperature readings of 102 degrees and 107 degrees respectively. S/B pump and POOH. No flow into the tubing was noted. There does appear to be a leak in the casing at 5,875'. Estimated Daily Cost: $14,500 12/24/99 Initial Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F Inj 0 525 100 N/A 1060 120 Time Operation 13:00 MIRU SWS and HB&R. 14:00 Hold PJSM with entire crew- appoint spill champion. 14:30 SI wing valve- begin pumping down IA 0.5 BPM 14:40 RIH logging. 16:01 No sign of hole. Park at 9,250' - minor spinner movement. Fluid level dropping. 16:10 Log up- continue pumping down IA at 0.5 BPM. Notice temp. Inflection at 5,875. 17:30 Perform stop count at 1,510' (fluid level)- minor spinner movement. 17:47 Log up from 6,100'. See temperature inflection at same depth. 17:50 Stop count at 5,682'. Temp- 102 degrees. 17:55 Stop count at 6,057'. Temp- 107 degrees. 18:00 S/D pump RDMO HB&R. POOH. 18:45 On surface. RDMOSWS. Final Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F Inj. 0 0 0 N/A 1100 52 Fluid Summary Total Operation: A-31ai Page: 2 Perforating Assembly Bottom Hole Assembly # 1 Tool String Descriptions O.D. Length Comments Logging Head 1.375 1.6 Swivel 1.6875 1.0 Weight bars (2) 1.6875 12.0 GR / CCL / Temp / Manometer 1.6875 7.9 Gradiometer 1.6875 5.0 In-Line Spinner 1.6875 2.6 Fullbore Spinner 1.6875 5.1 2" Turbine spinner I Total Length 35.2 J all ~j Date Schlumberger LEAK DETECTION SPIN/TEMP/PRESS/GRAD 24 DEC-1999 2316' FSL& 1012' FEL AT SURFACE · Elev. · K~B. 81.2 fi: G.L 50.7ff D.F. 8Oft Permanent Datum' Log Measured From' MEAN SEA LEVEL KELLY BUSHING Elev.' 81.2 ft Oft above Perm. Datum Drilling Measured From: KELLY BUSHING APl Serial No. I SECTION 50-029-21383-00 I 38 I 24-D EC- 1999 TOWNSHIP 11N RANGE 13E RUn Number __~th Driller Sc'hlumberger DePth Bottom Log Interval ] Dens~' [-- -~-T/~A~iNG/TUBi NO STRING _ F_r_om I0 L, asmc!/~ ubma Size .500 .n _ _W~i~ht ..................... 1_2_=6Z_! bn~/ff Grade NT13-CR From j.O ft ' To 9300 ff i ,Maximum Recorded Temperatures I Lo.qqer ,5~; Bosom- '} ~-;m~3 - 24-DEC-1999 i I '- -; ........ ~- ' - I ,;n,tNu:'n.,ber ¢ Location ~ 2150 ! PRuDHoE BAy' Recorded By . . I JAVlER ROJAS · Wbnessed By I KIRBY WAI_KER SUBSEQUENT 9672 ft 929O ft 5Oft INJECTION WATER & DIESEL ....................................... 510ff 8.500 in 9.512 ft 1 OO3O fi ALL INTERPRETATIONS ARE OPINIONS BASED ON INFERENCES FROM ELECTRICAL OR OTHER MEASUREMENTS AND WE CANNOT, AND DO NOT GUARANTEE THE ACCURACY OR CORRECTNESS OF ANY iNTERPRETATIONS, AND WE SHALL NOT, EXCEPT IN THE CASE OF GROSS OR WILLFUL NEGLIGENCE ON OUR PART, BE LIABLE OR RESPONSIBLE FOR ANY LOSS, COSTS, DAMAGES OR EXPENSES INCURRED OR SUSTAINED BY ANYONE RESULTING FROM ANY INTERPRETATION MADE BY ANY OF OUR OFFICERS, AGENTS OR EMPLOYEES. THESE INTERPRETATIONS ARE ALSO SUBJECT TO CLAUSE 4 OF OUR GENERAL TERMS AND CONDITIONS AS SET OUT IN OUR CURRENT PRICE SCHEDULE. OTHER SERVICES1 OS1: OS2: OS3: OS4: 095: NONE REMARKS: RUN NUMBER 1 LOG TIED IN TO JEWELRY AT 9100' AS PER WELL SCHEMATIC, DIESEL INJECTED DOWN THE INNER ANNULUS AT A RATE OF 0.5 BP A DOWNLOG WAS RUN. IT DID NOT SHOWANY OBVIOUS ENTRY POI =LUID CONTACT WAS SEEN AT 500', A STOP COUNT WAS PERFORMED AT THE BOTTOM OF THE TUBING. ,CONTINUOUS SPINNER SHOWED SOME SLIGHT FLUID MOTION. WE WELL IS TAKING FLUID. AN UPLOG WAS THEN RECORDED, AGAIN N WERE SPOI lED. THIS TIME THE FLUID LEVEL WAS FOUND AT 1150'. A STOP COUNT WAS TAKEN AT 1500'. AGAIN THE CONTINUOUS SPh'k =LOW. THIS SMALL FLOW AND THE DESCENT OF THE FLUID LEVEL :ONGOING PUMPING SEEM TO INDICATE THE WELL IS TAKING FLUID APPARENT LEAKS. THE TEMPERATURE SHOWED AN ANOMALY AT 51 _OGGED AND ANOMALY CONFIRMED. ALSO WITH STOP COUNTS. A ~3E THE REASON. -'-HANKS FOR CALLING SCHLUMBERGER- HAPPY HOLIDAYS -ODA¥'D C:RF-W JOHN CAPEN & JOHN BAMBURG RUN 1 SERVICE ORDER #: 6090439 ::'ROGRAM VERSION' 9C1-303 :LUID LEVEL: 510 ft LOGGED INTERVAL START I STOP OTHER SERVICES2 OS!: 092: 093: OS4: OS5: REMARKS' RUN NUMBER 2 Vl & 225O PSI '4TS. ONLY THE SUSPECT THE ENTRY POINTS NER SHOWS SLIGHT )ESPITE THE BUT STILL NO ,75'. A REPEAT WAS 3ASING LEAK MAY SERVICE ORDER #: PROGRAM VERSION: FLUID LEVEL' LOGGED INTERVAL I ..-"' RUN 2 START I PIP SUMMARY IZ-ZH-~e7 ~Time Mark Every 60 [ ; Well Temperature ._~___EP_)_ '~2"~ i20 (DEGF) L ......... .w~ IL .P.r.?.u- .r?.~. ?..".E- ~ .......... ~0 (PSIA) 4000 Gamma Ray (GAPI) 1001 Computed CCL (CCLC) . (v) ~ Cable Speed(CS) ____ (F/MN) 200 I[/" ' Cabl_._~e Speed (CS) (F/MN) 200 !i-19 Computed CCL (CCLC;) (v) Gamma Ray (GR} (GAPI) 100 I Differential Tam pe rat u re__(VV]'_ G R~ 1-0.5' (DF/F) ---- 0.~ PFCS X Caliper PFCS Y Caliper ~ ...... .(.P.F..0.1.) ........ _._.(~P F C_.~.~ _ ;5 (IN) o o (IN) Well Fluid Dens.~y (WFDE) (G/C3) Tension i (TENS) ! Well Tem_perat_ure (~N'I'_EP.~_ (LBF;) l0 (DEGF) 2000 Oi 100 OPEN PERFS OPEN i Filtered Main Spinner (SPIN~) PERFS !-20 (RPS) Filtered Main Spinner {S. PINI -20 (RPS) 20 Well Tem_pe_rat.._ure ~V~'__.EP_] (DEGF) 10 I Well Pressure (WPRE) Tension (TENS) i (LBF) 2000 L__. ..... We_Il Flu.~_id D_._ens_~V (WFDE) '0 (G/C3) [ PFCSXCaliper ! PFCS YCaliper i !~PFCl.) ~ ._.~.P ~ i ' ' ..... ('IN~ ...... ~io, (IN) ~ '-5j lO 20 STATE-OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Vadance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, A. nchorage, Alaska 99519-6612 5. Type of well: [] Development j--J Exploratory [--J Stratigraphic J~ Service 4. Location of well at surface 2962' SNL, 1014' WEL, SEC. 35, T11N, R13E, UM At top of productive interval 5050' SNL, 990' EWL, SEC. 36, T11N, R13E, UM At effective depth At total depth 441' SNL, 1519' EWL, SEC. 01, T10N, R13E, UM 6. Datum Elevation (DF or KB) KBE = 81.17' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-31Ai ' 9. Permit Number 199-056 10. APl Number 50- 029-21383-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10590 true vertical 8997 Effective depth: measured 10523 true vertical 8955 Casing Length Structural Conductor 110' Surface 2639' Intermediate 9484' Production Liner 1313' feet ~ Plugs (measured) feet feet Junk (measured) feet Size.' .. ., Cemented 20"x 30" "8cu yds concrete 13-3/8" 3254 cuft PF 'E', 465 cuft Permafrost 9-5/8" 197i cuft Class 'G' Whipstock set @ 9584', Tag WS @ 9588' CTD MD, Pumped 52 bbls of Class 'G' cmt, Sqzd 43 bbls to parrs; held 1500 psi MD TVD 110' 110' 2668' 2668' 9513' 8784' 2-7/8" 208 cu ft Class 'G' 9277'-10590' 8575'-9078' Perforation depth: measured 10491'-10522' true vertical 9015'-9035' Tubing (size, grade, and measured depth) 4-1/2", 12.6# @ 9300' RECEIVED JAN 1 2 2000 Oil& GmOons. C°mm lo. Anchoral~ Packers and SSSV (type and measured depth) Top of 2-7/8" liner @ 9270' ; Baker 4-1/2" KB Retrievable packer at top with seal assembly 13..Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation January 2000 16. If proposal was verbally approved Blair Wondzell 1/6/2000 Name of approver Date approved Contact Engineer Name/Number: De/dre Taylor 564-5086 17. I hereby certify thaJcJ?e foreg~g is trueand correct to the best of my knowledge Signed LEN SE~MOLfR- "k~'"'.7/~/"l,~l~ Title EOR/WF TEAMLEADER Commission Use Only 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By Name/Number: Michael Williams, 564-4657 so Approval No Conditions of Approval: Notify Commission representative may witness J.. . '....~5~Lb - Date I"Z~--'~.,'~.3 J Plug integrity __ BOP Test__ Location clearance __ Mechanical Integrity~ )Subsequ.~nt form required 10-., . /"7'-//~ J"( J.. _ f.. Z '-o~e~ ~ Approved by order of the Commission [//~ ' ~~~ _~,~O~;, C~ss~oner Form 10-403 Rev. 06/15/88 ~¢-~_~ Submit In Triplicate _ Well A-31Ai - Request for Variance At this time, we are requesting.a variance for Well A-31Ai. The well was recently sidetracked with the Coiled Tubing Drilling Unit. After A-31Ai was completed on November 30, 1999, it failed a mechanical integrity test (MIT). The well did pass a pre- CTST MIT on 6-10-99. Following the CTST, two attempts were made to get a successful pressure test on the inner annulus (IA), and both failed. While pumping down the backside, the IA appears to lose about 0.5 bpm at 2200 psi. The tubing appears to be in good condition, and passed a 3000 psi pressure test with a plug in the tailpipe. In addition, a Kinley Caliper survey secured on May 10, 1999 confirms the tubulars are in good shape. Recent reconnaissance work indicates a possible leak in the 9-5/8" casing at approximately 5900'. A leak detection log was run and a temperature anomaly was nbted at this location. We would like to inject water in A-31Ai based on the confirmation of the tubing integrity. Options to repair the well will be reviewed and considered. The AOGCC will be notified of any changes in well status in a timely manner. . \ .. . RECEIVED 2 000 Anchorage R CEtVED JA t 12 2000 · A. 31at WELLHEAD: McEvoy BF. ELEV = 52.19' ACTUATOR: BAKER sssv (CAMCO) (3.813" ID) Cemented 13 ~8" 72~ I L-8O ~TRS I 2,66~ ~ GAS LI~ MANDRELS ! / (MER~ W/RA ~TCH) ~ N~ ' MD(BKB) ~Dss ~Dev I KOP: 2,700' f 4 6,775 6,258 33° M~ ~Gk[: ~ ~ ~7 , 7~42 24° I 2 9,039 J 8,281 23° 1 9,181 I 8,410 26° 4-1/2' 12.~, NT13-CR, TDS TUBING ID: 3.958" ~ (PARKER) (3.813" ID) 9,21 ~ TUBING ANCHOR J 9'221J ~ 9-5/8" PACKER Top of 7" Liner I .9,24~ ~ ~ ~ ~,W HB-~P)(3.875' ,D) J 9,222J Topof2WS" Lineratg,2~b~ '~ ' j ~ 4-1/2", 12.6~/~, 13:CR TAILPIPE Baker 4 1~" KB Retrievable ' ~'. j j. ~ ~ 4-1/2" 'SWS' NIPPLE , (PARKER) (3.813" ID) ~ 0,278~ I J" ~ ~ 4-1/2" 'SWN' NIPPLE (PARKER) (3.8" ID) I 0'2901 9-5/8", 47,~, L-80, BTRS J 9,51~ ~ i , I Original 7", 26~/fl, L-80, IJ4S liner, PBTD at 9988', TD at 10,030 ft BKB ' ~r ~ CEMENT. Top of Baker Whipstock set at 9584 ft. PERFORA~ON ~UMMARY No RA Tag. I REF. LOG: Sper~ Sun MWD GR /ROP, 11-27-99 J 3.80" window milled from 9587-9596 ft. TIE IN LOG: BHCS / GR. J Pedorations were squeezed, with the i Size SPF Inte~al Ope~Sqzed CMT top at the whipstock at 9584 ft, 2" 4 1~91-10522 Open WARNING- ~ Radio transmitter in Weather I Monitoring Shack must be turned off I before any well work involving explosives can begin~ HORIZONTAL SIDETRACK DATE REV. BY COMMENTS PRUDHOE BAY UNI~ 7/18/85 . Initial Rig Completion 8/31/91 HE RWO Comp~etio~ WELL: A-31ai (36-11-13) 7/5/99 Nords Set Whipst~k APl NO: 50-029-21383-0! 11/29/99 R. Whitlow CTD HORIZONTAL SIDETRACK ~EC, 35; TN 11; RGE 13 BP Exploration (Alaska) GAS LIFT MANDRELS (MERLA W/RA LATCH) N" MD(BKB) TVDss ' Dev 6 3,100 3,018 5° 5 5,164 4,906 31° 4 6,775 6,258 33° 3 8,347 7,642 24° 2 9,039 8,281 23° 1 9,181 8,410 26° Re: A-31Ai Subject: Re: A-31Ai Date: Thu, 20 Jan 2000 11:08:24 -0900 From: Blair Wondzell <blair_wondzell@admin.state.ak. us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Tom Maunder <tom_maunder@admin.state.ak. us> Tom, Thanks for the info. Blair Tom Maunder wrote: > Deidre, > Thanks for returning my call. This confirms our request for the > activity report of the diagnostic work done on A-31Ai and a smafl (1 > sheet if possible) presentation of the relevant log interval. This is > not a request for a log copy. Please also include the activity report > when the MITT was conducted. > I will pass on the sundry recommending approval to continue injection as > you continue to troubleshoot the leak and determine the suitability of > the bottomhole location for injection. > Our normal requirements when approving continued injection in a weft > without IA integrity are demonstrated tubing integrity (previously > accomplished), daily monitoring of tubing and IA pressures, daily > monitoring of injection volume and monthly reporting of this information > to the AOGCC. If the rmnitoring indicates furtherproblems with the > well, it should be SI and the information forwarded to us. Under > separate cover I will forward a report format used by the ARCO problem > wells group for email reporting of the information on their variance > wells. > If you have any questions or need further information, please call. > Tom Maunder Internal RECEIVED JA I 'J 2 2000 Nas1 l, Oll & 0ohs. commisst°n Anchorage 1 of 1 1/20/00 2:31 PM Re: BP Well A-31 ai Subject: Re: BP Well A-31ai Date: Thu, 06 Jan 2000 10:32:37-0900 From: Blair Wondz¢ll <blair_wondzell~admin.stat¢.ak.us> Organization: State of Alaska, Dcpt o£Admin, Oil & Gas To: "PBU, Well Intcg T. L." <pbuw¢llintcgtl~BP.com> - Kevin/Bruce, Thanks for the detailed information. Its okay to continue injection, but we will need to process a 10-403 for Sundry Approvals, specifically, Regulatory Approval to continue injection. Please prepare the form and note that I have givern verbal approval to continue injection. Thank You. Blair wondzell 6jan00. "PBU, Well Integ T. L." wrote: > Blair, > We have discovered a problem with this water injection well, briefly, it is > a new coil tubing sidetrack, we went to pressure test the inner annulus and > discovered that it would not hold a liquid MIT test and we were able to > inject diesel down the annulus at .1/2bpm ~ 2200 psi. We had Schlumberger > rig up and run a leak hunt log while pumping diesel down the inner annulus > at this same rate as the leak test. They were not able to confirm any fluid > coming into the tubing at this time. The did however notice a large > temperature anomaly at 5875' We then had slickline set a plug in the > tailpipe and pressure tested the tubing with diesel to 3000 psi. This tubing > test passed with flying colors. I can only assume that with this leak rate > the fluid might be going out a hole in the inner annulus to the formation as > the tubing passed the pressure test and the logs did not show any fluid > entering the tubing. I have enclosed a well diagram and copy's of the actual > telex's for work performed on this well for you to look at. > <<a-31ai 13Cr. cdd>> <<991224 A31LeakDetect. doc>> <<991226A-31 tbgpt, doc>> > <<991223A-31cit (2) . doc>> > > Thanks for your help in this matter. > > Kevin. > Kevin E. Yeager / Bruce W. Smith > Well Integrity Team Leader > BPXA - Prudhoe Bay > MS: BP NS C-1 > Phone 907-659-4644 > Fax 907-659-4689 Name: a-31ai 13Cr. cdd a-31ai 13Cr. cdd Type: application/x-unknown-content-type-cdd_auto_file Encoding: base64 Name: 991224 A31LeakDetect.doc 991224 A31LeakDetect.doc Type: Microsoft Word Document (application/msword) Encoding: base64 Name: 991226A-31tbgpt.doc 991226A-31tbgpt.doc Type: Microsoft Word Document (application/msword) Encoding: base64 991223A-31cit (2).doc Name: 991223A-31cit (2) . doc Type: Microsoft Word Document (application/msword) 1 of 2 1/6/00 10:33 AM ' BP Well A-31 ai Subject: BP Well A-31ai Date: Mon, 27 Dec 1999 23:14:53 -0500 From: "PBU, Well Integ T. L." <pbuwellintegtl~BP.com> To: "'blair_wondzell~admin.state.ak.us'" <blair_wondzell@admin.state.ak.us> CC: "PBU, Well Ops TL" <PBUWellOpsTL@BP.com>, "PBU, Well Integ T. L." <pbuwellintegtl~BP.com> Blair, We have discovered a problem with this water injection well, briefly, it is a new coil tubing sidetrack, we went to pressure test the inner annulus and discovered that it would not hold a liquid MIT test and we were able to inject diesel down the annulus at .1/2bpm @ 2200 psi. We had Schlumberger rig up and run a leak hunt log while pumping diesel down the inner annulus at this same rate as the leak test. They were not able to confirm any fluid coming into the tubing at this time. The did however notice a large temperature anomaly at 5875'. We then had slickline set a plug in the tailpipe and pressure tested the tubing with diesel to 3000 psi. This tubing test passed with flying colors. I can only assume that with this leak rate the fluid might be going out a hole in the inner annulus to the formation as the tubing passed the pressure test and the logs did not show any fluid entering the tubing. I have enclosed a well diagram and copy's of the actual telex's for work performed on this well for you to look at. <<a-31ai 13Cr.cdd>> <<991224 A31LeakDetect.doc>> <<991226A-31tbg10t.doc>> <<991223A-31cit (2).doc>> Thanks for your help in this matter. Kevin. Kevin E. Yeager / Bruce W. Smith Well Integrity Team Leader BPXA - Prudhoe Bay MS: BP NS C-1 Phone 907-659-4644 Fax 907-659-4689 ti Name: a-31 ai 13Cr. cdd ~ a-31 ai 13Cr.cddI Type: unspecified type (application/octet-stream) IEncoding: base64 ~ 991224 A31LeakDetect.doc Type: Microsoft Word Document (application/msword) 1 Encoding: base64 ] Name: 991226A-3 ltbgpt.doc Type: Microsoft Word Document (application/msword) Encoding: base64 ~991223A-3 lcit (2).doc Name: 991223A-31 cit (2).doc Type: Microsoft Word Document (application/msword) Encoding: base64 1 of 1 12/28/99 9:00 AM PRUDHOE BAY, ALASKA TO: PE REPORT GROUP FROM: PAULSBERG YEAGER WELL NAME: [A-31 MAIN CATEGORY: IMAINT SUB CATEGORY OPERATION DATE 112/23/99 DATE: [12/23/99 OPERATION: ATTEMPT TO PRRESSURE TEST IA TO 2200 psig INITIAL PRESSURES: WHP=50 PSIG, TEMP= 130°, IAP=650 PSIG, OAP= 100 PSIG. Time TBG lAP OAP Fluid BPM Total TEMP COMMENTS 1300 ...... MIRU HB&R TO IA, PT LINES AND HELD SAFETY MEETING 1316 50 650 100 DSL .3 0 130° START PUMPING DOWN IA WITH HEATED DSL 1319 50 1000 100 DSL 1.1 3 130° CONTINUE PUMPING 1322 50 1800 100 DSL 1.5 6 130° CONTINUE PUMPING 1326 50 2200 100 DSL .4 9.75 130° S/D, IA AT TEST PRESSURE, BEGIN 30 TEST 1337 50 1800 100 DSL .5 10 130° BUMPING IA BACK UP TO TEST PRESSURE 1343 50 2200 100 DSL .3 12.5 130° SD, RE-START 30 TEST 1403 50 1750 100 DSL .7 12.5 130° #2500" NEW TEST PRESSURE" START PUMPING DOWN IA TO ESTABLISH INJECTIVITY RATE 1406 50 2050 100 DSL .50 14 130° CONTINUE PUMPING 1418 50 2350 100 DSL .48 20 130° CONTINUE PUMPING 1436 50 2350 100 DSL .52 29 130° CONTINUE PUMPING 1445 50 2300 100 DSL .52 33 130° S/D, END OF INJECTIVlTY TEST 1450 50 !2300 100 DSL - - BLEED IA BACK 1458 50 650 100 - - 7 - IA BLED BACK, R/D AND MOL Final Pressures: WHP=50 PSIG, TEMP=130°, IAP=650 PSIG, OAP= 100 PSIG. Fluid Summary: 33 BBLS DIESEL PUMPED AND 7 BBLS BLED BACK CONCLUSION: WELL FAILED CIT, AN INJECTIVITY RATE OF .52 BPM FOR 40 MINUTES WAS ESTABLISHED AT 2200 PSI. IA TAGGED AND PAD OPERATOR NOTIFIED. A LEAK HUNT LOG IS REQUIRED TO IDENTIFY LOCATION OF PROBLEM AND FOR STATE AOGCC DIAGNOSTIC WORK. To: Anchorage Production Engineering Locatio A-31ai n: From: Walker Date: December 24, 1999 Operation: Leak Detect Cost Code: Job Id: Detail Code: F55A31 - xxx Maint / Leak Detect. etc. Summary MIRU SWS and HB&R. SI wing and begin pumping diesel down IA at 0.5 BPM and 2,250 psi. RIH logging to 9,350'. Note fluid level at 500'. No sign of tubing leak. Perform stop count at 9,250' and see slight spinner response. Suspect well taking fluid. PUH logging. Note temperature inflection at 5,875' but no spinner change or caliper activity. Log repeat over this section and confirm temperature deflection. Perform stop count at 5,682' and 6,057' with temperature readings of 102 degrees and 107 degrees respectively. S/D pump and POOH. No flow into the tubing was noted. There does appear to be a leak in the casing at 5,875'. Estimated Daily Cost: $14,500 12/24/99 Initial Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F Inj 0 525 100 N/A 1060 120 Time Operation 13:00 MIRU SWS and HB&R. 14:00 Hold PJSM with entire crew- appoint spill champion. 14:30 SI wing valve- begin pumping down IA 0.5 BPM 14:40 RIH logging. 16:01 No sign of hole. Park at 9,250'- minor spinner movement. Fluid level dropping. 16:10 Log up- continue pumping down IA at 0.5 BPM. Notice temp. Inflection at 5,875. 17:30 Perform stop count at 1,510' (fluid level)- minor spinner movement. 17:47 Log up from 6,100'. See temperature inflection at same depth. 17:50 Stop count at 5,682'. Temp- 102 degrees. 17:55 Stop count at 6,057'. Temp - 107 degrees. 18:00 S/D pump RDMO HB&R. POOH. 18:45 On surface. RDMO SWS. Final Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F Inj. 0 0 0 N/A 1100 52 Fluid Summary 85 I Diesel (at 2 degrees F) Operation: A-31ai I 85 I Total I Page: 2 Perforating Assembly Bottom Hole Assembly # 1 Tool String Descriptions O.D. Length Comments Logging Head 1.375 1.6 Swivel 1.6875 1.0 Weight bars (2) 1.6875 12.0 GR / CCL / Temp / Manometer 1.6875 7.9 Gradiometer 1.6875 5.0 In-Line Spinner 1.6875 2.6 Fullbore Spinner 1.6875 5.1 2" Turbine spinner I Total Length 35.2 PRUDHOE BAY, ALASKA TO: PE REPORT GROUP FROM: PAULSBERG YEAGER WELL NAME: [A-31i MAIN CATEGORY: IMAINT SUB CATEGORY IPRESSURE TEST OPERATION DATE J12/26/99 DATE: 112/26/99 OPERATION: PRESSURE TEST TUBING TO 3000 psig. S/L HAS SET PLUG IN TAILPIPE. WELL FAILED INNER ANNULUS PRESSURE TEST, LEAK HUNT LOGGING COULD NOT CONFIRM PROBLEM WITH TUBING. INITIAL PRESSURES: SIP= 0 PSIG, 1AP= 680 PSIG, OAP= 40 PSIG. Time TBG lAP OAP Fluid BPM TotaI!TEMP COMMENTS 1530 0 680 40 DSL - - - MIRU HB&R TO TUBING, HELD SAFETY MEETING AND PT LINES 1540 130 680 40 DSL 3.0 0 - START PUMPING DOWN TUBING 1551 3000 730 40 DSL 3.0 19 - S/D TUBING AT TEST PRESSURE, BEGIN 30 MINUTE TEST 1621 3000 730 40 .... END OF TEST, BLEED OFF TUBING 1628 0 680 40 - - 2 - S/D, R/D AND MOL FINAL PRESSURES: SIWHP= 0 PSIG, IAP= 680 PSIG, OAP= 40 PSIG. FLUID SUMMARY: PUMPED 19 BBLS DIESEL AND BLED BACK 2 BBLS CONCLUSION: TUBING HELD PRESSURE FOR 30 MINWFE TEST. I_)1 Jl. i. I~.VIJ I'.1 ~ltJl~.~ ........ l~ ' . ...... I I ........ Illl ...... mmll WEILHEAD:McEvoy ' ! ! "-~~ ~ I J J r~ Mi -.. 4_1/2 $$$v LANDING NIPPLE j~-~--~--I i Cemented -----JL I ~ (CAMCO) (3,~13" ID) J ~".'L."~ I ' - GAS LI~ MA~'b'~'~L~ / MAX ANGLE: ~ : ~ ~- 6,775 6,25~ ~ 2' 8,~7 7,~4~ 24 ~-~/~,, ~l.~, .T~-o~,T~8 I~ . ...... ~ J ........ I 1 ~1: [~!~ TU:m ~.~ ~~ I , ~ ~~ :r-l?~ '1 Top of 2 7/8 Liner at 9,270 ft. " I 4-1/2 ,,,l, 2.O~/lt, 10-OR TAILPIPE Baker 4 1~" KB Retrievable J I ! I' i ~ 4-1/2 SWS' NIPPLE ~~ packer at top with seal assemb~ ~ ~ ~ ~ ; ~ ~ J ID = 2.40" I I ' I ~ J / , I I = . I ~ ~z8", ~,~6~, L-eo, STL, UNER J J ~ l ~ .... ' .......... I I , 7,~1/ Original 7', 2G~/fl, L-80, IJ~ liner, I : PBTD al 9988', TD at 10,030 ff BK~ . / Top Of Baker Whipstock set at g~84 fl J ~TION $UMMAR~ ~ J No ~A Tag. ' " REF. LOG: Sper~ Sun MWD GR / ROP, 11-27-99 3.80' window milled from g887-9596 fl, 1 TIE IN LOG: BHOS / GR. ' ~ , 1 ............... Perforations were ~qu~ez~d, wilh 8JJ~ ~PF I.tew. I ' OCe.lSq~ OBT top at the whipstock 8t 9584 Il. J 2" 4 10491-105~ Open ...... ~~ J ' J ~ , R ' r inWeather J Monitoring Shack must be turned off J __ ~, ~ before any well work invoMng 1 ............ ~ explosives can beginl / 27/8, 61G~ LSO STLLiner ,,~ · , - , ' j]u,59oj ~ CTDHORIZONTALSIDE~K / III ...... L, ,,,, DATE REV. BY COMMENTS ................... .... ii i ........ ~- I ..... -- / 8/3u9~ .... HF ..... RWO Comp~eti~ .... WELL: A'31Pi.(3_6-~!_3) J 7/~/99 Nprds Set Whip~k ..... '- APl NO; 50-02~l.~~1 J 11/2~9 .B.. ~itlow QTD HORIZONTAL SIDEkiCK SEC' 35: TN 11; RGE '13 ~L ........... ~ LL ....... ~ .......... ............... BP Exploration (Alaska) J I I ' -- I111 ....... iI ..... RII II Iq i GAS LIFT MA~'i~'F~'~L~ ........... N" MD(BKB) TVD~s Der . . 6 5 3,100 3,018 .5~ l 4 5,164 4,906 31 ° 3 6,775 6,258 33~ 2 8,347 7,642 24~ 1 9,039 8,281 23" TONY KNO WLE$, GO VERNOR ALAS OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 15, 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bav Unit A-31Ai BP Exploration (Alaska) Inc. Permit No: 199-56 Rev. Sur Loc: 2962'SNL? 10145NEL. Sec. 35, T11N, RI3E. UM Btmhole Loc. 441'SNL. 1519'EWL. Sec. 01, T10N, R13E. UM Dear Mr. Stagg: Enclosed is the approved revised application for permit to drill the above referenced well. The revision is for a change in bottom-hole location. The provisions of the original approved permit dated June 28, 1999 are in effect for this revision. Robert N. Christenson. P.E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl qz.:.r~,rmmgn"Tu~u"~-rogram= ETnme Vs~Dbpth PFot I--IRefraiStion-Analysis [] Seabed RePort ~ 20 AA-C 25~50 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21 I hereby · certify that the foregoing is true and correct to the best of my knowledge Signed ~,~,~ Ted Stagg Title CT Drilling Engineer Permit Number 199-056 Conditions of Approval: Approved By Commission Use Only APl Number Approval Date J See cover letter 50-029-21383-01 ~--~,~- .~/~ for other requirements Samples Required J"-I Yes ~r~o Mud Log Required Hydrogen Sulfide Measures I~-Yes I'-INo Directional Survey Required []No Required Working Pressure for/BOPE 1-12K; [-13K; ~4K; 1--15K; [-I10Ki 1'-115K Other: ORIGINAL SIGNED BY by order of Robert N. Christenson Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate _ hared . _ervices ' rilling Date: Nov. 8,1999 To: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Sr. Petroleum Engineer Re: Well A-31 ai Change of BHL Well A-31 is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The proposed sidetrack was issued permit 99-56 on 6/28/99. Since that time the sidetrack has been re-evaluated and the BHL has changed. A- 31 ai is now scheduled to be drilled as soon as Nov. 15, 1999. A new directional plan is attached. Please contact me if further information is needed. Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Data Center Section Path Distance (Feet) 500 1,000 1,500 2,000 2, ,500 3,000 MD:9588 8,945 · Tot Drld:921 ft 10509 TD Marker Depths ~:)ri~l Wellbore TSGR I 8,6801ft TVD 'TSHU TSAD I 8,70'51. TVD I 8,7 81, v 8,8 01, v[ IKick Off I 8,7661ft TVD 9,5881ff MD IDeprtr @KO 2,960 ft I MD KO Pt 9,588I MD New Hole 9211 I Total MD 10,509I TVD TD 8,9531 DLS de~l/100 Tool Face Len~lth Curve 1 6 0 ~0 Curve 2 34 0 167 Curve 3 34 30 59 Curve 4 16 90 60 Curve 5 16 -90 109 'Curve 6 16 180 180 Curve 7 16 - 135 326 921 Drawn: 11/7/1999 10:47 Plan Name: Case 103 -1,000 1, - 1,500 oo -2,000 .-.I .ffi >. -2,500 -3,000 -3,500 O0 A-31 2,200 2,700 3,200 8,945 :1~18,945 X distance from Sfc Loc 3,700 JWellName A-31 J CLOSURE JDistance 3,745 ft J Az 136 de~l NEW HOLE E/W (X) N/S (Y) i Kick Off 2,077 -2,087 TD 2,590 -2,705 State Plane 656,985 5,944,778 Surface Loc 654,395 5,947,483 DLS de~l/100 Tool Face Len~lth Curve 1 6 0 ~0 Curve 2 34 0 167 Curve 3 34 30 59 Curve 4 16 90 60 Curve 5 16 -90 109 Curve 6 16 180 180 Curve 7 16 - 135 326 921 Drawn: 11/7/1999 10:47 Plan Name: Case 103 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 28. 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit A-31Ai BP Exploration (Alaska) Inc. Permit No: 99-56 Sur Loc: 2962'SNL, 1014'WEL. Sec. 35. T11N. R13E, UM Btmhole Loc. 870'SNL, 2102'EWL. Sec. 01. T10N. R13E. UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of thc Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson. P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation x¥/o encl. ..-- STATE OF ALASKA ~-- ALASKA ._ .~ AND GAS CONSERVATION COrv~,¢ilSSlON PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork I--IDrill [~Redrill Ilb. Typeofwell I--IExploratory I-IStratigraphicTest I--I Development Oil [] Re-Entn/ [] DeepenI []Service [] Development Gas []Sin~lle Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska)Inc. KBE = 81.17' AMSL Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047472 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2962' SNL, 1014' WEL, SEC. 35, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 23100302630-277 230' NSL, 990' EWL, SEC. 36, T11N, R13E, UM A-31Ai At total depth 9. Approximate spud date Amount $200,000.00 870' SNL, 2102' EWL, SEC. 01, T10N, R13E, UM 07/07/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028286, 870'I No Close Approach 2560 11226' MD / 8881' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9590' MD Maximum Hole Angle 98° Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 1976' 9250' 8473' 11226' 8881' !113 cu ft Class 'G' ,, 19. To be completed for Redri,, Re-entry, and Deepen Operations. j iji,l ~ 5 1.999 Present well condition summary Total depth: measured 10030 feet Plugs(measured) ORIGINAL true vertical 9222 feet Alaska 0il & Gas ConG. 00mm Effective depth: measured 9700 feet Junk (measured) Fill at 9700'/~l~tJl~l~gO true vertical 8943 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20"x 30" 8 cu yds concrete 110' 110' Surface 2639' 13-3/8" 3254 cu ft PF 'E', 465 cu ft Permafrost 2668' 2668' Intermediate 9484' 9-5/8" 1971 cu ft Class 'G' 9513' 8784' Production Liner 782' 7" 278 cu ft Class 'G' 9248' - 10030' 8552' - 8528' Perforation depth: measured Sag River: 9496' - 9511'; Ivishak: 9584' - 9602', 9619' - 9649', 9730 ' - 9760' Sqzd: 9657' - 9662' true vertical Sag River: 8769' - 8782'; Ivishak: 8844' - 8859', 8874' - 8899', 8968' - 8994' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21' I hereby certify that the ~g~is true and c°rrect t° the best °f my kn°wledgeSignedTed Stagg~j~..~y CommissionTitle CT Drillinguse OnlyEngineer Date Permit Number I APl Number Approval Date.. I See cover letter _,~--,.~ 50-029-21383-01 ~..:. _,:.~ ¢i-- ~7 ~' for other requirements Conditions of Approval: Samples Required I--lYes ~No Mud Log Required _[]Yes ~No Hydrogen Sulfide Measures []Yes 'j~No Directional Survey Required '~['Yes []No Required Working Pressure for BOPE [-12K; 1--13K; J~4K; E]5K; ['-110K; I--] 15K Other: ORIGINAL SIGNED, BY by order of Date~- Approved By Robert N. Chdstenson Commissioner the commission Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX A-31ai Sidetrack Summary of Operations: A-31 has been a water injector since June 1993. The sidetrack, A-31ai, will relocate injection to better flood Zone 4B. This sidetrack will be conducted in two phases. Phase 1: Set whipstock: Planned for June 21, 1999. · A Mechanical Integrity Test will be performed with AOGCC witness. · A Kinley caliper has been run over the tubing and liner. · A permanent whipstock will be set on ELine at approximately 9,584' MD. Phase 2: Squeeze Perfs, Mill Window and Drill Directional Hole: Planned for July 7, 1999. Directional drilling coiled tubing equipment will be rigged up and utilized to squeeze perfs, mill the window and drill the directional hole as per attached plan to planned TD of 11,226' MD (8,881' TVDss). Mud Program: - Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.7 - 8.8 ppg) Disposal: - No annular injection on this well. - All drilling and completion fluids and all other Class II wastes will go to CC-2a for injection. - All Class I wastes will go to Pad 3 for disposal. Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 9,250' MD and cemented with approx. 20 bbls. cement to bring cement 200 ft above the window. The well will then be perforated with coiled tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 9,590' MD (8,768' TVD ss) - TD: 11,226' MD (8,881' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory Induction Log TREE: 4" CIW WELLHEAD: McEvoy ACTUATOR: BAKER '~-~-31ai Proposed Completior KB. ELEV = 81.17' BF. ELEV = 52.19' 13-3/8", 72#/ft, 126681-- L-8o, BTRS KOP: 2,700' MAX ANGLE: 33.65' 4-1/2", 12.6#/ft, NT13- CR, TDS TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT FOC SSSV LANDING NIPPLE I2028! I ( CAMCO)(3.813" ID) GAS LIFT MANDRELS N_o (MERLN RA LATGH) MF)(RKR/ TVI-) ~RTVD 3100 I 3018 I 5° 5164 14906 131° 6775 16258 133° 8347 I 7642 [ 24° I 8281 123° 91819039 / 8410 J 26° TOP OF 19248' I LINER 9-5/8", 47#/ft, 19512' I L-80, BTRS Liner cement 200 ft above window Whipstock Abandonment cement PERFORATION SUMMARY REF: LOG: CBL 7/18/85 INTERVAL OPEN/SQZD 9496-9511 9584-9602 9619-9649 9657-9662 9730-9760 OPN 10/21/90 OPN 6/22/90 OPN 6/22/90 SQZ 6/10/90 OPN 2/22/94 PBTD 7", 26#/ft, L-80, IJ4S OO3O1 TUBING ANCHOR 19221' 9-5/8" PACKER I (TIW HB-BP)f 3.875 .CJ~)~;),,,O________I 4-1/2", 12.6#/ft, 13-0R TAILPIPE "SWS" NIPPLE J 9278' (PARKER) (3.813" ID) 4-1/2 .... SWN" I .Cj ~).(~.(~! NIPPLE 4-1/2" WLEG 1931 O' ELMD WARNING: RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN! CONTACT PAD OPERA TOR. LU 22.5" 7 1/16" Annular ...... I I II Blind/Shear 7 1/16" Pipe/Slip 7 1/16' x 5,000 psi 7 1/16' x 5,000 psi 7 1/16" Pipe I SWAB OR MASTER VALVE 2 3/8" 2 7/8" 2 3/8" Section Path Distance (Feet) 500 1,000 1,500 2,000 2,500 3,000 Angle @ K,O,= 32 deg MD:9590 Tot Drld:1636 ft 11226 TD Marker Depths @Oriel Wellbore TSGR I 8,6801ft TVD 'TSHU I 8,7051ft TVD 8,8601 8,860lft TVD IKick Off 8,7681ft TVD 9,5901ft MD IDeprtr @KO 2,961 ft I MD KO Pt 9,590I MD New Hole 1636I I Total MD !1,226I TVD TO 8,8811 DLS de~l/100 Tool Face Length curVe 1 6 0 ~'0 Curve 2 34 0 169 Curve 3 10 90 119 Curve 4 10 0 80 Curve 5 10 -90 489 Curve 6 10 180 180 Curve 7 10 90 579 1,636 Drawn: 6/14/99 14:07 Plan Name' Case 101 A-31 '00 2,200 2,700 3,200 X distance from Sfc Loc 3,700 JWell Name A-31 J CLOSURE rDistance 4,458 ft Az 134 de~l NEW HOLE E/W(X) N/S (Y) KickOff 2,078 -2,088 TD 3,182 -3,122 State Plane 657,`577 `5,944,361 Surface Loc 654,39,5 ,5,947,483 DLS de~l/100 Tool Face Len~lth Cuwe 1 6 0 ~0 Curve 2 34 0 169 Curve 3 10 90 119 Curve 4 10 0 80 Curve 5 10 -90 489 Curve 6 10 180 180 Curve 7 10 90 579 1,636 Drawn: 6/14/99 14:07 Plan Name: Case 101 STATE OF ALASKA ALASK,~ LAND GAS CONSERVATION CO, IISSION APPLICATION FOR SUNDRY APPROVAL [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate 1. Type of Request: [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: [-~ Development ~] Exploratory [] Stratigraphic [~Service 4. Location of well at surface 2962' SNL, 1014' WEL, SEC. 35, T11 N, R13E, UM At top of productive interval 230' NSL, 990' EWL, SEC. 36, T11N, R13E, UM At effective depth 141' NSL, 1057' EWL, SEC. 36, T11N, R13E, UM At total depth 2' SNL, 1158' EWL, SEC. 01, T10N, R13E, UM 6. Datum Elevation (DF or KB) KBE = 81.17' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A-31i 9. Permit Number 85-142 10. APl Number 50-029-21383 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10030 feet true vertical 9222 feet Effective depth: measured 9700 feet true vertical 8943 feet Plugs (measured) Junk (measured) Fill at 9700' (11/90) Casing Length Size Cemented M D 'I-VD Structural Conductor 110' 20"x 30" 8 cu yds concrete 110' 110' Surface 2639' 13-3/8" 3254 cuft PF 'E', 465 cu ft Permafrost 2668' 2668' Intermediate 9484' 9-5/8" 1971 cu ft Class 'G' 9513' 8784' Production Liner 782' 7" 278 cu ft Class 'G' 9248' - 10030' 8552' - 8528' Perforation depth: measured Sag River: 9496' - 9511'; Ivishak: 9584' - 9602', 9619' - 9649', 9730 ' - 9760' Sqzd: 9657' - 9662' true vertical Sag River: 8769'-8782'; Ivishak: 8844'-8859', 8874' 8899', 8968'-8994' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, NT13-Cr to 9310' Packers and SSSV (type and measured depth) 9-5/8" TIW HB-BP packer at 9222'; 4-1/2" Camco BVLN at 13. Attachments [] Description summary of proposal [] Detailed operations program [--} BOP sketch ':¥,~,r~ 14. Estimated date for commencing operation June 21, 1999 16. If proposal was verbally approved Name of approver contact Engineer Name/Number: Ted Stagg, 564-4694 Date approved 15. Status of well classifications as: ~-I Oil [~j Gas [~ Suspended Service Water Iniection Prepared By Name/Number: Terrie Hubble, 564-4628 Signed Ted Stagg '~"r--~./'"""~'M~X' Title CT Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- I Approval N o.~ ~,~ Approved by order of the Commission Form 10-403 Rev. 06/15/88 Commissioner SUbmit In Triplicate H 15i821 o~;~,'~ VENDOR A, _ASKAST 14 DC DATE INVOICE ! CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 051199 CKO51199A 100. 0¢ 100. OC HANDLING INST- s/h ter~i bubble x4628 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~[e]llf'-~l~ ] I OD O~ 1 ~')(~ O~ .':BP ~:~PLORAT!QN (ALASKA):~ ~INC., P.O. BOX: .196612 '" .' 'ANCHORAGEil ALASKA 99519-6612 No....... H .......1:5 !. 82l CONS~J~.IDA'.~'ED COMMERCIAL :ACCOUNT' .:'56-389 '412 00151821 PAY ONE:HUNDRED &:':.:OO/1OO~w~~~'~,~~~~~ US DOLLAR ,:ALASKA STATE':~,:D~PTii:i;,'OF REVENUE ::300 I'?,i!YPi3R C UP I:NE:::.!!;: D~' ' ANCHORAOE DATE .... ....: 05/11 AK 99501-31;~0 AMOUNT NOT :VALID AFTER 120 DAYS :.: ". . :' '::' ' :":: , :i.; ";'," FIELD & ADMINISTRATION INIT CLASS ................. .'./_~C':_.~__~_.. .................................... GEOL AREA ENGINEERING /~PPR DATE GEOLOGY 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to v~) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 301 "p'ermit can be issued w/o hydrog~'n sulfide measureS. ~ . '.' . 31. Data presented on potential overpressure zones ....... dev redrll ',./ serv ~" wellbore seg ann. disposal para req .............................. ................. ............ 'N N N N N _v ,\ , N N N ANNULAR DISPOSAL APPR DATE 32. Seismic analysis of shallow gas zones ............. Y N ._/.~__,¢¢__._ ................................................................... 33. Seabed condition survey (if off-shore) ............. ,~Y N .4//")/ 34. Contact name/phone for weekly progress repods [exploratory only]CY~..N 35. With proper cementing records, this plan ~ c_,.~--,...~\~ ~-\ ~r~.~.--~ ~-. ,,.----'""~ ~- .--~'~- ........................................ (A) will contain waste in a suital~~z0~ ..... Y N (B) will not contaminate fr~'f'~ter; or cause drilling waste... Y N to surface; / . ~ ~ , ' x ~ -.: ..... ..~ - (C) will not impair rr~chanic~ integrity of the well used for disposa~ N (D) will not dama, g'e producing formation or impair recovery from a ~ ,/' pool; and ~ (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOG~ ENGINEERING: UIC/Annular COMMISSION: ~~ SEW WM ~ DWJ ~ JDH .,_ RNC co .-'_:i~ :':L:LL '---- Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09~27~99) COMPANY WELL PERMIT CHECKLIST FIELD & POOL ._.~ .~'?'~,//.~-~_~) ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... WELL NAME~,~'j2Z"~' PROGRAM: exp ~ dev ~ 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING Y N N N N N N 14. Conductor string provided ................... /Y'I N 15. Surface casing protects all known USDWs ........... ~yY N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... (~ N 19. Casing designs adequate for C, T, B & permafrost ....... (.~ N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... N 22. Adequate wellbore separation proposed. N 23. If diverter required, does it meet regulations .......... -Y-~N-,-'~ 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ (~ N 26. BOPE press rating appropriate; test to /-{ OOC.~ psig. (~) N redrll ~ serv ,.,~.. wellbore seg ann. disposal para req ~ UNIT# ./'/_~"Z_~"',~ ON/OFF SHORE DATE GEOLOGY 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~._.. N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. (__Y.) N ~ Permitcan be issued w,o hydrogen sulfide measures ..... ~/~ ~ ¥ N/"~ _,, 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratorygrily] Y N / ANNULAR DISPOSAL APPR DATE 35. With proper cementing records, this plan (A) will contain wast. e-iff~ suitabl, e-.receiving zone; ....... ¥ N (B) will not contarfiinate'" fresb'~ater"" or cause dril[in~ Waste... Y N (C) will not'impair m.ecfianical integrity of ~ well used for disposal; Y N (D) will'or damag~producing formatieff'(~r impair recovery from a ¥ N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N G EOL O~,-~: ENGINEERING: ,. UIC/Ann.t~r'"" COMMISSION: ~ DWJ ~ RNC '- CO co Comments/Instructions: c:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIXl No special 'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Mar 08 15:34:59 2000 Reel Header Service name ............. LISTPE Date ..................... 00/03/08 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 Date ..................... 00/03/08 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 UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 90195 STEVE LATZ SEVCIK/WHITL A-31A 500292138301 BP Exploration (Alaska) Inc. Sperry Sun 08-MAR-00 MWD RUN 2 A}~-MW- 90195 STEVE LATZ SEVCIK/WHITL MWD RUN 3 A/{-MW- 90195 STEVE LATZ SEVCIK/WHITL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MW- 90195 STEVE LATZ SEVCIK/WHITL MWD RUN 5 A/<-MW- 90195 STEVE LATZ SEVCIK/WHITL 35 lin 13E 2962 1014 81.17 .00 50.70 OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3. 750 7. 000 9584.0 3.750 3.750 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE SUB-SEA TRUE VERTICAL DEPTHS (SSTVD) . 3. MWD RUNS 10 - 50 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 4. MWD RUNS 1, 2, 3, 4, AND 5 ARE LABELED MWD RUNS ..t0, .. 20, 30, 40, AND 50. 5. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC LOG OF 11/27/99 (PDS GR) WITH A KBE OF 81.17' AMSL. THIS WELL KICKS OFF FROM A-31 AT 9584'MD, 8763'SSTVD 6. MWD RUNS 10 - 50 REPRESENT WELL A-31A WITH API # 50-029-21383-01. THIS WELL REACHED A TOTAL DEPTH OF 10,593' MD, 8,999' SSTVD. SGRD = Smoothed Gamma Ray SROP = Smoothed Rate of Penetration $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9580.0 10562.5 ROP 9603.5 10596.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 9580.0 9577.5 9602.5 9600.0 9619.0 9615.5 9630.5 9627.5 9656.5 9652.5 9658.5 9655.0 EQUIVALENT UNSHIFTED DEPTH 9660.0 9665.0 9680.5 9684.0 9695.0 9700.5 9704.5 9733.5 9745.5 9750.5 9752 5 9774 5 9775 5 9791 0 9792 0 9794 5 9798 0 9803 5 9807 0 9809 5 9813 0 9820 0 9830 0 9846 5 9849.5 9858.0 9860.0 9866.0 9872.5 9884.5 9893.0 9895.5 9920.0 9926.0 9935.5 9943.0 9948.0 9951.0 9953.5 9956.5 9961.5 9968.0 9973.5 9979.5 9981.5 9983.0 9985.0 9991.0 9994.0 9996.5 10004.5 10007.5 10008 5 10011 5 10015 5 10018 5 10022 5 10027 5 10040.0 10048 0 10051 0 10071 0 10078 5 10096 0 10103 0 10106 5 10112 5 10118 5 9657.0 9662.0 9678.0 9681 0 9693 0 9698 0 9701 0 9728 0 9740 5 9745 0 9747 5 9773.0 9774 5 9784 5 9787 5 9793 5 9798 5 9805 0 9807 5 9810 0 9813 5 9820.5 9830.5 9847.0 9849.5 9857.5 9860.0 9865.5 9872.5 9883.0 9891.5 9895.0 9916.5 9923.5 9930.5 9937.5 9942.0 9944.0 9945.5 9949.0 9954.0 9961.0 9967.0 9973.0 9975.5 9977.0 9979.0 9984 0 9987 0 9990 0 9998 0 10001 0 10002 5 10005 0 10008 0 10010 5 10014 5 10018 5 10031 0 10040 0 10043 5 10063.5 10079.5 10097.0 10105.0 10107.5 10114.0 10120.0 10138.5 10163.0 10168.5 10170 5 10172 5 10175 5 10178 5 10182 0 10185 0 10190 5 10193 5 10198 5 10208 0 10209 5 10210 5 10221 0 10223 5 10225 5 10234 0 10239 0 10251 5 10254 5 10261 0 10267.0 10274.5 10278.0 10280.0 10283.5 10285.5 10291.5 10293.5 10326.5 10327.0 10329.5 10333 0 10337 0 10340 0 10344 0 10347 5 10358 0 10366 5 10371 5 10376 0 10381 0 10390.5 10394.5 10395.5 10399.5 10403.5 10434.0 10448.0 10450.0 10458.5 10469 0 10478 0 10484 0 10487 0 10505 5 10507 5 10509 5 10510 0 10518 0 10520.5 10529.0 10538.0 10542.5 10548.5 10560.0 10140.0 10165.0 10170.0 10172.5 10175.0 10178.5 10179.5 10182.5 10185.0 10191.0 10193.5 10199.0 10207.5 10209.0 10210.5 10222.5 10225.0 10226.5 10231.0 10236 0 10250 0 10252 0 10258 0 10265 5 10272 5 10275 0 10277 0 10281 0 10282 5 10288 5 10291 0 10323 5 10324 5 10326 5 10330.0 10333.5 10336.0 10340.5 10344.5 10356.0 10363.0 10368.5 10373.0 10376.5 10386.0 10388.5 10391.0 10395.0 10398.5 10429 5 10444 0 10445 0 10456 5 10463 5 10478 0 10483 0 10486 0 10504.5 10505.5 10507.0 10508.0 10516.0 10519.5 10528.0 10537.5 10541.0 10546.5 10557.0 10596.0 10593.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 10 MWD 20 MWD 30 MWD 40 MWD 50 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 9577.5 9753.5 9723.0 9829.5 9800.0 10100.5 10069.5 10126.0 10095.5 10593.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 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 Name Service Unit Min Max Mean Nsam DEPT FT 9580 10596 10088 2033 ROP MWD FT/H 1.61 1602.21 85.9563 1986 GR MWD API 19.63 943.54 83.1249 1966 First Reading 9580 9603.5 9580 Last Reading 10596 10596 10562.5 First Reading For Entire File .......... 9580 Last Reading For Entire File ........... 10596 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 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 ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9577.5 ROP 9601.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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 9722.5 9753.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined 24-NOV-99 Insite 0 Memory 9748.0 41.2 55.6 TOOL NUMBER TLG 007 3.750 9584.0 Flo Pro 8.65 65.0 9.2 24000 7.8 .000 .000 .000 .000 .0 137.5 .0 .0 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9577.5 9753.5 9665.5 353 ROP MWD010 FT/H 16.58 1602.21 119.282 306 GR MWD010 API 19.63 223.76 49.9426 291 First Reading For Entire File .......... 9577.5 Last Reading For Entire File ........... 9753.5 First Reading 9577.5 9601 9577.5 Last Reading 9753.5 9753.5 9722.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NIIMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9723.0 9799.5 ROP 9754 . 0 9829 . 5 $ LOG HEADER DATA DATE LOGGED: 25-NOV- 99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9825.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 63.5 96.1 TOOL NUMBER TLG 007 3.750 9584.0 Flo Pro 8.65 65.0 9.5 24000 7.6 .000 .000 .000 .000 .0 137.5 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9723 9829.5 9776.25 214 ROP MWD020 FT/H 7.63 307.7 46.3621 152 GR MWD020 API 21.21 198.42 69.711 154 First Reading 9723 9754 9723 Last Reading 9829.5 9829.5 9799.5 First Reading For Entire File .......... 9723 Last Reading For Entire File ........... 9829.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN ArUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9800.0 ROP 9830.5 $ 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 10069.0 10100.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 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: 25-NOV-99 Insite 0 Memory 10100.0 106.8 113.2 TOOL NUMBER TLG 003 3.750 9584.0 Flo Pro 8.50 65.0 8.5 26000 7.8 .000 .000 .0 120.6 MI/D 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 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 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9800 10100.5 9950.25 602 ROP MWD030 FT/H 33.26 278.36 94.6822 541 GR MWD030 API 20.42 943.54 89.3586 539 First Reading 9800 9830.5 9800 Last Reading 10100.5 10100.5 10069 First Reading For Entire File .......... 9800 Last Reading For Entire File ........... 10100.5 File Trailer Service name.~ ........... STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER F~LE NUMBER: 5 RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NLTMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10069.5 ROP 10101.0 $ 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: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATtTRE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: STOP DEPTH 10095.0 10126.0 26-NOV-99 Insite 0 Memory 10126.0" 105.6 105.6 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL NUMBER TLG 007 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 3.750 9584.0 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60-.lin Max frames per record ............. Undefined Absent value ...................... -999 Flo Pro 8.50 65.0 8.5 26000 7.8 .000 .000 .000 .000 .0 120.6 .0 .0 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10069.5 10126 10097.8 114 ROP MWD040 FT/H 21.17 737.73 192.172 51 GR MWD040 API 151.54 817.62 253.719 52 First Reading 10069.5 10101 10069.5 Last Reading 10126 10126 10095 First Reading For Entire File .......... 10069.5 Last Reading For Entire File ........... 10126 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NI/MBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10095 . 5 10559.5 ROP 10126 . 5 10593 . 0 $ LOG HEADER DATA DATE LOGGED: 27 -NOV- 99 S 0 F TWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 0 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10593.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 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 TERMPER3tTURE: 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 .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 47.4 94.5 TOOL NUMBER TLG 007 3.750 9584.0 Flo Pro 8.60 65.0 8.6 23000 8.4 .000 .000 .000 .000 .0 125.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10095.5 10593 10344.3 996 ROP MWD050 FT/H 1.61 166.66 69.4682 934 GR MWD050 API 20.27 756.1 89.9674 929 First Reading 10095.5 10126.5 10095.5 Last Reading 10593 10593 10559.5 First Reading For Entire File .......... 10095.5 Last Reading For Entire File ........... 10593 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/03/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/03/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Reel Trailer Service name ............. LISTPE Date ..................... 00/03/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Library. ., Scientific Technical Scientific Technical Services Services Physical EOF Physical EOF End Of LIS File