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192-030
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-30 PRUDHOE BAY UNIT M-30 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 M-30 50-029-22255-00-00 192-030-0 W SPT 8194 1920300 2048 1028 1028 1028 1026 138 386 386 382 4YRTST P Guy Cook 6/6/2023 Testing was completed with a Little Red Services pump truck and calibrated gauges. 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 M-30 Inspection Date: Tubing OA Packer Depth 37 2286 2251 2241IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230605111659 BBL Pumped:5.5 BBL Returned:5.8 Wednesday, July 26, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 12, 2019 TO: Jim Regg��j�f 6 13J t l SUBJECT: Mechanical Integrity Tests P.I. Supervisor (1 BP EXPLORATION (ALASKA) INC. M-30 FROM: Guy Cook PRUDHOE BAY UNIT M-30 Petroleum Inspector Src: Inspector Reviewed By p P.I. Supry U`7t" NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M-30 Insp Num: mitGDC190607174839 Rel Insp Num: API Well Number 50-029-22255-00-00 Inspector Name: Guy Cook Permit Number: 192-030-0 Inspection Date: 6/5/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I M-30 Type Inj G 'TVD 8194 Tubing 1886 1887 1889 1891 PTD 1920300 " iType Test SPT Test psi 2048 IA 4 2800 ' 2777 - 2969 BBL Pumped: - ' 10 ' BBL Returned: 6 OA 56 154 ' 157 156 Interval 4YRTST PAF Notes: Job was completed with calibrated gauges and a triplex pump and bleed trailer. Wednesday, June 12, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday, , P.I.Supervisor ' ` i 6( .3(!> SUBJECT: MechanicalJune Integrity 182015 Tests BP EXPLORATION(ALASKA)INC M-30 FROM: Lou Grimaldi PRUDHOE BAY UNIT M-30 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,J gg— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M-30 API Well Number 50-029-22255-00-00 Inspector Name: Lou Grimaldi Permit Number: 192-030-0 Inspection Date: 6/18/2015 Insp Num: rnitLG150618143234 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M-30 Type Inj W TVD 8194 • Tubing 788 800 792 - 790 • PTD 1920300 Type Test SPT Test psi 2048 • IA 1439 2502 • 2484 • 2477 • Interval 4YRTST PIF P ,j OA 865 • 974 969 964 • Notes: 2.6 bbl's diesel pumped,2.5 returned.Good solid test.All required paperwork supplied prior to test. 14 f • CJ sums Welk Sc,Ge ,• ;c SCANNED JUL 1 3 2015 Thursday,June 18,2015 Page 1 of 1 •G" tr, (-3 -47 \5i Q —0 rsi) 0 -4( 0 ("? LJ 2 • 0 • • TREE' CNV SAFET -ITS:H2S READINGS AVERAGE 125 ppm WELLHEAD= FMC ® WHEN I. WELL REQUIRES A SSSV WHEN ON Irl J. ACTUATOR= BAKER C COMRDSITE:WRAP REPAIR Sii LEAK [X)NO 1 VIII OA OVEJ-2 KB ELEV = 57 00' 1200 PSI DUE TO DESIGNED PRESSURE RATING OR REPAIR BF. ELEV= 26.00' i I &DO NOT PUMP METH OR METH BLEND INTO OA DUE TO CHEMNCAL INCOMPATIBILITY w/EPDXY RESIN***7" KOP= 1500' Max Angle= 52°@ 4505' CHROME LNR*** Datum MD= 11045' I 2198° —4-112 HES XNIP,iD=3.813" Datum TVD= 8800'SS 13-3/8"CSG,72#, L-80 BTRS,ID=12.347" —{ 3138' Minimum ID = 3.726" c 10460' I I 10170° H4-1/2"HES X NIP,ID=3 813" 4-1/2" SWN NIPPLE 10201' _19-5/8"X 4-112"BKR S-3 PKR, ID=3.87" 4-1/2"TBG, 12.6#,L-80 TCi, H 10305' i ' 10235' —i4-1/2 HES X NIP, ID=3.813" .0152 bpf, ID=3.958" \ _..- " 10305' } 4-1/2"X 5-112 XO=3.958" 5-1/2"TBG STUB(04/22109) --1 10311' r ___ — 10316' _19-5/8"X 5-1/2"UNIQUE OVERSHOT 5-1/2"TBG,17#,L-80, .0232 bpf,ID=4.892" H 10353' ( ) 10353' —15-1/2"X 4-1/2"XO,ID=3.958" I r— 10375' H4-1/2"PKR SWS NIP,ID=3.813" >< 10398' _19-518"X 4-1/2"BKR SAB PKR,ID=4.75" i i 10440' —14-1/2"PKR SWS NIP,ID=3.813" TOP OF 7"LNR --1 10458' 10458' —+9-5/8"X 7"BKR LTP&A-GR, ID=? I i 10460' H4-1/2"PKR SWN NIP, ID=3.725" 4-1/2"TBG, 12.6#,L-80, .0152 bpf,ID=3.958" H 10472' / \ 10472' H4-1/2"WLEG,!D=3.958" 9-5/8"CSG,47#, L-80 BTRS,ID=8.681" --I 10715' • ® 10457 H ELMD TT LOGGED 11/23/00 PBTD —1 11397' PERFORATION SUMMARY ilk g 10946' HFISH- DEBRIS FROM PATCH(03/27/09) REF LOG'. SWS-BRCS ON 04/03/92;SWS GR/CCL ON 04/24/92 ANGLE AT TOP PERF:39°@ 10874' �y.�.�.�.�.� 10955' —TOP OF CEMENT CAP Note:Refer to Roduction D8 for historical perf data •••••• SIZE SPF INTERVAL Opn/Sqz DATE 10992' —1TOP OF SAND/CARBOLITE 3-3/8" 4 10874-10922 0 09/27/92 3-3/8" 4 10927-10958 0 04/25/92 3-3/8" 4 10958-10978 S 09/02/99 3-3/8" 4 10982- 11010 S 09/02/99 - 3-3/8" 4 11022-11054 S 09/02/99 3-3/8" 4 11170-11220 S 09/02/99 7"LNR,26#,13CR-N80 NSCC, .0383 bpf,ID=6.276' H 11480' .••••••• i! DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04106192 ML ORIGINAL COMPLETION 02/10/11 MB/JMD ADDED SSSV SAFETY NOTE WELL: M-30 04/26/09 NOES RWO 02/27/11 TQ/PJC SFTY NOTE(COMPOSITE WRAP) PERMIT No:'1920300 05/19/09 AW/JMD DRLG DRAFT CORRECTIONS 04/12/11 PC/JMD FISH,CMT,DEPTH CORRECTIONS API No: 50-029-22255-00 05/29/09 JMD TBG STUB DATE CORRECTION 01/18/12 TMN/JMD ADDED I-12S SAFETY NOTE SEC 1,Ti 1 N,R12E,2234'FSL&606'FEL 06/02/10 PJC WELLHEAD UPDATE 09/23/10 PJC SAFETY NOTE UPDATE BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday,June 18, 2015 9:01 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN;AK, OPS GC2 Ops Lead; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA); Summers, Matthew; Pettus,Whitney;Weiss, Troy D Subject: OPERABLE:Injector M-30 (PTD#1920300)AOGCC MIT-IA Passed Attachments: image001.png; image002.png All, Injector M-30(PTD#1920300) passed an AOGCC state witnessed MIT-IA to 2500 psi on June 18,2015 confirming two competent barriers in the wellbore. The well is reclassified as Operable. Please call with questions or concerns. Thank you, Whitney Pettus SCANNED EI AN , 6 2015 (Alternate.Kevin Parks) BP Alaska-Well Integrity Coordinator GWU g, tat+on WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com From: AK, D: ell Integrity Coordinator Sent: Friday, June 0 , •:41 AM To: AK, OPS GC2 OSM; AK, OP c- Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline o - ations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East e I it Engr; Peru, Cale; AK, OPS Well Pad MN; AK, OPS GC2 Ops Lead; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well rity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James A) (jim.reqg@alaska.gov); Summers, Matthew Subject: UNDER EVALUATION: Injector M-30 (PTD #1920300) Due for CC Witnessed MITIA All, Injector M-30(PTD#1920300) is ready to place on injection for an AOGCC witnessed MIT-IA. T ell is reclassified as Under Evaluation and placed on a 28 day clock. 1 ?Bu( -,o prh Vq.Z03o0 Regg, James B (DOA) From: Regg, James B (DOA) p(q 611/1i Sent: Wednesday, June 17, 2015 9:15 AM � To: Grimaldi, Louis R (DOA) Subject: RE: Need your opinion I'd postpone these; none appear stable to me. In addition, the OA in M-29 has increased above 1000psi; while the sustained casing pressure limits (2000 IA and 1000 OA) do not apply to injectors, it is still cause for concern and should be addressed. I would not make a definitive call right now that the annuli pressures are thermal. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 SCANNED JUL 0 2 2015 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: Grimaldi, Louis R (DOA) Sent: Wednesday, June 17, 2015 8:20 AM To: Regg, James B (DOA) Subject: Need your opinion Jim, Please take a look at these T/I/O plots. M-30 looks good to me but 28 & 29 are still climbing on the IA pressure. I'm guessing from filling the IA and that fluid is heating up. Just wondering if we should be getting on them at this point. I am working in the office up here so you can call if you have time. Lou Louis R. Grimaldi Petroleum Inspector Alaska Oil and Gas Conservation Commission 907-776-5402 (Home) 907-252-3409 (Cell) Lou.Grimaldi( Alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Lou Grimaldi at 907-252-3409 or Lou.Grimaldi@Alaska.gov. 1 • .18 .-F-18886 I 1 4 0 cr. 411.. 0 0 A •• LLI 0 TREE_ CM/ SAF DOTES:H2S READINGS AVERAGE 125 ppm WELLHEAD= FMC WHEN uN MI. WELL REQUIRES A SSSV WHEN ON MI. ACTUATOR= BAKER C. M -3 0 COMFL)SITE WRAP REPAIR SH LEAK-DO NOT MIT-OA OVER KB. ELEV = 57.00 1200 PSI DUE TO DESIGNED PRESSURE RATING OR REPAIR BF. ELEV = 2600' i 1 &DO NOT PUMP METH OR METH BLEND INTO OA DUE TO KOP= 1500' CHEMIICAL INCOMPATIBILITY w/EPDXY RESIN"'7" CHROME LNR Max Angle= 52°@ 4505' Datum MD= 11045' Datum TVD= 8800'S5 2198' —14-112"HES X NIP, ID=3.813" 13-3/8"CSG,72#, L-80 BTRS, ID=12.34T H 3138' -41 Minimum ID = 3.726" @ 10460' I I 10170' I-4-1/2'HES X NIP, ID=3.813° 1 4-1/2" SWN NIPPLE = x 10201' _9-5/8"X 4-1/2"BKR S-3 PKR, ID=3.87" 4-1/2"TBG, 12.6#,L-80 TCII, —1 10305' ii1©235' —41/2'HES X NIP, ID=3.813" 0152 bpf, ID=3.958 10305' —4-12"X 5-1/2 X0=3.958" / 5-1/2"TBG STUB(04/22/09) —I 10311' 10316' _19-5/8"X 5-1/2"UNIQUE OVERSHOT 1 5-1/2"TBG,17#, L-80, .0232 bpi,ID=4.892" — 10353' \ i 10353' —15-1i2'X 4-1/2"XO,ID=3.958" ' 10375' --I41/2" PKR SWS NIP, ID=3.813" X 10398' _19-5/8"X 4-1/2"BKR SAB PKR,ID=4.75" ' , 10440' —I 41/2" PKR SWS NIP, ID=3.813" TOP OF 7'LNR H 10458' 4. 10458' —19-5/8"X 7"BKR LTP&HGR,ID=? ' 10460' —14112"PKR SWN NIP, ID=3,725" 4-1/2"TBG, 12.6#,L-80, .0152 bpf, ID=3.958" —I 10472' `/ 10472' —14-1/2"WLEG,ID=3.958" 9-5/8"CSG,47#,L-80 BTRS, ID=8.681" —1 10715' A , 10457' — ELMD TT LOGGED 11/23/00 PBTD —I 11397' PERFORATION SUMMARY , 10946' —FISH- DEBRIS FROM PATCH(03/27/09) REF LOG: SWS-BHCS ON 04/03/92,SWS GR/CCL ON 04/24/92 ANGLE AT TOP PERF. 39° a. 10874' �.�.�- -�y�' 10955' --I TOP OF CEMENT CAP Note. Refer to Roduction DB for historical perf data I -•_•.•- .•-•-4 SIZE SPF INTERVAL Opn/Sqz DATE 10992' —TOP OF SAND/CARBOIJTE 3-3/8" 4 10874- 10922 0 09/27/92 3-3/8" 4 10927- 10958 0 04/25/92 I 3-3/8" 4 10958- 10978 S 09/02/99 3-3/8" 4 10982- 11010 S 09/02/991 3-3/8" 4 11022- 11054 S 09/02/99 3-3/8" 4 11170- 11220 S 09/02/99 7"LNR,26#, 13CR-N60 NSCC, .0383 bpi, ID=6.276" — 11480' �•�����������•� DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04106/92 ML ORIGINAL COMPLETION 02/10/11 MB/JMD ADDED SSSV SAFETY NOTE WELL: M-30 04/26109 N4ES RWO 02/27/11 TQ/PJC SFTY NOTE(COMPOSITE WRAP) PERMIT No:'1920300 05/19/09 AW/JMD DRLG DRAFT CORRECTIONS 04/12/11 PC/JMD FISH, CMT,DEPTH CORRECTIONS AR No 50-029-22255-00 05/29/09 JMD TBG STUB DATE CORRECTION 01/18/12 TMWJMD ADDED H2S SAFETY NOTE SEC 1,T11 N,R12E,2234'FSL&606'FEL 06/02/10 PJC WELLHEAD UPDATE 09/23/10 PJC SAFETY NOTE UPDATE BP Exploration (Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, June 05, 2015 9:41 AM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; AK, OPS GC2 Ops Lead; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA); Summers, Matthew Subject: UNDER EVALUATION: Injector M-30 (PTD#1920300) Due for AOGCC Witnessed MITIA Attachments: image001.png; Injector M-30 (PTD #1920300) TIO Plot .docx All, Injector M-30(PTD#1920300) is ready to place on injection for an AOGCC witnessed MIT-IA. The well is reclassified as Under Evaluation and placed on a 28 day clock. Plan forward: 1. Operations: Place on injection 2. DHD: Perform AOGCC MIT-IA to 2500 psi A copy of the TIO plot is included for reference. SCANNED JUN 3 0 2015 Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator GVVGlobal Wells y�/ Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, November 28, 2013j:14 PM To: AK, OPS GC2 OSM; AK, OPS GC2 F ee d-O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operatioui team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK,..f�&C Projects Well Integrity Engineer; 'jim.regg@alaska.gov' Subject: NOT OPERABLE: Injector M-30 (PTD #1920300) Due for AOGCC Witnessed MITIA 1 1612 0 ;)O Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Friday, June 05, 2015 9:41 AM /�/1IS To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN;AK, OPS GC2 Ops Lead; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA); Summers, Matthew Subject: UNDER EVALUATION:Injector M-30 (PTD #1920300) Due for AOGCC Witnessed MITIA Attachments: Injector M-30 (PTD #1920300) 110 Plot .docx All, Injector M-30 (PTD#1920300) is ready to place oninjection for an AOGCC witnessed MIT-IA. The well is reclassified as Under Evaluation and placed on a 28 day clock. Plan forward: 1. Operations: Place on injection 2. DHD: Perform AOGCC MIT-IA to 2500 psi SCANWEV , �,L 0 2 20/5 A copy of the TIO plot is included for reference. Thank you, Kevin Parks BP Alaska -Well Integrity Coordinator Global4'Vells Organlza;ior Office: 907.659.5102 WIC Email:AKDCWeIIIntegntyCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, November 28, 2013 7:14 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; jim.regg@alaska.gov' Subject: NOT OPERABLE: Injector M-30 (PTD #1920300) Due for AOGCC Witnessed MITIA 1 I • All, Injector M-30 (PTD#1920300) is due for its annual AOGCC compliance MIT-IA. The well has been shut in since December 2011 due to flowline integrity issues. There is no plan to place the well on injection in the near future. The well is reclassified as Not Operable and will be added to the Quarterly AOGCC Not Operable Injector Report. Please call with any questions. Thank you, Jack Disbrow BP Alaska -Well Integrity Coordinator GlyVGlobal Wells Organizalior Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 2 iii/101 G(S(i6- Injector M-30(PTD#1920300)TIO Plot • Snx �M .IX Td !pE 01.3315 W.i±s mmn *MIS mm'SS Y>i mita J 6aNE mwD • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 I I May 18,2012 Mr. Jim Regg AUG Alaska Alaska OiI and Gas Conservation Commission o30 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB M -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M 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. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M - 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M-07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 --1" M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 0 WELLHEAD Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ REPAIR Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter uspended Well ^ FURMANITE 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^ Exploratory ^ 192-0300 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ API Number: Anchorage, AK 99519-6612 50-029-22255-00-00 8. Property Designation (Lease N~unber) : \ 9. Well Name and Number ~ ADLO-028257 PBU M-30 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDOHE BAY POOL 11. Present Well Condition Summary: Total Depth measured ~ 11480 feet Plugs (measured) None ~~tC7Q~~S• true vertical ~ 9212.36 feet Junk (measured) None feet ~;11G+If~CdQE~ Effective Depth measured 10958 feet Packer (measured) 10201 10398 true vertical 8788 feet (true verticap 8194 8348 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 3138 13-3/8" 72# L-80 SURFACE - 3138 SURFACE - 3015 4930 2670 Intermediate 10715 9-5/8" 47# L-80 SURFACE - 10715 SURFACE - 8595 6870 4760 Production Liner 1022 7"26# 13CR-N80 10458 - 11480 8395 - 9212 7240 5410 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ - True Vertical depth: _ _ _ _ - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# LL-80 25 - 10305' 25 - 8275 a4-1/2" 12.6# LL-80 10353 - 10472 8312 -8406 - Baker SAB Perm Packer 10201 8194 Packers and SSSV (type, measured and true vertical depth) 4-1 /2" 4-1/2" Baker SAB Perm Packer 10398 8348 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-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1154 460 Subsequent to operation: SI 14. Attachments: 1 Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 3/15/2010 M-30 192-030 DCDC ATTA~`L.IMGNIT • n U Sw Name Operation Date Pert Operation Code ~ Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base M-30 4/25/92 PER 10,874. 10,908. 8,720.74 8,747.74 M-30 4/25/92 PER 10,912. 10,922. 8,750.92 8,758.87 M-30 4/25/92 PER 10,927. 10,978. 8,762.85 8,803.54 M-30 4/25/92 PER 10,982. 11,010. 8,806.74 8,829.15 M-30 4/25/92 PER 11,022. 11,054. 8,838.77 8,864.47 M-30 9/27/92 RPF 10,874. 10,922. 8,720.74 8,758.87 M-30 9/10/96 APF 11,170. 11,220. 8,958.14 8,998.76 M-30 9/2/99 SPS 10,958. 11,397. 8,787.57 9,143.74 M-30 11/23/00 BPS 10,424. 10,958. 8,368.03 8,787.57 M-30 6/12/02 BPP 10,424. 10,958. 8,368.03 8,787.57 M-30 5/17/04 BPS - 10,399. 10,958. 8,348.42 8,787.57 M-30 6/24/04 BPP 10,399. 10,958. 8,348.42 8,787.57 M-30 11/15/05 BPS 10,399. 11,220. 8,348.42 8,998.76 M-30 12/15/05 BPP 10,399. 11,220. 8,348.42 8,998.76 M-30 11/29/07 BPS 10,424. 10,428. 8,368.03 8,371.17 M-30 3/21/09 BPP 10,424. 10,428. 8,368.03 8,371.17 M-30 4/10/09 BPS 10,425. 10,427. 8,368.82 8,370.39 M-30 5/10/09 BPP 10,425. 10,427. 8,368.82 8,370.39 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • M-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~ ACTIVITYDATE ~ SUMMARY ~ 3/6/2010 T/I/O=Vac/0/12. Temp=S1. Prep work for MIT-OA (eval Furmanite repair). OA FL near surface. TP & IAP unchanged, OAP increased 12 psi overnight. Bled OAP from 12 psi to 0 psi in 30 seconds. pulled grating to inspect Furmanite wrap. no sings of fluid seepage or audible gas leaks. SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. _..._._.... ___...~a~~a_._.._____ _ .- ~. -- 3/7/2010 T/I/O=Vac/0/12. Temp=S1. MIT-OA **Pass** to 1200 psi w/diesel. (WH repair). OA FL near surface. Used 104.56 gallons of diesel to pressure up OA to 1200 ;psi in 20 minutes. OA decreased 20 psi in the first the 15 min, and decreased 5 psi in the second 15 min for a total decrease of 25 psi in 30 minutes. Bled OAP to 0 psi. Final WHPs=Vac/0/0. **Note"" removed containment from cellar. ~SV,WV=C. SSV,MV=O. IA,OA=OTG. NOVP. TF~EE _ CM! WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 57.00' BF. ELEV = 26.00' KOP = 1500' Max Angle = 52° @ 4505' Datum MD = 11045' Datum TV D = 8800' SS M -~ ~ SAFETY N :***7" CHROME LNR*** 2198' i--i 4-1l2" HES X NIP, ID = 3.813" 13-318" CSG, 72#, L-80 BTRS, ID = 12.347" 3138' Minimum ID = 3.725" @ 10460' 4-1 i2" SWN NIPPLE 4-1/2" TBG, 12.6#, L-80 TCII, 10305' .0152 bpf, ID = 3.958" 5-1/2" TBG STUB (04/22/09) 10311' 5-1i2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10353' TOP OF 7" LNR 4-1l2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10472' 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" 10715' - STD 11398' PERFORATION SUMMARY REF LOG: SWS-BHCS ON 04!03192; SWS GR/CCL ON 04/24/92 ANGLE AT TOP PERF: 39° @ 10874' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10874 - 10922 O 09/27/92 3-3/8" 4 10927 - 10958 O 04/25/92 3-3/8" 4 10958 - 10978 S 09/02199 3-3i8" 4 10982 - 11010 S 09!02!99 3-318" 4 11022 - 11054 S 09/02/99 3-3l8" 4 11170 - 11220 S 09/02/99 ~ 7" LNR, 26#, 13CR-N80 NSCC, .0383 bpf, ID = 6.276" ~-) 11480' DRTE REV BY COMMENTS DATE REV BY COMMENTS 04!06192 ML ORIGINAL COMPLETION 04/26/09 N4ES RWO 05/19!09 AW/JMD DRLG DRAFT CORRECTIONS 05/29/09 JMD TBG STUB DATE CORRECTION 1{1170' H4-1/2" HES X NIP, ID = 3.813" 10201' ~ 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.87" 10235' 4-1/2" HES X NIP, ID = 3.813"~ 10305' 4-1/2" X 5-1/2 XO = 3.958" 10316' 9-518" X 5-1/2" UNK~UEOVERSHOT 10353' 5-112" X 4-1/2" XO, ID = 3.958" 10375' 4-1/2" PKR SWS NIP, ID = 3.813" 10398' 9-5l8" X 4-1/2" BKR SAB PKR, ID = 4.75" 10440' 4-1/2" PKR SWS NIP; ID = 3.813" 18458' 9-5/8" X 7" BKR LTP & HGR ID = ? 10460' 4-112" PKR SWN NIP, ID = 3.725" 10472' 4-1i2" WLEG, ID = 3.958" 10457' - ELMD TT LOGGED 11/23/00 I ~ 1 FISH -DEBRIS FROM PATCH (03/27/09) 10_ 9581-LTOP OF GEMEM CAP 10995' TOP OF SAND 10992' GARBOLITE? PRUDHOE BAY UNIT WELL: M-30 PERMIT No: 1920300 API No: 50-029-22255-00 SEC 1, T11N, R12E, 2234' FSL & 606' FEL 6P Exploration (Alaska! NOT OPERABLE: M-30 (PTD #1920300) Confirmed Starting Head Leak Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ,~ ~~~~/~~ Sent: Sunday, September 27, 2009 6:01 PM ~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; Brown, Don L.; GPB, Prod Controllers Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Wellman, Taylor T; Murphy, Gerald L Subject: NOT OPERABLE: M-30 (PTD #1920300) Confirmed Starting Head Leak Attachments: M-30 TIO plot.doc; M-30.pdf ~ All, ~ Well M-30 (PTD #1920300) has been confirmed to have a startinghead thread leak. Please have the wel shut-in _ and freeze protected as soon as safely possible. The well has been reclassified as Not Operable. Plans are progressing to mitigate the thread leak with Furmanite composite wrap. ~ A TIO plot and wellbore schematic have been included for reference. -- «M-30 TIO plot.doc» «M-30.pdf» Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. ~alt Torin Roschinger) Well Integrity Caordinator ~ ~~~~~; ;;~1'~~ .. ~~ ~~a~~`` GPB Wells Group ~~'" Phoneti (907) 659-5102 Pager: (907} 659-5100 x1154 11 /5/2009 PBU M-30 PTD 1920300 9/27/2009 TIO Pressures 4I 3.C 2( 1.[ t Tbq ^ IA ~ OA OOA ~-OOOA ~ On TREE = CIW WELLHEAD= FMC ACTURTOR = OTIS KB. ELEV = 57.00' BF. ELEV = 26.00' KOP = 1500' Max Angle = 52° @ 4505' Datum MD = 11045' Datum TV d= 8800' SS SAFETY NOTES:~`**7" CHROME LNR*** ~ -3 $$' E-~ 4-1 /2" HES X NIP, ID = 3.813„ 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 3138~ Minimum ID = 3.725" @ 10460' 4-1/2" SWN NIPPLE _._..__..._......_._....-----•- 4-112" TBG, i2.6#, L-$0 TCII, 1U305' .0152 bpf, ID = 3.958° 5-1(2" TBG STUB (04/22/09) 10311' 5-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10353" TOP OF 7" LNR ~-~ 10458~ ~ 4-112" TBG, 12.6#. L-80, .0152 bpf, ID = 3.958" I 10472' ~I'~-~. 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" 10715~-- r~T~ 11398" PERFORATION SUMMARY REF LOG: SW5-BHCS ON 04/03/92; SWS GR(CCL ON 04/24I92 ANGLE AT TOP PERF: 39° @ 1087A' Note: Refer #o Production DB for histarical perf data SIZE SPF INTEftVAL Opn/Sqz DATE 3-3l8" 4 10874 - 10922 O 09127192 3-3t8" 4 10927 - 16958 O 04/25l92 3-3/8" 4 10958 - 10978 S 09/02l99 3-3/8" 4 10982 - 1101 Q S 09/02/99 3-31&" 4 11022 - 11054 S 09/02/99 3-3/8" 4 11170 - 1122d S 09/02/99 10170~ H 4-1 /2" HE5 X NIP, ID = 3.813" 102Q1 ~ ,~ 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.$7" 10235~ 4-1(2" HES X NIP, ID = 3.813" 10305~ 4-1l2" X 5-1/2 XO = 3.958" 10316' 9-5J8" X 5-1/2" UNIQUE OVERSHOT 10353' S-1(2" X 4-112" XO, ID = 3.958" 10375' 4-1/2" PKR SWS NIP, ID = 3.813" --. _..... _. _..... _... 10398~ 9-5/8" X 4-1/2" BKR SAB PKR, ID = 4.75" 1 Q44Q~ ~ 4-1 J2" PKR SWS NIP, ID = 3.813" '~ (}458' 9-5I8" X 7" BKR ~TP & HGR, ID =? 10460~ 4-1/2" PKR SWN NIP, ID = 3.725" 10472~ 4-1i2" WLEG, ID = 3.958" 1045T ELMD TT LOGGED 11/23/00 ~'~~ FISH - DEBRIS FROM PATCH (03/27109) 10958~ ~--j TOP OF CEMQJT CAP '~ ~~Q~° TOP OF SAND 10992~ CARBOLffE? ~ 7" LNR, 26#, 13CR-N80 NSCG, .0383 bpf, ID = 6.276" ~-j 11480~ DATE REV $Y COMMENTS DATE REV BY COMMENTS Y 04tQ6l92 ML QRIGINAL COMPLEf10N 04(26/d9 N4ES RWO 05l19109 AW/JMq pRLG DRAFT CdRRECTfUNS 05/29/09 JMD TBG STUB DATE CORRECTION PRUDHC}E BAY UN~T WELI: M-30 PERMIT No: ~1920300 API No: 50-029-22255-00 SEC 1, T11 N, R12E, 2234' FSL & 64B' FEL BP F~cploration (Alaska) MEMORANDUM To: Jim Regg ~~„~. 6~~'~ P.I. Supervisor j FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC M-30 PRUDHOE BAY UNIT M-30 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT M-30 Insp Num: mitCS090520063909 Rel Insp Num: API Well Number: 50-029-22255-00-00 Permit Number: 192-030-0 Inspector Name: Chuck Scheve Inspection Date: 5/19/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well M'30 . Type Inj. w I TVD 8~9a ~ IA a1o 2soo 2a6o 2460 P.T.D 1920300 ~ypeTCSt SPT Test psi Interval WRKOVR p~; P 2048.5 ~ OA ~ TUbing ~ 450 690 -!-- 350 350 ~ 690 350 690 350 Notes: ~y Wednesday, May 20, 2009 Page 1 of 1 STATE OF ALASKA A~ OIL AND GAS CONSERVATION COf~SION REPORT OF SUNDRY WELL OPERATIONS c ~ ~- +~ RE~~~ 1PD MAY Z ~: ~fltl9 1. Operations Performed: '~iaska ~tI ~ Gas ~~~1 a, +.~OmmtSS10 ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Er~~d~ded 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 19Z-030 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22255-00-00- 7. KB Elevation (ft): 57, 9. Well Name and Number: PBU M-30 8. Property Designation: 10. Field /Pool(s): ADL 028257 ' Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 11480' ~ feet true vertical 9212' feet Plugs (measured) None Effective depth: measured 10958' feet Junk (measured) Unknown Depth true vertical 8788' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 3138' 13-3/8" 3138' 3015' 4930 2670 Intermediate 10715' 9-5/8" 10715' 8595' 6870 4760 Production Liner 1022' 7" 10458' - 11480' 8395' - 9212' 7240 5410 Perforation Depth MD (ft): 10874' - 10958' Perforation Depth TVD (ft): 8721' - 8788' 4-1/2", 12.6# x 5-1/2", 17# x 4-1/2", 12.6# L-80 10472' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 4-1/2" Baker'S-3' packer; -~ 10201'; 9-5/8" x 4-1/2" Baker'SAB' packer 10398' 12. Stimulation or cement squeeze summary: Intervals treated (measured): W~~,~ S~ ~ ~4_~*~ ` Treatment description including volumes used and final pressure: ~ ~ 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: ,f ^ Explora ry ~ Development LyJ Service ® Daily Report of Well Operations 16. Well Status after work ® Well Schematic Diagram ^ Oil ^ Gas AG ^ 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 Aras Worthington, 564-4102 309-071 Printed Name errie Hubble _ Title Drilling Technologist Prepared By Name/Number: 1 Si nature Phone 564-4628 Date Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~~ ~` ~ ~`` ~ ~'~~ ~~ j ~ ~~u~ebmit Original Only • M-30, Well History (Pre Rig Sidetrack) Date Summary 03/20/09 WELL SHUT IN ON ARRIVAL. SSV NEEDED HEAT IN ORDER TO FUNCTION (-38). API VLV. TECHS SERVICED AND INSPECTED SSV. CURRENTLY RIH W/ 2-1/2" IBP EO SLEEVE W/ 2" JUC. 03/21/09 PULL 2-1/2" IBP FROM 10390' SLM (recovered all elements & stiffener ring). DRIFT TBG W/ 4.50" GAUGE RING TO TOP OF DWP PATCH AT 6829' SLM. JAR ON 5-1/2" DWP AT 6829' SLM W/ .125 WIRE AT 2000# FOR TOTAL OF 5 HRS. CURRENTLY POOH W/ SHEARED TOOLS. 03/22/09 PULLED DWP PATCH FROM 6,829' SLM. UNABLE TO WORK PATCH PAST 6,288' SLM. PULL 5-1/2" PRT FROM 5-1/2" DWP PATCH AT 6,849' SLM. BRUSH AND FLUSH TBG W/ HOT DIESEL TO PATCH AT 6850' SLM. 03/22/09 T/I/0= 350/220/120 Temp= SI Assist Slickline with Brush-N-Flush (Pre RWO). Pumped 200 bbls (150 beneficial Reuse) 180°f diesel down Tbg while slickline RIH with brush. 03/23/09 LRS PUMPED 250 BBLS HOT DIESEL DOWN TBG. MADE 4 ATTEMPTS PULL 5-1/2" DWP PATCH (total jar time 5 hrs). SHEARED PRT LEFT PATCH IN STA# 6 AT 5,480 SLM. CURRENTLY JARRING ON PATCH AT 5480' SLM. 03/23/09 Assist Slickline with Brush-n-Flush (Pre RWO) Pumped 60 bbls (260 total) 180°F diesel down Tbg while Slickline RIH with brush. Final WHP's = 1100/980/260. Slickline on well at time of departure. 03/24/09 PULLED 5-1/2" DWP PATCH FROM SSSVLN @ 2088' SLM (.125" wire, 3hrs jar time). UPPER ELEMENTS INTACT, LOWER ELEMENTS MISSING. DRIFTED W/ 5-1/2"BLB ,3.70" WIRE GRAB TO DWP PATCH AT 7,448' SLM, (nothing recovered). DRIFTED W/ 5-1/2" BLB, 4.51" WIRE GRAB TO DWP PATCH AT 7448 'SLM (nothing recovered). CURRENTLY POOH W/TOOLS. 03/25/09 RAN 3.45" CENT, 3.0" LIB TO PATCH @ 7448' SLM (lib has inconclusive marks). DRIFTED TBG W/ 2- 1/2" BRUSH, 2.62" WIRE GRAB THROUGH PATCH TO 7500' SLM (no restrictions). RAN 4-1/2" GS TO AVA DWP PATCH @ 7440' SLM (5 hrs TOTAL JARRING). 03/26/09 RAN 4-1/2" GS TO AVA DWP PATCH @ 7440' SLM, (3 HRS TOTAL JARRING). RIG UP BRAIDED ILNE, JAR ON PATCH FOR ONE HOUR @ 7455' BLM. 03/27/09 RIH W/ 4-1/2" BL- BRUSH, 3.7" 3 PRONG W IRE GRAB TO 10550' SLM (NO RESTRICTIONS). RAN 5 1/2 BRUSH, XO, 3.7 3 PRONG GRAB, SAT DOWN @ 10,346' SLM. ALL CLEAR. RAN T.E.L., 4 1/2" BRUSH,3.7" 3 PRONG GRAB, TAGGED EOT @ 10,463 SLM,10,457 ELM. 6~ CORRECTION, TAGGED TD @ 10,946 CORRECTED, 12' OF PERFS COVERED. RAN 4.5" 2 PRONG GRAB, SAS Dam 10,346 SLM. ALL CLEAR, RDMO. LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OP. 04/10/09 TI0=60/300/90. SI. T&IA FL for EL (call in). TBG FL @ surface, IA FL @ 576' (31 bbls). SV, WV = C. SSV, MV = O. NOVP. 04/10/09 WELL S/I ON ARRIVAL. INITIAL WHP/IA/OA=25/300/80. 4.5" HALLIBURTON FASDRIL SET AT 10425' MID 10' PUP BELOW PKR. LRS CMIT x IA TO 4000 PSI. 04/11/09 LRS CMIT TUBING IA TO 4000 PSI, PASSED, AFTER 15 MINUTES T = 3900 PSI, IA 3920 PSI, AFTER 30 MINUTES T = 3880 PSI, IA 3900 PSI. 04/11/09 CMIT TXIA TO 4000 PSI PASSED. Pumped 31 bbls dsl to reach test pressure, bleed pressure down to 0. Final WHP = 0/250/80. IA/OA = OTG, E-line to continue well work. 04/12/09 5.5" TUBING CUT WITH 4.15" POWERCUTTER AT 10322'. WING, SWAB LEFT CLOSED. FUSEABLE CAP REPLACED ON SSV AND PRESSURE DUMPED. MASTER LEFT OPEN. ALL CASING GUAGES OPEN TO TREE. FINAL TBG/IA/OA = 0/180/80. JOB COMPLETED. 04/13/09 T/I/0= 0/260/80. Circ well to Seawater (Pre RWO). Pumped 6 bbls neat, 15 bbls diesel and 1035 bbls of 110° F seawater down the tubing with returns up the IA to well 25 flowline. Pumped a 5 bbl. neat spacer and 135 bbls of 120° F diesel down the tubing and U-Tubed to freeze protect TxIA. Freeze protect well 25 FL with crude recipie, CMIT TXIA in progress. Page 1 of 2 i • M-30, Well History (Pre Rig Sidetrack) Date Summary 04/14/09 .Finish CMIT TXIA TO 1000 psi PASSED. MIT OA to 1000 psi PASSED. Bled pressures to 0, rig down (swab closed, ssv closed, master open, annulus valves open to gauges. Operator notified of well status). 04/15/09 T/I/O=SSV/0/0, Temp=S1. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test port (100 psi), bled to 0 psi. Functioned LDS, 1 LDS is tight but moving, all the rest moved freely (1 "/ET style). 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: Stung into test port (0 psi). Functioned LDS all moved freely (1 "/ET style). 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. Page 2 of 2 • BP EXPLORATION Operations Summary Report Page 1 of 6 ~ :Legal Well Name: M-30 Common Well Name: M-30 Spud Date: 3/18/1992 Event Name: WORKOVER Start: 4/16/2009 End: 4/30/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/26/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/17/2009 03:00 - 06:00 3.00 MOB N WAIT PRE Rig Service, General Maintenance with waiting on Well Prep on M-30 06:00 - 18:00 12.00 MOB N WAIT PRE Clean and inspect Rig Pits. Repalce wear pads on Drawworks drum. Continue with general cleaning and painting. 18:00 - 00:00 6.00 MOB N WAIT PRE General cleaning and painting. Move pipe bunks and storage trailers to M-pad. 4/18/2009 00:00 - 03:00 3.00 MOB N WAIT PRE General cleaning and painting. Move pipe bunks and storage trailers to M-pad. 03:00 - 04:00 1.00 MOB N WAIT PRE Hold weekly safety meeting Rig Crew, discussed hand safety 04:00 - 06:00 2.00 MOB N 06:00 - 11:00 5.00 MOB N 11:00 - 12:00 1.00 RIGD P 12:00 - 15:30 3.50 RIGD P 15:30 - 19:30 4.00 MOB P 19:30 - 20:30 1.00 MOB P 20:30 - 22:00 22:00 - 00:00 4/19/2009 00:00 - 02:00 1.50 MOB P 2.00 MOB P 2.00 KILL P 02:00 - 03:00 03:00 - 03:30 03:30 - 06:00 06:00 - 09:00 09:00 - 10:30 10:30 - 14:00 14:00 - 17:30 17:30 - 18:00 18:00 - 18:30 18:30 - 23:00 23:00 - 00:00 4/20/2009 00:00 - 01:00 1.00 KILL P 0.50 KILL P 2.50 KILL P 3.00 KILL P 1.50 WHSUR P 3.50 WHSUR P 3.50 BOPSU P 0.50 BOPSU P 0.50 BOPSU P 4.50 BOPSU P 1.00 BOPSU~ P 1.00 PULL P and use of impact gloves. Discussed vehicle safety and recent vehicle accidents. Reviewed permits and prejob forms. WAIT PRE General cleaning and painting. WAIT PRE Continue with general cleaning and painting. Hold Weekly Safety Meeting with day rig Crew. PRE Prep Rig and Modules to rig down. PRE Lower and scope down Derrick. Rig down Pipe Shed, Pits and Camp. Prep to move off location. Pull Sub Base off of Well Slot and prep to move off location. PRE Move Ri and Modules from F-Pad to M-Pad. PRE Spot tree and adaptor flange behind cellar. ay herculite and mats around wellhead. Spot sub over M-30. BP WSL and Pad operator present while spotting sub. PRE Spot and level pipe shed and pits. PRE Raise mast off of carrier, scope up mast and pin. DECOMP R/U secondary annulus valve on IA, R/U circulating lines to well and return lines to tiger tank. Rig accepted at 00:00 hours on 4/19/2009. DECOMP R/U DSM lubricator and pressure test to 500 psi, pull Cameron t e J BPV. 0 psi on IA and Tubing. UD lubricator. DECOMP Test return line to tiger tank to 1,000 psi ans circulating line to 3,500 psi. DECOMP Pump 140 degree seawater down the tubing taking returns out the IA through the choke to the tiger tank. 4 bpm at 360 psi. DECOMP ell. Monitor well dead. DECOMP S t st TWCV at 1000 si from below and 4,000 si from above x 10 minutes each. Record both tests on chart. DECOMP PJSM. Bleed Tree void. Nipple down Injection Tree. Check NSCC Hanger threads (9.1/2 turns). Good. DECOMP PJSM. Nipple up BOP stack. DECOMP R/U test assemblys. DECOMP Crew change, rig service, set and test PVT's DECOMP Test blind rams, 3-1/2" x 6" VBR's, choke manifold, floor valves, manual kill and choke valves, HCR kill and choke valves, Kelly valves to 250 psi low and 4,000 psi high, hold each test for 5 minutes on the chart, used 3-1/2" and 5-1/2" test joints. Test annular to 250 psi low and 3,500 psi with 3-1/2" test joint, hold each test for 5 minutes on the chart. Perform Koomey drawdown test. AOGCC witness of BOP test was waived by Jeff Jones. Test was witnessed by BP WSL and Nabors Tourpusher. DECOMP R/U DSM lubricator and test to 500 psi, Pull Cameron type J TWC. 0 si on tubing and IA. DECOMP M/U landing joint, screw 7" NSCC XO into hanger 9-3/4 turns. Printed: 5/4/2009 11:43:46 AM • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: M-30 Common Well Name: M-30 Spud Date: 3/18/1992 Event Name: WORKOVER Start: 4/16/2009 End: 4/30/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/26/2009 Rig Name: NABORS 4ES Rig Number: Date ~ From - To Hours.. Task Code I, NPT ' Phase Description-of Operations 4/20/2009 01:00 - 02:00 1.00 PULL N DPRB DECOMP Attem t to ull 5-1/2" L-80, LTC tubing. Hanger came off seat at 145K, Strin would not ull. Work string up to 265K. Discuss options with Anchorage well engineer. 02:00 - 06:00 4.00 PULL N DPRB DECOMP Work tubing string while working pump up to 5 bpm with 320 psi. No movement in tubing string. Tubing string should weigh 153K + blocks. Call out SWS E-line for second jet cut. 06:00 - 10:00 4.00 PULL N DPRB DECOMP Continue to wait on SWS E-Line Unit to arrive on location. Install Dutch System. Spot SWS E-Line Unit. Bring tools to rig floor. 10:00 - 15:00 5.00 PULL N DPRB DECOMP PJSM. Rig up E-Line. Trouble shoot cable head. Install SWS Lubricator. Test lubricator at 500 psi. Had an O-ring failure. Replace same and re-test at 500 si. Good test. 15:00 - 16:00 1.00 PULL N DPRB DECOMP Run in with 4.125" Jet cutter. Tie into GLM at 10,254' - 10,263'. Also saw jet cut at 10, 321. Position CCL at 10,314.4 and jet cutter at 10,326'. Fire cutter. Good 16:00 - 17:00 1.00 PULL N DPRB DECOMP Pull out with jet cutter tool string. 17:00 - 18:00 1.00 PULL N DPRB DECOMP R/D lubricator and set aside. Remove a-line sheaves and set aside. 18:00 - 18:30 0.50 PULL N DPRB DECOMP Crew change, rig service, derrick inspection, set and test PVT's 18:30 - 19:00 0.50 PULL N DPRB DECOMP R/D Dutch system lubricator and P/U landing joint, screw XO into hanger 9-3/4 turns. 19:00 - 19:30 0.50 PULL P 19:30 - 21:30 2.00 PULL P 21:30 - 00:00 2.50 PULL P 4/21/2009 00:00 - 00:30 0.50 PULL P 00:30 - 06:00 5.50 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 11:00 4.50 PULL P 11:00 - 13:00 13:00 - 14:00 14:00 - 16:00 2.00 PULL P 1.00 CLEAN P 2.00 CLEAN P 16:00 - 18:00 I 2.001 CLEAN I P DECOMP I Pull hanoer to rip floor,. hanger came off seat at 140K, string came free at 188K. Up weight 165-175K. DECOMP UD hanger, M/U circulating head and circulate bottoms up at 5 bpm with 200 psi. Remove a-line equipment from rig floor, R/U control line spooler. DECOMP POOH la in down 5-1/2" L-80, LTC com letion and control line. Pipe appears to be in good condition with some pitting / corrosion in pin and box. Encapsulation on dual control line was intact. DECOMP UD SSSV assembly, R/D control line spooler and remove from rig floor. Recovered 26 clamps and 3 stainless steel bands. DECOMP POOH laying down 5-1/2", L-80, LTC completion. Pipe appears to be in good condition with some pitting /corrosion in pin and box. DECOMP Crew change. Service rig. Perform PVT checks. Inspect Derrick. DECOMP Finish lay down 5 1/2" L-80 Completion. Several collars near the end of the completion were almost "rotted through". (threads s owing . ecovere the following: 243 total joints, Cut-Off joint, 7 ea GLM assemblies, OTIS BVN (SSSV). The 5 1/2" Cut-Off Stub = 14.88'. Jet cut flare = 6 5/8" OD. The original jet cut attempt only "bulged" the tube. It was 5' feet above the second successful cut. DECOMP Rig down 5 1/2" handling equipment. Clear and clean floor. Rig up 3 1/2" Drill Pipe equipment. DECOMP Install wear Bushing. Bring BHA #1 to Rig floor. DECOMP Make-u BHA #1 er Baker Fisherman as follows: 8 1/2" x 5 9/16" Dress-Off shoe, W P Ext, W P Ext, W P Ext, Dress-Off Mill, WO oot Basket, Double Pin XO, 9 5/8" Scraper, Bit sub, Bumper sub, Drill collars, Pump-Out Sub. DECOMP Single in with BHA #1 and 3 1/2" Drill Pipe from Pipe Shed. Printed: 5/4/2009 11:43:46 AM • • BP EXPLORATION Operations Summary Report Page 3 of 6 ~ Legal Well Name: M-30 Common W ell Name: M-30 Spud Date: 3/18/1992 Event Nam e: WORKO VER Start : 4/16/2009 End: 4/30/2009 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 4/26/2009 Rig Name: NABOB S 4ES Rig Number: Date ,From - To ~', Hours ' Task Code NPT Phase Description of Operations - -- 4/21/2009 18:00 - 18:30 0.50 CLEAN P DECOMP __ __ _ Crew change. Service Rig. Check PVT Alarms. Inspect Derrick. 18:30 - 00:00 5.50 CLEAN P DECOMP RIH with BHA #1 on 3-1/2" DP from Pipe Shed. 200-jts of 3-1/2" DP RIH at 2245-hrs. 4/22/2009 00:00 - 01:00 1.00 CLEAN P DECOMP RIH with BHA #1 on 3-1/2" DP from pipe shed. 01:00 - 02:00 1.00 CLEAN P DECOMP PU jt #322 and tag tubing stump at 10,312'. LD jt #322. PU & MU 10' pup jt and Kelly. Obtain parameters: PU wt = 160K, SO wt = 118K, Rot wt = 132K. Rotate at 50-RPM, 4300-ft-Ibs of free torque. Stage pumps up to 5-BPM with 1300-psi. RIH and retag tubing stump at 10,312'. 02:00 - 06:00 4.00 CLEAN P DECOMP Dress off tubing stump with 3-BPM with 500-psi and 55-RPM wi etween 3500 an 7000-ft-Ibs of free torque, running 5-7K-Ibs WOB. After milling 1', WOB drops off and able to mill down to internal mill at 10,329'. Attempt to PU off of stump and pull -30K-Ibs over PU wt. Resume dressing stump and work BHA down until internal mill tags at same location as before. PU off of stump and,able to come free with 25K-Ibs overpull. Resume dressing off stump. 06:00 - 06:30 0.50 CLEAN P DECOMP ~ i h dressin off 5 1/2" Stum No over ull. 'Clean. 06:30 - 09:00 2.50 CLEAN P DECOMP Pump 20 bbls Hi-Vis Sweep and circulate back to surface at 5.0 bpm/1500 psi. 09:00 - 09:30 0.50 CLEAN P DECOMP Service Rig. Inspect Derrick. Check PVT Alarms. 09:30 - 13:00 3.50 CLEAN P DECOMP Trip out with 3 1/2" Drill Pipe standing back in Derrick and BHA #1 13:00 - 15:30 2.50 CLEAN P DECOMP Lay down BHA #1. Inspect Shoe and Mill. Both indicated normal wear patterns. Clear floor. Recover -2-gallons of schmoo and metal millings from boot basket. 15:30 - 17:30 2.00 WHSUR P DECOMP Pull Wear Bushing. Clear and clean floor. 17:30 - 18:00 0.50 WHSUR P DECOMP Make up Pack-Off Pulling Tool. BOLDS. Pull 9 5/8" Pack-Off (came free at 35K). 18:00 - 19:00 1.00 WHSUR P DECOMP Install new 9 5/8" Pack-Off. RILDS. Test Pack-Off at 5,000 psi x 30 minutes. good test. 19:00 - 19:30 0.50 WHSUR P DECOMP Service rig. Inspect Derrick. Check PVT Alarms. 19:30 - 20:00 0.50 WHSUR P DECOMP Install Wear Bushing. 20:00 - 22:00 2.00 CLEAN P DECOMP PJSM. Make up BHA #2 as follows: Before Shear Out = 8 1/8" Cut-Lip Guide, Extention, XO Bushing, Shear Pin Guide, 6 Jts 2 7/8" PAC Drill Pipe XO, Bumper Sub, 4 3/4" Drill Collars, Pump Out Sub. After Shear Out = 3 5/8" Bladed Junk MITI, Shear Pin Guide, 6 Jts of 2 7/8" PAC Drill Plpe, XO, Bumper sub, 4 3/4" Drill Collars, Pump-Out Sub. 22:00 - 00:00 2.00 CLEAN P DECOMP RIH with BHA #2 on 3-1/2" DP from derrick. Fill pipe every 20-stds RIH. 4/23/2009 00:00 - 02:00 2.00 CLEAN P DECOMP RIH with BHA #2 on 3-1/2" DP from Derrick, filling pipe every 20-stds. RIH to 9812' (100-stds plus BHA). 02:00 - 06:00 4.00 CLEAN P DECOMP Hold PJSM on strapping and drifting tubing with rig crew, BP WSL and Nabors Tourpusher. Finish strapping and drifting 4-1/2" L80 TC-II tubing and completion jewelry in pipe shed. Circulate while strapping and drifting at 2-BPM with 300-psi. 06:00 - 07:00 1.00 CLEAN P DECOMP Service rig. Inspect Derrick. Check PVT Alarms. Perform initial Jewelry inspection. Good. 07:00 - 13:30 6.50 CLEAN P DECOMP Finish Trip in to top of the 5 1/2" Tubing Stump. Swallow tump and shear pins in Shear Pin Guide. Enter 4 1/2" Tubing Tail. Paramenters as follows Pump Rate = 4.0 bpm/1000 psi. Printed: 5/4/2009 11:43:46 AM • • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: M-30 Common W ell Name: M-30 Spud Date: 3/18/1992 Event Nam e: WORKO VER Start : 4/16/2009 End: 4/30/2009 Contractor Name: NABOB S ALAS KA DRI LLING I Rig Release: 4/26/2009 Rig Name: NABOB S 4ES Rig Number: Date From - To Hours ~ Task li, Code NPT ~ Phase. . Description of Operations 4/23/2009 07:00 - 13:30 6.50 CLEAN P DECOMP RMPs = 40 - 60. Free Torque = 4200 ft/Ibs. Drilling Torque = 7300 - 7500 fUlbs. PUW = 152K. SOW = 119K. ROTW = 133K. Tag Fas-Drill Plug at 10, 410' dd. Start to drill up Plug. -Acts like there is trash on to of Plu .Drill and ush Plu all the wa to the Tubin Tail at 10,472 and where it fell awa . Continue out TT with Mill until XO in fishing string lightly no-goes on the top of the 5 1/2" Stump. Final Mill depth = 10,504' dd. Once Plug fell, the Well not taking the "big" expected drin . 13:30 - 17:30 4.00 CLEAN P DECOMP Pull Mill back inside Tubing Tail and continue to pull above the 5 1/2" Stump with no problems. Bring Pump on line at 4.0 by/1160 psi. Fluid loss at 6 b~ Discuss lack of fluid loss with Anchorage ngineering. Continue with planned program. Circulate Well clean. Saw some gas at bottoms up. 17:30 - 18:00 0.50 CLEAN P DECOMP Begin POH with BHA #2. LD 3-1/2" DP to pipe shed. 18:00 - 18:30 0.50 CLEAN P DECOMP Service Rig. Inspect Derrick. Check PVT alarms. Perform pre-tour checks. 18:30 - 00:00 5.50 CLEAN P DECOMP Continue to POH with BHA #2. LD DP to i e shed. 100-jts of 3-1/2" DP laid down at 2000-hrs. 265-jts laid down at 2300-hrs. Maintain continuous hole fill. Fluid loss = 4-BPH while POH. 4/24/2009 00:00 - 00:30 0.50 CLEAN P DECOMP Hold PJSM with rig crew on LD BHA #2. Discuss hazards, order of breaking down tools, pipe shed safety and BP weight limitation. 00:30 - 02:00 1.50 CLEAN P DECOMP LD BHA #2 to pipe shed. 02:00 - 03:00 1.00 BUNCO P RUNCMP PU 24' pup jt and pull wear bushing. 03:00 - 05:00 2.00 BUNCO P RUNCMP Clean and clear rig floor of all Baker tools and un-necessary equipment. LD pipe spinners through pipe shed. 05:00 - 07:00 2.00 BUNCO P RUNCMP Bring all torque turn and pipe handling equipment to rig floor through pipe shed. RU to run 4-1/2" 12.6# L80 TC-II completion: power tongs, torque turn equipment, s abbing board. 07:00 - 18:00 11.00 BUNCO P RUNCMP Run 4-1/2" 12.6# L80 TC-II completion with 9-5/8" x 5-1/2" Unique Overshot, 5-1/2" x 4-1/2" XO, 3(ea) 4-1/2" X Nipples, and 9-5/8" x 4-1/2" Baker S-3 Packer. Use torque turn services to MU each TC-ll connection to 3850-Ibs-ft optimal torque. BakerLok all joints below packer. Use Jet Lube Seal Guard thread compound on each connection. Maintain continuous hole fill while running completion. 18:00 - 18:30 0.50 BUNCO P RUNCMP Perform pre-tour checks. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 23:00 4.50 BUNCO P RUNCMP Run 4-1/2" 12.6# L80 TC-II completion with 9-5/8" x 5-1/2" Unique Overshot, 5-1/2" x 4-1/2" XO, 3(ea) 4-1/2" X Nipples, and 9-5/8" x 4-1/2" Baker S-3 Packer. Use torque turn services to MU each TC-II connection to 3850-Ibs-ft optimal torque. Use Jet Lube Seal Guard thread compound on each connection. Maintain continuous hole fill while running completion. Replace jt #203 with Jt #247 (bad box). Run a total of 241-jts of 4-1/2" Tbg. 23:00 - 00:00 1.00 BUNCO P RUNCMP PU jt #242 and #243. RIH. Tag something at 10,316'. Set down 8K-Ibs and continue RIH. Tag again at 10,320'. Set down 12K-Ibs and continue RIH. No-go at 10,324'. PU above initial tag and RIH to confirm No-go. No-go in same location. LD jts 243 and 242. Calculate space-out. Decide to PU 9.99', Printed: 5/4/2009 11:43:46 AM . • • BP EXPLORATION Operations Summary Report Page 5 of 6 ~ Legal Well Name: M-30 Common Well Name: M-30 Spud Date: 3/18/1992 Event Name: WORKOVER Start: 4/16/2009 End: 4/30/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/26/2009 Rig Name: NABOBS 4ES Rig Number: Date From - To ', Hours Task Code NPT Phase Description of Operations 4/24/2009 23:00 - 00:00 1.00 BUNCO P RUNCMP 7.81', and 3.75' space out pups to give 5.5' of swallow. 4/25/2009 00:00 - 01:00 1.00 BUNCO P RUNCMP MU tubing space out pups, Jt #241 and tubing hanger using torque turn equipment. 01:00 - 02:00 1.00 BUNCO P RUNCMP PU wt = 113K-Ibs, SO wt = 94K-Ibs. Land tubing hanger. FMC tech RILDS. LD landing jt. 02:00 - 02:30 0.50 BUNCO P RUNCMP Attempt to reverse in 120-degree Seawater. Unable to circulate. Discuss situation with RWO engineer. Decide to unland completion and attempt to establish circulation. 02:30 - 03:00 0.50 BUNCO P RUNCMP PU & MU landing jt to tubing hanger. FMC tech BOLDS. 03:00 - 04:00 1.00 BUNCO P RUNCMP PU 4' (-2' of swallow with OS) and attempt to reverse -unable. PU 6' (OS at stump) and attempt to reverse -unable. PU 9' (off of stump w/ OS) and attempt to reverse -unable. Pump and able to reverse. RIH to OS at stump and reverse at 2-BPN with 500-psi. Continue RIH, washing ahead, seeing pressure increase to 800-psi with same pump rate. Pack-off at 4.5' of swallow with OS. 04:00 - 05:00 1.00 BUNCO P RUNCMP Discuss situation with RWO engineer, BP WSLs, Baker packer rep and Nabors tourpusher. Decide to land completion, RU Slickline to drift to confirm tubing continuity with current space out and then continue with circulation. 05:00 - 05:30 0.50 BUNCO P RUNCMP Land tubing hanger and RILDS. LD landing jt. 05:30 - 06:00 0.50 BUNCO DPRB RUNCMP Wait on Slickline. 06:00 - 07:00 1.00 BUNCO DPRB RUNCMP Service Rig. Inspect Derrick. Check PVT Alarms. 07:00 - 11:00 4.00 BUNCO DPRB RUNCMP Continue to wait on S-Line Unit to complete their job that is in progress. 11:00 - 13:00 2.00 BUNCO DPRB RUNCMP PJSM with All. Spot Unit. Rig up S-line. 13:00 - 15:30 2.50 BUNCO DPRB RUNCMP Run in hole with 4 1/2" GS Pulling Tool. Latch Plug at 10,239' dmd. Pull Plug free. ( ote: held Weekly Safety Meeting for day rig Crew while on-going S-line operations). (Inspect and install new packing on RHC-M Plug). 15:30 - 18:00 2.50 BUNCO DPRB RUNCMP Run in hole with a 3.625" Tapered Swedge. Passed through the Unique Overshot/Tubing Stump over-lap at 10,313' several times. Drop down through the 4 1/2" Tubing Tail and out the WLEG at 10,472 md. Stop Tapered Swedge at 10, 525'. Pull back through WLEG with no problems. Had to make several attempts to pull back through the SWN Nipple at 10, 460' md. Continue POOH with no further problems. 18:00 - 21:00 3.00 BUNCO DPRB RUNCMP Schlumberger Slickline RIH with re-dressed RHC-M plug body.( While RIH, Rig crew perform pre-tour checks. Service rig. Check PVT alarms.) Have to tap plug and packing through X-nipple above packer. Continue RIH & Set RHC-M plug in X-nipple below packer. Pull test to confirm RHC-M is set - good test. Shear off of RHC-M and POH. 21:00 - 22:00 1.00 BUNCO DPRB RUNCMP Hold PJSM with Schlumberger and rig crew on RD slickline. RD Schlumberger slickline. LD Dutch lubricator system. 22:00 - 22:30 0.50 BUNCO DPRB RUNCMP PU landing jt and MU to tubing hanger. BOLDS. Pull hanger to floor. Took 125K-Ibs to pull hanger off seat and then PU wt = 114K-Ibs. FMC tech inspect hanger -Good condition with no damage to seals. Run hanger back in hole to just below annular preventer. Close annular. 22:30 - 00:00 1.50 BUNCO P RUNCMP Reverse in 125-bbls of 120-degree seawater followed by 450-bbls of 120-degree seawater treated with EC1124A Printed: 5/4/2009 11:43:46 AM • BP EXPLORATION Page 6 of 6 ~ Operations Summary Report Legal Well Name: M-30 Common Well Name: M-30 Spud Date: 3/18/1992 Event Name: WORKOVER Start: 4/16/2009 End: 4/30/2009 Contractor Name: NABOBS ALAS KA DRI LLING I Rig Release: 4/26/2009 'Rig Name: NABOBS 4ES Rig Number: Date i From - To Hours Task Code NPT I Phase Description of Operations 4/25/2009 22:30 - 00:00 1.50 BUNCO P RUNCMP corrosion inhibitor at 3-BPM with 170-psi. 4/26/2009 00:00 - 02:30 2.50 BUNCO P RUNCMP Continue to reverse in 125-bbls of 120-degree seawater followed by 450-bbls of 120-degree seawater treated with EC1124A corrosion inhibitor. Circulate at 3-BPM with 160-psi. Spot LRS hot oil unit in preparation for freeze protecting while circulating packer fluid. 02:30 - 03:00 0.50 BUNCO RUNCMP PJSM with LRS and PT lines to 3500-psi. Good test. 03:00 - 04:30 1.50 BUNCO P RUNCMP LRS reverse in 125-bbls of 80-degree diesel for IA freeze protection. Pump at 2-BPM with 200-psi. 04:30 - 05:00 0.50 BUNCO P RUNCMP Land tubin han er. Shut-in annulus. RILDS. LD landing joint. 05:00 - 06:00 1.00 BUNCO RUNCMP LRS bullhead down tubing with 33-bbls of 80-degree diesel for tubing freeze protection. Pump at 1/2-BPM with 400-psi. 06:00 - 07:00 1.00 BUNCO RUNCMP Finish Freeze Protecting Tubing. Service Rig. Inspect Derrick. Finish cleaning Pits (no PVT alarms checks). 07:00 - 10:45 3.75 BUNCO P RUNCMP Pick up Landing Joint. Drop Packer setting Ball/Rod. Lay down Landing Joint. Lil' Red pressure up on tubing to 4,000 psi with diesel. Record on Chart x 30 minutes. Good test. Bleed back tubing to 1,500 psi and block in. Pressure up on 10:45 - 11:30 0.75 BUNCO P RUNCMP Record on Chart x 30 minutes. Good test. Bleed pressure from annulus to 0 psi. Bleed pressure from tubing to 0 psi. FMC Serviceman install TWCV. Pressure test TWCV from above to 3,500 psi. Record on Chart x 10 minutes. Unable to test from below due to Well completed as an Injector. Suck back BOP Stack and lines. Rig down Lil' Red. 11:30 - 14:00 2.50 BOPSU P RUNCMP Nipple down BOP and set back on stump. 14:00 - 17:30 3.50 WHSUR P RUNCMP NU tubinghead adapter flange and 4-1/8" production tree. FMC tech test adapter flange to 5000-psi for 30-minutes -good test. Test production tree to 5000-psi for 10-minutes -good test. 17:30 - 18:00 0.50 WHSUR P RUNCMP Install all jewelry on tree & Secure well. "Release Rig at 1800-hrs" Printed: 5/4/2009 11:43:46 AM TREE _ WELLHEAD = ACTUATOR = OTIS KB. ELEV - 57.00' BF. ELEV - 26.00' KOP = 1500' Max Angle = 52° @ 4505' Datum MD = 11045' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 3138' Minimum ID = 3.725" @ 10460' 4-1/2" SWN NIPPLE 4-1/2" TBG, 12.6#, L-80 TCII, 10305' .0152 bpf, ID = 3.958" 5-1/2" TBG STUB (04/21/09) 10312' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10353' TOP OF 7" LNR ~~ 10458' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10472' 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" 10715' PERFORATION SUMMARY REF LOG: SWS-BHCS ON 04/03/92; SWS GR/CCL ON 04/24/92 ANGLE AT TOP PERF: 39° @ 10874' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10874 - 10922 O 09/27/92 3-3/8" 4 10927 - 10958 O 04/25/92 3-3/8" 4 10958 - 10978 S 09/02/99 3-3/8" 4 10982 - 11010 S 09/02/99 3-3/8" 4 11022 - 11054 S 09/02/99 3-3/8" 4 11170 - 11220 S 09/02/99 PBTD ~ 11398, 7" LNR, 26#, 13CR-N80 NSCC, .0383 bpf, ID = 6.276" 11480' M -~ O S TES:***7" CHROME LNR*** 2198' I-I4-1/2" HES X NIP, ID = 3.813" 10170' ~I4-1/2" HES X NIP, ID = 3.813" 10201' ~ 9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.87" 10235' 4-1/2" HES X NIP, ID = 3.813" 10305' 4-1/2" X 5-1/2 XO = 3.943" 10316' 9-5/8"X5-1/2"UNIQUEOVERSHOT 10353' 5-1/2" X 4-1/2" XO, ID = 3.958" 10375' 4-1/2" PKR SWS NIP, ID = 3.813" 10398' _ 9-5/8" X 4-1/2" BKR SAB PKR, ID = 4.75" 10440' 4-1/2" PKR SWS NIP, ID = 3.813" 10458' 9-5/8" X 7" BKR LTP & HGR, ID = ? 10460' 4-1/2" PKR SWN NIP, ID = 3.725" 10472' 4-1/2" WLEG, ID = 3.958" 10457' ELMD TT LOGGED 11/23/00 ~~ FISH -DEBRIS FROM PATCH (03/27/09) 10958' I~ TOP OF CEMENT CAP 10995' TOP OF SAND 10992' CARBOLffE? DATE REV BY COMMENTS DATE REV BY COMMENTS 04/06/92 ML ORIGINAL COMPLETION 04/26/09 N4ES RWO 05/05/09 ?/JMD DRLG DRAFT CORRECTIONS CNV FMC PRUDHOE BAY UNff WELL: M-30 PERMfr No: '1920300 API No: 50-029-22255-00 SEC 1, T11N, R12E, 2234' FSL & 606' FEL BP Exploration (Alaska) • ~~ a ~ ~ -- ~ ~-g o SARAH PAL1N, GOVERNOR ~ i ~ L+~ OI~ ~ ~ 333 W. 7th AVENUE, SUITE 100 t~itt's-7 ANCHORAGE, ALASKA 99501-3539 COAT5ER~ATI01~ CODIlrIISSIOI~T PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 °~~°'~'~'~ ~~~ ~' ~ ~~~~ Anchorage AK 99519-6612 J ~ ~ V Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBIJ M-30 ` ~~,, Sundry Number: 309-071 ~ \ 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 alter 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 Conunissioil 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 holidayoorCourt ur? s P rehearing hasa bP en a Commission decision to Supen requested. Sincerely, ~~~G/ Daniel T. Se~~mount, Jr. Chair DATED this~day of February, 2009 Encl. .~~01 n ~' ~~ ~~ ~j~~ ~ STATE OF ALASKA _ _ ~ ~' ,,~ ('~ " ~ ~~('~ ALA OIL AND GAS CONSERVATION C011~SION ~~~ ~ ti APPLICATION FOR SUNDRY APPROVAL ~a~~~ FEQ ~ ~~ 4~,,,!~ 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ a;i 181'~tp. Lr9)f~1f11 ~~ ^ Alter Casing ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Sus~A&~~~ ^ 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 192-030 3. Address: ®Service ~ ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22255-00-00 - 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 M-30 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): _ ADL 028257 ~ 57' 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): 11480' - 9212' 10958' 8788' 10424' None in n h iz MD TV ur Ila s r ral n o r 11 1 11 ' urface 138' 1 - /8" 1 3015' 4930 2670 Interm diate 1 71 9-5/8" 1071 595' 6870 47 0 Pr i n Liner 1 22' 7" 104 ' - 11480' 395' - 9 12' 7240 541 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 10874' - 10958' 8721' - 8788' S-1/2", 17# x 4-1/2", 12.6# L-80 10472' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 10398' 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: May 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ®WINJ ^ WDSPL Commission Representative: 18. I hereby certify at the foregoing is true and correct to the best of my knowledge. Contact Aras Worthington, 564-4102 Printed Nam vi ' ee Title Engineering Team Leader Prepared By Name/Number. Signature Phone 564-5743 Date ~ X20 ~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~y~~ ~~ ~~ ,~~ ^ Plug Integrity BOP Test Mechanical Integrity Test ^ Location Clearance ~~~ Other: 1~-~~Oo~s~ ~~`~5~ i ~S~C~~ ~ ~\v\iv"v °h-~ Gt~t~~ Y~'~~5 Subsequent Form Required: `+-~~~-.` G; APPROVED BY ~ ~ ~ ~ J A roved B COMMISSIONER THE COMMISSION Date JJJ / Form 10-403 R~sa~H 06/2006 Submit In Duplicate h .. :: , ~ ~. Ft<~ ~ ~~ 2004 • M-30i Rig Workover Scope of Work: Cut & Pull 5-1/2" L-80 completion, change out 9-5/8" casing packoffs, Run new 4-1/2" L- 80 completion. MASP: 2300 psi Well Type: Injector Estimated Start Date: May, 2009 Intervention Engineer: Aras Worthington Pad Engineer: Don Brown Pre-Rip Work Request: S 1 Pull AVA-DWP "retrievable" patches @ 6825' MD and 7445' MD. Pull IBP @ 10,424' MD. S 2 Drift tubin for 5-1/2" Jet Cutter & 4 1/2" Fasdrill lu thru tb tail to 10,500' E 3 Set Fasdrill composite plug @ 10,425' MD (reference tbg tally 4/6/1992) in the middle of the first 10' pup joint below the production packer. CMIT TxIA to 4000 psi to verify ood lu set and PC inte rit . E 4 Jet Cut 5-1/2" 17# L-80 Tubing at 10,322' MD (reference tbg tally 4/6/1992) in the u er 10' of the first full ~oint above the roduction acker. F 5 Circulate well through the cut with seawater (8.6ppg) and diesel freeze protect to 2000' MD. CMIT TxIA to 1000 psi to verify Fasdrill plug's integrity for use as a barrier post-tbg cut. MITOA to 1000 si. W 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 7 Set BPV in the tubin han er. O 8 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 4ES. Circulate out freeze protection fluid with sea water through the cut. ND tree. NU and test BOPE to 250 psi low, 4000 psi high. 2. Pull and LD 5-1 /2" tubing string. 3. Change out 9-5/8" Casing packoffs through the stack. 4. Dress-off 5'/2' tbg stub. 5. Run new 4-1/2" L-80 premium thread stacker-packer completion with packer at 10,200' MD. 6. Displace the IA to packer fluid and set the packer. 7. Test Tubing & IA to 4000 psi. 8. Set TWC. ND BOPE. NU and test tree. Pull TWC, freeze protect to 2200' MD. Set BPV. RDMO. TREE = 6" CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 57.00' BF. ELEV = 26.00' KOP= 1817` Max Angle = 45 @ 7134' Datum MD = 11038' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80-BTRS, ID = 12.347" ~ M-30 Minimum ID = 2.992" @ 6825' 5-1/2" AVA DWP RETRIEVE PATCH 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I~ 10353' TOP OF 7" LNR ~-j 10458, 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10472' 9-5/8" CSG, 47#, L-80, ID = 8.681" 10715' PERFORATION SUMMARY REF LOG: SWS-BRCS ON 04/03/92; SWS GR/CCL ON 04/24/92 ANGLE AT TOPPERF: 39 @ 10874' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10874 - 10922 C 09/27/92 3-3/8" 4 10927 - 10958 C 04/25/92 3-3/8" 4 10958 - 10978 S 09/02/99 3-3/8" 4 10982 - 11010 S 09/02/99 3-3/8" 4 11022 - 11054 S 09/02/99 3-3/8" 4 11170 - 11220 S 09/02/99 PBTD 7" TBG, 26#, .0383 bpf, ID = 6.276" I 11480' I 5-1/2" OTIS HRO SSSV LAND NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3135 2964 39 OTIS RA 6 5507 4622 41 OTIS RA 5 7218 5908 44 OTIS RA 4 8441 6787 43 OTIS RA 3 9308 7429 40 OTIS RA 2 9856 7849 39 OTIS RA 1 10254 8165 39 OTIS RA 6825' 5-1/2" X 20' AVA-DWP RETR PATCH, ID = 2.992" 7445' I_J5-1/2" X 20' AVA-DWP RETRIPATCH, !D = 2.992" 10353' -~5-1/2° x a-v2" xo ~ 10375' 4-1 /2" PKR SWS NIP, ID = 3.813" 10398' 9-5/8" X 4-1/2" BKR SAB PKR, ID = 4.75" 10424' 2-1/2" BKR IBP (11/29/07) 10440' 4-1/2" PKR SWS NIP, ID = 3.813" 10460' 4-1/2" PKR SWN NIP, ID = 3.725" 10472' 4-1/2" PKR WLEG, ID = 3.958" 10457' ELMD TT LOGGED 11/23/00 10958' ~~TOP OF CEMENT CAP 10995' TOP OF SAND CARBOLffE DATE REV BY COMMENTS DATE REV BY COMMENTS 04/06/92 M L ORIGINAL COM PLE71ON 12/15/07 TEL/PJC SET IBP @ 10424' (11/29/07) 12/15/05 TWS/PJC PULL IBP @ 10399' 01/10/06 EZL/PJC WAIVERSFTY NOTE (12/31/05) 11/12/06 JMF/PJC SET BKR IBP @ 10406' 02/10/07 JCMIPAG PULL IBP @ 10413' (12/22/06) 11/11/07 RDW/SV WANER SFTY NOTE DELETED PRUDHOE BAY UNfT WELL: M-30 PERMff No: "1920300 API No: 50-029-22255-00 SEC 1, T11 N, R12E, 2233' SNL & 606' WEL BP Exploration (Alaska) TREE a clw WELLHtrAD = FMC ACTUATOR = OTIS MB. ELEV = 57.00' BF. ELEV = 26.00' KOP= 1817' Max Angle = 45 @ 7134' Datum MD = 11038' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80-BTRS, ID = 12.347" H 3138' 14-1/2" HES X-Niaale. ~ = 3.813" Minimum ID = 3.725" @ 10,460' 4-1/2" SWN NIPPLE 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958 4 1/2" FES X-Nipple, ID = 3.813" 9 5/8" X 4 1/2" S-3 Baker Packer 4 1 /2" HES X Nipple, ID = 3.813" 9 5/8" X 5-1/2" Unique Overshot 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 10353' 14353' 5-1/2" X 4-1/2" XO 10375' 4-1/2" PKR SWS NIP, ~ = 3.813" 10398' 9-5/8" X 4-1/2" BKR SAB PKR, ID = 4.75" TOP OF 7" LNR 1045$' 10440' 4-1 /2" PKR SWS NIP, ID = 3.813" 10460' 4-1 /2" PKR SWN NIP, ID = 3.725" " 4-1/2 TBG, 12.6#, L-80, .0152 bpf, ~ = 3.958" 10472' 10472' 4-1/2" PKR WLEG, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 10715' 10457' ~MD TT LOGGED 11/23/00 PERFORATION SUMMARY REF LOG: SWS-BRCS ON 04/03/92; SWS GR/CCL ON 04/24/92 ANGLE AT TOP PERF: 39 @ 10874' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10874 - 10922 C 09/27/92 3-3/8" 4 10927 - 10958 C 04/25/92 3-3/8" 4 10958 - 10978 S 09/02/99 3-3/8" 4 10982 - 11010 S 09/02/99 3-3/8" 4 11022 - 11054 S 09/02/99 3-3/8" 4 11170 - 11220 S 09/02/99 ~ PBTD H 11397' 7" TBG, 26#, .0383 bpf, ID = 6.276" 11480' CARBOLffE DATE REV BY COMMENTS DATE REV BY COMMENTS 04/06/92 ML ORIGINAL COMPLETION 12/15/07 THJPJC SEf IBP@ 10424' (11/29/07) 12/15/05 TWS/PJC PULL IBP @ 10399' 01/10/06 EZUPJC WANIERSFTY NOTE (12/31/05) 11/12/06 JMFlPJC SET BKR ~P @ 10406' 02/10/07 JCM/PAG PULL IBP@ 10413' (12/22/06) 11/11/07 RDW/SV WAIVERSFTY NOTEDEI.ETED PRUDHOE BAY UNfT WELL: M-30 PERMIT No: 1920300 API Nb: 50-029-22255-00 SEC 1, T11 N, R12E, 2233' SNL 8~ 606' WEL BP Exploration (Alaska) M-3i Proposed ~, 10958' ~ TOP OF CEMENT CA P 10995' TOP OF SAND STATE OF ALASKA ~~~ ECEI V CD ~. ALASK OIL AND GAS CONSERVATION COMMIS p ~~ Z U 2007 REPORT OF SUNDRY WELL OPERATIONS . 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ t ~'I ~@SplCl$Sj Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension C~~Chdl'8®@ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory ~~~ 192-0300 3. Address: P.O. Box 196612 ' Stratigraphic ~' Service , 6. API Number: Anchorage, AK 99519-6612 50-029-22255-00-00 7. KB Elevation (ft): 9. Well Name and Number: 57 KB ~ PBU M-30 ~ 8. Property Designation: 10. Field/Pool(s): ADLO-028257 Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11480 ' feet Plugs (measured) 10958' TOP OF CEM CAP true vertical 9212.36 feet Junk (measured) None Effective Depth measured 10958 feet w DEC ~p ~ ~ttf17 0~1~&'~6~8'~~~~ U Y tJU/ true vertical 8788 feet Casing Length Size MD TVD Burst Collapse Conductor 90 20" 91.5# H-40 29 - 119 29 - 1 i 9 1490 470 Production 10688 9-5/8" 47# L-80 27 - 10715 27 - 8595.45 6870 4760 Liner 1022 7" 26# 13CR80 10458 - 11480 8394.74 - 9212.36 7240 5410 Surface 3110 13-3/8" 72# L-80 28 - 3138 28 - 3015 5380 2670 Perforation depth: Measured depth: C 10874 - 10908 C 10912 - 10922 C 1 0927 - 10978 C10927 - 1 0958 True Vertical depth: 8720.74 - 8747.74 8750.92 - 8758.87 8762.85 - 8803.54 8762.85 - 8787.57 Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 25 - 10353 3-1/2" 9.3# L-80 6825 - 6845 TUBING PATCH 4-1/2" 12.6# L-80 10353 - 10472 3-1/2" 9.3# L-80 7445 - 7465 TUBING PATCH Packers and SSSV (type and measured depth) 5-1/2" AVA-DWP Patch Packer 6825 5-1/2" AVA-DWP Patch Packer 6845 5-1/2" AVA-DWP Patch Packer 7445 5-1/2" AVA-DWP Patch Packer 7465 4-112" Baker SAB Perm Packer 10398 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-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 2047 1000 446 Subsequent to operation: Shutin 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development }-' Service Daily Report of Well Operations X 16. Well Status after proposed work: 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: N/A Contact Gary Preble ~i ~~ ~~~ Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 12/7/2007 Form 10-404 RevisecJ.04/2006 ~' _ .. . _ E~,j ~ (~~~ ~ ~ ~~o~ Supmit Unginal Unly • • M-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTtVITYDATE SUMMARY 11/29/2007._ """WELL S-I ON ARRIVAL ""` INITIAL T/I/O 0/180/120 'SET 2.5" BAKER IBP AT 10,424'. CORRELATED TO TUBING TALLY DATED 6- '! APR-1992. '!TOP OF IBP AT 10,416.9'. OVERALL LENGTH 11.05'. FISHING NECK 1.375" OD. IBP SET IN JOINT BELOW PACKER. FINAL T/I/O 0/180/120 '"** JOB COMPLETE *''* FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL M-30 (PTD #1920300) Internal W~er Cancellation -Reclassified as Not O erable Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer jNSUADWWeIIlntegrityEngineer@BP.com] ~~` ~/(2~'0? Sent: Sunday, November 11, 2007 11:00 AM ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; Brown, Don L. Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: M-30 (PTD #1920300) Internal Waiver Cancellation -Reclassified as Not Operable All, An internal waiver was issued for TxIA communication on M-30 (PTD #1920300) on 12131/05. The well does not pass an MITIA and is not considered Operable. Paperwork has been sent to the AOGCC canceling the corresponding sundry. ~' Work to repair the well will continue when the produced water injection line on M-Pad is repaired. The well is reclassified as Not Operable. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Please calf with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~~ Nov ~ 2ao7 11 /21 /2007 BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 November 09, 2007 Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W . 7th Ave. Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well M-30 (PTD #1920300) Application for Cancellation of Sundry #302-169 Dear Mr. Norman: by ~E~E~ V NOV Y 4 2007 Alaska Oil $~ Gas Cons. Commissimn An~hRraao This request is to cancel Sundry #302-169 for Prudhoe Bay Unit well M-30 (PTD #1920300). The Sundry, originally issued June 06, 2002, was for continued water injection with tubing by inner annulus communication. The well no longer adheres to BP's We11 Integrity Systems Policy and will remain shut-in until the communication has been repaired. A State witnessed MITIA for UIC compliance will be conducted once the repair is complete and the well is on injection. The application for Sundry cancellation form 10-404 is attached. If you require any additional information, please contact Anna Dube or myself at (907) 659-5102. Sincerely, I +' . ~ , ~ QC~ ~ ~ - ~,~ <= u~ Nov ~ :zoa~ ndrea Hughes Well Integrity Coordinator ORIGINAL • Attachments: • Application for Sundry Cancellation form 10-404 STATE OF ALASKA ~ ~~~ 1 ~ ~~~~, ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~I~~~ G~IS Cons. Commission -__.._ AAP^AP7MA 1. Operations Performed: Abandon Repair Well Plug Perforations^ Stimulate ^ _o_ I OtherOX 10-403 Canc Alter Casing Pull Tubing Perforate New Pool Waiver Time Extension Change Approved Program Operation Shutdown Perforate ~ Re-enter Suspended Well 2. Operator gp Exploration (Alaska), Inc. Name: 4. Current Well Class: Development ~ Exploratory 5. Permit to Drill Number: 192-0300 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic~ Service^X 50-029-22255-00-00 7. KB Elevation (ft): 9. Well Name and Number: 57.00 M-30 8. Property Designation: 10. Field/Pool(s): ADL-028257 Prudhoe B ay Field / Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11480 feet true vertical 9212.0 feet Plugs (measured) None Effective Depth measured 10958 feet Junk (measured) None true vertical 8788.0 feet Casing Length SIZe MD TVD Burst Collapse CONDUCTOR 90 20" 91.5# H-40 29 - 119 29.0 - 119.0 1490 470 SURFACE 3110 13-3/8" 72# L-80 28 - 3138 28.0 - 3014.7 5380 2670 PRODUCTION 10688 9-5/8" 47# L-80 27 - 10715 27.0 - 8595.4 6870 4760 LINER 1022 7" 26# 13CR80 10458 - 11480 8394.7 - 9212.4 7240 5410 Perforation depth: Measured depth: 10874-10922, 10927-10958 True vertical depth: 8721-8759, 8763-8788 Tubing (size, grade, and measured depth): 5-1/2" 17# L-80 @ 25 - 10353 4-1/2" 12.6# L-80 @ 10353 - 10472 3-1/2" 9.3# L-80 @ 6825 - 6845 Tubing Patch 3-1/2" 9.3# L-80 @ 7445 - 7465 Tubing patch Packers & SSSV (type & measured depth): 5-1/2" AVA-DWP Patch Packer @ 6825 5-1/2" AVA-DWP Patch Packer @ 6845 5-1 /2" AVA-DWP Patch Packer @ 7445 5-1/2" AVA-DWP Patch Packer @ 7465 9-5/8" Baker SAB Packer @ 10385 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~(~tf ~ ~ ~~of Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Iniection Data Prior to well operation: Subsequent to operation: 14. Attachments: oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Last Injection 09/07/07 1986 1000 446 Copies of Logs and Surveys run Daily Report of Well Operations _ X 15. Well Class after proposed work: Exploratory 16. Well Status after proposed work: Development Service^X Oil Gas WAG ~ GINJ~ WINJ^X WDSPL~ Prepared by DeWayne R. Schnorr (907) 564-5174. 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 Andrea Hughes 302-169 Printed Name Andr a Hu Title NSU, ADW WI Coordinator Signature _ 9 ~~ Phone 659-5102 Date 11/6/07 Form 10-404 Revised 4/2004 - UKIVIfv~1L k~`Lts M-30 (PTD #1920300) Interr~Waiver Cancellation -Reclassified as Not Operable Page I of 1 Maunder, Thomas E (DOA) From: NSU, ADW Wel! Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Sunday, November 11, 2007 11:00 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Welt Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Weltpad Lead; GPB, Wefts Opt Eng; GPB, Optimization Engr; Brown, Dan L, Cc: NSU, ADW Wet{ Integrity Engineer; NSU, ADW WI Tech Subject: M-30 (PTD #1920300) Intemaf Waiver Cancellation -Reclassified as Not Operable Atl, An intemaf waiver was issued for TxIA communication on M-30 (PTD #1920300) on 12/31105. The well does not pass an MITtA and is not considered Operable. Paperwork has been sent to the AOGCC canceling the corresponding sundry. Work to repair the wel! wilt continue when the produced water injection tine on M-Pad is repaired. The well is reclassified as Nat Operable. Please remove aft waivered well signs and the tam'rnated copy of the waiver from the wetlhouse. Please salt with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (9fl7) 659-5102 Pager: (907) 659-5100 x1154 11/15/2007 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test n \Z, "z,.. "(,10 íV K4{1 Email to:Winton_Auberi@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / M pad 12/11/06 Joe Anders ôO \<\ d-'0 Packer Depth Pretest Initial 15 Min. 30 Min. We1l1M-30 I Type Inj. ! N TVD I 8,348' Tubing 180 2,260 2,200 2,190 Interval I v P.T.D.11920300 I Tvpe test P Test psi 2087 Casing 490 2,580 2,520 2,500 P/FI P Notes: CMIT TxlA TO 2500 PSI FOR VARIANCE OA 120 390 380 380 Weill Type Inj. I I TVD I Tubing Intervall P.T.D.I I Type test I I Test psi Casing I P/FI Notes: OAI Weill I Type Inj.1 TVD I Tubing Interval/ P.T.D.I I Type test I Test psi! Casing I P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval I P.T.D.I I Type test I ! Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval/ p.T.D.1 Type test I I Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M ::: Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey 0= Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) tirANNED JAN 0 8 2007 MIT PBU M-30 12-11-06 "xis RECEIVED '\ STATE OF ALASKA "') ALAb. Á OIL AND GAS CONSERVATION COMrv.. -,SION J ð t\.1 2 4 2006 REPORT OF SUNDRY WELL OPERATION~t\ sk 'I Co Co .. 1. Operations Abandon D Repair Well D Plug Perforations 0 Stimulate D · la 8tR~r Mas os. mnIIIIOII Performed: Alter Casing D Pull Tubing D Perforate New Pool D WaiverD Time Extension ~nGhoraüc Change Approved Program D 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 Exploratory C 192-0300 3. Address: P.O. Box 196612 Stratigraphic [] Service R' 6. API Number: Anchorage, AK 99519-6612 50-029-22255-00-00 7. KB Elevation (ft): 9. Well Name and Number: 57 KB 8. Property Designation: ADL-028257 11. Present Well Condition Summary: Total Depth measured 11480 true vertical 9212.36 Effective Depth measured 11397 true vertical 9143.74 Casing Conductor Surface Production Liner Length 90 3110 10688 1022 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# 13CR80 Perforation depth: Measured depth: 10874 - 10922 True Vertical depth: 8720.74 - 8758.87 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: 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 M-30 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) None None feet feet MD 29 - 119 28 - 3138 27 - 10715 10458 - 11480 TVD Burst Collapse 29 - 119 1490 470 28 - 3014.69 5380 2670 27 - 8595.45 6870 4760 8394.74 - 9212.36 7240 5410 10927 - 10958 8762.85 - 8787.57 5-112" 17# 4-1/2" 12.6# 3-1/2" 9.3# 3-1/2" 9.3# L-80 L-80 L-80 L-80 25 - 10353 10353 - 10472 6825 - 6829 7445 - 7465 6825 6845 7445 7465 10398 5-1/2"'AVA-DWP Patch Packer 5-1/2" AVA-DWP Patch Packer 5-1/2" AVA-DWP Patch Packer 5-1/2" AVA-DWP Patch Packer 4-1/2" Baker SAB Perm Packer . " ,,",' f1,liÜ 1>2 \:\ 'ìOÚ5RBDMS 8Ft ,¡AN 2 5 2006 ~ÇANNED JA¡r (J¡ ,-. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 11590 280 o 6400 500 15. Well Class after Droposed work: Exploratory r Development r 16. Well Status after proposed work: Oil r Gas r WAG r Tubing pressure 550 401 Service ¡;¡ WDSPLr GINJ r W INJ ¡;¡ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal '2¿~'1 ", /;. ¡; J .y (~) Signatu~1IÍ'¿'/:11d'¿/Lé.,> Title Data Mgmt Engr Phone 564-4424 Date 1/20/2006 Form 10-404 Revised 04/2004 1: ~ ~ ~,' 1 ,~ 1 ~ \ ; h~ ì 1 ~ J ~¡ ¡, \'I,) 1 d 1\,..,1' ~ '., ~,~ ,.-- Submit Original Only ) ') M-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 12/14/2005 *** WELL SI ON ARRIVAL, MASTER VL V CLOSED *** ( pull ibp) RAN 2.75 LIB TO 10,392' SLM, LIB INCONCLUSIVE, MADE ONE ATTEMPT W/ EQ BELLGUIDE & PULLING TOOL, RIH W/ 2.25 PUMP BAILER @ REPORT TIME. *** JOB IN PROGRESS/ CO NT ON 12-15-05 WSR *** 12/15/2005 *** CO NT FROM 12-14-05 WSR *** ( pull ibp, reg campi) EQUALIZED & PULLED BAKER IBP, ALL ELEMENTS RECOVERED W/ IBP. RDMO *** PAD OP NOTIFIED, WELL LEFT SI*** 1/2/2006 IBP MONTHLY RENTAL FOR 11/15/05 - 12/15/05, MO 1. NOTE: IBP SET ON 11/15/05 & PULLED 12/15/05 FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL I-<t:. L~ "- n I . STATE OF ALASKA - DEC r O'Oh ALA OIL AND GAS CONSERVATION COM~ION 1 6 2 .1 REPORT OF SUNDRY WELL OPERATIO~a Oil & Gas Cons. """'Lh.~_.i; 1. Operations Abandon D Repair Well D Plug Perforations [2] Stimulate D OthArnElIDrage Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program, D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 192-0300 3. Address: P.O. Box 196612 Stratigraphic Service IV" 6. API Number: Anchorage, AK 99519-6612 50-029-22255-00-00 7. KB Elevation (ft): 9. Well Name and Number: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing pressure SHUT-IN SHUT-IN 15. Well Class after proposed work: Exploratory Development Service r;a 16. Well Status after proposed work: Oil Gas WAG WINJ r;a 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: RBDMS BFl DEC 1 9 2005 N/A " 57 KB 8. Property Designation: ADL-028257 11. Present Well Condition Summary: Total Depth measured 11480 true vertical 9212.36 Effective Depth measured 11397 true vertical 9143.74 Casing Conductor Surface Production Liner Length 90 3110 10688 1022 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# 13CR80 Perforation depth: Measured depth: 10874 -10958 Closed True Vertical depth: 8720.74 - 8787.57 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: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signat~/t-. M-30 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool feet feet Plugs (measured) Junk (measured) 10399 None feet feet MD 29 - 119 28 - 3138 27 - 10715 10458 - 11480 TVD Burst Collapse 29 - 119 1490 470 28 - 3014.69 5380 2670 27 - 8595.45 6870 4760 8394.74 - 9212.36 7240 5410 10958 - 11220 Sqz'd 8787.57 - 8998.76 5-1/2" 17# L-80 4-1/2"12.6# L-80 5-1/2" AVA-DWP Patch Packer 5-1/2" AVA-DWP Patch Packer 5-1/2" AVA-DWP Patch Packer 5-1/2" AVA-DWP Patch Packer 25 - 10353 10353 - 10472 6825 6845 7445 7465 b\.\.~~'i'-\ " ~CU'\nö \1K;.--) C) -i "in q¡:-, (e:' .;. '-....UoJ Title Data Mgmt Engr Phone 564-4424 Date 12/9/2005 Form 10-404 Revised 04/2004 nnl~1~'l\' Submit Original Only " e e M-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ~~t¡.fft. ".§&JVÎMÄRY 11/14/2005 *** WELL INJECTING ON ARRIVAL *** DRIFTED W/ 2.75 CENT, TEL & SAMPLE BAILER- LOC EOT @ 10,447' SLM- 10,457' CORRECTED, TAG TD @ 10,947' CORRECTED DEPTH. RDMO *** PADOP NOTIFIED, WELL INJECTING ON DEPARTURE *** 11/14/2005 F-PROTECT TBG/F-LlNE TRANSFER FLUID LOAD 60/40 METH H2o TRAVEL WAIVER COMPo 11/15/2005 TIO=200/950/200 F-PROTECT TBG AND F-LlNE WAIVER COMPo WELL FLOWING ON ARRIVAL SHUT WING PUMP 58 BBLS OF 50* 60/40 METH H2o DOWN TBG PUMP 10 BBLS OF 60/40 METH H2o DOWN F-LlNE FWH P=200/950/200 11/15/2005 SET IBP AT 10399' CORRELATED TO IBP SETTING RECORD DATED 17~ MAY-2004. IBP SET IN THE PUP JOINT BELOW THE PACKER. ***JOB COMPLETE*** FLUIDS PUMPED BBLS 1 I ::::L 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission FROM: DATE: Wednesday, November 30,2005 TO: Jim Reggí")./ .. __X!'-~!lP~D'iSoL_fS,.{2çN_tZ;LZI1)-2)·___ - ~UBJEC!:~~~~;Æ~ii¿~~I~~)iNc-- -- ~ 0 M-30 ,/ '}.I PRUDHOE BAY UNIT M-30 · (\ J: \"~ ---_._~--- Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 51)t'- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT M-30 API Well Number 50-029-22255-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS05 1129153139 Permit Number: 192-030-0 Inspection Date: 11/29/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i M-30 [Type Inj. N I TVD I I IA I i I I 8348 ¡ 560 2500 2460 2450 I I I P.T. ¡ 1920300 !TypeTest SPT I Test psi I 2087 lOA I 60 190 ! 190 ! 190 I I I I I Interval REQVAR P/F P Tubing I 60 1980 I 1940 [ 1930 ¡ I ¡ Notes With a plug set in the tubing below a known leak, this CMIT was perfonned verifying production casing and packer integrity. ~(;ANNEL 1~ c¡ ..¡ r'f\fW_ ~-> Il.â .i luLtJ Wednesday, November 30, 2005 Page I of I Schlumbel'ger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well NK-20 P2-34 N-14A 4-38/K-34 B-19A 15-31 B MPF-89 DS 16-01 DS 16-15 DS 09-10 M-30 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 10889223 11072853 10991753 10933591 11058502 10942223 11132060 10980601 10980599 11058237 11072877 Log Description Date 03/21/05 06/05/05 01/22/05 10/29/04 05/06/05 07/16/05 10/08/05 08/15/05 08/13/05 08/16/05 08/04/05 PPROF W/DEFT TEMPERATURE PRESSURE LOG LDL PPROF WIDEFT/GHOST RST MCNL SCMT (PDC-GR) INJECTION PROFILE PPROF W/DEFT INJECTION PROFILE INJECTION PROFILE Ô(;ANNED NOV 0 2 2005 I~ ð~ M\) (, 10/18/05 NO. 3503 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 Color CD "~ 1 1 1 1 "_/ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99r;LJ03 8 (lJjJ ATTN: Beth Received by: ' 1 q2- ~t\~:'\- øJÞ MEMORANDlJM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supen'isor Ket[1 7/I~M DATE: Wednesday. June 30. 2(10~ SlIBJECT: Mechanicallmegrn)' Tests BP EXPLOR.ATION (ALASKA) INC FROM: John Crisp Petroleum Inspector M-30 PRUDHOE BAY UNIT M-30 Src: Inspector Re\'iewed By: P.I. Supn' --JC::f- 7/1 b( Of Comm NON-CONFIDENTIAL \Vell Name: PRUDHOE SA Y UNIT t-.1-30 Insp Num: mitJCr040612191058 Rellnsp Num: API Well Number: 50-029-22255-00-00 Permit Number: 192-030-0 Inspector Name: John Cnsp Inspection Date: 6/6/2004 Packer Depth Pretest Initial 15 Min. 30 Min. ~5 Min. 60 Min. Well M-30 Type Inj. s TVD 9192 I IA 500 2990 2950 2930 P.T. 1920300 TypeTest SPT Test psi 2087 lOA 150 300 300 300 Inten'al REQVAR PIF P Tubing 1-10 2530 2.tSO 2-155 Notes: CI\HT Tbg x IA againsllBP in tbg. for 2 year compliance sundry #302-169 Wednesday. June 30. 200-1 Page J of I MEMORANDUM State of Alaska TO: Alaska Oil and Gas Conservation Commission FROM: Jeff Jones Petroleum Inspector DATE: Wednesday, May 26, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORA T]ON (ALASKA) INC M-30 PRUDHOE BAY UNIT M-JO , a - D 3 () Src: Inspector \ 9 THRU: Jim Regg ~{¡l t) Zí/C,tj" P.I. Supervisor { ( NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT M-30 Pad: 640 API Well Numbe 50-029-22255-00-00 Inspector Name: Permit Number 1920300 Inspection Date: Jeff Jones 5/22/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: M-30 Type Inj. F TVD 9]92 IA 250 2400 P.T. ]920300 TypeTest SPT Test psi 2086.75 OA 50 50 --- Interval REQV AR PIF F Tu bing 0 ]860 Notes: This waivered welI has known tubing leaks at 8070' and 8120' MD and tubing patches at 6825' and 7445' MD. An IBP was instalIed in the tubing at 10399' MD to facilitate the test. The pretest pressures were observed to be stable and the IA was pressured up to 2400 PSI with the tubing tracking due to the leaks. Because the well had not been fluid packed prior to the test, approximately 30 BBLS of 50/50 methanol was pumped to pressure up the IA & tubing & the test was inconclusive & was aborted. Apparently the BPXA DHD field personnel have no instructions or requirements to properly fluid pack the welI prior to performing an MIT, which precludes a definitive test. Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SALT WATER INJ. N=NOT INÆCTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=lntemal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test Interva] l=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during Workover O=Other (describe in notes) M.I.T.'s Performed: Number of Failures: Total Time during tests: houris Wednesday, May 26, 2004 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 2233' FNL, 606' FEL, Sec. 01, T11N, R12E, UM At top of productive interval 4137' FNL, 1' FEL, Sec. 36, T12N, R12E, UM At effective depth 4926' FNL, 16' FEL, Sec. 35, T12N, R12E, UM At total depth 4725' FNL, 254' FEL, Sec. 35 T12N, R12E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 3107' Intermediate 10684' Liner 1022' Operational shutdown _ Re-enter suspended well _ Plugging _ Ti me extension _ Stimulate _ Pull tubing _ Variance _X Perforate _ 5. Type of Well' 6. Datum elevation (DF or KB feet) Development_ RKB 57.0 feet Exploratory_ 7. Unit or Property name Stratigraphic _ Service__X (asp's 628229, 5973310) (asp's 623485, 5977419) (asp's 623482, 5976630) (asp's 623241,5976827) Plugs (measured) 11480 feet 9192 feet Junk (measured) 10955 feet 8790 feet Prudhoe Bay Unit 8. Well number M-30 9. Permit number / approval number 1920300 10. APl number 50-029-22255-00 11. Field / Pool Prudhoe Bay Oil Pool Other _ IBP set in tubing @ 10399' (11/23/2000) Tag Top of Cement Cap @ 10955' (11/19/2000) Size Cemented Measured Depth True vertical Depth 20" 72 cf 141' 141' 13-3/8" 3650 cf Arcticset III, 700 3138' 3014' cf Class 'G' 9-5/8" 2370 cf Class 'G' 10715' 8595' 7" 300 cf Class 'G' 10458' - 11480' 8394' - 9212' Perforation depth: measured Open Perfs 10874'-10922', 10927'-10955' Below Cement Cap 10955'-11010', 11022'-11054', 11170'-11220' (size, grade, and measured depth Packers & SSSV (type & measured depth) true vertical Open Perfs 8725'-8764', 8768'-8790' Below Cement Cap 8790'-8834', 8844'-8870', 8963'-9003' ?'¥)¢;?.~t;?:¥:~:;~,, 5-1/2", 17¢, L-80 TBG to 10353' MD. 5-1/2" X 4-1/2" XO ~ 10353'. 4-1/2" Tubing Tail ~ 10472'. 5-1/2" x 20' AVA-DWP RETRIEV Patches set 8 6825' and 7445'. 9-5/8" x 4-1/2" Baker SAM Packer ~ 10398' MD. 13. Attachments Description summary of proposal 14. Estimated date for commencing operation June 1,2002 16. if proposal was verbally approved 5-1/2" Otis HRQ SSSVLN @ 2100' MD. Detailed operations program 15. Status of well classification as: BOP sketch Oil __ Gas w Suspended Name of approver Date approved 17. I hereby c§rtify that,t~e foregoing is true and correct to the best of my knowledge. Signed /f'~Iv/I/~'*'~/?/ /j~' Title: Well Integrity Engineer Joe Anders FOR COMMISSION USE ONLY Conditions of approval' Notify Commission so representative may witness Service __,WATER INJECTOR Questions? Call Joe Anders or Kevin Yeager at (907) 659-5102. Date May 23, 2002 R. Schnorr 564-5174 Approval no. Plug integrity BOP Test Location clearance -- ~-A ' "~'" -- ~O- Mechanical IBtegrity Test ~ ~,,"~ , ~~ . Subsequent form required Approved by order of heCo m'ssio ~commi~~~EP d~t~. Form ~0-403 ~ov 0~/~5/88 · SUBMIT M-30 Description Summary of Proposal 05/23/02 Problem- Injector with Rapid TxiA communication Well History and Status Well M-30 (PTD 1920300) is an injector that failed an MIT-IA on 11/12/00. A LLR of .3 bpm @ 2500 psi was established. Recent events: > 11/12/00: Failed MITIA, LLR .3 BPM @ 2500 psi > 11/23/00: Set IBP > 11/24/00: MITIA Failed, LLR 15 GPM @ 2500 psi > 12/27/00' LDL found holes in TBG at 8070',~ & 8120' > 05/17/02' CMIT TxlA passed to 3000 psi This sundry request is to allow for continued injection of water. The following supports the request: - A CMIT TxlA Passed on 05/17/02 to 3000 psi against an IBP, demonstrating competent production casing. - Pressures and injection rates will be checked and recorded daily and monitored for indications of a production casing leak. - A CMIT TxlA against a plug will be conducted every 2 years to confirm production casing 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 combination MIT Tubing x IA against a plug every 2 years. 5. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. ~GANNE~t JUN ~ 'z~ 2002 TREE ' 6" CIW WFI LHEAD = FMC KB. ELEV = 57.00' KOP = 1817' Max Angle = 45 @ 7134' Datum MD - 11038' Datum TVD = 8800' SS I 13-3/8" CSG, 72#, L80-BTRS, ID= t2.347" 3t38' M-30 2100' SAFETY NOTES- LEAKS DETECTED @ 8120'& 8070' INTUBING. INJECTION WELL 1~5,1/2" o~s HRQ SSSV LAND NIP, ID: 4.562" I GAS LIFT MANDRELS Mi ni mum ID - 2.992" ¢__. 6825' 5-1/2" AVA DWP RETRIEVE. PATCH 6825' 7445' Id5-1/2" x 20' AVA-DWP RETRIEV PATCH, D = 2.992" Iq5-1/2" x 20'AVA-DWPRETRIEV PATCH, ID = 2.992" 1 5-1/2"TBG, 17#, L-80, .0232 bpf, ID:4.892" Iff 10353" I 10353' I ITOP OF 7" LNR ]--~ 10458" 4-1/2" TBG, 12.6~, L-80, .0152 bpf, ID= 3.958" 9-5/8" CSG, 47#, L-80, D = 8.681" 10472' 10715' PERFORATION SUM MA RY REF LOG: SWS-BHCS- 04/03/92' SWS GR/CCL- 04/24/92 ANGLEATTOPPERF: 39 @ 10874' Note: Refer to Productbn DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3- 3/8" 4 10 874' -10922' C 0 9/27/92 3-3/8" 4 10927' -10978' C 04/25/92 3-3/8" 4 10982' -11010' C 04/25/92 3-3/8" 4 11022' -11054' C 04/25/92 3-3/8" 4 11170'-11220' C 09/10/92 7" TBG, 26#, 13Cr-NSC:C, .0383 bpf, ID = 6.276" 11480' I 10353' Id5-1/2" x 4-1/2" XO I 10375' I--'~ 4-1/2"_ PKR SWS NIP, ID= 3.813" 10398' J_~9-5/8" x 4-1/2" BKRSAB FKR, ID=4.75"J 10399' Iq '"" SETll/23/00 l 10440' H4-1/2" PKR SWS NIP, ID: 3.813" 10460' [-~4-1/2" PKR SWN NIP, ID= 3.725" 10472' H4-~/2" PKR WLEG, D: 3.958"I 10457' I--I ELMDTTLOGGED11/23/001 II I-ITO. o. CEMENT CAP I . 't992' I-lCA..o.rr.l DATE REV BY COMMENTS DATE REV BY COIVtvlENTS 04/06/92 iVl_ ORIGINAL COIVPL ETLON 61/15/01 SlS-SLT OONVERTEDTO CANVAS 01/23/01 SIS-MD RNAL 07/23/01 RN/TP CORRECTIONS , PRUDHOE BAY UNIT WELL: M-30i PERMIT No: 92-0300 APl No: 50-029-22255-00 Sec. 1, Tt 1N, R12E rati ~las Re: M-30 Failed MITIA (PTD 1920300) Subject: Re: M-30 Failed MITIA (PTD 1920300) Date: Mon, 20 Nov 2000 08:58:39 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "GPB, Well Integrity Engineer" <GPBWelllntegrityEngineer@BP.com> Guys, \~%¥¥'~\'~-/~. (~ I [~ I~e'~ Thanks for the information. I'll look forward to your diagnostic information.~, ~,-~' '~. -4~ ! t ~ I °'t ~- Tom "GPB, Well Integrity Engineer" wrote: Hello Tom. Well M-30 failed an MITIA on 11/18/00. A leak rate of.3 BPM at 2500 psi was established. It has 2 patches covering known tubing holes. Pressure readings are inconclusive as to whether the leak is in the tubing or casing. Plan is to set an IBP to evaluate casing integrity, then run a LDL to locate the leak. A sundry request to allow continued injection will be evaluated post LDL. Please call if you have any questions. Joe Anders, P.E./Kevin Yeager Well Integrity Engineer BP Exploration Alaska, Inc. (907) 659-5 ~ 02 ernail: G PB WelllntegrityEngineer@bp. corn Tom Maunder <tom maunder@admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission ~ '""' '~ 11/20/00 8:58 AM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P M E E L E W A T E R IA L U N D ER TH IS M A R K ER C:LO~LM.DOC ~.~ ii~l ALAS..~ OIL AND GAS ~,C~I~I~'~/~/[,~iON COMMISSIQN 'REPORT : SUNDRY WELL OPE. ATIONS 1. Operations performed: Operation shutdown__ Stimulate__ Plugging~ Perforate__ Pull tubing~ Alter casing __ Repair well Otherx 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchoracle, Alaska 99519-6612 4. Location of well at surface 2233'SNL, 606' WEL, SEC. 1, T11N, R12E At top of productive interval 1142' NSL, 5279' WEL, SEC. 36, T12N, R12E At effective depth 4750' NSL, 213' WEL, SEC. 35, T12N, R12E At total depth 1383' NSL, 278' WEL, SEC. 35, T12N, R12E 5. Type of Well: Development Exploratory Stratigraphic Servicex ~rDatum elevation (DF or KB) KBE=57 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number M-30(14-36-12-12) 9. Permit number/approval number 92-30 / 10. APl number 50.029-22255 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural .- Conductor 110 Surface 3107 Intermediate 10684 Production -- Liner 1022 Perforation depth: measured 11480 9192 11397 9127 Size feet Plugs (measured) feet feet Junk (measured) feet Cemented Measured depth 141 3138 10715 20 13 3/8 9 5/8 3653 c.f. Artic set 111/700 2212 c.f. Class "G" 7 300 c.f. Class "G" 10458-11480 10874L10908~10912L10922~10927L10978~10982L11010~11022'-11054' true vertica§ubsea 8719'-8746', 8749'-8757', 8761 '-8800', 8804 '-8825', 8835'-8860' True vertical depth BKB 141 3014 8595 8394-9212 Tubing (size, grade, and measured depth) 5 1/2" @ 10472' Packers and SSSV (type and measured depth) Packer @ 10398' and SSSV@2100 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil__ Gas Suspended 17. I heret:iy c,¢tify that the~'¢egoing is tr, ue,~nd correct to the best of my knowledge. S i g n e d '~'~,,/_~ ~z.~/~%~~~ j Title TechnicalAssistantlV Form 10-404 Rev 0~1~88 Service Wat~.r Ini. ector SUBMIT N DUPLICATE,~ ' M-30 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS O9/O2/99 A Sandback Cement Cap was performed using the following fluids: SUMMARY September 1, 1999: MIRU DS CTU #6. Pick up pig shear nozzle. RIH. Tag at 11389' (slickline tag of 8/31/99 corrected to TT). Pump 7500# of carbolite (80% of calc'd volume). At one hour, soft tag at 11228'. Wait another hour. Tag plug at 11178', wait 25 minutes and confirm with second tag - no change. Gel did not break in a timely fashion. Pump 4400# carbolite, increase breaker in slurry. Wait one hour. Tag plug at 10848'. Circulate and fluff up. Tag at 10860'. Circulate and fluff up again. Tag at 10962'. Fluff up and tag again at 10962'. No progress. Carbolite is 30' high. Flag Pipe @ 10745'. POH SDFN. Will rig up reverse out equipment and dress top tomorrow. September 2, 1999: Rig up reverse equipment. Pick up injector. RIH. Correct at flag. Tag at 10953'. Fluff up carbolite and reverse out down to 10995'. Reverse circulate clean. Wait 30 minutes and dry tag at 10992'. Mix and pump 1.5 bbls cement. Spot cement plug from 10992' to 10955' (error on shallow side pursuant to program and assume some loss to open perforations). POH. Freeze protect tubing, flowline and coil with MEOH. RD DS CTU #6 and associated equipment. Fluids Pumped BBLS. Description 153 MeOH 1003 2% KCL 59 Gelled Water 1.5 Cement 1216.5 Total Pumped RECEIVED r.7,¥ 999 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing_ Stimulate __ Plugging__ Perforate__ Alter casing __ Repair well __ Other X ¢ 0 ~ V E R T E D T 0 t~] A G 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X 2233' SNL, 606' WEL, SEC. 1, T11N, R12E At top of productive interval 1142' NSL, 5279' WEL, SEC. 36, T12N, R12E At effective depth 4750' NSL, 213' WEL, SEC. 35, T12N, R12E At total depth 1383' NSL, 278' WEL, SEC. 35, T12N, R12E 6. Datum elevation (DF or KB) KBE=57 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-30(14-36-12-12) 9. Permit number/approval number 92-30 / 10. APl number 50- 029-22255 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11480 feet Plugs (measured) 9192 feet 11397 feet Junk (measured) 9127 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length .. 110 3107 1O684 __ 1022 Size Cemented Measured depth True vertical depth BKB 20 141 141 13 3/8 3653 c.f. Artic set 111/700 3138 3014 9 5/8 2212 c.f. Class "G" 10715 8595 7 300 c.f. Class "G" 10458-11480 8394-9212 measured true vertical 10874;10908', 10912; 10922', 10927; 10978', 10982; 11010', 11022'-11054' RECEIVED subsea8719'-8746',8749'-8757',8761'-8800',8804'-8825',8835'-8860' .,UG 1 9 1996 Tubing (size, grade, and measured depth) 5 1/2" @ 10472' Packers and SSSV (type and measured depth) Packer @ 10398' and SSSV@2100 13. Stimulation or cement squeeze summary Alaska 0il & Gas Cons. Commission Anchorage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 2190 2364 550 1920 274 6770 7556 2810 1940 426 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily ReportrOf-W,~ell Operations Oil Gas Suspended Service WAG 17. ~-yy certify~/~f t~/e(~(!~oing"' ''' ' Signed ~' ~--v~t Date SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 is true and correct to the best of my knowledge. Title Supervisor Northwest Fault Block LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK., 99501. Date: 20 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ ~ DESCRIPTION M-09 ~ ~' 1 PLS FINAL BL+RF R-04 (22-05-1!-!3)~ 1 PFC/PERF FINAL BL+RF P-23 (41-32-11-13) .~ ~ ,!~ PLS FIN~ BL+RF 3 3 A-08 (2 - 6-11-13) PFC/PE~ FIN~ BL+~ 1 CCL FIN~ BL+RF F-43 q (/0~ ~ 1 PLS FIN~ BL+~ ECC No. Run ~ '1 2187.07 '- Run # 1 5627.10 Run # 1 5671.02 Run # 1 5957.05 Run # 1 6043.04 Run # 1 6163.03 Run ~ 1 Run # 1 6236.05 Please sign and return to: Attn. Rodney D. Paulson - Atlas Wireline Services 5600 B Street suite ~chorage, ~ 99518 ~ Or F~ to (907) 56~ Received by: Date: ?ERMIT DATA )2-030 BHCS/GR 92-030 CNL/PORO )2-030 PERF 92-030 PFC/GR (PERF) )2-030 PIL (DITE/GR) 92-030 PROD )2-030 PROD 92-030 PROD )2-030 SSTVD 92-030 TIE )2-030 407 92-030 DAILY WELL OP 32-030 SURVEY 92-030 SURVEY AOGCC Individual Well Geological Materials Inventory T DATA_PLUS 32-030 5259 L 10708-11438 L 7852-11419 L 10200-11378 L 10725-11241 L 10708-11478 L 10600-11200 L 10700-11150 L 3050-11150 L 10708-11478 L 10130-11378 R COMP DATE: 04/25/92 R 03/18/92-04/08/92 R 480-10641, MWD R 480-10641, TELECO T 7851-11493, OH-BHCS Page: 1 Date: 04/01/94 RUN DATE_RECVD 1 04/15/92 1 04/15/92 1 05/14/92 1 10/16/92 1 04/15/92 1 07/14/92 1 07/24/92 1 07/14/92 1 04/15/92 1 05/14/92 06/17/92 06/17/92 06/17/92 06/17/92 1 05/14/92 Are dry ditch samples required? ~as the well cored? y es~~~s Are well tests required?~ece ~ell is in compliance I~'~l-ni~i~ yes~d._r_~ived? ~ & description received? ived? ye~ 3omments '~ " STATE OF ALASKA Al: ,A OIL AND GAS CONSERVATION COMMISS~..,:.; REPORT OF SUNDRY WELL OPERATIONS , : ., 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing__ Alter casing Repair well Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2233' SNL, 606'WEL, SEC. 1, T11N, R12E At top of productive interval 1142' NSL, 5279'WEL, SEC. 36, T12N, R12E At effective depth 4750' NSL, 213' WEL, SEC. 35, T12N, R12E At total depth 1383' NSL, 278' WEL, SEC. 35, T12N, R12E 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF K~r~/_,5~,~../feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-30(14-36-12-12) 9. Permit number/approval number 92-30 / 10. APl number 50- 029-22255 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural -- Conductor 110 Surface 3107 Intermediate 10684 Production -- Liner 1022 Perforation depth: measured 11480 feet Plugs (measured) 9192 feet 11397 feet Junk (measured) 9127 feet Size Cemented Measured depth 20 141 13 3/8 3653 c.f. Artic set 111/700 3138 9 5/8 2212 c.f. Class "G" 10715 7 300 c.f. C/ass "G" 10458-11480 10874'- 10908', 10912'- 10922', 10927'- 10978', 10982'- 11010', 11022'- 11054' True vertical depth BKB 141 3014 8595 8394-9212 true vertical subsea8719'-8746', 8749'-8757', 8761 '-8800', 8804'-8825°, 8835'-8860' Tubing (size, grade, and measured depth) 5 1/2" @ 10472' Packers and SSSV (type and measured depth) Packer @ 10398' and SSSV@2100 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 2190 // 2364 550 1920 6770 7556 2810 1940 Tubing Pressure 274 426 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby (;ertify that the fo/r~ioing,i~tr~ue and correct to the best of my knowledge. Signed~[~~'~ ~ /'"[(?¢w,~ Title SeniorTechnicalAssistantl Form 10-40~t'Rev 06/15/88 / SUBMIT IN DdPL'JCATE 9/27/92 10/03/92 f~h 5/12/93 WELL M-30(14-36-12-12) Reperf/Frac The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 10874'- 10922' MD A Frac(Ivishak) was performed using the following fluids: Fluids Pumped: 30 bbls 40# gel prepad to establish rate 138 bbls 40# X-link gel pad w/no esl 42 Dirty 1 PPG 8 Dirty 2 PPG 13 Dirty 3 PPG 20 Dirty 4 PPG 23 Dirty 5 PPG 27 Dirty 6 PPG 28 Dirty 7 PPG 32 Dirty 8 PPG 30 Dirty 9 PPG 311 Dirty 10 PPG 42 Dirty 20# linear gel flush BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 10/12/92 T# 83967 BP PFC Logs Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. H-15~~'~1 PFC M-30 9%')* PFC P-03 ?l.~3~ PFC 10/04/92 #1 09/27/92 #1 10/06/92 #1 11100.00-11397.00 ATLAS 5 " 10725.00-11241.00 ATLAS 5 " 10358.00-10525.00 ATLAS 5 " Information Control Well Records RECEIVED OCT 1 6 1992 Alaska 0tl & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/23/92 T# 83747 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any ~uestions, please contact BP Well Records at (907) 564-4004. ~B-32 ~/,~o INJ 07/11/92 #1 5-32 INJ 07/14/92 #! E-26 ~8-? GAS ENTRY SURVEY 07/07/92 5 " F-46~'/f~ PROD-F 07/01/92 #1 M-30 ~'~ PROD-F 07/06/92 #1 U- 12 ~3'-/~2- PROD-F 06/30/92 ~1 W- 05 ~3 TEMP 07/03/92 ~1 W-40 ~/~/~ TEMP 07/03/92 ~1 X-09 .~ JEWELRY 07/06/92 ~ ~ 5 " IX-09 PROD-F 07/06/92 ~1 IX-09 PROD-F 07/03/92 ~1 ~-32 -~ ~{_~/ PITS 07/13/92 ~1 information Control) ;';ell Records Adrian J. Martin 10250.00-10850.00 CAMCO 5 " 10250.00-10770.00 CD, CO 5 " #1 9000.00- 9147.00 CAMCO 9200.00- 9400.00 CAMCO 5 " 10700.00-11150.00 CAMCO 5 " 10600.00-10901.00 CAMCO 5 " 14200.00-14444.00 CAMCO 5 " 9950.00-10332.00 CAMCO 5 " #1 12830.00-12388.00 CAMCO 11900.00-12320.00 C~CO 5 " 11900.00-12320.00 CAMCO 5 " 11800.00-12750.00 CAMCO 5 " // RECEIVED BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/07/92 T# 83680 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. F-46 PFC M-30 ~..-,~O PRODUCTION LOG Z-19 ~,~ PRODUCTION LOG 06/29/92 #1 07/02/92 #1 07/04/92 %1 07/01/92 #1 10700.00-11149.00 SCH 5 " 8800.00- 9377.00 ATLAS 5 " 10600.00-11200.00 ATLAS 5 " 13950.00-14314.00 SCH 2/5" Information Control Well Records Adrian J. Martin JUL AlaSka 0it & Gas Cons. commiss[or~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/02/92 T~ 83667 BP CASED HOLE FINALS . . · Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. F-39 ye-!~l TEMP M-29 8~-% INJ M-30 ~"~ PROD-F M-31 ~>-~'PROD-F M-321;~~ PROD-F 06/18/92 #1 06/20/92 #1 06/22/92 #1 06/18/92 #1 06/20/92 #1 06/18/92 #1 9200.00- 9753 00 CAMCO 5 " 3000.00-13404 00 CAMCO 2 " 9550.00- 9800 00 CAMCO 5 " 3050.00-11150 00 CAMCO 2/5" 9300.00- 9600 00 CAMCO 5 " 2900.00- 9100 00 CAMCO 2/5" Information Control Well Records Adrian J. Martin RECEIVED dUI 1 4 1992 Alaska Oil & Gas Cons. Commission Anchorage ALASKA .~'AND GAS CONSERVATION WELL COMPLETION OR RECOMP LETION REPORT AND LOG' 1. Status of Well Classification of Service Well OIL [] GAS I-! SUSPEhDED [] ABANDONED [] SERVICE [] 2. Name of Operalor . 7. Permit Number BP Exploration 92-30 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22255 4. Location of well at surface ~ ...................9. Unit or Lease Name ~ COMPL.ETJ0N~ 10. Well Number At Top Producing Interval i,, ,/DA~ ' ~ 1142'NSL, 5279'WEL, SEC. 36, T12N, R12~~_~,~,,j,! VE[~I~IED i::~.,, 11.M'30(14'36'12'12)Field andBayPOOl At Total Depth, -~--,-.,~/"/~ - ~ Prudhoe Field/trudhoe Bay Pool 1383'NSL, 278 WEL, SEC. 35, T12N, R12E~ 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Sedai No. KBE = 57' I ADL 28257 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 3/18/92 473/92 4/25/92 I N/Aeet MSL I ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey J20. Depth where SSSV set Fl. Thickness of Permafrost 11480'MD/9192'TVD 11397'MD/9127'TVD YES E~ N3 [] ! 2100teat MD ! 1910' 22. Type Electric or Other Logs Run DITE/BHC/CNL/GR /R/D 23. CASING, LINER AND CEMENTING REC. OF~ ~ DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20' Cond. Weld Surface 11 O' 30" 13-3/8' 72# L-80 Surface 3138' 17-1/2" 3653 cu ft Arcticsetlll/700 cu ft Class "G" 9-5/8' 47#' L-80 Surface 10715' 12-1/4" 2212 cufl Class "G" 7' 26# 13CR80 10458' 11480' 8-1/2" 300 cu ft Class "G" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4 spf 5-1/2" 104 72' 10398' MD TVD ' 10874'- 10908' 8719'-8746' 26. ACID, FRACTURE, CEMENT SQUEEZe. ETC. 10912'-10922' 8749'-8757' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10927'- 10978' 8761 '-8800' 10982'- 11010' 8804'-8825' 11022'-11054'. 8835'-8860' 27. PRODUCTION TEST Date First Production 1Method of Operation (Flowing, gas lift, etc.) 5/2/92 I Gas Lift Date of Test Hours Tested PRODUC, TIONFOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips. and presence of oil. gas or water. Submit co~cl~~,?_. ~ ~i,~,~ ~ JUN Alaska Oil & Gas Co~s, C(Dmmission ^r~chor~!to Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · ~' .... 30. GEOLOGIC MARKERS {MATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Shublik 10755' 8719' Top Sadlerochit 10873' 8626' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~"~~ ..TitleWorkoverEn~ineerSuoerv[sor Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing toolo Form 10-407 Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. t~ ~D Item 28: I, no cores taken, indicate "none'. R£CF- BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: M-30 NORTH SLOPE PRUDHOE BAY PRUDHOE BAY 50-029-22255 ACCEPT: 03/18/92 12:03 SPUD: RELEASE: 04/07/92 12:04 OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NONE 03/18/92 ( 1) TD: 0'( 0) 03/19/92 ( 2) TD: 1170' (1170) 03/20/92 (3) TD: 2310'(1140) 03/21/92 ( 4) TD: 3155' ( 845) 03/22/92 ( 5) TD: 3155' ( 0) 03/23/92 (6) TD: 3858'( 703) 03/24/92 ( 7) TD: 3952' ( 94) 03/25/92 (8) TD: 5120' (1168) 03/26/92 (9) TD: 6379' (1259) 03/27/92 (10) TD: 7464'(1085) PU BHA MW: 0.0 VIS: 0 TURNKEY RIG MOVE. MIX SPUD & PU BHA & FUNCTION TEST DIVERTER. DRLG AHEAD MW: 9.6 VIS:224 MIX SPUD MUD & PU BHA. TEST LINES & PUMP. GYRO SURV. DRILL TO 682. POH. RIH, WASH & REAM. DRLD TO 1170. DYNA DRLG MW: 9.8 VIS:216 DRLG TO 1432. CBU, POH. CHG MWD & PU DRL ASSY. RIH. SYRO SURV. DRLG TO 2310. REAM TO BOTT MW: 9.8 VIS:197 DRILG TO 2488. CIRC & COND MUD. POH & CHG BITS. RIH, DRLG TO 3155. POH. PU STABS & RIH TO 1956. REAM TO BOTT. NU SPEED HEAD MW: 9.0 VIS: 41 WASH & REAM MOTOR RUN TO 3155. CIRC & COND MUD. RU & RUN JTS, LAND & CIRC. CMT CSG. RD & LD LNDG JTS. ND, NU DP & SPEED HEAD. DRLG AHEAD MW: 9.2 VIS: 39 NU BOPE & TEST. INSTL WEAR RING. LD CSG TOOLS, PU BHA. CUT DRLG LINE. RIH & TAG CMT. FRLG CMT & TEST. DRL FLOAT CLR & CMT TO 3109. TEST CSG. DRLG CMT & SHOE + 10'NEW HOLE. CIRC & LEAK OFF TEST. DRLG. DRLG MW: 9.7 VIS: 45 DRLG TO 4677. CBU & DROP SURV. TRIPPING. WASH & REAM. ATTMPT TO RE-ENTER IN HOLE. DRLG NEW HOLE TO 3952. DRLG 12 1/4" HOLE MW: 9.7 VIS: 41 POH, CHG BHA & RIH. SERV RIG. RIH. DRL TO 4492. PUMP PILL & POH. PU MOTOR-BIT. RIH. DRLG TO 5120. RIH W/BIT #9 MW: 9.7 VIS: 40 DYNA DRILL TO 5530° SHORT TRIP 12 STDS. DRILL TO 6379. POH, CHG BIT & RIH. MW: 9.8 VIS: 43 CUT & SLIP DRLG LINE. CONT RIH. DRILL & SURV TO 7464. WELL : M-30 OPERATION: RIG : NABORS 18E PAGE: 2 03/28/92 (11) TD: 8266' ( 802) 03/29/92 (12) TD: 8904' ( 638) 03/30/92 (13) TD: 9999' (1095) DRLG 12-1/4" HOLE MW: 9.7 VIS: 48 DYNA DRILL & SURV TO 7793. POH, CNG BIT & BHA. RIH. DRLG TO 8266. MW: 9.8 VIS: 49 DRLG TO 8391. CIRC & DROP SNGL SHOT. POH, CHG BIT. RIH, DRLG TO 8904. DRLG 12 1/4" HOLE MW: 9.8 VIS: 38 DRLG TO 9589. CHG SHAKER SCREENS. DRLG TO 9999. 03/31/92 (14) TD:10738' ( 739) POH MW: 9.9 VIS: 45 DRLG TO 10653° CBU CUTTING SAMPLE. DRLG TO 10738. POH. 04/01/92 (15) TD:10783' ( 45) 04/02/.92 (16) TD: 10783' ( 0) 04/03/92 (17) TD:l1480' ( 697) 04/04/92 (18) TD:l1480' ( 0) 04/05/92 (19) TD:l1480 PB: 0 04/06/92 (20) TD:l1480 PB: 0 04/07/92 (21) TD:l1480 PB:11397 RUN 9-5/8 CSG MW:10.0 VIS: 43 POH, PU DRLG ASSY & RIH TO 10738. CIRC & COND MUD. POH. INSTL RAMS, POH & LD BHA. RU & RUN 9-5/8 CSG. DRLG FLOAT COLLAR MW: 9.0 VIS: 34 RUN 9-5/8 CSG & LAND. RU & CIRC. CMT CSG. INSTL TEST PKOFF, CHG UPPER RAMS. TEST BOPE & SET BOWL PROT. RIH W/BHA, TAG CMT @ 10525. DRLG FIRM CMT. TEST CSG DRLG FLOAT COLLAR & CMT. PLEASE NOTE: DUE TO ERROR IN DAILY COST CALCULATIONS COST TO DATE = $1,676,127.96. POOH FOR LOGS. MW: 9.1 VIS: 37 DRLG FLOAT EQUIP, CMT, NEEW HOLE TO 10745' CIRC. DRLG TO 11480'. TD WELL @ 02:30 HRS, 4/3/92. SHORT TRIP TO SHOE. CIRC. POOH. RUNNING 7" LINER MW: 9.1 VIS: 42 POH. RU & LOG. RD LOGGERS. RIH W/BIT. CIRC HI VIS SWEEP. POH & INSTL RAMS. LD BHA & RU TO RUN 7" CR LINER. CUT DRLG LINE MW: 8.6 Seawater PU LINER & HGR & CIRC PIPE COL. RUN LINER ON DP & PU CMT HEAD 7 CIRC. RUN TO BOTT. CIRC & RECIP & CMT LINER. SET PKR. POH, INSTL RAMS. PU BIT & SCRAPER, RIH. CUT DRLG LINE. RUNNING 5.5 TBG MW: 8.6 Seawater RIH W/BIT & CSG SCRAPER. CBU. TEST LAP, CLEAN PIT. DISP MUD W/FILTERED BRINE. CLEAN SHKR PITS & REV CIRC. POH, CHG RAMS, LD BHA. PULL WEAR RING & RU & RUN 5.5 TUBG. SECURE TREE MW: 8.5 Seawater RUN 5.5 TBG & LDNG JT. CHG RAMS. ND BOPE, NU TREE & TEST. DISP BRINE W/DIESEL. SET PKR & TEST. SECURE TREE. WELL : M-30 OPERATION: RIG : NABORS 18E PAGE: 3 04/08/92 (22) TD:l1480 PB:11397 RIG RELEASED MW: 8.5 Seawater FINISH TESTING PKR. INJECT FLUIDS DN BKSIDE. CLEAN PITS. PUMP OUT CELLAR. RIG REL 07-APR-92 12:00. SIGNATURE: (drilling superintendent) DATE: ORIGINAL TELECO OILFIELD SERVICES, INC. ANCHORAGE, ALASKA BP EXPLORATION Well Name Location Date Surveyed Job No. Survey Performed By : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE : MARCH 31, 1992 : 860TAK : BRIAN BANNAN J U N 1 7' '1992 Alaska Oil & Gas Cons. Commission Anchorage.' This survey is correct to the best of my knowledge and is supported by actual field data. ...... COMPANY REPRESENTATIVE NO INTERPOLATION TELECO OILFIELD SERVICES, INC. Client : BP EXPLORATION Well Name : M30 Location : M-PAD : PRUDHOE BAY : NORTH SLOPE No Interpolation Date MARCH 31, 1992 Filename : M-30MERG Plane of Vertical Section : 307.4° Latitude & Departure relate to : PLATFORM CENTER Vertical Section Originates at : PLATFORM CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method · : MINIMUM CURVATURE Magnetic Declination :+30° 0.000'E Platform north : +0° 0' 0'' (T) Grid convergence : +0.0000° TELECO OILFIELD SERVICES, INC. Client : BP EXPLORATION Well Name : M30 Location : M-PAD : PRUDHOE BAY : NORTH SLOPE No Interpolation Page 1 of 3 Date MARCH 31, 1992 Filename : M-30MERG MD CkL INC DIR ft ft deg deg 0 0 0.0 0.0 480 480 1.5 218.0 TVD ft 0.0 479.9 VS ft 0.0 0.0 LAT ft 0.0 -5.0 DEP D'LEG BUILD ft °/100 °/100 0.0 0.0 0.0 -3.9 0.3 0.3 TURN o/lOO 0.0 %-29.6 963 483 0.9 217.0 1385 422 0.4 202.3 1445 60 0.7 261.7 962.8 1384.8 1444.8 0 -0 0 .1 .3 .0 -13 -17 -17 .0 .0 .2 -10.0 0.1 -0.1 -12 . 6 0 . 1 -0 . 1 -13.0 1.0 0.5 -0.2 -3.5 99.0 1539 94 3.2 296.5 1632 93 5.9 306.7 1724 92 8.8 322.1 1817 93 10.5 316.9 1911 94 11.9 308.1 1538.7 1631.4 1722.7 1814.4 1906.6 2.9 -16.1 -16.0 2.8 2.7 10.2 -12.1 -22.1 3.0 2.9 21.8 -3.7 -30.2 3.8 3.2 37.0 8.1 -40.4 2.1 1.8 55.1 20.3 -53.9 2.3 1.5 37.0 11.0 16.7 -5.6 -9.4 2006 95 14.2 312.3 2099 93 16.4 315.5 2193 94 18.8 318.6 2287 94 19.6 313.0 2381 94 20.8 308.4 1999.1 76.5 34.2 -70.2 2.6 2.4 2088.8 100.9 51.2 -87.8 2.5 2.4 2178.4 128.9 72.1 -107.2 2.7 2.6 2267.2 159.5 94.2 -128.7 2.1 0.9 2355.4 191.8 115.3 -153.3 2.1 1.3 4.4 3.4 3.3 -6.0 -4.9 2475 94 22.7 304.2 2569 94 24.0 302.8 2662 93 25.0 299.6 2754 92 28.5 298.2 2849 95 31.4 298.9 2442.7 226.6 135.9 -181.4 2.6 2.0 2529.0 263.8 156.4 -212.5 1.5 1.4 2613.7 302.1 176.4 -245.5 1.8 1.1 2695.8 343.1 196.4 -281.7 3.9 3.8 2778.1 389.9 219.0 -323.4 3.1 3.1 -4.5 -1.5 -3.4 -1.5 0.7 2943 94 33.9 300.4 3036 93 36.2 300.4 3079 43 37.2 299.6 3190 111 38.2 303.2 3284 94 38.0 302.1 2857.3 2933.4 2967.9 3055.7 3129.7 440 493 518 586 644 .2 .2 .7 .2 .0 244.1 -367.4 2.8 2.7 1.6 271.2 -413.5 2.5 2.5 0.0 284.0 -435.8 2.6 2.3 -1.9 319.4 -493.7 2.2 0.9 3.2 350.7 -542.5 0.8 -0.2 -1.2 3378 94 37.5 300.0 3471 93 37.4 301.4 3564 93 38.5 300.7 3659 95 40.5 302.5 3752 93 42.7 302.1 3204.0 3277.8 3351.2 3424.5 3494.0 701 757 814 874 935 .2 .3 .2 .3 .8 38O 409 438 470 503 .4 .2 .7 .4 .4 -591.8 1.5 -0.5 -640.4 0.9 -0.1 -689.4 1.3 1.2 -740.9 2.4 2.1 -793.0 2.4 2.4 -2.2 1.5 -0.8 1.9 -0.4 3847 95 44.8 301.1 3939 92 46.8 300.7 4033 94 47.9 302.8 4128 95 48.6 302.5 4222 94 49.1 304.2 3562.6 3626.8 3690.5 3753.7 3815.6 1001 1066 1135 1206 1276 .1 .7 .5 .1 .7 537 571 608 646 685 .8 -849.0 2.3 2.2 -1.1 .7 -905.6 2.2 2.2 -0.4 .0 -964.4 2.0 1.2 2.2 .3 -1024.0 0.8 0.7 -0.3 .2 -1083.2 1.5 0.5 1.8 4315 93 49.3 303.9 4409 94 50.6 304.9 4505 96 51.9 303.9 4600 95 50.5 303.5 4693 93 49.2 302.8 3876.3 3936.8 3996.9 4056.4 4116.4 1347.0 1418.8 1493.6 1567.5 1638.4 724.6 765.3 807.6 848.6 887.5 -1141.5 0.3 0.2 -0.3 -1200.9 1.6 1.4 1.1 -1262.6 1.6 1.4 -1.0 -1324.2 1.5 -1.5 -0.4 -1383.7 1.5 -1.4 -0.8 TELECO OILFIELD SERVICES, INC. Client : BP EXPLORATION Well Name : M30 Location : M-PAD : PRUDHOE BAY : NORTH SLOPE No Interpolation Page 2 of 3 Date MARCH 31, 1992 Filename : M-30MERG MD C~L INC DIR ft ft deg deg 4787 94 46.8 300.4 4881 94 46.2 304.2 4972 91 44.7 303.9 5065 93 43.6 303.9 5160 95 43.4 304.6 TVD ft 4179.3 4244.0 4307.9 4374.6 4443.5 VS ft 1707.9 1775.8 1840.5 1905.2 1970.5 LAT ft 924.1 960.5 996.9 1033.0 1069.8 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 -1443.2 3.2 -2.6 -2.6 -1500.8 3.0 -0.6 4.0 -1554.6 1.7 -1.6 -0.3 -1608.3 1.2 -1.2 0.0 -1662.4 0.5 -0.2 0.7 5254 94 42.8 304.2 5346 92 42.3 302.8 5438 92 41.9 306.3 5532 94 41.3 307.0 5626 94 42.7 307.4 4512.1 4579.9 4648.2 4718.5 4788.3 2034 2096 2158 2220 2283 .6 .7 .3 .7 .6 1106.1 1140.4 1175.4 1212.6 1250.7 -1715.4 0.7 -0.6 -0.4 -1767.2 1.2 -0.5 -1.5 -1818.0 2.6 -0.4 3.8 -1868.1 0.8 -0.6 0.7 -1918.2 1.5 1.5 0.4 5721 95 43.4 307.7 5816 95 43.5 307.0 5911 95 42.9 308.1 6004 93 42.7 309.1 6100 96 42.0 310.2 4857.7 4926.7 4996.0 5064.2 5135.1 2348 2413 2478 2541 2606 .4 .7 .8 .9 .6 1290 1329 1369 1408 1450 .2 .8 .4 .9 .1 -1969.6 0.8 0.7 0.3 -2021.6 0.5 0.1 -0.7 -2073.1 1.0 -0.6 1.2 -2122.5 0.8 -0.2 1.1 -2172 . 3 1.1 -0.7 1.1 6195 95 42.0 312.0 6287 92 41.0 311.3 6383 96 39.7 310.9 6478 95 38.4 311.3 6572 94 36.5 313.7 5205.8 5274.7 5347.8 5421.6 5496.2 2670 2730 2792 2852 2909 .0 .8 .8 .5 .4 1491 1532 1573 1612 1651 .9 .4 .3 .6 .2 -2220.2 1.3 0.0 1.9 -2265.7 1.2 -1.1 -0.8 -2312.6 1.4 -1.4 -0.4 -2357.7 1.4 -1.4 0.4 -2399.8 2.5 -2.0 2.6 6666 94 38.5 312.0 6759 93 39.6 313.4 6851 92 41.0 309.1 6946 95 41.7 308.1 7040 94 42.5 305.6 5570.8 5643.0 5713.2 5784.5 5854.3 2966 3024 3084 3146 3209 .4 .7 .1 .8 .8 1690 1729 1769 1808 1846 .1 .8 .0 .2 .0 -2441.8 2.4 2.1 -1.8 -2484.8 1.5 1.2 1.5 -2529.6 3.4 1.5 -4.7 -2578.6 1.0 0.7 -1.1 -2629.0 2.0 0.9 -2.7 7134 94 44.7 305.6 7229 95 43.9 308.1 7322 93 42.5 306.0 7418 96 44.6 303.5 7512 94 45.7 303.2 7606 94 43.6 305.3 7701 95 42.4 305.6 7795 94 42.3 305.6 7889 94 44.5 303.5 7985 96 45.2 304.6 5922.3 5990.3 6058.1 6127.7 6194.0 6260.9 6330.3 6399.8 6468.1 6536.2 3274 3340 3404 3470 3537 3603 3667 3731 3795 3863 .6 .9 .6 .7 .1 .1 .8 .1 .6 .2 1883 1923 1961 1999 2036 2073 2110 2147 2184 2222 .7 .5 .8 .5 .1 .3 .9 .7 .3 .3 -2681.7 2.3 2.3 0.0 -2734.8 2.0 -0.8 2.6 -2785.6 2.2 -1.5 -2.3 -2840.0 2.8 2.2 -2.6 -2895.6 1.2 1.2 -0.3 -2950.3 2.7 -2.2 2.2 -3003.0 1.3 -1.3 0.3 -3054 . 5 0.1 -0.1 0.0 -3107.7 2.8 2.3 -2.2 -3163.8 1.1 0.7 1.1 8080 95 44.6 303.9 8174 94 44.5 304.2 8268 94 44.2 305.3 8361 93 43.4 306.3 8455 94 43.2 305.6 6603.5 6670.4 6737.7 6804.8 6873.2 3930.2 3996.0 4061.6 ~126.0 4190.4 2260.0 2296.9 2334.4 2372.0 2409.9 -3219.2 0.8 -0.6 -0.7 -3273.9 0.2 -0.1 0.3 -3327.9 0.9 -0.3 1.2 -3380.1 1.1 -0.9 1.1 -3432.3 0.6 -0.2 -0.7 TELECO OILFIELD SERVICES, Client : BP EXPLORATION Well Name : M30 Location : M-PAD : PRUDHOE BAY : NORTH SLOPE No Interpolation MD CkL INC DIR TVD VS ft ft deg deg ft ft 8550 95 43.9 306.0 6942.1 4255.9 8650 100 44.5 306.3 7013.7 4325.6 8744 94 43.3 305.3 7081.5 4390.7 8838 94 43.7 305.6 7149.7 4455.4 8929 91 44.0 306.7 7215.3 4518.4 LAT ft 2448.2 2489.3 2527.4 2564.9 2602.1 9021 92 42.0 307.7 7282.6 4581.1 9114 93 41.4 306.7 7352.0 4643.0 9208 94 40.8 308.8 7422.8 4704.8 9302 94 39.6 307.7 7494.6 4765.5 9396 94 40.2 309.5 7566.8 4825.7 2640.1 2677.5 2715.3 2752.8 2790.5 9490 94 39.8 309.5 7638.8 4886.1 9585 95 38.4 309.1 7712.5 4946.0 9680 95 38.6 309.5 7786.8 5005.1 9775 95 38.7 308.1 7861.0 5064.4 9870 95 38.7 308.8 7935.2 5123.8 2828.9 2866.8 2904.3 2941.5 2978.4 9965 95 38.3 307.4 8009.5 5182.9 10060 95 38.3 307.0 8084.1 5241.8 10153 93 39.0 308.1 8156.7 5299.9 10248 95 38.9 309.8 8230.6 5359.6 10343 95 38.7 309.5 8304.6 5419.1 3014.9 3050.5 3085.9 3123.4 3161.4 10436 93 38.2 309.1 8377.5 5476.9 10529 93 38.6 309.5 8450.3 5534.6 10641 112 38.9 310.2 8537.7 5604.6 3198.1 3234.6 3279.6 INC. Page 3 of 3 Date MARCH 31, 1992 Filename : M-30MERG DEP D'LEG BUILD TURN ft /100 /100 /100 -3485.4 0.8 0.7 0.4 -3541.6 0.6 0.6 0.3 -3594.5 1.5 -1.3 -1.1 -3647.2 0.5 0.4 0.3 -3698.1 0.9 0.3 1.2 -3748.1 2.3 -2.2 1.1 -3797.4 1.0 -0.6 -1.1 -3846.2 1.6 -0.6 2.2 -3893.9 1.5 -1.3 -1.2 -3941.0 1.4 0.6 1.9 -3987.6 0.4 -0.4 0.0 -4034.0 1.5 -1.5 -0.4 -4079.7 0.3 0.2 0.4 -4126.0 0.9 0.1 -1.5 -4172.5 0.5 0.0 0.7 -4219.0 1.0 -0.4 -1.5 -4265.9 0.3 0.0 -0.4 -4312.0 1.1 0.8 1.2 -4358.4 1.1 -0.1 1.8 -4404.2 0.3 -0.2 -0.3 -4449.0 0.6 -0.5 -0.4 -4493.7 0.5 0.4 0.4 -4547.5 0.5 0.3 0.6 Origin of Bottom Hole Closure PLATFORM CENTRE Bottom Hole Closure 5607 ft 305.8° 100 ' IN'i'Ei~,I:~OLA~E'ED ME~UI~,3~D DEP'I'H TELECO OILFIELD SERVICES, INC. ANCHORAGE, ALASKA BP EXPLORATION Well Name Location Date Surveyed Job No. Survey Performed By : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE : MARCH 31, 1992 : 860TAK : BRIAN BANNAN This survey is correct to the best of my knowledge and is supported by actual field data. ...... COMPANY REPRESENTATIVE TELECO OILFIELD SERVICES, INC. Client : BP EXPLORATION Well Name : M30 Location : M-PAD : PRUDHOE BAY : NORTH SLOPE Date MARCH 31, 1992 Filename : M-30MERG Interpolated 100 ft of MD Plane of Vertical Section : 307.4° Latitude & Departure relate to : PLATFORM CENTER Vertical Section Originates at : PLATFORM CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30° 0.000'E Platform north : +0° 0' 0'' (T) Grid convergence : +0.0000° Client Well Name Location TELECO OILFIELD SERVICES, : BP EXPLORATION : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE INC. Page 1 of 3 Date MARCH 31, 1992 Filename : M-30MERG Interpolated 100 ft of MD MD ft 0 100 200 300 400 50O 600 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 C~L ft 0 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 INC DIR deg deg 0.0 0.0 0.3 45.4 0.6 90.8 0.9 136.3 1.3 181.7 1.5 218.0 1.4 217.8 1.2 217.5 1.1 217.3 1.0 217.1 0.9 215.7 0.7 212.2 0.6 208.7 0.5 205.3 0.5 217.2 2.2 282.1 5.0 303.2 8.0 318.1 10.2 317.9 11.7 309.1 14.1 312.0 16.4 315.5 18.9 318.2 19.8 312.4 21.2 307.6 23.0 303.8 24.3 301.7 26.4 299.0 29.9 298.5 32.8 299.7 35.3 300.4 37.4 300.3 38.2 303.1 37.9 301.7 37.5 300.3 37.7 301.2 39.3 301.4 41.5 302.3 43.8 301.6 46.0 300.9 TVD ft 0.0 100.0 200.0 300.0 400.0 499.9 599.9 699.9 799.9 899.9 999.8 1099.8 1199.8 1299.8 1399.8 1499.8 1599.5 1698.9 1797.6 1895.8 1993.3 2089.8 2185.0 2279.4 2373.1 2465.7 2557.2 2647.6 2735.7 2821.0 2903.9 2984.5 3063.6 3142.3 3221.5 3300.7 3378.9 3455.1 3528.7 3599.6 VS ft 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.0 0.0 -0.1 -0.2 -0.2 1.7 7.7 18.7 34.2 53.0 75.2 101.2 131.2 163.9 198.9 236.5 276.6 319.0 365.8 417.2 472.7 531.5 592.3 653.7 714.5 775.1 837.0 901.4 968.8 1038.9 LAT ft 0.0 -1.0 -2.1 -3.1 -4.1 -5.3 -6.9 -8.6 -10.3 -11.9 -13.3 -14.3 -15.2 -16.2 -17.0 -16.6 -13.5 -5.9 5.9 18.9 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0.0 0.0 0.0 0.0 -0.8 0.3 0.3 45.4 -1.6 0.5 0.3 45.4 -2.4 0.7 0.3 45.4 -3.2 0.9 0.3 45.4 -4.1 0.9 0.2 36.3 -5.4 0.1 -0.1 -0.2 -6.7 0.1 -0.1 -0.2 -8.0 0.1 -0.1 -0.2 -9.2 0.1 -0.1 -0.2 -10.3 0.1 -0.1 -1.4 -10.9 0.1 -0.1 -3.5 -11.5 0.1 -0.1 -3 . 5 -12.1 0.1 -0.1 -3.5 -12.7 0.1 -0.0 11.9 -14.7 2.0 1.7 64.9 -20.0 3.1 2.8 21.1 -28.1 3.5 3.1 14.9 -38.5 2.1 2.1 -0.2 -52.3 2.3 1.5 -8.7 418.4 -655.7 0.6 0.3 0.9 450.7 -708.9 1.5 1.5 0.2 484.9 -763.9 2.3 2.2 0.9 520.8 -821.3 2.3 2.3 -0.7 557.3 -881.6 2.3 2.2 -0.7 260.7 -395.7 2.6 2.6 0.7 290.7 -446.7 2.1 2.1 -0.1 322.7 -498.8 1.9 0.8 2.8 355.7 -550.9 0.9 -0.3 -1.3 387.2 -603.3 1.0 -0.4 -1.4 141.3 -189.7 2.3 1.9 -3.7 163.1 -223.5 1.5 1.3 -2.1 184.6 -260.4 2.4 2.1 -2.7 207.3 -301.9 3.5 3.5 -0.5 232.6 -347.3 2.9 2.9 1.2 33.3 -69.2 2.4 2.3 2.9 51.5 -88.0 2.5 2.4 3.5 73.7 -108.8 2.6 2.4 2.6 97.1 -132.1 2.1 0.9 -5.8 119.5 -159.0 2.2 1.4 -4.8 Client Well Name Location TELECO OILFIELD SERVICES, : BP EXPLORATION : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE INC. Page 2 of 3 Date MARCH 31, 1992 Filename : M-30MERG Interpolated 100 ft of MD MD ft 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 C~L INC DIR TVD VS ft deg deg ft ft 100 47.5 302.1 3668.1 1111.3 100 48.4 302.6 3735.1 1185.3 100 49.0 303.8 3801.1 1260.2 100 49.3 303.9 3866.5 1335.7 100 50.5 304.8 3931.0 1412.0 100 51.8 304.0 3993.8 100 50.5 303.5 4056.4 100 49.0 302.6 4121.1 100 46.7 300.9 4188.2 100 45.9 304.1 4257.3 5000 100 44.4 303.9 5100 100 43.5 304.2 5200 100 43.1 304.4 5300 100 42.5 303.5 5400 100 42.1 304.9 5500 100 41.5 306.8 5600 100 42.3 307.3 5700 100 43.2 307.6 5800 100 43.5 307.1 5900 100 43.0 308.0 6000 100 42.7 309.1 6100 100 42.0 310.2 6200 100 41.9 312.0 6300 100 40.8 311.2 6400 100 39.5 311.0 6500 100 38.0 311.9 6600 100 37.1 313.2 6700 100 38.9 312.5 6800 100 40.2 311.5 6900 100 41.4 308.6 7000 100 42.2 306.7' 7100 100 43.9'''' 305,6 7200 100 44.1 307.3 7300 100 42.8 ~306.5 7400 100 44.2~' 370~.0 7500 100 45.6 ?303.2 7600 190 ~43.7 305.2 7700 100 42..4 ~ 305.6 7800 10Q 42 4''~ 305.5 7900 100 44.6 303.6 4327.9 4400.0 4472.7 4546.0 4620.0 4694.5 4769.0 4842.4 4915.1 4987.9 5061.3 5135.1 5209.5 5284.6 5361.0 5439.1 5518.4 5597.2 5674.3 .5750.0 5824.6 5897..7 5969.6 6042.1 611'4.6 6185.5 6256.6 6329.6 6403.4 6475.9 1489.7 1567.5 1643.6 1717.3 1789.3 1860.0 1929.2 1997.8 2065.6 2132.8 2199.4 2266.2 2334.1 2402.7 2471.2 2539.2 2606'.6 2673.3 2739.2 2803.5 2865.8 2926.4 2987.7 3051.2 3116.4 3183.0 3251.2 3320.7 3389.5 3458.3 3528.6 3598.9 3667.1 3734.6 3803.4 LAT ft 595.3 635.0 676.1 718.3 761.4 805.4 848.6 890.2 929.2 968.1 1007.7 1046.5 1085.2 1123.2 1160.9 1199.9 1240.1 1281.4 1323.1 1364.9 1407.2 1450..1 1494.1 1538..0 1580.3 1621.7 1662.8 1704.6 1747.3 1789.2 1829.9 1870.1 1911.3 1952.8 1992.5 2031.5 2070.9 2110.5 2149.7 2188.7 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 -943.7 1.8 1.6 1.2 -1006.5 1.0 0.9 0.5 -1069.3 1.1 0.6 1.2 -1132.1 0.3 0.3 0.1 -1195.2 1.4 1.2 0.9 -1259.4 1.5 1.4 -0.9 -1324.2 1.4 -1.3 -0.5 -1388.2 1.6 -1.5 -0.9 -1451.2 2.6 -2.3 -1.7 -1512.0 2.5 -0.8 3.2 -1570.7 1.5 -1.5 -0.2 -1628.2 0.9 -0.8 0.3 -1684.9 0.4 -0.4 0.3 -1741.3 0.9 -0.6 -0.9 -1797.1 1.0 -0.5 1.4 -1851.1 1.4 -0.6 1.9 -1904.3 0.9 0.8 0.5 -1958.2 1.0 0.9 0.3 -2012.8 0.4 0.2 -0.5 -2067.1 0.8 -0.5 0.9 -2120.4 0.8 -0.3 1.1 -2172.3 1.0 -0.7 1.1 -2222.7 1.2 -0.1 1.8 -2272.1 1.2 -1.1 -0.7 -2320.6 1.4 -1.4 -0.3 -2367.5 1.6 -1.5 0.9 -2412.3 1.2 -0.9 1.3 -2457.5 1.9 1.8 -0.7 -2504 . 8 1.5 1.3 -1.0 -2554.9 2.2 1.1 -2.9 -2607.6 1.5 0.8 -1.9 -2662.7 1.9 1.7 -1.1 -2718.6 1.2 0.2 1.7 -2773.6 1.4 -1.3 -0.8 -2829.8 2.2 1.4 -2.5 -2888.5 1.4 1.4 -0.7 -2946.8 2.3 -1.8 1.9 -3002.5 1.4 -1.3 0.4 -3057.4 0.1 0.0 -0.1 -3114.2 2.5 2.2 -1.9 Client Well Name Location TELECO OILFIELD SERVICES, : BP EXPLORATION : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE INC. Page 3 of 3 Date MARCH 31, 1992 Filename : M-30MERG Interpolated 100 ft of MD MD C~L INC DIR TVD VS ft ft deg deg ft ft 8000 100 45.1 304.5 6546.8 3873.8 8100 100 44.6 304.0 6617.7 3944.2 8200 100 44.4 304.5 6689.0 4014.2 8300 100 43.9 305.6 6760.8 4083.8 8400 100 43.3 306.0 6833.2 4152.7 8500 100 43.5 305.8 6905.8 4221.4 8600 100 44.2 306.1 6977.9 4290.7 8700 100 43.9 305.8 7049.8 4360.2 8800 100 43.5 305.5 7122.1 4429.2 8900 100 43.9 306.3 7194.4 4498.3 9000 100 42.5 307.5 7267.2 4566.8 9100 100 41.5 306.9 7341.6 4633.7 9200 100 40.9 308.6 7416.8 4699.5 9300 100 39.6 307.7 7493.1 4764.2 9400 100 40.2 309.5 7569.8 4828.3 9500 100 39.7 309.5 7646.5 4892.4 9600 100 38.4 309.2 7724.2 4955.3 9700 100 38.6 309.2 7802.5 5017.6 9800 100 38.7 308.3 7880.5 5080.0 9900 100 38.6 308.4 7958.7 5142.5 10000 100 38.3 307.3 8037.0 5204.6 10100 100 38.6 307.5 8115.3 5266.8 10200 100 39.0 308.9 8193.3 5329.4 10300 100 38.8 309.6 8271.1 5392.1 10400 100 38.4 309.3 8349.3 5454.5 10500 100 38.5 309.4 8427.6 5516.6 10641 141 38.9 310.2 8537.7 5604.6 LAT ft 2228.2 2267.9 2307.3 2347.3 2387.7 2428.0 2468.7 2509.6 2549.8 2590.3 2631.4 2671.8 2712.1 2752.0 2792.1 2832.9 2872.8 2912.1 2951.2 2989.9 3028.0 3065.7 3104.5 3144.2 3183.9 3223.2 3279.6 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 -3172.6 0.8 0.5 0.9 -3230.9 0.6 -0.5 -0.5 -3288.8 0.4 -0.2 0.5 -3345.8 0.9 -0.5 1.1 -3401.7 0.7 -0.6 0.4 -3457.4 0.3 0.2 -0.2 -3513.5 0.7 0.7 0.4 -3569.8 0.4 -0.3 -0.4 -3625 . 9 0 . 4 -0 . 3 -0 . 3 -3681.9 0.7 0.4 0.9 -3736.7 1.6 -1.4 1.1 -3790.0 1.1 -1.0 -0.6 -3842.1 1.3 -0.6 1.8 -3892.9 1.4 -1.2 -0.9 -3943.0 1.3 0.6 1.8 -3992.5 0.5 -0.5 -0.0 -4041.2 1.2 -1.2 -0.3 -4089.5 0.2 0.2 0.0 -4138.2 0.6 0.1 -0.9 -4187.2 0.1 -0.1 0.1 -4236.3 0.7 -0.3 -1.1 -4285.7 0.3 0.3 0.2 -4334.9 1.0 0.3 1.5 -4383.5 0.5 -0.2 0.7 -4431.7 0.5 -0.4 -0.4 -4479.8 0.1 0.1 0.1 -4547.5 0.8 0.5 0.9 Origin of Bottom Hole Closure PLATFORM CENTRE Bottom Hole Closure 5607 ft 305.8° 100 ' Ilq'I']~RPOLA'I']~D ~ TELECO OILFIELD SERVICES, INC. ANCHORAGE, ALASKA BP EXPLORATION Well Name Location Date Surveyed Job No. Survey Performed By : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE : MARCH 31, 1992 : 860TAK : BRIAN BANNAN This survey is correct to the best of my knowledge and is supported by actual field data. COMPANY REPRESENTATIVE TELECO OILFIELD SERVICES, INC. Client : BP EXPLORATION Well Name : M30 Location : M-PAD : PRUDHOE BAY : NORTH SLOPE Date MARCH 31, 1992 Filename : M-30MERG Interpolated 100 ft of TVD Plane of Vertical Section : 307.4° Latitude & Departure relate to : PLATFORM CENTER Vertical Section Originates at : PLATFORM CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30° 0.000'E Platform north : +0° 0' 0'' (T) Grid convergence : +0.0000° Client Well Name Location TELECO OILFIELD SERVICES, : BP EXPLORATION : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE INC. Page 1 of 3 Date MARCH 31, 1992 Filename : M-30MERG Interpolated 100 ft of TVD MD C~L INC DIR ft ft deg deg 0 0 0.0 0.0 100 100 0.3 45.4 200 100 0.6 90.8 300 100 0.9 136.3 400 100 1.3 181.7 5OO 600 700 8OO 900 1000 1100 1200 1300 1400 1500 1600 1701 1802 1904 2007 2111 2216 2322 2429 2537 2647 2759 2875 2995 3120 3246 3373 3499 3627 3760 3901 4047 4198 4352 100 100 100 100 100 100 100 100 100 100 1.5 218.0 1.4 217.8 1.2 217.5 1.1 217.3 1.0 217.1 TVD ft 0.0 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 90O.O 0.9 215.7 1000.0 0.7 212.2 1100.0 0.6 208.7 1200.0 0.5 205.3 1300.0 0.5 217.3 1400.0 100 2.2 282.1 1500.0 100 5.0 303.2 1600.0 101 8.1 318.3 1700.0 101 10.2 317.7 1800.0 102 11.8 308.7 1900.0 103 14.2 312.3 2000.0 104 16.7 315.9 2100.0 105 19.0 317.2 2200.0 106 20.0 311.3 2300.0 107 21.8 306.3 2400.0 108 23.6 303.3 2500.0 110 24.8 300.1 2600.0 112 28.6 298.2 2700.0 116 32.1 299.3 2800.0 120 35.2 300.4 2900.0 124 37.6 300.9 3000.0 127 38.1 302.5 3100.0 127 37.5 300.1 3200.0 126 37.7 301.2 3300.0 128 39.8 301.9 3400.0 133 42.9 302.0 3500.0 140 46.0 300.9 3600.0 147 48.0 302.8 3700.0 151 49.0 303.8 3806.0 , 153 49.8 304.3 3900.0 VS ft 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.1 0.0 0.0 -0.1 -0.2 -0.2 1.7 7.7 18.9 34.6 53.8 76.8 104.4 136.3 171.5 209.6 251.3 295.9 345.5 403.8 470.0 543.4 620.8 698.1 774.5 854.2 941.5 1039.3 1146.1 1258.9 1375.1 LAT ft 0.0 -1.0 -2.1 -3.1 -4.1 -5.3 -6.9 -8.6 -10.3 -11.9 -13.3 -14.3 -15.2 -16.2 -17.0 -16.6 -13.5 -5.8 6.2 19.4 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 0.0 0.0 0.0 0.0 -0.8 0.3 0.3 45.4 -1.6 0.5 0.3 45.4 -2.4 0.7 0.3 45.4 -3.2 0.9 0.3 45.4 -4.1 0.9 0.2 36.3 -5.4 0.1 -0.1 -0.2 -6.7 0.1 -0.1 -0.2 -8.0 0.1 -0.1 -0.2 -9.2 0.1 -0.1 -0.2 -10.3 0.1 -0.1 -1.4 -10.9 0. 1 -0.1 -3.5 -11.5 0.1 -0.1 -3.5 -12.1 0. 1 -0. 1 -3.5 -12.7 0.1 -0.0 12.1 -14.8 2.0 1.7 64.8 -20.0 3.1 2.8 21.0 -28.2 3.5 3.1 14.9 -38.8 2.1 2.1 -0.5 -52.9 2.3 1.5 -8.8 34.4 -70.4 2.5 2.4 3.5 53.8 -90.2 2.6 2.4 3.4 77.4 -112.4 2.2 2.2 1.3 102.0 -137.9 2.1 1.0 -5.6 125.8 -167.7 2.3 1.6 -4.7 149.5 173.2 197.5 226.0 259.3 -202.0 2.0 1.7 -2.8 -240.1 1.7 1.2 -2.9 -283.8 3.5 3.4 -1.7 -335.6 3.0 3.0 0.9 -393.3 2.6 2.6 0.9 296.9 -456.9 1.9 1.9 0.4 338.1 -522.9 0.9 0.4 1.3 378.8 -589.1 1.3 -0.4 -1.9 418.1 -655.2 0.5 0.2 0.9 459.8 -723.7 1.7 1.6 0.6 506.4 557.5 613.8 675.4 740.5 -797.9 2.3 2.3 0.1 -882.0 2.3 2.2 -0.8 -973.4 1.7 1.4 1.3 -1068.3 0.8 0.6 0.7 -1164.7 0.6 0.5 0.3 Client Well Name Location TELECO OILFIELD SERVICES, : BP EXPLORATION : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE INC. Page 2 of 3 Date MARCH 31, 1992 Filename : M-30MERG Interpolated 100 ft of TVD MD ft 4510 4668 4817 4961 5100 5237 5373 5507 5642 5779 5917 6052 6187 6320 6450 6577 6704 6834 6967 7103 7242 7380 7520 7660 7795 7934 8075 8215 8354 8492 8631 8770 8908 9044 9178 9309 9439 9569 9697 9825 CkL INC DIR TVD ft deg deg ft 158 51.8 303.9 4000.0 158 49.6 303.0 4100.0 150 46.6 301.6 4200.0 144 44.9 303.9 4300.0 139 43.5 304.2 4400.0 137 136 134 135 137 137 136 135 133 130 127 127 130 133 136 139 138 141 139 136 139 141 140 139 138 139 139 138 137 133 131 130 130 128 128 VS ft 1497.5 1619.0 1729.6 1832.5 1929.3 LAT ft 809.7 876.9 935.8 992.4 1046.6 42.9 304.3 4500.0 2023.3 1099.7 42.2 303.8 4600.0 2114.8 1150.7 41.5 306.8 4700.0 2204.3 1202.8 42.8 307.5 4800.0 2294.5 1257.3 43.5 307.3 4900.0 2388.4 1314.5 42.9 308.2 5000.0 2482.5 1371.8 42.3 309.7 5100.0 2574.5 1429.7 42.0 311.9 5200.0 2664.8 1488.5 40.5 311.2 5300.0 2752.3 1546.6 38.8 311.2 5400.0 2835.0 1601.1 36.6 313.6 5500.0 2912.3 38.9 312.6 5600.0 2990.0 40.7 309.9 5700.0 3072.9 41.9 307.5 5800.0 3160.8 44.0 305.6 5900.0 3253.4 43.7 307.8 43.8 304.5 45.5 303.4 42.9 305.5 42.3 305.6 44.8 304.0 44.6 303.9 44.4 304.7 43.5 306.2 43.5 305.8 6000.0 6100.0 6200.0 6300.0 6400.0 6500.0 6600.0 6700.0 6800.0 6900.0 7000.0 7100.0 7200.0 7300.0 7400.0 7500.0 7600.0 7700.0 7800.0 7900.0 44.4 306.2 43,4 305.4 43.9 306.4 41.8 307.4 41.0 308.1 3350.0 3444.4 3543.1 3639.6 3731.3 3827.3 3926.7 4024.9 4121.4 4215.9 4312.2 4408.3 4503.7 4596.7 4684.9 4769.9 4853.6 4935.8 5015.6 5095.6 39.6 307.8 40.0 309.5 38.6 309.2 38.6 309.3 38.7 308.5 1653.2 1706.2 1761.7 1816.6 1871.3 1929.0 1984.5 2039.5 2094.5 2147.8 2202.1 2258.1 2313.4 2369.3 2424.8 2481.4 2537.6 2593.5 2649.4 2703.1 2755.6 2808.2 2860.4 2910.9 2960.9 DEP D' LEG BUILD TURN ft °/100 °/100 °/100 -1265.8 1.3 1.3 -0.3 -1367.5 1.5 -1.4 -0.6 -1461.6 2.1 -2.0 -0.9 -1547.9 1.7 -1.2 1.6 -1628.3 1.0 -1.0 0.2 -1706.0 0.5 -0.5 0.1 -1782.2 0.6 -0.5 -0.3 -1854.9 1.6 -0.5 2.2 -1926.9 1.1 1.0 0.5 -2001.4 0.5 0.5 -0.1 -2076.0 0.6 -0.4 0.6 -2147.6 0.8 -0.4 1.1 -2216.3 1.1 -0.3 1.6 -2282.0 1.1 -1.1 -0.5 -2344.5 1.4 -1.4 0.0 -2401.9 2.1 -1.7 1.9 -2459.2 1.9 1.8 -0.8 -2521.2 1.9 1.4 -2.0 -2589.8 1.5 0.9 -1.8 -2664.5 1.8 1.5 -1.4 -2742.1 1.1 -0.2 1.6 -2818.3 1.7 0.0 -2.4 -2900.6 1.4 1.2 -0.8 -2980.0 2.1 -1.9 1.5 -3054.7 0.5 -0.5 0.1 -3134.0 2.0 1.8 -1.1 -3216.4 0.1 -0.1 -0.1 -3297.6 0.4 -0.2 0.5 -3376.4 1.0 -0.7 1.1 -3452.9 0.2 0.0 -0.3 -3530.9 0.7 0.7 0.4 -3608.8 0.8 -0.7 -0.6 -3686.3 0.7 0.4 0.8 -3760.5 1.6 -1.5 0.7 -3830.5 0.7 -0.6 0.5 -3897.4 1.0 -1.0 -0.2 -3962.5 0.9 0.3 1.3 -4026.1 1.1 -1.1 -0.3 -4087 . 9 0 . 0 -0.0 0.1 -4150.4 0.4 0.1 -0.6 Client Well Name Location TELECO OILFIELD SERVICES, : BP EXPLORATION : M30 : M-PAD : PRUDHOE BAY : NORTH SLOPE INC. Page 3 of 3 Date MARCH 31, 1992 Filename : M-30MERG Interpolated 100 ft of TVD MD C~L INC DIR TVD VS ft ft deg deg ft ft 9953 128 38.4 307.6 8000.0 5175.3 10080 128 38.5 307.2 8100.0 5254.5 10209 128 38.9 309.1 8200.0 5334.9 10337 128 38.7 309.5 8300.0 5415.3 10465 128 38.3 309.2 8400.0 5494.7 10641 176 38.9 310.2 8537.7 5604.6 LAT ft 3010.2 3058.3 3107.9 3159.1 3209.4 3279.6 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 -4213.1 0.5 -0.3 -0.7 -4276.0 0.2 0.1 -0.3 -4339.2 1.0 0.4 1.4 -4401.4 0.3 -0.2 0.3 -4462.8 0.3 -0.3 -0.2 -4547.5 0.4 0.1 0.5 Origin of Bottom Hole Closure PLATFORM CENTRE Bottom Hole Closure 5607 ft 305.8° PRUDHOE BAY DRILLING M-30 SIDETRACKED @ 3471 MD Alaska Oil &. Gas Cons. GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY PRUDHOE BAY DRILLING COMPANY M-30 WELL NAME PRUDHOE BAY LOCATION AL392D10 MWD 04/03/92 JOB NUMBER DON LEJEUNE NAME TYPE SURVEY DATE DEPTH INTERVAL DATE SURVEY TAKEN 0.00 FT 10641. FT FROM TO 03/16/92 03/31/92 FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. ;REAT LAND DIRECTIONAL DRILLING, :lient .... : ~ield ..... : lell · ~ection at: ~ngineer..: PRUDHOE BAY DRILLING PRUDHOE BAY M-30 N,52.63,W DON LEJEUNE INC. MEAS INCLN DEPTH ANGLE 480 1.50 963 0.90 1385 0.40 1445 0.70 1539 3.20 RECORD OF SURVEY VERTICAL-DEPTHS SECTION DIRECTION BKB SUB-SEA DISTNCE BEARING 479.9 448.8 962.8 931.7 1384.8 1353.7 1444.8 1413.7 1538.7 1507.6 1632 5.90 1631.4 1600.3 1724 8.80 1722.7 1691.5 1817 10.50 1814.4 1783.2 1911 11.90 1906.6 1875.4 2006 14.20 1999.1 1968.0 2099 16.40 2088.8 2057.7 2193 18.80 2178.4 2147.3 2287 19.60 2267.2 2236.1 2381 20.80 2355.4 2324.3 2475 22.70 2442.7 2411.6 2569 24.00 2529.0 2497.9 2662 25.00 2613.7 2582.5 2754 28.50 2695.8 2664.7 .2849 31.40 2778.1 2747.0 2943 33.90 2857.3 2826.1 3036 36.20 2933.4 2902.2 'Survey Codes: 3/MWD iGLDD (c) 92 PM30D B1.30 9:01 AM 2) Computation...: Survey Date...: KB Elevation..: Reference ..... : Magnetic Dcln.: 04/03/92 MINIMUM CURVATURE 03/31/92 31.15 ft AL392D10 30.00 E 0.1 ' S 38.00 W' 0.1 S 37.00 W -0.3 S 22.30 W -0.1 S 81.70 W 2.9 N 63.50 W 10.2 N 53.30 W 21.8 N 37.90 W 37.0 N 43.10 W 55.1 N 51.90 W 76.5 N 47.70 W 100.9 N 44.50 W 128.9 N 41.40 W 159.5 N 47.00 W 191.8 N 51.60 W 226.6 N 55.80 W 263.8 N 57.20 W 302.1 N 60.40 W 343.1 N 61.80 W 389.9 N 61.10 W 440.2 N 59.60 W 493.2 N 59.60 W RELATIVE-COORDINATES FROM-WELL-HEAD 5.0 S 3.9 W 13.0 S 10.0 W 17.0 S 12.6 W 17.2 S 13.0 W 16.1 S 16.0 W 12.1 S 22.1 W 3.7 S 30.2 W 8.1 N 40.4 W 20.3 N 53.9 W 34.2 N 70.2 W 51.2 N 87.8 W 72.1 N 107.2 W 94.2 N 128.7 W 115.3 N 153.3 W 135.9 N 181.4 W 156.4 N 212..5 W 176.4 N 245.5 W 196.4 N 281.7 W 219.0 N 323.4 W 244.1 N 367.4 W 271.2 N 413.5 W CLOSURE DL DISTNCE BEARING /100 6.3 S 38.00 W 0.31 16.4 S 37.77 W 0.12 21.1 S 36.58 W 0.12 21.6 S 37.13 W 1.01 22.7 S 44.69 W 2.82 25.2 S 61.28 W 3.02 30.5 S 82.96 W 3.78 41.2 N 78.70 W 2.05 57.6 N 69.35 W 2.35 78.1 N 64.03 W 2.62 101.7 N 59.75 W 2.53 129.1 N 56.08 W 2.74 159.5 N 53.81 W 2.14 191.8 N 53.06 W 2.12 226.6 N 53.17 W 2.61 263.8 N 53.64 W 1.50 302.3 N 54.30 W 1.79 343.4 N 55.12 W 3.87 390.6 N 55.89 W 3.07 441.1 N 56.40 W 2.80 494.5 N 56.74 W 2.47 [-30 MEAS INCLN DEPTH ANGLE o79 3190 38.20 3284 38.00 3378 37.50 3471 37.40 3564 38.50 3649 40.50 3752 42.70 3847 44.80 3939 46.80 4033 47.90 4128 48.60 4222 49.10 4315 49.30 4409 50.60 4505 51.90 4600 50.50 4693 49.20 4787 46.80 4881 46.20 4972 44.70 5065 43.60 5160 43.40 5254 42.80 5346 42.30 5438 41.90 5532 41.30 5626 42.70 5721 43.40 5816 43.50 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 2967.9 2936.7 518.7 3055.7 3024.5 586.2 3129.7 3098.5 644.0 3204.0 3172.8 701.2 3277.8 3246.7 757.3 3351.2 3320.0 814.2 3416.7 3385.6 868.0 3493.8 3462.6 936.1 3562.4 3531.2 1001.4 3626.5 3595.4 1067.0 3690.2 3659.1 1135.8 3753.5 3722.3 1206.4 3815.3 3784.2 1277.0 3876.1 3844.9 1347.3 3936.6 3905.4 1419.1 RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 60.40 W 284.0 N 435.8 W N 56.80 W 319.4 N 493.7 W N 57.90 W 350.7 N 542.5 W N 60.00 W 380.4 N 591.8 W N 58.60 W 409.2 N 640.4 W N 59.30 W 438.7'N 689.4 W N 57.50 W 467.1 N 735.4 W N 57.90 W 503.6 N 793.2 W N 58.90 W 538.0 N 849.2 W N 59.30 W 571.9 N 905.8 W N 57.20 W 608.3 N 964.6 W' N 57.50 W 646.5 N 1024.2 W N 55.80 W 685.4 N 1083.4 W N 56.10 W 724.8 N 1141.7 W N 55.10 W 765.5 N 1201.1 W 3996.7 3965.5 1493.9 N 56.10 W 4056.2 4025.0 1567.8 N '56.50 W 4116.2 4085.0 1638.7 N 57.20 W 4179.1 4147.9 1708.2 N 59.60 W 4243.8 4212.6 1776.1 N 55.80.W 4307.6 4276.5 1840.8 4374.3 4343.2 1905.5 4443.3 4412.1 1970.7 4511.9 4480.7 2034.9 4579.7 4548.5 2097.0 807.8 N 1262.8 W 848.9 N 1324.4 W 887.7 N 1383.9 W 924.3 N 1443.4 W 960.8 N 1501.0 W N 56.10 W 997.1 N 1554.8 W N 56.10 W 1033.2 N 1608.5 W N 55.40 W 1070.0 N 1662.6 W N 55.80 W 1106.3 N 1715.6 W N 57.20 W 1140.6 N 1767.4 W 4647.9 4616.8 2158.5 4718.2 4687.1 2220.9 4788.1 4756.9 2283.8 4857.5 4826.4 2348.7 4926.5 4895.3 2414.0 N 53.70 W 1175.6 N 1818.2 W N 53.00 W 1212.8 N 1868.3 W N 52.60 W 1250.9 N 1918.4 W N 52.30 W 1290.4 N 1969.8 W N 53.00 W 1330.0 N 2021.7 W Page 2 04/03/92 CLOSURE DISTNCE BEARING 520.1 N 56.91 W 588.0 N 57.10 W 646.0 N 57.12 W 703.5 N 57.27 W 760.0 N 57.42 W 817.2 N 57.53 W 871.2 N 57.58 W 939.6 N 57.59 W 1005.3 N 57.64 W 1071.2 N 57.73 W 1140.3 N 57.76 W 1211.2 N 57.74 W 1282.0 N 57.68 W 1352.3 N 57.59 W 1424.3 N 57.49 W 1499.1 N 57.39 W 1573.1 N 57.34 W 1644.2 N 57.32 W 1714.0 N 57.36 W 1782.2 N 57.38 W 1847.0 N 57.33 W 1911.8 N 57.29 W 1977.1 N 57.24 W 2041.3 N 57.18 W 2103.5 N 57.16 W 2165.2 N 57.12 W 2227.4 N 57.01 W 2290.2 N 56.89 W 2354.8 N 56.77 W 2420.0 N 56.66 W DL /lOO 2.58 2.18 0.75 1.47 0.92 1.27 2.71 2.15 2.33 2.20 2.02 0.77 1.46 0.33 1.60 1.58 1.51 1.51 3.18 3.00 1.67 1.18 O.55 0.70 1.16 2.59 0.81 1.52 0.77 0.52 'Survey Codes: 3/MWD ' I I i ! I ] ] i ] I I I I ~-30 MEAS INCLN DEPTH ANGLE 5911 42.90 6004 42.70 6100 42.00 6195 42.00 6287 41.00 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 4995.7 4964.6 2479.1 5064.0 5032.8 2542.2 5134.9 5103.8 2606.9 5205.5 5174.4 2670.3 5274.4 5243.3 2731.1 3 6383 '39.70 5347.6 5316.4 3 6478 38.40 5421.4 5390.2 3 6572 36.50 5496.0 5464.8 3 6666 38.50 5570.6 5539.4 3 6759 39.60 5642.8 5611.6 · 3 6851 41.00 5713.0 5681.8 3 6946 41.70 5784.3 5753.1 3 7040 42.50 5854.0 5822.9 3 7134 44.70 5922.1 5890.9 3 7229 43.90 5990.1 5958.9 2793.1 2852.9 2909.8 2966.7 3025.1 3084.4 3147.1 3210.2 3274.9 3341.3 3 7322 42.50 6057.9 6026.7 3404.9 3 7418 44.60 6127.5 6096.3 3471.0 3 7512 45.70 6193~8 6162.6 3537.5 3 7606 43.60 6260.6 6229.5 3603.4 3 7701 42.40 6330.1 6299.0 3668.2 RECORD OF SURVEY 3 7795 42.30 6399.6 6368.4 3731.5 3 7889 44.50 6467.9 6436.7 3796.0 3 7985 45.20 6535.9 6504.8 3863.5 3 8080 44.60 6603.2 6572.1 3930.5 3 8174 44.50 6670.2 6639.1 3996.3 3 8268 44.20 6737.4 6706.3 3 8361 43.40 6804.6 6773.4 3 8455 43.20 6873.0 6841.8 3 8550 43.90 6941.8 ,6910.7 3 8650 44.50 7013.5 6982.4 4062.0 4126.3 4190.8 4256.2 4325.9 DIRECTION BEARING N 51.90 W N 50.90 W N 50.90 W N 48.00 W N 48.70 W RELATIVE-COORDINATES FROM-WELL-HEAD 1369.7 N 2073.3 W 1409.1 N 2122.7 W 1449.9 N 2172.9 W 1491.2 N 2221.2 W 1531.7 N 2266.7 W N 49.10 W 1572.6 N 2313.5 W N 48.70 W 1611.9 N 2358.6 W N 46.30 W 1650.5 N 2400.8 W N 48.00 W 1689.4 N 2442.8 W N 46.60 W 1729.1 N 2485.8 W N 50.90 W 1768.3 N 2530.5 W N 51.90 W 1807.5 N 2579.6 W N 54.40 W 1845.2 ,N 2630.0 W N 54.40 W 1883.0 N 2682.7 W N 51.90 W 1922.7 N 2735.8 W N 54.00 W 1961.1 N 2786.6 W N 56.50 W 1998.8 N 2841.0 W N 56.80 W 2035.4 N 2896.6 W N 54.70 W 2072.6 N 2951.2 W N 54.40 W 2110.1 N 3004.0 W N 54.40'W 2147.0 N 3055.5 W N 56.50 W 2183.6 N 3108.7 W N 55.40 W 2221.5 N 3164.8 W N 56.10 W 2259.3 N 3220.2 W N 55.80 W 2296.2 N 3274.9 W N 54.70 W 2333.6 N 3328.9 W N 53.70 W 2371.3 N 3381.1 W N 54.40 W 2409.1 N 3433.2 W N 54.00 W 2447.4 N 3486.3 W N 53.70 W 2488.6 N 3542.6 W Page 3 04/03/92 CLOSURE DL DISTNCE BEARING /100 2484.9 N 56.55 W 1.01 2547.8 N 56.42 W 0.76 2612.2 .N 56.29 W 0.73 2675.3 N 56.12 W 2.04 2735.7 N 55.95 W 1.20 2797.4 N 55.80 W 1.38 2856.8 N 55.65 W 1.39 2913.4 N 55.49 W 2.55 2970.0 N 55.33 W 2.40 3028.1 N 55.18 W 1.52 3087.2 N 55.05 W 3.38 3149.8 N 54.98 W 1.01 3212.8 N 54.95 W 1.98 3277.6 N 54.94 W 2.34 3343.9 N 54.90 W 2.02 3407.5 N 54.86 W 2.16 3473.6 N 54.87 W 2.83 3540.3 N 54.90 W 1.19 3606.3 N 54.92 W 2.73 3671.1 N 54.91 W 1.28 3734.4 N 54.91 W 0.11 3799.0 N 54.92 W 2.80 3866.7 N 54.93 W 1.09 3933.7 N 54.95 W 0.82 3999.7 N 54.96 W 0.25 4065.4 N 54.97 W 0.88 4129.7 N 54.96 W 1.14 4194.2 N 54.94 W 0.55 4259.6 N 54.93 W 0.79 4329.3 N 54.91 W 0.64 ^Survey Codes: 3/MWD } I ] ' ] ] } ] } ] ] ] } } ] ] I I } ~[-30 MEAS INCLN DEPTH ANGLE 8744 43.30 8838 43.70 8926 44.00 9021 42.00 9114 41.40 9208 40.80 9302 39.60 9396 40.20 9490 39.80 9585 38.40 9680 38.60 9775 38.70 9870 38.70 9965 38.30 10060 38.30 10153 39.00 10248 38.90 10343 38.70 10436 38.20 10529 38.60 10641 38.90 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DIRECTION DISTNCE BEARING 7081.2 7050.1 4391.1 N.54.30 W 7149.4 7118.3 4455.7 N 54.40 W 7212.9 7181.7 4516.7 N 53.30 W 7282.4 7251.2 4581.5 N 52.30 W 7351.8 7320.7 4643.3 N 53.30 W 7422.6 7391.5 7494.4 7463.3 7566.6 7535.4 7638.6 7607.4 7712.3 7681.1 7786.6 7755.5 7860.8 7829.7 7935.0 7903.8 8009.3 7978.2 8083.9 8052.7 8156.5 8125.4 8230.4 8199.2 8304.4 8273.3 8377.3 8346.1 8450.1 8419.0 8537.5 8506.3 RELATIVE-COORDINATES FROM-WELL-HEAD 2526.9 N 3595.4 W 2564.6 N 3647.9 W 2600.5 N 3697.2 W 2639.7 N 3748.8 W 2677.1 N 3798.0 W 4705.1 N 51.20 W 2714.9 N 3846.9 W 4765.8 N 52.30 W 2752.5 N 3894.5 W 4826.0 N 50.50 W 2790.1 N 3941.7 W 4886.4 N 50.50 W 2828.5 N 3988.3 W 4946.3 N 50.90 W 2866.5 N 4034.6 W 5005.4 N 50.50 W 2904.0 N 4080.4 W 5064.7 N 51.90 W 2941.1 N 4126.6 W 5124,.1 N 51.20 W 2978.1 N 4173.2 W 5183.2 N 52.60 W 3014.6 N 4219.7 W 5242.1 N 53.00 W 3050.2 N 4266.6 W 5300.2 N' 51.90 W 5359.9 N 50.20. W 5419.4 .N 50.50 W 5477.2 N 50.90 W 5534.9 N 50.50 W 5604.9 N 49.80 W 3085.6 N 4312.6 W 3123.1 N 4359.1 W 3161.1 N 4404.9 W 3197.7 N 4449.7 W 3234.3 N 4494.4 W 3279.2 N 4548.2 W '. Page 4 04/03/92 CLOSURE DISTNCE BEARING 4394.5 N 54.90 W 4459.2 N 54.89 W 4520.2 N 54.88 W 4584.9 N 54.85 W 4646.7 N 54.82 W 4708.4 N 54.79 W 4769.0 N 54.75 W 4829.2 N 54.71 W 4889.5 N 54.66 W 4949.3 N 54.61 W 5008.3 N 54.56 W 5067.5 N 54.52 W 5126.8 N 54.49 W 5185.9 N 54.46 W 5244.7 N 54.44 W 5302.8 N 54.42 W 5362.4 N 54.38 W 5421.8 N 54.34 W 5479.5 N 54.30 W 5537.1 N 54.26 W 5607.1 N 54.21 W DL /1oo 1.35 0.43 0.93 2.22 0.96 1.60 1.48 1.38 0.43 1.50 0.34 0.93 0.46 1.01 0.26 1.05 1.13 0.29 0.60 0.51 0.47 'Survey Codes: 3/MWD } } ] } 1 ! } ~! } 1 ! } } } } i I i } 1-30 Page 5 04/03/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 500 531 1.44 531 0 0 S 37.89 W 5.99 S 4.68 W 600 631 1.31 631 0 0 S 37.69 W 7.88 S 6.15 W 700 731 1.19 731 0 0 S 37.48 W 9.61 S 7.48 W 800 831 1.06 831 0 0 S 37.27 W 11.17 S 8.67 W 900 931 0.94 931 0 0 S 37.07 W 12.56 S 9.73 W 1000 1031 0.82 1031 0 0 S 34.62 W 13.79 S 10.64 W 1100 1131 0.70 1131 0 0 S 31.14 W 14.90 S 11.37 W 1200 1231 0.58 1231 0 0 S 27.65 W 15.85 S 11.94 W 1300 1331 0.46 1331 O 0 S 24.17 W 16.63 S 12.39 W 1400 1431 0.63 1431 0 0 S 68.18 W 17.22 S 12.90 W 1500 1531 3.00 1531 0 0 N 66.32 W 16.39 S 15.63 W 1600 1632 5.89 1631 1 0 N 53.33 W 12.13 S 22.09 W 1700 1733 8.96 1731 1 1 N 38.38 W 2.69 S 31.04 W 1800 1834 10.75 1831 3 2 N 44.70 W 10.34 N 42.57 W 1900 1936 12.51 1931 5 2 N 50.79 W 23.62 N 58.02 W 2000 2039 14.98 2031 8 3 N 46.56 W 39.86 N 76.31 W 2100 2143 17.53 2131 12 4 N 43.04 W 60.56 N 96.77 W 2200 2249 19.27 2231 18 6 N 44.72 W 85.35 N 119.58 W 2300 2355 20.47 2331 24 6 N 50.33 W 109.57 N 146.22 W 2400 2462 22.45 2431 31 7 N 55.24 W 133.16 N 177.44 W 2500 2571 24.02 2531 40 9 N 57.28 W 156.93 N 2600 2681 25.74 2631 50 10 N 60.69 W 180.45 N 2700 2794 29.74 2731 63 13 N 61.50 W 205.70 N 2800 2912 33.07 2831 81 17 N 60.10 W 235.45 N 2900 3033 36.13 2931- 102 22 N 59.60 W 270.33 N 3000 3159 37.92 3031 128 26 N 57.81 W 309.00 N 3100 3286 37.99 ' 3131 155 27 N 57.94 W 351.29 N 3200 3412 37.46 3231 181 26 N 59.48 W 390.85 N 3300 3538 38.20 3331 207 26 N 59.11 W 430.61 N 3400 3668 40.91 3431 237 30 N 57.57 W 473.71 N 213.27 W 252.69 W 299.05 W 352.51 W 412.09 W 477.50 W 543.47 W 609.77 W 675.80 W 745.89 W I } } ' }' ! ! } i I } I } ! } ! ! I ! [-30 Page 6 04/03/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 3500 3803 43.83 3531 272 35 N 58.44 W 522.15 N 3600 3946 46.88 3631 315 42 N 59.15 W 574.39 N 3700 4094 48.35 3731 363 49 N 57.39 W 632.93 N 3800 4246 49.15 3831 415 52 N 55.88 W 695.67 N 3900 4400 50.48 3931 469 54. N 55.19 W 761.71 N 4000 4560 51.08 4031 529 60 N 56.33 W 831.87 N 4100 4716 48.62 4131 585 55 N 57.78 W 896.96 N 4200 4863 46.32 4231 632 47 N 56.54 W 953.42 N 4300 5005 44.31 4331 674 42 N 56.10 W 1009.97 N 4400 5143 43.44 4431 712 38 N 55.52 W 1063.51 N 4500 5280 42.66 4531 749 37 N 56.20 W 1116.24 N 4600 5415 42.00 4631 784 35 N 54.56 W 1166.76 N 4700 5549 41.56 4731 818 34 N 52.93 W 1219.71 N 4800 5685 43.13 4831 854 36 N 52.41 W 1275.24 N 4900 5822 43.46 4931 891 38 N 52.93 W 1332.70 N 5000 5959 42.80 5031 928 37 N 51.38 W 1390.05 N 5100 6095 42.04 5131 964 36 N 50.90 W 1447.73 N 5200 6229 41.63 5231 998 34 N 48.26 W 1506.49 N 5300 6362 39.99 5331 1030 32 N 49.01 W 1563.57 N 5400 6490 38.15 5431 1059 29 N 48.38 W 1617.01 N 5500 6616 37.44 5531 1085 26 N 47.10 W 1668.64 N 5600 6744 39.42 5631 1113 28 N 46.83 W 1722.54 N 5700 6875 41.18 5731 1144 31 N 51.15 W 1778.29 N 5800 7009 42.24 5831 1178 34 N 53.58 W 1832.98 N 5900 7147 44.59 5931 1216 38 N 54.06 W 1888.20 N 6000 7286 43.05 6031 1254 39 N 53.18 W 1946.43 N 6100 7423 44.66 6131 1292 38 N 56.52 W 2000.79 N 6200 7565 44.52 6231 1334 42 N 55.62 W 2056.29 N 6300 7702 42.40 6331 1371 37 N 54.40 W 2110.70 N 6400 7838 43.31 6431 1407 36 N 55.36 W 2163.83 N 823.1~4 W 910.03 W 1002.99 W 1098.49 W 1195.64 W 1298.85 W 1398.43 W 1490.08 W 1573.95 W 1653.14 W 1730.32 W 1806.01 W 1877.40 W 1950.17 W 2025.29 W 2099.07 W 2170.25 W 2238.24 W 2303.19 W 2364.44 W 2420.07 W 2478.83 W 2542.88 W 2613.15 W 2689.99 W 2766.72 W 2844.00 W 2927.83 W 3004.80 W 3079.43 W ~-30 Page 7 04/03/92 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 6500 7978 45.15 6531 6600 8119 44.56 6631 6700 8259 44.23 6731 6800 8398 43.32 6831 6900 8535 43.79 6931 1447 40 N~55.48 W 2218.79 N 1488 41 N 55.97 W 2274.64 N 1528 40 N 54.80 W 2330.11 N 1566 38 N 53.97 W 2386.11 N 1604 38 N 54.06 W 2441.41 N 3160.84 W 3243.05 W 3323.86 W 3401.34 W 3478.04 W 7000 8675 44.19 7031 1644 7'100 8813 43.59 7131 1682 7200 8951 43.47 7231 1720 7300 9086 41.58 7331' 1755 7400 9219 40.66 7431 1788 39 N 53.86 W 38 N 54.37 W 39 N 53.03 W 35 N 53.00 W 33 N 51.33 W 2498.74 N 3556.54 W 2554.43 N 3633.76 W 2611.01 N 3711.14 W 2666.15 N ~ 3783.43 W 2719.51 N 3852.62 W 7500 9350 39.90. 7531 7600 9480 39.84 7631 7700 9609 38.45 7731 7800 9737 38.66 7831 7900 9865 38.70 7931 1819 1849 1878 1906 1934 31 N 51.39 W 31 N 50.50 W 29 N 50.80 W 28 N 51.34 W 28 N 51.24 W 2771.36 N 2824.61 N 2875.94 N '2926.38 N 2976.15 N 3918.55 W 3983.51 W 4046.25 W 4108.02 W 4170.78 W 8000 9993 8100 10120 8200 10249 8300 10377 8400 10505 "~"-'8500 10633 38.30 8031 1962 38.75 8131 1989 38.90 8231 2018 '38.52 8331 2046 38.50 8431 2074 38.88 8531 2102 28 N 52.72 W 28 N 52.29 W 29 N 50.20 W 28 N 50.65 W 28 N 50.60 W 28 N 49.85 W 3025.01 N 3073.00 N 3123.49 N 3174.63 N 3224.68 N 3275.92 N 4233.40 W 4296.51 W 4359.55 W 4421.40 W 4482.68 W 4544.28 W ! I I / ! I } } - ~ } } [-30 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 04/03/92 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 0.86 1000 969 0 S 35.71 W 13 S 2000 14.05 1993 1962 75 N 47.97 W 33 N 3000 35.31 2904 2873 472 N 59.60 W 261 N 4000 47.51 3668 3637 1111 N 57.94 W. 595 N 5000 44.37 4328 . 4296 1860 N 56.10 W 1008 N 10 W 17 S 37.72 W 0.1 69 W 77 N 64.34 W 2.6 395 W 473 N 56.62 W 2.5 944 W 1116 N 57.77 W 2.0 1571 W 1867 N 57.31 W 1.2 6000 42.71 5061 5030 2540 N 50.94 W 1407 N 7000 42.16 5824 5793 3183 N 53.34 W 1829 N 8000 45.11 6547 6515 3874 N 55.51 W 2228 N 9000 42.44. 7267 7236 4567 N 52.52 W 2631 N 10000 38.30 8037 8006 5205 N 52.75 W 3028 N 2121 W 2545 N 56.43 W 0.8 2608 W 3186 N 54.96 W 2.0 3174 W 3877 N 54.93 W 0.8 3738 W 4571 N 54.86 W 2.2 4237 W 5208 N 54.45 W 0.3 PRUBHOE BAY DRILLING #arker Iden~ i ficat ion 140 N/S E/It M-30 PLAN VIEW CLOSURE ..... : 5607 ft at N 54.21 DECLINATION.: 30.00 E SCALE ....... : ! inch = BOO feet DRAWN ....... : 04/08/92 Great Land Directional Drillin# ',~ .............. .~ ............................................................... I ........ % I. ................................... t .................................................. ',. I ..~,,. . I ......... ! - i _.~,,. .......... ! ........................... ~ ............ I ' I ~ ~ ~'-~ ......................................... I ........... I ; ~ ...................... J ............. ~.~. ~ ...... ; ................... ~ .............. , ...... ~... ' ~'-~ .................. ; ....................... ~ .................................. ; ............. I [ ............................. ~ ............... ' ............. ! 5200 4800 4400 4000 3600 3200 2800 2400 2000 t600 t200 800 400 O. 400 <- NEST · E4S'r -> f [ , PRUDHOE BAY DRTLLING SIDETRACK KOP CITD M-30 VERTICAL SECTION VIEW ......................................................................... S~ction at: N 52.63 W :_.:-_-:::::: T:::LZ: ::::_:::::::::::::::::::::::__:7::_':::Z ':Z:7:.T:_-.T/:..-: TVD Scale.' 1 inch = 1000 fee~ ................................................................................ Dep Scale.' ! inch = tO00 feet Drawn · 04/08/92 .......... :.:_: __:: ....... :.: :-:: ,::.: ........ :--.:-:.-:':-'::.':: Great Land D~rect~onal Dr~]l~ng Al ~B 0 0 0 0.00 347! 3278 757 37.40 10641 8537 5605 38.90 1 0 500 tO00 J.500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 Section Departure PERMIT# /~- - ,,~ o WELL NAME ,, , COMPLETION DATE ? / ,~,5' ! ~.~. CO. CONq'ACT ' AOGCC GEOLOGICAl_ MATERIAL~ INYENT'ORY LIST [ check offorlist data as it is received ] . cored intervals,, ,core ,,an,a,,lysis' , d~ di,t,ch intervals d!gital, data ..... '" LOG :VCPE ' RUN 'INTERVALS scALE NO. ~-1 o,.~,(.~ ~,,.~,..,..¢-eJ ~.,~,-,~,~, / / o ?o,/' & ,,,'Y~Z " ~ ~" ,~ ..c'" ...... . , ~' /~2.~. ~¢..~ ~.~,~ ,, ,/ ..... ~ ~ ~- /,/, aT~, ' ~" ,,, ,, 71. , ........ 10! .......... , , , 13! i'4! ............... , ,, , ........ 16] ~! ...... ,,,, 18! ..... ~9! ---"" ,, ,, ~ , , ,, , , , ,,, ~,.,,,. ~ ~ ~ ~H,..,,. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/29/92 T# 83454 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-04 ~ (~ PERF ~ M-30 TIE IN LOG M-30 ~z'~' PERF 04/24/92 #1 04/21/92 #1 04/24/92 #1 04/24/92 #1 8950.00- 9758.00 ATLAS 9320.00-11142.00 SCH 10130.00-11378.00 SCH 10200.00-11378.00 SCH 5 " 5 " 5 " Information Control Well Records Adrian J. Martin R£C£ VED MAY 1 ~ 1992 Alaska Oil & Gas Cons. Gommission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/29/92 T# 83448 f~' ~ o BP OPEN HOLE FINALS Enclosed is your copy of the materials listed below. questions, please contact BP Well Records at (907) M-30 OH/BHCS 7851.50-11493.50 API#500292225500 FIN 04/03/92 1600BPI 8574->TP# #1 If you have any 564-4004. SCH REF#92249 / Information Control Well Records Adrian J. Martin MAY t ~ 1992. Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/08/92 T# 83387 BP OPEN HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. M-30 -- BHCS 04/03/92 #1 10708.00-11438.00 SCH M-30 M-30~/ CNL PORO 04/03/92 #1 7852.00-11419.00 SCH M-30 2/5" 2/5" SSTVD CORRELATION LOG 04/03/92 #1 10708.00-11478.00 SCH 2 " PHASOR INDUC?ION LOG (DIT 04/03/92 #1 10708 . 00-11478 . 00 SCH 2/5" Information Control Well Records Adrian J. Martin RECEIVED APR 1 5 1992 Alaska Oil & Gas Cons. Commission Anchorage TO: THRU: FROM: MEMORANDUM , Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION . LO~hi~ C. S~..~~~ DATE:~ April 14,1992 Commissioned FILE NO: DA. 414.4 Blair Wondzell ~/~ Sr. Petroleum Engineer Doug Amos ~ Petroleum Inspector TELEPHONE NO: SUBJECT: BOPE Test BPX PBU M-30 Permit No. 92-30 Prudhoe Oil Pool Nabors Rig 1SE Wednesday April ~, .!992: I traveled this date to BPX PBU M - 30 well to witneSs..the BOPE test on Nabors Rig 1SE. As the atta6hed AOGCC BOPE Test Report indicates the following equipment failed; 1 APt ring and the stack choke line block valve on the choke manifold. Both items were repaired and retested on 4/2/92, In summary~ I witnessed the BOPE test at BPX PBU M-30 well on Nabors Rig 1SE, Both of the failures uncovered during this test were repaired and retested 4/2/92 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report OPERATION: Drlg ~ Wkvr ~I'~/~ ~ csg set ~ ft Location (general) Housekeeping (general) Rep, J[~'/ Permit # Well sign t/' Rig , ~" Rsrve pit ~{i ~/~ ~UD SYSTEMS: Vi sual Audio Trip tank / I / Pit gauge L~ I / Gas detectors ~ ~ BOPE STACK: Test Pressure Annul ar preventer Pi pe rams BIind rams ~ Choke 1 ine valves HCR valve /I Kill line valves'V~c~'~ 4 '/' TEST: Initial Weekly ~'~ Other /-~/~/Dr~'H-~. Rig phone # ~' ~'~_.-~ Location: Sec J T //~,/ R ACCUMULATOR SYSTEM: Check valve TEST RESULTS: Full charge pressure Press after closure Pump incr clos press 200 psig min Full charge press attained ~ min N2 ~_.'~1~5;0 ~.~ '/.,~ psig Controls: Master Remote KELLY AND FLOOR SAFETY VALVES: Upper Kelly / /Test pressure Lower Kelly J ~Test pressure Ball type / P~ Test pressure Inside BOP .~ ~ Test pressure Choke manifold / c~ Test pressure Number valves / ~7 / Number flanges ~/~ ~" Adjustable chokes ~ ~' Hydraulically operated choke / ~" // Failure; ~ Test time 3 ~;'/~ ' hfs Repair or replacement of failed equipment to be made within ~ days. Notify the Inspector, and follow with written/FAXed [276-7542] verification to Commission office. _~ OO o psig psig sec !/ Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/92) STATE WITNESS REOUIRED? J Waived by: yes V~ no j 24-HR NOTICE GIVEN? i Witnessed by: yes ~ no__ I OONFIDENTIA ,~. · AS 31.05.035 ALASKA OIL AND GAS CONSERVATION COMMISSION / ' WALTER J. HICKEL, GOVERNOR /: , ; 3001 PORCUPINE DRIVE ? ANCHORAGE, ALASKA 99501-3192 , PHONE: (907) 279-1433 / TELECOPY: (907) 276-7542 March 16, 1992 Michael Zanghi PBU Lead Engineer B P Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit M-30 B P Exploration (Alaska), Inc. Permit No: 92-30 Sur. Loc. 2233'SNL, 606'WEL, Sec. 1, TllN, R12E, UM Btmhole Loc. 4519'SNL, 167'WEL, Sec.. 35, T12N, R12E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill 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) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope Pager at 659-3607. Sincerely ~an; ~in~iiva:t io~C°mmiS s ion BY ORDER OF THE COMMISSION dlf/Enclosures cc. Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ' STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] Redrillr"lllb. Type of well. Exploratoryl-] Stratigraphic Test I-! Development Oil[] Re-Entry [] DeepenF'II Service [] Development Gas I-I Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE 57'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28257 4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(s,,,, 20 AAC 25.025) 2233' SNL. 606' WEL. Sec. 1, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 4775' SNL, 5250' WEL, Sec. 36, T12N, R12E M-30 ( 14-36-12-12) 2S100302630-277 At total depth 9. Approximate spud date Amount 4519' SNL, 167' WEL, Sec., 35, T12N, R12E 3/16/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(UDandmVD) property line ADL 28260 @ 759 feet M-5 @ 200'/31 feet 2560 11472'MD/9126'TVD[eet 16. To be completed for deviated wells 17. Anticipated pressure (seo 20 A^C 25.035 (o)(2)) Kickoff depth ~,~so M~feet Maximum hole angle ,~ 0 Maximum surface 3330psig At total depth (TVD) 880~)'/z~90pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight' Grade Coupling Length M D TVD MD TVD (include stage data) 20" Cond. 80' Surface 110' 110' 17-1/2" 13-3/8" 68# L-80 Butt 3130' Surface 3130' 2927' 4350 cu fl Arcticset ,111 12-1/4" 9-5/8" 47# NT80-S NSCC 10695' Surface 10695' 8548' 2370 cu ft Class G 8-1/2" 7 .... 26# 13cr80 FL4S 1025' 10445' 8363' 11470' 9124' 300 cu fl Class G 5-1/2" 17# 13cr80 NSCC 10450' Surface 10450" 8366' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate Production MAR 1 6 1992 Liner Perforation depth: measured Alaska 0il & Gas Cons, true vertical Anchoraoa 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling pro'graml~l Drilling fluid program [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ce/rt,~ ,.~ t~' foregoing is true and correct to the best of my knowledge Signed/t/i--~ Title PBU Lead Engineer Date Commission Use Only Permit Number IAPI number IApproval date ISee cover letter C:~_..-~4) [50-O~,~-2. Z~..5'.5- ] ,.~ ---./~, .-, ~',,~.... [for other requirements Conditbns of approval Samples required [] Yes .~No Mud I~"~ requir,ed [] ?es~'l~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required J:~'Yes [] No Requ~ure~M; r-13M; /~5M; I--I10M; I-]15"'M; Oth ..e~ ~.._-~ ~"~[~---~,~ ~ by order of / Approve ...... Commissioner me comm,ssion .Date~3//~:~!_.....---. Form 10-401 Re~.. Submit PRELIMINARY WELL PLAN Well: M-30 [ 1 4-3 6-1 2-1 2] PB U LOCATION: Surface: Target: T.D.: 2233' SNL, 606' WEL, Sec. 1, T11 N, R12E 4775' SNL, 5250' WEL, Sec. 36, T12N, R12E 4519' SNL, 167' WEL, Sec. 35, T12N, R12E ESTIMATED START: March 16, 1992 OPR. DAYS TO COMPLETE: 22 (17 days drilling, 5 days completion) CONTRACTOR: Nabors 18E MAX ANGLE/SECT COURSE/KOP/BUILD RATE: 420/ N 52.6° W/1450'/2.5 Item .. TVD$8 MD(BKB) Mud Wt. 20" CONDUCTOR 13-3/8" SHOE BASE WEST SAK FORMATION 9-5/8" SHOE TOP SAG RIVER SANDSTONE CURRENT GOC TOP SADLEROCHIT TARGET TOTAL DEPTH 80 8.5 2927 3130 9.5 5280 6297 9.0 8548 10695 9.7 8549 10695 8.4 Above Sad 8.4 8675 10865 8.4 8768 10990 8.4 9126 11472 8.4 LOGGING PROGRAM: Open Hole - Record all logs on magnetic tape where applicable. 12-1/4" Hole: None 8-1/2" Hole: DIL/CNL/GR/SP/SDT, Optional: LDT/GR, RFT Cased Hole Gyro survey after rig release. SS: 3/15/92 RECEIVED MAR 1 6 1992 Alaska Oil & Gas Cons. Commission Anchorage PROPOSED DRILLING AND COMPLETION PROGRAM WELL M-30 [36-12-12] PBU Install and cement 80' of 20" conductor to surface. The Drilling fluid program will consist of an 8.5 - 9.5 ppg spud mud in the 17- 1/2" hole, a 9.0 - 9.7 ppg water base mud in the 12-1/4" hole and an 8.4 ppg water based mud in the 8-1/2" hole. Drill 17-1/2" hole to 3150'. Run and cement 13-3/8", 68 #, L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. -. A formation leak-off test will be performed 10' below the 13-3/8" shoe. Directionally drill 12-1/4" hole to the 9-5/8" casing point above the top of Sag River Sandstone. Run a 9-5/8" casing string to within 10' of 12-1/4" TD and cement with Class G cement around the 9-5/8" shoe. The annulus will be freeze protected by Diesel. Directionally drill the 8~1/2" hole to TD. Run 7" liner from TD to 250' inside 9- 5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to NaCI completion fluid. Test casing and lap to 3500 psi. Run 9-5/8" production packer on tubing. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 100' below base of permafrost. Install and test Xmas tree. Displace tubing to Diesel. Set and test packer. The well will be perforated after the rig has been released. Fluids incidental to the drilling of a well will be pumped down the 7-5/8" x 10- 3/4" annulus of the well. Tubing Size: 5-1/2", 17 # NT13CR-80, NSCC tubing with 6 GLM's. SS: 3/15/92 RECEIVED MAR 1 6 1992 Alaska Oil & 6as Cons. Commission Anchorage MUD WEIGHT WELL M-30 CALCULATIONS (14-36-12-12) Mud Wt. (8-1/2" Hole): 8.4 ppg. P Sag River: P Sadlerochit: P Top Sadlerochit: 3550 psi. 3630 psi. at 8800' TVDSS 3586 psi. OB Sag River: OB Top Sadlerochit: Current GOC: 210 psi. 227 psi. Above Top Sadlerochit 9-5/8" Casing Pt. Top Sag River Top Sadlerochit 8605' TVDBKB 86O6' TVDBKB 8732' TVDBKB Cement Calculations 13-3/8" CASING Measured Depth: Basis: Total Cement Vol: Lead Slurry Vol: Tail Slurry Vol: 9-5/8" CASING Measured Depth: Basis: Total Cement Vol: Lead Slurry Vol: Tail Slurry Vol: 5-1/2" LINER Measured Depth: Basis: Total Cement Vol: SS: 3/15/92 3130' 2 X Annular volume 4350 (cuft) 3650 (cu ft) 1880 Sx Arcticset III @ 1.94 Cu ft/Sk 700 (cuft) 600 Sx class G cement @ 1.16 Cu ft/Sk 10695' 90% Annular Volume of 12-1/4" hole + 50 cu ft 2370 (cu ft) 2220 (cu ft) 810 Sx G+8% @ 2.75 Cu ft/Sk 150 (cu ft) 129 Sx Neat G @ 1.15 Cu ft/Sk 10445' (Hanger)- 11470' (Shoe) 1.5 X Annular volume to 9-5/8" shoe + 150 cuft 300 (cu ft) 256 Sx Neat G @ 1.16 Cu ft/Sk RECEIVED MAR 1 6 1992 Alaska 0il & Bas Cons. (;ommissio" Anchorage PR["~"IMINARY WELL PLAI~~' .,,,,W,,ELL, M,30 [14-36-12~1.2] PBU 20" Concluctor PROPOSED DEPTH MD/BKB 110' Bali Valve 2100' 13-3/8" Casing 3130' 17-1/2" hole 3150' TOp Of cement in the g-5/8" annulus is estimated at 3430' Note: This will provide 600' coverage at the top of Ugnu (the shallowest hydrocarbon zone) 5.1t2" 17# 13Cr-8(] NSCC tubing with GLM's 9-5/8" Packer 10395' 7" Tieback Assembly 0445' 9-5/8" Shoe 10695' 12-1/4" Open Hole 10700' 7" 26~ i3 Cr-NT 80 FL4S Liner PBTD 7" Liner Shoe 8-1/2" Open Hole RECE]VED t~AR 1 7 199~ Gas Gons, Gommission Anohorage 11390' 11470' 11472' SS 3t15/92 GREAT LAND IOIRECTIONAL DRILLING INC. Close Approach Analysis we, M-30 F~o~d Prudhoe Bay M-Pad co,~...y PRUDHOE BAY DRILLING AFE# ATT£.T~O~ Saad Saleh D.,~ March 14, 1992 WELL CROSSINGS Crossing Well TVD TVD Distance Above/Below M-29 888 1913 1025 BELOW M-03 3343 2322 1021 ABOVE M-09 4134 2741 1393 ABOVE M-27 P 3617 2916 701 ABOVE M-10 4472 3154 1318 ABOVE M-22 5922 3962 1960 ABOVE WELLS WITHIN 100 FEET OF PROPOSED WELL Close Approach Distance Range 'FVD with well TVD M-29 35 100 SURFACE TO 100' M-29 32 475 M-29 36 2233 M-02 69 0 @ WELL HEAD M-02 52 900 M-05 31 200 SURFACE TO 200' M-25 65 488 SURFACE TO 488 Wells Considered for Wells Considered this analysis for this analysis M-01 G M-19 G M-02 G M-20 G M-O2OH G M-21 G M-03 G M-22 G M-04 G M-23 G M-05 G M-24 G M-06 G M-25 G M-07 G M-26 G M-08 G M-27 P M-09 G M-28 G M-lO G M-29 G M-11 G M-12G M-13 G M-14G M-15 G M-16 G M-17 G M-18 G Survey Status: P = Planned D = MWD G =Gyro Survey COMMENTS The profile for M-30 was computed from parameters supplied by PBD. This profile consists of a 1450' KOP building 2.5°/100 up to an angle of 42.00° at 3130 MD, 2984' TVD. This inclination and a direction of N 52.59 W is held to the target at 10991' MD, 8825' TVD, and finally to TD at 11473' MD, 9184' TVD. All other wells in the M-pad area were computed from directional gyro surveys supplied by PBD, or current on-hand planning data. As shown above M-30 will encounter 6 crossings with existing wells. M-30 comes within 100' or less of 4 wells in the M-pad area, as outlined above. ANALYSIS BY: CHECKED BY: B. Price RECEIVED MAR 1 6 1992 Alaska 0ii & Gas Cons. Commission Anchorage _$45DUA247:[DRAN033]M30_CLOSAP_SHORT.LIS;9 13-MAR-1992 13:33 Page 1 Closest Approach Analysis --- Date: 13-MAR-92 Time: 13:33:05 Search Radius= 200 COURSE LINE For proposed well: M-30 [ 0-36-12-12] Location = W-E S-N TVD(SBS) Top 628230.00 5973309.00 -57.00 Bottom 623346.08 5976914.07 9015.00 Note: Ail depths in feet Below Kelly Bushing (BKB) Closest Approach WELL IDENT /PROPOSED% /NEARBY% TVD DEPART TVD DEPART CLOSEST DISTANCE Vertical /PROPOSED% TVD DEPART Intersection /NEARBY~ TVD DEPART VERTICAL DISTANCE A029-2004200 M-1 15.8 A029-2010100 M-2 OH 1736.6 A029-2010101 M-2 RD 1736.6 A029-2010200 M-3 2092.4 A029-2010500 M-4 2247.7 A029-2019400 M-5 0.3 A029-2036700 M-6 4016.4 A029-2037300 M-7 2536.2 A029-2049900 M-8 2674.1 A029-2051200 M-14 3067.5 A029-2052200 M-13 3443.1 A029--2056300 M-9 2828.0 A029--2056700 M-10 3275.2 A029-2058900 M-11 2878.4 A029-2059300 M-12 2976.9 A029--2061200 M-15 3217.1 A029-2061300 M-16 2557.2 A029-2062800 M-17 4.9 A029--2081000 S-13 8334.3 A029-2085500 M-TW 3709.1 0 0 18 2 18 2 92 5 143 6 0 0 1518 6 274 3 354 5 664 3 1002.4 461.0 851 .3 500 3 582 9 799 0 285 8 0 0 5406 2 1241 9 0.0 1724.0 1724.0 2079 6 2234 6 00 4048 6 2538 7 2668 7 2971 4 3602 7 2871 3 3514 1 2859 4 2967 1 3208 4 2192 7 00 8241 2 4010 8 0.0 23.1 23 .1 9.5 19.5 0.0 1256.4 17.9 8.7 36.4 152.3 14 .0 198 .9 25.5 15.7 11 .3 74 .3 0.0 4965.6 1032.9 272.6 49.1 49.1 131.0 208.8 31.0 244.0 374 2 451 0 956 6 885 1 548 0 580 6 692.5 798 2 1066 8 1396 4 140 0 1208 9 954 6 2324 .5 173 . 5 3329 .3 152.1 1017.3 2739.1 397.5 4129.0 535.0 1393.9 3154.2 742.3 4468.5 675.5 1319.0 $45DUA247:[DRAN033]M30 MARK.LIS;1 13-MAR-1992 14:12 Page 1 PRUDHOE BAY UNIT DRAN033 / 13-MAR-92 /14:12:55 MARKERS FOR WELL M-30 [ 0-36-12-12] ENGINEER: Saad Saleh Label TVD TVD MD DEPART INC KOP #1 BASE PERMAFROST END OF BUILD ~1 13 3/8" SHOE 17 1/2" HOLE TOP UGNU SANDS BASE WEST SAK FORMATION IKRU-PBU PACKER TOP 7" LINER 9 5/8" SHOE TOP SAG RIVER SANDSTONE 12 1/4" HOLE TOP SHUBLIK FORMATION TOP SADLEROCHIT TARGET CURRENT OWC TOP HOT ORIGINAL OWC TOTAL DEPTH TOP EILEEN SANDSTONE KAVIK (BASE SADLER) CURRENT GOC SS 1393. 1840. 2926. 2927. 2941. 3590. 5280. 6670 8325 8363 8548 8549 8552 8587 8675 8768 8870. 8965 9015 9126 -1 -1 -1 (BKB) 1450. 1897. 2983. 2984. 2998. 3647. 5337. 6727. 8382. 8420. 8605. 8606. 8609. 8644 8732 8825 8927 9022 9072 9183 0 0 0 1450. 1900. 3130. 3130. 3150. 4023. 6297. 8167. 10395. 10445. 10695. 10696. 10700. 10747. 10865. 10990 11127 11255 11323 11472 0 0 0 ANGLE 0. 0.00 44. 11.25 589. 42.00 589. 42.00 602. 42.00 1186. 42.00 2708. 42.00 3959. 42.00 5450. 42.00 5483. 42.00 5651. 42.00 5651. 42.00 5654. 42.00 5685. 42.00 5765. 42.00 5848.. 42.00 5940. 42.00 6025. 42.00 6070. 42.00 6170. 42.00 0. 0.00 0. 0.00 0. 0.00 $45DUA247:[DRAN033]M30 CLOSAP SHORT.LIS;9 13-MAR-1992 13:33 Page 2 A029-2089700 M-19 2595.9 307.1 2581 . 9 376 . 2 1535 . 2 A029-2093600 M-22 2595 . 9 307 . 1 2694 . 1 311 . 3 1078 . 2 A029-2093700 M-23 2233 . 9 138 . 2 2366 . 7 534 . 1 774 . 2 A029-2157000 M-25 0.0 0.0 0.2 0.0 66.0 A029-2157800 M-28 99.9 0.0 100.0 0.2 106.1 A029-2190400 M-29 483.9 0.0 483.0 11.1 31.6 A029-2199200 M-27 2616 . 9 319 . 8 2660 . 9 26 . 3 309 . 9 A029-2200400 M-26 ( 2348.1 183.7 2345.5 3.6 239.0 3962.1 1900.6 2809.4 1469.7 45.3 447.4 5927.5 866.4 3582.5 1970.4 36.3 380.5 -1033.3 773.4 SUMMARY The well which comes closest to the proposed well is: A029-2019400 M-5 Closest approach distance = 31.0 feet KICK OFF for this run = 1450.0 feet TO STA~) m)'~ PiT AMD KILL &l~ Choke Manifold Poor Boy Degasser . Brandt Vacuum. Type Degasser Brandt Dual Tandem Shale Shaker Pioneer Mud Cleaners Pioneer MKI Centrifuge 1 - RecOrding drilling fluid, pit 'level tndicaC0r with both visual and audio warning devices at driller's console 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp Agitators TRIP TANK ~ND ,/ / PIlL ~ / e~s~ ~ t ,I BOP STACK CONFIGURATION 13 5/8", 5000 PS1 WP TRIPLE RAM .STACK BRILLING , . RISER J, , ANNULAR PREVENTER 2" KILL LINE MANUAL HYDRAULIC GATE GATE[ P l PE RAM5 BLIND RAM5 DRILLING SPOOL · P l PE RAMS I 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE RECEIVED] MAR 1 ~ 19~' Ala8k~ Oil & Gas C~ns. Commission Anchorage FLARE PIT ?, S-PAD FLOWLINE ~ TO R-P/ 16 18 15 14 SUMP SUMP 19 20 M 13 12 (A)---~-- e 12 ,31 (B).-~- e 21 __.~j 22 11 23 10 ____j 24 9 L__ 8 i 7' 6 z~---- SUMP SUMP 4 ~'----- 2~ 28 SEWAGE 17 -- PIT , NOTES: ~'1 WELL, 6" PRODUCTION LINE, AND 3" G~ WELL, 6" WSW LINE, AND 4" MI LINE THERMO. HIGH RISK -- NO RWS DRILLING W..L .ND "W WL,N. WSW TWINS: WELLS NUMBER I AND 28 PROPOSED NEW SURFACE LOCATION RELIEF PIT ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DSTE [ 2 thru (3) Adm i n ~>c--' '~ ]~,~.~:Z. [~ thru 13 [10 & 13] (4) Casg [14 thru 22] ( 5 ) BOPE /~,~,~' ~-?~ - ~' [23 thru 28] (6) Other [-29 th (6) Addl e 3. 4. 5. 6. 7. 8. t 10. 11. 12. 13. 14. '15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Is permit fee attached ............................................... /~ Is well to be located in a defined pool .............................. _/~. .... Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available i~ this pool ............. Is well to be deviated & is wellbore plat included ................... ~ ~ Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ' ~ Is a conservation order needed ....................................... ~ Is administrative approval needed .................................... .~. Is lease n~nber appropriate .......................................... ~ Does well have a unique name & nLmber ................................ ~ Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to ~o~o psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. NO '- REMARKS Z geology' enD i neer ing,: DWJ_~ MTM ~ LCS -~' ~ JH .~ rev 03/29/91 jo/6.011 INIT'IAL GEOI UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' 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 APPENDIX.. No special 'effort has been made to chronologically organize this category of information. ALASKA COMPUTING CENTER *------- $CHbUMBERGE~ WEbb NAME BOROUGH API'NUN~£R' REFERENCE:ND BP EXPbORATZON M- 30 PRUDHOE BAY NORTH SLOPE ~50~029 92~49 RECEIVED ldaska Oil & 6ae Cent,. ~ion Tape verification Listing ~hlumDerger AlasRa ComPuting Center 22-APR-1992 I4:02 ***'* REEL HEADER **** SER¥ICE NAME : EDIT DATE : 92/04t22 REEb NAME : 92249 CONTINUATION # : PREVIOU~ REEL : COMMENT : BP EXPbORATION,PRUDHOE BAY,N - 30 (1.4-36-1.2-12),50~029-22255o00 **** TAPE HEADER SERVICE NAM~ : ~DXT DAT~ ~ 92/04/22 ORIGIN : Fbi TAP~ NAME : 92249 CONTINUATION # ~1 PREVIOUS TAPE CO~ENT c BP EXP~ORATION,PRUDHOE BAY,H - 30 (14~36~]2-X2),50-029~22255-00 TAPE HEADER PRUDHOE BAY UNiT OPEN HOLE WIRELINE LOGS WE~L NAME{ APl NUMBER{ OPERATOR~ LOGGING COMPANYI TApS CREATION DATMI jOB D&TA JOB NU~BER~ LOGGING MNGINEER~ OPERATOR WITNESS: SURFACE ~OCATXON SECT!ON~ TOWNSHIP: DANGE: FNL~ FSL: FEL: FWL: ELEVATIOM(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: G~OUND LEVEL: WELL CASING RECORD !ST STRING ~ND STRING NO,' 30_ (14'36"'12'12 5. 02922255. . ~! APR ~ RUN1 1 92249 D, WARNER B, BRYANT/J, RUN 2 RUN 3 10 lin 12E 2233 606 57.00 56.00 26'0O OPEN HOLE CASING DRILI.,ER$ BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9,625 10715.0 PAGEI :hlUmber'ger AlasKa Computinq Center :22'APR-!992 14:02 3RD STRING PRODUCTION STRING TOOL NEUTRON MATRIX : 8ANDSTO,E,~, HOLE:~CORRECTION : BIT SIZE'. RANi CML WITHOUT BOWSPRING., .LOCATION~ OF PRODUCTION XNTERVAL:: 4775' 8NL & 5~50' WEL, SEC 36, T12N,~RI2E' $ SERVICE VERSZON , D~TE' , 9~04/22 M!X REC SIZE : t 4 FILE TYPE : LO FILE HEADER FILE NUMBER: EDITED CURVES AIl tOO! strings; DEPTH INCREMENT ~ILE SUMMARY PBU TOOL CODE CNTH DTE GRCH $ CUR Depth shifted and c!ipped: curveS; all runs merged; 0.5000 START DEPTH 11440,0 11420,0 11470°0 10750,0 STOP DEPTH 10708,0 10708.0 10708,0 10708,0 ~LINE CURVE FOR SHIFTS" GR.BCS VE SHIFT DATA (MEASURED DEPTH) .... '''''''-''EQUIVALENT UNSHIFTED DEPTH'''''--''' ~ASEbINE DEPTH DT,BC$ NPHI SFL,DTE SP,DTE GRCH 1t 74 11 74 Il 67 I1 45 11 40 {1 34 11324 888,0 436,0 3 5 ] 0 ~ 5 0 0 5 292.0 88888.$ 88888.0 88889.5 88888.5 88888.0 I1437,5 11374,5 11334.5 I1344.0 341,0 {1335.0 t1325,0 11368.5 I1134.5 1130 5 11374,5 no cased hole data, ~ 1,27'7,0 11233~5 1 i 23 t'5 11228,5 1~ !, 228;10 I i 225,0 ! t 223; 5 1120 0 1110 5 t 03' {. ! 013' 0 11012' 5 i 1002~;~0 i 0999,0 10981,; o 10980,5 ]0944,0 0926;0 ].0925'5 10909,0 0~87'0 0869-5 0868'5 864' 0 0849 ~ osco: 10822'0 08,0 t0802.5 0?95.0 {0786.5 ~0778 5 10767,5 ~0767.0 ~0766.5 10765 5 ~0759 5 ~ 075~ 5~ 10755 5 ~0754 5 10752 5 ~070~ 5 10706.0 t1228,0 11001.0 tosTo.o 10864'0 0816-5 1.0796,~ 10786. t0778.5 i0767.0 I0706.0 1i239.0 t =2s. o ! t o.3 7,5 11012.5 ! 0980,5 i0944,:0 10925.5 870 I0816.5 10778,5 10767,0 10755.5 I0708.0 22-APE'1992:14:02 !1278.5 11234.0 ! 22'7,5 1224.0 t1118,0 1 ! 079.5 11039.5 1 10 ! 6.5 202,0 11109, :05 11102, 11055'0 11001.5 io98o. S 10925,5 I0870.0 108490 10841;0 10827.5 10823.0 10816.5 10808.5 1080¢.0 10767.0 10757.5 10751.5 10767.5 10765.0 10759.0 10755,5 10706.0 PAGE: Tape Verification Lts:ing :~lUmberger~ Alaska Computing~ Cen:er 22-.APR-1992 14:02 ~067~,~ ~064 ~ 100,0 TOOL CODE $ I0676,5 10640.5 100,0 100.5 99,0 99.0 100,0 PASS NO. MERGE TOP REMiRKS~ THE OVERLAP PORTION Dr THE GAM~A RAY FROM TH~ CASING PASS WAS INCLUDED IN TH~S FiLE A~D THE DEPTH SHIFTS ~HAT WERE APPLIED ARE SHOWN ABOVE, L~S FORMAT DATA PAGEI ** DA?A. FORMAT 8PF~CIF~CA~ION RE~ORD ** **SET TYPE REPR.i:,CODE . VALUE 0 0 66' I 68 0 5 ~5 65 FT 66 68 l ** SET TYPE = CHAN NAME SERV UNIT SERVICE API AP1 AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbEN CODE - (HEX) DEPT FT 425514 O0 000 O0 0 ! ! I 4 68 0000000000 DT BC8 US/F 425514 O0 000 O0 0 I 1 ! 4 68 0000000000 GR SCS GAP! 425514 O0 000 O0 0 1 I 1 4 68 0000000000 TENS SCS LB 425514 O0 000 O0 0 1 ! i 4 68 0000000000 TEND SCS LB 425514 O0 000 O0 0 1 1 ! 4 68 0000000000 IDP~ DTE OHMM 425514 O0 000 O0 0 1 1 1 4 68 0000000000 Tape Yeriflcation bistlng :hlum~erger Alaska Comput n~ center 22-APP-1992 14102 P AGE; :5 NAME SERV UNI? SERVICE API APl AP1 AP! FILE NUMB NUHB SIZE REPR PROCESS ID ORDER-# LOG TYPE CLASS MOD NUMB SAMP ELEM CODE... (HEX) IMP~ DTE OHMM 425514 O0 000 O0 0 I I i 4 88 0 ILM DTE OHM. M 425514 0~0 O0 0 I I I 4' 68 0 MV SP NPH! CRAT NC~T FCNT GRC~ OD ooo D~ DEGF 4~5514 000 0~0 CNTH CPS 425514 O~ 000 CNTH CPS425514 0 000 CNTH O0 0 I 1 O0 0 1 1 O0 0 1 1 O0 0 1 .I O0 0 I 1 O0 0 1 O0 0 I I I 4 68 1 4 68 I 4 68 1 4 68 I 4 6 000000000 000000000 000000000 0000000000 0000000000 0000000000 0000000000 O~ 0000000 o °o°o o oooo 0000000000 0000000000 0000000000 0000000000 0000000000 425514 0 000 O0 0 I 1 CNTH 4255.t4 O0 000 O0 0 I 1 CNTH CPS 425514 O0 000 O0 0 1 1 CNTH CPS 425514 0 000 0 000 O0 0 I 1 CN TH GAPI 425514 O0 O0 0 1 I I 4 88 I 4 68 t1 4 68 4 8 I 4 ~8 ** DATA DEPT TEND BCS IbM DTE MRE$ :DTE NRAT CNTH GRC~ CNTH DEPT TEND!ECS IL~ DTE MRES.DTE N~AT.CNTH GRCM,CN?H DEPT IL~.DTE MRE$,DTE NRAT.CNTH GRCM.CNTH 11480 000 ~015 80 999 ~50 -999 250 -999 .250 -999 250 I:~0 0 000 1~7 758 16 500 I 2 744 -999 250 10708 000 1460~047 1,133 ,54 8 ,037 DT.BC ID~H'DT~ SP,DTE NPMI,CNTH CRAT, CNTH DT,BCS IDPH,DTE SP.DTE NPHI.CNTH CRAT.CNTH -999 50 -999 50 50 65 -10 438 25 912 2 467 DT.BC$ 79.016 IDPH.DTE 0,634 SP.DTE 27.281 NPHI,CNTH 25,810 CRAT.CNTH 2,460 GR,BCS IMPH,DTE SFL,DTE. CNTC.CNTH NCNT.CNTH GR.BC$ IMPH,DTE SFL.DTE CNTC.CNTH NCNT.CNTH GR.BC$ IMPH.DTE SFL.DTE CNTC.CNTH NCNT.CNTH -999 250 -999 )50 -999 50 -999 ~50 · .999 50 27 750 3262 432 3394 637 75.333 0.955 9.136 1988.:107 2418.324 TENS,BCS ILD-DTE MTEM,DTE CFTC.CNTH FCNT.CNTH TENS ECS IbD:DTE MTEM,DTE CFTC,CNTH FCNT.CNTH 'TENS.BCS ILD.DTE NTEM.DTE CFTC.CNTH FCNT.CNTH .6470,000 999'.250 '.999,250 .999,250 999. 250 6610'000 20,936 185,507 1319.196 1252.771 6960,250 17~.'679 222 846 773 854:637 ** END OF DATA Tape v:erificat~on Listing hlumberger AlasKa,. ComPuting Center 22-APR-1992 i4:02 1~,1 FILE TRAILER 111* FILE NANE: . EDIT .00! SEA.iCE I FLIC VERSION 'I O01AO? DATE. : 92/04/22' MAX R~C:~$IZE' ~ {024 VERSION : OOIA07 DATE: ~ 92/04/22 ~AX AEC $'iZE I 1024 FILE TYPE : hO LAST FILE : FILE HEADER EDITED CASED,HOLE DePth Shl,ted and, clipped Curves PASS NUMBER: DEPTH INCREMENT 0,5000 FIL~ SUMMARY POU TOOb CODE START DEPTH BASELINE CURVE CURVE SHIFTS" GRCH SHIFT DATA (MEASURED DEPTH) PASS NUMBER: BASELINE. DEPTH 88888,0 10767.5 0755,0 ~0714o0 10580,0 ~055~o0 10546 0 10510 0 10494 5 ~048~ 0 1045 5 10320 0 ior open ho.le: loQs run into: casin~. STOP DEPTH '7851,5 -3 .---"-----EQUIVALENT UNSHIFTED DEPTH''"-'''"'" NPH! 88888.0 ~0~67~5 I0755.5 I0714'5 0709,0 0619,0 10591.5 10565.0 10510 10481:5 10450,5 10321.5~ AlasKa ComputlnO Center t0304,0 0279"5 0254, 5 0225,0 016 6 ~ 5 0 t 47 ' 0 {0133'5 0098 ' 0 0061; 0 0023 * 0 9991'0 9954;0 9932;5 9911,0 9885,0 9818 5 9784 5 9746 5 969 ! 5. 9649 5 9570 0 9465 0 9406 0 9369 5 9359 0 9323 0 927 6 0 9235 0 9096 0 9058 5 9052 5 9033 5 8875 5 8818 5 8782 0 8.763,5 8677.5 8577,5 8509,0 8482,0 8442 0 8326 0 8281 0 8249 0 8245 5 8231 5 8168 0 8131 5 8047 0 8013 5 7992 0 7969 0 7892 0 loo:o S 0 10~ 79: 55 10224 10i66 10147 0 1013~ 5 !009 5 10060 0 1002~ 5 99 96 9467~0 9408,5 9370 0 932~ 0 927 9235 0 9095,5 9058,5 9051'5 9033,:5 8876,0 8818,5 87B3.5 8765.5 8679,0 8577 0 8so7:o 8481.0 8442,5 8326,0 8280'0 8248 5 8230'5 8167,0 804 5 80ii,5 7991.5 7968.5 7904.0 7~93.5 101,5 22'APR'1992 1.4:02 PAGE: Tape Veritication List. in~ .-hlumberger Alaska ComPutin~ Center 22-A~- 199~. 1.4: 02 ~EMA:RKS: THE DEPTH ADJUSTMENTS SHOWN NP~I: TO C.~SEO HOhE GR. S ffblS FORMAT DATA CASED HO~Ei PAGE: DATA FORMAT 'SPECIFICATION RECORD SET TYPE - 64EB ** ., TYPE REPR.CODE VASUE I 66 0 2 66 0 4 66 1 5 66 6 73 7 65 8 9 65 F 1~ 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE aPI AP1 APl APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # 50G TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) -------------------;-------------------------------------------------------------------DE FT 514 0 000 O0 0 2 ! I 4 68 0000000000 GRC~ CNTH GAPI 425514 O0 000 O0 0 2 I I 4 68 0000000000 NP~I CNTH PU 425514 O0 000 O0 0 2 ! 1 4 68 0000000000 TENS CNTH LB 425514 O0 000 O0 0 2 - I ! 4 68 0000000000 ** DATA ** DEPT, 10708.000 GRCH.CNTH 84,037 NPHI,CNTH 24.463 TENS,CNTH DEPT, I0000,000 GRCH,CNTH 44.839 NPHI,CNTH 28.t68 TE~$,CNTH 6890,000 6545,000 S Ta~e~V~rl~icatio~ Listinq hlUmbercjer Alasl<a CO~{outinq Center DEPT., 9000.000 GRCH.CMTH DEPT. gO00.O00 GRCH.CNTH DEPT,. 78§1,500 GRCH,CNTH 22'APR-J992 t4~02 62:,884 NPBI.CNTH 46,952 NPHi,CNTH 54,998 NPHI,CNTH 57.555 TENS.CNTH 45'~567 TENS.CNTH -999.250 TENS*CNTH PAGE: 5795,000 4925,000 4775,000 . FILE NAME ~ EDIT ,002 SERVICE : FLIC VERSION : O01A07 DATE : 92/04/22 MAX REC SIZE : 1024 FILE TYPE : LO bAST FILE **** FILE HEADER **** FILE NAME : EDIT .,003 SERVICE : FLIC VERSION DATE : 92/04/22 MAX REC SIZE { 1024 FILE TYPE { bO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLE MAIN PASS Curves and loQ header data {or each run and tool string {n separate f~le~; Tool St~n~ #~ fo Sadlerochtt run Presented first (prtmary.depth~ contrgl'str~ng used to depth snlft the Sadler interval) followed ~y files for other maln pass strings per run. RUN NUMBER: TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREUE~T: 0,5000 # FILE SUmmARY VENDOR TOOL CODE START DEPTH BHCS ~440,0 DITE ~47~,0 CNTH 11420.0 $ gOG HEADER DATA ~ATE ~OGGED~ SOFTWARE VERSIONI STOP DEPTM 10638,0 10638,0 10638,0 03'APR'92 5B0'231 992 !4=02~ ¸!0 TIME CIRCULATION ENDED: TD DRISLER (FT), TD LOGGER(FT), TOP LOG,'INTERVAL {FTI~ DOT,OM ~OG~ INTERVAL. T)~ LOGG.ING SPEED (FPHR)= TOOL STRING. (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE R ~ TCC TELEMETRY CART. IDGE GR GAM~A RAY SONDE CNTH COMPENSATED NEUTRON BHCS BOREHOLE COMP,~'SONiC BHCS BOREHOLE COMP;~ SONIC_ DITE PHASOR INDUCTION CART DITE PHA$OR INDUCTION SONDE $ ~DREHOLE AND CASING DATA OPEN MOLE. BIT SIZE DRILLERS CASING DEPTHC'FT)~ LOGGERS CASING DEPTH BOREHOLE CONDITIONS MUD TYPEI MUD DENSITY MUD VISCOSITY MUD FLUID LOSS MAXIMUM RECORDED TEMPERATURE (DEGF){ RESISTIVITY (OHMS) ~Ti TEMPERATURE CDEGF) MUD AT MEASURED T~MPERATURE MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT)t MUD FILTRATE AT(BHT): MT' MUD CAKE AT (BH)::~) CAKE AT ( NEUTRON TOOL TOOL TYPE {EPITMERMAL.OR THERMAL)= MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOoL STANDOFF ~E~ARKSI 2o6 11480,0 11478'0 11419.0 1800,0 TOOL~ NUMBER TCC~B::320 SGC-SA 60 CNC~HA. 2~90 $~C-UA 136 7 DIS-,.S 4 4 8.500 10715.0 '10708'0 SOLIDS 9,00 37,00 9,00 7'60 tgo.o 3,990 1,394 4,510 1,576 2,590 62'o 190'0 o:g 190 62,0 SANDSTONE 2.65 TOOLSTRING (BOT-TOp) = DITE-BHC-CNL-GR-TCC-AMS NEUTRON MATRIX = SANDSTONE, HOLE CORRECTION = BITSIZE RAN CNL WITHOUT BOWSPRING. LOCATION OF INTERVAL: 4775' SNL & 5~50' WEL SEC 36 T12N R12E $ £$.?aee verification Listing :h!umber.qer a$l<a ¢omVutlnO Center :22-APR-i992 ~4:02 PAGE.= 1, DATA: FORMAT :SPECIFICA?ION RECORD ** TYPE~ REPR CODE VALUE i 66 4 66 5 66 6 73 7 65 O 68 9 65 11 66 i2 68 13 66 ! 4 65 15 66 I6' 66 0 · 66 0 0 22O 1 4 68 I ** SET TYPE - CHAN ** ' . . ~AM:E SERV UNIT SERVICE APl APl APl AP! FILE NUMB NUMB!: SIZE REPR PROCES~ ID ORDER # LOG TYPE.CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 425514 00 000 O0 0 3 1 1. 4 68 DT BHC US/F 425514 00 000 O0 0 3 1 I 4 68 TT1 BHC US 425514 00 000 O0 0 3 1 1 4 68 TT2 BHC US 425514 O0 000 00 0 3 I 1 4 68 TT3 BHC US 425514 00 000 00 0 3 1 ! 4 68 TT4 B~C US 425514 O0 000 00 0 3 ! 1 4 68 BP BHC MV 425514 00 000 00 0 3 1 % 4 68 GR BBC GAPI 425514 O0 000 O0 0 3 1 % 4 68 TENS BHC LB 425514 O0 000 O0 0 3 1 I 4 68 . NTEM BHC DEGF 425514 O0 000 O0 0 3 ! I 4 68 MRES BHC OHM~ 425514 00 000 00 0 3 1 1 4 68 HTEN BHC LB 425514 O0 000 00 0 3. I 1 4 68 CYDP DTE MMHO 425514 00 000 00 0 3 1 1 4 68 IDPH DTE OHMM 425514 O0 000 O0 0 3 ! 1 4 68 C]MP DTE MMHO 425514 O0 000 O0 0 3 ! I 4 68 I~PH DTE OH~M 425514 O0 000 O0 0 3 ! 1 4 68 CDER DTE MMHO 425514 O0 000 O0 0 3 1 1 4 68 IDER DTE OHMM 425514 O0 000 O0 0 3 i 1 4 68 CMER DTE MMHO 425514 O0 000 O0 0 3 I 1 4 68 IMER DTE OHMM 425514 O0 000 O0 0 3 1 I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Tape Verification Llstlnq :hlUmber'qer AlasKa Computin~ Center 22-APR-1gg214:02 PAGE: 12 NAmE SERV UNIT SERVICE APl AP1 AP1 APl FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUHB SAMP ELEM CODE (HEX) CDYR DTE ~MHO 425514 O0 000 O0 0 3 I ! 4 68 0000000000 ZDV~ DTE O~ 425514. O0 000 O0 0 3 I ~ 4 65 0000000000 C.~VR D~g ~,~0 4255~4 O0 000 O0 0 3 1 ! 4 6~ 0000000000 IMVR D~E OHM~ 4255~4 O0 000 00 0 3 I I 4 68 0000000000 C:I~P DT~ MMHO 4~55.14 00 000 00 0 I 1., 4 6~ 0~00000000 Z~D DTg OHM~ 425514 00 000 00 0 1 ) 4 68 0v00000000 c~ DTg ~HO 4255~4 00 000 00 0 ~ I · 4 6~ 0000000000 IL~ DTE OH~ 42551.4 00 000 O0 0 .3 I I 4 68 0,000000000 ~DQF DTE 425514 00 000 00 0 3 I 1 4 68 0000000000 ~QF DTE 425514 00 00000 0 3 ! 1 4 68 0000000000 IIRD DTE MMHO 425514 OD 000 O0 0 3 I I 4 68 0000000000 IXD DTE HMHO 425514 00 000 O0 0 ~ ! I 4 68 0000900000 ~IRM DTE M~HO ~25514 O~ 000 O0 0 , I ! 4 6~ 00000.00000 o ooo oo o , , , oooooooooo ~bt, ~T~ 0.~ 4.~s14 oo ooo oo o ~ ! ~ ~- ~s o. ooooooooo s~ oT~ ~v ¢255~4 OD ooo OD o s : 1 4 ~ oooooooooo ~. D?~ ~AP! 4~55:¢ OD 000 O0 o S I : ~ ~ 0o0o00000o T~ DTE L~ 42~S~,~ O0 000 O0 0 S ! : ¢ ~ 0000000~00 ~?EH 07~ DE~ 42551~ O0 000 O0 0 S 1 1 4 ~ 000000~ ..~ D?E O~M. ~255:4 O0 000 O0 0 S : I ¢ ~ 0000000000 ~ OT~ L~ ~25514 O0 000 O0 0 S : : 4 ~ 0000000000 ~'P.! CN~ PU 4255!~ O0 000 O0 0 S .: I ¢ ~ 0000000000 RT~R CNL 425514 00 000 00 0 3 1. I 4 6S 0000000000 TNPH C~b PU 425514 O0 000 O0 0 S ! ! 4 68 0000000000 TNRA CNn 425514 O0 000 O0 0 3 1 1 4 OS 0000000000 NPO. CNb PU 4255!4 O0 000 O0 0 3 1 I 4 68 0000000000 ~e.T C~s C~S 425514 O0 000 O0 o ) 1 I 4 ~S 00000o0000 ReFT CNL CPS 425514 O0 000 O0 0 S ! I 4 68 0000000000 CNTC C~L CPS 425514 O0 000 O0 0 3 1 1 4 68 0000000000 C~TC C~S CPS 425~4 O0 000 O0 0 S I 1 4 ~S 0000000~00 ~ C~ ~AP! 425514 O0 000 O0 0 S 1 i 4 ~ 0000000000 ~S~s C~ La 4255~ O0 000 O0 0 S 1 ~ ~ ~ 0000000000 ~E$ CNL OH~M 425514 O0 000 O0 0 3 1 ! 4 68 0000000000 ~TS~ C~ OS~ 425514 O0 000 O0 0 S. 1 I 4 ~8 0000000000 H~SN C~L ~S 4255~4 O0 000 O0 0 S- 1 ~ 4 ~8 0000000000 DATA D~PT 11493.500 DT.BHC 69.400 TTI,BHC 512.000 TT2.BHC TTS:BHC 536.800 TT4.BHC $96.~0 SP.SHC -20.000 GR,BHC CIDP.DTE 410.684 IDPH.DTE 2,435 CIMP,DTE 52z ~o, IMPH.DTE CDER.DTE 409.651 IDER.DTE 2.441 CHER.DTE 522.~81 I~ER.DTE CDYR.DTE 410.331 IDVR.DTE 2.437 CMVR.DTE 522.738 I~¥R.DTE CILD DTE 414.034 ILD.DTE 2,415 CILM,DTE 523,090 IL~ DTE IDQF:DTE 0 000 IMOF.DTE 0,000 IIRD,DTE 338.731 IIXD'DYE IIR~.DTE 481:556 IIXM.DTE 27,352 SFLU.DTE 4.524 SP:DTE G~.DTE 38.416 TENS'DTE 3695.000 HTEM.DTE 191.497 HRE$.DTE HTEN.DTE 403.9~5 NPHI.CNL 23.353 RTNR.CNL 2~455 TNPH.CNL 314,800 8,416 403,985 1,913 1,913 1,913 1,912 5B,690 -20,000 1.078 23,606 [S ?a~e Yerl~lca:tlon Listing :hlumi.erqer· Alaska Computing Center CNTC'CNL DEPT. T?3:..BHC TFN$'BHC CIDP.DTE: CDE~<DTE CDVR DTE IDQF. DTE DT IIR~D~E .T~ DT TN~A C~TC~CN~ MRESCNL DE~T. CIDP,DTE CDERiDTE CDVR'D?~ :CI~D:~DTE I~QF,DTE IIRM.DTE GR*DT~ HT~N.DTE TN~A-CNL CN?C.CN~ aRES.CML CFTC,CMl, .1t00 6385 OOO 47 472 46.50! . 509 0~000 1~628.000 999~250 6830'000 95*.847 .541 .000 '45~ 146~'4]0 1423.736 1,194 DT*BHC TT4*BHC;' IDPH.DTE IDER*DTE IDYR,DT~ .I~D.DTE I!XM;DT~ TENS~DTE NPOR*CNL CFTC.CML MTEM,CNL DT.BHC TT4'B~C NTEM,BHC IDPH;DTE' IDER,DTE~ iDVR*DTE IbD,DTE IMOF.DTE IIXM,DTE N~NI~CN~ CFTC,CML MTEM.CNL END OF DAT~ ~ FIL~ NAME: : EDIT ,003 SERVICE VERSION : 001A07 DATE : 92/04/22 MAX REC SIZE : 1024 FIL~ TYPE : LO LAST FILE 22-APR-1992:14102 23,606 RCNT,CNb I409'476 ,GR*CNb: 19! ,,497 HTEN:*CNb: 89,350 .407'2~0 185~507 2!.065 2i,505 23.628 .20.6i5 63 12 .250 10 · 4 3 0.000 845.719 6830. 54.742 356.8O0 172,488 C!MP~DTE· CMERiD?E CMVR,~DTE CISM, DTE: IIRDiDTE~ SFLU DTE! MTEM ,:DTE RCNT GR HTEN,CNS: TTI,BHC MRES,BHCi CIMP, DTE CMER*DTE= C~VR*DTE, CILM,DTE $~LU~DT~ MTEM,DTE RTNR'CNL, RCNT,CNL GR,CNL HTEN,CNL 334~.460 'RCFT,CNL ,416 TENB*CNL 4~3.:985 584'800 't5;.t25 GR'BHC~ 1.!31 H?£N'BHC. 57.618 IMPH*DTE 56,~23 IMER*DTE 53'.08! IMYR~DTE 62-620 ILM.DTE 42'631 !IXD!*DTE 24.640 18~,:~07: MRE$,DTE 2.,7:4~' ~TNPH'CNL ~394~63~. RCFT,CNL 12~3,268 . "i.194 HTEN '229 811 PH '231 845. ~ER YR -256 639 IbM :76 255 !IXO 0~677 i72488 MRES 4~465 6:3 ~2 TENS 1466,430 DTE DTE DTE .DTE .DTE DTE .DTE CML CML CML PAGE: 13 13695" 000 405-800 33:~942: 1::213'268 17'356 17,630 18:839 15 969 1'601 !5 26, 1 1252:~ 6385, 0 -999=250 63452 1466 430 1950 000 1950 000 1950 000 :1950 000 -408 087 -92 563 1 194 54 140 357 571 6830 000 ,hlumberger Alas~a~ computing Center 22"APR-1992 i4~02 14¸ FILE= NAME,' 'SERVICE { 001407 VERSION DATE { 92/04/22 MAX EEC SYZE : 1024' FI'~ TY~E: I bO bAT FILE F!LE HEADER FILE. NUMBER 4 R,AW OPEN HOPE REPEAT PASSES Curves and log ~eader data for each Pass, tool string, and run ~n seParate:files, RUN NUMBER: 1 TOOL STRING NUMBER: ! PASS NUMBER{ 1 DEPTH INCREMENT{ O*50OO FILE SUMMARY VENDOR TOOL CODE $TART DEPTH BHCS CNTH $ LOG HEADER DATA DATEibOGGEDI {{070,0 t~102;0 11050,0 $OFTWARE.VERMIONI~ TIME CIRCULATION ENDED{ TINE LOGGER TD DRILLER (FT)~ TD bOGGER(FT) TOP bOG INTERVAL (FT) BOTTOM LOG INTERVAh (~T){ LOGGING SPEED (FPHR){ 18638,0 10 8,0 · TOOL STRING (TOP TO BOTTOM VENDOR TOOL CODE TOOL '{"YPE TCC CNTH B~CS BHC$ DITE DITE TELEMETRY CARTRIDGE GAMMA RAY SONDE COMPENSATED NEUTRON BOREHObE COMP,~ SONIC BOREHOLE COMP,, SONIC PHASOR INDUCTION CART BOREHOLE AND CASING DATA Open HO[,~: B~[T ~IZE DRILLERS CASING DEPTH{FT): O'3-APR'92 5B0-23! ~00 1~06 03-APR-9~ 7852.0 ~14t9.0 1800,0 TOOL NUMBER TCC-B 320 SGC-$A ~gO CNC-HA SbC-UA X36 Sb$-WA 200! DIC=EO 427 DI$-HB 434 8 500 io'tl5.o ?ape ver~lcetion List! ~hlumberger ~las~a Com. puti~ Center 22'APR-1992 14:02 LOGGERS CASING DEPTH BOREHOLE CONDITIONS MUD TYPE:. F~U!D bO~S MAXIMUM' RECORDED~ TEMPERATURE~ (DE~F){~ F AT MEASURED T~MP~RA~URE~ (~T) MUD AT BOTTOM HOLE ~ENP~R~TUR:E: (BHT): HUD FILTRATE AT MUD FILTRATE AT (BHT)~ MUD CAKE AT (MT): CAKE AT NEUTRON TOO~ TOO[, TYPE (EPITHERMA[, OR THERMAL)I MATRIX: MATRIX. DENSZTY'I HOLE CORRECTION (IN): TOOL STANDOFF (IN): ~ENARKS~ 10708.0 9,~00 37,:00 9'00 7'60 tgO'O 3,990 1;394 ;5~0 ~'576 2!,590 1~2'0 0'0 0'0 1~0,0 SANDSTONE 2.6 5 TOOLSTRING (BOT-TOP~ =.,DITE-BHC-CNL-GR-TCC-AM$ NEUTRON ~A. TRIX= SA DSTONE. HOLE CORRECTION =..BITSIZE RAN CNL WITHOUT BOWSPRING. OCATION OF INTERVAL~: 775' &Nb & 5250' WES'SEC 36 T12N R~RE ~I$ FOR~A.T DATA PAGEI 15 DATA FORMAT SPECIFICATION ** SET TYPE - 64EB TYPE REPR · I 66 2 66 3 73 4 66 5 66 6 73 7 65 B 68 9 65 11 66 12 68 RECORD ** CODE VAbUE 0 0 22O 1 0.5 FT 4 ~hlu~erger Alast~a Computing Center 22-APR-Igg2 14C02. TYPE REP~ CODE VALU~ 13 6b 0 15 66 16 66 0 66 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE APl AP1 APl APl FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASSY. NOD NUMB SAMP ELEM CODE (HEX) DEPT FT 425514 O0 000 O0 0 4 i ! DT BHR US/F 425514 O0 000 O0 0 4 1 TTI BHR US 425514 O0 000 O0 0 4 I I TT2 BHR US O0 0 4255t4 000 O0 4 TT3 BH. US 425514 O0 000 O0 0 4 TT4 BHR US 425514 O0 000 O0 0 4 1 SP BHI~ NV 425514 O0 000 O0 0 4 I 1 GR BHR GAP! 425514 O0 000 O0 0 4 I 1 TEN'8 BHR LB 425514 O0 000 O0 0 4 1 .TE~ BHR DEG:F 4255~4 O0 000 O0 0 4 Me S oo ooo oo o ID P" OTR OH~. 4255~ O0 000 O0 0 4 oo ooo oo o C'E~ DT" "M"O 4255t4 O0 000 O0 0 4 IME~ DTR OHMM 425514 O0 000 O0 0 4 1 1 COY" DT" ~""O 425514 O0 000 O0 0 4 oo 000 oo 0 4 c v. oo 000 oo 0 CIbD DTR MMHO 425514 O0 000 O0 0 4 1 IbO DT~ OHMM 425514 O0 000 O0 0 4 CIL" DTR M~HO 425514 O0 000 00 0 4 1 IL~ DTR OH~M 425514 00 000 O0 0 4 1 1 ID~F DT~ 425514 00 000 00 0 4 1 1 I~OF DTR 425514 O0 000 O0 0 4 1 1 II~ D~ ~O 425514 00 000 00 0 4 1 1 IIX~ DT~ NNHO 4255~4 00 000 00 0 4 1 1 II~ DT~ MNHO 425554 00 000 O0 0 4 1 IZX~ DTR N~HO 425514 00 000 00 0 4 1 1 SFLU DTR OH~M 425514 O0 000 O0 0 4 1 SP DT~ HV 425514 O0 000 O0 0 4 1 GR DT~ GAPI 425514 O0 000 O0 0 4 1 1 TE~S DTR 6B 425514 O0 000 O0 0 4 1 MTE~ DTR DEGF 425514 O0 000 O0 0 4 1 1 M~E~ DTR OH~M 425514 O0 000 O0 0 4 1 I 4 6B 0000000000 4 ~ 0000000000 4 0000000000 4 68 0000000000 4 68 Og~O000000 4 68 0 0000000 4 68 06 0000000 4 68 00~0000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 :hlUm rger Alas' put nq Center 22-APR-t992 14:02 PAGE: !¸7 NAME SERV UNIT SERVXCE APl ID ORDER # bOG CNT~ CNR CPS 42 514 O0 000 O0 4 1 1 CFTC CNR CP 42'514 O0 000 O0 4 ! ! GR CNR GAP! 4255'14 O0 000 O0 0 4 ! 1 TEN8 CNR hB 425514 O0 000 O0 0 4 MRE$ CNR OHMM 425514 O0 000 O0 0 4 1 NTE~ CNR DEGF 425514 O0 ~00 O0 0 4 1 1 HTE~ CNR LB 425514 O0 ~I~~J~ImI~IIIJII~J~IJI~Im~J~J~JJJ~IIII~IIII~ AP1 API AP1 FILE NUMB NUMB SIZE REPR PROCESS TYPE CbA$$ MOD NUMB SA~P EbEN CODE (HEX) 4 68 0000000000 ,, oooooooooo oooooooooo oooooooooo oooooooooo oooooooooo ' ooooooo o 0000000 0 4 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 080.0000000 4 68 0 00000000 DEPT. TT3.,BHR TEN$.BHR CID DTR CDV DTR CI~ DTR IIR DTR G HT£ DTR TNRA CNR CNTC CNR ~RE8 CNR DEPT. TT3.BHR T~NS.BHR ClDP.DTR CDER,DTR CDVR.DTR CILD.DTR IDQF.DTR IIRH.DTR GR.DTR HTEN.DTR TNRA.CNR CNTC CNR ooo 139 ~65 0 iO0 t00 16 1066 4gl 312 11000.000 582 800 65O5 000 48 126 53 955 49 871 49.224 0,000 61.822 46 361 1216:087 2,462 3220,741 1.12i DT,BHR TT4,BHR MTEM,B~R IDPH..DTR IDER DTR IDVR DTR I~D D?~ IMQ~ DTR IIXM DTR TENS NPHI CNR NPOR CNR C~TC CNR MT£M.CNR DT.BHR T?4.BHR MTEM.BHR IDPH.DTR IDER,DTR IDVR.DTR ILD.DTR I~F.DTR IIXM.DTR TENS.DTR NPHI.CNR NPOR.CNR CFTC.CNR MTEM.CNR 85 41~ 7 7 0 477~ 25 25 1299 1~6 81 404 185 20 18 20 20 0 9 6505 25 27 1298 185 ~00 TT1,BHR 200 SP,BHR 559 MRES.BHR 177 CIMP,DTR 187 CMER,DTR 170 CMVR,DTR 064 CILM.DTR 000 IIRD,~DTR: 63 SFhU,DTR O0 MTEM,DTR 394 RTNR.CNR 646 RCNT,CNR .616 GR.CNR .559 HTEN.CNR 350 TT1.BHR 800 SP,BHR 793 MRE$.BHR 779 CIHP.DTR ~14 CMER,DTR 2 CMVR,DTR 315 CILM,DTR .000 IIRD.DTR 463 8FLU.DTR 000 MTEM.DTR 843 RTNR.CNR 0~2 RCNT.CNR 698 GR.CNR 793 HTEN.CNR 578 -20 104 !04 106 124 3264 16 1066 800 O0 12 18 ! 24 559 600 7 32 '715 48t GR BHR HTEN BHR XMPH DTR IME~ DTR IMVR DTR ~.~ DTR IIXD DTR SP DTR MRE$ DTR TNPH CNR RCFT CNR TEN$.CNR 5~!i00 TT2:BHR 25 GR BHR ! 21 HTEN.BHR 61 65 64:~ IMPH.DTR IMVR.DTR 65 IbM.DTR 13 773 SP,DTR 185:793 MRE$,DTR 2.612 TNPHoCNR 3344.864 RCFT,CNR 46.36! TENSeCNR 1216,087 4.02,800 16.715 1066,4B1 9.597 9.598 9,59~ 9,41 13,087 -20,000 2~.,127 .646 1235.865 4770.000 399,600 46,361 1216.087 16.269 15.605 16'582 15.351 2,670 -2,625 1,121 26.797 1211.250 6505.000 ~lum~erqerAlaska~ ComPUtt · in~ Center. 22'APR'!gg2 14{02 D~PT. TT3.BHR TEN'~.BHR CIPP,DTR CDE~*DTR CDVR,DTR ClLD,DTR IDOF,DTE II~ OTR GR HTEN DTR TNRA CNE CNTC CNA 250 6730 000 ?o 66 376 71.012 0~000 '239,017 48,754 1438.550 4'1]3 1537,874 1.203 DT.BHR TT4.BHR MTEMjBHR IDPH~DTR IDER~DTR IDYR~DTR ILO DTR IM~F I.IX~ DTR TENS DTR NPOR,CNR CFTC,CN~ MTEM.CNR 67.,85 =T~ 999,25~ 176.i~6 MRES, !4'.1~8 ,CI. MP 15'066 !4~082 C~V~ 13.293 CIb~ 0,000 IIRD~ 808~t5~ ~MFLU~ 67~0~000 54'8~0 RTNR, 54,478 RCNT, '397 ~,166. HTEN ~BHR .DTR ~DTR ,DTR ~DTR DTR DTR ~CNR CNR~ CNR: . ,1'203 T~N .273,~551 279'711 lEER '274,~5~ I~VR -2B1,218 Ib~ 176'166 4'688 1669.215 48.954 ~4~8.550 BMR BHR BHR DTR DTR DTR :DTR DTR .CNA ,CNA CNA :-999250 48 754 :I438550 1950.000 t950 000 1950 000 1950 000 -~07874 563 ;9~ 203 55 059 334,086 6730.000 END OF DATA ** **** **** FILE NAM,:' EDIT .004 VERSION' O0~A07 DATE~ [:92.04/22 ~AX REC'S~Z~ ~ 1024 'FILE TYPE ~ LO LAST~ FILE, **** TAPE TRAILEP SERVICE NAME : EDIT D!.T~~ : 92/04/22 T~PE NAME : 92249: CONTINUATION # : P~VIOU$ TAPE COM"ENT : BP EXPLORATIOH,PRUDHOE BAY,M - 30 (14-36-12'1~),50-029-22255-00 **** REEL TRAILE~ **** SERVICE NAM~ : EDIT DATE : 92/04/22 ORIGIN : REEL NA~E : 92249 CONTINUATION PREVIOU~ REE~ COM"ENT : BP EXPLORAT{ON,PRUDHO~ BAy,M - 30 (14-36-~2-12),50-029-22255=00
