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193-158
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 04-11A PRUDHOE BAY UNIT 04-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 04-11A 50-029-20286-01-00 193-158-0 W SPT 7927 1931580 2390 1730 1715 1715 1716 94 328 331 316 REQVAR P Josh Hunt 6/21/2025 2-year required by AIO 4G.016 to the greater of the maximum anticipated injection pressure. 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 04-11A Inspection Date: Tubing OA Packer Depth 999 2697 2640 2621IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250622100208 BBL Pumped:4.6 BBL Returned:4.1 Thursday, July 24, 2025 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector 04-11A (PTD #1931580) AA for continued water injection Date:Wednesday, June 14, 2023 3:01:57 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, June 14, 2023 3:00 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector 04-11A (PTD #1931580) AA for continued water injection Mr. Wallace, Sea Water Injector 04-11A (PTD #1931580) approved AA 4G.016 has been received for continued water injection. The well is now classified as OPERABLE. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, June 1, 2023 11:09 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector 04-11A (PTD #1931580) anomalous IA re-pressurization Mr. Wallace, Sea Water Injector 04-11A (PTD #1931580) was identified on 05/31/23 as having slow IA re- pressurization. A bleed was performed on 06/01/23 and the IA pressure increased during the subsequent 30-minute monitor. The well is now classified as UNDER EVALUATION and is on the 28- day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T, re-energize WH seals as necessary 2. DHD: Monitor for IA re-pressurization 3. Fullbore (pending): AOGCC MIT-IA 4. Well Integrity (pending): Apply for AA if MIT-IA passes Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 04-11A PRUDHOE BAY UNIT 04-11A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 04-11A 50-029-20286-01-00 193-158-0 W SPT 7927 1931580 1982 2250 2250 2250 2255 5 160 163 153 OTHER P Guy Cook 6/6/2023 Under evaluation for TxIA communication. MIT-IA for AA application. Max injection pressure to seawater header pressure of 2300 psi. 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 04-11A Inspection Date: Tubing OA Packer Depth 476 2997 2901 2870IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230605155535 BBL Pumped:6.7 BBL Returned:6.4 Wednesday, July 26, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 Under evaluation for TxIA communication. James B. Regg Digitally signed by James B. Regg Date: 2023.07.26 16:42:37 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector 04-11A (PTD #1931580) anomalous IA re-pressurization Date:Thursday, June 1, 2023 11:13:22 AM Attachments:04-11A.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, June 1, 2023 11:09 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector 04-11A (PTD #1931580) anomalous IA re-pressurization Mr. Wallace, Sea Water Injector 04-11A (PTD #1931580) was identified on 05/31/23 as having slow IA re- pressurization. A bleed was performed on 06/01/23 and the IA pressure increased during the subsequent 30-minute monitor. The well is now classified as UNDER EVALUATION and is on the 28- day clock for diagnostics. Plan Forward: 1. DHD: PPPOT-T, re-energize WH seals as necessary 2. DHD: Monitor for IA re-pressurization 3. Fullbore (pending): AOGCC MIT-IA 4. Well Integrity (pending): Apply for AA if MIT-IA passes Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the 5" X 7" FMC 75 WfliHEAD= GRAY GEN2 ACTUATOR= AXE -SON KB_ ELEV = 56.8' BE E -EV = Refer to Production DB for historical perf data KOP= 2459' Max Angle = 52" @ 5274' Datum ND= 11323' Datum TVD = 8800'SS 04-11A 13-318" CSG, 72#, N-80, ID = 12.347" 2741' Minimum ID = 0.35" @ 10191' 3-1/2" DOWNHOLE CHOKE ASSY TOP OF 7" LNR 9-5/8" CSG, 47#, Iw80, D= 8.681" 10397 STOCK SET IN BAKE? DW -1 PKR WHIPSTOCK 10412' 101 11468' 1 7" LNR, 29#, L-80_0371 bpf, D = 6.184" SAFETY NOTES: ***ORIG W ELLBORE NOT SHOWN BELOW WS 0 10412'*** 9653'-10002 I15-1/2" WFD HCR PATCH ASSY, [)=2.990"(04126/081 10125' 1--� 9-518" X 5-1/2" TIW HBBP PKR 3-1/2" OTIS XN NP RE]1JC62, D = 2.635" (04/26108) 2.75" OTIS XN LOCK, DH CHOKE ASSY, ID = 0.35" (01 /05/21) 10203' —15-1/7 WLEG, D=4.892" ELMD TT NOT LOGGED MILLOUT WINDOW (04-11A) 10392--10404- 111151101 0392'-10404' 11510' PERFORATION SUMMARY REF LOG: BHCA ON 11/17/93 PRUDHOE BAY UNIT WELL:04-11A PERMIT No: 1931580 API No: 50-029-20286-01 SEC 26, T11 N, R15E, 4592.71' FEL & 1646.15' FNL ANGLE AT TOP PERF: 34 @ 11188' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 6 11188- 11210 O 1/11/2006 3-3/8" 6 11229 - 11248 O 3/15/08 3-3/8" 6 11266 - 11322 O 3/15/08 2-1/2" 4 11330- 11350 O 12/13/93 101 11468' 1 7" LNR, 29#, L-80_0371 bpf, D = 6.184" SAFETY NOTES: ***ORIG W ELLBORE NOT SHOWN BELOW WS 0 10412'*** 9653'-10002 I15-1/2" WFD HCR PATCH ASSY, [)=2.990"(04126/081 10125' 1--� 9-518" X 5-1/2" TIW HBBP PKR 3-1/2" OTIS XN NP RE]1JC62, D = 2.635" (04/26108) 2.75" OTIS XN LOCK, DH CHOKE ASSY, ID = 0.35" (01 /05/21) 10203' —15-1/7 WLEG, D=4.892" ELMD TT NOT LOGGED MILLOUT WINDOW (04-11A) 10392--10404- 111151101 0392'-10404' 11510' PRUDHOE BAY UNIT WELL:04-11A PERMIT No: 1931580 API No: 50-029-20286-01 SEC 26, T11 N, R15E, 4592.71' FEL & 1646.15' FNL DATE REV BY COMMENTS DATE REV BY COMMENTS 112493 ORIGINAL COMPLETION 11/18/10 RRD/PJC SET IBP (1111/1111110) 189194 LAST WORKOVER 02/28/11 MBM/PJC PULL IBP 02117/11 11/16/06 CJN/PAG PULL PXN PLUG 10191' 09/17/11 MSS/ PJC SET XXN PLUG (09/10111) 04/02/08 GJF/PJC PERFORATIONS (03/15)08) 12/11/11 BSE/PJC PULL XXN (11125111) 04/15/08 RRD/PJC SET LOWER PATCH 04/06/08 11/29/17 RCB/JMD SET DH CHOKE 1128/17 (0110421) Hikorp North Slope, LLC 05/04/08 CJN1 PJC XN NIP RED/ UPPER PKR (0412 01/1021 TD/MM PULL & RESET DH CHOKE ASSY MEMORANDUM TO: Jim Regg k�� P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, September 22, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC - 04-11 A PRUDHOE BAY UNIT 04-11 A Src: Inspector Reviewed By: P.I. Supry J4— Comm Well Name PRUDHOE BAY UNIT 04-11A API Well Number 50-029-20286-01-00 Inspector Name: Austin McLeod IRsp Num: mitSAM200920105043 Permit Number: 193-158-0 Inspection Date: 9/20/2020 - Rel Insp Num: Packer Well 04-11A Type Inj W ''iTVD PTD 1931580 'IType Test SPT'',Test psi BBL Pumped: 63 BBL Returned: Interval' 4YRTST BPIF Notes: MIT -IA Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 7927 Tubing 1825 1820 1810 1815 1982 IAi 78 2500 2347 }- 2368 6 OA 7 39 46 45 P / Tuesday, September 22, 2020 Page 1 of I 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,----7 DATE: eggDATE: Wednesday,September 07,2016 P.I.Supervisor of e? 1/q/& SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 04-11A FROM: Chuck Scheve PRUDHOE BAY UNIT 04-11A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry — NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 04-11A API Well Number 50-029-20286-01-00 Inspector Name: Chuck Scheve Permit Number: 193-158-0 Inspection Date: 9/2/2016 Insp Num: mitCS160902153416 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 04-11A ' Type Inj W' TVD 7927 ' Tubing 938 - 938 938 938 PTD 1931580 Type Test SPT Test psi 1982 - IA 4 2180 - 2067 - 2033 - Interval 4YRTST P/F P ✓ OA o - 0 0 0 - Notes: SCANNED tii(IN 0 32017 . Wednesday,September 07,2016 Page 1 of I o • Wallace, Chris D (DOA) -I■I From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, August 22, 2016 5:12 PM To: AK, GWO SUPT Well Integrity;AK, OPS FS2 OSM; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AKOpsProdEOCTL; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Regg, James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel, Troy;Worthington, Aras J Subject: OPERABLE:Injector 04-11 (PTD#1931580) POI post-seawater line repairs All, Injector 04-11 (PTD#1931580)was shut in as a result of seawater line repairs. While shut in its AOGCC-witnessed MIT- IA expired and was reclassified as Not Operable. The well is now reclassified as Operable and can be POI. Once injection has been stabilized an AOGCC-witnessed MIT-IA will be performed. Thanks! Jack Lau (Alternate:Adrienne McVev) BP Alaska-Well Integrity Superintendent sums NOV 0 82016 W: 907.564.5102 C: 907.943.0296 H: x2376 om: AK, GWO SUPT Well Integrity Sent: day, July 10, 2016 7:37 PM To: AK, OPS SM; AK, OPS FS2 Field OTL; AK, OPS FS2 Facility OTL; AKOpsProdEOCTL; AK, OPS PCC Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Stechauner, Bernhard; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (lim.reo•Eaalaska.gov); Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; ernicki, Oliver R; Tempel, Troy; Worthington, Aras J Subject: NOT OPERABLE: Injector 04-11 (PTD #1931580) Will Remain Shut In Past AOGCC Test Due Date All, Injector 04-11 (PTD# 1931580) is due for an AOGCC-witnessed MIT-IA by the end of July.The well will not be brought online by then due to seawater line repairs and facility turnarounds, expected to be completed in August 2016.The well is reclassified as Not Operable. Thanks, • S Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,July 10, 2016 7:37 PM To: AK, OPS FS2 OSM;AK, OPS FS2 Field OTL;AK, OPS FS2 Facility OTL;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, RES GPB West Wells Opt Engr; G GPB FS2 Drillsites; Stechauner, Bernhard;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Regg,James B (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J Subject: NOT OPERABLE:Injector 04-11 (PTD#1931580)Will Remain Shut In Past AOGCC Test Due Date All, Injector 04-11 (PTD#1931580) is due for an AOGCC-witnessed MIT-IA by the end of July.The well will not be brought online by then due to seawater line repairs and facility turnarounds,expected to be completed in August 2016.The well is reclassified as Not Operable. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWeIlIntegrityCoordinator@BP.com 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /~;~"/_~ ~/File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No, [] Other, No/Type OVERSIZED . [] Logs 'of various kinds , [] Other Scanned by: BeverJ~ Diann~athan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ 04/28/11 Schlumberger /10.5729 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 ../ Alaska 00 8 Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 15 -09A BBKA -00096 PRODUCTION PROFILE / 9:3 ° 03/14/11 1 .. O`P(a 1 17 -06 BBKA -00094 INJECTION PROFILE () [(• ( _ 03/10/11 1 t.b 1 C -12B BAUD -00064 MEM PRODUCTION PROFILE ( 03/08/11 G -23B BLP0-00079 MEM PRODUCTION PROFILE q — 14 B FS> • ^F.'11. 71111=1 16.08A BJGT -00022 GLS ^ " — r 0 �:• • —_ BLPO -00087 h,laa,[.Ias►1,Zr s; IIEEEEGOEMFT•T:F a 0IIIIMIIIIOMIIMIII IMIIIMIIIEEGQIMIIIIIIIII BJGT -00023 , ♦j4. _ '®' l0 -- i • iii:. • •-• • . V-105 BLP0-00091 MEM INJECTION PROFILE BBSK -00065 Ih!1aNFl•1JIJ:U73IIaP�ly� j i�a�"�i , ♦ _ i OP;~TiLY�il�IIMMill... • BAUJ -00071 MEM INJECTION PROFILE .a ' �. r ���OG- •CMjO� —_ BAUJ -00077 • • • • 5 (���0:_rILrIelO -- 3- 05/0 -29 BG4H -00043 iZ �11 _ r BLPO -00092 MEM PRODUCTION PROFILE ' ∎'YfeTiY�O�!�Ttz�C�i ■ BBSK -00057 [.-] GT __ .. MIMEEXE7ylME1 BD88 -00097 MEM INJECTION PROFILE ^ [a j'r �eG EMMEM -- \ , NCTI OI • PRODUCTION PR PROFFLE ILE Z 0 j ` �'"'� �� ,1 T r ••iii •-•• -• •-• ',(�.. 03/24/11 MAIM 1 Z -20 BP5G- 00010 Q • 03/29/11 1 II41•tr�l 1 -- Y -29A BCUE -00122 MEM LDL r / -7 1, 03/20111 1 . lc_ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulttng Services Petrotechnical Data Center LR2-1 2525 Gambell Street, Sulte 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 0 mil ,, ; . c .Ii, I; i,', STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIAP • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other El ACID Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ ' 193 -1580 3. Address: P.O. Box 196612 Stratigraphic El Service IO 6. API Number: Anchorage, AK 99519 -6612 t° 50- 029 - 20286 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: a ADLO- 028324 PBU 04 -11A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 11510 feet Plugs (measured) 9658 feet true vertical 9045.99 feet Junk (measured) None feet Effective Depth measured 11468 feet Packer (measured) 10125 feet true vertical 9011.27 feet (true vertical) 7927 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 84' 20" 94# H-40 27 - 111 27 - 111 1530 520 Surface 2715' 13- 3/8 "72# N -80 26 - 2741 26 - 2731 5380 2570 Intermediate Production 10367' 9 -5/8" 72# N -80 25 - 10392 25 - 8129 6870 4780 Liner 1311' 7 "29# L -80 10199 - 11510 7982 - 8914 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ - True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 23 - 10203 23 - 7985 Packers and SSSV (type, measured and true vertical depth) 9 -5/ X 5 -1/2" TIW HBBP PKR 10125 7927 u 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): DEC 07 2010 Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cons. Commiss 13. Representative Daily Average Production or Inject Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 10,439 2,246 Subsequent to operation: 7,026 1,123 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Servic El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -391 Contact Joe Lastufka Printed Nam: • = astufka ilk i Title Data Manager Signature ago Phone 564 -4091 Date 12/3/2010 Form 10-404 Revised 10/2010 RBDMS DEC 0 8 Submit Original Only ;/ 04-11A 193 -158 , . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth To Tvd Depth Base 04 -11A 12/13/93 PER 11,330. 11,350. 8,897.18 8,913.72 04 -11A 7/24/02 BPS 10,181. 10,182. 7,968.72 7,969.47 04 -11A 7/30/02 BPP 10,181. 10,182. 7,968.72 7,969.47 04 -11A 7/12/03 BPS 10,181. 10,182. 7,968.72 7,969.47 04 -11A 7/21/03 MLK 9,699. 9,700. 7,611.47 7,612.2 04 -11A 7/23/03 BPP 10,181. 10,182. 7,968.72 7,969.47 04 -11A 11/2/05 BPS 10,185. 10,186. 7,971.72 7,972.47 04 -11A 12/26/05 BPP 10,185. 10,186. 7,971.72 7,972.47 04 -11A 1/11/06 APF 11,188. 11,210. 8,779.79 8,797.98 04 -11A 11/3/06 BPS 10,200. 10,201. 7,982.97 7,983.72 04 -11A 11/16/06 BPP 10,200. 10,201. 7,982.97 7,983.72 04 -11A 10/23/07 BPS 10,186. 11,188. 7,972.47 8,779.79 • 04 -11A 12/1/07 BPP 10,186. 11,188. 7,972.47 8,779.79 04 -11A 12/6/07 BPS 9,658. 11,188. 7,581.75 8,779.79 04 -11A 12/7/07 BPP 9,658. 11,188. 7,581.75 8,779.79 04 -11A 3/15/08 APF 11,226. 11,248. 8,811.21 8,829.39 04 -11A 3/15/08 APF 11,266. 11,322. 8,844.27 8,890.57 04 -11A 3/20/08 BPS 10,205. 10,206. 7,986.73 7,987.48 04 -11A 4/3/08 BPP 10,205. 10,206. 7,986.73 7,987.48 04 -11A 11/18/10 BPS 9,658. 11,350. 7,581.75 8,913.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED 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 w • • 04 -11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ( 11/24/2010 CTU #8 W/ 1.75" CT: Job Scope:, Mud Acid w/ Foam livertPr• MIRU CT unit. MU and RIH with 2.25" JSN BHA. Begin pumping mud acid and foam diverter stages per 'schedule while reciprocating CT across perforations. ** *Job Continued on 25 Nov 110*** 3 � i ? 11/25/2010CTU #8 W/ 1.75" CT: Job Scope: Mud Acid w/ Foam Diverter: Continued from 24 E Nov 10. Continue pumping mud acid and foam diverter stages per schedule while !reciprocating CT across perforations. Complete acid pumping schedule and displacement. Hand well over to operations to place on injection. RD CT unit. 1 ** *Job Complete * ** ( � 4 FLUIDS PUMPED BBLS 96 12% HCL ✓ / 68 9:1 HCL:HF 164 TOTAL TREE= GRAY GEN 2 • SAFETY N 04-1 1 A C.: * * *ORIG W ELLBORE NOT SHOW N WELLHEAD= GRAY = AXELSON BELOW w 10412' * ** KB. ELEV = 56.8' BF. ELEV = KOP = 2459' Max Angle = 52 @ 5274' Datum MD = 11323' ( 2206' 1— {5 -1f2" CAM BAL 0 SSSV NIP, ID = 4.562" Datum TVD = 8800' SS 113 -3/8" CSG, 72 #, N-80, ID = 12.347" I-I 2741' Minimum ID = 2.635" @ 10191' 5 -1/2" X 3-1/2" NIPPLE REDUCER 1 9653' -10002 I-- 5 FD , 2.990 (04!26/08) PKRPATCHASSY S X I 10125' H9-5/8" X 5 -1/2" TIW HBBP PKR 1 ii I 10191' H5-1/2" OTIS XN NIP, ID = 4.455" 1 10191' I 5 -1/2" X 3 -1/2" OTIS XN NIP TOP OF 7" LNR I 10199' 1 REDUCER, ID = 2.635" (04/26/08) 15 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" I--I 10203' 1 / ‘ I 10203' I— I5 -1/2" WLEG, ID = 4.892" H ELMD TT NOT LOGGED I 19 -5/8" CSG, 47 #, N-80, ID = 8.681" I-I 10392' • MILLOUT WINDOW (04 - 11A) 10392' - 10404' I WHIPSTOCK SET IN BAKER DW -1 PKR H 10392' I WHIPSTOCK I 10412' ` PERFORATION SUMMARY ` I 11319' 1 BKR IBP ((11 /18110) I REF LOG: BHCA ON 11/17/93 ANGLE AT TOP PERF: 34 @ 11188' Note: Refer to Production DB for historical perf data . SIZE SPF INTERVAL Opn /Sqz DATE 4 401%,. 3 -3/8" 6 11188 - 11210 0 1/11/2006 I PBTD I 11468' \R� 44 vo 3 -3/8" 6 11229 - 11248 0 3/15/08 `�� * 3 -3/8" 6 11266 - 11322 0 3/15/08 N O 2 -1/2" 4 11330 - 11350 C 12/13/93 1 LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 11510' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/24/93 ORIGINAL COMPLETION 11/18/10 RRD /PJC SETIBP(11/18/10) WELL: 04 -11A 10/01/94 LAST WORKOVER PERMIT No: r 1931580 11/16/06 CJN/PAG PULL PXN PLUG @ 10191' API No: 50- 029 - 20286 -01 04/02/08 GJF /PJC PERFORATIONS (03/15/08) SEC 26, T11 N, R15E, 4592.71' FEL & 1646.15' FNL 04/15/08 RRD /PJC SET LOWER PATCH (04/06/08) 05/04/08 CJN/ PJC XN NIP RED/ UPPER PKR (04/24/08) BP Exploration (Alaska) A LtA Z K a SEAN PARNELL, GOVERNOR �T�+r�tt � OIL A" GAS 333 W. 7th AVENUE, SUITE 100 CO COMZrIISSION � ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 f FAX (907) 276 -7542 Olivia Bommarito Petroleum Engineer i BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04 -11A Sundry Number: 310 -391 Dear Ms. Bommarito: ,, DEC q 1 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this y of November, 2010. Encl. • � Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, November 24, 2010 3:15 PM To: 'Bommarito, Olivia 0' Subject: RE: Request for verbal Sundry approval DS 4 -11A (PTD 193 -158) Based on our phone conversation describing the work planned and reviewing the submitted 403 sundry you have verbal permission to perform the Mud acid stimulation on DS 4 -11A. 11� e 0 � ' J" '' ll p Regards, n'" N Guy Schwartz J" 1 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bommarito, Olivia 0 [mailto: Olivia. Bommarito@bp.com] Sent: Wednesday, November 24, 2010 2:24 PM To: Bommarito, Olivia 0 Cc: Schwartz, Guy L (DOA); AK, D &C Wells CT Scheduler; laujj @bp.com Subject: Re: Request for verbal Sundry approval The permit # is 193 -158 On Nov 24, 2010, at 2:22 PM, "Bommarito, Olivia O" <Olivia.Bommarito @ bp.com> wrote: Guy - Thanks for taking my call and Happy early Turkey Day!! Gary just walked down to have the hard copies couriered over for the 10 -403 for the 04 -11Ai mud acid job. I'm sure you get expedited requests all the time, so thanks for taking one more. Please call me at 907.952.4799 for verbal approval once you've had a chance to review everything. Coil will move off the well (job had not yet started) and proceed to another job. Olivia Bommarito 907.952.4799 11/24/2010 STATE OF ALASKAD ALASSIL AND GAS CONSERVATION COMMISSIO APPLICATION FOR SUNDRY APPROVALS l'3 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑Q - Alter Casing ❑ ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 193 -1580 3. Address: P.O. Box 196612 Stratigraphic ❑ Service FIT 6. API Number: Anchorage, AK 99519 -6612 50-029-20286-01-00, 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ PBU 04 -11A 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028324 PRUDHOE BAY Field / PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11510 9045.99 11468 9011.27 9658 11/18/10 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 84 20" 94# H-40 27 111 27 111 1530 520 Surface 2715 13- 3/8 "72# N -80 26 2741 26 2731 5380 2570 Intermediate Production 10367 9 -5/8" 72# N -80 25 10392 25 8129 6870 4760 Liner 1311 7'29# L -80 10199 8914 7982 8914 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached - - 5 -1/2" 17# L -80 23 10203 Packers and SSSV TVDe: 5 -1/2" TIW HB -BP Packer Packers and SSSV MD and TVD (ft): 10125 7927 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service ❑� - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/8/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: �� j WINJ ❑ - GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: `,w �c�w.t�.tL GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing-A true and correct to the best of my knowledge. Contact Olivia Bommarito Printed Name Olivia Bommarito Title P.E. Sig r R Phone Date /VtN-j 564 -4096 11/24/2010 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number3)0 �� , I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: '`SEC +. N NOV 2 4 2010 0 0 Subsequent Form Required: /,r� _ giD �a r� !ie'Sd' njs cons. Al vv 77 �t�C$�r�t - APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: JI /3's Form 10-403 Revised 1/2010 RI AL / 'G`�� f/� Submit in Duplicate 04 -11 A 193 -158 PERF ATTACHMgNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Tor Tvd Depth Bas 04 -11A 12/13/93 PER 11,330. 11,350. 8,897.18 8,913.72 04 -11A 7/24/02 BPS 10,181. 10,182. 7,968.72 7,969.47 04 -11A 7/30/02 BPP 10,181. 10,182. 7,968.72 7,969.47 04 -11A 7/12/03 BPS 10,181. 10,182. 7,968.72 7,969.47 04 -11A 7/21/03 MLK 9,699. 9,700. 7,611.47 7,612.2 04 -11A 7/23/03 BPP 10,181. 10,182. 7,968.72 7,969.47 04 -11A 11/2/05 BPS 10,185. 10,186. 7,971.72 7,972.47 • 04 -11A 12/26/05 BPP 10,185. 10,186. 7,971.72 7,972.47 04 -11A 1/11/06 APF 11,188. 11,210. 8,779.79 8,797.98 04 -11A 11/3/06 BPS 10,200. 10,201. 7,982.97 7,983.72 04 -11A 11/16/06 BPP 10,200. 10,201. 7,982.97 7,983.72 04 -11A 10/23/07 BPS 10,186. 11,188. 7,972.47 8,779.79 04 -11A 12/1/07 BPP 10,186. 11,188. 7,972.47 8,779.79 04 -11A 12/6/07 BPS 9,658. 11,188. 7,581.75 8,779.79 04 -11A 12/7/07 BPP 9,658. 11,188. 7,581.75 8,779.79 04 -11A 3/15/08 APF 11,226. 11,248. 8,811.21 8,829.39 04 -11A 3/15/08 APF 11,266. 11,322. 8,844.27 8,890.57 04 -11A 3/20/08 BPS 10,205. 10,206. 7,986.73 7,987.48 04 -11A 4/3/08 BPP 10,205. 10,206. 7,986.73 7,987.48 04 -11A 11/18/10 BPS 9,658. 11,350. 7,581.75 8,913.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL I 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 by 0 To: C. Olsen/T. Norene Date: 5 August 2010 Well Operations Team Leaders From: Olivia Bommarito, DS 04,11,17 Pad Engineer Code: APBD04WL11 -C Jack Lau, Wells Engineer Subject: 04 -11 Ai Acid Treatment IOR: 100 BOPD Est. Cost: $300M 1. F MIT -IA to 1500 psi; LLR if fails 2. SP D &T 3. EP Set IBP 4. CP Mud acid treatment with foam diversion 5. SP Pull IBP Current Status: Operable Seawater Injector - RIR 8000 BWPD Max Deviation: 52° at 5274' MD Minimum ID: 2.990" through 5 -1/2" WFD patch at 9651- 10002' MD Last Downhole Op: 10/24/09 IPROF Last Drift/Tag: 9/17/09 Ran 2.5" drift to 11362' MD Latest 1-1 Value: NA Job Objective: Stimulate perforations in Zones 21, 22, and 23P that are not taking water based on a recent 10/09 IPROF. Well History: 04-11 Ai was drilled in 11/93 to provide injection support to the lower Romeo and a 100k frac was pumped 12/93. The well struggled in the early months to stay on injection due to fill issues. The last of several FCOs stuck the CT string and a 10/94 RWO had to be performed to pull it out. Injectivity continued to be an issue post -RWO and several more FCOs were performed. A tubing leak was identified in 2003, the well was waivered, and remained on injection with yearly waiver compliance testing. The well was swapped to SWI in 2006. The well was SI in 10/07 and the waiver cancelled 12/07. 21/22P perfs were shot in 3/08 and the well was POI in 7/08 following the installation and successful pressure testing of a long patch. A recent 10/09 (PROF indicated the 21/22P adperfs shot in 3/08 are not taking any water injection along with the 23P perfs; a majority of the injection is entering 14P. A choke change is currently planned for 2H10. Page 1 of 8 Options Considered: • SBG treatment: Historical benefits of SBG treatments appear to be very short -lived ( <3 months). A longer -term solution is desired. • Reperforating: Due to the patch ID restriction, gun size would be limited to 2 -1/2" guns with max penetration of 30.6 inches. Given the 3/08 adperfs were shot pre -patch with 3 -3/8" guns with a penetration of 36 inches, significant incremental benefit is not expected. • Setting an IBP to isolate the 14P was considered, however a majority of the online producers in the pattern rely on pressure support in the 14P zone so it needs to stay open. • Fullbore acid treatment: Due to the long patch currently set in the well, it is preferred not to,/ expose the patch elements to acid. A coil acid treatment was selected. • Wax bead diversion was considered, however the cool temperature of the SWI would be a difficult design hurdle. Rock salt diversion was also considered, but is not compatible with HF and is not currently available on the Slope. Foam diversion has been recommended by Schlumberger. Contact Jack Lau at 564 -5102 (work), 227 -2760 (cell) or Olivia Bommarito at 564 -4096 (work), 952- 4799 (cell) with questions or comments. Cc w/ att: Well File Page 2 of 8 04 -11Ai ACID PROGRAM: • Procedure Design: Perf'd treatment footage: 80 ft Diversion type: Foam Acid penetration design: 2 ft Porosity: 30% Casing size: 7 in HCI design volume: 50 gal /ft Total 12% HCI: 96 bbls Mud acid design volume: 36 gal /ft (target 2' penetration) Total 9:1 HCI:HF: 68 bbls Overflush design volume: 129 gal /ft (target 4' penetration) Max injection pressure: 1600 psi Acid mixtures: Mud Acid 12% HCI 25.0 ppt A153 Inhibitor Aid 25.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 1.0 % A261 Inhibitor 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 20.0 ppt L058 Iron Stabilizer 0.3 % W054 Non - Emulsifying Agent 0.3 % W054 Non - Emulsifying Agent 0.3 % W060 Sludge and Emulsion Preventer 0.3 % W060 Sludge and Emulsion Preventer 5.0 ppt L041 Iron Chelating Agent 5.0 ppt L041 Iron Chelating Agent Preflush /Spacer 0.2 % F103 Surfactant, EZEFLO Displacement 250.0 ppt J285 Ammonium chloride 0.2 % F103 Surfactant, EZEFLO 3.0 % U067 Mutual Solvent 250.0 ppt J285 Ammonium chloride Fullbore (pre - acid): 1. MIT -IA to 1500 psi to confirm tubing integrity; estimate LLR if fails. If MIT -IA fails, diagnose and correct tubing integrity issue prior to acid stimulation. Slickline (pre -acid pending passing MIT -IA): 2. MIRU Slickline. D &T 2.50" cent, TEL, & S- Bailer. Correct depths to tubing tally. • Ran 2.50" drift to 11346' SLMD/11362' MD on 09/17/09 E -Line (pre -acid pending passing MIT -IA): 3. MIRU E -Line. RIH with 2.5" IBP. Tie into SWS Perforating Record dated 15- March -2008. 4. Set mid element of 2.50" IBP at 11326' (between perfs at 11266- 11322' MD and perfs at 11330-11350' MD). IBP shou bfte des gned to hold max dp from above. POOH. RDMO. Coil Acid Treatment (pending passing MIT -IA): • Filter all fluids possible to 3 microns onsite immediately prior to pumping downhole. Do not add friction reducer to any stimulation fluids. • Acceptable acid concentrations are +/- 1 % for HCI and +/- 0.25% for HF. 5. MIRU CTU. 6. Maintain sufficient pressure on backside to ensure acid doesn't enter IA during treatment should TxIA communication develop, but do not exceed differential rating of 5 -1/2" DWP patch! It is desirable to have the IA fluid level within 1000 -2000' of surface when acidizing Page 3 of 8 . both to minimize Aential pressure across the packer and0allow for more immediate pressure response in the inner annulus should a tubing leak develop while acidizing. 7. MU BHA with side jet nozzle to allow agitated jetting action across perfs. Min ID is 2.990 ". 8. RIH to 11800' MD. Position nozzle just above the perfs at 11188 - 11210' MD (24P/23P) when the first stage of diversion hits the nozzle in an attempt to block off this higher injectivity zone (24P). Reciprocate the remainder of the following acid pump schedule across the perfs from 11205-11322' MD (23P/22P/21 P). Caution should be used to prevent stacking down weight on IBP. Volume Rate Pump Time Stage Type .. Liquid pack & establish inj 3% NH4CI +F103 280 2 140 Preflush 3% NH4CI +F103+ 3 %U67 20 2 10 Diverter Foam 15 bbls of 30 Quality Foam Spacer 3% NH4CI +F103+ 3 %U67 5 2 2.5 HCI 12% HCI (50 gal /ft) 24 2 12 HCI:HF 9:1 Mud Acid (36 gal /ft) 17 2 8.5 Overflush 3% NH4CI +F103 (129 gal /ft) 61 2 30.5 Diverter Foam 15 bbls of 30 Quality Foam Spacer 3% NH4CI +F103+ 3 %U67 5 2 2.5 . HCI 12% HCI (50 gal /ft) 24 2 12 HCI:HF 9:1 Mud Acid (36 gal /ft) 17 2 8.5 Overflush 3% NH4CI +F103 (129 gal /ft) 61 2 30.5 Diverter Foam 15 bbls of 30 Quality Foam Spacer 3% NH4CI +F103+ 3 %U67 5 2 2.5 HCl 12% HCI (50 gal /ft) 24 2 12 HCI:HF 9:1 Mud Acid (36 gal /ft) 17 2 8.5 Overflush 3% NH4CI +F103 (129 gal /ft) 61 2 30.5 Diverter Foam 15 bbls of 30 Quality Foam Spacer 3% NH4CI +F103+ 3 %U67 5 2 2.5 Stage 5 HCI 12% HCI (50 gal /ft) 24 2 12 HCI:HF 9:1 Mud Acid (36 gal /ft) 17 2 8.5 Overflush 3% NH4CI +F103 (129 gal /ft) 61 2 30.5 DISPLACEMENT Post flush 3% NH4CI +F103 +3 %U67 10 2 5 Displacement 3% NH4CI +F103 200 2 100 TOTALS 938 469 Page 4 of 8 ' II I 9. POOH. Pump 10 bOdiesel at surface to FP well. • 10. Work with DSO to POI at RIR (8 MBWPD) ASAP to continue chasing acid into formation. 11. RDMO. Slickline (pending passing MIT -IA, at least 3 days after acid treatment): 12. MIRU slickline. RIH and pull IBP. RDMO. ' I i Page 5 of 8 e TFEE= GRAY GM2 NFJT ,Y 04 , � 11 ACTUAT49R= AXE �.cwvvrsf��auis,.� . ELeV r KCIP 24 5 9 ° Max Angle = S2 S27 #" 1F2" CAM SSV ND, D = 4$82" 4 SS 134W CSG, M, to -80, ate = 1234r 2741* Min®nu [D =2.635" @ 10191' 5.112" X 3.1/2" NPPi.E REDUCER 9651'-10M 5 - 1122" VWM AM FA404 AS sY, Vii =2.9W (47114X0 1fli25' 9 - 5k9'7KS -�,�" 10191' 5-111" 0T15 xN ate, = 4458 14191" 5-111° x 312^ XN NP T OF r LNR 121199' =2.635° ( ) S-Ilr TBG, 170, L -SD, .02 , 0 =4.89r 142Q3" TTNOT L 9- ' CSG, 47#, N-W, C7 8.681" 1 04.1 IA) 10397- iOWr SET N MMER OW -1 FXR i i m* - -TocKH 1 1 PEFWCft SLAMARY FIFF LOS. SHCA ON 191'17193 ANCLEAT TOPF8W: 34 @ 1 118 NoW Refer 1aPfoirmnD8 for tuacnea peg# data SIZE SFF NTERVAL OpWSg. DATE 3.348" 6 11188-11210 0 111 9 120 FBTD 11 33(W 6 11229 -59248 0 3P9sm 3-Ir 6 11266 -11322 0 3m 5m 2 -1)2 4 113V- 11350 0 i21IVW r LW 290, L40_0371 b9f, O = 6.iF4' 11510' DATE Fel+ BY 00MAENTS GATE REV BY BAY LW 1124M3 0R NAL COOAPLEnom CX3X9 M JCJ PJC SET PM PATCH (F}7 ) VALL 04 -91A IGMAM LAST VOOMOVOt FOOSTNm 0 1931 WO 11116X}6 G PLYLPalFLUGaiC1595 APINa: W W 0"2X78 C FMJC POWORATIOM (03415108) SEC 26, Ti1N, R15E 45592.71 1 Fa & 1646.13' FNL 0416 JC SET LOVkER PATCH (044OWS) ( 4W CJWPJC XNNPFEYUPFa3RFaKR("24,O8) 13P Expiwation (Afaska) Page 6 of 8 s • BP,Exploration by Short Well Name: 04 -11A W Name: DRILLSITE 04 N011A Operator: BPX L RUN_DATE: 29- Mar -2006 Drilled Depth: 11510' TVOSS pud Date. 1993-11- 1100:00:00 X Coordinate: 713214 r _aoo easurement Ref: I® Y Coordinate: 5952150 R ef Elevation: 56.7 Depth Range: - 20' -'20 DT ayout Name: Ijl_wellbook_ofluids Vertical Scale: 1:500 UvURD ICL Fluids ss Mo Perts ILD rhob , TOPE Tnp4 '-fi 4 In I! DEPTH Depth _.I am., M I'll -n- GR HIM NPHI yWRD.S'JyvJRD T< o NOV TEL BCG 91100 - f Q t 26P 23SB 25N — J + � - -9700 24N 10/09 I O 1 22TS 24P 1120D 17' (al ,in 24P) `yr 1 22N 22P 0% 21 TS 21N t i 0% [ 21P 1 ,00 r TZ18 T 14P 83 U � r } -ea00 11400 r G B& 10N 1 I 11700 Page 7 of 8 Daily Injection Plot WELL: 04-11A1PRUDHOE Dates From 06/03/2005 to 0 6/0 31201 0 ------------ ------- - - --- ------------------- ------- ------------------ ----------------------------- ------------------------- ---------------------------------------------------------------------------------------------------------- M , ------------- --------------------------- --------------------------- ------------------ ------ ----------- - ----- -- --- ------ ----- --------- .... ----------------------------------------------- ------- -------- --------------- M - ---- i ------- CO Jw INY a - -- ---- -- ---- - -- - -------- ---- - -- -- - --- --- -------- -- -- -- --- -- --- ------- ---- ------ - ---- -- ---- ---- --- -------- -- --- - - -- -- -- ---- -- ---- ------ --- ------- 1CM -- -------- ------- Sm -- - - - --- - -------- - --- - - ------ -------- ------ ---- ------- ------- -- - -- - - - - ----- - ----- -- - -- - -- ----- - -- -- ----- -- -- 20M 2CM 20M 2= • ------- - -- -- ------ ---- - ------ --------------------- - ------------------ - -- --------- --------- ---------------------- - ------------------- -- --- - 3 ------------------- ---- ----- -------------------- -------------------------------- -------------------------------- ------------------------------------ 2 ------------------ ---- ------ --- ---------------- --------------- ------ L ----- ---------------------------------------------------------- ------------------ ----- - - ----- - ------------------------------------------------------- -------- ---- ------ - ------------------- --------- Miscible Injectant 6ii Sea Water Field Inj Target Op_ Source Water WELL 04 -11A Produced and Lean C-az Reservoir Inj Target WH Inj Pressure Max Disposal Water niabRa vn a vas %ons Gomm Anchorage, AK 99503 2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date BL Color CD MPI -13 AWJI -00055 SCMT r n 1 F/ 10/18/09 1 1 MPC -07 AXBD -00057 MEM PROD PROFILE 1 10/24/09 1 1 04 -11A AWL8 -00040 INJECTION PROFILE 10/24/09 1 1 V -220 AYS4 -00100 INJECTION PROFILE (JT (t_ d �O 10/04/09 1 1 L -220 B1JJ -00035 MEM INJ PROFILE (REVISED) Z. a4 /b' L5 07/30/09 1 1 V -221 AXBD -00037 MEM INJ PROFILE (REVISED) ()0,_. gc�j -b, j3 07/28/09 1 1 L -214A AP30 -00064 INJ PROFILE/RST („)-r'(' (s(o.- Oa-� 9 n 10/06/09 1 1 S -22B AYTU -00052 INJECTION PROFILE I q 06-7 10/27/09 1 1 14 -07 B581 -00016 PROD PROFILE 1 --n i 9 i 5 10/27/09 1 1 07 -05 AYS4 -00105 SCMT -p 9 10/28/09 1 1 R -28 AWL8 -00041 USIT 19 Q-/ 1 1 1 2- 08/K -16 AZCM -00046 PRODUCTION PROFILE /'ff 6 J J1597)51 10/3W09 1 1 PSI -05 B14B -00080 TEMP WARMBACK SURVEY rr q 0 9 /'Ss'9 y 11/03/09 1 1 W I C -12B B2Y -00030 MCNL O ('7 fS.`1 'f5 09/19/09 1 1 U-05A 09AKA0074 OH MWD /LWD EDIT Ly-xo .aM O 7(' t c5 08/19/09 2 1 01 -18A 09AKA0151 OH MWD/LWD EDIT 1 4- (h l s'Thf 08/27/09 4 1 H -09 ANHY -00110 RST11) t /2'b 0 C,/ s lf° f O G, 09/20/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 'AO:, STATE OF ALASKA ~ ALA OIL AND GAS CONSERVATION COM~~ J ~ , REPORT OF SUNDRY WELL OPERA~I~~ ~~~~ 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ ' ~~t ~-~~blrlg patch Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver' Trme ixtension 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 1~ Exploratory 193-1580 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 '~, 50-029-20286-01-00 7. KB Elevation (ft): , 9. Well Name and Number: .\ 56.7 KB ~ 04-11A 8. Property Designation: 10. Field/Pool(s): ~ ADLO-028324 \ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11510 feet Plugs (measured) 11450 true vertical 9045.99 feet Junk (measured) None ,rte th measured 11450 feet ~ J~ ~'~~ ~0.rC..~ ~~1 "" ~®® v~ot Effective De p true vertical 8996 feet ~~~ ~ ~ Casing Length Size MD TVD Burst Collapse Conductor 84 20" 94# H-40 27 - 111 27 - 111 1530 520 Surface 2715 13-3/8" 72# N-80 26 - 2741 26 - 2731 5380 2570 Production 10367 9-5/8" 72# N-80 25 - 10392 25 - 8129 6870 4760 Liner 1311 7" 29# L-80 10199 - 11510 7982 - 8914 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ ~` '. {'` ., ~- ~, ~ ry±~ a;j~t~o~"~6~.~/--~ `~.~ . G.UQ~ True Vertical depth: _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 23 - 10203 0 0 - Packers and SSSV (type and measured depth) 5-1/2" TIW HB-BP Packer;. 10125 0 0 0 0 0 0 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: SHUT-IN Subsequent to operation: 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: 308-040 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ~- Phone 564-4944 Date 7/25/2008 Form 10-404 Reed 04/2006n ~~- ~~~~~ `~~ ~ ~ ~ `~ r~ Submit Original Only ~,y;yt 04-11 A 193-1580 PERF ~TT~(:HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04-11A 12/13/93 PER 11,330. 11,350. 8,897.18 8,913.72 04-11A 7/21/03 MLK 9,699. 9,700. 7,611.47 7,612.2 04-11A 1/11/06 APF 11,188. 11,210. 8,779.79 8,797.98 04-11 A 10/23/07 BPS i 0, i 86. 11,188. 7,972.47 8,779.79 04-11A 10/24/07 BPS 10,186. 11,188. 7,972.47 8,779.79 04-11A 12/7/07 BPP 9,658. 11,188. 7,581.75 8,779.79 04-11A 12/7/07 BPS 9,658. 11,188. 7,581.75 8,779.79 04-11A 3/15/08 APF 11,226. 11,248. 8,811.21 8,829.39 04-11A 3/15/08 APF 11,266. 11,322. 8,844.27 8,890.57 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 • • 04-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/20/2008 ' `*WELL S/I ON ARRIVAL*** (pre patch) DRIFTED W/4.50" CENT. 5 1/2" BRUSH TO XN NIPPLE @ 10203' SLM.. SET 5-1/2" x 3-1/2" NIPPLE REDUCER (2.75" pkg bore) IN XN NIPPLE @ .10203' SLM. SET 3-1/2" XXN PLUG IN 5-1/2" x 3-1/2" NIPPLE REDUCER C 10205' SLM. LRS PUMPED 90 BBLS (39 meth, 51 diesel) & IS CURRENTLY PERFORMING CMIT. ***CONT. JOB ON 03/21/08 WSR'`'"' 3/20/2008?:T/I/0=100/vac/vac Temp=S/I Assist S-Line. CMIT TxIA to 2500 psi (Restore ':tubing integrity with patch) Loaded TBG with 5 meth and 23 diesel. Pumped 28 bbls diesel and 34 bbls meth to pressure TBG and IA to 2500 psi ***Job continued on 3-21-08**'` 3/21/2008''*** Job continued from 3-20-08 WSR*** CMIT TxIA PASSED 2500psi. TBG ';and IA lost 60/10 psi in 1st 15 min and 0/10 psi in he 2nd 15 min for a total ''loss of 60/20 psi in 30 min test. Bled TBG and IA pressures to 500/380 psi ',, (approx 6 bbls) FWHPs = 500/380/0 *** Annulus casing valves left open to gauges*~ 3/21/2008':***CONT. JOB FROM 03/20/08 WSR*"" (pre patch) ''LRS PERFORMED CMIT-T x IA (PASSED). ''RAN 3-1/2" X-EO PRONG TO 3-1/2" XXN TT-PLUG 10205' SLM (SAW 20psi CHANGE). '' RAN 2.25" P-BAILER TO 3-1/2" XXN PLUG ~ 10205' SLM (TSP OF METAL SHAVINGS). ATTEMPTING TO PULL 3-1/2" XXN TT PLUG AT 10,205'SLM (TOTAL OF 3 *'`*CONT. JOB ON 03/22/08 WSR'`** • • 3/22/2008 ""`CONT. JOB FROM 03/21/08 WSR*'* (pre patch) ATTEMPTED TO PULL 3 1/2" XXN PLUG @ 10205' SLM 3 TIMES, RAN 3-1/2" X-EO PRONG TO 10205' SLM, 1 SMALL MARK. NO RING. PRESSURED UP TUBING TO 600#, PRESSURE DROPPED TO 300#. RAN 1.65" HYDROSTATIC BAILER W/MODIFIED BTM, RECOVERED 1 ::THIMBLE OF METAL SHAVINGS. I~A~I O i /~]~~ !'+O O ATTC~Af]TCI'1 T/l 171 II I O i /n ~~ VV~I TT OI 1 IC C~/l~A C x 3-1/2" NIPPLE REDUCER. 3/23/2008: RING ON EO-PRONG lno CURRENTLY ATTEMPTING TO PULL 3-1/2" XXN TT-PLUG @ 10205' SLM 3 hrs 20 mins jarring time). ""'CONT. JOB ON 03/23/08 WSR*"" **'`CONT. JOB FROM 03/22/08 WSR*** (pre patch) MADE 2 ATTEMPTS W/ 3-1/2" GS TO PULL TTP @ 10205' SLM. RAN 10' x 3.00" P-BAILER TO 10205' SLM, RECOVERED TABLE SPOON OF METAL SHAVINGS. RAN 3-1/2" GR W/ 3-1/2" X-EO. PRONG TO 10205' SLM (total 2-1/2 hrs jarring time for ticket). '`'`'`WELL LEFT S/I, TURNED WELL OVER TO DSO*** "**"NOTE: 3-1/2" XXN TT-PLUG STILL IN HOLE @ 10205' SLM***** 3/29/2008''COST PLACE HOLDER FOR PATCH MATERIAL 4/3/2008'``**'`WELL S/I ON ARRIVAL'** (pre patch) `°.PULLED 3 1/2" XN PLUG FROM 10157 SLM ''`'`'`WELL LEFT S/I ON DEPARTURE **" • • '`'`WELL SHUT IN UPON ARRIVAL'`** INITIAL T/I/0= 0/175/0 PSI RIG UP TO SET 5.5" WEATHERFORD LOWER PACKER ASSEMBLY. **'`LOG CONTINUED ON 06-APRIL-08'`'`** 4/6/2008 **'"LOG CONTINUED FROM 05 APRIL 2008*""* 'INITIAL T/I/O = 0/175/0 PSI `RIH W/ WEATERFORD ER PACKER ASSEMBLY. ASSEMBLY O.D = 4.5", ASSEMBLY I.D = 3.0", ASSEMBLY LENGTH = 6' CENTER OF ELEMENT SETTING DEPTH = 10.006' 4.3' FROM CENTER OF ELEMENT UP TO TOP OF PATCH. TOP OF PATCH = 10,001.7' FINAL T/I/O = 0/175/0 PSI. ***JOB COMPLETE, WELL LEFT S/I*** 4/23/2008`.:***WELL S/I ON ARRIVAL***[patch] 'RAN 4.50" CENT & 4.0" LIB TO 5- 1/2"WFD BTM PKR @ 10,000' SLM `, [impression of fn] !'SET 7 [~31'] SEGMENTS OF WFD SPACER PIPE INTO WFD BTM PKR @ ',',10,000' SLM ''CONTINUE PROCESS OF SETTING REMAINING PATCH SEGMENTS (5 ir; TO GO). "`""CONT. JOB ON 4/24/08 WSR*** *'`'`WELL S/I ON ARRIVAL"`**(patch) SET REMAINING 4 [~31'] "SO" TIEBACK SLV's (5-1 /2" G FN, 3-1/2" TBG, SNAP LATCH). RIH W/ HES ETD AND WFD "ER" PKR/SPACER PIPE ASSY (17.11'). SET AT 9669'SLM. TOP OF WFD "ER" PKR AT 9669' SLM, 11 SO TIEBACK SLV's, WFD "ER" PKR ON BTM. PATCH OAL = 354' (OAL INCLUDES BTM "ER" PKR ,MIN ID: 2.990" AT THE SNAP LATCH). ***RDMO, RETURN TO DSO S/IN'`** . __ _. ~._ T/I/0= 100/Vac./0 Temp= S/I Load IA pre-AOGCC MITIA INCOMPLETE (Restore TBG integrity with patch) Pumped total of 88 bbls. down IA, Unable to establish LLR, Final WHP's 150/Vac./0 "Annulus casing valves tagged & left open" 4/26/2008 • • 4/26/2008`T/I/0=110Nac/0. Temp=S1. IA FL for MITIA (PE call-in). IA FL C 1400' (62 `; bbls). 4/28/2008 T/I/0= 110NAC/0+. Temp= SI. IA FL (pre-MITIA). IA FL @ 42' (2 bbls). 5/10/2008 T/I/0= 100/0/0 Temp=S1 MIT-IA FAILED to 2200 psi. (Post batch) Pumped 55 bbls of Inhibited 60/40 at 4.0 bpm down IA to reach 2000 psi. IAP began to decreae pressure when slowing rate. Established LLR of 3 bpm @ 2000 psi for 15 bbls. (Pumped a total of 75 bbls of Inh 60/40). TBG pressured up to 500 psi while pumping down IA. SD and monitored IA. IA decreased from 2000 psi to 500 psi in 1 min. IA went to a vac after 8 mins. Rigged down and left jobsite. FWHP's =150/vac/0 Tags hung, casing valves open to gauges 5/12/2008~T/I/0=100/VAC/0. Temp=S1. IA FL (post MITIA). IA FL near surface. • w 6/24/2008 '`'`WELL SHUT IN ON ARRIVAL**'` INITIAL T/I/O = 100/0/0 LOG LDL FROM SURFACE TO 10350'. SUSPECT LEAK IN THE PATCH 9653-10002'. MADE STOP COUNTS ACROSS THE PATCH. CONTINUE ON 25-JUNE-2008 ***JOB NOT COMPLETE*** _.. 6/24/2008 T/I/0= 100/0/0 Temp= S/I Assist E-Line w/ LDL- (Restore TBG integrity with patch) Pumped 35 bbls. 70* 60/40 MW @ 3 bpm down IA, Pumped 52 bbls. 70* 60/40 MW down IA, Started pumping 55* diesel down IA, -----Job In Progress---- ***WSR Continued to 06-25-08*** 6/25/2008 ***WSR Continued from 06-24-08*'`'` Temp= S/I Assist E-line with LDL Pumped 294 bbls of 55"F diesel down IA while E-line logged well. Final WHP's 50/40/0 "E-line has control of Swab, Wing, SSV, Master, IA open to gauge, OA open to gauge, E-line on well on departure" 6/25/2008"`***JOB CONTINUED FROM 24 JUNE 08'`** ``:LOG LDL FROM SURFACE TO 10350'. SUSPECT LEAK IN THE PATCH '!9653-10002'. MADE STOP COUNTS ACROSS THE PATCH. LOGGED `°ANOMALY PASSES 80 FPM. ESTABLISHED LEAK IN THE TOP SECTION °"OF THE PATCH BY SPINNER RESPONCE. FINAL T/I/O = 75125/25. WELL LEFT-SHUT IN ON DEPARTURE. ""`*JOB COMPLETE*** _. 7/23/2008 **' WELL INJECTING UPON ARRIVAL *** (patch) ',PULLED 5-1/2" WFD ER PACKER & SPACER PIPE @ 9658' SLM PULLED UPPER SO TIEBACK SLEEVE FROM 9671' SLM (MISSING ***JOB CONT. ON 7/24/08*** s • 7/24/2008'.. T/I/0=200/200/0. Temp = SI MIT IA PASSED to 2500 psi (Post patch) Pressure up on IA w/ 6.7 bbls diesel IA lost 100 psi in 1st 15 mins, IA lost 20 psi 2nd 15 mins. Bled IA pressure down to 200 psi. Final WHP's=200/200/0. IA & OA valves tagged & open to guages. Slickline has control of swab, SSV, wing, & master valves. 7/24/2008'' ***JOB CONT. FROM 7/23/08"**(patch) ::SET (29.2') "SO" TIE BACK SLEEVE (TOP @ 9671'SLM) y 'SET (19.15') "ER" PACKER W/SPACER PIPE ASSEMBLY (TOP @ 9651' SLM) Ana rCnrnVw~CV rvu i -ih i v cwvrr lrr~JOw/ *** TURN WELL OVER TO DSO -LEFT WELL SHUT IN *** 7/30/2008`T/I/O= 1300/VAC/5. Temp= 68". IA FL Pre-MIT (AOGCC). Integral on IA. IA ', FL near surface. '';SV-C W-O SSV-O M-O IA,OA-OTG. 7/31/2008 T/I/0= 900/vac/0 Temp.= Hot AOGCC MIT-IA PASSED to 2750 psi. (Witnessed by John Crisp). Pressured up IA to 2750 psi w/ 8.5 bbls meth. 1 st 15 min lost 120 psi, 2nd 15 min lost 30 psi for a total loss of 150 psi over 30 `min test. Bled IAP down. (--7 bbls) FWHP's= 900/40/20 *"**Annulus casing (valves tagged and left open to gauges**'`" Swab shut. Wing, SSV, Master open. FLUIDS PUMPED BBLS 351.7 diesel 149 60/40 MRTH 500.7 Total 1VIEIVI®RAliTDUlr'I To~ Jim Regg P.I. Supervisor ~~ j~j ~ ~~ ~~ FROM: John Crisp Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 04, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-1 I A PRUDHOE BAY UNIT 04-11 A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~`-~ Comm Well Name: PRUDHOE BAY UNIT 04-1 lA Insp Num• mitJCr080803135150 Rel Insp Num: API Well Number: 50-029-20286-0~ 0 Permit Number• 193-158-0 Inspector Name: John Crisp Inspection Date: 7/31/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well oa-11A Type Inj. N' TVD ' 7927 IA o i 2~so ~ 2630 z6oo p•T• 1931580 TypeTest SPT ' Test psi 1981.~s pA o o to to Interval IraTAL P/F P ~ Tubing 900 900 ~ 900 900 ~ ~ NOteS• MIT -IA post patch test. 8.5 bbl's pumped for test. ~~~~ AU G ~ ~ 2008 Monday, August 04, 2008 Page 1 of 1 07/03/08 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,JUL .~ ~DI~~ WPII .Inh !k ~ .... ne NO.4768 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 MPB-50 11999019 RST WFL ~ 06/13/08 1~ 1 M-04 11962601 PRODUCTION PROFILE 06/21/08 1 1 P1-24 12066527 MEM LDL CP"° f 06/18/08 1 1 04-11A 11975778 LDL l°1 - / 06/24/08 1 i M-04 11962601 PRODUCTION PROFILE _ ~0 06/21/08 1 1 12-03 12071857 USIT l -.- d . ~(~ 06/21/08 1 1 GNI-03 12066530 MEM PRESS/TEMP LOG ~.~ G 06/20/08 1 1 E-10B 40016750 OH MWD/LWD EDIT 04/05/08 2 1 18-13B 11972960 MCNL v~..~ (o ~ 12/07/07 1 1 18-13B 12021159 MCNL U"'~..r. ~ 05/18/08 1 1 ~. ~.~r..~....~.... ~~~~ ~~ ~~...~ .... _._. ...._ --.- ---..--..-.- -..- __. -__ .._._.._ .. ____._ ..~~~.. ... .......................-. v....a.v v.. a. vvr . ~n~.n ~ v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Bivd. Anchorage, Alaska 99508 Date Delivered: ~ v> i! ~~'°` / ~ . Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~-^ `_ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM SIGN MAR 1 7 2008 REPORT OF SUNDRY WELL OPERATION~IcaO~&Gas Cons. C~mmiss~~i~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Othe Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension 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 193-1580 " 3. Address: P.O. Box 196612 Stratigraphic Service "~ 6. API Number: Anchorage, AK 99519-6612 50-029-20286-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56.7 KB ~ PBU 04-11A ~ 1 8. Property Designation: 10. Field/Pool(s): ~. ADLO-028324 - Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 11510 feet Plugs (measured) 11450 true vertical 9045.99 - feet Junk (measured) None Effective Depth measured 11450 feet ~(~~~~~~~~ APR ®Q 200$ true vertical 8996 feet Casing Length Size MD TVD Burst Collapse Conductor 84 20" 94# H-40 27 - 111 27 - 111 1530 520 Surface 2715 13-3/8"72# N-80 26 - 2741 26 - 2731 5380 2570 Production 10367 9-5/8" 72# N-80 25 - 10392 25 - 8129 6870 4760 Liner 1311 7" 29# L-80 10199 - 11510 7982 - 8914 8160 7020 rf 1 1 1 22 ~ 11 30 11350 d d 8 Pe oration - epth: Measured epth: 1 188 - 1 210 11226 - 1124 11266 - 13 3 True Vertical depth: 8780 - 8798 8811 - 8829 8844 - 8891 8897 - 8913 Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 23 - 10203 0 0 - Packers and SSSV (type and measured depth) 5-1/2" TIW HB-BP Packer 10125 0 0 0 0 0 0 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: 4696 2160 Subsequent to operation: Shut-in 2270 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development ~ $erVlCe ~` 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 Prepared by Gary Preble 564-4944 Printed Name Gary Pr le Title Data Engineer Manager Signature -- Phone 564-4944 Date 3/17/2008 Form 10-404 Revised 04/2006 ~'3 ~~4? Submit Original Only • • 04-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY - --- ~ ACTIVITYDATE SUMMARY 3/14/2008`""'WELL SHUT-IN ON ARRIVAL*"" INITIAL WHP 0 PSI RU ELINE FOR 3-3/8" HSD PERFORATION *"*JOB CONTINUED 15 MAR 08**'` )8 """CONTINUED FROM 14-MAR-2008*** WELL SHUT-IN ON ARRIVAL. T/I/O 40/0/0. RU ELINE FOR 3-3/8" HSD, 6 SPF, 60 DEGREE PHASING, PERFORATION OF 21 P AND 22P INTERVALS 11,226-11,248 AND 11,266-11,322 FT_ IN FOUR 'RUNS. GUN SPECIFICATIONS: 0.45" ENTRANCE HOLE, 38" PENETRATION. DEVIATION AT PERFS 34 DEGREES. TD TAGGED 11,330 ELM. DEPTH CORRELATED TO ATLAS BHC SONIC DATED 17-NOV-1993. WELL LEFT SHUT-IN. FINAL T/I/O 40/0/0. '**JOB COMPLETE'`*' FLUIDS PUMPED BBLS 1 diesel 1 Total • ~ ~ ~~ ~~ s ALASSA OIL AHD GA5 COHSLRQATIOH COl-II~II551O1~T Robert Chivvis Production Engineer BP Exploration Alaska, Inc PO Box 196612 Anchorage, AK 99519-6612 ~~~ ~E~ ~ ZaQ~ SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU_ Q.4-.1-1-A ~ '-s Sundry Number: 308-040 Dear Mr. Chivvis: 3.1~ ~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court .unless rehearing has been requested. DATED this ~ay of February, 2008 • Encl. Sincerely, - ~ ~ ~ ~~~ /~~~ STATE OF ALASKA ~ SAN ~ ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION I~ APPLICATION FOR SUNDRY APPROV~aska Oit ~ Gss Cons. Commisa~ort 20 AAC 25.280 pflChOt'ia0e 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver ^ Othe Alter casing^ Repair well ~ Plug Perforations^ Stimulate ^ Time Extension ^ patch tubing Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development^ Exploratory ^ 193-1580 ~ 3. Address: P.O. Box 196612 Stratigraphic^ Service ~ 6. API Number: Anchorage, AK 99519-6612 s 50-029-20286-01-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 04-11 A Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028324 , 56.7 KB ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11510 ~ 9045.99 11450 8996 11450' NONE Casing Length Size MD TVD Burst Collapse Conductor 84 20" 94# H-40 27 111 27 111 1530 520 Surface 2715 13-3/8" 72# N-80 26 2741 26 2731 5380 2570 Production 10367 9-5/8" 72# N-80 25 10392 25 8129 6870 4760 Liner 1311 7"29# L-80 10199 11510 7982 8914 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11188 - 11210 8708 - 8798 5-1/2" 17# L-80 23 - 10203 11330 - 11350 8897.18 - 8913.72 - Packers and SSSV Type: 5-1/2" TIW HB-BP Packer Packers and SSSV MD (ft): 10125 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 2/14/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ Q WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conlact Robert Chivvis Printed Name Robert Chivvis Title Production Engineer Signature Phone 564-5412 Date 1/31/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: ~~~ APPROVED BY Approved by: C THE COMMISSION Date: ~~~ Form 10-403 Revised 06/2006 ~,/ yC/ U C~ I v I I V H L Submit in Duplicate by To: Jerry Bixby /Clark Olsen GPB Well Ops Team Leads From: Nick Frazier, Wells PE Subject: 04-11: 5-1/2" WFD L-80 Tubing Patch • Date: AFE: December 14, 2007 Est. Cost: $60,000 IOR: 200 1. S SL to set RN in XN Ni le @ 10,191'. 2. E Set WFD 5-1/2" L-80 Lower Packer Ass Mid-Element @ 10,006' 3. S Set WFD 5-1/2" L-80 Upper 350' Patch Assy, Set Packer w/E-Fire, MIT- IA to 2,500 si to test patch, LLR if Fails Tie-in log: Schlumberger LDL: 21 July 2003, 80 FPM UP Pumping Pass, (Log File Number 36). Current Status as of 12/14!07: Max Deviation: Min. ID: Last TD Tag: Last Downhole Op: Latest H2S level: PWI SI 52° @ 5274' MD 4.455" @ 10,191' - 5-1/2" Otis XN Nipple SL to 11,326' MD on 12/26/2005 EL to 11,350' on 03/29/06 with (PROF 12/07!07: SL Pull WRP, Drift DMY Patch to 10,203' MD Injector, no data available but H2S is on DS SUNDRY REQUIRED: Setting Patch in Iniector W®II, Sundry No: Well History Well 04-11 is an injector with TxIA communication and currently SI. A SLB E-Line LDL was run on 07/21/2003 and located a Tubing Leak @ 9.699'. PDS Caliper logs were run on 10/20/03 and then on 08/28/07 that showed line corrosion and isolated pitting over the same area that the LDL identified the Tubing Leak. Most recently SL set a WRP @ 9658' SLM, performed a passing MIT-T to 2400 psi and drifted w/Dummy 4.45" O.D. Patch to 10203' MD. If the extent of the leak cannot be repaired, the well will require a RWO. • • Program Objective The objective of this program is to patch over an existing leak at 9,699' and also cover a section of tubing below the leak that is highly corroded. This 350' patch will restore tubing integrity and protect against the high probability of another tubing hole forming in the future. AnnComm Summary > 07/21 /03: LDL leak at 9,699' md, LLR=.75 bpm @ 1,950 psi. > 07/23/03: Pulled TTP > 10/20/03: Caliper log shows the 5.5" tubing to have 67 jts with 20-40%, 9 jts with 40- 85% penetrations. > 11/29/03: Set TTP @ 10,191' MD, CMIT-TxIA Passed to 3,000 psi. Pulled TTP > 12/15/03: MITOA Passed to 3000 psi. > 11/02/05: TTP Set CMIT-TxIA Passed to 3,000 psi; MIT-OA Passed to 1,000 psi. > 08/29/06: MITOA PASSED to 2,500 psi. > 11/11/06: CMIT-TxIA Passed to 2,500 psi. > 08/08/07: MIT-OA Passed to 2,500 psi. > 08/28/07: Caliper 5.5": 181 jts <20%; 64 jts 20-40%; 10 jts 40-85% > 10/20/07: IA FL @ Surface. > 08/27/07: MIT-OA Passed to 2,500 psi. > 08/28/07: Brush & Flush, PDS Caliper Tbg from 10,208' SLM to Surface. > 10/20/07: AC-Fluid Level, IAFL @ Surface. > 10/23/07: Brushed XN Nipple @ 10,186' SLM, Set 5-1/2" PXN Plug Body @ 10,186' SLM, Set Prong @ 10,180' SLM. > 10/28/07: CMIT TxIA Passed to 2,500 psi. > 12/01/07: Pull PX Plug & Prong from 10,191' MD > 12/06/07: Drift to XN Nipple @ 10,191' MD > 12/07/07: Set 5-1/2"WRP @ 9,658' SLM, MIT-T Passed to 2400 psi, Pulled WRP from 9658' SLM, Drifted w/Dummy Patch 4.45" O.D. to 10,203' MD If you have any questions or comments regarding this procedure, please call Nick Frazier @ (907) 564-5633 (w) or 229-4596 (c). cc: Well File 5-1/2" WFD Patch Specs The Patch is L-80 carbon steel Patch O.D. = 4.50" Upper and Lower Packer I.D. is 3.00" Minimum Restriction = 2.90" Snap-Latch Patch length . 350' (Element to Element) Slickline Procedure • 1. Drift TTP through Upper and Lower Packers and Snap-Latch at WFD's shop prior to sending to location. 2. Run 5-1/2" x 3-1/2" "X" Reducing Nipple and set at 10,191'. A reducing nipple with a 2.75" ID is preferable due to the 2.90" minimum ID of the patch. E-line Procedure 5. RU EL. Ensure patch has been drifted with TTP. RIH with Lower packer with GRlCCL and log from 10,200' up to 9450' correlating to SLB LDL Dated: 21 July 2003 on the "UP Pumping Pass At 80 FPM Across Leak" Log File #36. (Packer O.D. is 4.50") 6. Set Lower Packer @ 10,006' (Mid-Element) Slickline Procedure 7. RU SL. May need Peak Crane due to height of lubricator. Run Slickstick patch per manufacturer's recommendations. Ensure entire upper patch has been drifted with TTP. RIH with Upper Patch assembly 1 joint at a time. At 100' above each connection, slow down to ~50 FPM until weight loss is observed. With Spang-Jars "TAP" patch bore into the Snap-Latch. Confirm that pipe is "Latched in place" by pulling up 500 Ibs over tool and line weight. Repeat process until final joint with top packer is run. Top of patch will be set w/E-Fire at ~ 9,658'. It is alright to set the upper packer higher than 9658' if the lengths of the 3-1/2" STL pipe make it necessary.~11-12 joints of 3-1/2" STL Carbon Steel Tubing will be needed. 8. MIT-IA to 2500 psi to test patch. Establish LLR if Fails. 9. RDMO, Notify DSO upon Departure. C 1'~ ~ t~IX t;B1Z a~ ~ ~€an: COY AG71A7"~1t8_ ~ A![7Ff 6. F3.E5t ... ~K ... ~.-- 56;& IMF ~-~ . h~~ 459 91e: Ante . ~ 52 ~ 527d ~ ~m9o 71923 t~m,rnivo ~ 8aaa• ss I t 9.3s' 7:Sii T2/. N~BQ D w 123lT ! ~t~ ~ ~ ~t.455" 1 Q 191' 5112" O'fRS 7CN NIP ~7N64K~QM61 PqZ 102 tA7lQNRY ~CiXa dN 11AtT~t ANG6.E ATTOP PE1iF' 9! ~ f i 189' Nor: R~far b Ra~6an ~ far l7isnrital atrH de6n awa' a z~im.iitw u ir~v~uo 2-1R,'" S ti3.i0-It35E1 t7 12/t9189 • 5a1fETYN15T~lA: ""RAP9gTx1A{%~MI. C,IP€RATMN3i.MfTt1.11+tXIAP*~b00P8t IIIA7C ~ 1000P91 {iill#!D5 WAIVIs~"" {~.~-~T CAM BALA;35137/ NP, ~_ ` I 0 TTNOT[ alit: Ir~l/ 8Y G~{B1TS al7E 1N9/ BY fl01~1EM3 111293 itf8G~1IMiC0~9P1_E710N 1479119/ tJ-S7 YYi016~Vl9< ItAJ1l09 J.JII# PDQIiLUC,Sf3 11X106 JARILN )OtN77P~T tt/t9A"18 GIWPAG PIJLLP19~kRil[s 101St` t 11'19!Q5 ESJHIC NMW~2SA~ETY N077 t2R8~06 7"IPPIB.tffi 4ktV0B t~lkROG Fi~FS ~~~~ 9ilL41lf'N~+f]OAN tA913?'- tO~FI+F PfiDK)EBAY LM WB.L: 0!•ttA P1~ No: RI93t 5911 ARNa_ 410=tP29-2U~8.4f 28,17 ~ Rt9E,1692d_Ti' !$ & i8t8.1S FN. HA Spier din n {rliarkr) • • 2~F t ~ ~ s< €~ TUBITJS~SUMABA~i!' `> ~~ ~~~~ ~~` '.:~ xf ~ ~{ ~~ ;K2o"a X40 } m23IQN ~~~.$~~~y... 4 ~~fp~ '#t.181uY~ : ~ S ~ .. ~ 8b ~ ~' F~~'~~; 3r2~ ,~ -., - ~Xt . xc r k <~ ~s ~, ~< ;. y ry~ R t ~ ~,• ;,~,~ ~293•~lTS ~}P! RA>riC~~ .:z ~ $~ .1~~~ .~ 2 2~a3T~ ~ f 4}~T~~F > ~. p~ ~, 18T8q R5 ~ Off {~1~~,K £ y ~~' x s ~C##Atd,.~ J~. ,~ z N ~`~ ~;~~ ~. . yZh2 .~.~.4.. ~ ~. ~ fJ 'yj8~.jsp\Jl Y~, A ~hx ` W_ ~Y/ W Yy ~~ ~..~ Y j: tTE-~D~~st fc1~, IrtE~ude4f~: S13E.1''lPE CONMECTlON J1'~tlt-4 :,';~ < ;:.: `<. < s;.• ITEM ID 4D LENGTFI TC}R 8OTTUM WIREL~EENTRYGLADE 4,815 6.5 1.2fi 14202.14 10203.10 PCJP,ICNFli' 4. D1 3.05 9.57 1tltA2.51 14242.44 6.6" aTIS XM N1~PLE W1RHC PLU[i 4.455 8.10 1.40 101 Ai.i7 10742.57 t'UPJOINT 4-91 8.45 9.82 10181.55 1tl181,17 5.5' N9CC CUBING JT tY253 1 4.91 6.45 41.46 tb140.09 ttl181,55 PLIPJOINT 4.91 8.453 8.35 tb134.74 t014tl,p9 9.5'8" X 5-112" TIiN NBeP PAGKER 4.T5 B.2{9 8.17 10124.57 14iS0.74 PUS JC~IM 4.91 6, 45 9.62 i b1 t 4.95 t 0124.57 fi.5"LTC B4X X 5.5" NSCC P1N X-0 4.91 6,05 40,48 ip0T4.47 1A114.96 5.5' LTC TUEING dT k1.192 A.97 9.05 7846.17 2229.3D 14474,47 5.5' ?UP fL90 LTC 4.9t 9.03 10,22 2218.08 2228-30 5.5` FLUN1 COUPLING 4.767 6.05 5.95 2212.13 22 t 9.08 5.5"BALO NIPRLE WAJUNYY 4.562 9.981 fi.48 2245.66 2212..13 5.5'ROWGOUPLINO 4,77 6.05 8-19 2159,46 2205.65 5.5' PUP L8D LTC 4,91 6.05 10.25 2189.21 2159.46 5.S' I,TC TU94NG JT X193-226 4.91 &.45 1387.75 941.4$ 2199.21 5.5"LTC PIN X 5.5"NSCG NOX XO 4.91 fi,05 41.23 T6p.33 891.46 5.5' ItiSf:C TU~31NG J7 kc"27-2d2 4.91 6.45 &66.14 1oD.tl9 760.23 .°~~CtlT 4.91 b 45 25.43 7d.e6 144.49 5.5' IvSCC TURIKG JT 4243 4.91 E, tl5 41.44 33.22 T4, fi6 5.S GRAY QEN II HANGER 5.87 27.35 99,2$ N2B-E RKB 37.35 27,35 • • Memony Mum-Finger iCa6per Results mm~lr Comparry: BP ExpMr~tiwr ~P-laslra} Inc. Welt DS 94-11 a Log Da4e: August 28, 201)7 Field: Ptudhoe Bay ~9 t~lta_ : 6679 ate: Al~ka Itra~ Noy ? API No,: 5C1.029-2!7288-01 Pfpe7 Desc_: 5.5' 77 ~. 480 Top Log Iniv19.: Surface 7 lJse: T<fring Sot. Log kdrti.: 10,'91 F-t_ It1117} rf~spectc~ type : Cofrtasitre a jl~et:ttanical l3arr~age lrtSj3~eCitit?R CU>IMIIENTS This oa/grer data is tied into the 11fr tvippte ~ itt isi (la-iAters t?~pOr). This iog vYas run 'tc assess the cxuudition of ~ tiutsing wiih n~pect ~ in~mal oorr~ive end rrreoheniral ~mage_ The caliper recondirsps irrdicvafe That the 5.5' tul>irg togged is in good to poor eorrcliti[rn, w61t a mandrrwm recxarded penetration ofi 8996 ~ 9.993_ W~ penetrations ranging from 21196 to ~39i waR 1hio~ ere receded n 74 of itue 255 joints fogged. The damage recorded appears in tttie tarn of Isolated PiiBng, and Line Corrosion. There are rxn area of significant Cross 5ec6anal WaU lass yr LD_ rest,icticn recorded ttnrrrrrgtwut the trbing. This is the second PDS caliper of #ris we®. A ocmparisan between this tog end the previous log (Qchober 20, 2003) indicates a sligtrt increase ~ eerrosive damage. A graph filrrstrBting the dilferenoe in maxin-an recorded perretrafions in each joint is included in this report Crvss3ectional drawings of the nrost significarnt events recorded are indtuted in this repcxt. The distrit~icn of maximum recorded penetreticr~ is i6ustrah'ei in the B«ty Region Analysis Page of this report. A graph ibustrattt-g the correlafion of necc>rded damage ~ borehole prvfie is inc~ded in ilris report. MAXIMUM RECORDE© WALL PENETRATIONS Lice Corrosion (8996) Jt 243 ~ 9,993 Ft (frtD} Isolated F'"it4"ng (5291) Jk 138 ~1 5,888 Ft (MD} Line Corrosion (5194) Jt 781 7,419 Ft (141D} l.iuee Corrosions (5194) Jk 237 ~ 9,738 Ft (MD} Lice Corrosion (489!.} Jk 293 8,730 Ft (MD} MAXIMUM RECURRED CROSS-SECTIONAL ME3AL LC}SS ; No areas of si~ificent rxass-sectional vrall loss (>796} are recorded. MAXIMUM RECURRED ~ RESTRICTIONS No sir~ificant LD. reskidiars are recorded. Field Engineer. IY i+Cesseru AnaFyst J. Thorrrp~eon Wiliness: D. Yar6Ae Ptc.4~ti,~?!)iagnosric5ei~'xes, inc, ,' P.?~. Box ~'. . ~'~ffc ~, TX. "49' Rharxe,~2Bijar~888g9b3-f#}SS .~,:(2°t'ti5%~5-13~r9~ E-m~": F~~•~?~i~emvr;l~g,co~tt F r-_~_'.:w. Barf i=iek3 4t~ice Rhcne~ ; `+Fi7} 659-23Ui Fix.; ~9~J?; 6;9-~31= • - °~ 1 +_~~ '_; ~~, ~„~~ . , ;,, '~ ~ ~ ~ ,~° ~, '. <~, ~. SARAH PALIN, GOVERNOR ~+g~ ~ ~T ~r ~ ~-7~L'1 ®~ ~ ~ +~ 333 W. 7th AVENUE: SUITE 100 C~1~TSFiIaQ1~-hIDI~T tt®~II~+`'+IOl` ~ , ANCHORAGE, ALASKA 99501-3539 -7iJii• li " li -7-7 PHONE (907) 279-1433 FAX (907) 276-7542 CANCELLATION SUNDRY APPROVAL N0.303-252 Ms. Anna T. Dube ~j~;,~ F~~ ('~ `~ ~~~~ Attention: Well Integrity Coordinator, PRB-20 BP Exploration (Alaska) Inc. P.O. Box 196612 ~ ~' Anchorage, AK 99519-6612 RE: Cancellation of Sundry Approva1303-252 (Well PBU 04-11A) Dear Ms. Dube: Pursuant to BP Exploration (Alaska), Inc. ("BPXA")'s request dated January 18, 2008 Alaska Oil and Gas Conservation Commission ("Commission") hereby cancels Sundry Approval 303-252, which allows continued water injection. This well exhibited tubing by inner annulus communication, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to conditions set out in the sundry approval. Since then, BPXA has shut in and does not plan to operate PBU 04-11A until repairs have been completed. Consequently, Sundry Approval 303-252 no longer applies to operation of this well. Instead, injection in well PBU 04-11A will be governed by provisions of the underlying Area Injection Order No. 4E. The copy of Form 10-404, Report of Sundry Operations, provided with BPXA's request noting the cancellation of Sundry 303-252 has been placed in the Commission's files. DONE at Anchorage, Alaska and dated February 1, 2008. ail and Gas Conservation comm~ss~on v~ i Cathy P. F erster Commis over r • • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 18, 2008 Mr. John Norman, Chairman Alaska Oil & Gas Conservation Commission 333 W . 7th Ave. Anchorage, Alaska 99501 Subject: Prudhoe Bay Unit well 04-11 A (PTD #1931580) Application for Cancellation of Sundry #303-252 Dear Mr. Norman: by This request is to cancel Sundry #303-252 for Prudhoe Bay Unit well 04-11 A (PTD #1931580). The Sundry, originally issued September 04, 2003, was for continued water injection with tubing by inner annulus communication. The well no longer adheres to BP's Well Integrity System Policy and wi11 remain shut-in until the weN has been repaired. An AOGCC witnessed MITIA for UIC compliance will be conducted once integrity has been restored and the well is on injection. The application for Sundry cancellation form 10-404 is attached. 1f you require any additional information, please contact Andrea Hughes or myself at (907) 659-5102. Sincere , l J ` ~ ' ~(/ Anna T. Dube, P.E. Well Integrity Coordinator {~ 2 ~`~ r ~~~"rnl~~ln~~ 18s~~~,, ~ pnc~4ca~~ ~~ 1g3'~5~~ Attachments: U Application for Sundry Cancellation form 10-404 STATE OF ALASKA ALAS A OIL AND GAS CONSERVATION - -,D~ COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ Cancel 10-403 Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ 303-252 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 193-1580 3. Address: P.O. Box 196612 Stratigraphic Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-20286-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56.7 KB PBU 04-11A - 8. Property Designation:. L 10. FieldlPool(s): ~~~ P dh Fi ld/ P B O-028324 AD ru e ru oe ay 11. Present Well Condition Summary: JAN 2 C ~ooU el Total Depth measured 11510 feet Plugs (measured) 11 0 E&$1~ & G8S 00115. C®rrUr!)SSI true vertical 9045.99 - feet Junk (measured) None Anchorage Effective Depth measured 11450 feet true vertical 8996 feet Casing Length Size MD TVD Burst Collapse Conductor 84 20" 94# H-40 27 - 111 27 - 111 1530 520 Surface 2715 13-3/8" 72# N-80 26 - 2741 26 - 2731 5380 2570 Production 10367 9-5/8" 72# N-80 25 - 10392 25 - 8129 6870 4760 Liner 1311 7" 29# L-80 10199 - 11510 7982 - 8914 8160 7020 Perforation depth: Measured depth: 11188 - 11210 11330 - 11350 _ _ - True Vertical depth: 8780 - 8798 8897 - 8913 _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 23 - 10203 0 0 - Packers and SSSV (type and measured depth) 5-1/2" TIW HB-BP Packer 10125 0 0 0 0 0 0 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: 4696 2160 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development ,~"' Service ~'' Daily Report of Well Operations /3f' 16. Well Status after proposed work: n)ct f ~t,~Q4( ~ 3~3~ Oil Gas ~`.' WAG ~ GINJ WINJ WDSPL ~~ 17. I hereby certify that the foregoing is true d correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 303-252 Contact Anna Dube Prepared by Gary Preble 564-4944 Printed Name Anna Q be Title Well Integrity Coordinator .~ Sign r ~'~~;~ ~ Phone 907-659-5102 Date 1/7/2008 t : ~: .t Form 10-404 Revised 04/2006 ~~ tl3r'~~ idt/a~ Submit Original Only 04-1 lA (PTD #1931580) Interna aver Cancellation Page 1 of 1 Re James B DOA • 99, ~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj i'7 f (~-I -~~,-~ Sent: Monday, December 10, 2007 3:41 PM ~ ~~~~t To: Maunder, Thomas E (DOA); Regg, James B (DOA}; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS2 DS Ops Lead; GPB, FS2/COTU OTL; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Chivvis, Robert Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Dube, Anna T Subject: 04-11A (PTD #1931580) Internal Waiver Cancellation All, An internal waiver was issued for TxIA communication on well 04-11A (PTD #1931580) on 11/12/05. The well is currently shut-in and there are no plans to return the well to injection before 12/31/07. Therefore, both the waiver and Sundry are being cancelled. The well has been reclassified as Not Operable. Please remove all waivered well signs and the laminated copies of the waiver and Sundry from the wellhouse. The corresponding Sundry cancellation will be sent to the AOGCC. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~~~ JAN ~ ~ 200 12/18/2007 • MEMORANDUM To: Jim Regg ~ ' jl P.[. Supervisor ~~~~ Z ~Q 7 FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATF,: Wednesday, October 31, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04- t I A PRCiDF{OEi BAY UNIT 04-11A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J-~'v Comm Well Name• PRUDHOE BAY UNIT 04-1 to API Well Number: 50-029-202RGA1-00 Inspector Name: Bob Noble Insp Num• mitRCN071030162712 Permit Number: 193-158-0 Inspection Date: 1028/2007 Rel Insp Num: ~ L : .. _ . ,..._ _.. Wednesday, October 3l, 2007 Page 1 of I MEMORANDUM . . State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor "l . ~~ ¿Ò(3D/CO DATE: Monday, August 27, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 04-11 A PRUDHOE BAY UNIT 04-11 A FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv${2. Comm NON-CONFIDENTIAL Well Name: PRUDHOE SAY UNIT 04-IIA API Well Number: 50-029-20286-01-00 Inspector Name: John Crisp Insp Num: mitlCr070826 165343 Permit Number: 193-158-0 Inspection Date: 8/25/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04-11 A Type Inj. w TVD 7927 IA 1180 P.T. 1931580 TypeTest SPT Test psi 1981.75 OA 10 Interval REQVAR P/F .7 N¡- Tubing 930 Notes: MIT OA for variance. OA was pressured to 1700 psi & the stem packing on the annulus valve started leaking. The pressure was bled down & Grease truck & Valve shop Supervisor was called out. When the decision to replace valve was made I left location. Josh Morales later called & said the stem could be packed & PT could continue. I did not return to DS 4 for this test. S ~ll\C":3- 3ù3 - 2Ç 1.- j""8L<. õ¿.5 C.t-t::¡:;;¡- T J<.:X.A ev~ 'Z~£S : \(S+ C,L,lVr T)<.~ tLPlr1 ~ ,/ SCANNEi:> SEP 1 02007 Monday, August 27, 2007 Page I of I 04-11A (PTD #1931580),13-22 (P.#1820770), 13-32A (PTD #2012350).T Forms Regg, James B (DOA) Page 1 of 1 From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Sunday, August 26,20074:17 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADWWelllntegrity Engineer; NSU, ADWWI Tech SUbjec':;'~11A (PTD #1"931580),b3-22 (PTD #1820770), 13-32A (PTD #2012350) MIT Forms Attachments: MIT PBU 04-11 08-25-07.xls; MIT PBU 13-22 13-32 08-25-07.xls Jim, Tom and Bob, Please see the attached MIT forms for the following wells: 04-11A: MITOA for variance compliance 13-22: MITOA for variance compliance 13-32A: MITOA for variance compliance - failed, plan to retest when well is back on-line. Please call with any questions or concerns. «MIT PBU 04-11 08-25-07.xls» «MIT PBU 13-22 13-32 08-25-07.xls» Thank you, Andrea Hughes Well Integrity Coordinator 'Office: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED SEP 0 7 2007 8/28/2007 'Í( 1211 0/t <at 01 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@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 / DS 04 08/25/07 Andrea Hughes ~ltß(O 1 ~11 Packer Depth Pretest Initial 15Min. 30 Min. Weill 04-11A I Type Inj. I W TVD I 7927 Tubing 930 9401 940 940 Interval I V P.T.D.I 1931580 ! Type test I P Test psi I 2500 Casing 1180 12001 1200 1200 P/FI P Notes: AOGCC State witnessed (declined) MIT -OA for varianc OA 10 25001 2340 2310 compliance. Weill I Type Inj. I I TVD I Tubing I ntervall P.T.D.I I Type test ! I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD ! Tubingl ! I Interval I P.T.D.I I Type test I I Test psi! Casing I I I P/FI Notes: OAI I I Weill I Type Inj.1 ! TVD I Tubing I Interval! p.T.D.1 I Type test I ! Test psil Casing I P/FI Notes: OA I I Weill I Type Inj.! I TVD I Tubing Interval! P.T.D.I I Type test I I Test psil Casing P/F! 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 D = 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) MIT PBU 04-11 08-25-07.xls DS 4-11, 11-12 Annulus Pressure Monitori.formation for... l't~-tcs~ . Subject: DS 4-11, 11-12 Annulus Pressure Monitoring information for AOGCC From: "Engel, Harry R" <Harry.Engel@bp.com> Date: Wed, 22 Nov 2006 16: 11 :32 -0900 To: winton_aubert min.state.ak.us CC:"GP Winton- This is a follow-up to our November 13th telephone conversation regarding the subject wells. Prudhoe Bay Unit well 04-11 is a water injector operated under Sundry Approval 303-252 due to confirmed Tubing X Inner Annulus communication. The approval requires pressure testing every two years and monthly reporting of daily injection rates and pressures. The well was shut in on 08/27/06, passed an MIT-OA on 08/29/06 and remained shut-in until 10/20/06 when it was put on Produced Water Injection. Daily injection rates and pressures were monitored however, on 10/28/06, the outer annulus (OA) valve was found closed, rendering the OA pressure gauge incapable of monitoring the true OA pressure. Upon opening the valve, the pressure gauge read 2200 psi. The OA pressure was bled on 10/28/06 and has remained stable since. The outer annulus valve was inadvertently closed from approximately 8/29/06 to 10/28/06. Prudhoe Bay Unit well 11-12 is a long term shut-in producing well with Tubing X Inner annulus communication and a wellhead and surface casing leak when the OA pressure builds. As a result, the OA pressure is maintained near zero. The well was secured with a tubing tail plug in January 1994 and has been shut in since. In January 2006, the tubing tail was cut off to allow logging in the well. The well was again secured with a WRP set in the remaining tubing tail on 01/19/06 after running the log. Operator recorded OA pressure readings changed from 10 psig to 40 psig on 10/11/06. On 10/28/06 a needle valve immediately upstream of the OA valve was found closed, rendering the OA pressure gauge incapable of monitoring the true OA pressure. Upon opening the valve, the pressure gauge read 40 psi. The OA pressure was bled on 10/28/06 and has remained stable since. The needle valve was inadvertently closed from approximately 10/11/06 to 10/28/06. BPXA takes these incidents very seriously, consequently they have been reviewed by our Operations staff to establish corrective actions to prevent future incidents of this nature. Corrective actions include; 1. Expectations have been reinforced with the wells support group regarding the requirement to properly tag and flag all valves where positions have been changed. 2. Discussions with Operators have communicated and reinforced clear expectations related to permit close out and sign off to validate work completed and condition of equipment. Additionally, we have emphasized the need for thorough daily operator checks which include proper valve position and accurate pressure readings. 3. Needle valve handles will be replaced with quarter turn valves to make their position easily identifiable. I am available if you require further information. 1 of 2 11/28/20063:44 PM RECEIVED Scblumbepger AUG 2 3 2006 NO. 3929 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth AIæka Oil & Gas Cons. CommiSSion Anchorõge r'l \ f- ,) (, SC,-\NNED ¡'cUt! (~ i' Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 WII CJXQ, J03~ l5-~?) L D C Field: Prudhoe Bay J b# C BL e 0 og escrlptlon Date olor D 07 -34A N/A SENSA/MEMORY LDL 03/22/06 1 C-08B 11209599 MEM PROD & INJECT PROFILE 04/22/06 1 D.S.04-11A 11211384 INJECTION PROFILE 03/29/06 1 D-10 11258702 LDL 04/17/06 1 09-24 11217261 PROD PROFILE W/DEFT & GHOST 06/12/06 1 14-13 N/A INJECTION PROFILE 08/03/06 1 V-01 40010636 OH EDIT OF MWD/LWD 07/05/04 2 1 Petrotechnical Data Center LR2-1 900 E, Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 08/16/06 . . & STATE OF ALASKA . AL OILAND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIO o o o 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 56.7 KB 8. Property Designation: ADL-028324 11. Present Well Condition Summary: Total Depth measured 11510 true vertical 9045.99 Effective Depth measured 11468 true vertical 9011.27 Casing Conductor Surface Production Liner Length 84 2715 10367 1311 Size 20" 94# H-40 13-3/8" 72# N-80 9-5/8" 47# N-80 7" 29# L-80 Perforation depth: Measured depth: 11188 - 11210 True Vertical depth: 8779.79 - 8797.98 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 Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic [J feet feet feet feet MD 27 - 111 26 - 2741 25 - 10392 10199 - 11510 11330 - 11350 8897.18 - 8913.72 5-1/2" 17# 5-1/2" TIW HB-BP Packer RECEIVED FEB I 6 2006 Stimulate 0 0 Ixr WaiverD Time ExtensfðR liiyt: Re-enter Suspended Well 0 5. Permit to Drill Number: 193-1580 M 6. API Number: 50-029-20286-01-00 Exploratory Service 9. Well Name and Number: 04-11A 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Oil Pool Plugs (measured) Junk (measured) None None TVD Burst Collapse 27 - 111 1530 520 26 - 2731.09 5380 2670 25 - 8129.14 6870 4760 7982.22 - 9045.99 8160 7020 L-80 23 - 10203 10125 ~ANNEl F Er¡ RBDMS 8Ft FEBl c¡ 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 18150 7690 Printed Name Sharmaine Vestal / Signatu~~&/71&~ ~2~.;4Lf 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil [J Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Revised 04/2004 Tubing pressure 1848 743 Service M WINJ (;" WDSPL Title Data Mgmt Engr Date 2/16/2006 Submit Original Only e e 04-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/11/2006 PERFORATED 11188'-11210' WITH 3 3/8" 3406 POWEJET HMX, 6 SPF. CORRECTED TO SEGMENTED BOND LOG 20-NOV-93. USED CCL TO CORRELATE TO TUBING TAIL AND SHORT JOINT. ALL SHOTS FIRED. ***DSO NOTIFIED WELL INJECTING ON DEPARTURE*** FLUIDS PUMPED BBLS 1 5 6 I ~i:~~ TOTAL MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission a I DATE: Wednesday, November 16,2005 TO: Jim Regg '\', II{/loa;; ,. -- - --. P.LS"",m", .. '£tì---- ..sUB.!"", :~?~~~'~'::i;;¡iÑc- / \ iftJ FROM: John Crisp PRUDHOE BAY UNIT04-]]A ~(1 ~ Petroleum Inspector ~ \J Src: Inspector _._~-_.- NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: PRUDHOE BAY UNIT 04-IIA API Well Number 50-029-20286-01-00 Inspector Name: John Crisp Insp Num: mitJCr051111091223 Permit Number: 193-158-0 Inspection Date: 11110/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 04-11A IType Inj. i N I TVD I 7926 I IA I 0 2990 I 2960 I 2935 ! I I P.T. I ]93]580 ITypeTest I SPT I Test psi I ]981.5 lOA I 0 I 240 ! 250 ¡ 250 I I Interval REQVAR P/F P Tubing I 0 i 2980 i 2960 i 2940 I Notes CMIT - TxIA for new waiver. 13.5 bbl's pumped for test. ~· \iÀ..H,\i¡¡':;;t ' ,¥~'¡¡U~G~lþL. c ~~ 1 Wednesday, November 16,2005 Page I of I Pt1)Ji i C( 3-- J 5Cò Notice of Waiv"red Well , ,< ' .. L...",d!!t""T:: ' welL: 04-11 A WELL TYPE: ,W~11i1r I(tj~ç~~ DATEt 12..164)3 lojactlot\Data: iOl2QJt;)3: 5.075 aWPÐ@ 941 p$i, PteàiSOt~: lrw¡eMi(1~l 81 Tubil'lg 1140' 0 psi psi 9-{i¡.'8'tANN 1~~-o I)$i Õ Q$í 13~3,l8ØA.Nt.j 340 p~ì 0 ~'$ij AEASONFORNOtlGE: e.pldT:XIA ç~m:~(nl~"ion &" _""""",;1 """"""!"~'""",..",, TUBING BY 9.5/3" COMMUNICATfON? YES xx . NO - ,fr:~ , ..,., ",,<Jj , -. .,,--_.~,-,,_._- -""'...-"".--..- --- - ----,-, leaK Defé-Ù1 109 fourdbak a~ 969g'MO ,. 07/2~,iO3. lLH-IA~, .68 bprr. fly '1000 p::>i d¡He-runt¡al ,- U6,'~:4Æ3, :;:;¡¡;¡';¡¡¡¡¡¡;~"'""""""--""'._._-".'--"----'._.':""'-"-Ri;;;¡¡;;--¡;¡'¡¡¡¡¡¡".tt~ ~ ~,---,~._--_._.. .. 9..518'* BY'.13--3la';-COM11ùNlCATiõÑ'? "'" " - YES -, .-,--. NO .-.-. --- -.:=---=--=.::::::::::="==.::::::.-:::=.:::::-"."'" or.::;æ'. ""'" """"""'.. xx '--'--'---'- Q (::MIT'"T;.: \r~, Pas.~lød :,0 :itJ1;J() psi - 11/2,9f{l3" .. MIlO;; P¡:J;~::Hx1 b:Y'JOO OS1 - 12/E\"{):l .. 'T iO pbt d:>t:;s n:)'t ir:d¡ca::f:! JA 'X ()l.. 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Dati) ,t ~)!$?rit\ !.;f'i'íJr.': " '. '" """""" """,""""'" "".., "'." .. ':""',"""':'.':. .:: "'":::.":.:':.,,,,:,,""'.:::::,,:,,:,,:.:~,,:::' :":,, :::.:..,:":"".""::":~,.:." ~":,"-_:"'::::,~","'-'...,.":::':'::';':="',",U',i.",",",,'" """"""""".~"":""",~-",~""""""""""""""."".""."."",,'.""_a..-'_..,...."","""",,""""""""""""""""""""""~"""""""""""'"""'"""..."~",."",.",.""",,, !".", '" ."':', X"'1",..r .' ;:' .. .. ",.': :::--."t: .""':' .' , Il"ti'.::'" ',<:';\[\\;<', [it"<!'ìAfj ~t;~\!J~~~~Ü.] Jè-â\i .1 t,i ¿UU/,"~ 08/05/03 Schlumberger Alaska Data & consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2933 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott Color Well Job # Log Description Date Blueline Prints CD D.S. 9-04A I ~ .~-(~;~-) ~ PROD PROFILE/DEFT 07/31/03 NK-38 / ~z~,/7~' STATIC PRESSURE SURVEY 08/01/03 E-10A }~ - ~ LDL 07~07~03 C-16 I ~"~ t ~ G~VEL PACK W/RST-C 04/30103 D.S. 11-16 [ ~ (C" C~ PROD PROFILE/DEFT/GHOST 06/05/03 R-34 ~ ~ ~" ~ ~ INJECTION PROFILE 05/17/03 1 D.S. 7-21 ~ ~ ~ -~ LDL 07/30103 D-14A ~' ~-'( ~ '- ~ ~. ~ LDL 07~28~03 1 A-06 ~ ~ ~ -~'~ ~ PROD PROFILE/DEFT 06/27103 1 D.S. 4-1 lA ~ ~ ~- ~, ~ ~ LDL 07/21/03 1 3-25/M-27 ~ ~',.', t~ SCMT (REPRINT-DEPTH SHIFTED) 01/04103 1 ~S-28B ~-%,.-~~ 23414 CHMEMGR(PDC) 03/09/03 1 *(PRINTS SENT OUT 5/08/03) PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ., Schlumberger GeoQuest .... , .... 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 · , ATTN: Beth · Received by: BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp June 26, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 04-11A (PTD 1931580) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well 04-1 lA. This re/quest is for approval to continue water injection in a well exhibiting rapid Tubing x IA communication. A description summary of proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Sinc~~.l~ j~n~~,ubbon Well Integrity Engineer Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Wellbore Schematic STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request Abandon D Suspend D Operation ShutdownD Perforat6D Vadanc6[ AnnuarDisposal[--] Alter CasinQ [] Repair Well [] Pluc~ Perforations [--] Stimulat6[] Time Extensiorr-I Other[--] ChanQe Approved Pro(]ram [] Pull Tubin(~ [] Perforate New Pool ~ Re-enter Suspended Wel[] VARIANCE 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development[--] ExploratoB[--] 193-158 ''~ 3. Address: P.O. BOX 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic[-'l Service[] 50-029-20286-01-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 56.70 04-1 lA /' 8. Property Designation: 10. Field/Pool(s): ADL 028324 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):l 1510' IT°tel Depth TVD (ft': I Effective Depth MD (ft): I Effective Depth TVD (ft): I Plugs (measured): I Junk (measured):9046' 11450 (06/05/1999) 8996' None 11450' Casing Length Size MD TV• Burst Collapse top bottom top bottom Conductor '84' 20" 118' 118' 40K 520 Surface 2707' 13-3/8" 2741' 2732' 80K 2670 Intermediate 10358' 9-5/8" 10392' 8128' 80K 4760 Sidetrack Liner 299' 7" 10211' - 11510' 11129' - 9046' 80K 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: I Tubing Grade: Tubing MD (ft): 11330'-11350' 8897'-8914' 5-1/2", 17#I L-80 10203' Packers and SSSV Type: I Packers and SSSV MD (ft): 9-5/8" x 5-1/2" TIW HBBP Packer, 5-1/2" Camco BAL-O SVLN I Packer @ 10125', SVLN @ 2206' 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work Detailed Operations Progran ~,~,~.~BOP Sketch FI Explorator~F[ Developmenr-[ Service[] 14. Estimated Date for'~.~ ' ~; ~, ,,1~;~,5003 15. Wel/ilSlatUSo[~] after proposed work: Gasr-I Pluggedr'-] Abandoned~ Commencing Operation 16. Verbal Approval: Date: WAG r'-~ GINJF~ WINJB WDSPL ['-~ Commission Representative: Perpared by S, Copeland 564-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John R Cubbon Printed Name John R Cubbon Title Wells Inte~lrit¥ En~lineer Signature Phone (907) 659-5102 Date Jun 26,. 200.3. Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ,.~-~, '-~'~-" Plug Integrity r"] BoP T estr-] Mechancial Integrity Tesr-I Location clearancC] Subsequent Form Required: BY ORDER OF Approved~~.,~.....,.~. ~bY: '- COMMISIONER THE COMMISSION Dato: Form 10-403 Revised 2/2003 SUBMIT IN DUPLICATE 04-1lA Description Summary of Proposal 06/26/03 Problem: Injector with Rapid TxlA communication Well History and Status Well 04-1 lA (PTD 1931580) is a water injector that failed an MIT-IA on 6/17/02. The IA equalized with the tubing and the pad operator was unable to bleed the pressure down. A LLR of 4.5 gpm @ 2500 psi was established during the MIT-IA. However, a more recent LLRT performed on 6/24/03 showed that the LLR had increased to 0.58 BPM ~ @2000 psi. Recent events: > 06/16/02: > 06/17/02: > 07/24/02: > 07/25/02: > 07/29/02: > 01/03/03: > 06/24/03: Unable to bleed IAP. Equalizes w/TBG in 15 minutes MITIA FAILED LLR - IA = 4.5 GPM @ 2300 psi /~ SL set TTP MIT-T Failed, CMIT T x IA Passed (variance evaluation) SL pulled TTP Sent Sundry to AOGCC for approval. LLR .58 bpm @ 1000 psi differential / This sundry request is to allow for continued injection of water. The following supports the request: · A CMIT-TxlA passed on 7/25/02 to 2500 psi against a tubing plug, demonstrating competent production casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · A CMIT TxlA against a TTP will be conducted every 2 years to confirm J 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 rates. 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. r~EE= GRAY GEN 2 WELLHEAD = FMC ACTUATOR = AXB_SON KB. REV = 56.8' BF. B_EV = kOP = 2459' Max Angle = 52 @ 5274' Datum rvD = 11323' Datum TVD = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" H 2741' Minimum ID = 4.455" @ 1019'1' 5 1/2" OTIS XN NIP 04-11A SAFETY NOTES : ***SLOW TxlACOMM. OPERATING UMITS: MAX lAP = 2000 PSI, MIN OAP = 1000 PSI (04/21/03) *** 2206' H5-1/2"CAMBAL-0 SSSV NP, ID=4.562" I 10125' H 10191' H 10191' H 9-5/8" X 5-1/2" TEN HBBPPKR I 5-1/2" OTIS XN NIP, ID = 4.455" PXN PLUG (07/12/03) I 5-1/2"TBG, 17#, L-80,0.0232bpf, ID=4.892" I--I 10203' 10203' I-'-I 5-1/Z' TUBING TAIL WLEG I H I 10392' IWHtPSTOCK SET IN BAKER DW-1 PKR I--I 10392' Iw~nPsT°cK I-'l 10412' MILLOUT WINDOW 10392' - 10404' I 7"LNR, 29#,L-80, 0.0371 bpf, ID= 6.184" H 11468' 11510' 11510'I PERFORATION S UIV~vlARY RE3= LOG: BHCA ON 11/17/93 ANGLE AT TOP PERF: 35 @ 11330' Note: Refer to Production DB for historical 3erf data SIZE SPF I',ITERVA L Opn/Sqz DATE 2-1/2" 4 11330- 11350 O 12/13/93 DATE REV BY COIVIVIENTS DATE REV BY COMIVENTS 11/'24/93 ORIGINAL COIVPLETION 04/28/03 ATD/TLH WAIVER SAFETY NOTE 10/01/94 LAST WORKOVER 07/12/03 PVVF_JKK SET PXNPLUG 12/29/00 SIS-MWH CONVERTED TO CANVAS 02/20/01 SIS-MD FINAL 12/'27/01 RN/TP COF~,ECTIONS 11/03/02 ?/TP PB'rD DEPTH CORRECTION PRUDHOE BAY UNIT WELL: 04-11A PERMIT No: 1931580 APl No: 50-029-20286-01 SEC26, T11N, R15E, 4592.71' FEL & 1646.15' FNL BP Exploration (Alas ka) BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp June 26, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 04-11A (PTD 1931580) Application to cancel Sundry #303-005 Dear Mr. Aubert: Attached is Application to Cancel Sundry form 10-404 for Sundry #303-005. This request is to cancel the current sundry for slow T x IA communication at well 04-1 lA. The well has recently been diagnosed with rapid T x IA communication and a new sundry application has been forwarded to the AOGCC for approval. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Sincerely, ,,.,, ,,~ ,,~ J~hn C~bbon~~~ Well Integrity Engineer Attachment: 1) Application for Sundry Oancellation form 10-404 ORIGINAL 'i, STATE OF ALASKA AL~SK~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. OperatiOns Performed AbanonF] Suspend[--] Operation Shutdowrr-1 Perforat(:['"] varianceE~] Annuar Disposalr-] After Casim3[--] Repair Wellr-~ PluQ Perforation.~r--~ Stimulate[--] Time Extensior[-"l Other, Change Approved ProgranE~ Pull TubingJ--~ Perforate New PooE~ Re-enter Suspended Well-'] CANCEL 10-403 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developmentr'-~ Exploratoqr--] 193-158 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphicr--1 Service. 50-029-20286-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56.70 04-11 A 8. Property Designation: 10. Field/Pool(s): ADL 028324 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 11510 feet true vertical 9046 feet Plugs (measured) Tagged TD @ 11450' (06/05/1999). Effective Depth measured 1 1450 feet Junk (measured) true vertical 8996 feet Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 118' 118' 40K 520 Surface 2707' 13-3/8" 2741' 2732' 80K 2670 Intermediate 10358' 9-5/8" 10392' 8128' 80K 4760 Liner 299' 7" 10211'-11510' 9046'-11129' 80K 7020 Perforation depth: Measured depth: Open Perfs 11330'-11350'. True vertical depth: Open Perfs 8897'-8914'. Tubing: ( size, grade, and measured depth) 5-1/2" 17# L-80 TBG @ 10203' MD. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" TIW HBBP Packer @ 10125' MD. 5-1/2" Camco BAL-O SVLN @ 2206' MD. 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 OiI-Bbl Gas-Mcf Water-Bbl Casin~ Pressure Tubin~l Pressure Prior to well operation ( --- ) Subsequent to oper, ation ( --- ) 14. Attachments: 15. Well Class after proposed work Explorator~ Developmen{~ Service~ Copies of Logs and Surveys run __ 16. Well Status after proposed work: oilr--~ GasE] WAG r-'] GINJr-] WINJ, WDSPLE~ Daily Report of Well Operations __X Prepared by Sharmaine V. Copeland (907) 564-4424. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact John Cubbon I 303-005 Printed Name /iJo~Cl~on Title Well Integrity Engineer /i Signature 1!/~'.( J~.Y~m~ Phone 907/564-5102 Date June 26. 2003 Form 10-404 Revised 2/2003 ORIGINAL BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp June 26, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 04-11A (PTD 1931580) Application for Sundry Approval Dear Mr. Aubert: Attached is Application for Sundry Approval form 10-403 for well 04-1 lA. This requ. gest is for approval to continue water injection in a well exhibiting rapid Tubing x IA communication. A description summary of proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. John Cubbon Well Integrity Engineer Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) WellbOre Schematic ORIGINAL RECEIVED JUL 0 ~ 2003 Alaska Oil & G,~s Cons, Cornn'~ission SCANNED,' '"'JUL 1 6 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 2O AAC 25.28O 1. Type of Request Abandon ]-'] Suspend r-1 Operation Shutdown ['-1 Perforat6E~ Varianc6[ Annuar Disposal[-'] Alter Cas/nd ~] Re~3air Well ['-I Plua Perforations [--I stimulat~E] Time Extensior[-"] Otherr--] ChanQe Approved Proaram [--1 Pull Tub/nd r"'l Perforate New Pool ['-I Re-enter Susoended walE] VARIANCE 2. Operator 4. Current Well Class: 5. Permit to Drill ~,~ber: Name: BP Exploration (Alaska), Inc. Developmentr"'] ExploratoB[--] 193-158 3. Address: P.O. Box 196612 6. APl Number / Anchorage, Ak 99519-6612 Strut/graphic[-'] Service[] 50-029-20286-01-00 7. KB ElcO/at/on (ft): 9. Well Name and Number: RKB 56.70 04-1 lA 8. Property Designation: 10. Field/Pool(s): ADL 028324 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY T°tal DePth MD (ft):11..510' ITotal Depth TVD (ft): I Effective Depth MD (ft): [ I=:ffective Depth TVD (ft): I Plugs (measured): I Junk (measured):9046' 111450 (06/05/1999)I 8996' None I 1.1450' Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 84' 20" 118'1 118' 40K 520 Surface 2707' 13-3/8" 2741 'i 2732' 80K 2670 Intermediate 10358' 9-5/8"' 10392' 8128' 80K 4760 Sidetrack Liner 299' 7" 10211' - 11510' 11129' - 9046' 80K 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): I Tubing Size: I Tubing Grade: Tubing MD (ft): 11330'-11350' 8897'-8914' 5-1/2", 17# L-80 10203' Packers and SSSV Type: I Packers and SSSV MD (ft): 9-5/8" X 5-1/2" TIW HBBP Packer, 5-1/2" Camco BAL-O SVLN I Packer @ 10125', SVLN @ 2206' 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work Detailed Operations Progran E] BOP Sketch r'"] ExploratoBr-~ Developmenr"] Service[] 14. Estimated Date for July, 2003 15. Welolil~.~tus affe;ParsOlP..~sed wo;~;ggedr..1 commencing Operation Abandoned~ 16. Verbal Approval: Date: WAG [-'~ GINJ r'-~ WINJB WDSPL ~'1 Commission Representative: Perpared by $. Copeland $64-4424 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John R Cubbon ,, Printed Name AJo~n .RI C/t~bbon Title Wells Inte~lrity En~lineer Signature /~//~, (~ Phone (907)659-5102 Date .Jun 26. 2003 V Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness _,~ ~- / '7~, Plug Integrity E] "BOP TestF"] Mechancial Integrity TeeO Location Clearance] JUL 0 2003 Subsequent Form Required: BY ORDER OF Approved by: //~~"~-"-~Z__..~ COMMISIONER THE COMMISSION Date: Form 10-403 Revised 2/2003 ORI61NAL SUBMIT IN DUPLICATE 04-1 lA Description Summary of Proposal 06/26/03 Problem: Injector with Rapid TxlA communication Well History and Status Well 04-1 lA (PTD 1931580) is a water injector that failed an MIT-IA on 6/17/02. The IA equalized with the tubing and the pad operator was unable to bleed the pressure down. A LLR of 4.5 gpm @ 2500 psi was established during the MIT-IA. However, ~mor9 recg~RT performed on 6/24/03 showed that the LLR had increased to~~B~/~ ~si. Recent events: ~>?r > 06/16/02: Unable to bleed IAP. Equalizes w/TBG in 15 minutes ,/' > 06/17/02: MITIA FAILED LLR - IA = 4.5 GPM @ 2300 psi > 07/24/02: SL set TTP > 07/25/02: MIT-T Failed, CMIT T x IA Passed (variance evaluation)/~ > 07/29/02: SL pulled TTP > 01/03/03: Sent Sundry to A9~ for approval. > 06/24/03: LLR .58 bpm @~'psi differential This sundry request is to allow for continued injection of water. The following supports the request: A CMIT-TxlA passed on 7/25/02 to 2500 psi against a tubing plug, demonstrating competent production casing. Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. A CMIT TxlA against a TTP 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 rates. 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. TREE= GRAY GEN 2 WELL H~, D: FMC: ~,CTUATO R: AXELSON KB. REV: 56.8 BF. REV = KOP: 2459' Max Angle = 52 @ 5274' Datum IVD = 11323' Datum TV D = 8800' SS 04-11A SAFETY NOTES : ***SLOW TxlACOMM. OPERATING UMITS: MAX lAP = 2000 PSI, MIN OAP = 1000 PSI (04/21/03) *** 2206' H5-1/2"CAMBAL-0 SSSV NP, ID=4.562" I 13-3/8" CSG, 72#, N-80, ID= 12.347" I--~ 2741' Minimum ID = 4.455" @ 10191' 5 1/2" OTIS XN NIP 10125' I'-'l 9'5/8"X5'I/2"TIWHBBPPKRI 10191' I-J 5-1/2" OTIS XN NIP, ID:4.455"I 5-1/2" TBG, 17#, L-80, 0.0232 bpf, ID: 4.892" I--{ 10203' 10203' I-I i I I--} ELMDTTNOTLOGGED I 10392' 10392' IWHIPST°cK I-'1 10412' MILLOUT WINDOW 10392' - 10404' r~"H 11468, I 7"LNR, 29#,L-80, 0.0371 bpf, ID=6.184" H 11510' PERFORATION SUMMARY REF LOG: BHCA ON 11/17/93 ANGLE AT TOP PERF: 35 @ 11330' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 11330- 11350 O 12/13/93 DATE REV BY COMMENTS DATE REV BY COMMENTS 11/24/93 ORIGINAL COIVPLETION 04/28/03 ATD/TLH WAIVER SAFETY NOTE 10/01/94 LAST WORKOVER 12/29/00 SIS-MWH CONVERTED TO CANVAS 02/20/01 SIS-MD FINAL 12/27/01 RN/TP CORRECTIONS 11/03/02 ?/TP PBTD DEPTH CORRECTION PRUDHOE BAY UNIT WELL: 04-11A PERMIT No: 1931580 APl No: 50-029-20286-01 SEC26, T11N, R15E, 4592.71 FEL 1646.15 FNL BP Exploration (Alas ka) BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp June 26, 2003 Mr. Winton Aubert, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 04-11A (PTD 1931580) Application to cancel Sundry #303-005 Dear Mr. Aubert: Attached is Application to CanceI Sundry form 10-404 for Sundry #303-005. This request is to cancel the current sundry for slow T x IA communication at well 04-1 lA. The well has recently been diagnosed with rapid T x IA communication and a new sundry application has been forwarded to the AOGCC for approval. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. C~bbon Well Integrity Engineer Attachment: 1) Application for Sundry Cancellation form 10-404 JUL 0 9 2003 ORIGIN, L , ,. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abanon[--] Suspendr-~ Operation Shutdowr r'-~ Perforat6r'-~ variancsF-~ Annuar Disposalr-] After Casin(~[-I Repair WellF'~ Plua Perforation~,['-] Stimulat6[~ Time Extensiorl-I OtherI Change Approved Progran~] Pull Tubing[~ Perforate New Pool""] Re-enter Suspended welr-] CANCEL 10-403 2. Operator !4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developmentr"'] Exploratory[--1 193-158 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 StratigraphicF-~ ServiceI 50-029-20286-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56.70 04-11 A 8. Property Designation: 10. Field/Pool(s): ADL 028324 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 1 1510 feet true vertical 9046 feet Plugs (measured) Tagged TD @ 11450' (06/05/1999). Effective Depth measured 11450 feet Junk (measured) true vertical 8996 feet Casing Length Size MD TVD Burst Collapse Conductor 84' 20" 118' 118' 40K 520 Surface 2707' 13-3/8" 2741' 2732' 80K 2670 Intermediate 10358' 9-5/8" 10392' 8128' 80K 4760 Liner 299' 7" 10211'-11510' 9046'-11129' 80K 7020 Perforation depth: Measured depth: Open Perfs 11330'-11350'. True vertical depth: Open Perfs 8897'-8914'. Tubing:( size, grade, and measured depth) 5-1/2" 17# L-80 TBG @ 10203' MD. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" TIW HBBP Packer @ 10125' MD. 5-1/2" Camco BAL-O SVLN @ 2206' MD. 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 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation ( --- ) Subsequent to operation ( --- ) 14. Attachments: 15. Well Class after proposed work Explorator~ Developmenl~ Service~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: oilr--~ Gasr-~ WAG[~] GINJF-1 WINJI WDSPL["~ Daily Report of Well Operations ~X Prepared by Sharmaine V. Copeland (907) 564-4424. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact John Cubbon I 303-005 Printed Name ,~h~C,a~} Title Well Integrity En~lineer Signature //~,, ~ Phone 907/564-5102 Date June 26. 2003 RBD BFL OR.IGINA'L Form 10-404 Revised 2/2003 BP Exploration (Alaska) Inc. Post Office Box 196612 PRB-20 Anchorage, Alaska 99519-6612 bp January 3, 2003 Mr. Tom Maunder, P.E. Alaska Oil & Gas Conservation Commission 333 W. 7th Ave. Anchorage, Alaska 99501 Subject: 04-11A (PTD 1931580) Application for Sundry Approval Dear Mr. Maunder: Attached is Application for Sundry Approval form 10-403 for well 04-1 lA. This request is for approval to continue water injection in a well exhibiting slow Tubing x IA communication. A description summary of proposal and wellbore schematic is included for the well. If you require any additional information or clarification, please contact either John Cubbon or Joe Anders at (907) 659-5102. Sincerely, ~o~ Anders, P.E. Well Integrity Engineer Attachments 1) Application for Sundry Approval form 10-403 2) Description Summary of Proposal 3) Wellbore Schematic RECEIVED · !AN 0 7 2005 Alaska 0il & Gas ~0ns. C0mm~ss~u Anchorage SCANNED JAN 2 ~ 20D3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. TyPe of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 56.7 feet 3. Address Exploratory_ 7. Unit or PrOperty name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service._x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5013' FNL, 4888' FEL, Sec. 26, T11 N, R15E, UM (asp's 713214, 5952150) 04~1 lA At top of productive interval 9. Permit number/~proval number 1457' FN L, 4749' FEL, Sec. 36, T11N, R15E, UM (asp's 718682, 5950583) 193-158~ At effective depth 10. APl number 1631' FNL, 4609' FEL, Sec. 36, T11N, R15E, UM (asp's 718827, 5950413) 50-029-20286-01 At total depth 11. Field / Pool 1649' FNL, 4593' FEL, Sec 36 T11N, R15E, UM (asp's 718843, 5950395) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11510 feet Plugs (measured) FCO to 11450' (06/05/1999) true vertical 9046 feet Effective depth: measured 11468 feet Junk (measured) true vertical 9011 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 90' 20" 320 sx Arcticset II 116' 116' Surface 2715' 13-3/8" 5900 sx Arcticset II 2741' 2732' Intermediate 10366' 9-5/8" 920 sx Class 'G' 10392' 8128' Liner 1299' 7" 250 sx Class 'G' 10211' - 11510' 7991' - 9046' Perforation depth: measured Open Perle 11330' - 11350' true vertical Open Perfs 8896' - 8913' Tubing (size, grade, and measured depth 5-1/2", 17#, L-80 @ 10125. 5-1/2", 17#, L-80 Tubing Tail @ 1.(~9~'. Packers & SSSV (type & measured depth) 9-5~8" x 5-1/2" TIW HBBP Packer @ 10125' MD. ,x.l~.S~(a 0il,~& GaSC0ilS' 5-1/2" CAMBAL-0 SSSV Nipple @ 2206' MD. 13. Attachments Description summary of proposal __X Detailed operations program ~ BOP sketch 14. Estimated date fgr qommencing~operation 15. Status of well classification as: ,.. tl - 16. If proposal was verbally approved Oil ~ Gas ~ Suspended Name of approver Date approved Service WATER INJECTION WELL 17. I hereby certify thatJ~e foregoing is true and correct to the best of my knowledge. Questions? Call Joe Anders or John Cubbon, 907/659-5102. Signed jo ~e'Anders Title: Well Integrity Engineer Date January 2, 2003 ~ P.E. Prepared by DeWayne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity ~ BOP Test~ Location clearance ~ ! Mechanical Integrity Test__ ~ . Subsequent form required 10- Approved by order of the Commission ('~IRIklA! .~1~1~11=~ av ~Commissiorr)er Dat~ /77/ Form 10-403 Rev 06/15/88 ~ :~!~$ BF L ML Bill ; GANNED JAN 4: JAN 9 2003 SUBMIT IN TRIPLICATE 04-1lA Description Summary of Proposal 01/02/03 Problem: Injector with Slow TxIA communication Well History and Status Well 04-1 lA (PTD 1931580) is a water injector that failed an MIT-IA on 6/17/02. The IA equalize,~l~wi~fi t~tubing and the pad operator was unable to bleed the pressure down. A LLR o~ 2500 psi was established during the MIT-IA. Recent events: >'0~/16/02: Unable to bleed IAP. Equalizes w/TBG in 15 minutes > 06/17/02: MITIA FAILED LLR - IA = 4.5 GPM ~ 2300 psi > 07/24/02' SL set TTP > 07/25/02: MIT-T Failed, CMIT T x ~ Pass~(variance evaluation) > 07/29/02: SL pulled TTP This sundry request is to allow for continued injection of water. The following supports the request: · A CMIT-TxlA passed on 7/25/02 to 2500 psi against a tubing plug, demonstrating competent production casing. · Pressures and injection rates will be monitored and recorded daily and checked for indications of a production casing leak. · An annual IA leak rate test will be conducted to monitor the leak severity. · A CMIT TxlA against a TTP will be conducted every 4 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 rates. 4. Perform an annual IA leak rate test. 5. Perform combination MIT Tubing x IA against a plug every 4 years. 6. Stop injection and notify the AOGCC if there is any indication of loss of production casing integrity. 8CANNED JAN 2 4 2003 , , TREE= GRAY GEN 2 WEII HF_AD = FMC ACTUATOR = AXELSON KB. B. EV = 56.8' BF. B. EV = KOP = 2459' Max Angle = 52 @ 5274' Datum IVD = 11323' Datum 3VD = 8800' SS 13-3/8" CSG, 72#, N-80, ID= 12.347" I-'1 2741' IMinimum ID = 4.455" @ 10191' 5 1/2" OTIS XN NIP ITOP OF 7" LNR H 10199' 04-11A 2206' 10125' H 10191' SAFETY NOTES: H5-1/2" CAM BAL-0 SSSV NP, ID = 4.562" 9-5/8" X5-1/2"TIW HBBPPKR I 5-1/2" OTIS XN NIP, ID= 4.455" I 5-1/Z'TBG, 17#, L-80,0.0232bpf, ID=4.892" H 10203' 10203' H 5-1/2" TUBING TAIL WLEG ] H I I,9-5/8" CSG, 47#, N-80, ID = 8.681" H 1039Z IWHIPSTOCKSETINBAKERDW-1PKR I--I 10392' IWI'IPSTOcK H, 10412' MILLOUT WINDOW 10392' - 10404' ITDH 11468' 11510' I 11510'I PERFORATION SUMMARY REF LOG: BI-ICA ON 11/17/93 ANGLE AT TOP PERF: 35 @ 11330' Note: Refer to Production Di3 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 11330 - 11350 O 12/13/93 SCANNED JAN 4 2003 DATE REV BY COIVlVlENTS DATE ~ BY COMIVENTS 11/24/93 ORIGINAL COIVPLETION 10/01/94 LAST WORKOV ER 12/29/00 !SlS-MWH CONVERTED TO CANVAS 02/20/01 SIS-lVD FINAL 12/27/01 RN/TP CORRBCTIONS 11/03/02 ?/TP PB'rD DEPTH CORRECTION PRUDHOE BAY UNIT WELL: 04-11A PERMIT No: 1931580 AFl No: 50-029-20286-01 SEC 26, Tl11~ R15E, 4592.71 FEL 1646.15 FNL BP Exploration (Alaska) He: u4-1 lA l-allea Mi I I/-~ (,!-' i U '1 ~'IO~U) Subject: Re- 04-11A Failed MITIA (PTD 1931580) -Date: Thu, 20 Jun 2002 12:56:t0 -0800 From' Tom Maunder <tom_maunder@admin.state.ak. us> To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> CC-"-Jim Regg AOGCC (E-mail)" <jim_regg@admin.state.ak.us>, Bob Fleckenstein <bob_fleckenstein@admin.state.ak.us> Joe, Thanks for the notice. Your diagnostic plan is appropriate. Please keep us informed and we will look to receiving the sundry. Tom Maunder, PE AOGCC Bob, Would you please enter this information into the data base as a MIT failure on 6/17. Thanks. "NSU, ADW Well Integrity Engineer" wrote: > Hello Tom & Jim. > Injection well 04-1 lA (PTD 1931580) failed an MIT-IA. On 06/17/02, an MIT-IA > was attempted in preparation of the 4-year MIT. The IA was pressured to 2500 > psi and lost 200 psi in 3 minutes. An injection rate of 5 GPM at 2300 psi > (600 psi differential) was established. The well is currently on water > injection. > Our plan is to set a tubing tail plug, pressure test the tubing and > production casing, evaluate running a LDL depending on leak rates and > evaluate pursuing a sundry. We?/keep you informed of evaluation progress. > Please call if you have any questions. > Joe > Joe Anders, PE / Kevin Yeager > Well Integrity Engineer > BP Exploration, Alaska Inc. > (907) 659-5102 - Work > (907) 659-5100, x1154- Pager > emaih NSUADWWelilntegrityEngineer~,bp.com Tom ..... Maunder <tom maunder~_admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 6/2012002 12:56 PM PERMIT DATA 93-158 5937 93-158 407 93-158 DAILY WELL OP 93-158 SURVEY 93-158 BHCA/GR 93-158 BHP 93-i58 CCL 93-158 CCL 93-158 CNL/GR 93-158 DLL/MLL/GR/SP 93-158 GR/CCL (PSR) 93-158 INJP 93-158 PERF 93-158 SBT/GR/CCL 93-158 SSTVD AOGCC Individual Well Geological Materials Inventory T DATA_PLUS '~OH-DLL, 10379-11486 ~CCOMP DATE: 12/13/94 ~11/06/93-I!/24/93 ~10400-11102 u~'~11000-11430 ~10379-!1486 ~/~10000-10234 ~1000-10185 ~11000-11387 Y~10379-11486 ~-w~1042-11206 .~w11200-11348 ~0000-11400 ~0190-1!428 ~"~11000-11430 Page: 1 Date: 10/13/95 RUN DATE_RECVD 1 12/15/93 02/04/94 02/04/94 02/04/94 1 12/15/93 1 12/15/93 i 10/05/94 1 09/28/94 1 12/15/93 1 12/15/93 1 01/14/94 06/20/94 1 01/14/94 1 01/14/94 1 12/15/93 Are dry ditch samples required? Was the well cored? yes ~/Analysis & descriptio~l-~-d? Are well tests required? yes ~_/Received~ ycs~o ~ Well is in compliance ~ Initial COMMENTS yes ~__~d received?~_--y~s---n~- yes STATE OF ALASKA .... '~ ALASKA OIL AND GAS CONSERVAT ON COMMIS,.,.ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging Perforate Pull tubing __ Alter casing __ Repair well Other x Fish coil tubing 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. Development KBE = 56. 7 feet Exploratory 3. Address Stratigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 Service X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 267' NSL, 4888' WEL, SEC. 26, T11N, R15E 4-1 IA At top of productive interval 9. Permit number/approval number 1457'SNL, 531' EWL, SEC. 36, T11N, R15E 93-158/94-247 At effective depth · . 10. APl number 1619' SNL, 681' EWL, SEC. 36, TI IN, R15E ~ ' 50- 029-20286-01 At total depth " 11. Field/Pool 1636' SNL, 697' EWL, SEC. 36, T11N, R15E Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured 11510 feet Plugs (measured) true vertical 9046 feet Effective depth: measured 11468 feet Junk (measured) Top of Coil Tubing Fish @ 10165' MD true vertical 9011 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 84' 20" 320 sx Arcticset II 90' 90' Surface 2707' 13-3/8" 5900 sx Arcticset II 2741' 2732' Intermediate 11472' 9-5/8" 920 sx Class "G" 10392' 8128' Production Liner 299' 7" 250 sx Class "G" 10211 '- 11510' 11129;9046' Perforation depth: measured 11330; 11350' true vertical 8896'-8915' RECEIVED Tubing (size, grade, and measured depth) 5-1/2", L-80,17# tubing to 10203'MD OCT 2 8 1994 Packers and SSSV (type and measured depth) 9-5/8", TIW "HBBP"packer @ 10125' MD; 5-I/2" Camco Bal-O SVLN Nipple @ 2206' MD ~l~.ska u~ & Gas Cons. C0mmi 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaoe Production or Iniection Data OiI-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 x Oil__ Gas Suspended Service Water Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~lned ~,~¢¢/¢ ~/,~ Title Drillin~IEn~lineerSupervisor Date Form 10-404 Rev 9( SUBMIT IN DUPLICATE BP/AAI SHARED SERVICE DAILY OPERATION~ ~ PAGE: 1 WELL: DS 4-11IA BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: SPUD: RELEASE: OPERATION: DRLG RIG: WO/C RIG: 09/14/94 07:00 09/30/94 07:00 NABORS 28E 09/15/94 ( TD:ll510 PB: 9053 09/16/94 ( TD:ll510 PB: 9053 09/17/94 ( TD:ll510 PB: 9053 1) 2) 3) TESTING BOP MW: 8.5 Seawater MOVED RIG FROM DS 4-48 TO DS 4-11IA. COMMISION/DECOMMISION XMAS TREE/WELLHEAD/HANGER. TESTED TREE. PRESSURE TEST COMPLETED. REMOVED TUBING HEAD ADAPTER AND TREE. RIGGED UP BOP STACK. WORK COMPLETED. BOTTOM RAM IN POSITION. 2 7/8" BOTTOM RAMS INSTALLED. RIGGED UP TOP RAM. WORK COMPLETED. TOP RAMS IN POSITION. 2 7/8" TOP RAMS INSTALLED. TESTED BOP STACK. MU JT 2 7/8" TBG ON GRAY GEN II TUBING HANGER RUNNING TOOL FOR TEST JT. ATTEMPT TO SCREW INTO TOP OF TUBING HANGER. WOULD NOT GO. "STANDARD" TEST PLUG 3/16" LARGER THAN RUNNING TOOL. CHANGE TEST PLUG. MAKE UP BHA %1 MW: 8.5 Seawater TESTED PIPE RAM, BLIND RAM, CHOKE AND KILL LINES, FLOOR SAFETY VALVES, CHOKE MANIFOLD. TESTED ANNULAR, FAILED @ 1800 PSI. REPLACED HYDRIL RUBBER IN ANNULAR PREVENTER. DEEP HAIRLINE CRACK IN RUBBER ELEMENT. TESTED ANNULAR. ATTEMPTED TO PULL BPV. COULD NOT EQUALIZE PRESSURE BELOW BPV WITH LUBRICATOR ON SHOOTING FLANGE. PRESSURED LUBRICATOR, SHOOTING FLANGE. INSTALL BELL NIPPLE, FLOWLINE. P/U CUT LIP GUIDE AND BELOW TOOL FOR FISHING 1.75" COILED TUBING FROM INSIDE 5 1/2" TUBING. P/U 69 JTS 2 7/8" TUBING TO SHALLOW COILED TUBING. BHA %1 MADE UP. SINGLE IN DP TO 10000' MW: 8.5 WBM SINGLED IN DP TO 10000' BEGAN PRECAUTIONARY MEASURES. CIRC AT 10000'. CIRC AND VISCOSITY SEAWATER WITH BIOZAN POLYMER. OBTAINED REQ'D FLUID PROPERTIES - 100%, HOLE VOL. NO GAS OR SAND IN RETURNS. SINGLED IN DP TO 10191' WASH DOWN TO TOP OF FISH @ 10191' DPM. OBSERVED 2000 LBF RESISTANCE. FISHED AT 11274'. WASHED DOWN OVER FISH F/10191'-11274'. DID NOT SEE ANY FILL OR SAND IN RETURNS. SET DOWN ON ISOLATION PACKER. LATCHED FISH. WORKED STUCK PIPE AT 11274'. WORKED STUCK PIPE INCREASING PULL TO 210K. PIPE NOT MOVING. PULLED 215K, PIPE CAME FREE. CIRC AT 11244'. OBTAINED BOTTOMS UP (100% ANNULUS VOLUME). NO SAND OR SIGN OF FILL IN RETURNS. POOH TO 1090'. LOST 14 BBLS FLUID WHILE POH. STOPPED: AT SUB-ASSEMBLY. STRIP OUT COILED TUBING FISH BY CUTTING INTO 30' LENGTHS. LD FISH. POH LD 2-7/8" TUBING AND 1-3/4" COILED TBG FISH. OCT 2 8 1994 Alaska 0il & Gas Cons, Commission Anchort ? WELL : DS 4-11I OPERATION: RIG : NABORS 28E PAGE: 09/18/94 ( TD:ll510 PB: 9053 09/19/94 ( TD:ll510 ?B: 9053 4) 5) LD FISH MW: 8.5 WBM LD FISH. FINISH L/D 1-3/4" COILED TBG FISH AND 2-7/8" TBG. (1090' TOTAL COILED TBG) LAST 250' COILED TBG FILLED WITH FRAC SAND. COILED TBG PARTED @ SLIPS IN KELO OVERSHOT LEAVING COILED TBG AND 2.25" WASH NOZZLE BELOW TOP OF ISOLATION PACKER. AT WELLHEAD. FISHING BHA #2. SINGLED IN DP TO 2070'. 69 JTS PICKED UP. POOH TO 0'. POOH & STAND BACK 2-7/8" DP. AT WELLHEAD. BHA #2 - BOWL W/2.25" GRAPPEL, BUSHING, BOWL W/1.75" GRAPPEL, TOP SUB, SUB, (2) JTS 2-7/8" TBG, SUB, SUB, BUMPER JARS, OIL JARS, SUB, PMP OUT SUB = 89.02'. RIH TO 11271' ON FRAC SAND ON TOP ISOLATION PACKER. OBSERVED 2000 LBF RESISTANCE. REVERSE CIRC AT 11274'. REVERSE CIRC FRAC SAND OFF TOP OF PACKER. OBTAINED CLEAN RETURNS - 100% HOLE VOLUME. FISHED AT 11274'. ATTEMPT TO GET FISHING ASSY INTO BORE OF ISOLATION PACKER. COULD NOT WASH OR WORK INTO PACKER TO GRAB FISH. ABORTED ATTEMPTS TO LATCH. LD DP TO 3255'. POH LDDP LD DP & FISHING BHA MW: 8.5 WBM LD DP TO 3166'. L/D DP & FISHING BHA. AT WELLHEAD. NU TOP RAM. RU TOP RAM. CLOSED BLIND RAM. PULLED 2-7/8" PIPE RAMS AND INSTALLED VBR'S. WORK COMPLETED - TOP RAM IN POSITION. NU BOTTOM RAM. RU LUBRICATOR. ATTEMPTED TO SET BPV WITH "T" BAR RUNNING TOOL. RUNNING TOOL PARTED @ WELD. RETRIEVED BPV & BAR. R/U LUBRICATOR AND RAN BPV & TEST DART. BPV & TEST DART LEAKED. PULL DART & BPV. RAN BPV & DART #2. WORK COMPLETED - HANGER PLUG IN POSITION. RU BOTTOM RAM. PULLED 2-7/8" PIPE RAMS AND INSTALLED VBR'S. WORK COPLETED - BOTTOM RAM IN POSITION. TESTED DOORS TO 3000 PSI, OK. RD LUBRICATOR. PULLED TEST DART, BPV. WORK COMPLETED, EQUIP LAID OUT. FINISHED LAY DOWN LUBRICATOR. RU SERVICE LINES. WORK COMPLETED - LINES/CABLES IN POSITION. R/U ATLAS WIRELINE TO CUT 5-1/2" TBG ABOVE THE PACKER. PREPARED & FIRED CUTTING CHARGE AT 10125'. RIH W/CCL/5.5' TBG CHEMICAL CUTTER. CORRELATE AND SHOT TUBING @ 10125'. POH & R/D WIRELINE. CHARGE FIRED SUCCESSFULLY. CIRC AT 10125'. CIRC DIESEL CAP AND ANNULUS CAPACITY. OBTAINED CLEAN RETURNS - 100% HOLE VOLUME. RU TBG HANDLING EQUIP. WORK COMPLETED - TBG HANDLING EQUIP IN POSITION. LD TBG TO 3000'. TBG LOOKS IN GOOD CONDITION FOR RERUN. WELL : DS 4-11I OPERATION: RIG : NABORS 28E PAGE: 3 09/20/94 ( TD:ll510 PB: 9053 09/21/94 ( TD:ll510 PB: 9053 6) 7) POH MW: 8.5 WBM LAID DOWN TUBING. RECOVERED 28 SS BANDS. RAN BOP TEST PLUG. TESTED BOTTOM RAM. PRESSURE TEST COMPLETED SUCCESSFULLY. TESTED TOP RAM. PRESSURE TEST COMPLETED SUCCESSFULLY. PULLED TEST PLUG. INSTALLED WEAR BUSHING. COMMISIONED CIRCULATING HEAD. LD 3 1/2" KELLY AND PU 5" KELLY. MADE UP BHA #3. 8 1/8" OVERSHOT, EXT, BUMPER JARS, OIL JARS, SUB. BHA #3 MADE UP. SINNGLED IN DRILL PIPE TO 10125'. OBSERVED WELL. FISHED @ 10125'. TAGGED TOP OF FISH. ATTEMPTED TO LATCH FISH BUT COULD NOT. ROTATED AND SET DOWN BUT ONLY GOT TEMPORARY GRAB. PULLED 15K BUT CAME OFF. FISH APPEARED TO GO ONLY PART WAY INTO OVERSHOT. POH. PULLED BHA MW: 8.5 WBM PULLED BHA. LIP GUIDE ON OVERSHOT BENT IN. EVIDENCE OF TBG STUB IN OVERSHOT BUT HUNG UP ON BENT LIP GUIDE. BHA STOOD BACK. MADE UP BHA NO. 4. FISHING BHA #4: GUIDE SHOE EXTN W/HOLLOW MILL INSERT-OVERSHOT-EXTN-BUMP JARS-OIL JARS-SUB-(9) DC-SUB. BHA NO. 4 MADE UP. RIH TO 2000 FT. STOPPED: TO SERVICE DRLG EQUIP. SERVICE BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 10125'. OBSERVED 2000 LBF RESISTANCE. FISHED AT 10125'. ATTEMPTED TO MILL TOP OF FISH TO FIT INTO OVERSHOT GRAPPEL. COULD NOT GET FISH INTO GRAPPEL. 280 K UP, 170 K DN, 215 ROT 20,000 TQ. ABORTED ATTEMPTS TO LATCH. POOH TO 0' AT BHA. PULLED BHA. L/D & INSPECT FISHING TOOLS. NO EVIDENCE OF TBG STUB INSIDE GUIDE SHOE OR HOLLOW MILL. LIP OF GUIDE WHOE TURNED IN, WITH 3" OF WEAR PATTERN ON OUTSIDE OF 8-1/8" GUIDE SHOE. BHA STOOD BACK. MADE UP BHA NO 5. FISHING BHA #5: MILL SHOE (8-1/2" X 5-1/2")-BUSH-OVERSHOT-EXT-BUMP JARS-OIL-JARS-SUB-(9) DC-SUB. BHA NO 5 MADE UP. RIH TO 10125'. OBSERVED 2000 LBF RESISTANCE. MILLED TBG AT 10125'. MILL WOULD NO DRILL OFF W/5000#. TBG STUC AND ANCHOR SEAL ASSEMBLY MAY BE TURNING. 280 K UP, 170 K DN, 215 K ROT, 19000 TQ. COMPLETED OPERATIONS. POOH TO 0'. AT BHA. L/D & INSPECTED BHA. ONLY WEAR TO MILL WAS ON MILL FACE. FISH DID NOT GO UP INTO FISHING ASSY. FISH MAY BE TURNING. MADE UP BHA #6. FISHING BHA #6: 4.25" MILL-SUB-SUB-SUB-SPEAR-EXT-SUB-SUB-BUMP JARS-OIL JARS-SUB-(9) DC-SUB. BHA #6 MADE UP. RIH TO 5000' R CI IV D OCT 2 8 i994 Alaska Oil & 6as Cons. Cornrnissio~ Anchor:~. ~ WELL : DS 4-11I OPERATION: RIG : NABORS 28E PAGE: 09/22/94 ( TD:11510 PB: 9053 8) 09/23/94 (9) TD:ll510 PB: 9053 09/24/94 (10) TD:ll510 PB: 9053 RIH TO 10125' MW: 8.5 WBM RIH TO 10125'. AT TOP OF FISH. FISHED AT 10125'. ATTEMPT TO SPEAR FISH. ROTATED @ 40 RPM WITH 1000-3000 WEIGHT. NO SUCCESS. ABORTED ATTEMPTS TO LATCH. POOH TO 364'. PULLED BHA. BHA LAID OUT. MADE UP BHA #7. SHOE-CUTTER-2 JTS WASH PIPE-D.BUSHING-BUMP JAR-OIL JAR-SUB-(9) DC-SUB(363.92'). RIH TO 10125'. AT TOP OF FISH. FISHED AT 10125'. WASH OVER TOP OF FISH @ 10125' DOWN TO K-ANCHOR @ 10151' WORKED CUTTER UP 4' TO TBG COLLAR TO MAKE CUT. PULLED UP PAST COLLAR DEPTH WITH NO RESISTANCE. LATCHED FISH. POOH TO 364'. AT BHA. LD FISH. RECOVERED 25.80' OF TBG AND K-ANCHOR. 1 JTS LAID OUT. MADE UP BHA #8. RIH TO 10152'. AT TOP OF FISH. MILLED PRODUCTION PACKER AT 10152' MILLED PROD PACKER AT 10152' MW: 8.5 WBM MILLED PROD PACKER AT 10152' COMPLETED OPERATIONS. CIRC AT 10152'. HOLE SWEPT WITH SLUG - 150% HOLE VOLUME. POOH TO 364' AT BHA. LD FISH & TOOLS. (PACKER & TAIL PIPS ASSY). RECOVERED 1 RUBBER SEAL, 2 METAL RINGS & 1 SLIP DIE FROM JUNK BASKETS. STOPPED: TO CHANGE HANDLING EQUIP. PULLED BHA. BHA LAID OUT. L/D 9 6-1/4" DC. RU DRILLSTRING HANDLING EQUIP. CLEAR RIG FLOOR & CHANGE PIPE HANDLING EQUIP TO 3-1/2". MADE UP BHA NO. 9. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. BHA RUN #9. RIH TO 9045'. STOPPED: TO CHANGE HANDLING EQUIP. TESTED BOP STACK. MADE UP & SET 9-5/8" RTTS W/STORM VALVE @ 90'. PLANNED TO CHANGE OUT GREY 9-5/8" PACK OFF AFTER TESTING BOPE. TESTED BOP STACK MW: 8.5 WBM TESTED BOP STACK. REMOVED SEAL ASSEMBLY. RETRIEVED 9-5/8" PACKOFF. EQUIP WORK COMPLETED. INSTALLED SEAL ASSY. INSTALL NEW 9-5/8" PACK OFF. PRESSURE TEST TO 5000 PSI. RELEASED & L/D 9-5/8" RTTS. INSTA WEAR BUSHING. EQUIP WORK COMPLETED, SEAL ENERGISED. FILL PITS WITH WATER BASED MUD. EMPTY & CLEAN MUD PITS. MIX NEW 10.5 PPG MUD FOR ENDICOTT WELL CONTROL. RECEIVED 0CT 2 8 lg 4 Alaska Oil & Gas Cons. Cotnmission WELL : DS 4-11I OPERATION: RIG : NABORS 28E PAGE: 5 09/25/94 (11) TD:ll510 PB: 9053 09/26/94 (12) TD:ll510 PB: 9053 09/27/94 (13) TD:ll510 PB: 9053 FILL PITS WITH WATER BASED MUD MW: 8.5 WBM FILL PITS WITH WATER BASED MUD. MIX 10.5 PPG MUD FOR ENDICOTT WELL CONTROL. CLEANED MUD PITS & TOOK ON SEA WATER FOR DS 4-1lA WORK OVER OPERATIONS. FTA#9 SHOE, EXT, D SUB, B JAR, 0 JAR, 7-3.5" DC, 4-3.5" HWDP, P.O.SUB, 27 JTS 3.5" DP, DP SUB. RIH TO 11274' AT TOP OF FISH. MILLED PERMANENT PACKER AT 11274' FB-1 RETAINER PRODUCTION PACKER MILLED FROM 11274' TO 11279' COMPLETED OPERATIONS. CIRC AT 11279' HOLE SWEPT WITH SLUG - 100% HOLE VOLUME. POOH TO 1230' AT BHA. PULLED BHA. BHA STOOD BACK. OVER SHOT W/4.75" GRAPPLE, EXT, EXT, D. SUB, B JAR, 0 JAR, 7-3.5" DC, 4-3.5" HWDP, PO SUB, 27 JTS 3.5" DP. MADE UP BHA #10. RIH TO 9000'. RIH TO 11274' MW: 8.5 WBM RIH TO 11274' AT TOP OF FISH. FISHED AT 11274'. WORK OVER FISH WITH OVER SHOT. LATCHED FISH. POOH TO 861' AT BHA. PULLED BHA. BHA STOOD BACK. DID NOT RECOVER FISH. BHA RUN NO 11. RIH TO 11274' AT TO POF FISH. WASHED TO 11279' WASHED OVER PACKER TO CLEAN OUT FILL FROM 11274' TO 11279'. NO FURTHER RESISTANCE. CIRC AT 11279'. HOLE SWEPT WITH SLUG - 200% HOLE VOLUME. POOH TO 862'. AT BHA. PULLED BHA. BHA STOOD BACK. MADE UP BHA #12. RIH TO 11274' AT TOP OF FISH. FISHED AT 11274'. LATCHED FISH. LATCHED ON TO FISH WITH 4-3/4" GRAPPLE. PICKED UP WITH 40K OVER PULL TWO TIMES & 30K THREE TIMES. POOH TO 1392'. AT BHA. PULLED BHA. BHA LAID. MADE UP BHA #13. FISHING MW: 8.5 WBM MADE UP BHA #13. STOPPED TO SERVICE DRILLING EQUIPMENT. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. MADE UP BHA #13. RIH TO 11274'. FISHED AT 11274'. ABORTED ATTEMPTS TO LATCH. UNABLE TO OG OVER TOP OF FISH WITH GUIDE. POH TO 1394' PULLE BHA. BHA STOOD BACK. NO FISH RECOVERY. MADE UP BHA #14. RIH TO 11274' FISHED AT 11274' ATTEMPT TO LATCH FISH WITH NO SUCCESS. ABORTED ATTEMPTS TO LATCH. POH TO 1380'. PULLED BHA. LAY DOWN SHORT CATCH AND BUSHING. ALL OF THE CARBIBE WAS WORN OFF THE BOTTOM AND GRAPPLE HAD MARKS ON THE VERY BOTTOM. MADE UP BHA #15. RIH TO 13274'. FISHED AT 11274' RECEIVED OCT 2 8 i~94 Alaska 0il & Gas Co.s, Colnrnissior, Anchor: .~,, WELL : DS 4-11I OPERATION: RIG : NABORS 28E PAGE: 09/28/94 (14) TD:ll510 PB: 9053 09/29/94 (15) TD:ll510 PB: 9053 09/30/94 (16) TD:ll510 PB: 9053 POH OUT OF LINER MW: 8.5 WBM MILLED PERMANENT PACKER AT 11281'. MILLED OVER PACKER 2' FROM 11281-11283'. CIRCULATED @ 11281'. HOLE SWEPT WITH SLUG. POH TO 1380'. PULLED BHA. MADE UP BHA #16. SERVICED BLOCK LINE. LINE SLIPPED AND CUT. RIH TO 11281'. FISHED AT 11281'. LATCHED FISH. LATCHED ON TO PACKER. POH TO 1380'. PULLED BHA. NO FISH RECOVERY. 4 3/4" GRAPPLE HAD SIGN OF BEING FULLY OVER FISH. MADE UP BHA #17. RERUN BHA #16. CHANGED GRAPPLE SIZE TO 4 5/8". RIH TO 11276'. TAGGED FISH @10225'. PUSHED FISH DOWN TO 11276'. FISHED AT 11276'. LATCHED FISH. WORKED OVER FISH FROM 11276-11281'. PULLED OUT OF HOLE TO 10200' OUT OF LINER. RUN TBG TO 11200' MW: 8.5 WBM POH TO 1380'. PULLED BHA. BHA STOOD BACK. LAID DOWN FISH. MADE UP BHA #18. RIH TO 11214'. WASHED TO 11480'. CIRCULATED AT 11480'. HOLE SWEPT WITH SLUG. CIRCULATED @11480'. HOLE DISPLACED WITH SEA WATER. 20 SWEEP FOLLOWE BY CLEAN SEA WATER. LAID DOWN DRILL PIPE TO 10077'. SERVICED LINES/CABLES. LINE SLIPPED AND CUT. PULLED BHA. BHA LAID OUT. RUN SINGLE COMPLETION 5 1/2" O. D. RIGGED UP TBG HANDLING EQUIPMENT. PULLED WEAR BUSHING. RIG UP TO RUN COMPLETION. RAN TUBING TO 11200' LAND TUBING HANGER MW: 8.5 WBM RAN TUBING TO 7996'. MAD UP AND TESTED CONTROL LINES. PRESSURE TEST COMPLETED SUCCESSFULLY. RAN TUBING TO 8316'. LAID DOWN TUBING TO 322' L/D SSSV AND CHANGED DUMMY. STILL WOULD NOT TEST. WAITED FOR NFS SSSV TO BE SENT TO CAMCO TO BE MADE UP AND TESTED. RAN TUBING TO 10200'. SPACE OUT TBG AND MAKE UP HANGER. MAKE UP AND TEST SSSV CONTROL LINES. CIRCULATED. CIRCULATE CLEAN SEA WATER TREATED WITH CORREXIT. PUMPED 135 BBL OF DIESEL AND LET IT U-TUBE FOR FREEZE PROTECTION. HOLE DISPLACED WITH DIESEL/SEA WATER MIX. RAN TUBING TO 10203'. DROP PACKER SETTING BALL AND LAND TUBING HANGER. HANGER LANDED. RECEIVED OCT 2 8 19 4 Alaska Oil & 6as (ions. Commission, WELL : DS 4-11I OPERATION: RIG : NABORS 28E PAGE: 10/01/94 (17) TD:ll510 PB: 9053 RELEASE RIG MW: 8.5 WBM RAN TUBING TO 11193' LAND HANGER. HAD PROBLEMS ALIGNING HANGER AND ENERGIZING RING. TESTED METAL AND LOWER SEAL. TESTED DUAL CONTROL LINE. PRESSURE TEST COMPLETED SUCCESSFULLY. SETTING PACKER @ 10120'. TEST SURFACE LINES AND SET PACKER. PACKER SET @ 11120' TESTED TUBING - VIA STRING. PRESSURE TEST COMPLETED SUCCESSFULLY. TESTED PERMANENT PACKERR, VIA ANNULUS. PRESSURE TEST COMPLETED SUCCESSFULLY. INSTALLED HANGER PLUG. EQUIPMENT WORK COMPLETED. RIGGED DOWN BOP STACK. WORK COMPLETED, EQUIPMENT LAID OUT. INSTALLED XMAS TREE. TREE, ADAPTER FLANGE AND CONTROL LINES TESTED. EQUIPMENT WORK COMPLETED. WELL SECURE. RIG RELEASED @1900 HRS ON 09/30/94. SIGNATURE: (drilling superintendent) DATE: RECEIVED OCI" 2 8 199q /.,Jaska Oil & Gas Cons. Cr, mmissior, Anchor~ ,,~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 19 September 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 CCL/TUBCUTR.FINAL BL Run # 1 1 CCL/TUBCUTR.RF SEPIA Run # 1 1 IEL/GR FINAL BL Run # 1 1 BHC/AL/GR FINAL BL Run # 1 1 SSVD/MWD FINAL BL Run # 1 1 IEL/GR RF SEPIA Run # 1 1 BHC/AL/GR RF SEPIA Run # 1 1 SSVD/MWD RF SEPIA Run # 1 ECC No. 6085.04 6268.00 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ ~ ~~odney D. Paulson ~~ % %. Receive' ate LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 25 September 1994 RE: Transmittal of Data Sent by: U.S. MAIL Dear Sir/Madam, Enclosed, please find the data as described below: 3-31 ~ 1 CCL/TUBCUTR FINAL BL Run # 1 2040.02 1 CCL/TUBCUTR RF SEPIA Run # 1 4-1lA /~ 1 COL/OHEMTUB FINAL BL Run ~ 1 6085.05 ~/ 1 COL/CHEMTUB RF SEPIA Run # 1 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Received b~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate Other x 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 267' NSL, 4888' WEL, SEC. 26, T11N, R15E At top of productive interval 1457' SNL, 531' EWL, SEC. 36, T11N, RI5E At effective depth 1619'SNL, 681'EWL, SEC. 36, T11N, R15E At total depth 1636'SNL, 697' EWL, SEC. 36, T11N, R15E 12. Present well condition summary Total depth: measured true vertical __ Fish coil lublng 11510 feet 9046 feet 5. Type of Well: Development Exploratory StratJgraphic Service x Plugs (measured) 6. Datum elevation (DF or KB) KBE = 56.7 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 4-11A 9. Permit number 93-158 10. APl number 50- 029-20286-01 11. Field/Pool Prudhoe Bay Field~Oil Pool ORIGINAL Effective depth: measured 11468 feet true vertical 9011 feet Junk(measured) Top of Coil Tubing Fish @ 10165'MD Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 84' 20" 320 sx Arcticset II 90' 90' Surface 2707' 13-3/8" 5900 sx Arcticset II 2741' 2732' Intermediate 11472' 9-5/8" 920 sx Class "G" 10392' 8128' Production Liner 299' 7" 250sxClass "G" 10211'-11510' 11129'-9046' Perforation depth: measured 11330'-11350' true vertical 8896'-8913' Tubing (size, grade, and measured depth) 5-1/2", L-80/NT-80 ,17# tubing to 10218' MD; w/ 3-1/2" tubing tail to 11272'MD Packers and SSSV (type and measured depth) 9-5/8", TIW "HBBP"packer@ 10152'MD; 5-1/2" Camco BaI-O SVLN Nipple @ 2180' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 9/11/94 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas Suspended __ Service Water Injector 17. I hereby cedify that the~,foregoing is true and correct to the best of my knowledge. " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test __ Location clearance __ Mechanical Integrity Test~ Sul~sequent form required 10- z~o ~ Original Signeo i.~;, Approved by order of the Commission David W. Johnstor. Form 10-403 Rev 06/15/88 Commissioner Approved Copy Date SUBMIT I1~ TRIPI'IC~TE Returned BP EXPLORATION ARCO Alaska, Inc. September 9, 1994 Sundry Application DS 4-11iA Workover Objective A rig workover of well 4-11 iA is proposed to fish the 1-3/4" CT string in the 5-1/2" tubing and return the well to injection. If the current completion must be pulled and the packer milled, the same 5-1/2" L-80 string will be rerun with a new TIW 9-5/8" x 5-1/2" HBBP packer set at 10,100'. A 7" x 3-1/2" plugback packer at 11,252' will not be replaced if same must be milled to fish the CT. Work Scope Pre Rig Work 1. Pull SSSV. 2. Check tbg for pressure. · If well is dead, skip to step 3. · If tubing has pressure RU CTU & circ well to 9.0 ppg brine. 2000'. 3. Install BPV in Gray Gen II hanger. 4. Remove wellhouse and flowlines. Prep for RWO. Freeze protect top Move in Rig Nabors 28E 1. ND tree. NU BOPE. Test to 5000 psi 2. Pull BPV. 3. RIH w/OS on 2-7/8" tbg & fish 1-3/4" CT @ 10,165' (CTM). 4. ND BOPE. NU and test tree to 5000 psi. Bullhead diesel down tubing to 2000'. injection rate cannot be established, RIH w/2-7/8" to 2000' & freeze protect. 5. Release rig. 6. RU CTU & cleanout fill below plugback packer to PBTD. ARCO Alaska, inc. Date: June 14, 1994 P.O. Box 100360 ..... ?3chorage, AK 99510,a~ ~ Transmittal#: 94045 ~ ~' Subject: From/Location: Telephone: ARCO Cased Hole Finals John E. DeGrey/ATO-1529 To/Location: 82-~ 8::3- (907) 263-4310 Distribution A!2ska 0!! & Gas Cons. Commission { Well iL°g DateI(M-D-Y) Tool Type Number ~ : Run, Scale USIT ! I 5" 1-10A ! 06-02-94 !/ 2-33 i 05-22-94i f 3-18A i 05-19-94i.~ CCL i05-24-94 ?BAKER IBP REC i05-26-94 i~' PERF REC !06-04-94 !-' INJ PROFILE i 3-27 } 4-07ST Contractor SCH CNL SCH 5" 5" 5" 5" 5" 5" SCH SCH SCH SCH t 4-11A ~ 4-19 i 05-25-94 I/' USIT SCH 1, 1" 5" SCH SCH 4-46 ! 06-04-94 ~Production Profile ! 5-3A ! 06-02-94 !/ CCL ! 1, 5" 6-3 i 06-03-94 l/ PERFREC i 1, 5" 6-t0 i 05-22-94 i/Patch Settin9 Rec i 6-16 J 06-05-94 .,~'ubJ~in9 Puncheri 6-22A i 05-22-94 !~ CNL ! 1, 5" 7-4A i 05-21-94 .k/ CNL i 1, 5" SCH SCH 1, 5" SCH SCH 7-6 i 05-21-94 },'Production Profile i 1, 5" 7-7A ! 05-20-94 ! / Pref Rec i 1, 5" 7-18 ! 05-21-94 ]-" CNL ! 1, 5" 7-23 i 05-24-94 !/ CCL i 1, 1" 5" 7-26 ! 05-21-94 l'." Prod Profile i 1, 5" 7-28 i 05-26-94 iv/ Perf Rec i 1, 5" 9-13 i 05-25-94 i," Bridge Plug ! 1, 5" 9-44 i 05-20-94 .~¢'Production Profile i 1, 5" 9-50 i 05-20-94 i/Production Profile i 1, 1" 5" 05-31-94 t/ CNL 1 5" 11-291 i 11-291 { 05-30-94 ! ~- USIT 11-291 i 05-31-94 ! ~ TDT-~' 11-291 I 05-30-94 I / CBT 11-35 I05-31-94 !f USIT 11-35 i 05-31-94!-" CBT 11-36 ! 05-23-94!/ CBT 1 5" 1 5" I 5" 1 5" 1 5" 14-3 i 06-03-94 1," PERFREC i 1 5" 14-12 } 05-28-94{ / GRLOG J 1 5" 14-12 { 05-28-94 ~'Product~on Profile ! 1, 14-20 ! 06-01-94 i,/'' PERF REC I 1, 5" 14-34 I 06-01-94 l/ PERFREC ~ 1, 5" 16-13 i 05-24-94 ! ~ Baker IBP Rec ! 1, 5" 17-12 ! 06-05-94 I/~ Leak Detection I 1, 1" 2" 5" I 05-26-94 t / PERF REC l 1, 5" 17-19 18-1 } 06-04-94 ~,' PackOff Gas Lift i 1, 5" 18-1 l 06-04-94 I/Tubing Puncher i 1, 5" SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH ARCO AlasKa, Inc. Is a Subsidiary of Atlant~cRIchfleldCompa~y STATE OF ALASKA ALASKA _ AND GAS CONSERVATION CC -ilSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown ~ Stimulate ~ Plugging ~ Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development ARCO Alaska, Inc. Exploratory _~ 64 RKB feet 3. Address Stratigraphic 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 service ~ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 267' NSL, 4888' WEL, Sec. 26, T11N, R15E, UM 4-11Ai At top of productive interval 9. Permit number/approval number 93-158 At effective depth 10. APl number 50 - 029-20286-01 At total depth 11. Field/Pool 1636' SNL, 697' EWL, Sec. 36, T11N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Totaldepth: measured 11510 feet Plugs(measured) Fill @ 11400' MD (1/13/94) true vertical 9046 feet Effective depth: measured 11400 feet ...... true vertical 8954 feet Junk(measured) .... · Casing Length Size Cemented Measured depth True vertlcal depth Conductor 112' 20" 320 sx AS II 112' 112' Sudace 2677' 13-3/8" 5900 sx AS II 2741' 2731' Production 10328' 9-5/8" 920 sx Cl G 10392' 8114' Tieback Liner 1311' 7" 250 sx Cl G 11510' 9046' Perforation depth: measured 11330-11350' :'' ""'" 0ii & (:-'..a',sbans." ' 6s~n~nissi0n true vertical 8896-8913 ..... Tubing (size, grade, and measured depth) 5-1/2", 17#, NT-80, Tbg @ 10218' MD; 3-1/2", Tbg Tail @ 11257-11272' MD Packers and SSSV (type and measured depth) TIW HB-BP Hyd Set Perm Packer @ 10152' MD; FB-1 Retainer Packer @ 11252' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Averaoe Production or Injection Data Oil-0bl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation .......... ..... Subsequent to operation .... 8353 '/''' -- 1558 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil . Gas m Suspended __ Service INJEOTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ~-~ 1103/8 MJB cc: JED, JWP 4-11Ai DESCRIPTION OF WORK COMPLETED HYDRAULIC FRACTURE TREATMENT OF ZONE I I I/26/93: RIH & tagged bottom PBTD at 11448' MD. 12/13/93: MIRU & PT equipment. RIH w/perforating gun & logged into position. Pressured up on the 9-5/8" to 3000 psi while pumping 96 bbls Slickwater to pressure up in tubing to 6500 psi, then shot initial perforations at: 11330' - 11350' MD (Z1) Ref. Log: BHCA 11/17/93. Rigged down. POOH w/gun. I 2/1 4/93: Attempted to place the well on initial seawater injection, but the well would not take injection. 12/18/93: RIH & tagged PBTD at 11444' MD. 12/19/93: MIRU & PT to 9000 psi. Pumped a Hydraulic Fracture Treatment, using 16/20 mesh proppant, through the perforations (listed above). Pumped 400 bbls 20# Pro-Pad Gel @ 30 bpm, followed by Shutdown. ISIP @ 1600. Resumed pumping 220 bbls 30# Crosslinked Pad @ 30 bpm, followed by 441 bbls Slurry w/proppant stages @ I - 10 ppg, followed by 273 bbls 20# Flush, followed by Shutdown. Placed a total of 98,000 lbs of proppant into the formation. Rigged down. I/1 3/94: RIH w/CT & jetted a proppant fill cleanout w/biozan gel, from 11220' to 11410' MD. 1/14/94: RIH & tagged bottom fill at 11230' MD. 1/29/94: RIH w/CT & jetted another proppant fill cleanout w/biozan gel, down to 11400' MD. Placed the well on initial seawater injection & obtained a valid initial injection rate. STATE OF ALASKA I ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ W~t~r Ini@ctor 2. Name of Operator 0J~/8/~4L 7. Permit Number ARCO Alaska, Inc. 93-158 3. Address / B. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20286-01 4. Location of well at surface 9. Unit or Lease Name 267' NSL, 4888' WEL, SEC. 26, T11N, R15E ~.-'::~ '~".';:'.'":'-'~' Prudhoe Bay Unit At Top Producing Interval !i"(":~-"">~f~'~'~l 10. Well Number At Total Depth I: .~' ¢~.,.,~ i 11. Field and Pool 1636' SNL, 697' EWL, SEC. 36, T11N, R15E ~'~:~"~ Prudhoe Bay Field/Prudhoe Bay Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 56. 7' ADL 28324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.~asp. or Aband. 15. Water Depth, if offshore 16. No. of Complelions 11/11/93 11/16/93 12/13/,8,¢~,~ N/A feet MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey 20. Depth where SSSV set Fl. Thickness of Permafrost 11510'MD/9046'TVD 11468'MD/9011'TVD YE,SE] kO [] 2180' feet MD ! 1900'(Approx.) 22. Type Electric or Other Logs Run Run #I CHT/DLL/GR/MLL Run #2 CHT/GR/CNL/AC/MLLMWD 23. CASING, LINER AND CEMENTING RECORD SE'FI'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE S~ZE CEMENTING REC. ORD AMOUNT PULLED 20" 94~ H-40 Surface 112' 30" 320 sx AS II 13-3/8" 72# N-80 Surface 2741' 17-1/2" 5900 sx AS II 9-5/8" 47# N-80 Surface 10392' 12-1/4" 920 sx Class "G" 7" 29# L-80 10211' 11510' 8-I/2" 250sx 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 (MDI Gun Diameter 2-1/2", ~s~f MD/ vu 5-1/2", L-80/ 11272' 10153' 11330'-11350' 8896'-8913' NT-80 26. ACID, FRACTURE, CEMENTSQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 12/20/94 injecting Date el Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S[ZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF ~ATER-BBL ;)IL GRAVITY-APl (corr) Press. :~4-HOUR RATE m~ 28. CORE DATA Brier description of lithology, porosity, fractures, apparent dips, and presence of oJl, gas or water. Submit core chips. RECEIVED FEB - 4 1994 Ai~sk~ 0il & Gas Cons. Commission , ~chorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. [ GEOLOGIC MARKERS FOHMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and lime of each phase. Subsea Top Sadlerochit 11068' 8622' Zone 1 11273' 8793' Base Sadlerochit 11354' 8961' R.:CEIVED Alaska 0il & Gas Cons. C0r~missi0n ~Ch0rago 31. LIST OF ATTACHMENTS 32. I hereby cerlily thai the foregoing is true and correct lo the best of my knowledge Signed .!~/~///~ ~ j~./~/~ Title Drillin9 EnoineerSuoervisor Date '~J'["~/~/( INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (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 tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no ceres taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: WELL: DS 4-1lA BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 11/06/93 04:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON 16 WO/C RIG: DOYON 16 11/06/93 ( TD:l1520 PB:l1450 1) TOOK ON SEAWATER. RIG ACCEPTED @ 04:00 HRS, 11/6/93. MW: 8.5 Seawater TOOK ON SEAWATER. 11/07/93 ( TD:11520 PB:l1450 11/08/93 ( TD:l1520 PB:l1450 2) 3) PULL TBG. MW: 8.5 Seawater R/U LUB. PULL BPV. DISP OUT F/P FLUID. N/D TREE. N/U BOPE. TEST BOPE. OIK. R/U LUB. PULL BPV. R/D LUB. RIH W/ SPEAR. PULL TBG HGR TO FLOOR. CBU. POOH, L/D TBG. P/U DP. MW: 8.5 Seawater POOH, L/D 5-1/2" TBG. TEST BOPE. P/U BHA, DP. 11/09/93 ( TD:l1520 PB:11450 11/10/93 ( TD:l1520 PB:11450 4) RIH MW: 8.5 Seawater RIH TO 10552. REV CIRC. TEST CSG. POH FOR E-LINE. RU & RIH W/JUNK BSKT. PU PKR, RIH. SET PKR. RIH W/SURVEY. 5) MILLING WINDOW MW:10.0 KCl RIH W/GYRO. POH. RIH W/PROTECTORS. SET PKR. DISPLC W/MUD. MILL WINDOW. ii/il/93 ( TD:10404 PB: 0 6) DRLG FORM W/ MILL. MILL WINDOW F/ 10392'-10395'. CBU. RIH. MILL WINDOW F/ 10395'-10404'. MW:10.0 KCl POOH. CHANGE MILL. 11/12/93 (7) TD:10525' (10525) 11/13/93 (8) TD:10641' ( 116) 11/14/93 (9) TD:10973' ( 332) PUMP DRY JOB MW:10.1 VIS: 53 CONT MILL WINDOW. PUMP DRY JOB, POH. RIH, TEST MWD. DIRECT DRILL TO 10525. PUMP DRY JOB. RIH W/BHA MW:10.0 VIS: 49 POH DUE TO MTR FAILURE. LD MTR & BIT. PU NEW & RIH. TEST MWD & MTR. RIH. W/BHA. DIRECTIONAL DRILL TO 10641. POH, RIH W/BHA 93. DIRECT. DRILL CONT TO RIH. DRLD TO 10973. MW: 9.9 VIS: 50 RECEIVED FEB - 4 1994 Alaska Oil & Gas Cons. Commission Anchorage WELL : DS 4-1lA OPERATION: RIG : DOYON 16 PAGE: 2 11/15/93 (10) TD:ll127' ( 154) 11/16/93 (11) TD:11275' ( 148) 11/17/93 (12) TD:llS10'( 235) 11/18/93 (13) TD:ll510' ( 0) 11/19/93 (14) TD:ll510 PB:11468 DIRECT DRILL MW: 9.9 VIS: 53 DIRECT DRLD. CBU. PUMP DRY JOB. POH. POH. BOPE TEST. MU BIT, NEW MWD, RIH. TEST. CONT RIH. DRLD TO 11127. DRILLING MW: 9.9 VIS: 51 CIRC. CONT TO DRILL. CBU. PUMP DRY JOB. POH. RIH, FILL PIPE. CONT RIH & REAM. DRLD TO 11275. TOH FOR LOGS MW: 9.7 VIS: 49 DRLD TO 11510. CIRC & COND HOLE. DROP SURV. PUMP PILL. TOH TO LOG. LD BHA MW: 9.8 VIS: 60 CONT TRIP'OUT TO LOG. RU & LOG. LD STAB & DC. TIH. REAM TO BTTM. CIRC PUMP SWEEP. TOH, LD BHA. RIH W/CSG SCRAPPER MW:10.0 KCl RU & RUN LINER. CIRC LINER VOL. PUMP CMT. DISPLC CMT, BUMP PLUG. SET PKR. TRIP OUT. MU BIT & RIH. 11/20/93 (15) TD:ll510 PB:11468 LD DRILL STRING MW: 8.5 Seawater PU DP, TIH, WASH TO LINER TOP. TAG CMT. CIRC. TEST CSG. CIRC HOLE CLEAN. REV OUT. TOH LD DRILL STRING. 11/21/93 (16) TD:ll510 PB:11468 11/22/93 (17) TD:ll510 PB:11468 TRIP IN W/CSG SCRAPPER MW: 8.5 Seawater TOH, LD DRILL STRING. RU WIRELINE. LOGGED LINER. TRIP W/JUNK BSKT & PKR. TRIP, NO PROBLEMS. PU PKR ASSY, TRIP IN. LD ASSY, RD WIRELINE. PU BIT & CSG SCRAPPER, TRIP IN. PU DRL STRING. TRIP IN HOLE MW: 8.5 Seawater TRIP IN W/SCRAPPER. WASH TO BTTM. REV CIRC. POH. RIH W/PKR ON DP. 11/23/93 (18) TD:ll510 PB:11468 11/24/93 (19) TD:ll510 PB:11468 RUN 5-1/2" TBG. MW: 8.5 Seawater RIH W/ BAKER ISOLATIONPKR ON DP. R/U ATLAS. RIH W/ W/L TO TIE-IN DEPTH. R/D ATLAS. SET PKR @ 11252' W/ 1500 PSI. POOH. L/D DP. RIH W/ 5-1/2" TBG, SSSV, CNTRL LINES. RELEASE RIG MW: 8.5 Seawater RUN COMP. STRING. INSTL BPV. LAND TBG. ND, NU, TEST FLG & TREE. PUMP DIESEL. SET PKR. SET BPV. RELEASE RIG 11-23-93 @ 24:00 HRS. SIGNATURE: (drilling superintendent) DATE: RECEIVED FEB -' 4. 1994 Alaska Oil & Gas Cons. Commission Anchorage COMF'ANT PDt: WELL NAMI~ I)S4-IIA LOCATION 1 PEr'HOE BAt', NSD LOCA?ION 2 ALASKA MAGNETIC DECLINATION 30,00 ELL NUMi~R 0 ~LL HEAD LOCATIOt~: LAT(N/-$) 0,00 AZII~]TH FROM ROT~¥ TABLE TO TARG~.T IS TiE IN F'DINT(TIP) : M~A~IRED DF..PTH TR~]£ S~T D~PTH B135~00 INCLINATIOt.~ .39. ,9.2 £]:~,~r~H 108.~ ~TITUDE(N/-S) -1430,30 DEF'ARTL~£ (~-W) 5170~?0 DEP(EI-W) 124, 0~00 RECEIVED FEB - 4 1994 Alask~ Oil & 8as Cons. Coramission Anchorage BS4-11A SURreY CALCULATION~ *****.****~*** CIRCLF~ ARC ~9]RED INTE6~,~ql, V~RTICAL TA~;GET ~ATION AZImutH LATITLE~ D~PAE%URE DISF'LAC~MBCf, at ~I~ ~EP?d D~'TH %~IDN I~LN, N/-S ft ft ft ft deg deg ft ft ft 104~00 0,0 B135,00 ~78,7~ ~ 1~,30 -14~,30 51~.90 5~4,35 105.41 1~35,74 2~,7 8~.5E 5178.84 ~,~ 14%~' -1498,02 52~0,03 ~98,04 10%8I 1F,6~.7~76 ~.0 ~64,29 ~ ~ ~7~46 151,38 -I510,31 ~ 1~98,~~ ~.5 ~0,77 5~4.74 30.58 153,2~ -1523~42 5303,7! ~18,36 106,03 I072~,~ ~.2 8416,~ 5~9,51 ~,30 1%,0~ -1538,84 5311,18 ~29.62 106,16 10762,01 31,5 8444.37 .~'~-~.7I 35,18 155,~0 -1~5.01 S316,46 5541,12 106,30 107.92.24 30,8 8469,24 5270,44 37.22 154,57 -t571,~1 5326,14 ~.~J-3,15 106,44 16423.30 30,5 8493,06 5287.06 ~.~0 152,88. -1588,53 5~4,55 5566,05 106,58 10853,37 )%1 8515,76 5304,58 42,04 151,37 -1605,95 5343,78 557.~9o88 106,73 1088%73 32,4 8~39.,E4 5324,13 43,06 151,57 -162.5,18 5354,23 5595,44 106,88 10916.39' 30,7 8562,07 ~342.78 42.66 151,22 -1643,4~ 5364.21 5610,33 107,03 10~48,60 32,2 8585,73 53~2,41 42,83 150,60 -1662,~9 5374,84 5626,11 107,19 10980,82 32,2 8609,44 b'382,37 42.42 146,59 -1681,21 5386,21 5642,49 107,33 11009,64 28,8 EWQ1,33 53c/9,98 38,72 142,8! -1696o51 5397,01 56~7,38 107,45 11041.48 31,8 B656,~ 541B,~ 36,42 140,1~ -1711,70 5409.09 5673,47 107,56 11072,56 31,1 ~41.92 5435,95 34.24 130,97 -1725,39 5420,~ 5686,72 107,66 I i102.17 29,6 8706,5~ ~51,93 3~,.. I~,65 -1737,~3 5431,65 ~02,~ 107.74 '~f7~ deg/ lOOft 0.00 10,93 10,66 %61 6,~ 6,65 9,45 7,84 3,17 1.53 1,42 8.52 15,41 8,65 7,34 7,58 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 01-04-94 REFERENCE: ARCO CASED HOLE FINALS 1-03 11-~3-93 --1-15 11-20-93 ~2-32 11-27-93 ~3~3-16i 11-19-93 ~ 3.~ ~-~4 ~ ~-~ 1-9~ _~-3-25A 11-22-93 ~ a ~a-a6 11-13-93 ~4-1 lA 11-20-93 ~-11A 11-20-93 4-22 11-17-93 4-30~T 11-13-9a 5-06 11-27-93 5-12 11-27-93 5-26 11-27-9a 5-31 11-28-93 6-12A 11-12-93 6-18 11-17-93 6-22A 11-16-93 9-03 11-20-93 13-28 11-16-93 I4-02 11-15-93 14-04 11-16-93 14-23 11-16-93 14-31 11-12-93 15-03 11-21-93 16-07 ll-la-ga 16-20 11-13-93 17-13 11-20-93 I8-23A 11-17-93 18-29A 11-23-93 Perf Record I B~O .~111) lO ,Run Prod Profile ~,~ Inj Profile/~-~)~e~l~61 (~c Run Leak Detect/GR/g(J~t~ ]i'i!~?tl(.t. Run Prod Profile/{¥~,~/~ ~9/~ Perf Record I'~e~b-'['2_-~'0 Run SBT/GR/CCL t0~cl0 -llct~ Run GR/CCL {'~] ii.~i!?~~ R~ Peff Record qc'~i', .~ic.,~ ~... ~, R~ Perf Record :'}i:~E: ~':!~ R~ Perf Record ~c~:~;~;. --~. [ I ~{ R~ Perf Record ~c ~C '--~ '~; ~ R~ Perf Record !,-fi:~: - '~.~i::: R~ Packer Setting Rec Peri Record I~'~:i~ D~l B~st TDT-P/~ R~ TBG Cutter ~00- Packoff GLM 3-~ ~, ~ R~ ~od ~ofile]~h ~?~ ~i~R~ ~ Detect [ ~ ~m?~ ~]C ~ ~ R~ Perf Record [~j~ 105i ~ R~ Perf Rego~d ~06 ~ 10~ 0 R~ USiT{~olor,~ ~0- ca R~ Perf Record q~-qs~ R~ 1, 5" Sch 1, 5"'?~00 '- cl-~o 0 Sch 1, 5" :~-f~'O "~i550 Sch 1, ~' ]AiC~-~TO Sch 1, ~' 7~-IL~ Sch 1, 5" Sch 1, 5" Atlas 1, 5" Atlas 1, 5" Sch 1, 5" Sch 1, 5" ~.~.:.~:,.- -..,.:~}~ 9 Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5"~'~--~( .... ~ Sch I, 5" Sch 1, 5" 2~'~78~ Sch 1, R'95~ ~ Sch 1, ~' Sch 1, ~' Sch 1, 5" q~ ~ Im A 0 Sch 1, 5''fl~o0,qgq0 Sch 1, S' ~i~ ~ ~0[ ~ Sch 1, 5" Sch 1, ~' Sch 1, ~' Sch 1, 5" Sch Please sign and return the attached copy as receipt of data. .E EIVE-- Have A Nice Day! John E. DeGrey ATO-1529 APPROVED ""%~'~',-.' ""' ' Trans# 94004 · # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # PHILLIPS # ANO8 GEOLOGY # EXXON # MOBIL * The corrected API# for 18-29A is 50~029-22316-01 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-3-94 REFERENCE: ARCO CASED HOLE FINALS '~-11 12-18-93 ~qD-~L__l - 18 12-12-93 ~/?~L__1-22 12-03-93 ~Z_f2~3__l-25 12-17-93 ~___T~2 - 6 12-05-93 2-22 10-22-93 3-4 12-20-93 ~3-36 12-11-93 4-1 12-06-93 -1 IA 12-13-93 ~_4-23A 12-14-93 4-31 12-11-93 4-41 12-14-93 5-28 12-10-93 ~-2 12-20-93 6-16 12-15-93 ..'9-1 12-5-93 ~--~9-1 12-9-93 9-20 12-19-93 ~__.9-29 12 - 13- 93 ~-36A 12-17-93 ~-36A 12-17-93 ~~9-51 12-07-93 ¢t~1-12 12-06-93 ~~l-13A 12-14-93 ~~4-1 12-5-93 ~~a-DA 12-9-93 16-17 12-4-93 ~~6-23 12-10-93 ~16-29A 12-18-93 ~~18-29A 10-19-93 CNL (Cfi] I b2,Zc-~i cc:'~ Leak Detect Peff Record Prod Profile Peff Record ~ (dep~ InJ Profile ]6~a Perf Record I 'Lotto - l-a-Ltl O Run Perf Record ~1c%o -~$~o Rrm , Perf Record )co c o - 1~¼00 Run Dual Burst TDT-P (l~) Run Prod Proflle~0,~ ~c-,'~;(-;'~':~Si::..~;..~ Rrm Perf Record q!?:-:: -n:'_.; ,2' ~ 1, 5" Sch 1, 5" ¥'?00 - qZcc Sch 1, 5' Sch 1, 5" cd~Oo .-ic0'ZO Sch 1, S" Sch 1, 5" ~icCo ~ %,30 Sch 1, 5" I tOOO ~f'L-6qo Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5" q*>$0 --q~-7-% Sch 1, 5" :1%~ ~i I:c~ ,',~ Sch 1, 5" Sch Sch $ch · ' Dual Burst TDT-P !G .... 3~-~.i:%Run d-., .. · Production:Y; Prod Profile .'¢;.c' ' w.':..,;::] !:':;?:/(:~,,.tfRun 1.5" 'i :(.'C--';", ~- :-- Sch Leak Detect.!.m'-~ Leak Detect; '?':'~ MI Inj Profile :~.."-,:4',c;¢~'.:';(e~ Runl, 5,,':{~.L:i .-:i'-~.6 :'; Sch LeakDetecti~.,.~ .... f !,-~: Rtml, 5''~ .... ', '~ ....' Sch CNL] ¢~G ~&- ~/090 ~qci~ Run 1, 5" Sch Dual Burst TDT-P/GR .... , iRun i, 5" "l 0:SQ'Lq.q,. [i~'~' Sc,h Prod Pronle~¢,%¢e,~i~l V'c,~?&~un i, r'&5" o ,~,~2x~ s~ Production; 5B¢) 1%~nfl g~/~¢o ~ Run 1, 5" ~x~o- ~z~ S sc.h Prod Proflle/5~ ]~tm~l [~c~[c*£d~Run 1, 5' ql~50~ t0iYg~ $ch TBG Cutt~ ~0 ~-f/q Run 1, 5" $ch ~R/CCL l~a)~0 ~:~90 , Run i, S" Sch Leak Detection Leak Detection I¢%i~-' - ~.,~ bc~c) Run 1.~&5">O- ~c-l~>u~'~o Sch Perf Record 1 ~2oo-i7.~- Run 1, 5' Sch TDTP (depth corrected) Run 1, 5" Please sign d return 0ie atta, ched cgpy ~, ~e. ceipt of data. RECEIVED BY__~__/~_~?_~_I~~ / John E. DeGrey APPROVED /. ATO- 1529 Trans # 94002 · # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # PHILLIPS # ANO8 GEOLOGY # EXXON # MOBIL The correct well name is 4-1lA and the corrected API# is 50-029-20286-01 The correct well name is 4-31 and the corrected API# is 50-029-21334-00 The correct well name is 18-29A and the corrected API# is 50-029-22316-01 ARCO .~l~sk~, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: /4-11A. q~l~% ~4-11A 4-11A 4-11A 4-11A ~-)~l ~;18-23A18_23A 12-7-93 ARCO OPEN HOLE FINALS 11-17-93 SSTVD //Run 1, l"&2" 11-17-93 11-17-93 11-17-93 11-17-93 11/6-13/93 11/6-13/93 DLL _/!~. ~/GR/SP Run 1, 2"&5" HHC. A/GRii~Hi%° Run 1, 2"&5" CNL/GR ~wa-ll~g[ Run 1, 2"&5" BH Profile~°%7q- )iq~l~l 1, 2" MWD: GR ?qqq-q~:~5'2"&5"MD ~ MWD: GR /2"&5"TVD Please sign and return the attached copy as receipt of data. Have A Nice Day!. Sonya Wallace ATO-1529 APPROVED Trans# 93149 # CENTRAL FILES # CHEVRON #D&M # ANO8 GEOLOGY # EXXON # MOBIL # PHILLIPS # PB WELL FILES # STATE OF ALASi~/II~¢ The co~ect ~I~ for 18-23A is 50-029-21898-01. ARCO 2,1~s1~; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: REFERENCE: Please sign and return the attached copy as receipt of data. RECEIVED BY_~~~___~ Have A Nice Day! Sonya Wallace AT0-1529 ARCO MAGNETIC TAPE(S) WITH LISTINGS o ,'7~l)~i(~~ 11-17-93 0~ DLL/lV~.I./GR/AC/~ Run 1 Job//6085.01 1,1-13-cJ3 oH-CN/~L/GR Run l Job~6087 APP ROVED .... //J' ._L-~__ Trans# 93147 Atlas Atlas # BOB OCANAS (OH/GCT) # EXXON # BPX # PHILLIPS # STATE OF ALASKA 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 --~ STATE OF ALASKA ~ ~ " Al'ASK/'~ 'L AND GAS CONSERVATION C '?MISSION (~,,-,, ~ APPLICA 'ION FOR SUNDRY APPROVALS Alter ~sing Repair well ~ Plugging . Time extension Stimulate ~ Ch~ge approv~ pr~ram Pull tubing Va~ PaSte ~ ~ ] 5. Type of Well 6. Datum of elevation(DF or~ ~lopment .. ~ RKB ~feet Explomto~ Strat[gr~hic 7. Unit or Pro~ Se~ ~ Pmdhoe Bay Unit ~ 4. Location of well at surface 267' FNL, 391' FEL, Section 26, T11N, R15E, UM At top of productive interval 3700' FSL, 4499' FEL, Section 36, T11N, R15E, UM At effective depth At total depth 3623' FSL, 4439 FEL, Section 36, T11N, R15E, UM 11510 feet Plugs(measured) 9053 feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured 11468 feet true vertical 9018 feet Junk(measured) 8, Well number 4-11Ai 9. Permit number 93-274 / ,~'~ ~.~ ,.~=~.. 10. AP[number 50 - 029-20286-0J 11. Field/Pool Prudhoe Bay Oil Pool Casing Length Size Cemented Measured depth True vertical depth Conductor 112' 20" 320 sx AS II 112' 112' Surface 2677' 13-3/8" 5900 sx AS II 2741' 2726' Production 11328' 9-5/8" 920 sx Cl G 11392' 8955' Tieback Liner 1311' 7" 250 sx Cl G 11510' 9053' RECEIVED Perforation depth: DEC - 9 199,~ Alaska 0il & Gas Cons. Commission Anchorage measured None true vertical None Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 & N-80 Tbg @ 10218' MD; 3-1/2", 9.38, Tbg @ 11272' MD Packers and SSSV (type and measured depth) TIW HB-BP Hyd Set Perm Packer @ 10152' MD; Camco BaI-O SSSV @ 2180' MD 13. Attachments Description summary of proposal ~ Detailed operations program . BOP sketch X Gas __ Suspended Injector 15. Status of well classification as: Oil ~ Date / z/'/~[/'? ?- SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 1078/7 MJB cc: SW, JWP Approved by order of the Commissioner driginal Signed By David W. Johnston 14. Estimated date for commencing operation I December, 1993 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (/~ '7-" ~~- Title Sr. Area Operations Engineer FOR ~OMMI.~ION U~l= ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- ¥O~p IApproval No. Approved Copy Returned Commissioner Date o Drill Site 4-11Ai Zone I Fracture Treatment Pro 'ure Isolate SSSV. Load 9 5/8" x 5 1/2, annulus. RU pressure relief equipment and pressure test backside to 3000 psi. Rig up tree saver for 5 1/2', 17#/ft tubing. MIRU pump trucks. Load tiger tanks with 1100 bbls of 1% KCL water or equivalent (plus tank bottoms) heated to 90° F. Conduct pre-job safety meeting. The fracture treatment will be pumped at 30 BPM. The expected treating pressure is 3000 psi. Maintain 3000 psi on the annulus during the frac. Pump 150 bbl, 30 pptg crosslinked pad including 25 pptg Adomite Regain, 5% diesel, and 15 pptg silica flour for fluid loss control. Pump 361 bbls of 30 pptg crosslinked slurry, total sand of 76,700 lbs to a maximum concentration of 10 ppg. Flush with 273 bbls of 20 pptg linear gel (5 bbls short of top perf). RU slickline, tag proppant, return SSSV to service. Move in CTU and cleanout fill to PBTD. Ensure perfs are open to bottom for injection. Return well to injection. RECEIVED DEC ,--9 199,~ Alaska Ojt & Gas Cons. Commission Anchorage 6 5 4 3 2 COILED TUBING UNIT BOP EOUIPH£NT 1. 5000 PSI ?" WELLHEAD CONNECTOR 2. 5000 PSI 4 1/16" PIPE RAMS .3. 5000 PSI 4 1/6" HYDRAUL~ SLIPS 4, 5000 PS! 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX FLANGE 4 3 2 RECEIVED DEC --9 199~ ~k~ Oil & Gas Cons. Commission Anchorage N]REL ]NE 1 BOP EOU]PHENT 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF MEMORANDU State Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Johnst~, Chairmar~'~'- Blair Wondzell, ~ P. I. Supervisor FROM: DougAmos, q:)e~~ SUBJECT: Petroleum Inspector DATE: FILE NO: November 7, 1993 afihkgad.doc BOPE Test Doyon 16 Arco PBU D$4-1 lA Prudhoe Oil Pool PTD No, 93-158 Saturday November 6, 1993: I traveled to AAI's PBU DS4-1 lA well to witness the BOPE Test on Doyon Rig No. 16, The Operator Rep. contacted me 9:30 AM, via the pager and informed me that they would be testing the BOPE stack at 2:00 PM and if I wanted to witness the test to show up at'that time. I returned his call and informed him that we require a 24 hour notice on all BOPE test and that he would have to stand by until i completed the SVS test I was currently conducting at AAI's KRU DS 2U. Inspectors Bobby Foster and Lou Grimaldi have had to take similar aCtion in the past with Doyon 16, I arrived on location at 5:00 PM and the drilling crew was still in the process of nippling up the BOPE Stack. The BOPE Test commenced at 7:00 PM and was concluded at 10:30 PM. The Annular Preventer and Pipe Rams could not be tested until after the 5 1/2" Tubing and Hanger were pulled. All other BOP equipment was tested satisfactorily. Sunday November 7, 1993: I returned to DS4 to witness the tests on the Annular Preventer and Pipe Rams at Doyon Rig No. 16, Both components passed. Summary: I witnessed the BOPE Test at Ah:o's PBU DS4-1 lA well on Doyon 16. 4.5 test hours, 24 valves tested, 3 failures. Attachment AFIHKGAD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: DOYON Rig No. Operator: Arco Alaska Inc. Well Name: DS4- 11A Redn'tl Casing Size: 7" Set ~;~ 10,250 Test: Initial X Weekly Other DATE: 11/6 & 7/fg93 16 PTD# g3-158 Rig Ph.# 659- 4610/4640 Rep.: .... Zee Runje ., . Rig Rep.: Snake Location: Sec. 26 T. 11 N R. 15 E Meridian Urn/at Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: "OK, (Gert) Reserve Pit N/A Well Sign OK Dri. Rig . .OK BOP STACK: Quan. Annular Preventer 1 Pipe Rams .... 1 Pipe Rams 0 Blind Rams Choke Ln. Valves 1 HCR Valves "'2 Kill Line Valves ..... ~ Check Valve N/A Test Pressure P/F 300/25O0 P 300 / 5000 P 300/5000 P 300/5000 P 30015000 P 300/5000 P P/F N/A N/A P FLOOR SAFETY VALVES: Quart. Pressure UpperKelly/IBOP ,1 I 300/5000 Lower Kelly / IBOP I '1 300/5000 Ball Type ~ 300/5000 Inside BOP 1. 300/5000 Test CHOKE MANIFOLD: Pressure No. Valves 14 I 300/5000 No. Flanges 38! 300/5000 Manual Chokes ...1 . Functioned Hydraulic Chokes '/ Functioned P/F P/F P/F p, p ACCUMULATOR SYSTEM: System Pressure ,, 3t.000. , !, P. Pressure After Closure .1, go0 ..... J P , MUD SYSTEM: V~sual Alarm 200 psi Attained After Closure 0 minutes f5 sec, Trip Tank OK OK System Pressure Attained I minutes I sec. Pit Level Indicators 'O/~ OK' Blind Switch Covers: Master:, Yes Remo'te: Yes Flow Indicator OK OK Nitgn. Bt's: 2 ~ 2,.0.00, 2 ,~ 2,300 ' Gas Detectom OK OK f ~ 2400 .... Psig. Number of Failures: 3 ,Test Time: 4.5 Hours. Number of valves tested 24 Repair or Replacement of Failed Equipment will be made within" N/A days. NolJfy the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax N 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Failures: I.) Stem Seal on Choke Manifoild Valve leaked. 2.} Choke Line Flan~,. o, n ~Stack leaked. 3.) Mud Cross to Pipe Rams Flange leaked. All Leaks were repaired and equipment r~teSted Ok. ! had to r~t'urn ot~ 1~/~//93 to ~vitnes'~s the teSt¥~n the A~nular end'P}pe R,,ams., ~eSt 'could n~t b,e COndu,cted,u, ntil TBG. was POH. 11/7/93 l/trSnessed the test on the ,Anr?ular, Preventer and Pipe Rams Distribution: orig-Weil File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector '' S~ATi: WITNESS REQUIRED?' YES X NO 24 HOUR NOTICE GIVEN YES NO , X Waived By: W~messed By: Ft-021L (Rev; 7/19) AFIHFAD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION October 22, 1993 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA gg501-3192 PHONE: (g07) 279-1433 TELECOPY: (907) 276-7542 Terry Jordan Drilling Engineer Supervisor ARCO Alaska, Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 4-1lA ARCO Alaska, Inc. Permit No. 93-158 Sur. Loc. 267'NSL, 4888'WEL, Sec. 26, TllN, R15E, UM Btmnhole Loc. 3633'NSL, 4432'WEL, Sec. 36, TllN, R15E, UM Dear Mr. Jordan: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested An accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under-20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and 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 tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. 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 COrv~i~ISSION ALASKA O~L AND GAS CONSERVATION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillDIlb. Type of well. Exploratory• Stratigraphic Test[] Development Oil[] Re-Entry [] DeepenE11 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 55.6 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28324 4. Location of well at surface 7. Unit or property Name 11. Type Bond(6,,, 20 AAC 25.025 267' NSL, 4888' WEL, SEC. 26, T11N, R15E Prudhoe Ba)/ Unit At top of productive interval 8. Well number Number 3699' NSL, 4499' WEL, SEC. 36, T11N, R15£ 4-1 lA U-630610 At total depth 9. Approximate spud date Amount 3633' NSL, 4432' WEL, SEC. 36, T1 IN, R15E 11/03/93 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MU and TVD) property line ADL 28327-3633' feet No close approach feet 2560 11563' MD/9037' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (se,, 20 AAC 25.035 (e)(2)) Kickoff depth ~o,~oo feet Maximum hole angleag,~3 o Maximum sudace 3330 psig Al 1oral deplh (TVD) ~8Q0'/4~0 psi~ 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 8-1/2" 7" 29# ,. :£ao NSCC 1313' 10250' 8020' 11563' 9037' 250 sx Class "G" 19. To be completed for Redrill, Re-entry, and Deepen Operations. 00T .-- 6 Present well condition summary Total depth: measured 11520 feet Plugs (measured) ~,laska 0il & 6as Cons. 00rllrnissto' true vertical 9023 feet Anchorage Effective depth: measured 11450 feet Junk (measured) true vertical 8966 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 84' 20" 320 sx AS II 90' 90' Surface 2707' 13-3/8" 5900 sx AS II 2741' 2732' Intermediate 11472' 9-5/8" 920 sx Class "G" 11500' 8991' Production Liner Perforation depth: measured 11103'-11173' (6 squeezed intervals) true vertical 8672'-8904'(6 squeezed intervals) 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program ITl Drillin9 fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby cerjj, fy th_at the. foregoing is true and correct to the best of my knowledge Signedd' /f~4t~ .~~ TitleDrillin~E,~gineerSupervisor Date LD Commission Use Only Permit Number APl number Approval d_a.ate See cover letter ~',,~ -/_~'"¢ 50- O.2. 9'- ~-. o.~. ~'¢~'-~ / /~) ..-.~,/~.~ ~'.~ for other requ rements Conditions of approval Samples required [] Yes ~ No Mud Icg requiredi-'lYes [] No Hydrogen sulfide measures [] Yes [S?l No Directional survey reqmred ~ Yes [] No Required working pressure for BOPE FI2M; r-]3M; ~L5M; 1-110M. n15M; Other: Original ~"r~ .... ~une~ By by order of Approved by David W. Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit in triplicale Well Nalne: I DS 4-1 lA Redrill Plan Summary [Type of Redrill (producer or injector): ] Producer Surface Location: 267 FSL 4888 FEL S26 T11N R15E Target Location: 3699 FSL 4499 FEL S36 T11N R15E Bottom Hole Location: 3633 FSL 4432 FEL S36 T11N R15E I AFE Number: 14J8013 I I Rig: I Doyon #16 IEstimated start Date: I11/03/93 ] l Operatingdayst°c°mplete: ITM I MD: I 11563 I ITVD: I 8981' ss [ I KBE: [ 55.60' [ Well Design (conventional, slimhole, etc.): I conventional ] Objective: I Impr°ve injecti°n Pr°file t° the L°wer R°me° interval and remedy a c°rr°ded 7"Iproduction liner. Mud Program: A 9.5 - 10.00 ppg Biozan polymer/KC1 water based mud will be used. I Speciat design considerations I none Depth Density PV YP INT 10MIN FL ()IL SOLIDS (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) KOP' 9.5 10 15 5 10 10 0 5 tO tO tO tO tO tO tO tO tO TD' 10.0 18 30 15 30 5 0 8 Directional: I KOP: I ~o4oo' Mm I Maximum Hole Angle: [ 39.13 degrees Close Approach Well: NONE The above listed wells will be secured during the close approach. RECEIVED Redrill Plan Summary OO~ ~- 6 199~ Oil & Gas Cons. L;ommissto," Anchorage Page 1 Casin~/Tubin; Pro~ram: Wt/Ft Hole Siz~ Csg/ " Wt/Ft"- Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 29# 13CR/80 NSCC 1313 10250/8020 11563/9037 Cement Calculations: I LinerSize: I ~/" Basis:I 50¢0 open hole ex6ess,'40' shoe joint, 150' liner lap and 150' excess above line~' with DP. Total Cement Volume: 250 sxs of Class G Blend @ 1.18 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and mud fluid system schematics on file with AOGCC. OCT ~-~; 199;~ Alaska OJJ & Gas Cons. 6ornmissio, Anchorag¢ Redrill Plan Summary Page 2 3. 4. 5. 10. 11. DS 4-11A SUMMARY PROCEDURE: Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation (upper most perfs are at 11103'). Cut 5-1/2" tubing @10650'md. Freeze protect. MIRU sidetrack rig. Test intermediate packoff to 5000 psi. Pull BPV. Circulate out freeze protection fluid. Set BPV. ND tree. NU BOP's. Install tree test plUg. Test BOP's to 5000 psi. Pull tree test plug and BPV. Pull and lay down 5-1/2" tubing. RIH on E-line with a 9-5/8" Baker model "DW-I" packer - postion set at 10400' md - POOH. RIH w/Gyrodata Gyro orientation survey. Obtain survey to determine packer alignment key position relative to borehole high side. POOH Perform timing operations on Baker "W-2" Anchor latch/whipstock assembly to ensure proper orientation to BHL. Bakerlock and tack weld whipstock and anchor connection. RIH w/starting mill/whipstock/anchor assembly. Locate into DW-1 9-5/8" 47# packer. Slack off +/- 6,000 lbs to engage anchor latch into DW-1 packer. P/U +/- 6- 7,000 lbs above string wt. to shear carriage bolt from starting mill. Circulate well to milling/drilling fluid. Mill 1.5' to 3.0' with starting mill. POOH. P/U window milling assembly - RIH and mill +/- 120' md. POOH. 12. 13. Ensure that footage milled is sufficient to cover up stabilization points on the followin~t "packed" BHA. Do not rotate stabilizers across wh/pstock. P/U "packed" BHA and drill an intial 500' md off of the whipstock assembly. Drop a tandem magnetic single shot survey. Perform short trip back and up into the 9-5/8" 47# casing. RIH w/Totco Unit w/overshot and retrieve magnetic single shot. Dependant upon azimuth and inclination angle either POOH for directional assemby or continue drilling until trip is nescessary due to bit hours or other associated drilling problems. Prior to RIH to TD the well at 11564' md - monel collars will need to be picked up to provide magnetic isolation for the Sperry Sun Multi shot EES service. RU Atlas wireline and log with the triple combo (GR/AC/DLL/4-Arm Caliper), Upon completion of logging make wiper trip prior to running 7" liner. (Note: Use four arm caliper to calculate your cement volumes) 14. 15. 16. 17. 18. 19. 20. DS 4-11A SUMMARY PROCEDURE cont'd: Run 7" 29# L-80 NSCC standard liner assembly to TD with liner top packer and +/- 150' lap. Cement liner using information obtained from 4-Arm Caliper run while logging. Clean out liner to PBTD and test to 3500 psi. Replace intermediate casing packoff and test the same. Change over to clean inhibited seawater. Run cement evalution SBT logs to satisfy AOGCC injectors requirements. Perforate the well in the Victor (Zone 3) interval per direction of onsite Qperations Engineering representative. RIH with 5-1/2" 17.0# L-80 x 4-1/2" 12.6# L-80. The Victor (Zone #3 ) interval will be straddled w/2 injection GLM's. Definitive 9-5/8" and 7" packer placement depths will require evaluation of open hole logging information. Set BPV. ND BOP's. NU the adapter flange and 6" 5M tree. Install tree test plug and test to 5000 psi with diesel. Pull tree test plug and BPV. Pressure tubing and set packer(s) w/4000 psi.. Test down tubing to 3500 psi. Bleed tubing pressure down to 1500 psi and hold. Test tubing x casing annulus to 3500 psi. 21. Shear RP valve and freeze protect. Set BPV. Release rig. OCT--~; !99;~ ,~laska 0il & Gas Cons. Anchorage 'SEP-30-1993 15:45 FROM ~C~7~EAT LRND DIR DRILLING TO PBD ENGINEERS P.04 PRUDHOE BAY DRILLING BI ENBOFCURVE 10875 "~ ~ ~.~; VERTICAL SECTION VIEW DI TO tI563 9037 5442 39.]3 Sec(ion a[: ~34.30 ~TvD Scale.' ~ inch ~ 200 feet Oep Scale.' ~ inch - 200 feet 7800--- ',% I 'Drawn ..... · 09/07/93 '-, Great Land OJr~ctiona] Orillin¢ 8000 ......... - 8200-- · . .... 8500- j ,, 8~oo-I ',,~ I i ~~~ ~ .............. ~. %- % ........ ~ .... ~ ..... ~800 ..... ' _ I ..... ; ........ I ~ , * I %"' ~ T I 9000 ' 9[00- -- 9200 ' '~. -, i OC'r ~ 5 iig~' i I . Ala~fa Oil & ~as Con~. Commi~isto~' ' I 1 4400 ~soo 4~00 4700 4800 4900 5000 5too 5~00 5300 5400 5500 5800 5700 5800 Sec(ion DeDarture PRUDHOE BAY DRILLING Marker Identification A) lIE-IN / KB~ I0400 143! 5192 B) E~ID OF CURVE t0675 ~5t~ 5338 C) IARGEI 11413 I845 ~72 D) TD tt~3 ~911 5739 Sreat Land Dff£ectJonal Drilling DS 4-:t A (P1) PLAN VIEW CLOSURE ' 5049 feet at Azi~uth ~OB.4I ,il " iIDECLINATION': 30.000 E ! I ~ , ISCALE ....... : ~ inch = 800 leer I ~ ,, KB ~ ~ . IDRAI~N ....... : 09/07/93 I · I ~taska 0ii & Gas C ns, Oo~ .....; Antic :a~e ~ ......... : t I ! 400 D 400 800 tE~¢ 1600 2000 2400 2800 3200 t§00 4000 4400 4800 5200 5600 BOOO 6400 <- ~Si' EASI -> m I Ld ' LO C3 t~ m z I-n ITl [6'.133 Ic192 DS4II~PI Bl.ig 3. 12 PI(I) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI$,.,~.JN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend __ Operation Shutdown __ Re-enter suspended well __ ~ Alter casing __ Repair well __ Plugging x Time extension __ Stimulate __ 'Change approved program __ Pull tubing __ Variance__ Perforate__ ~ther x Plugback for redrlll 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 267' NSL, 4888' WEL, SEC. 26, T11N, R15E At top of productive interval 1321' SNL, 705' EWL, SEC. 36, T11N, R15E At effective depth N/A At total depth 1430'SNL, 925' EWL, SEC. 36, Tl lN, RISE 5. Type of Well: Development Exploratory Stratigraphic Service. x 6. Datum elevation (DF or KB) KBE = 64' feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 4-11 9. Permit number 78-6 10. APl number 50- O29-2O286 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 11520 feet 9023 feet 11450 feet 8966 feet Size Plugs (measured) Junk (measured) Cemented 84' 20" 320 sx Arcticset II 2707' 13-3/8" 5900 sx Arcticset II 11472' 9-5/8" 920 sx Class "G" Measured depth True vertical depth measured 11103'-11392' (6 squeezed intervals) true vedical 8672'-8904' (6 squeezed intervals) 90' 90' 2741' 2732' OCT 6 1993 ~laska 0il & Gas Cons. Commisslo~ Anchorage Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80 to 10836', 4-I/2", 12.6#, N-80 tubing tail to 10951'MD Packers and SSSV (type and measured depth) Baker SAB packer @ 10824', Baker PFVE SSS V n/pple@ 2307' MD 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 10/15/93 16. If proposal was verbally approved Name of approver Date approved 15, Status of well classification as: Oil__ Gas __ Suspended __ Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ ~ Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Date/P' ~/-~ I Approva' No. ~J.. o~'~ ~'~I Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ~ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- Approved by order ofthe Commission,,,.'~/~'~ .~-.~ ~'~ X,)i[' ~,~ Form 10-403 Rev 06/15/88 Commissioner SUBMIT IN TRIPLICATE CHECK LIST FOR NEW WELL PERMITS ** ITEM ' APPROVE DATE (1) Fee /f~//__ ~ (2) Loc /~d /~'~/gJ '['2 thru 8]' (3) Adm i n L~?~ [9 thru 13] [10 $ 13] (4) Casg ~j,,~L [14 thru 22] ~ (5) BOPE [23 thru 28]'~' Company ~__~.~ YES 1. Is permit fee attached ............................................... ~ 2. Is well to be located in a defined pool .............................. ~ 3. Is well located proper distance from property line ................... ~ 4.' Is well located proper distance from other wells ..................... 5. Is sufficient undedicated acreage available in this pool ............. 6. Is well to be deviated & is wellbore plat included ................... ~. 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ /~ 9. Does operator have a bond in force ................................... / 10. Is a conservation order needed ....................................... 11. Is administrative approval needed .................................... 12. Is lease ngrnber appropriate .......................................... ~ 13, Does well have a unique name & nLrnber ................................ 14. Is conductor string provided ......................................... ,,, A 15. Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ., 16. Is enough cement used to circulate on conductor & surface ............ 17. Will cement tie in surface & intermediate or production strings ...... 18. Will cement cover all known productive horizons ..................... ~ 19. Will all casing give adequate safety in collapse, tension, and burst. ~ 20. Is well to be kicked off from an existing wellbore ................... ~- 21. Is old wellbore abandonment procedure included on 10-403 ............. ~ 22. Is adequate well bore separation proposed ............................. ~ 23. Is a diverter system required ........................................ 24. Is drilling fluid program schematic & list of equipment adequate ..... ~%t- 25. Are necessary diagrams & descriptions of diverter & BOPE attached .... ~ 26. Does BOPE have sufficient pressure rating -- test to ~-~D~ psig ..... x/m~ 27. Does choke manifold comply w/API RP-53 (May 84) ...................... -~-~ 28. Is presence of H2S gas probable ...................................... Lease & Well ~4Z~Z .2~g~/; /~g~ NO REMARKS [29 thFu~31] 1-32'1' (8) A~I FOR EXPLORATORY & STRATIGRAPHIC WELLS: 29. Are data presented on potential overpressure zones ................... 30. Are seismic analysis data presented on shallow gas zones ............. 31. If offshore loc, are survey results of seabed conditions presented... 32. Name and phone nLrnber of contact to supply weekly progress data ...... 33. Additional requirements ............................................. geology: DWJ~:j~__ R TAB rev 6/93 jo/6.011 engineering: ~ B~ JDH\/F/~/r/~ ~,~/~£~ INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA SHORE Additional remarks: UM MERIDIAN: SM W~LL TYPE: Exp/De~ Redrill ~ Inj X Rev 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 effod has been made to chronologically organize this category of information. ARCO ALASKA INC D.S. 4 - IIA PRUDHOE BAY II I I Tape Subf~le 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 6085.01 J. DAHL SEE REMARKS D.S. 4 - llA 500292028601 ARCO ALASKA INCORPORATED ATLAS WIRELINE SERVICES 01-DEC-93 RUN 2 RUN 3 26 liN 15E 267 4888 56.80 56.80 28.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 9.625 10392.0 PRODUCTION STRING 8.500 11510.0 REMARKS: DLL/MLL/GR & AC/CN/MLL/GR LOGS WITNESSED BY: V. HUTCHINS & E. POTTER. CIRCULATION STOPPED AT 01:30, 17-NOV-93. DLL/MLL TOOL STRING: GAMMA RAY SECTION FROM REPEAT PASS (11336 - 11364) SPLICED INTO MAIN PASS DUE TO STICK & PULL AT THIS POINT ON MAIN PASS. MICROLATEROLOG PAD WAS DESTROYED ON THE FIRST RUN. MLL WAS LATER RUN WITH AC/CN & SPLICED INTO DLL PASS. MLL COVERAGE ONLY OVER ZONE OF INTEREST DUE TO HOLE CONDITIONS. REPEAT SECTION OF MLL HAS EXCESSIVE STICK & PULL. AC/CN/MLL TOOL STRING: MAIN PASS HAS BOTTOM SECTION OF REPEAT PASS SPLICED INTO IT TO PRESENT A FULL PASS OF THE ZONE OF INTEREST (SPLICE AT 11316'). STICK & PULL CAUSES AC TO STRAIGHT LINE WHEN STUCK. REPEATABILITY IS ALSO EFFECTED BY STICK & PULL. MAIN PASS WAS THE SMOOTHEST PASS. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, 8.5" BOREHOLE CORRECTION, CHISM FILTERING IS ACTIVE, NO CASING OR SALINITY CORRECTIONS APPLIED. FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; all runs merged; no case hole data. DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 10379.0 DLL 10397.0 MLL 10996.0 STOP DEPTH 11466.0 11455.0 11378.0 GR 10970.0 11380.0 BCS 11021.0 11430.0 2435 11023.0 11386.0 $ BASELINE CURVE FOR SHIFTS: GR from DLL Main Pass. CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH LL3 10379.0 10379.0 10403.0 10402.5 10411.5 10411.5 10419.0 10419.0 10430.0 10429.5 10439.5 10439.0 10445.5 10446.0 10451.0 10451.0 10455.0 10454.5 10458.5 10458.0 10470.0 10470.0 10472.5 10472.0 10474.5 10474.0 10486.5 10486.5 10499.5 10499.0 10507.5 10507.0 10516.5 10517.0 10519.5 10519.0 10524.0 10523.0 10526.0 10525.0 10625.0 10625.0 10626.5 10627.0 10638.5 10638.5 10657.0 10656.0 10666.5 10666.5 10682.0 10682.0 10689.0 10688.5 10699.0 10699.0 10719.5 10719.0 10721.5 10721.5 10744.5 10744.5 10750.0 10749.5 10788.5 10787.5 10801.0 10801.0 10832.5 10833.0 10859.0 10858.5 10867.5 10867.0 MLL GRCN DT NPHI 10379.0 10379.0 10379.0 10379.0 10931.0 10939.0 10958.5 10975.5 10981.0 10983.0 10984.0 10992.5 10995.0 10998.5 11002.0 11005.5 11006.0 11013.5 11021.0 11032.5 11036.5 11049.0 11049.5 11051.0 11055.0 11064.5 11065.0 11066.5 11071.0 11080.0 11080.5 11098.0 11099.0 11099.5 11134.0 11134.5 11148.0 11148.5 11149.0 11159.0 11160.5 11162.5 11164.5 11167.5 11178.0 11178.5 11181.5 11182.0 11182.5 11185.0 11191.5 11195.0 11198.0 11202.5 11203.0 11206.5 11207.0 11211.0 11215.0 11215.5 11226.5 11229.0 11231.0 11231.5 10933.0 10940.5 10958.5 10992.5 11005.5 11134.0 11148.0 11167.5 11180.5 11198.0 11206.0 11210.0 11215.0 11006.5 11050.5 11066.5 11098.5 11135.0 11159.0 11181.0 11195.0 11210.0 11216.0 11232.5 10977.0 10980.0 10982.0 10983.5 10995.5 10998.5 11002.0 11013.0 11020.5 11033.0 11036.5 11048.5 11055.0 11065.0 11070.5 11080.5 11099.5 11133.5 11150.0 11161.5 11166.5 11178.5 11181.5 11185.5 11205.0 11207.0 11210.5 11215.0 11226.0 11229.5 11233.0 11033.0 11036.5 11047.5 11055.0 11065.0 11070.5 11078.0 11097.5 11133.0 11150.0 11161.5 11166.5 11184.5 11192.5 11205.0 11207.0 11210.5 11215.0 11226.0 11229.5 11233.0 11033.0 11036.5 11047.5 11055.0 11065.0 11070.5 11078.0 11097.5 11134.5 11149.5 11162.5 11180.0 11184.0 11192.5 11205.0 11207.0 11210.5 11215.0 11226.0 11229.5 11233.0 11234.5 11235.5 11240.0 11243.0 11245.0 11246.5 11247.0 11247.5 11249.5 11253.0 11255.5 11259.5 11264.5 11268.5 11269.0 11270.0 11272.5 11278.0 11278.5 11283.0 11294.5 11295.0 11302.5 11305.5 11307.5 11308.0 11315.5 11320.0 11320.5 11325.5 11326.5 11332.5 11333.0 11339.5 11347.5 11348.0 11351.0 11351.5 11352.0 11355.5 11356.0 11362.0 11364.5 11366.5 11382.0 11404.0 11436.0 11500.0 $ MERGED PBU GR DLL MLL DATA SOURCE TOOL CODE 11242.0 11279.0 11294.5 11305.5 11316.5 11321.0 11352.5 11403.5 11436.0 11500.0 RUN NO. 1 1 1 11240.0 11243.0 11246.5 11252.5 11270.5 11278.0 11295.5 11236.0 11236.0 11245.0 11247.5 11251.0 11254.5 11270.0 11272.0 11284.5 11295.0 11303.5 11306.5 11308.5 11320.0 11249.0 11260.5 11269.0 11273.0 11279.0 11284.5 11294.0 11307.5 11320.0 11334.0 11347.5 11352.0 11357.0 11361.5 11364.5 11325.5 11334.0 11347.5 11352.0 11357.0 11362.5 11365.5 11367.5 11236.5 11247.0 11250.5 11264.0 11269.0 11273.0 11279.0 11284.5 11294.0 11306.5 11323.5 11332.0 11339.0 11347.5 11356.0 11364.0 11366.0 11381.5 11500.0 11500.0 11500.0 11500.0 PASS NO. 4 4 3 MERGE TOP 10379.0 10397.0 10996.0 MERGE BASE 11466.0 11455.0 11378.0 GR BCS 2435 $ 3 10970.0 11021.0 11023.0 11380.0 11430.0 11386.0 REMARKS: MAIN PASS. MLL CURVE IS FROM AC/CN/MLL TOOL STRING. CALl CURVE IS FROM MLL TOOL USED IN DLL/MLL STRING. LLD, SP, CALl, MTEM, TEND, & TENS (from DLL String) WERE SHIFTED WITH LL3. "GRCN" REFERS TO GAMMA RAY RECORDED WITH AC/CN/MLL TOOL STRING. TEND & TENS (from AC/CN string) WERE SHIFTED WITH GRCN. FUCT & NUCT WERE SHIFTED WITH NPHI. CN WN FN COUN STAT /??MATCH1.OUT /??MATCH2.OUT /??MATCH3.OUT /??MATCH4.OUT /??MATCH5.OUT $ : ARCO ALASKA INCORPORATED : D.S. 4 - llA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GR DLL 68 1 GAPI 2 LL3 DLL 68 1 OHMM 3 LLD DLL 68 1 OHMM 4 MLL DLL 68 1 OHMM 5 CALl DLL 68 1 IN 6 SP DLL 68 1 MV 7 MTEM DLL 68 1 DEGF $ TEND DLL 68 1 LB 9 TENS DLL 68 1 LB 10 GR BCS 68 1 GAPI 11 DT BCS 68 1 US/F 12 TEND BCS 68 1 LB 13 TENS BCS 68 1 LB 14 NPHI 2435 68 1 PU-S 15 FUCT 2435 68 1 CPS 16 NUCT 2435 68 1 CPS Size 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD (TYPE# Total Data Records: 0) 958 BYTES * 161 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 20 789 90 0 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 98 211 23 1 4 98 211 23 1 4 98 211 23 1 64 Tape File Start Depth = 11500.000000 Tape File End Depth = 10379.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 38132 datums Tape Subfile: 2 428 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10352.0 10379.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: CASED HOLE portion of MAIN PASS (from DLL/MLL string). CN WN FN COUN STAT * FORMAT RECORD : ARCO ALASKA INCORPORATED : D.S. 4 - llA : PRUDHOE BAY : NORTH SLOPE : ALASKA (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units Size 1 GRCH GR 68 1 GAPI 4 2 TEND GR 68 1 LB 4 3 TENS GR 68 1 LB 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1 API API API API Log Crv Crv Length Typ Typ Cls Mod 4 21 990 60 6 4 10 579 41 1 4 10 579 41 1 12 Tape File Start Depth = 10379.000000 Tape File End Depth = 10348.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 253 datums 28 records... 62 bytes 1014 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 START DEPTH STOP DEPTH 10352.0 11477.0 10369.0 11466.0 10996.0 11378.0 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: 0. 2500 FILE SUMMARY VENDOR TOOL CODE GR DLL MLL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE CHT TEMP PCM MIS DLL GR MIS KNJT KNJT MLL $ TOOL TYPE CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB KNUCKLE JOINT KNUCKLE JOINT MICROLATEROLOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMI/M RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) 17-NOV-93 FSYS REV. J001 VER. 1.1 130 17-NOV-93 901 17-NOV-93 11510.0 11490.0 10379.0 11486.0 2100.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229EA/1229MA 1309XA 3967XA 3921NA 3921NA 1233XA 8.500 10392.0 10379.0 KCL/POLYMER 9.70 49.0 9.0 7.6 147.0 MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0. 112 0.056 0. 103 0.000 0.155 0.000 68.0 147.0 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 TOOL STANDOFF (IN): 2.0 REMARKS: DLL/MLL/GR MAIN PASS. MLL CURVE INCLUDED HERE WAS RECORDED WITH THE AC/CN/MLL TOOL STRING. CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 4 - llA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 2 RS DLL 68 1 OHMM 3 RD DLL 68 1 OHMM 4 ED DLL 68 1 MV 5 ES DLL 68 1 MV 6 ID DLL 68 1 A 7 IS DLL 68 1 A 8 SP DLL 68 1 MV 9 TEMP DLL 68 1 DEGF 10 CHT DLL 68 1 LB 11 TTEN DLL 68 1 LB 12 TEN DLL 68 1 LB 13 SPD DLL 68 1 F/MN 14 RMLL MLL 68 1 OHMM 15 CAL MLL 68 1 IN 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 71 857 46 1 4 90 132 02 1 60 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 308 Tape File Start Depth = 11500.000000 Tape File End Depth = 10348.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 111877 datums Tape Subfile: 4 389 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 START DEPTH STOP DEPTH 10970.0 11402.0 11020.0 11449.0 10976.0 11408.0 TOOL STRING NUMBER: 2 PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE GR AC 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE CHT TEMP GR CN PCM MLL KNJT KNJT AC $ TOOL TYPE CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR MICROLATEROLOG KNUCKLE JOINT KNUCKLE JOINT BHC-ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 17-NOV-93 FSYS REV. J001 VER. 1.1 130 17-NOV-93 1311 17-NOV-93 11510.0 11450.0 11000.0 11430.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 1233XA 3921NA 3921NA 1609EB/1603MA 8.500 10392.0 10379.0 KCL/POLYMER 9.70 49.0 9.0 7.6 151.0 0. 112 68.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0.053 0.103 0.000 0.155 0.000 151.0 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 8.50O TOOL STANDOFF (IN): 0.0 REMARKS: AC/CN/MLL MAIN PASS. MLL DATA RECORDED FROM THIS STRING IS PRESENTED WITH THE DLL DATA. CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 4 - llA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 CHT AC 68 1 LB 4 4 TTEN AC 68 1 LB 4 5 SPD AC 68 1 F/MN 4 6 CNC 2435 68 1 PU-S 4 7 CNCF 2435 68 1 PU-S 4 8 CN 2435 68 1 PU-L 4 9 LSN 2435 68 1 CPS 4 10 SSN 2435 68 1 CPS 4 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 40 * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 87 Tape File Start Depth = 11450.000000 Tape File End Depth = 10954.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 22089 datums Tape Subfile: 5 167 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE GR DLL MLL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): START DEPTH STOP DEPTH 10964.0 11372.0 10952.0 11372.0 11010.0 11371.0 17-NOV-93 FSYS REV. J001 VER. 1.1 130 17-NOV-93 836 17-NOV-93 11510.0 11490.0 10379.0 11486.0 2700.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE CHT TEMP PCM MIS DLL GR MIS KNJT KNJT MLL $ TOOL TYPE CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB KNUCKLE JOINT KNUCKLE JOINT MICROLATEROLOG TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229EA/1229MA 1309XA 3967XA 3921NA 3921NA 1233XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 8.500 10392.0 10379.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): KCL/POLYMER 9.70 49.0 9.0 7.6 147.0 0.112 0.056 68.0 147.0 MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0.103 0.000 0.155 0.000 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 TOOL STANDOFF (IN): 2.0 REMARKS: DLL/MLL/GR REPEAT PASS. MLL CURVE INCLUDED HERE WAS RECORDED WITH THE AC/CN/MLL TOOL STRING. $ CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 4 - llA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 15 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR DLL 68 1 GAPI 4 2 RS DLL 68 1 OHMM 4 3 RD DLL 68 1 OHMM 4 4 ED DLL 68 1 MV 4 5 ES DLL 68 1 MV 4 6 ID DLL 68 1 A 4 7 IS DLL 68 1 A 4 8 SP DLL 68 1 MV 4 9 TEMP DLL 68 1 DEGF 4 10 CHT DLL 68 1 LB 4 11 TTEN DLL 68 1 LB 4 12 TEN DLL 68 1 LB 4 13 SPD DLL 68 1 F/MN 4 14 RMLL MLL 68 1 OHMM 4 15 CAL MLL 68 1 IN 4 4 57 515 01 6 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 4 46 103 82 1 4 46 103 82 1 4 46 103 82 1 4 11 639 82 1 4 71 857 46 1 4 90 132 02 1 6O * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 114 Tape File Start Depth = 11372.000000 Tape File End Depth = 10948.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 139030 datums Tape Subfile: 6 193 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR 1 2 5 0.2500 AC 2435 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): START DEPTH 11000.0 11000.0 11000.0 TOOL STRING (TOP TO BOTTOM) TOOL TYPE CABLEHEAD TENSION TEMPERATURE GAMMA RAY COMPENSATED NEUTRON PULSE CODE MODULATOR MI CROLATEROLOG KNUCKLE JOINT KNUCKLE JOINT BHC-ACOUSTILOG VENDOR TOOL CODE CHT TEMP GR CN PCM MLL KNJT KNJT AC $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: F .U D ,oss (c3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): STOP DEPTH 11402.0 11449.0 11408.0 17-NOV-93 FSYS REV. J001 VER. 1.1 130 17-NOV-93 1421 17-NOV-93 11510.0 11450.0 11000.0 11430.0 1500.0 TOOL NUMBER 3974XA 2806XA 1309XA 2435XA 3506XA 1233XA 3921NA 3921NA 1609EB/1603MA 8.500 10392.0 10379.0 KCL/POLYMER 9.70 49.0 9.0 7.6 151.0 0. 112 68.0 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: 0.053 0.103 0.000 0.155 0.000 151.0 68.0 0.0 68.0 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMALOR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 0.00 8.500 TOOL STANDOFF (IN): 0.0 REMARKS: AC/CN/MLL REPEAT PASS. MLL DATA RECORDED FROM THIS STRING IS PRESENTED WITH THE DLL DATA. CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 4 - llA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 10 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 2 AC AC 68 1 US/F 3 CHT AC 68 1 LB 4 TTEN AC 68 1 LB 5 SPD AC 68 1 F/MN 6 CNC 2435 68 1 PU-S 7 CNCF 2435 68 1 PU-S 8 CN 2435 68 1 PU-L 9 LSN 2435 68 1 CPS 10 SSN 2435 68 1 CPS 4 4 4 4 4 4 4 4 4 4 4 06 969 49 6 4 48 852 89 1 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 98 211 23 1 4 98 211 23 1 4 52 326 75 5 4 84 023 70 1 4 83 368 34 1 4O * DATA RECORD (TYPE# 0) 1018 BYTES * Total Data Records: 80 Tape File Start Depth = 11450.000000 · ap~ File End Dep%h = 10994.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 42165 datums Tape Subfile: 7 160 records... Minimum record length: 62 bytes Maximum record length: 1018 bytes Tape Subfile 8 is type: LIS 93/12/ 1 01 **** REEL TRAILER **** 93/12/ 2 01 Tape Subfile: 8 Minimum record length: Maximum record length: End of execution: Thu 2 records... 132 bytes 132 bytes 2 DEC 93 8:38p Elapsed execution time = 36.85 seconds. SYSTEM RETURN CODE = 0
