Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
199-053
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: PWI S-11B (PTD 199053), WAG S-123 (PTD 204137) potential pressure interaction investigation Date:Tuesday, September 30, 2025 11:50:16 AM Attachments:S-11B S-123 TIO and Inj plots 250930.docx S-11B (PTD 1990530) S-123 (PTD 2041370) From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Tuesday, September 30, 2025 11:40 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: PWI S-11B (PTD 199053), WAG S-123 (PTD 204137) potential pressure interaction investigation Mr. Wallace, On 9/29/25, increasing IA pressure was noted in Not Operable PWI well S-11B (PTD 199053). The IA pressure was bled from 1470 psi to 600 psi in 15 minutes with 5 bbls of fluid returned. Based on the known production casing leak depth in S-11B at 7076' MD (6754’ TVD), offset Kuparuk injection wells in close proximity were reviewed as the potential pressure source. WAG injector S-123 (204137) was identified as the likely source of the resultant pressure increase in the S-11B IA and injection into S-123 was shut-in late on 9/29/25. We are currently monitoring the IA pressure in S-11B to see if there is a corresponding drop in pressure due to ceasing injection into S-123. Please respond with any questions. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 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. S-11B TIO Plot: S-123 TIO and Inj plot: Regg, James B (OGC) From: Brooks, Phoebe L (OGC) Sent: Friday, February 14, 2025 1:58 PM To: PB Wells Integrity Cc: Regg, James B (OGC) Subject: RE: Hilcorp (PBU) January 2025 MIT Forms Attachments: MIT PBU 11-26 01-18-25 Revised.xlsx; MIT PBU S-11B 01-17-25 Revised.xlsx Follow Up Flag: Follow up Flag Status: Completed Hi Ryan, Attached are revised reports as follows: • MIT PBU 11-26 01-18-25 — revised the packer TVD to reflect 8146' • MIT PBU S-11B 01-17-25 — revised the packer TVD to reflect 8439' Please update your copy or let me know if you disagree. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone:907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). it may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you., contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: PB Wells Integrity <PBWellslntegrity@hilcorp.com> Sent: Sunday, February 2, 2025 12:23 PM To: Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Hilcorp (PBU) January 2025 MIT Forms 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. Attached are the completed MIT forms forthe tests completed in January 2025 by Hilcorp North Slope, LLC. Well: I PTD Notes 01-12A 12230900 MIT-T reservoir abandonment per Sundry #324-596 03-13 1790710 2-year MIT -IA per AA AIO 4E.016 04-25 1860490 4-year MIT -IA 11-26 1861340 4-year MIT -IA 13-24B 2240870 MIT-T per Sundry #324-589 16-02 1801500 2-year MIT -IA per AA AIO 4E.014 C-37B 2101000 2-year MIT-T & CMIT-TxIA per CO736 M-207 2241410 MIT -IA post initial injection S-11 B 1990530 MIT -IA not witnessed / under evaluation diagnostics S-107 2011130 2-year MIT -IA per AA AIO 22F.001 W-220 2101260 MIT-T & CMIT-TxIA cement plug for reservoir abandonment per Sundry #324-660 Please respond with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Rvan.Holt Hilcoro.com P: (907) 659-5102 M: (907) 232-1005 The information contained in this email message is confidential and maybe legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or h 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 onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: 'im. mggAalaskaaov'. OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test AOGCC InspeCloreAalaska.00y, phoebe brooks0alaska goy Hilcorp North Slope LLC Prudhoee Bay / PBU / S-Pad chds wallace*alaska.00v Well 5.1113 ' Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1990530 Typelnj N Tubing 0 0 0 Type Test P Packer ND 1439 BBLPump 1.8 IA 1211 2000 1596 Interval 0 Test psi 2110 " BBL Return 1 1.0 OA 3 3 3 Result F Notes: Not Witnessed. Caine MIT -IA for Diagnostics. Well is Under Evaluation for high IA prassure. Lost 10%in 15 minutes. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 6O Min, PTD Type Inj Tubing Type Test Packer ND BBLPump IA Interval Test psi I BBL etuml I OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer ND BBLPump IA Interval Test psi EEL Return OA Result Notes: Wall Pressures. Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Typelnj Tubing Type Teel Packer ND BBLPump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min, 60 Min. PTD Type Inj Tubing Type Tesl Packer ND BBLPump IA Interval Test psi 1381 Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTO Typelnj Tubing Type Test PackarND BBLPump IA I marvel Test psi BBL Return OA Result Nobs: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type T. Packer ND BBLPump IA Interval Test psi BELL Return OA Result Note.: Well Pressures: Pretest Initial 15 Min 30 Min. 45 Min. 60 Min. PTO Type Inj Tubing Type Test Packer ND BBLPump IA Interval Test psi BBL Return OA Result Notts: TYPE INJ Cedes W=wrier G=Gee 6=Slurry I=l CustrO wasusverer N=Net llovin0 TYPE TEST Codes INTERVAL Codes P=Pressure TM 1=Initial Test 0= 00er ldescei. In Nolon 4=Four Year Cycle V = RepueW Ey Valiance o = alas, (doembe'n nevi.) Result Cod. P=Pau F=Fail Form 10426 (Revised 0112017) MIT PBU S-11B e1-17-25 Revase 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: NOT OPERABLE: Injector S-11B (PTD #1990530) Secured with TTP Date:Tuesday, February 4, 2025 4:00:07 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, February 4, 2025 3:46 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector S-11B (PTD #1990530) Secured with TTP Mr. Wallace, Injector S-11B (PTD #1990530) failed an MIT-IA while the well was shut in on 01/17/25. A tubing plug has been set and verified tubing integrity with passing MIT-T on 02/03/25. The well then failed a CMIT-TxIA which indicates loss of integrity in the casing and / or packer. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. 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 Sent: Thursday, January 16, 2025 12:42 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector S-11B (PTD #1990530) anomalous IA bleed Mr. Wallace, Injector S-11B (PTD #1990530) had a bleed performed on 01/16/25. The IA pressure was bled from 1,270 psi to 690 psi. After the bleed, the IA pressure increased 480 psi up to 1,170 psi in a 30 minute period. The tubing pressure remained @ 440 psi during the entire process. The well will now be classified as UNDER EVALUATION for up to 28-days to diagnose the anomalous bleed. Plan forward: 1. Operations: Shut-in well 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed 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 the individual 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 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. 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 S-11B (PTD #1990530) anomalous IA bleed Date:Thursday, January 16, 2025 4:34:57 PM Attachments:S-11B.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, January 16, 2025 12:42 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector S-11B (PTD #1990530) anomalous IA bleed Mr. Wallace, Injector S-11B (PTD #1990530) had a bleed performed on 01/16/25. The IA pressure was bled from 1,270 psi to 690 psi. After the bleed, the IA pressure increased 480 psi up to 1,170 psi in a 30 minute period. The tubing pressure remained @ 440 psi during the entire process. The well will now be classified as UNDER EVALUATION for up to 28-days to diagnose the anomalous bleed. Plan forward: 1. Operations: Shut-in well 2. Fullbore: Offline MIT-IA 3. Well Integrity: Additional diagnostics as needed 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, 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 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. wMesn no rMe +TW, on ■ ■eea ♦ OO + "xapv ♦ ...IErel M f en.lA Mm.00A � Men.000A p Men.WXI TREE= 4-1/16" CIW WELLHEAD= MsEVOY ACTUATOR = BAKER OKB. E -EV = 67.8' BF. E LEV = 39.4' KOP= 3603' Max Angle = 115" @ 1005V Datum MD = 9809, Datum TVD= 8800'SS 19-5/8" DV PKR —L 2605 13-318" CSG, 729, N-80, D = 12.347" 267W Minimum ID = 2.310"@ 8836' - 8859' BKR STRADDLE PKR w/SLD SLV TUBING PUNCH (01/06/08) �. TOP OF 4-1/2"LNR I— 8964' TBG, 12.60, L-80.0'152 bpf, D = 3.958" — 8964' 9-5/8" CSG, 47#, N-90, D = 8.s81" 9136' ' LNR 26#, L-80, .0383 bpf, ID = 6.276" 913W 7" WHPSTOCK 9138' PERFORATION SIA MRY REF LOG: ON XXbD(= ANGLEATTOPPE RR 80" Q 10430' Note: Refer to Production DB for historical pert data SEE SPF INTERVAL Opn/Sgz I SHOT I SQZ 2-718" 1 4 1 10430 - 104801 O JO&OD99 2-7/8" 4 10495 - 105651 O 1081021991 7" LNR 26#, L-80, .0371 bpf, D = 6.184" 11 110004' S-11 B 2182- 114-1/2"HES X NP, ID=3.813" 8627' H 9-5/8- X 7- BKR HGR 835' - 8859' 14-12" BKR STRADDLE PKR w / CMU SLD SLV, D = 2.31" (I 8892' 4-1/2- HES X NP, D = 3.813" 8902' 7" X 4/12" BKR 9-3 PKR, D = 3.875" A99� 4-12"HFS x NP n=3 ai-7 1 8947- —14-1/2- HES XN NP, D = 3.725" 1 8947' 4-1/2" x 2-7/8" NP REDUCER, D = 2.313" 8964' 9-5/8" x 7" BKR LTP, ID = _" 8969' 4-12" W/LEG, D= 3.958" 8969' ELMD TT LOG ON XXDOM MILLMMVIANDOW (S-11B) 9138'-9151' PBTD 10682' 4-1/2" LNR 12.6#, L-80 MOD, .0152 bpf, D = 3.958" 1077W DATE REV BY COMMENTS DATE REV BY COMMENTS 06/16182 INITIAL COMPLETION 07/14/16 KDP/JMD TREE C/O (07/02116) 12/14198 SIDETRACK 541 10/12117 BOMMD MINOR WBS CLEAN UP 08/08199 NIIES SIDETRACK S41B 1227/17 ZV/JMD SET XX PLUG(1224/17) 62JI0115 JMGUMD PULL CHOKE (02107/15) 07117/18 GJB/JMD PULLED XX PLUG (0627/18) 0222M6 CJN/JMD SET PX PLUG (022V76) 07/12/16 JG/JMD PULLED PLUG 07A74/16 TD H 10771' 1 PRUDHOE BAY UNIT WELL: S-11B PERMT No: 1990530 API No: 50-029-20728-02 T12N, T12E, 164V FNL 8 185° HElcorp North Slope, LLC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-11B PRUDHOE BAY UNIT S-11B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/15/2024 S-11B 50-029-20728-02-00 199-053-0 W SPT 8439 1990530 2200 218 218 234 223 15 51 50 50 REQVAR P Brian Bixby 7/6/2024 MITIA as per AIO 3B.008 to MAIP. 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 S-11B Inspection Date: Tubing OA Packer Depth 190 2449 2383 2360IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB240707132001 BBL Pumped:10 BBL Returned:4.9 Thursday, August 15, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 99 99 9 9 9 9 AIO 3B.008 James B. Regg Digitally signed by James B. Regg Date: 2024.08.16 15:13:48 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-11B PRUDHOE BAY UNIT S-11B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 S-11B 50-029-20728-02-00 199-053-0 W SPT 8439 1990530 2110 333 337 333 334 241 373 373 372 REQVAR P Brian Bixby 7/3/2022 MITIA as per AIO 3B.008 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 S-11B Inspection Date: Tubing OA Packer Depth 281 2216 2153 2132IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220704092441 BBL Pumped:9.7 BBL Returned:7.6 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 AIO 3B.008 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 14:25:48 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor % FROM: Jeff Jones Petroleum Inspector Well Name PRUDHOE BAY UNITS- I I B Insp Num: mitJJ200720110512 Rel Insp Num: NON -CONFIDENTIAL State of Alaska .Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 19, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC S-1 1B PRUDHOE BAY UNIT S-1 I B Src: Inspector Reviewed By: P.1. Supry Comm API Well Number 50-029-20728-02-00 Inspector Name: Jeff Jones Permit Number: 199-053-0 Inspection Date: 7/3/2020 Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 157 163 _ 167 160 IA 628 2000. 1946 - 1930 OA 338 432 437 440 - Wednesday, August 19, 2020 Page 1 of I Packer Depth Well S -11B Type Inj W ,TVD 8439 _ PTD 1990530 Type Test SPT Test psi 2110 BBL Pumped: 6 BBL Returned: Interval REQVAR P/F P Notes: 2 year MIT per AIO 313.008 to MAIP (1800) Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 157 163 _ 167 160 IA 628 2000. 1946 - 1930 OA 338 432 437 440 - Wednesday, August 19, 2020 Page 1 of I • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, November 14, 2017 11:56 AM To: AK,OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W; AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Frankenburg, Amy;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Tempel,Joshua; Worthington,Aras J; Regg,James B (DOA) Subject: NOT OPERABLE: Injector S-11 (PTD# 1990530) IA x OA communication confirmed All, WAG Injector S-11 (PTD#1990530)was put under evaluation to diagnose possible inner annulus by outer annulus communication.Slickline set a tubing tail plug and performed a passing MIT-IA. However,during follow up monitors it was discovered that when the well is offline and gas is present in the inner annulus,the outer annulus experienced repressurization.This well is now classified as NOT OPERABLE and will remain shut in. Plan forward: 1. Fullbore—Load Tubing 2. Slickline—Secure well with tubing tail plug 3. Anchorage Engineer—Evaluate repair Please respond if in conflict Andrew Ogg SCANNED Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 From: AK, • Well Integrity Engineer Sent: Tuesday, 0 •:- 17, 2017 12:33 PM To: AK, OPS GC2 Facility • OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; , •'S WELL PAD S; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells •• ngr; Bergene, Matthew; 'Regg,'James B (DOA) (jim.regg@alaska.gov)' Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integri OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; - , ski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Worthingto -s 3; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Injector S-11 (PTD# 1990530) Possible Anomalous I :ehavior All, 1 • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, November 14, 2017 9:00 AM To: 'AK, GWO Well Integrity Engineer' Cc: Regg,James B (DOA);AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information Subject: RE: Injector S-11 (PTD# 1990530)Anomalous IAxOA Communication Andrew, Our database indicates the well was converted to WAG injector via sundry 314-427 and has most recently been on gas injection. It would seem an AA is appropriate now IAxOA is confirmed. Even if conditions are unique/specific and manageable. I do not see any detail on possible repair scenarios and why they are not being pursued? If water only is requested, monitoring and testing would be minimal. If WAG is requested,a detailed explanation of EOR WAG benefits to surrounding producers is required. Justifications on benefits of this well to the recovery rather than using another more competent well is required. For a WAG well,additional monitoring and testing requirements should be considered to account for additional risks associated with higher pressures. Thanks and Regards, Chris Wallace,Sr. Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501, (907)793-1250(phone),(907)276-7542(fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From:AK,GWO Well Integrity Engineer[mailto:AKGWOWellSiteEnginee@bp.com] Sent: Monday, November 13,2017 3:42 PM To:Wallace, Chris D (DOA)<chris.wallace@alaska.gov> Cc: Regg,James B (DOA)<jim.regg@alaska.gov>;AK,GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK,GWO Well Integrity Well Information<akgwowellintegritywe@bp.com> Subject: Injector S-11 (PTD#1990530)Anomalous IAxOA Communication Mr.Wallace, SCANNED _ v Injector S-11 (PTD#1990530)was put under evaluation on 10/17/17 for having possible IA x OA communication. According to the pressure plot below the inner annuls and outer annulus pressures would equalize when the well was shut in and allowed to cool off.The diagnostic work consisted of setting a tubing tail plug and after that we were able to perform a passing MIT-T to 2250 psi and a passing MIT-IA to 3000 psi. While holding a >600psi differential between the inner and outer annulus,follow up monitors did not indicate any communication between the IA and OA in a fluid packed system.Trying to recreate the leak scenario,with the well still shut in, a gas cap was applied to the inner annulus and the well underwent another monitoring period.This monitoring period confirmed that the well does in fact exhibit IA x OA communication when it is offline,cold and gas is present in the inner annulus.The outer annulus build-up rate during this period was 40 psi/day. 1 • Due to the unique circumstances required for the well to exhibit annular communication, BP would like to know if the state will require Administrative Approval for the well to remain online and operational. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 Cell:307-399-3816 From: AK, GWO Well Integrity Engineer Sent: Tuesday, October 17, 2017 12:33 PM To: AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS WELL PAD S; AK, OPS Well Pad SW; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Bergene, Matthew; 'Regg, James B (DOA) (jim.reggt alaska.gov)' Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Worthington, Aras J; 'chris.wallace@alaska.gov' Subject: UNDER EVALUATION: Injector S-11 (PTD# 1990530) Possible Anomalous IAxOA Behavior All, Water Injector S-11(PTD# 1990530) began exhibiting possible anomalous inner by outer annulus behavior after a nitrogen cap was inserted into the inner annulus. The well has been reclassified as Under Evaluation to progress further diagnostics. Plan Forward: Evaluate Possible IAxOA Communication 1. Slickline: Set Tubing tail plug& perform CMIT 2. WIE: Additional diagnostics Recent TIO and Injection plots have been included for reference. Thanks, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 2 • • • 4.000 - 3.500 - mil • 3.000- 2.000 - 1.500 - 500 ir+ 1 1017116 10:31116 1111416 1128/16 12'12`16 12126116 01/09/17 01123117 02%17 02120117 03/06/17 0320117 2,500- ihkiliii 2.000 - a- 1,500- 1.000 - 500- 10'17116 1 Y3116 1111416 11:2&/16 12112116 12126/16 01109117 0123117 02/06117 022{:x'17 03'06117 0321 3 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, October 17, 2017 12:33 PM To: AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS WELL PAD S; AK, OPS Well Pad SW;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; Bergene, Matthew; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Injector S-11 (PTD# 1990530) Possible Anomalous IAxOA Behavior All, Water Injector S-11 (PTD#1990530) began exhibiting possible anomalous inner by outer annulus behavior after a nitrogen cap was inserted into the inner annulus. The well has been reclassified as Under Evaluation to progress further diagnostics. Plan Forward: Evaluate Possible IAxOA Communication 1. Slickline:Set Tubing tail plug& perform CMIT 2. WIE: Additional diagnostics Recent TIO and Injection plots have been included for reference. Thanks, Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 SCANNED _.EB 2 1 u 1 S Cell 907-980-0552 Harmony 4530 1 Pi3Lt 5-. 118 Regg, James B (DOA) F Iii 4S 30 From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>. Sent: Tuesday,July 11, 2017 2:32 PM '7 ' 71Z-117To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay f? Cc: AK, GWO SUPT Well Integrity;AK, RES GPB West Wells Opt Engr;AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; Daniel, Ryan; Fueg, Esther M; Bergene, Matthew; Ohms, Danielle H; Cocklan-vendl, Mary E;AK, OPS FF Well Ops Comp Rep Subject: RE: Notification Regarding Well S-11: Operate Well with Defeated SVS (PTD#1990530) Mr. Regg `3-It 3 This note is to inform you that well S-11 (PTD#1990530) is no longer on low pressure PWI injection due to the recent well conversion to MI injection. The LPP has been returned to normal status with this WAG swap to MI. Please contact me if you have questions on this notice. Regards, Lee Hulme Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony— 7187 ( ,F 5 9017'(Alternate: Vince Pokryfki) SUMO From: Cocklan-vendl, Mary E Sent: Thursday, June 01, 2017 3:06 PM To: Regg, James B (DOA) Cc: AK, GWO SUPT Well Integrity; AK, RES GPB West Wells Opt Engr; AK, e'S Pipeline Compl Specialist; AK, OPS FF Well Ops Comp Rep; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M IL; AK, OP. GC2 Wellpad Lead; Daniel, Ryan; Fueg, Esther M; Bergene, Matthew; Ohms, Danielle H Subject: Notification Regarding Well S-11: Operate Well with D: -ated SVS (PTD #1990530) Jim, Per AOGCC waiver dated March 11, 2013, PBU Oi 'ool Low Pressure Water Injectors (attached), BPXA is providing notification that well S-11 (PTD 1990530) will •- operating with the SVS defeated with a well pressure of<250 psi. Attached is the S-11 Injectivity Plot fo eference. SSV hydraulic controls will be bypassed and the SSV will be operated manually on this PWI well. T - well is equipped with a SSSV that has been tested twice since it was installed in July of last year, passing both times This well was put on water in.-ction (PWI)Tuesday night in preparation for shutting in and pigging the produced water lines going to S& M Pads. ere was not enough back pressure to keep the LPP satisfied without over-injecting on the desired rate of 2000-25s i psi. Pigging of the PW lines going to S& M Pads are planned for next week—June 7th or 8th The plan is to c. tinue injecting water in S-11, post pigging, while the MI lateral line is being repaired. MI line repair is slated to wrap up in July, but any delays may push that into August. After the MI line repair, S-11 will be put back into MI service. 1 Pews-03 16190 0 Regg, James B (DOA) From: Cocklan-vendl, Mary E <mary.cocklan-vendl@bp.com> Sent: Thursday, June 15, 2017 11:52 AMc'" (,1!5'0-7 � To: Regg,James B (DOA) fl Cc: AK, OPS FF Well Ops Comp Rep; Daniel, Ryan Subject: FW: S-11 Flow vs Pressure profile Hi Jim, Below is the Injection Pressure/Injection Rate plot for S-11 through June 8, 2017 when the well was shut-in. I expect that there might have been a data input error for the injection rate for June 5th and the rate should have been closer to 956 bbls, but have not confirmed that. I will be able to provide subsequent plots when the well returns to service if you would like. In the meantime, we will continue to operate the well under the waiver once it returns to water injection service. Please let me know if you have any additional questions. Thanks, Mary Mary E Cocklan-Vendl Pipeline Team Lead Office Phone-Anchorage: 907-564-4766 Office Phone—North Slope: 907-670-7550 Cell Phone: 907-227-3464 e-mail: Mary.Cocklan-Vendkabp.com From:AK, OPS FF Well Ops Comp Rep Sent: Friday,June 9, 2017 1:14 PM To: Cocklan-vendl, Mary E<mary.cocklan-vendl@bp.com> Cc:AK, OPS FF Well Ops Comp Rep<AKOPSFFWellOpsCompRep@bp.com> Subject: 5-11 Flow vs Pressure profile Mary, Here is the data from DWF prod/inj plotted. Let me know if you need anything else. 1 PB k.5-.--t 15 (FM >,ct9os ter) s-ii WHIP In)Vol S-11 injection/Pressure 6/8/2017 1 0 6/7/2017 113 188 12000 1400 6/6/2017 137 0 1200 locxo 6/5/2017 137 9658 B 1C4G 6/4/2017 138 863 1 8000 - 6/3/2017 119 855 « SOC E 6/2/2017 134 1717 a 6000 600 = 611/2017 1147 789 .fats 4000 - - A ------ ........s-11{nj Vol 5/31/2017 415 6184 ( 400 —S-11 WHIP 2000 - - AIPPF 200 1111111101% 0 i______ 0 1 1 1 1 1 1 1 h 1 c1,0 Date Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907) 354-1352 Harmony-7187 Alternate:Lee Hulme 2 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMIN REPORT OF SUNDRY WELL OPERATIS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Convert to WAG I$ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 199-053 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service Ed 6. API Number: 50-029-20728-02-00 7. Property Designation(Lease Number): ADL 0028257 8. Well Name and Number: PBU S-11 B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL RECEIVED 11.Present Well Condition Summary: 2 9 C Total Depth: measured 10771 feet Plugs measured feet N O V 2016 true vertical 8839 feet Junk measured feet Effective Depth: measured 10682 feet Packer measured 8907 feet AOGCC /� true vertical 8823 feet Packer true vertical 8396.8 feet ��// V Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2647 13-3/8"72#L-80 30-2677 30-2676 4930 2670 Intermediate 9106 9-5/8"47#L-80 29-9134 29-8605 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10430-10480 feet 10495-10565 feet True vertical depth: 8771-8780 feet feet 8783-8799 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 26-8963 26-8448 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSV 2182 2182 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED APR 1 12.011; 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2941 400 205 Subsequent to operation: 13244 100 2467 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Er Exploratory ❑ Development 0 Service ® Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 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: 314-427 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signaturead 041 ` Phone +1 907 564 4424 Date 11/28/16 Form 10-404 Revised 5/2015 V It/ t--- ,3/ v/v 1 LT ,T,�.V 7 RBDMS 0/ DEC - 6 2016 Submit Original Only • NQ 00000 C11 (r8 O O N- v LO u) C N U N O o 0 0 0 L M i� M O) 00 N V NI- ca O I-- 00 CO N CO CO N O CO CO CO CO CO -zt' N 00 co O 00 1 1 1 1 1 1 H N O O V V O COCON ,-- NrN CO CO 4-0 I� ( O N O) 0) C) CO V • CO a N O 6) N LO CO CD I CO CO N O O) N _ O CO .12 O O O O 00 00 OO O J J d N *k J co • X - ( Cl) r N co E0 (N U M O N N (i) i O i t 4-' N- O CO N- O O C COO - CO 0) d N O O i- CO J W CC ~ of O — C F-- W • UUW N U O cc u Q CY Z O D Z Z D (n Z J J • • Packers and SSV's Attachment PBU S-11 B SW Name Type MD TVD Depscription S-11B SSSV 2182 2181.65 4-1/2" MCX I-SSV S-11 B TBG PACKER 8907.2 8396.8 4-1/2" Baker S-3 Hydro Set Packer S-11B PACKER 8958.57 8443.52 5" Baker ZXP Top Packer • 0 o -0 •. o rri N • o•N Q- CO Na) L O U)) O L rn L N 0 a) (� O �° RS rn a) N 0 a) 2 c W O a. C .� a) o O Q p J Q O C "'I Q- a) ate' LCf, t .LO •C IL t0 W O V) O ° e O Q Q O •N ° C "C. as rn a) = O °) Q Q Q. O E O a) a) L . -° m C -i ° 0 r t. E ---I C . Q • C 06 Q N Q 00 "d 2 -- N LL J rn N ID p o f Z E mu) I fl O 8 c m W Q a) . Q -p Z L O E co � a) p Q O O r Q Et o ON rn T o o V Z ° E ° N 13 oo > e U t m ° O 3 C 0 L _N C ti a o N m > C > a > - Q D 3 ° I1 .0 caw o > cu o 0 0 C a) . -a > o CU73 p > CI) U)V) L p } m o °� ° o > 0) Z Q CO o ° (0 > co ic' - ami cou mv °usQ in W ) U N ea _ b mL E N N 0d .mo N 5 > L 'm d C W e- , > � o -F � ma)a- Q N a Oo 0 a) a) � m $ E- o o miCoZQ 0 coQ Qo O QoN �> n • 0 �� N r _ ) J J7a O O _ LOdr N Q . ( O O V) C0)OQ -OQCF- oH .,W , om C II o E (Ts + Oa QaN •E OOJU o �o Qo Qao iiE . � ° rn © YCD 1Q °5N mo13 a) o2 is g ) �a v) � Q omUQy- Ow2 v) jm H0I- � S m $ Q ° d . o - a E . •� � °-° O a°) N aa) a°i Eiv0 Q' oW * ° (nF' pU . m G () < 0O I�� (7) 0- 0)Q c o Om O m 1:3u : o) Hw -OW ~tt Q * -c .in CI II II II OD N cU - _ .0 Il . le L > Q * c i OD Q * O J (� a * vJ CC od Q-> aai ac') .C > (7) C') > n OJ ° W °6‹ u- w -� ea �, E n aE) 2cr m E � � QNa > � � I- pm O � 06 o > H > oJa > 'aW j Q-O o = " EzwOCC , oHcn Nm po � � n (nom Ii = Eg oiu) E05lo > CCwJF- W1ncn5 = F- \ ° m 1- • N > c Nc F- C vwH Q °) � 2QUQ > i- 0-- DaNOcimJ 000) 0 -0 CO O - > O c6 � � � _C �Zinm0QNC W NF- N `'U) O II M652D O 0_ C � -0 > a) I� CL>_ V) ONa W I-- 0Z 0 N > �) N CO O ciLL � � N II rn � `- a) u) C- N � � � c > mZ O Q \ O Q co y O "6 Q m __ W J O r- (0u ; • • a Q_ co in Q 0 a 0 Q & 10 m Q a C N _c v t m 05 @a as -rn c`o 3ein 73 � N C C O J O C N • y= . • O ,6 O 'E Q_ LL '- J O N J V Q N t) U O O Q O u LL L N O rn --I •° E N E ¢ N � g � -47... � O D `- fn C a) 'ff C O � . I` N tl0) 03 _C N : tt O N co a 5 M II T ' N L W O _� c. C co a E N a In C U > C U C O a T (p N O o Z o � C O 0) Q 2 CO Q O 0 N 8-a N N a � a Q_- J � > 70 < o o Q ' CO N Q U 2 _J rn N = U ❑ io p O O J W fY > O (Na) O a C U C 206 t4 N V- O (n fxL mN E o to E > m . >D 'C cn N r N C d > (o N W a`) a m (coo -Q 0 > Q 1-D, > � n > NLnN 'o co- o w 13 0 M . O N Q v-).- Q -Q a O C Q 0S D Z i N C N N O = N O U N tr, a) � i ami N c _c cu Z _ _ _ L Cn *� ill N Q Q N Q Q O N d N N N CL _1 Z ❑ ❑ L O C O Q O p L o Q � `� O '- N O C _ w Q N ❑ 2w m - II O - MO � c .. Q a"aa 0 _ m O J �_ D J a cn > O Q N- O a ,.. O 'p N ¢ O O r- 'O OW � F- (nom LL___ Q O OQ- V2 D06 _Qt a O ¢ uNi � (� N E 03 __I -I 0NZ O •`� F o •Za < 13N. NF0-- Q ai , I- < 92 a E 0 O o � Omc4,1 �i iv ao0 oQu- 2 mN •_c � 2 � -45.cNO m 0 oQ -0 c oo 0II .0 m QJIYz CNI& ,_ 2 ❑ N * • c _o 0 : aim Q-aQmD E II oa a) Q O a , m _ � ❑ -loo* �, Q X * ter .— 0 Q ° Qo N-. .-- 0 a cOUQ .0 o 0 Q * O OF- � fY * L.L. a O � N Q ON 0c`lL0 II ° Q o . Q 0) N 06 cl) farnm ❑ ON ,_ CAftW � r` � � o '� N- II cnQcc\10c)_ (0cS c Q re oD w 2 N fn Y Q ch co II " Q Q II > II •� a •� M N •N O >, � Qz > cnao(� � �SQ > � N 0-- oo Q_..-: 2 Q_ Q_2Q a O_ rn0 ' Q_ E .E O � �, a ,J \ �n2 � E " � o0 E o, Eos a QN .c If ° co 6 0 co \ � O ❑ m0 (no � Ua b O Na N u N c > No - > E � QD m - II 0 ❑ _ mF- (n � Q O � Q Op > F- � 0) . O N N > N > NO3 j aoow -IZc� -W' z co�I 0 N ami ami � 2 � > •LL. ~ C ❑ IFN- CONQ 2 `- (nUQ200 ' No > - . M ,F . (nen Q > 0) 4-, NNj O FF- a' N ❑ 2 0 a O C 865 (o W (n p cA a. co N U L co _C (n ❑ Q- aW U ❑ COm Z = ~ C co N N CO ci (0 : O. cp .0 N .0 E N c.;- CO o p � �) o -1CCr I w o cN) c � o � No -0 ,- oa ` 6- a cNoo ZOcow ❑ r-• � I- I- OJ I- � wN 'Ca2> N -0 o � (I) -o _1° c r- ¢ Q � . OZZ � a � N00 -1w wC 5 II cin — • a (nU II m ACU ❑ vy ai : aQi II II *� Q Q Q (I) ZZ U U J a ' T O m c as If Q a) n Q W o 0 (o U OI co Q a a U alr2 � � � a * oi- c EiiwH .c (>n � .0 .c (>ni- (7) _c (7) 00 c cn Ln Lc) co u') Lo co cr) O p p p p O o 0 co N- co 0) 0) 0 N N N N M M - N N CO CO CO • • T.w , c0 L Q �.. O c c Cli 2 O N Q 2 a O p � r rn Q O U a) c Ea - C ° �ONg a) @m42� � TS CD O • O ao v w CO �FF- II V _2 co ai w u_ O O 6 2 E� ) a O to _0 U a Q � a) E c r coE a a v) co `t • °�' o C *Q E in >= Q Q o r (,, co a) C - Tu- a) (n c2 cr) _c .c c g a `n m e c rn tO E a � : a� O N Eo Jc'Ts Cl). o) a) NI- Q O * to C C N N — vi v) O rE p �c-- ,r a= > > `) •u� N- .c caooOOo0 arca_ -1) p � da-sEO Q UCaE " m N p • :. C V o oa o1- oY 'ET) '' a0i > o 5 ..(7) ‹O o Q O 0 co ��-0, 2o —Q ¢ a _c Q O C\I 01.0 _,.., � C a M Q to �o o c L - E •c Q E H v Ot -0co io c cE- 0 Nc) v O r d co c) — 2E13 r r Q U a) M O L o a 0 0 p o Q cN Qvop •� 1-4 LI— ac°i E M "• > o '� Q > a c aaop a) 0 mXa0 o C d Q voi N p •- 5o ZQaoo _o ZO0 U �? Z0I oOo1, O a UcaQ }- n- - U aio (0 a O = O5 Oa) N H Q � 1- NQQcoa _ ¢' O 3 -o 4.i 0) ,D I1 5 m Eaam0 : § OQU .� m II ° . n m c n W Z V a. a2c ° . ^w a II . 0 Iz ooN Q ° . Q .- Q I w : `- o Qoc� _ 'CoaOZa a C di> N N co 0- N O a) c N r N O w Q _� 'CI (NIc ocoo - ‹ m E Qr < n ai < r w - Qw `n � � cZ, W s2 II m N O o II Q II N O II Q E - II m vi � � � N a Q rn Q a. ai o M O cI O E :� O 0 c o F- N < w >+ > a E -Q o ° E O E cco u� :c M n Ell o -�? II E ai E t O 0 (-/ Q w o .� a0, obto - a IU) � � t Q- no > 1- > F- - > Fo- ccuo � n QOZZ > ao r `in fi co O > O Z r0 ~ 6Li QUO co 0, (n , J O II 68cn8 co c) a) 0- 2Uu) O _ - w w O > ¢ v O O +-. N. Q>- (3511- < 120 a O co O O 0 J O Z Z N > II N E e N C 2 6 M CO .- O N Q o = B 0 J V R. IQO5 o � C -c II .cU a .- N o � U II o II .SU a 0 OU ( c -c0Z N - c a - E M 0 u , - v) co co n O n O o a p —•c m n 'w w --. LIDO O Q coco - > > - c a) - c > _ , co � v- � O NMrf- O (nF- O Iz.Ow wHcoH 2O (ni- o2LL > QK K a' K aa O r r r O r' N N N N O O O O O Cr) U) CO CD CD N _N N N N N N O O OO r r • • o . N.0 O O O O r Q CD CM 0O (O t) TCO L0 .( CD O N. co > -Q <Y' •- Q. 0) N N Oaz) p O +. N �\ _C ��11 > O r (o CO Q L V [LII-I- Q- M .O j o_ CO r ) co _ c, N �O O N O C Q * o N CLZ CV J E O „,C)- U) CO v7 N O O O E > Q Qj \r (o o co ° a > io Q) 3 , c") a J (n O -Q C _ - �i C LL N Q- (n Q � -a � in I- � __ (0 C co 4) O p C (o O O O O C to u) O N L Ln O O O O __I -O C 0 CD cocc N r d C O in L (� N (1) cn S-12 o N - Co O 4) D oo CL cn E CCn O 's J * N c F- t.+ 0 0 a N m o O ors Q N 0 i c ~ W o a N Q� c 0 c w U o * Ui 0 d o ff IY co _LL -° C ••�ar$ 0 * O Q J Q co CO a �? L J ooZ (n ..,a) -u.)- Ra O OH 4- a��i � g - (1 — ' c o Z O N , N. Q O C Z w _o Q N Z n 3i (� * Z `� O W N N O N O * 0 N ti N C ¢ (0 0 0 p � � aN0 * F' Z (_LO a co ,- j • r La -a o U) Q� a; d c1C ) 0 0 W = 0 c N_ rn o U o c n o J o O ZO -0 p-- m am 30 � N 0 X1- o -a _0 caH M O c cn II p p N 0- Lo O co U N M ±n -p _ 7 N C 0 a .- C U LL )? N W N U) a) 4) rn 5 O . N I- (n to m . ca a_ C cn N U "a O J W O m O Cr) c N 3 cL !� O O II c Oo DE E ba a - 0 p W a) W `� ° N `o p-:0 U a) - o = ai O U N v* O N Q V O O > N Q-N J Q fl coNW 0 D 2 c °� C a) (D O -p ~ I.L (O *k 0 m Ntt c- ,W ~ OF- to a) fin +.. a) E L- to _ C co _O 2...) (1.) L 0 ` Q O a) � 1 CD 0 in 0 a) > �`CC D a_ H' •L N O O (a O +• ' (n J N 3 O Cl) O k..-_,3 CL J , CO (t0 � • C a) Q ° T3 in 3 (n - *k ~ --I • C °2S <`) L � W W 0_ X -1 ca E O IT") 2 O (q LQQ H ii ZW • (n �- CD z U- � w 0 (n0 o � 0 U) m 0 � * >, Q. iv • �; a) . F- w .0 a) .E 0 cn a) a W (A a) 0 0 m �2w p c_po2 � 2Wf- 0 c N o � - .- CL - � ;c0Cj - < 0 - r- OJN 3 U 0-OU NE.- Z •- o 'a.- /),(') > vi E U 'a) DCL l 13 a dv- Emn` LI) Le oW > mQco3a) Q -0 � _ > -IX E - Um V a) ILo `- 0 in O 0- a) W O .. 4- N Q La IA J «S * I- 1.0 N D O Z to N O i C • r _= U L 3 (R) to a) O = N a. -a * , W l:9 c Q p p) ,- -a I- in D U (n O a, Q , , p m Q) CD * oma * 2O WWQ � U ° co050 0- p up) (/)�`* X rn sz .L 0 a 2ca 1 * Jm � J a a_ aD * . ~ N aid O � C XVa) a a O0 * cr Q .F-- Xct —O > cNm a a_ aLLi fY -lin n..ca. a ' � U a) v) QO0 d * az0) ' w CO ZUO � (>/) U Q 3 - a O O 2 >> x ` 282 Ce * w - (5 CO co � _ZZ0 > 0OI [n O > O II > E .a) 13 cn A QI- X II -0 (D C) X (n (5F- o O (o E ? L � � p i C as � ] UUP ,zoN � N Z (n (n � (0r cn -a (A v, rnin a) pU a a f° U cis w � EMS > - < < < ' cnN a) (q E N a O ` u) -0 2 - U 0 1I- - N a) >, Oa - N � Oma 2 O � U) co a OO O ° (j) O 0N � 1- ' ._ Q IX N-- o N 2 2 m o J o o o N v N •- � � C � j m O * N QQ QO O O O za .azo 30 _ I- En_ a- z E (0\I (13U) c' a..5 o api o a a) O 00 (j0) � N � XX � 0 2 -0 .0o N a E o � o . cf)- CNH p W `- W S30. 00 - "- a) SOON . = Lo O0N *kM 0-z WW p ° (o4- 040vN13- W (A t Q- cB n �" > a. r o co4U o20 -I I-- coF- Q c-.' CC E -0 a0 cu LJJctf- zN a) Zii � 0J ` W W J c a E pQ (n F' � •2 c'`) 'a •• L_ i- 'no � � ww-, ° -- u� ° " (nWI- v) (,, ° ca € ,c_u °ts0 a U) 0 -0cf) _0 3a• -ao * -IL * r- -0 * CL -J W -1 -J * * cliFp- QI a. na I= cne- 1- (a (Ddo CO CD CO CO CO O O ' m CO N N N o 0 0 `' N N N 0 O O N N Na)M N N N N N N M 0 • q / < \ e 0 � f / / a. : \ kco / k - - k k .% 2 % C / L m g ,I . P G w -1 E� § a » I « L = � � 0 / A \ y / R < m _ CO5 n - _j e . f o � » � / o 0 % 2 & ate \ D t \ 2 @ � y CL p $ �L � §O / f co � � / 0 / / .CW $ 0 20 > ƒ b "L7 (..-3 l g % E2 2 2 L � -i00 y � E a) ° e / 2 % / m Z .g = 5 E Q § 2 ƒ _Z § q 0- $ _\ ;pi. \ k 0 ca / ~ & 2 E 0 ® co E m co ,- / 0 � ��» % % w / $ ¥ pƒ f -542 d ƒ d ƒ � $ p / � O ƒ� $ � wLLiE O / 0 *aCO :� / / / k \ 0 � § � / � k / / / 055 / - ƒ •0" :¢ ƒ a kg2 � / $ Oo 0 0. « 2 t « II @ 2ii & � k % G � , G � ƒ � �k 3i < Ct E / k / <- ‹ v-- G > t % 2 § 2 § � < o < < � � E � © k Zwr � � 7y � . 2 ƒ g E / _� & 0 @ m w w „ ¥ 7 I, 0 00G0 ~ � R � � ~ � / 3 ƒ E / a 2_/ k > a > Zz2i Z % EE � mZZE0 / ko� >Z / > cu O Z � e OL mmr & e a = x L mom D2 � Cr0 � CCO IF- / f ® ® am q \ 0 CO, L m 2 / 3 0 ^ / & 22 O � � / & � � GW0EC0 02 't � 2 C / � Cu2 ® 1-- --Lu F- F-- '- 6 ( 1 a . � & q I Z 0 0 § # 0Z 0 / ,� o f d / 2 d ® c k „ f0_ k � : : * Wo ƒ w / * < / 2 / ƒ k 11 0>— o > k � / ? � f 2 m t : x : G £ O (N m 6 .§ m 5 k / / ƒ o co = 0 0 0. / CV ƒ d ® = w � c # CO k $ CO % d / a f \ N- N. ® a a WEI= 4-1/16"ow • S-1 1 13 NOTE:142S%%DINGS AVERAGE 125 ppm WI-EN ON MI.WELL>TV@ 9559'`"'"IA HAS lOPPG VAILHEAD----7- ---- Mc EVOY 1 ACTUATOR= BAKER! OKB ELEV= BF ELEV= KOP= 67 8'1 39,4' 3603' Max Angle= 115°©10056' Datum MD= Datum TVD= 9809' 88°°'SSJ 19-5/8"D—CF-1132PK —1- 2605' IT r I NACL BRINE FROM PKR TO 2605'MD. ''''SEE 12/4/09 I AWGRS;CONSULT WIC PRIOR TO ANY MIT-IA*** PATCH RATED TO 3500 PSI DIFFERENTIAL,CI-ECK 0 TBG CALCS PRIOR TO PRESSURE TESTING*** 2182' J-4-1/2"HES X NIP,0=3171-5:7 I 13-3/8"CSG,72#,N-80,ID= 12 347" I— 2679' , 8836' -8859' 4 1/2 BKR STRADDLE PKR I-TuBm RANIal(01/06/ — 0- 1 -8-645' 1 a i w/CMU SLD SLV,ID=2.31 (04/10/11) J !TOP OF 7"LNR I—I 8627' .---1 8637 1--19-5/8"X 7"BKR S-3 FKR-1 _ -....--- 8Z --i9-5/8"X 7"BKR WC HGR J Minimum ID =2.310"@ 8836' -8859' 8892' BKR STRADDLE PKR w/SLD SLV I 1 j—4-1/2"HES X NP,ID=3_8131 IC X- L._1 8902' 1--7'.X 4/1/2"BKR S-3 PKR ID=3-875" 1 I i I 8926' I--[4-1/2"FIES X MP,ID=3.813" I 8947' —4-1/2"HES XN NIP,ID=3.7251 1 8947" H4-1/2"x 2-7/8"NIP REDUCER,ID=2.313" I II 1TOP OF 4-1/2"LNR 1— 8954' 8954' j—I 9-5/8"x 7"BKR LTP,ID= ^ i... • I- 4-1/2" TBG, 12.6#,L-80, .0152 bpf,ID=3,958" I-1 8954' L 8959' 4-1/2"W/LEG,ID=3.957F1 8959' I--1 amp u LOG ON XX/XX/XX I 1 1 9-5/8"CSG,47#,N-80,ID=8.681' I.--I 9136' .1 7"LNR,26#,L-80,.0383 bpi,ID=6.276" H 9138' ...., MLLOUT WINDOW (S-118) 9138'-9151' _ 17"WHIPSTOCK H-9138 I FERFORA TUN SIJIWARY REF LOG ON XX/XX/XX C114'f c V. \ A NGLE A T TOP FEW:80°©10430' 0...1.1* ........ Note: Refer to Fi-oduction DB for historical perf data ......1. \ 4.1.... SIZE SFF INTERVAL Op n/Sqz SI-10T SQZ ......14 4...4.* 2-7/8" 4 10430- 10480 0 08/02/99 411.1.1. ••••••41 2-7/8" 4 10495- 10565 0 08/02/99 1....../ 0....I.. 0.....1. 1/4...1. 4..1.1. — ........t...•.• _ _ I TD 1— 1OTT1' 1 7"LW,26#,L780,.0371 bpf,ID=6.184" I— 10004' 4itik dam", I P6T[71---1 10682' •mkik,a1vir I 4-1/2"Lt'R, 12.6#,L-80 MOD,.0152 bpf,1D=3.958" I—I 10770' DATE REV BY COACIENTS 1- DA TE REV BY COMENTS — PRUDHOE BAY 11,11. 06/16/82 IMTIAL COMPLETION i 07/14/16 KDFYJNID 11-3±C/0(07/02/16) WELL, S-11B _ T212/14198SIDETRACK(S111A) I - _ PERK.,"No '1990530 . 08/08/99 N9ES SIDETRACK(S-11B) AFI No 50-029-20728-02 02/10/15'JMG/A6 PULL CHOKE(02/07/15) SEC 35,T12N,T12E, 1646'FM_&1855'PAL 62/22/16 CJN/Jtv1) SET PX PLUG(02/21/16) 107/12/16 JG/JM) PULLED PLUG(07/04/16) - - BP Exploration(Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg l DATE: Thursday,May 07,2015 P.I.Supervisor �j� llZf l SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC S-11B FROM: Chuck Scheve PRUDHOE BAY UNIT S-I 1B Petroleum Inspector Src: Inspector Reviewed By:e P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-11B API Well Number 50-029-20728-02-00 Inspector Name: Chuck Scheve Permit Number: 199-053-0 Inspection Date: 4/30/2015 Insp Num: mitCS150430135905 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well s-1 1B - ;Type Inj W" TVD 8392 - Tubing 178 186 191 - i 185 - PTD 1990530 (Type Test SPT Test psi' 2098 IA 518 2399 ' 2354 - 2335 = Interval 4YRTST - PAF P ✓ OA 31 66 • 68 - 68 Notes: -- - - I - smote° mk.' 2 2 [015 Thursday,May 07,2015 Page 1 of I P rectos-30 Regg, James B (DOA) From: Regg, James B (DOA) Sent: Friday, February 20, 2015 9:35 AM rel 2�1-t jiS To: AK, OPS FF Well Ops Comp Rep; DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator; AK, RES GPB West Wells Opt Engr; Cocklan-Vendl, Mary E; Daniel, Ryan; Richmond, Diane M;AK, OPS GC2 OSM;AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead Subject: RE: S-11: OPERATE WELL w/ DEFEATED SVS LONG TERM (PTD # 1990530) PBU S-11B (PTD 1990530) BPXA appears to be reading a requirement into the approved waiver dated 3/11/13 that does not exist. This request does not require action by AOGCC—there is no limit for how long the SSV on a low pressure water injection well can remain defeated; the only control is wellhead injection pressure (250psi). One point of clarification—reference to 250psi wellhead injection pressure in the 3/11/13 waiver(and here) should be understood to be stabilized pressure. BPXA is reminder that it must return the SSV to actuated service when the injection pressure exceeds 250psi, must be tagged with information as required by 20 AAC 25.265(m), and must maintain a log of the defeated SSV. Jim Regg Supervisor, Inspections AOGCC SCANNED a L'k: 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or jim.regg@alaska.gov. From: AK, OPS FF Well Ops Comp Rep [mailto:AKOPSFFWeIIOpsCompRep@bp.com] Sent: Friday, February 13, 2015 1:07 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: AK, D&C Well Integrity Coordinator; AK, RES GPB West Wells Opt Engr; Cocklan-Vendl, Mary E; Daniel, Ryan; Richmond, Diane M; AK, OPS FF Well Ops Comp Rep; AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead Subject: S-11: OPERATE WELL w/ DEFEATED SVS LONG TERM (PTD # 1990530) Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that well 5-11 (PTD 1990530) is currently operating with the SVS defeated with a well pressure of< 250 psi. BPXA is requesting a waiver to operate S-11 long term (greater than 90 days) with a defeated SVS system. SSV hydraulic controls will be bypassed and the SSV will be operated manually on this PWI Well. Prior to this request, a down hole restrictive orifice had been installed to help increase the low injection pressure enough to satisfy the LPP reset. The restrictive orifice caused a hazard scenario with the potential of 1 a frozen line due to hydrate formation and static flow due to Schmoo plugging off the orifice. In addition, the low WHIP has been tripping the LPP and subsequently shutting in the well repeatedly which is cause for concern for both the tubing and the flow line. Please see attached pressure plot for reference with the wells target injection rate shown in the circled area. Please contact me with any questions/concerns that you may have. Thank you, Lee Hulme FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. Office: (907) 659-5332 Cell: (907) 229-5795 Harmony—7187 (Alternate:Vince Pokryfki) From: AK, OPS FF Well Ops Comp Rep Sent: Sunday, February 08, 2015 6:13 AM To: AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead Subject: RE: 453172478, S-11: OPERATE WELL w/DEFEATED SVS LONG TERM Yes, I will send a letter off to AOGCC today for the waiver and request. Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Cell: (907) 354-1352 Harmony-7187 Alternate: Lee Hulme From: AK, OPS GC2 Field O&M TL Sent: Saturday, February 07, 2015 4:26 PM To: AK, OPS GC2 Wellpad Lead; AK, OPS FF Well Ops Comp Rep Subject: 453172478, S-11: OPERATE WELL w/DEFEATED SVS LONG TERM Rick, Stage 3 has been signed. Vince/Lee It is in your ball park now. I believe you are required to notify the AOGCC of the status of this well. Thanks, Richard MOC Title: S-11: OPERATE WELL w/DEFEATED SVS LONG TERM MOC#: 453172478 2 Work Order: K242010 EPT: 45013003-05 Area: West, Facility: S-PAD Initiation Date: 11/12/2014 Current Status: Stage 3 Complete. Pending Stage 4 Authorization. Link to online form: http://apps-alaska.bpweb.bp.com/moc/default.aspx?pagex=moc&id=453172478 3 !" ~l.. Pages NOT Scanned in this Well History File XHVZE 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 COMMENTS: Scanned by: Bevedy Mildred Dareth~Lowell -- [] TO RE-SCAN Notes: ~_00 '~~ Re-Scanned by: Bevedy Mildred Daretha ~ Lowell Date: '~//5 Is~ ~ RECEIVED STATE OF ALASKA , AKA OIL AND GAS CONSERVATION COMMIS ION S E F 19 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Wellu Plug Perforations U Perforate U OtherU Bright Water Treatment Performed: Alter Casing❑ Pull Tubingd Stimulate-Frac ❑ Waiver❑ Time Extensiorr0 Change Approved Program 0 Operat.Shutdowr0 Stimulate-Other 0 Re-enter Suspended Wet[] 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc DevelopmenC Exploratory 199-053-0 • 3.Address: P.O.Box 196612 Stratigraphik Service 0 6.API Number: Anchorage,AK 99519-6612 50-029-20728-02-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028257 • PBU S-11B • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 10771 feet Plugs measured None feet true vertical 8839.1 feet Junk measured None feet Effective Depth measured 10682 feet Packer measured See Attachment feet true vertical 8822.71 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 27-107 27-106.99 1490 470 Surface 2652 13-3/8"72#N-80 26-2678 26-2676.81 4930 2670 Intermediate None None None None None None Production 9110 9-5/8"47#N-80 25-9135 25-8605.08 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10430-10480 feet 10495-10565 feet True Vertical depth 8770.72-8780.34 feet 8783.43-8798.72 feet scoot) N o\" .- Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 24-8958 24-8443 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10430'-10480',10495'-10565' Treatment descriptions including volumes used and final pressure: 1686 Gallon 9360A Surfactant,8250 Gallon 9398A Polymer,300 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1766 0 198 Subsequent to operation: 0 0 2208 0 206 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator0 Development❑ Service 0 • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas 0 WDSPI[] GSTOR 0 WINJ 0 WAG • GINJ fl SUSP ❑ SPLUC[] 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 Garry Catron Email Garry.Catron @BP.Com Printed Name f�Gryy Garry Title PDC PE { Signature Y eety Phone 564-4424 Date 9/19/2013 / P- RBDMS OCT 11 4 1 \i/ P-- ,p/1,0, 3 ,x,,,,,,6„ Form 10-404 Revised 10/2012 Submit Original Only • • Packers and SSV's Attachment ADL0028257 SW Name Type MD TVD Depscription S-11 B PACKER 8835 8265.01 3-1/2" Baker Packer S-11B PACKER 8850 8278.57 3-1/2" Baker Packer S-11 B PACKER 8901 8324.77 4-1/2" Baker S-3 Packer S-11 B PACKER 8954 8372.96 4-1/2" Baker ZXP Packer Casing / Tubing Attachment ADL0028257 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20"91.5# H-40 27 - 107 27 - 106.99 1490 470 LINER 512 7"26#L-80 8626 - 9138 8143.42 - 8607.84 7240 5410 LINER 1816 4-1/2" 12.6# L-80 8954 - 10770 8439.36 - 8838.92 8430 7500 PATCH 10 1/2" Baker CMD Sliding Slee 8840 - 8850 8335.92 - 8344.97 PRODUCTION 9110 9-5/8"47#N-80 25 - 9135 25 - 8605.08 6870 4760 SURFACE 2652 13-3/8" 72# N-80 26 - 2678 26 - 2676.81 4930 2670 TUBING 8934 I 4-1/2" 12.6# L-80 24 - 8958 24 - 8443 8430 7500 • • • Daily Report of Well Operations ADL0028257 ACTNITYDATE I SUMMARY T/I/O 300/620/700 Temp=120* *** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2500 bwpd. Pumped 84.5 gal. EC9360A(Surfactant) Average of 13 gph for 6.5 hrs. Pumped a total of 84.5 gal. since start of project. Pumped 384 gal. EC9398A( Polymer) Average of 64 gph for 6 hrs. Pumped a total of 384 gal. since start of project ***Establishing rates with proving pots*** ***Job continued to WSR*** 8/17/2013 ***Job continued from 8-17-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2500 bwpd. Pumped 1536 gal. EC9360A(Surfactant) Average of 64 gph for 24 hrs. Pumped a total of 1920 gal. since start of project. Pumped 312 gal. EC9398A( Polymer) Average of 13 gph for 24 hrs. Pumped a total of 396 gal. since start of project ***Establishing rates with proving pots*** ***Job continued to 8-19-13 WSR*** 8/18/2013 ***Job continued from 8-18-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2500 bwpd. Pumped 312 gal. EC9360A(Surfactant) Average of 13 gph for 24 hrs. Pumped a total of 708 gal. since start of project. Pumped 1536 gal. EC9398A( Polymer) Average of 64 gph for 24 hrs. Pumped a total of 3456 gal. since start of project ***Establishing rates with proving pots*** ***Job continued to 8-20-13 WSR*** 8/19/2013 ***Job continued from 8-19-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2500 bwpd. Pumped 312 gal. EC9360A(Surfactant) Average of 13 gph for 24 hrs. Pumped a total of 1020 gal. since start of project. Pumped 1536 gal. EC9398A( Polymer) Average of 64 gph for 24 hrs. Pumped a total of 4992 gal. since start of project ***Establishing rates with proving pots*** ***Job continued to 8-21-13 WSR*** 8/20/2013 • • Daily Report of Well Operations ADL0028257 ***Job continued from 8/20/13 WSR***(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ xxxx bwpd. Pumped 312 gal. EC9360A(Surfactant) Average of 13 gph for 24 hrs. Pumped a total of 1332 gal. since start of project. Pumped 1536 gal. EC9398A( Polymer) Average of 64 gph for 24 hrs. Pumped a total of 6528 gal. since start of project 8/21/2013 ***Establishing rates with proving pots*** ***Job continued to 8/22/13 WSR*** ***Job continued from 8/21/13 WSR***(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 2.5K bwpd. Pumped 312 gal. EC9360A(Surfactant) Average of 13 gph for 24 hrs. Pumped a total of 1644 gal. since start of project. Pumped 1536 gal. EC9398A( Polymer) Average of 64 gph for 24 hrs. Pumped a total of 8064 gal. since start of project 8/22/2013 ***Establishing rates with proving pots*** ***Job continued to 8/23/13 WSR*** ***Job continued from 8/22/13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ xxxx bwpd. Pumped 42 gal. EC9360A(Surfactant) Average of 13 gph for 3.25 hrs. Pumped a total of 1686 gal. since start of project. Pumped 186 gal. EC9398A( Polymer) Average of 64 gph for 3 hrs. Pumped a total of 8250 gal. since start of project ***Establishing rates with proving pots*** FWHP = 300/680/200, SV=close. WV, SSV, MV=open. IA, OA= OTG 8/23/2013 Well on injection at 2.5K BWPD on depatrure TREE= 41/16 CAN III Y NOTES:H2S READINGS AVERAGE 125 ppm WELLAEAD= AkEVOY! S 11 B WHEN ON ML WELL ""' _____. W_. 9559' IA HA310PPG ACTUATOR= AXELSON� NACL BRINE FROM PKR TO 2605'M a """SEE 174/09 KB.ELEV= 67.8' AWGR4;CONSULT WIC PRIOR TO ANY MIT-IA'•' BF,ELE'I/= 39.4':! PATCH RATED TO 3500 PSI DIFFERENTIAL,CHECK KOP= 3603'; TBG CALCS PRIOR TO PRESSURE TESTING " Max Angie= 115°@ 10056' Datum MD= 9809! 2182' 4-1/2"HES X NIP,ID=3.813" Da TVD= 8800 SS — 2605' 9-5/8"DV PKR 13-3/8" 72#,N-80 12.347" 2678 ■ I 8836'-8859' I—4-12"BKR STRADDLE PKR 'TUBING PUNCH(01!06/08) H 8845' ii�! w/CMU SLD SLV,ID=2.31" TOP OF 7"LNR -I 8627' I . I 8637' I-I9-518"X 7"BKR S-3 PKR I . I 8642' H9-5/8"X 7"BKR HMC I-IGR I Minimum ID =2.310"@ 8846" 1 I 8892' H412"HES X NIP,ID=3.813" 1 SLIDING SLEEVE IN STRADDLE PACKER e S I 8902' H7"X 4/1/2"BKR S-3 PKR,ID=3.875" I 8926' 4-1/2"HES X NIP,ID=3.813" 8947' H4-12"HES XN MP,ID=3.725" 1 I 8947' H412"x 2-7/8"NIP REDUCER,ID=2.313" I ii TOP OF 4-12"LNR —I 8954' I ( 8954• H 7"BKR Lift TOP PKR I 41/7'TBG,12.6#,L-80,.0152 bpf,ID=3.958" 8964' 8959' H4-1/2"W/LEG,ID=3.958" I I H L 8959' HELMDTT LOG NOT AVAILABLE 1 1 9-5/8"CSG,47#,N-80,O=8.681" H 9136' I— 17"LNR,26#,L-80,.0383 bpf,O=6.276" H 9138' I M1 LOUT WINDOW (S-11 B) 9138'-9151' ITOP OF WHIPSTOCK H 9138' I- ' PERFORATION SUMMARY 4'fS��Cf*v.' ` REF LOG: •••••••• ` ANGLE AT TOP PERF:80°0 10430' 444S4.4.4.44 Note:Refer to Roduction DB for historical perf data 4,4�*�*,41 SIZE SPF INTERVAL Opn/Sqz DATE 4••••••1 2-7/8" 4 10430-10480 0 08/02/99 4 400 4�4�1�1 2-7/8" 4 10495-10565 0 08/02/99 4404 �•�•�4�•�4�•�41 0••••••••••••••1 ;i�� TD 10771' t.1•............1 P810 10682' li``q% 44 •■••■ %%sal! ■••••••A1 �;... •••••••• i iiii" Pam --I 9962' r#11'.',1.1 7"LNR,261,1-80,.0371 bpf,ID=6.184" 10004' A.A.��������4�1 1 4-12"LNR,12.61,L-80 MOD,.0152 bpf,ID=3.958" H 10770' I DATE REV BY COMMENTS DATE REV BY COWEJN/TS I PRUDI-IOE BAY UNIT 06/16/82 ORIGINAL COMPLETION 03/31/11 RCT/PJC PULL PATCH/SET PLUG(328-29/' WELL: S-11B 08/08/99 DTR SIDETRACK COM PLETION 04/28/11 RRDI PJC SET PATCH(04/10/11) PERAIT No:'1990530 10/13/99 NORDS LAST WORKOVER 04/29/11 MBNY PJC FULL XX PLUG(04/16/11) API Na: 50-029-20728-02 05/19/08 KDC/SV CORRECTIONS 01/18/12 TMWJMD ADDED H2S SAFETY NOTE SEC 35,T12N,T12E,1646'FM-&1855'FWL 12/12/09 TTW/SV SAFETY NOTE 08/17/10 KLS/PJC TBG PUNCH CORRECTION(01/06/08) BP Exploration(Alaska) P r6 ig9as30 Regg, James B (DOA) From: AK, OPS FF Well Ops Comp Rep [AKOPSFFWellOpsCompRep @bp.com] Sent: Monday, May 20, 2013 11:27 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Redmond, Randy; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, D &C Well Integrity Coordinator; Daniel, Ryan; Bill, Michael L (ASRC); AK, OPS GC2 Field O &M TL; Starck, Jennifer L; AK, RES GPB West Wells Opt Engr Subject: RE: FYI: BPXA PBU Low PSI H2O Injector SVS Defeat - S -11 B Dear Mr. Regg, As of 5/20/13 S -11 B SVS has been returned to normal service. Please contact me with any questions. SCANNED MAY 31 2013 Thank you, Ryan Hayes (Alt. Lee Hulme) FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659 -5332 Cell: (907) 350 -2473 Harmony - 7187 From: AK, OPS FF Well Ops Comp Rep Sent: Saturday, May 18, 2013 6:14 PM To: Regg, James B (DOA); aogcc.inspectors@alaska.gov Cc: Redmond, Randy; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 OSM; AK, D &C Well Integrity Coordinator; Daniel, Ryan; Bill, Michael L (ASRC); AK, OPS GC2 Field O &M TL; Starck, Jennifer L; AK, RES GPB West Wells Opt Engr Subject: FYI: BPXA PBU Low PSI H2O Injector SVS Defeat - S -11B Dear Mr. Regg, Per AOGCC waiver dated 3/11/13, PBU Oil Pool Low Pressure Water Injectors, BPXA is providing notification that well S- 11 B (permit #1990530) in now operating with its SVS defeated as of 5/18/13. Per the wavier, BPXA has tagged and logged the defeated components, and will notify AOGCC once the SVS is returned to service. Please contact me with any questions. Thank you, Ryan Hayes (Alt. Lee Hulme) FF Well Ops Compliance Rep BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659 -5332 Cell: (907) 350 -2473 Harmony - 7187 1 MEM MEMORANDUM • 0 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 18, 2011 TO: Jim Regg � S'2.3/ P.I. Supervisor ! SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -11B FROM: John Crisp PRUDHOE BAY UNIT S -I IB Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvC-- NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT S -11B API Well Number: 50- 029 - 20728 -02 -00 Inspector Name: John Crisp Insp Num: mitJCr110517120554 Permit Number: 199 -053 -0 Inspection Date: 5/13/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s -IIB Type Inj. Wt—TVD 1 8392 IA 570 2400 • 2330 2320 ' P.T.D 1990530 - TypeTest SPT 1 Test psi 2098 " OA 430 600 600 610 Interval OTHER - P/F P Tubing 550 550 550 550 Notes: 5.3 bbls pumped for test. Post reclassification of Operable. - `O Wednesday, May 18, 2011 Page 1 of 1 STATE OF ALASKA ,_ -'~ ~ ~ ~ ~ ®~ ALAS~IL AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS ~~as~ ~~ . ~'~~: ~r~. Ca~Yrrs~i~~ 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Oth~ , , Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extensic^ Seal the Change Approved Program ^ Operat. Shutdown ^ Perforate ^ R -enter Suspended W~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory 199-0530 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-20728-02-00 8. Property Designation (Lease Number) : .Well Name and Number: ~ ADLO-028257 PBU S-11 B 10. Field/Pool(s): OO L PRUDHOE BAY FIELD / PRUDHOE BAY P 11. Present Well Condition Summary: Total Depth measured 10771 feet Plugs (measured) None feet true vertical 8839.1 feet Junk (measured) None feet Effective Depth measured 10682 feet Packer (measured) 8637 8902 true vertical 8823 feet (true vertical) 8153 8392 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20"X30" SURFACE - 110 SURFACE - 110 Surface 2679 13-3/8" 72# L-80 SURFACE - 2679 SURFACE - 2678 5380 2670 Intermediate Production 9136 9-5/8" 47# L-80 SURFACE - 9136 SURFACE - 8606 6870 4760 Liner 511 7" 26# L-80 8627 - 9138 8144 - 8608 7240 5410 ~iner 1816 4-1/2" 12.6# L-80 8954 - 10770 8439 - 8839 8430 7500 Perforationl, depth: Measured depth: SEE ATTACHED i = - - True Vertical depth: _ _ - - - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 SURFACE - 8954 SURFACE - 8439 Packers ar~d SSSV (type, measured and true vertical depth) 9-5/8"x7" baker S-3 8637 P 2 ~ 8153 ~ P~(C i 7"X4-1/2" BAKER S-3 8902 8392 12. Stimulation or cement squeeze summary: red): t l t t d meas I ~y t n ~t i -~tV ~ Z~ E ~ ~ rea e ( u n erva s ,~ tl~ t1t 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: 4367 474 Subsequent to operation: 983 303 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Servic^ Daily Report of Well Operations X 6. Well Status after work Oil Gas WDSPL G TOR ^ WAG GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-358 Contact Danielle Ohms Printed Name Danielle O Title Sr. Petroleum Engineer Signature ~ Phone 564-5759 Date 12/23/2009 Form 10-404 Revised 7/2009 ~1a~M5 ,IAN " 5 10'ro ~%' Submit Original Only S-11 B 199-053 ococ nrTnru~eGUT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base S-11 B 8/8/99 PER 10,430. 10,480. 8,770.72 8,780.34 S-11 B 8/8/99 PER 10,495. 10,565. 8,783.43 8,798.72 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 2EE= 4-1/16" CP WELLHEAD= McEVOY ACTUATOR = _ AXELSON KB. ELEV = 67.8' BF. ELEV = 39.4' KOP = 3603' Max Angle = 115 @ 10056' Datum MD = 9809' Datum TV D = 8800' SS 13-3/8" CSC, 72#, N-80, ID = 12.347" • S-11 B TUBING PUNCH (01!06!08} i-i 8$35' TOP OF 7" LNR Minimum ID = 2.31"@ 8838'" 4-1 /2" BKR STADDLE PKR w/ SLD SLV LTOPOF4-1/2" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-518" CSC, 47#, N-80, ID = 8.681" ~-j y'13ti. 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9138' TOP OF WHIPSTOCK 9138' PE72FORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 80° @ 10430' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10430 - 10480 O 08!02/99 2-7/8" 4 10495 - 10565 O 08102!99 PBTD 9962' 7" LNR, 26#, L-80, .0371 bpf, ID = 6.184" 10004' I PBTD 1 S TES: WELL - 70° @ 9559'. IA HAS 1 OPPG NACL BRINE FROM PKR TO 2605' MD. SEE 12/4/09 AWGRS; CONSULT WIC PRIOR TO ANY MIT-IA. 2182' -~4-1J2" HES X NIP, ID = 3.813" 26~ 9-518" DV PKR 8838'-8850' ~4-1/2" BAKER STRADDLE W/SLIDING SLEEVE, ID = 2.310" 8637' - ~ 9-518" X 7" BKR S-3 PKR 8642' 9-518" X 7" BKR HMC HGR 8$92' 4-1/2"HES X NIP, ID = 3.813" 8902' 7" X 4/1/2" BKR S-3 PKR, ID = 3.875" 8926' 4-112"HES X NIP, ID = 3.813" 8947' 4-1 /2" HES XN NIP, ID = 3.725" ______________ 8947' 4-112" x 2-718" NIP REDUCER, ID = 2.313" 8954` 7" BAKER ZXP LNR TOP PKR 8959' 4-1(2" W/LEG, ID = 3.958" 8959' ELMD TT LOG NOT AVAILABLE MILLOUT WINDOW (5-11 B) 9138' - 9151' 1 TD I 4-1/2" LNR, 12.6#, L-80 MOD, .0152 bpf, ID = 3.958" ~-) 10770' DATE REV BY COMMENTS DATE REV BY COMMENTS 06/16/82 ORIGINAL COMPLEf10N 03/18/08 JIM/TLH XX PLUG SET (12107!07) 08/08199 DTR SIDETRACKCOMPLETION 05/19/08 KDGSV CORRECTIONS 10/13/99 NORDS LAST WORKOVER 07/22/08 JLJlSV XX PLUG PULLED (07/11!08) 06/01/07 RDWlPA WANER SFTY NOTE DELETED 12!12!09 TTW/SV SAFETY NOTE 12/15/07 DAV/PJC SET NIP REDUCER (12/07/07) 01/08/08 TEL/SV SET STRADDLE (01/06/08) PRUDHOE BAY UNIT WELL: S-11B PERMff No: 1990530 API No: 50-029-20728-02 SEC 35, T12N, T12E, 1646' FNL & 1855' FWL BP Explaratian (Alaska) S-11B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/6/2008; *""* S-11 Bi -TUBING PUNCHER -SLIDING SLEEVE PATCH *'""` WELL SHUT IN ON ARRIVAL: T/I/0=0/175/0. 1ST RUN) TUBING PUNCH SHOT AT 8,845', 2 FT BELOW THE COLLAR OF :THE FIRST FULL JOINT ABOVE THE PACKER. '2ND RUN) SET BAKER 4.5" STRADDLE W/SLIDING SLEEVE ACROSS `:PUNCHED INTERVAL. PATCH SET FROM 8.840' - 8.850'._ '"""* JOB COMPLETED *"""" ,___. __ . ~, ._ __ _ _,_m__ _~ , . _.__, _ , ~__ . e_._,_ 6/23/2008 ""*WELL S/IN ON ARRIVAL""" (pre seal tite) "CLOSED SLIDING SLEEVE @ 8826' SLM. W/ 2 7/8" 4260 SHIFITING TOOL. 'MIT-T TO 3000, PASSED. .OPENED SLIDING SLEEVE @ 8826' SLM W/ 2 7/8" 4260 SHIFTING TOOL. **"RECOVERED 2 PIECES OF 26" X 13" CLEAR PLASTIC WRAP*"* ""*WELL LEFT S/IN, OPER NOTIFIED"*" (DSO has verified vlv positions) 7/1/2008 T/I/0=200/480/420 Circ out T x IA [Seal Tite] Pumped 3 bbls neat meth ':through jumper line, down S-36 F/L. Pumped 750 bbls 10# NACL down Tubing, SStaking returns up IA through Jumper line down S-36 F/L. Freeze Protected Jumper line with 3 bbls neat meth. **Annulus casing valves open to gauges, !SSV/Swab valves closed- All valves in jumper line to S-36 closed, S-36 Swab/ +:SSV and Wing valves closed on departure. FWHP's= SSV/240/460 7/2/2008 T/I/0= ssv/240/200 Temp=S/I Circ Well to 10# Brine (Seal Tite) Pumped 3 "bbls neat meth, 870 bbls 10# corrosion inhibited NACL, 40 bbls diesel down "Tbg, taking returns up IA through jumper to S-36 Flowline. Freeze protected Jumper line from Tbg to S-36 Flowline with 4 bbls neat meth. "*IA/OA casing valves open to gauges, S-11 SSV, Swab valves closed- All valves on jumper line's closed, S-36 Master, SSV, Swab, and Wing valves closed on departure'`' FWHP's= ssv/200/140 7/3/2008:T/I/O=ssv/100/20 Temp=S1 Assist Seal-tite (Eval source of IAxOA comm for :.Seal Tite treatment) Pumped 129.3 bbls DSL down IA taking returns up TBG through jumper to S-36 F/L to displace seal tite. Squeeze Seal tite per Seal tite procedure, see log. SSV, swab, all vales in jumper line closed, annulus casing '!valves tagged and left open, operator notified. S-36 swab closed, turned over to ;pad op to BOL. FW HPs= 1620/2000/0 7/4/2008 T/I/0= SSV/1760/0. Temp= SI. Assist Seal-Tite (WH Repair). No A/L. R/D :hardline used for circ-in out S-11 into S-36. IA FL @ surface. Pumped IAP from +'++.1760 psi to 2300 psi in 25 minutes (using 36.5 gal diesel). Monitored for 1 hour, IAP decreased 10 psi, OAP unchanged. Pumped IAP from 2290 psi to 2700 psi in 20 mins (31.54 gal diesel). Monitored for 1 hour, IAP decreased 20 psi, OAP ;unchanged. Pumped IAP from 2680 psi to 3100 psi in 18 minutes (25.2 gal ?:diesel). Pumped IAP from 3080 psi to 3600 psi in 25 minutes (46.7 gal diesel). :Monitored 1 hour, IAP decreased 40 psi, OAP increased 2 psi. Continued ::;pumping IAP from 3560 psi to 3600 psi in 5 mins. Total fluid used (3.33 bbls) '?Will monitor tomorrow. Final WHPs= SSV/3600/2. ~_ .. _ ~ _ ~ _ _ _M_~_.._,_~~ 7/5/2008 T/I/0= SSV/3280/0. Temp= SI. Assist Seal-Tite (WH Repair). No A/L. IAP ':decreased 320 psi, OAP decreased 2 psi overnight. IA FL @ surface. Pumped '(29.9 gal diesel) to pressure-up IAP from 3280 psi to 3600 psi in 21 minutes. Monitored for 30 minutes, IAP & OAP unchanged. 2" integral installed on IA. Final WHPs= SSV/3600/0. _.. , . . 7/6/2008 T/I/O=SSV/3250/0. Temp=S1. Monitor (Seal-Tite monitor). IAP decreased 350 ':psi. No change in OAP. 7/7/2008:T/I/O=SSV/2950/80. Temp=S1. Bleed IAP <500 psi (assist seal-tite). IA has 'integral installed. Bled IAP to 700 psi per seal-tite rep. During IA bleed OAP 'went on a vac. Monitor 30 min, during monitor IAP increased 70 psi. Final 'WHPs=SSV/770Nac. 7/11/2008'*""* WELL SHUT IN "**" (sealtite/close ssd / mit-t /pull ttp) "SHIFT BKR S.SLV CLOSED (DOW NI W/2-7/8" 4280 @ 8835' SLM `MIT-T TO 3000# (GOOD TEST) EQUALIZE XX PLUG BODY @ 8933' SLM PULL 2-7/8" PLUG BODY FROM NIP. REDUCER @ 8933' SLM. HUNG UP IN `'?SLIDING SLEEVE. IA PRESSURE DROPPED FROM 450 PSI TO 200 PSI. CONTINUE OUT OF `HOLE. ';?"""CONTINUE WSR ON 07-12-08"'" • w_.~,____~ .w_~ _,.__,_ ._,. 7/12/2008 "*"CONTINUED WSR FROM 07-11-08'''''` (post seal tite) ';RAN 2-7/8" 4260 (SELF REL. KEYS) TO S.SLV C«~ 8835' SLM, BOBBLE THRU 'RAN 2-7/8" 4260 (NOT SELF REL.) TO S.SLV C~ 8835' SLM, JAR DOWN :SHEAR "**WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF ALL CONDITIONS*"* 7/15/2008 T/I/0= SSV/410/95. Temp= Hot. Bleed OAP < 100 psi, IAP to ~ 1000 psi (Post Seal-Tite). No need to bleed, pressure already establish. .. _ . _ ._ 7/16/2008'T/I/O= 600/340/120. Temp= Hot. WHPs post Seal-Tite. TP increased 660 psi, IAP decreased 70 psi, OAP increased 25 psi overnight. ' SV=SHUT WV,MV&IA,OA= OTG 7/17/2008 T/I/0=620/220/85. Temp=125'. Monitor WHP's post-Sealtite (under eval) day 2. TP decreased 40 psi, IAP decreased 120 psi, OAP decreased 35 psi overnight. ** Note: water injection has decreased slightly in the past 48 hrs as per PCC. '"" MV, SSV & WV open; SV SI; IA & OA OTG "* 7/19/2008 T/I/O = 700/440/260. AOGCC MITIA to 2400 psi, LLR if fails,. '""`PASS""" Pumped 3.7 bbls of 60/40 down IA to reach test pressure. 15 min. check IA lost "20 psi. 30 min. check no loss on IA. Total loss of 20 psi. Bled pressure back to :normal. Annulus casing valves tagged and left open on departure. Final WHP= ::700/680/300. F/O verified valve positions. Swab closed. Wing,SSV,Master,lA, ;and OA open 7/28/2008 T/I/O =725/820/480. Temp= Hot. Bleed IAP to 350 psi, OAP to 120 psi (REG ;COMP). No AL (INJ). IA FL @ surface, OA FL C~ surface. Bled IAP to BT to ;.350 psi in 10 mins, bled OAP to 120 psi in 10 mins, all fluid. Final WHPs = 725/350/120. !SV shut. WV, SSV, MV open. IA & OA otg. 7/29/2008 T/I/O = 625/280/100. Temp =Hot. Monitor (UIC) No AL (INJ). TP decreased 100 psi, IAP decreased 70 psi, OAP increased 20 psi overnight. SV shut. WV, SSV, MV open. IA & OA otg. __ _. _ 7/30/2008 T/I/0=680/190/40. Temp=Hot. Monitor (UIC). TBGP increased 55 psi. IAP decreased 110 psi. OAP decreased 50 psi overnight. SV shut. SSV, WV, MV open. IA & OA otg. _ _ _ ._. 7/31/2008;T/I/O= 680/190/40. Temp= Hot. Monitor (UIC). WHPs unchanged overnight. 'Swab= C, Wing= O, SSV= O, Master= O, IA= OTG, OA= OTG. 1/13/2009'T/I/O=500/150/100. Temp=Hot. !REPORT) (pre SL LDL). 'SV=closed. MV,WV,SSV=open Bleed IAP to LP CLP 0300 psi) (DIAG IA & OA=OTG 1/15/2009;T/I/0=550/340/300. Temp=110*. IA FL (pre-AOGCC MITIA). IA FL C«~ surface. `;Bled OAP to 240 psi in 1 min. Final WHPs=550/340/240. "SV=Closed. WV, SSV, MV=Open. IA&OA=OTG. NOVP. __ ~~ .... _,,._, _~,„ _., ,_.___. _w .___ _ . _ru.~w. 1/18/2009 ***WELL INJECTING ON ARRIVAL*** (pre adperf) :DRIFT TBG W/ 2" x 10' DMY PERF GUN & S/B, 159" OAL, 'STOP DUE TO DEVIATION @ 9634' SLM, NO OBSTRUCTIONS, NO `SAMPLE -'***WELL INJECTING ON DEPARTURE**" _..„ ._ _ _ ... ., 1/21/2009 T/I/0=600/300/260. Temp=Hot. Assist FB with AOGCC MIT to 4000 psi ''FAIL"` (witnessed by Chuck Shheve). Pressured IAP with 4.9 bbls of methanol to 4000 psi in 500 psi increments In the first 15 mins IAP lost 40 psi and in the second 15 mins IAP lost 40 psi for a total of 80 psi in 30 mins. Extend test for an additional 15 mins. IAP lost 40 psi in the third 15 mins for a total of 120 psi in 45 mins. LRS Bled IAP down to 0 psi. Final WHPs=600/0/260. LRS in control of well on departure. _ _._ 1/21/2009 T/I/0=600/300/260 AOGCC MIT IA FAILED to 4000 psi (.Witnessed by C. Sheave) Pumped into the IA with 4.9 bbls of neat methanol to reach test ..:pressure. IA lost 40 psi in the 1st 15 mins and 40 psi in the 2nd 15 mins and 40 ;psi in the 3rd 15 mins for a total loss of 120 psi in the 45 min test. Bled IA. Final `WHP's=600/0/320. Valve positions at the time of departure: Swab =Closed. 'Wing, SSV, Master =Open. IA & OA are open to the gauges. Tag hung on IA valve. 1/23/2009 T/I/0= 300/330/330. Temp= 115". MITIA PASSED w. triplex to 3750 psi, LLR if `:: ;fails. TP decreased 300 psi, IAP increased 330 psi, OAP increased 70 psi since :1/21/09. Stepped up IAP in increments to 3750 psi (see Log). In the first 15 "minutes, IAP decreased 70 psi ,OAP increased 60 psi. In the second 15 minutes, IAP decreased 20 psi for a total of 90 psi, OAP increased 20 psi fora ;total of 110 psi. Bled IAP to bleed trailer from 3650 psi to 1500 psi in 15 `minutes. OAP decreased 180 psi during bleed. 30 minute monitor. IAP "unchanged, OAP increased 50 psi. Final WHPs= 300/1500150. ''SV=C. WV,SSV,MV=O. IA,OA=OTG. NOVP. _ ._ ,... e 1/24/2009 T/I/0= 500/1130/850. Temp= 110'`. Monitor WHPs post MITIA TP increased -200 psi, IAP decreased 370 psi, OAP increased 800 psi overnight. SV=C. WV,SSV,MV=O. IA,OA=OTG. NOVP. ~~_ - __ __ 1/25/2009'T/I/O = 750/940/780. Temp=Hot. Monitor WHPs Post MITIA. No AL. TP increased 250 psi, IAP decreased 190 psi, OAP decreased 70 psi overnight. SV=C. WV,SSSV,MV=O. IA,OA=OTG. NOVP. _. _ _. 1/26/2009T/I/O = 750/960/840. Temp =Hot. Bleed IA & OA to O psi. IA FL C~ surface. Bled IAP to 0+ psi in 50 min (2 bbls liquid). SI, bled OAP to 0+ (< 5 psi) in 20 !min (1/2 bbl liquid). IAP switched to vac. SI monitored for 15 min. OAP increased to 20 psi. Bled for additional 30 min to 0+ psi. FL rose to surface. SI, monitored for 30 min. OAP increased to 20 psi. Final WHPs = 750/vac/20. SV=C. WV, MV & SSV=O. IA & OA=OTG. NOVP. __ _. 1/27/2009 T/I/0= 500/15/35. Temp= Hot. Assist FB w/ AOGCC MITIA FAILED to 4000 psi. Witnessed by Chuck Scheve. LRS increased IAP to 4000 psi with 8 bbls meth. OAP increased to 130 psi. In the first 15 minutes, IAP decreased 90 psi, -:OAP increased 20 psi. In the second 15 minutes, IAP decreased 30 psi, OAP increased 20 psi. Continued test for additional 15 minutes. In the third 15 ;minutes, IAP decreased 50 psi, OAP increased 20 psi. Increased IAP to 4000 ;';psi, SI IA casing valve, restart test. 2nd test also failed. MITIA FAILED to 3000 psi. Bled IAP to 2000 psi. OAP decreased to 120 psi. Increased IAP to 3000 "psi. OAP increased to 210 psi. In the first 15 minutes, IAP unchanged, OAP ;increased 20 psi. In the second 15 minutes, IAP decreased 20 psi, OAP ;increased 20 psi. LRS bled IAP to 25 psi. OAP decreased to 40 psi. Final WHPs= 500/25/40. ''SV=C. WV,SSV,MV=O. IA,OA=OTG. NOVP. Attached tags to IA CV, MV. 1/27/2009 T/I/0= 515/15/35 Temp= Hot AOGCC MIT IA FAILED to 4000 psi (State AOGCC Witnessed by Chuck Scheve) Pressured up IA to 4000 psi w/ 8 bbls meth. 2nd test results- 1st 15 min IAP lost 40 psi, 2nd 15 min IAP lost 30 psi with a 70 psi loss in 30 min test. Bled back IA to 2000 psi . MIT IA FAILED to 3000 psi. Pressured up IA to 3000 psi with 1.7 bbls meth. 1 st 15 min IAP lost 0 ;psi, 2nd 15 min IAP lost 20 psi with a total loss of 20 psi in 30 min test. Final WHPs= 500/25/40 "Operator notified of valves as MV=closed, WV, SSV, MV= 'open, IA and OA valves open to gauges on departure" 2/3/2009 T/I/O =VAC/VAC/0+. Temp = SI. Reactivate Seal-Tite (reg comp). IA FL 54' (2.9 bbl), OA FL @ 42' (2.4 bbl). Increased IAP from VAC to 1500 psi w/8.9 bbl methanol. OAP increased to 8 psi. Monitored pressures for 60 min. IAP decreased 20 psi to 1480 psi, OAP unchanged. Increased IAP from 1480 psi to 2000 psi w/1.5 bbl methanol. OAP increased to 9 psi. Monitored pressures for 30 min. IAP decreased to 1960 psi, OAP unchanged. Increased IAP from 1960 ': ;psi to 2000 psi w/.20 bbl methanol. Monitored pressures for 45 min. IAP decreased to 1950 psi, OAP unchanged. Increased IAP from 1950 psi to 2500 psi w/1.3 bbl methanol. Monitored pressures for 30 min. IAP decreased 50 psi to 2450 psi. OAP unchanged. Final WHPs = VAC/2450/9. WV, SV =closed. IA & OA valves = OTG. SSV, MV =open. ' __ ... _ _a 2/4/2009 T/I/0= VAC/1360/450. Temp= SI. MITIA w/triplex to 3000 psi, eval Seal-Tite. ;: TP unchanged, IAP decreased 1090 psi, OAP increased 440 psi, OA FL rosed k ?42' to surface overnight. Re-pressured IAP from 1360 psi to 2000 psi in 12 !minutes using 1.16 bbls of methanol. During pumping OAP 80 psi. Monitored =for 30 minutes, IAP decreased 20 psi, OAP increased 20 psi. Increased IAP :from 1980 psi to 2500 psi in 10 minutes using 1.06 bbls methanol. OAP also 'increased 70 psi. Monitored for 1 hour, IAP decreased 50 psi, OAP increased 70 psi. Bled OAP from 690 psi to 0 psi, 0.12 bbls fluid returned. final WHPs= "":VAC/2450/0. SV,WV=O. SSV,MV=O.IA,OA=OTG. NOVP. 2/5/2009;'T/I/O = VAC/1740/110. Temp = SI. Reactivate Seal-Tite (reg comp). TP ;unchanged, IAP decreased 710 psi, OAP increased 110 psi overnight. Bled :OAP to 0 psi into BT(.9 bbl), during OA bleed IAP decreased to 1640 psi. 'Increased IAP from 1640 psi to 2500 psi w/2.3 bbl methanol, OAP increased to :170 psi. Monitored pressures for 60 min. IAP decreased 80 psi to 2420 psi, :OAP increased to 280 psi. Increased IAP from 2420 psi to 2500 psi w/.75 bbl methanol. 1st 15 min IAP lost 10 psi, 2nd 15 min IAP lost 10 psi, 3rd 15 min IAP ;lost 10 psi for a total loss of 30 psi in 45 min. OAP increased 50 psi to 410 psi .during 45 min monitor. Increased IAP from 2470 psi to 2500 psi w/.25 bbl meth, ;OAP increased to 420 psi. 1st 15 min IAP lost 10 psi, 2nd 15 min IAP lost 10 :psi, 3rd 15 min IAP lost 0 psi , 4th 15 min IAP lost 10 psi for a total loss of 30 psi ', in 60 min. OAP increased to 470 psi. Bled IAP to 1350 psi (2.1 bbl), OAP to 0 .' ;psi into BT (1.2 bbl). Final WHP =VAC/1350/0. WV, SV =closed. IA & OA valves = OTG. SSV, MV =open. _~ _ ,_ ~,a _ _ _ _ , ~ ~ _ ~__ .,_ ..~_ _. . _ rv . ..____v ,__ . 2/6/2009?T/I/O= VAC/1090/340. Temp= SI. Monitor WHPs post Seal-Tite (Perforating). TGB unchanged, IAP decreased 1360 psi, OAP increased 331 psi overnight. „SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. 11 /29/2009,""*W ELL S/I ON ARRIVAL*"" (pre wh repair /seal tite job) :.RIGGING UP SLICKLINE UNIT '--FINAL T/I/O=0/150/0-- '"*"CONTINUED ON 11/30/09 WSR""" ~. ._e..~ _k~.._.. ~ _ _.. ~_._ 11/30/2009 ***WSR CONTINUED FROM 11/29/09*"* (pre-wh repair /seal tite job) LRS LOAD TBG, B&F W/ 2 7/8" BRUSH & 2.25" GAUGE RING `:SET 2 7/8" XX PLUG IN NIPPLE REDUCER @ 8947'MD :MIT-T TO 3000# PASSED ::SHIFTED CMU SLIDING SLEEVE OPEN @ 8838'SLM --FINAL T/I/0=1100/100/0-- `*""TURN WELL OVER TO PAD OP, WELL LEFT SHUT IN -FLAGGED W/PLUG INFO **" _,. _.. __ _~ , ~ _~. _.. __w~ w_ _ _ .__ .r,..._... 5/27/2009; Pre-job meeting. Set up trailer and job site. Pressure test pumps and hoses. !:.Check the depth on the conductor (2"). Treat the well with RG2401 chemical ' (1.7 Gallons). O/A was at 0 psi and the I/A was at 0 psi and the well was On- line. Demobe off the job site. 11/29/2009Assist Slickline with Brush and Flush. Rig-up in progress, Continued on WSR 11 /30/09 11/30/2009 T/I/0=0/150/40. Temp=S/I. Assist Slickline with Brush and Flush and MIT Tbg Tito 3000 psi. Pumped down Tbg 200 bbls. 180*F diesel for load and flush. Slickline set plug and pumped 4.2 bbls to MIT Tbg. Passed. Tbg lost 200 psi in first 15 minutes & 60 psi in second 15 minutes. Bleed tbg pressure down to 800 psi. FWHP=800/400/0. IA & OA valves OTG. Slickline still on well upon LRS departure. 12/4/2009., T/I/O=950/0/0 temp=si Circ Tx IA to load, Assist Seal-Tight [Mitigate IA x OA "comm] Rigged up to choke skid and pumped 5 bbls neat meth, 694 bbls 90" `; inh. 10# NACL2 and 30 bbls 90" DSL down TBG, taking returns up IA, down :jumper line to well #37. Bled back ~9.2 bbls DSL from TBG, creating a vac on the IA. DHD loaded ~7 bbls Seal Tight into IA. Line up choke skid and pumped '';128.3 bbls 90" diesel down IA, taking returns up Tubing through~umoer line to 1 - 7 to spot Seal Tight pill. Rig mped 10 s iese roug a ar memo - '- Stand by to rig up ""Continued on 12-5-09""` 12/4/2009 *"*WELL S/I ON ARRIVAL"*" .~.~. _,J R/U SLICKLINE UNIT p k" **"CONT WSR ON 12-5-09'`" ~ ~e~lr` 12/4/2009`Seal-Tite Repair. MIRU. Mix 7 bbl Flo-Seal pill and spot. Coordinate with LRS to spot pill in IA. Wait on slickline to close sliding sleeve. ' "''" Job Continued pumping on 12/06/09 "* _ ~. _.. ~ ___w ~ ~ . _~ ___ 12/5/2009 *"Continued from 12-4-09"* Assist S/L with MIT Tubing 1500 psi PASS. Rigged up to choke skid and pumped 1.2 bbl diesel to pressure test S/L ,lubricator- bled back approx .7 bbl. Pumped .1.3 bbl neat meth to fill lubricator :and Equalize prior to S/L runs. MIT Tubing- Pumped .7 bbls neat meth to ,reach test pressure. Tubing lost 30 psi in 15 min's, 0 psi in 2nd 15 min's for a total loss of 30 psi in 30 min's. Bled back approx .8 bbls. Pumped .9 bbls neat :':meth down TBG to test equalization of plug. Bled back approx .5 bbls. Pumped '?? 1 bbl DSL down tubing to freeze protect surface pipe/ Wellhead after S/L pulled '!Plug. *"S/L in control of wellhead on departure"" FWHP's= vac/20/0 ___ . __ ~ . _a ~ , _ _ _.. _ __ , .. , . ~ _. ~ ~ __ 12/5/2009::*"`CONT WSR FROM 12-4-09***~ (post wh repair) "`:SHIFTED BAKER CMU SSD CLOSED AT 8.825' SLM (8,838'MD) 'LRS MIT-T TO 1,500 PSI (see Irs log) ;EQUALIZE 2.313" XX PLUG @ 8920' SLM / 8947 MD '.BAIL ~6 CUPS OF FILL FROM XX-PLUG AT 8,920' SLM/8,947 MD `PULLED 2.313" XX-PLUG AT 8,920' SLM/8,947 MD, (shifted baker cmu ssd !:open while pulling plug) :SHIFTED BAKER CMU SSD CLOSED W/ 2-7/8" 4260 AT 8,825' SLM/8,838' `MD '"*"`LEFT WELL S/I, NOTIFY DSO ON DEPARTURE*** 12/6/2009 T/I/O =SSV/140/0+. Temp SI. Assist Seal-tite w/IA load (repair IAxOA comm. '..Hardline rigged to IA companion valve, SI @ block valve. Increased IAP to 2000 `psi w/3.3 bbl diesel, OAP increased to 15 psi. Monitored pressures for 1 hour "30 min. IAP decreased to 1950 psi, OAP decreased to 2 psi. Increased IAP to 2500 psi w/.66 bbl diesel, OAP increased to 38 psi. Monitored pressures for 60 min. IAP decreased to 2460 psi. OAP increased 66 psi. Increased IAP to 3000 `;psi w/1.15bbl diesel, OAP increased to 110 psi. Monitored pressures for 60 ;min. IAP decreased 2960, OAP increased to 140 psi. Increased IAP to 3000 °psi w/.15 bbl diesel. Final WHPs =SSV/3000/140. WV, SV, SSV =closed. MV =open. IA, OA = OTG. 12/6/2009 T/I/O=Vac/35/10. Temp=S1. IA FL (for slickline). IA FL @ surface. ***slickline in control of well*'`* _. _ .M _ ~._ .. .. 12/7/2009 T/I/O = SSV/2800/330. Temp = SI. Obj: Hold open bleed and assist sealtite w/ pumping sealant down OA (repair IA x OA communication). IA FL @ surface. OA FL @ surface. IAP decreased 200 psi & OAP increased 190 psi overnight. Bled OAP from 330 psi to 0+ psi in 10 minutes. OAP repressured to 20 psi in 15 'minutes. Bled OAP from 20 psi to 0+ psi in 1 mins. Pressured up IA to 3000 ;psi. While pressuring up IA, OAP increased 30 psi. Monitored IA/OA 2.5 hrs for ;.pressure changes. IAP decreased 25 psi & OAP increased 80 psi. *"See Fluids !,and Log for details.** Final WHPs = SSV/2975/80. "*Job incomplete, will continue on 12-08-09."* SV, WV, SSV =Closed. MV =Open. IA & OA = OTG. NOVP. _v _ _b ~~, .. _ w_ . „ ._..__ 12/8/2009 T/I/0= SSV/2850/240. Temp= SI. Monitor WHPs (post Seal-Tite). No AL. IAP `;decreased 125 psi, OAP increased 160 psi overnight. 'SV,WV,SSV=closed. MV=open. IA,OA=open to gauge. NOVP. _. ._ 12/9/2009 T/I/O=SSV/2820/280. Temp=S1. WHP's. (Post Seal tite). IAP decreased 155 ;psi in 2 days. OAP increased 200 psi in 2 days. (1:30AM) ;SV, WV &SSV =CLOSED. MV =OPEN. IA & OA = OTG. NOVP. _ _ _. _ _ 12/9/2009 T/I/0= SSV/2800/330. Temp= SI. Monitor WHPs, (post Seal-Tite). No AL. IAP decreased 20 psi, OAP increased 50 psi in 8 hours. Monitored WHPs @ 9:30 a.m. SV,WV,SSV=closed. MV=open. IA,OA=open to gauge. NOVP _. 12/10/2009T/I/O = SSV/2710/440. Temp=SL WHPs & IC void pressure. IAP decreased 110 psi, OAP increased 160 psi overnight. No access to IC void for pressure. IA is fluid packed. "SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. NOVP. • _~ v . , _ _......,..... 12/11/2009 T/I/O =VAC/2600/500. Temp=S1. MIT-IA PASS to 3000 psi, pre AGOCC. IAP %decreased 110 psi, OAP increased 60 psi overnight.Bled OAP to BT from 500 `;psi to 0 psi in 2 min, all fluid. Increased IAP to 3000 psi with 21.82 gal. diesel. IA lost 0 psilN 1st 15 min and 0 psi in the second 15 min. OA gained 20 psi 'during test. Seal-Tite will leave 3000 psi on IA for further treating of TBG w/ !Flow Seal. Placed a 5000# gauge on IA to monitor for thermal expansion. Final `' W HPs=VAC/3000/70. '.SV,WV=Closed. SSV,MV=Open. IA,OA=OTG. NOVP. _, _. 12/14/2009 SSV/2800/420. Temp=S1. Bleed IA to 1500 psi (Sealtite). IA & OA FL C«3 -surface. Pressures unchanged from last nights monitor. Bled IAP from 2800 psi !to 1470 psi in 15 mins. Bled back ~2 bbls of diesel. During IA bleed, the OAP ':decreased to 270 psi. Monitor for 30 mins, Pressures unchanged. Final WHP's=SSV/1470/230 SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. 12/14/2009 T/I/O = SSV/2800/420. Temp = SI. Bleed IAP to 1500 psi (Sealtite). POP postponed due to OPs. SV, WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 12/15/2009 T/I/O=SSV/1500/230. Temp=S1. psi, OAP unchanged. Monitor WHP's (Sealtite). IAP increased 30 12/15/2009 T/I/0=730/730/140. Temp=S1. Tbg & IA FL (Sealtite). TBG & IA FL's @ ++surface (clean diesel). 'SV,WV=Closed. SSV,MV=Open. IA,OA=OTG. C7 12/16/2009~~T/I/O=600/1210/230. Temp=128°. Monitor WHP's (Sealtite). IAP decreased ``290 psi, OAP remained the same overnight. Bled IAP from 1210 psi to 400 psi ''.in 25 mins (all fluid). OAP decreased 20 psi. Final T/I/0=600/400/210. i SV=C. W V, SSV, MV=O. IA, OA=OTG. NOVP. ~,.__ .__..____,_. ,._ _ _ ,._~ .__.__ .__. _,__ _~... _ ..e___ d _._ ..~.~_~.w_e~ 12/17/2009 T/I/O =600/920/610. Temp=128. Bleed IA & OA. Well on water inj. Bleed IAP to BT from 920 psi to 200 psi in 10 min, all fluid. Bled OAP from 610 psi to 0 psi in 3 min, all fluid. Monitor for 1 hr. IAP increased 100 psi, OAP increased 100 psi. "Job complete" Final WHPs=600/300/100. SV=Closed. WV,SSV,MV=Open. IA,OA=OTG. NOVP. 12/18/2009T/I/O = 600/260/210. Temp = 118". WHPs (sealtite). IAP decreased 40 psi, `:OAP increased 110 psi overnight. "SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. ~, __... ._ 12/19/2009 T/I/0=500/280/340 AOGCC MIT IA PASSED to 2460 psi, (AOGCC witnessed `by Bob Noble) Pumped 4.2 bbls of 60/40 methanol into the IA to reach test ;pressure. MIT IA lost 10 psi in the 1st 15 min and 0 psi in the 2nd 15 min for a total loss of 10 psi in the 30 min test. Bled IAP back down to 800 psi per DHD. Final WHP's = 500/800/480 Valve positions at the time of departure: Swab =Closed /Wing, SSV, Master, IA, OA =Open /Tag hung on IA Valve FLUIDS PUMPED BBLS 261.8 NEAT METH 655.2 DIESEL 4.2 60/40 METH 1620 10# NACL 4151.2 Total • MEMORANDUM To: Jim Regg ~~~ 1~7.~~to P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 23, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-]1B PRUDHOE BAY lINIT S-1 lB Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~re-- Comm Well Name: PRUDHOE BAY UNIT S-11B API Well Number: 50-029-20728-02-00 Inspector Name: Bob Noble lnsp Num: mitRCN091223080528 Permit Number: 199-053-0 Inspection Date: 12/19/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. - s-I IB --- - r - - T . _ ~- --- -- -- Type Inj. I ~'/ ; T ~ 199053 ~ ~ - _ ~ 8392 IA 280 I 2460 ''~ 2450 ! X350 "r ~ Well __ ~ -- 2460 X40 540 ~ 540 560 P.T.D, ~TYPeTest ~ sPT i, Te - - %--- -- ~ - ~ --- _ ---4- ----- --- st st ~ I OA ~......_ L--_.-.-__._.1_-_-~..__.. _ - __-I._ _______ f_- _ __~__ _.__.~- _-. ___.- -__--_ Interval °T~R P/F P ~ Tubing ~ soo ~ soo ~ soo soo --------- ----~--- -y ~-----~ -- ~---- Notes: MIT-IA post seal-tite n N11~ . ~C,s,'1~ ~trSSv~fl 1'~~, ct~ ^P~1 ~~`I~ ~s', Wednesday, December 23, 2009 Page 1 of 1 NOT OPERABLE: S-11B (PTD #1990530) MIT-IA Failed post-Seal-Tits Regg, James B (DOA) From: Regg, James B (DOA) Sent: Thursday, January 29, 2009 11:31 AM j 7 To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: RE: NOT OPERABLE: S-11 B (PTD #1990530) MIT-IA Failed post-Seal-Tits Page 1 of 1 inspector witnessed 2 failed MIT attempts (1/19 and 1127} on PBU S-116, and subsequently brought the wail to my attention. From the inspector's review of info provided in the field, and after my review of the well file (sundry application only; we have not yet received 10-404 report}, f understand holes were punched in the tubing and a straddle packer installed wlsliding sleeve for Seal-Tits treatment (and retreatment if necessary} to repair production casing leak. The current configuration appears to restrict any ability to perform a MITT with restrictians due to straddle packer and sliding sleeve (I'm speculating here since I do not have ID). I'm a bit surprised that BP would attempt to qualify this well for MI injection (energized fluid) since well has holes purposely punched in the tubing to effect a repair of the production casing. And from the limited info about attempts to date, I'm not convinced that the Seal-Tits repairs have provided the success (cerkainly not fang term) that would give the certaintly needed for al(awing WAG injection. I can't tell you what to do or how to do it, but in its current configuration, 1 don't see much patential for the Commission approving injection of MI into PBU 5-11 B. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 r;, ~,rn-~ From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, January 28, 2009 2:30 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Ohms, Danielle H Cc: NSU, ADW Well Integrity Engineer; Townsend, S. Eliot; Wellman, Taylor T Subject: NOT OPERABLE: S-11B (PTD #1990530} MIT-IA Failed post-Seal-Tits All, Well S-11 B (PTD #1990530) failed an MIT-IA to both 4,000 psi and 3,000 psi on 01/27/09. The MIT-IA was completed in hopes of qualifying the well for MI service after aSeal-Tits treatment of the production casing was completed. The well no longer meets BP policy or AOGCC AIO requirements and has therefore been reclassified as Not Operable. The well needs to be shut-in as soon as possible and remain so until two competent barriers have been established. A copy of the MIT form has been included for reference. «MIT PBU S-11B 01-27-09.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1 /29/2009 MEMORANDUM • To: Jim Regg '~~,~,~ ~ ! ~I Zq`~ P.I. Supervisor _~ FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 28, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC S- I I A PRUDI IOE BAY UNIT S-1 1 B Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~`- Comm Well Name: PRUDHOF BAY UNIT S-I 1 B API Well Number: 50-029-20728-02-00 Inspector Name: ('hock Scheve Insp Num: mitCS090122081757 Permit Number: l~`)-053-0 Inspection Date: Ii2t~2oo9 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. " 45 Min. 60 Min. . _. Well salB Type Inj. W 'I'VD _ 8392 ~ IA 300 3960 3920 4000 / 3880 ~ P.T. 1990530 TypeTest SPT Test psi ''-~8 ~ OA '~ eso eso ego goo , _ Interval... orxER p/F P _ .~ Tubing 600 60o eoo eoo 600 NOtes• Test performed post seal-rite treatment to qualify well for MI service . Test indic ated a 40 psi per I Smin leak urobably IA to OA. Well also now • has a patch in the tubing (8838 - 8850) covering holes punched to s pot seal-tile. This well does not appear to be a good candidate for gas injection. Wednesday, .lanuary 28, 200q Page 1 of I MEMORANDUM To: Jim Regg `~„ ~1 1'~jl ~;a P.I. Supervisor ,\~` FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 28, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-1 I B PRUDHOE BAY 11NI1' S-I IB Sre: Inspector NON-CONFIDENTIAL Keviewed Bv: P.I. Suprv ,1jr= Comm Well Name: PRiJDHOE BAY UNIT S-I 1 B API Well Number: 50-029-20728-02-00 Inspector Name: Chuck Scheve Insp Num: mitCS090127123955 Permit Number: 199-os3-o Inspection Date: Uz7izoo9 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-1IB Type Inj. w TVp s39z ~' IA Is aooo 3910 3sso , 3a3o P.T. t99os3o 'TypeTest . sPT Test psi zo9s ~- OA 3s 130 Iso 170 Iso Interval orttER p~F P / Tubing soo soo soo soo soo _. __ _ _. _ NOtes' In addition to referenced data the !A was repressured to 4000 psi and indicated a 40 psi per 15 min pressure loss with corresponding OA pressure increase. Wednesday, .lanuary 28, 2009 Pa,e I of I UNDER EVALUATION: S-11B (PTD #1990530) Place well on injection, AOGCC MIT... Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~ v~ ¢~©~ Sent: Saturday, July 12, 2008 9:46 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Wellman, Taylor T; Winslow, Jack L.; NSU, ADW Well Integrity Engineer; Ohms, Danielle H Subject: UNDER EVALUATION: S-11 B (PTD #1990530) Place well on injection, AOGCC MITIA for UIC compliance Hi all, Well S-11 B (PTD #1990530) has recently been treated downhole with Seal-Tite to attempt to mitigate IAxOA ~~ communication. AMIT-IA passed to 3280 psi while applying pressure to cure a Seal-Tite treatment. The well has been reclassified as Under Evaluation so that it may be put on injection. Use caution while placing the well on injection as the IA pressure may increase due to thermal effects. The plan forward includes: 1. Operator: Put well on injection. 2. F: AOGCC MITIA with well on injection for UIC compliance Please call with any questions. Thank you, Anna ~u6e, ~. E. Weil Integrity Coordinator GPB Wells Group Phone: (907) 659=5102 Pager: (907) 659-5100 x1154 8/4/2008 ~~ To~ Jim Regg P.I. Supervisor ~~~J~ ~~~~ ~~~ FROM: Chuck Scheve Petroleum Inspector State ®f Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 23, 2008 SliBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-11B PRUDHOE BAY UNIT S-1 IB Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~j~' - Comm Well Name: PRUDHOE BAY UNIT S-11B Insp Num: mitCS080721061642 Rel Insp Num: API Well Number: 50-029-20728-02-00 Permit Number: 199-053-0 Inspector Name: Chuck Scheve Inspection Date: 7/19/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well salB Type Inj. W 'rVD 8392 - IA ~ 460 2400 2350 2380 p.T. 199os3o TypeTest SPT Test psi 2o9s ~ OA ~ zao ~ aao aao aao Interval oTr->ER ' P/F P ~ Tubing goo zoo ~ goo goo Notes• Test performed post repair (seal tight) for IA x OA comunication- / '~;,~ AU G ~ 200 Wednesday, July 23, 2008 Page 1 of 1 OPERABLE: S-11B (PTD #199053~0) AOGCC MITIA passed post-Seal-Tite Regg, James B (DOA) Page 1 of 2 From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com]~,,~ Sent: Sunday, July 20, 2008 7:02 AM ~~'~i~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); GPB, GC2 Wellpad Lead; GPB~~C2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr; Fleckenstein, Robert J (DOA) Cc: Wellman, Taylor T; Winslow, Jack L.; Ohms, Danielle H; NSU, ADW Well Integrity Engineer; Julian, Jennifer Y Subject: OPERABLE: S-11B (PTD #1990530) AOGCC MITIA passed post-Seal-Tite Attachments: MIT PBU S-11 B 07-19-08.x1s All, Well 5-11 B(PTD #1990530) passed an AOGCC witnessed MIT-IA on 07/19/08. The passing test confirms the success of the downhole Seal-Tite repair to mitigate the IAxOA communication. The well has been reclassified as Operable and a 10-404 form will be submitted to the AOGCC for the repair. ~ Please see the attached MIT form for the passing test. «MIT PBU S-11 B 07-19-08.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 1 ~F ~w ~~tJ~ ~'::~.~i~`:~~~~' '`"~,> E ~ From: NSU, ADW Well Integrity Engineer Sent: Saturday, July 12, 2008 9:46 AM To: 'jim.regg@alaska.gov'; 'tom.maunder@alaska.gov'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Wellman, Taylor T; Winslow, Jack L.; NSU, ADW Well Integrity Engineer; Ohms, Danielle H Subject: UNDER EVALUATION: S-11B (PTD #1990530) Place well on injection, AOGCC MITIA for UIC compliance Hi all, Well S-11 B(PTD #1990530) has recently been treated downhole with Seal-Tite to attempt to mitigate IAxOA communication. A MIT-IA passed to 3280 psi while applying pressure to cure the Seal-Tite treatment. The well has been reclassified as Under Evaluation so that it may be put on injection. Use caution while placing the well on injection as the IA pressure may increase due to thermal effects. The plan forward includes: 1. Operator: Put well on injection. 2. F: AOGCC MITIA with well on injection for UIC compliance Please call with any questions. 10/22/2009 OPERABLE: S-11B (PTD #1990530) AOGCC MITIA passed post-Seal-Tite Page 2 of 2 Thank you, Anna ~u6e, ~P. E. We11 lntegrity Caardinatar GPB Wells Group Phone: (907) 659-5102 I'ager: (907} 659-51t~Q x1154 10/22/2009 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. ~ Prudhoe Bay/PBU/S-Pad ~`~~~ 07/19/08 Andrea Hughes Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well S-11 B Type Inj. W TVD 8,393' Tubing 700 700 700 700 Interval 4 P.T.D. 1990530 Type test P Test psi 240 Casing 460 2,400 2,380 2,380 P/F P Notes: 4 year injection complicance test post repair OA 240 440 440 440 for IAxOA communication Well Type In'. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubin Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA 7YPEINJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water 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 O = Other (describe in notes) MIT Report Form BFL 11/27l07 MIT PBU S-11B 07-19-08.x1s • { ~L~ ~"~ ~( ~~ SARAN PALIN, GOVERNOR ~t ~t7~t~-t7~~ OII, Al~TD GAS 333 W. 7th AVENUE, SUITE 100 COI~TSI;R`QA'I`IOi~ COI~IIrIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Danielle Ohms Sr. Petroleum Engineer BP Exploration Alaska Inc. PO Box 99519-6612 Anchorage, Alaska 99519-6612 ~, Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 5-11 B Sundry Number: 307-358 ~~~ DEC ~. ~ ~Op7 Dear Mr. Ohms: 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 day of November, 2007 Encl. RinrPrPly STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R~G~IVEC~ NOV 2 ~ 2007 APPLICATION FOR SUNDRY APPROVAL Al~sk~ OII ~ Gas ~~~ Ccmmissloril 20 AAC 25.280 1. Type of Request: Abandon Suspend Operational shutdown Perforate Waiver Othe Alter casing ^ Repair well ^~ Plug Perforations^ Stimulate ^ Time Extension ^ SEAL TITE 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. Developmeni^ Exploratory ^ 199-0530 ' 3. Address: P.O. Box 196612 Stratigraphic^ Service Q 6. API Number: Anchorage, AK 99519-6612 50-029-20728-02-00~ 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU S-11 B Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): - ADLO-028257. 66.4 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): 10771 8839.1 - 10682 8823 NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 110' 20"x30" URFACE 110' SURFACE 110' Surface 2679' 13-3/8" 72# L-80 URFACE 2679' SURFACE 2678' 5380 2670 Production 9136' 9-5/8" 47# L-80 URFACE 9136' SURFACE 8606' 6870 4760 Liner 511' 7" 26# L-80 8627' 9138' 8144' 8608' 7240 5410 Liner 1816' 4-1/2" 12.6# L-80 8954' 10770' 8439' 8839' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10430 - 10480 8770.72 - 8780.34 4-1/2" 12.6# L-80 SURFACE - 8954' 10495 - 10565 8783.43 - 8798.72 - Packers and SSSV Type: 9-5/8"x7" BAKER S-3 Packers and SSSV MD (ft): 8637 7"X4-1/2" BAKER S-3 8902 7" BAKER ZXP LNR TOP PKR 8954 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service Q 14. Estimated Date for 15. Wetl Status after proposed work: Commencing Operations: 12/5/2007 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. Contact Danielle Ohms Printed Name anielle Ohms Title Sr. Petroleum Engineer Signature a Phone 564-5759 Date 11/21/2007 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 ^ \\ p Other: V~T~~'t~BS~U M\~ G't~r[C WQt~ J~ r~C~ ~~ `~~~C~~17^~ Subsequent Form Required: `,~,~~ ~} APPROVED BY •~ ~ Approved by: MMISSIONER THE COMMISSION Date: T Form 10-403 Revised 06/2006 `~~~ ~ ~ f ~ ~ i~ ~ ~ ~ it in Duplicate s by To: C. Olsen / J. Bixby Well Operations Team Leaders From: Danielle Ohms Jennifer Julian DeWayne Schnorr • Date: November 20, 2007 Est. Cost: $100K Cost Code: PBSPDWL11-N IOR: 200 Subject: S-11 Bi; Set Baker Straddle with Sliding Sleeve &Sealtite Repair - IA x OA communication Type Procedure S Drift w/ Dummy Patch, Run Nipple Reducer with TTP E Punch 4-1/2" tubing. Set single set Carbon Steel 4-1/2" Baker straddle w/ sliding sleeve F Circulate brine and diesel, pump Sealtite treatment and cycle squeeze S Pull TTP. Shift sliding sleeve closed (wait 3 days for treatment to cure) F MIT-IA to 2400 psi (Determine LLR if MIT-IA fails) Current Status: PWI - SI 08/28/2007 Max Deviation: 115° @ 10056' MD Min ID: 3.725" @ 8947' - 4-1/2" HES XN Nipple. Last Tag: 10/01/2007 @ 9623' SLM, stopped due to deviation - 80 degrees Last DH Op: 11/20/2007 - LDL found leak in production casing @ 2604' Latest H2S: N/A (injection well) Leak Rate: LLR --- 0.23 gpm @ 2500 psi (09/03/2007) PROBLEM DESCRIPTION: The objective of this procedure is to restore mechanical integrity to a confirmed leak in the production casing. This will be done by sealing leak (LLR = 0.23 gpm) in 9-5/8" Production Casing at 2604' with Sealtite's sealant. This technique has been performed successfully on two Kuparuk injectors by Conoco Phillips. These two jobs have lasted over one year. If this job is successful, it will open up more candidates for this promising technique and a $3.2 million workover will be avoided. The procedure consists of punching the 4-1/2" tubing (the well does not have GLM's), so that brine can be circulated down 4-1/2" tubing and back up IA. A 4-1/2" Baker single set straddle with sliding sleeve will be set across the holes in the 4-1/2" tubing. This will allow the well to be retreated if necessary. A recent caliper indicates the 4-1/2" tubing is in excellent condition. Sealtite sealant will be then be displaced to the leak with diesel, down IA, and then squeezed to seal the leak. After the sealant has cured, the sliding sleeve will be shifted closed and the IA will be pressure tested before bringing the back on water injection. The sliding sleeve has been ordered from Bob Harris and should be available in a few days. • If you have questions or concerns regarding this program, please contact Jennifer Julian at 564- 5663(w), 274-0929(h) or 240-8037(c); or Danielle Ohms at 564-5759(w), 345-2477(h) or 440- 9082(c) with any questions or comments. cc: w/a: Well File Objective: Run Baker straddle with Baker sliding sleeve (well does not have GLM's), so shallow production casing leak at 2604' ELMD can be repaired with Sealtite sealant. Slickline -Nipple Reducer w/ TTP 1. Run 2-3/8" Nipple Reducer w/ TTP Installed. E-line Punch tubing and set straddle 2. Tie into driller's depth (PDS caliper 10/02/2007 -page attached) and perforate 2' below collar of first full tubing joint above packer with tubing punchers, loaded 4 spf at 8845' DD. 3. Pump with triplex to ensure tubing has been punched. 4. Set 4-1/2" Baker straddle with Baker sliding sleeve (10' element to element) across tubing punches from 8840' to 8850' DD per manufacturer's recommendations. Ensure straddle has been drifted with the TTP that is in the nipple reducer in the well and make sure sliding sleeve is in the open position. Actual depths will be based on length of Baker straddle. At this time it is estimated to be about 10'. The tubing caliper indicates that the tubing is in excellent condition, so setting depth is not critical, just want to make sure that tubing punches are covered! Fullbore and SealTite Pumping Operation 5. SealTite Pumping Procedure is attached. Slickline (Post Sealtite treatment) 6. Pull TTP. 7. Shift sliding sleeve closed. Slickline may consider adding a knuckle joint in their toolstring to accommodate the fact that part of the tool string will be inside the smaller ID and the upper portion will be inside the 4'lz" tubing. Fullbore (Post Sealtite treatment) 8. MIT-IA to 2400 psi. Establish LLR if fails. • SealTite's Procedure --- Objectives Repair IA Communication and restore IA Integrity using Seal-Tite Sealants and Procedures Mechanical Considerations This well has an apparent leak in the 9 5/8" production casing, identified via a TecWel log at +- 2605'. The recorded liquid leak rate from previous diagnostics is 0.23 gpm at 3000 psi. - The production casing is 9-5/8" 47 #/ft L80 - The production tubing is 4-1/2" 12.6#/ft, capacity to packer = 135 bbls - IA volume is 2.2 gal/ft, total +- 457 bbls to the packer at 8902' (inclusive of 7" x 4'/z" liner area. - IA volume to leak location at 2605' is 136 bbs - IA fluid is assumed to be a mixture of brine and diesel Given the large volume to the leak location, it will be best to circulate the IA volume to brine and then spot the sealant across the leak location. The basic steps of the procedure will be as follows: - Install a sliding sleeve tubing patch just above the packer (in procedure above) - Circulate the IA to 10 ppg brine (or brine required for freeze protect). - Inject sealant pill into IA - Displace sealant pill to leak location with diesel - Squeeze sealant into leak - Close tubing patch sliding sleeve & pull TTP, and return well to service. (in procedure above) Intended Diagnostic Procedure 1. Meet with field personnel; travel to location and verify well condition. 2. Perform Job Safety Analysis with all concerned personnel. 3. Take pressure readings as follows: - Tubing - IA - OA 4. Locate the test port the intermediate casing hanger void area. Rig up pressure relief tool with gauge and bleeder valve to the test port. Record void. pressure and compare with adjacent casing pressures. Bleed off any trapped pressure to zero. Monitor for pressure build up in the void during the remaining procedure. (Note: Well history shows that the IC hanger was plastic packed and tested OK, this is suggested as a precaution only to ensure that no fluid bypass occurs during the procedure.) • Intended Repair Procedure • 5. Using Tubing Punchers, place holes 2' below the top collar of the first full tubing joint above the packer @ 8845'. 6. Install a sliding sleeve packoff across the tubing punch holes (8840'-8850'). 7. RU pump to be able to pump down tubing or IA with choke manifold to take brine returns from tubing back to tank. 8. Circulate down tubing and up IA with inhibited 10.2 ppg CaCl2 per PE manual guidelines so as not to cut out the sliding sleeve. (Note: 10.2 CaCl2 has a rated freeze point of -21 F, 10.7 CaCl2 has a rated freeze point of -49 F). If a greater freeze point is desired modify fluid accordingly. Sealant weight will be blended based on final fluid weight selected. 9. Continue circulating until entire tubing and annulus are full of 10.2 CaCl2. Capacity of tubing is +/- 135 bbls. Capacity of annulus is +/- 457 bbls. Total capacity +/- 592 bbls. 10. Pressure tubing and IA to 3600 psi. Obtain a base line pressure fall off and confirm estimated leak rate. 11. Blend 7 bbls Flo-Seal to a weight of 9.8 ppg or +/- 0.4 ppg less than weight of selected brine. 12. RU pump to IA and line up choke manifold to take brine returns from tubing back to tank. 13. Pump sealant into IA, taking returns from tubing 14. Displace sealant down IA with 126 bbls diesel, taking returns up tubing. Note: Total displacement to leak @ 2605' is 136 bbls. Compression of fluid below leak is 5.2 bbls. Compression of fluid in tubing is 2.1 bbls. Compression of diesel above sealant is 2.8 bbls. Therefore the above displacement volume will put the bottom of sealant as follows: - 3 bbls above the leak at 0 pressure - 1 bbl above the leak at 1000 psi - 1 bbl below the leak at 2000 psi - 3 bbls below the leak at 3000 psi - 4.1 bbls below the leak at 3600 psi 15. Close choke on tubing and continue to pump diesel until the IA is pressured up to 1400 psi. This should put bottom of sealant at or near the leak location. 16. Monitor IA pressure, tubing pressure and OA returns as sealant moves down annulus toward leak. Bump up IA pressure as required to maintain 1400 psi. 17. Once a seal is established at 1400 psi (no further returns on OA), allow to cure for 30 minutes. 18. Increase IA pressure to 2000 psi. Monitor for OA returns. Allow seal to cure for 1 hour. • 19. Increase IA pressure to 2500 psi. Monitor for OA returns. Allow seal to cure for 1 hour. 20. Increase IA pressure to 3000 psi. Monitor for OA returns. Allow seal to cure for 1 hour. 21. Increase IA pressure to 3600 psi. Monitor for OA returns. Allow seal to cure for 12 hours or overnight. Record data for IA integrity test records. 22. Reduce IA pressure to 2000 psi and lock in. Allow seal to cure for 3 days.. • TaEE= 41116" G'N 'NB_WEAD = Ak t3Y ACftA1TOR= AXELSON KB. = 61,8 BF 0.EV = .4" KOP = 3608 Ma+t An ~ = 115 10056 Datum MD= X09' DatumTL'D= $BOE7SS ~E SPF ~JiERv'AL O~taSgz DATE 2-118" 2-118" 4 4 10430 -10480 10495 -10565 O Q 08!02199 08'02199 -~ ~ ~ SAFETY NOTES: *'' 70" ~ 9559' 8 90° ~ 9684"' DATE RE1/ SY ~MTAH+IiS DOTE ` BY CCA9~S 06116182 ORIGINAL COMPLETION 06i08t99 OTR SIDEiRACKCOMPLETION fOt13t99 NOTES LAST WOAKOM1lER 12/28/03 TJP/TLP WANERSAFETYNOTE 01110tt35 F1lIPJC WAMERSFf`f NOTEIi2(30A5' O6tQ1t07 f~W/PA WAIYEfiSFfYNOTEDELETH} PFdJDIif?E BAY IAVIT ~Ngl: S-ii6 P82hit N~: "~ 990530 APf No: 5D-029-2072&02 S~ ~. T12N. T12E BP E~laation {Alaska) • • PDS REPORT JOINT TABULATION SHEET Pipe: 4.S in 12.6 ppf L-8U ~ti'eIY: 5-1 l6 Body Wall: 0.271 in Field: Prudhoe Bay Upset Wap: 0.271 in Cnrnpany: BP Fxplrxatinn {ALiska), Inc. Nominal Ll).: 3.958 in Country: t1SA Survey Date: October 2, 2007 -otnt No. Jt. Depth (Ft.- 1'c~n. t_!lasct {Im.! Pen. body {Ins.- Pen. °~~ hte~il Loss "••~~ >v1in. LU. (Ins.} Comments 197 7989 0 0.03 13 1 3.96 hallow ittirt . 1y$ 1 199 _ i3U30 1 807 __0 . - 0 O.U4 003 t 3 I0 1 ? 3.92 3.95 -Shallrnv p+tting. _ _,__ - _____ .~ 200 . 81 t2 U 0.02 -`I--- -1 _ 3.95 . ------- -__- _ 2U1_ _ _ _ $152 +) 0 U.O1 0 (1~ :i i I 1 I 3.96 9~ _. ~aIIQw Qitin~ ?U2 203 819_ 8233 O . 03 U 12 _ 1 _ 3.95 Sh tllo-v pitting U . UL U $ 1 9G 5 .._.._.__ 204 8273__ +l . 04 Q __ I~ I . 9Fi Shallnw pittng 201 ~Q 831 . 8315 - ___ 0 . 0.03 _ 12 _ . -- 1 __ _ . 3.9G `- __ Shallow ilfin~ _ X07 8395 +1 U.U3 1"L 1 3.95 Shallow ittin . 171 0 : 3 2U8 1343 _, i) - - , . _ - ~ - ---- 9 d7i t) 0-03 10 ~ 39( 210 8518 U.U4 14 1 3.92 Shallow ittin . X11 85 '7 r Sillw i'n ~1~ 199 ti O.f)1 3 1 3.95 213 f3G39 0.00 1 1 3.95 ~ t d 8680 0.05 18 1 3.9 a tit II vv ittin 215 13'J 1 -_ _ __ .0.00.. t_ 1 _ _ -3.9f, _ -- - - - _ _ . -- -- ----- - _ 216 8'G 1 _? ~ O.U3 ~ - 2 3.95 - 2 t i --- - 8802 ,. _ ~'~ _.. O.U 1 __ 3 1 _ 3.95 -- _-_y- - -- _ 218 8843 i) O.UI _ 3 2 3.95 ~ ~y R~~~Lt` __ ~i'ra'~~~ i a 218.1 t I t3.2 - 3 ? 1$ 8883 ._ 8842 8894 ~'' i ~ C! :0.00 0 U.0 I S t) _ 3 _' Q 1 3.95 3.8 I 3.95 P!,! P -' X ;SIP _ - ~q~ - - _ PUP _ C --- ~ ,. 218.1 _ _ 8903 +) U - 0 0 _ 3.8ti ,~s~~ b~~ PACKER _ _ '' 2113,5. t39U7 1 ' ll t) O.U1 I 3 1 .1.97 3 9 PUP ~ °~it. ,~} PUP ~OC 1 218 , 892G 0 0 0 0 3.81 X NIP ~ . "118.8 891.8 ~' U.U1 3 1 3 ~l5 PUP_ -- -.- -- ' 18 8917 r i 0 1 3 73 N I _ 19 1 89=19 _ ~ ~ _ __- 0-OU I I 3.97 PUP 219.2 8958 ~ i U U U N A WLEG 3 ~ 19 8960 ' ~ U N ~' . y 19 4 89i~1 (1 0.01 i 1 3.97 Pl P ?0 8978 (} 0.O1 ~ 1 3.9(1 PPnetratinn licxly ~Vtetal Loss Body Page ~ 8-11 (PTD #1990530) MITlA Fai1.or AA Regg, James B (DOA) . ~"11 'b\1-'\\D7 From: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Wednesday, August 29, 2007 11 :09 AM To: NSU, ADWWelllntegrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; Ohms, Danielle H Cc: NSU, ADWWI Tech; Lau, John, Jack Subject: S-11 (PTD #1990530) MITIA Failure for AA Page 1 of 1 All, v Well S-11 (PTD #1990530) failed its recent MITIA for AA update. The well has been shut in and swapped to Non-Operable status pending further evaluation for a Rig repair option. Thank you - Jack L. Winslow (for Anna Dube) Well Integrity Engineer office - 659-5102 pager-659-5100, 1154 SCANNED SEP 0 7 2007 8/29/2007 Re: S-llB (PTD #1990530) Internal Waiver Cancellation - Operab... Our records show WAG injector PBU S-11B has IAxOA communication and is covered by Admin Approval AIO 3.014 allowing it to continue injecting water only with certain other conditions of approval. Conditions of AIO 3.014 apply until canceled by the Commission. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote, On 5/31/2007 3:45 PM: All, An internal waiver was issued for TxIA communication on well S-11B (PTD #1990530) on 12/30/05. The well passed an MITIA on 12/26/06 proving two competent barriers. Under the new WI System Policy set to take effect on June 1, 2007, well S-11B will be Operable. The well is reclassified as an Operable well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you - */Anna Dube, P.E./* *Well Integrity Coordinator* *GPB Wells Group* *Phone: (907) 659-5102* *Pager: (907) 659-5100 x1154* sCANNED JUN ç, 1 2007 Jim Regg <¡im rcgg(a),admin.state.ak.us> Petroleum Engineer AOGCC I of I 6/1/2007 8:48 AM /~ !~f ~~ r ~~ , ~ ~~ ~~~ ~, L1 r ~ ~? ~ ~r `~ ~~ 1 ~ ~ SARAN PAL/N, GO~IERNOR C011~S~,1t~TiOH ~ ~ 5*~ ' ~'r 333 W 7th AVENUE, SUITE 100 •s~7 i~ lio~~`~~•~~~iii~~•iiidll i f ANCHORAGE,ALASKA 99501-3539 ~ PHONE (907} 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 3.014 Mr. Steve Rossberg, Wells Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. ~~~~'~~%~~ ' ~ .IAN ~ ~ ~~~~ P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU S-11B (PTD 1990530) Request for Administrative Approval .... Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order 003.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to inject water in the subject well. The Commission hereby denies BPXA's request for administrative approval to inject gas in the subject well. PBU S-11B exhibits surface casing repressurization. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 5-11 B and is able to manage the surface casing pressure with pressure bleeds. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU 5-11 B exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that well operation in water injection service will not threaten the environment or human safety. However, the Commission believes that PBU S-11 B's condition does not conform to the relatively more stringent standards of well integrity necessary to ensure safe gas injection. AOGCC's administrative approval to inject water only in PBU S-1 iB is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform aMIT-IA every 2 years to 1.2 times the maximum anticipated well pressure; AIO 3.014 January 30, 2007 Page 2 of 2 4. BPXA shall limit the well's IA pressure to 1000 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. after well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is December 26, 2006. Please note that PBU S-11 B's status is changed from WAGIN to 1 WIND. 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. DONE at An~lfo~ra~e, Alaska and dated January 30, 2007. J~ifi K. (~ Chairman 5 ~y ~~aA 1~~~'~~~i/af V ~ e)~ ~~ '~. ~~y ,,~'vs,Q _ ,.Yl f~..~,.Q6~~' ~ ~ Cathy P. Foerster Comm ssioner S-I1B (PTD #1990530) MITIA and MITOA for AA request . Jim, Winton, and Bob, Please see the attached MIT form well 8-11 B (PTD #1990530). A MITIA and MITOA have been complete in preparation for requesting Administrative Approval to operate the well with slow OA repressurization. An AA request will be sent within the next couple of weeks. The AOGCC representative declined witnessing these tests. «MIT PBU 8-11 12-27-06.xls» Thank you, )lnna (])u6e, œ. P.. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED JAN 0 8 2007 . -' ( . ,~ :""_-":'~_-_:_-:':.}:____-_-_-_'_-___-_-.'t:;_:\- Content-Désèrrptiòit~'Mrr PBÚ'·~rt 12-27-06.xls PBU S-1112-27-06.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 1 of 1 1/5/2007 10:25 AM . . . r ..-01 l''J ~t{tt 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 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / S pad 12/27/06 Joe Anders 6~ \ &... O( 0 Packer Depth Pretest Initial 15 Min. 30 Min. Well1S-118 I Type Inj. I W TVD I 8,392' Tubing 850 900 9001 900 Interval I V P.T.D. 1990530 I Type test I P Test psi I 2098 Casing 1,500 1,640 1,7101 1,710 P/FI P Notes: MIT-OA to 3600 psi for AA request OA 1000 3600 34001 3300 Well S-11B I Type Inj. I W TVD I 8,392' Tubing 700 850 850 850 Interval V P.T.D·11990530 I Type test I P Test psil 2098 Casing 740 3,600 3,520 3,500 P/FI P Notes: MIT-IA to 3600 psi for Vairiance OA 680 1000 1040 1040 Weill Type Inj.1 TVD Tubing Interval I P.T.D.I Type test I Test psi Casing P/FI Notes: OA Weill I Type Inj.1 TVD Tubing Interval I p.T.D.1 I Type test I Test psi Casing P/FI Notes: OA Weill I Type Inj.1 TVD Tubing Interval p.T.D.1 Type testl Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water 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 o = Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU S-11 12-27 -06-1.xls MEMORANDUM ) ') State of Alaska Alaska Oil and Gas Consel'vation Commission "ro: Jim Regg Kêäq i( A- ( O(P P.I. Supervisor ( \ DATE: Wednesday, December 28, 2005 FROM: John Crisp Petrolcum Inspcctor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-I18 PRUDHOE BAY UNIT S-IIB Src: Inspector ,qß ~(}c;?J Reviewed By: P.I. Suprv .:JS/2 Comm NON-CONFIDENTIAL WeIl Name: PRUOI-IOE BAY UNIT S-llB Insp Nmn: mitJCr051228064706 Rei Insp Num API Well Number 50-029-20728-02-00 Permit Number: 199-053-0 Inspector Name: John Crisp Inspection Date: 12/24/2005 Packer Pretest Initial 8392 IA 680 4000 2098 OA 700 1040 Tubing 2950 2950 15 Min. 30 Min. 45.Min. 60 Min. Well P.T. 5-IIB 3970 3950 1990530 1060 1060 J.ºJ~n'_aJ .~_~~_~_0:~_ ..P/~.. p 2950 2950 .. .... "~"" ,~",_"""""_"__"_,,_~___,w___,___,,,,,__.....w__,,.._,.._..~_.,~.._.....,._,_.._..~..__".._ _"_'__..~"._.___._".'__" ,__ .._._.,',........,..,_..,.,.'''._".,.. . . -, .--........-....."........-..........,. Notes 6.7 bbl's fluid pumped for test. The data submitted is from the first PT performed. The MIT was performed successfully, PT showed stabilization, test pressure was almost twice of what is required for State test & pressure loss of 1 % to 2% is insignifigant as per PI manlllal. The DI-ID crew continued Diagnostic testing on IA for several hours before I had to leave to continue SVS testing in KRU. ~(;ANNED J#4N 11 2006 Wednesday, Dcccmber 28. 2005 Page I of I 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 OPERATOR: BP Exploration (Alaska) Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU / S Pad DATE: 10/24/03 OPERATOR REP: Anna Dube AOGCC REP: none Packer Depth Pretest Initial 15 Min. 30 Min. We,,IS-~IB [Type ,nj.I S TVD I 8.392' TubingI 8751 9501 9501 9501 IntervaI O P.T.D. I1990530 Type test P Test psiI 2098 CasingI 6501 4,0001 3,9401 3,9401 P/FI P Notes: MITIA to 4000 psi, pre-MI injection start. WellI Type I nj. TVD Type test Test Casingl I I P/FI Notes: P'T'D'I Type tesll ITTeVstD Casing1 I IntervalP/FI Notes: I Type ,nj.I TVD Tubing[ P.T.D.I Ty,e,., ITest psiI I Casing1 I I I' ntervalP/FI Notes: WellI Type Inj.I TVD I Tubingl Type testITest psiI I I IInterval Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential 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 Report Form Revised: 06/19/02 2003-1024_M IT_PB U_S- 11 .xls 199-053-0 PRUDHOE BAY UNIT Roll #1: Start: Stop Roll #2: MD 107_71 ~TVD 08839 JCompletion Date: S-11B 50- 029-20728-02 BP EXPLORATION (ALASKA) rNC Start Stop 8/2/99"Completed Status: WAGIN Current: L INJP/RST L US1T R CALIPER SRVY R SRVY RPT T Name Interval c 9342 ~ 1,2 SCHLUM IMP-DEPTH CORRECT OH C 9451 I SCHLUM RST CH L IMP-MDCORRECT '~.-'FINAL 9170-10771 OH L"FII~AL 8736-10663 CH Z~INAL BL(C) 6503-8572 7/23/99 CH f./PPDS 0-8964 12/15/99 CH ~LUM 0-10771 '~- ~{~k-. OH Sent Received T/C/D 10/6/99 10/13/99 2/15/00 2/25/00 10/6/99 10/13/99 C 2/15/00 2/25/00 C 8/10/99 8/13/99 1/26/00 1/26/00 8/19/99 8/19/99 D Wednesday, June 20,2001 Page 1 ofl MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim Regg P.I. Supervisor FROM' John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL DATE: July 9, 2003 2SUBJECT: Mechanical Integrity Tests BPX S-pad 04, 06, 11 Prudhoe Bay Unit Prudhoe Bay Field WellI S'04I P.T.D.I 1830790 Notes: P.T.D. I 1821650 Notes: P.T.D. I 1990530 Packer Depth Pretest Initial 15 Min. 30 Min. I .nj.I S I T.V.D. I8373I Tubing 11480 11480 11480 11480 I,nterva, I4I Typetestl P ITestpsil 2093 I Casingl 920 I 2500 I 2460 I 2460I p/FI P I Type _ Type lnj.I S I T.V.D. I 8273I Tu i. l~00 I~00 I~oo I 1100 Ilntervall 4 I TypetestI P ITestpsil 2068 I Casingl 150 12500I 2520I 2510I P/FI P I Inj.I S I T.V.D. I 8392I Tu i. {1860I I I I Interva, I4 I Typetestl P ITestpsil 2098 I CasingI 1160I 2490I 2380I 2340 ] P/F I P I Type _ Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = N©T INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details All wells were 4 year standard pressure tests. Well S-11 tubing is showing a fairly sharp decline. Shortly after the standard pressure test began the Gathering Center had an upset and shut down. I believe the reduction in the injection pressure resulted in the decline on the annulus pressure. The pressure tests appear to meet the AOGCC criteria for a successful MIT. M.I.T.'s performed: _3 Number of Failures' 9 Total Time during tests: _4 Attachments: cc: MIT report form 5/12/00 L.G. 2003-0709_M IT_PB U_S- 1 lis.xls 7/18/2003 AUG O 1 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state. ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / S-PAD 07/09/03 Pat Lattner John Spaldin~l WelllS-O4 P.T.D.183O79O Notes: WelIIS-06 P.T.D.1821650 Notes: WelIIS-11B P.T.D. I1990530 Notes: WellI P.T.D.I N ores: WellI P.T.D.I Notes: Type test Packer Depths (ft.) MD/TVDI 8,600'I 8,373' Test psiI 20791 Pretest Initial 15 Min. 30 Min. TubingI 14801 14801 14801 14801 Interva.~ 4 CasingJ 920l 25001 2460l 2460l P/FI P ITypeTyPetestlnj' ] P I Test psil 20681 ~ Casingl 1501 25001 25201 2510[ P/FI P I ~¢¢~5 I Type lnj.IS I~O, TV~l ~.~0~'I 8,392'I T,bing] 18601 5001 2001 ~01 IntervaI 4I Typetesq P ~ Testpsi[ 2098[ ~ CasingI 1160] 24901 23801 23401 P/Fl P [ I Type Inj. Type Inj. Test Details: 4-year MITIA TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 M IT PBU S-04,06,11 07-09-031 .xls GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AI'rN: Sherrie NO. 121187 Company: Field: Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 2/15/00 Well Job # Log Description Date Blueline Sepia Color CD Prints M-10 PRODUCTION PROFILE 000207 1 1 M-30 L~l (-~ INJECTION PROFILE 000208 I 1 N-15 PRODUCTION PROFILE 000206 ! 1 H-28 .~..o~'-'~'~ 20077 CNTD 000209 1 I 1 S-11B L.L, C_ .~(-Q~l~,(J~ 20029 RST 991008 1 I 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Bivd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED FEB 2 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 9/9503-5711 /" ATTN: Sherrie ~ ......... / ." Wi=LL LOG TRANSMITTAL . ~Active Diagnostic Services, Inc. T0~ State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99508 I Los DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT{S) OR OD-ROM FILM BLUELINE Open Hole I I 1 Res. Eval, CH I I 1 Mech. CH _ S-22bi 12-1 5-99 C_~aliper Survey_______ I Rpt or i RECEI\tED Signed · ~ Date Print Name: ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: pdspmdhoe~NAS00.net Website: wwxv.memcr. '., _-.con] Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Desc: Pipe Use: BP Exploration (Alaska) Inc. Dec. 15, 1999 1031 1 4.5" 12.6 lb. Buttress Tubing Wcfll: Field: State: AP! No.: Top Log lntvl.: Bot. Log lntvl.: S-22bi Prudhoe Bay Alaska 50-029-22119-02 Surface 8,964 Ft. (MD) Inspection Type' Mechanical Integrity Inspection COMMENTS · This log was run to assess the condition of the tubing with respect to corrosive damage after failing an MIT test. The caliper log indicates that the tubing ranges from good to poor condition, with holes recorded in 4 joints and 29 joints indicating possible holes (>85% wall penetration). Almost all of the joints between GLM's 2 and 5 ( 5600' - 8600') show maximum wall penetrations in excess of 70% wall thickness. The damage recorded in this interval appears in the form of a wide line of corrosion, or general corrosion that extends between 1/8th and 1/4th of the circumference of the tubing ID. The top 45 joints logged ( 0'- 1900') appear in good condition, with no penetrations recorded in excess of 20% wail. The sevedty of the recorded damage increases somewhat lineady between 1900' and 5600'. A graphical representation of the distribution of the damage recorded throughout the logged interval is included in this report. The most severe areas of cross-sectional wall loss are recorded between joint numbers 98 and 128 (4100' - 5400') where most joints show 20% - 29% maximum cross-sectional wall loss. The distribution of maximum circumferencial metal loss recorded in each joint throughout the logged interval is included on the following page of this report. Severe damaqe is suspected in the tubinq ~ 9,045' MD. An initial attempt was made to log the entire tubing string from below the tubing wire line entry guide @ 9,275' MD, but the tool hung up at 9,045' and could not be pulled further. After waiting for the measuring arms to close, the wire line spang jars were used to jar both up and down on the tool string several times before it came free. A subsequent drift of the tubing was unable to pass this point in the tubing. This report is the result of a second caliper run made to 8,964' · MD, immediately after the ddft run. MAXIMUM RECORDED WALL PENETRATIONS · HOLE (100%) Jt. 162 @ 6,839' MD HOLE (100%) Jt. 165 @ 6,944' MD HOLE (100%) Jt. 169 @ 7,111' MD HOLE (100%) Jt. 172 @ 7,281' MD POSSIBLE HOLE ( 98%) Jt. 151 @ 6,345' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · General Corrosion (29%) Jt. 110 @ General Corrosion (27%) Jt. 120 @ General Corrosion (27%) Jt. 118 @ General Corrosion (26%) Jt. 115 @ General Corrosion (25%) Jt. 122 4,653' MD 5,067' MD 4,986' MD 4,863' MD 5,153' MD RECEIVED 26 2000 [Field Engineer' J. Burton Analyst: J. Burton Witness: Dave Romberg I PmActi;/,'~, Diagnostic Services, inc./ P.O. Box i369, Stafford, ~ 77497 Pt]one' (281) o1' (,888) 565-9085 Fax: (281) 565-i369 E=mail: PDS@memoryiog,com Prudhoe Bay Field Office Phone: (907}. 659-2307. Fax: (907) uJ;~q-zo~.~-"'*~" Well: S-22bi Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA, INC. Country: USA PDS Caliper Overview Body Region Analysis Survey Date: Dec. 15, 1999 Tool Type: MFC40 No. 99493 Tool Size: 2.75 in. No. of Fingers: 40 Analysed: ~. Burton Tubing: Size Weight Grade & Thread 4.5 ins 12.6 ppf Lq30 BTC-M Nora. OD Nora. ID Nora. Upset 4.5 ins 3.958 ins 4.5 ins Penetration and Metal Loss (% wall) penetration body ~ metal loss body 0to 1to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 226) Pene 0 23 30 31 111 31 Loss 6 108 93 19 0 0 Damage Configuration ( body ) Number of joints damaged (total = 200) 19 109 40 0 32 Damage Profile (% wall) penetration body ~! metal loss body 0 50 100 49 93 GLM 6 GLM 5 140 GLM 4 GLM 3 GLM 2 Bottom of Survey = 212 Analysis Overview page 2 Well: S-22bi Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA, tNC. Count~/: USA PDS Caliper Overview Upset Region Analysis Survey Date: Dec. 15, 1999 Tool Type: MFC40 No. 99493 Tool Size: 2.75 in. No. of Fingers: 40 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nom. OD Nora. ID Nom. Upset 4.5 ins 12.6 ppf L430 BTC-M 4.5 ins 3.958 ins 4.5 ins Penetration and Metal Loss (% wall) penetration upset 0to I to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total: 226) Pene 66 0 6 32 120 2 Damage Configuration ( upset ) Number of joints damaged (total = 159) 14 142 0 1 2 Damage Pro§le (%wall) ~pene~a~on upset 0 50 100 1 GLM 6 GLM 5 GLM 4 GLM 3 GLM 2 Bottom of Survey: 212 RECEIVED Analysis Overview page 3 dAN 2 ~ ~00D Pipe: 4.5 ins 12.6 ppf bS0 8TC-M Wall thickness. Body: 0.271ins Upset = 0.2 71 ins Nominal ID: 3.958 ins Penetration Well: Field: Company: Country: Date: S-22bi PRUDHOE BAY BP EXPLORATION ALASKA, INC. ~%~ penetration body ~/~;~ metal loss body USA Dec. 15,1999 Damage profile (% walt) 50 I00 Pipe Tabulations page 1 Minimum ID Comments inches 3.91 3.91 PUP 3.91 PUP 3.92 3.91 3.9/ 3.92 3.89 3.90 3.92 3.92 3.92 3.93 3.92 3.91 3.92 3.93 3.92 3.93 3.92 3.90 3.93 3.89 3.91 3.92 3.90 3.92 3.91 3.93 3.90 3.92 3.92 3.90 3.91 3.92 3.89 3.92 3.89 3.90 3.88 3.92 3.91 Shallow corrosion. 3.88 3.87 Corrosion. 3.91 Shallow corrosion. 3.89 Shallow corrosion. 3.91 Shallow corrosion. 3.91 Corrosion. 3.91 Corrosion. 3.89 Corrosion. RECEIVED dAH 2000 Pipe: 4.5 ins 12.6 ppi b80 BTC-M Wall thickness. Body: 0.271ins Upset = 0,271 ins Nominal ID: 3,958 ins Penetration Well: Field: Company: Country: Date: Dec. }5, 1999 Minimum ID inches 3.87 Line corrosion, 3.85 Corrosion, 3.88 Line corrosion. 3.90 Corrosion. 3.90 PUP Corrosion. 3.88 SSSV 3.88 PUP Corrosion. 3.88 Corrosion. 3.88 Line corrosion. 3.88 Corrosion. 3.87 Corrosion. 3.86 Corrosion. 3.88 Line corrosion, 3.90 Corrosion. 3.88 Corrosion. 3.89 Corrosion. 3.86 Line corrosion. 3.88 Corrosion. 3.88 Corrosion. 3.88 Line corrosion. 3.90 Line corrosion. 3.87 Corrosion. 3.88 Corrosion. 3.88 Corrosion. 3.90 Corrosion. 3.89 Corrosion, 3,88 PUP Corrosion. 3.90 3.90 GLM 6 (Latch @ 4:30) PUP Line corrosion. 3.89 Corrosion. 3.87 Line corrosion, 3,91 Corrosion. 3.89 Corrosion, 3.90 Corrosion. 3.88 Corrosion. 3.90 Corrosion. 3.87 Corrosion. 3.89 Corrosion. 3.86 Line corrosion. 3.89 Line corrosion. 3.88 Corrosion. 3.87 Corrosion. 3.91 Corrosion. 3.89 Corrosion. 3.89 Line corrosion, 3,89 Line corrosion. 3.88 Corrosion. 3.86 Corrosion. 3.86 Corrosion. 3.90 Line corrosion. S-22bi PRUDHOE BAY BP EXPLORATION ALASKA, INC. g~ penetration body USA ~2~:~ metal koss body Pipe Tabulations page 2 Damage profile I°/e, walt) 50 RECEIVED 2000 1 O0 Pipe: 4.5 ins 12.6 ppf L~30 BTC-M Wall thickness. 8ody:0.271ins Upset=0.271ins Nominal ID: 3.958 ins Penetration Well: Field: Company: Country: Date: Dec. 15, ~ 999 Minimum ID inches 3.88 Line corrosion. 3.87 Corrosion. 3.86 Corrosion. 3.88 Line corrosion. 3.88 3.87 3.86 3.88 3.87 3.88 3.88 3.88 3.89 3.88 3.86 3.88 3 ~89 3.88 3.88 3.89 3~88 3.86 3.90 3.89 3.87 3.86 3.88 3.88 388 3.89 3.86 3~86 3.83 3.86 3.88 3.86 3.89 3.85 3.88 3.90 3.84 3.87 3.87 3.87 3.86 3.88 Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Line corrosion. Corrosion. Corrosion. Corrosion. Line corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. Corrosion. POSSIBLE HOLE. POSSIBLE HOLF. Corrosion. Corrosion, Corrosion. Line corrosion. Corrosion. Corrosion. Corrosion. POSSIBLE HOLE. Corrosion. POSSIBLE HOLE. Line corrosion. PUP Corrosion. PUP Line corrosion, Corrosion. Corrosion. 3.87 Corrosion. 3,87 Line corrosion. 3.89 Corrosion. 3.87 Corrosion. S-22bi PRUDHOE BAY BP EXPLORATION ALASKA, INC. ~ penetration body USA ~:~ metal loss body Pipe Tabulations page 3 Damage profile (% wail) 50 RECEIVED 26 2000 100 Pipe: 4.5 ins 12.6 ppf L430 BTC-M Wall thickness. Body: 0.271ins Upset = 0.271in~ Nominal ID: 3.958 ins Penetration Well: Field: Company: Country: Date: S-22bi PRUDHOE BAY BP EXPLORATION ALASKA, INC. ~ penetration body USA ~ metal loss body Dec. 15, 1999 Minimnm ID inches 3.85 Corrosion. 3.87 Corrosion. 3.88 Corrosion. 3.88 Corrosion. 3.87 Corrosion. 3.84 Line corrosion. 3.86 Corrosion, 3.87 Corrosion. 3.85 Corrosion. 3,84 Corrosion. 3.83 Corrosion. 3.85 POSSIBLE HOLE. 3,85 Corrosion. 3.86 Line corrosion. 3.85 POSSIBLE HOLE. 3.83 Corrosion. 3.85 Corrosion. 3.88 Line corrosion. 3.83 Corrosion. 3.86 Corrosion. 3.77 Corrosion. 3.67 POSSIBLE HOLE. 3.87 Corrosion. HOLE in upset. 3.85 Corrosion. 3.84 POSSIBLE HOLES. 3.81 HOLES. 3.80 Line corrosion, 3.85 Line corrosion. 3.82 POSSIBLE HOLE, 3.88 HOLES. 3.86 Line corrosion. 3.88 Corrosion. 3.89 PUP POSSIBLE HOLE. 3.88 3.88 3.78 3.87 GLM 4 (Latch @ 9:00) PUP Corrosion. HOLES in body and upset POSSIBLE HOLES. 3.85 POSSIBLE HOLE. 3.85 Corrosion. 3.87 POSSIBLE HOLE. 3.64 POSSIBLE HOLE. 3.87 POSSIBLE HOLE. 3.86 Corrosion. 3.85 POSSIBLE HOLE. 3.86 Line corrosion. 3.87 POSSIBLE HOLE. 3.87 POSSIBLE HOLES. 3.86 POSSIBLE HOLE. 3.81 Line corrosion. 3.86 POSSIBLE HOLE. Damage profile %wa ) 50 100 Pipe Tabulations page 4 PDS CA ER JOINT TABULATION Pipe: 4.5 ins 12.6 ppf L4~O BTC-M Wall thickness. Body: 0.271ins Upset = 0.271ins Nominal ID: 3.958 ins Well: Field: Company: Country: Date: S-22bi PRUDHOE BAY BP EXPLORATION ALASKA, INC. ~ penetration body USA ~:~?~ metal loss body Dec. 15, 1999 Penetration Minimum ID Comments inches 3.8B POSSIBLE HOLE. 3.86 Corrosion. 3.88 POSSIBLE HOLE. 3.8B POSSIBLE HOLE. 3.88 PUP POSSIBLE HOLE. 3.81 GLM 3 (Latch @ 8:00) 3.81 PUP Corrosion. 3.85 POSSIBLE HOLE. 3.87 Line corrosion. 3.62 Corrosion. 3.85 POSSIBLE HOLE. 3.75 POSSIBLE HOLES. 3.86 Corrosion. 3.86 Corrosion. 3.84 POSSIBLE HOLE. 3.62 Corrosion. 3.58 Line corrosion. 3.84 POSSIBLE HOLE. 3.84 Line corrosion. 3.86 Corrosion. 3.84 PUP Corrosion. 3.88 _arch @ 7:00t 3.88 PUP Line shallow corrosion. 3.85 Line corrosion. 3.86 Line corrosion. 3.86 Line shallow corrosion. 3.86 3.84 3.86 Line shallow corrosion. 3.85 Line shallow corrosion. 3.83 Line shallow corrosion. 3.87 Damage profile (% walL) 50 100 Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring ~ damage area exceeds 75% of circumference, but depth range does not exceed I * pipe ID Line- damage depth range exceeds 10 * pipe ID, but extends less than 20% of circumference General ~ damage depth range exceeds 1 * pipe ID and/or extends more than 20% of circumference Isolated -darnage depth range does not exceed 10 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0.780 feet. Pipe Tabulations page 5 REOEIVED Well: S-22bi Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA, INC. Country: USA Tubing: 4.5 ins 12.6 ppf L-80 BTC-M PDS Caliper Sections Survey Date: Dec. 15, 1999 Tool Type: MFC40 No. 99493 Tool Size: 2.75 in. No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 110 Tool speed = 70 Nominal ID = 3.958 Nominal OD -- 4.500 Remaining wall area -- 76 % Tool deviation = 37 ° at depth 4653.49 ft Finger 6 Radius = 2.071 ins POINT OF MAXIMUM RECORDED X-SECTiONAL WALL LOSS Cross-Sections page 1 Well: Field: Company: Country: Tubir S-22bi PRUDHOE BAY BP EXPLORATION ALASKA, INC. USA 4.5 ins 12.6 L-80 BTGM PDS Caliper Sections Survey Date: Dec. 15, 1999 Tool Type: MFC40 No. 99493 Tool Size: 2.75 in. No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 169 Tool speed = 52 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 89 % Tool deviation = 59 ° at depth 7111.24 ft Finger 6 Penetration = 0,328 ins RECORDED HOLE Cross-Sections page 2 Well: Field: Company: Country: Tubir S-22bi PRUDHOE BAY BP EXPLORATION ALASKA, INC. USA 4.5 ins 12.6 L-80 BTC-M PDS Caliper Sections Survey Date: Dec. 15, 1999 Tool Type: MFC40 No. 99493 Tool Size: 2.75 in. No. of Fingers: 40 · Burton Cross section for Joint 165 Tool speed = 52 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 91% Tool deviation = 59 ° at depth 6943.94 ft Finger 6 Penetration = 0.292 ins RECORDED HOLE RECEIV Cross-Sections page 3 Well: S-22bi Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA, INC. Country: USA Tubin 4.5 ins 12.6 ppf L-80 BTC-M PDS Caliper Sections Survey Date: Dec. 15, 1999 Tool Type: MFC40 No. 99493 Tool Size: 2~75 in~ No. of Fingers: 40 Analysed: J. Burton Cross section for Joint 172 at depth Tool speed -- 66 Nominal ID = 3.958 Nominal OD = 4.500 Remaining wall area = 96 % In Upset Region Tool deviation = 59 ° 7281.26 ft Finger 7 Penetration: 0.272 ins RECORDED HOLE REOE ¥ D Cross-Sections page 4 PDS czALIPER JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf l_-80 BTC-M Wall thickness. Body: 0.271 ins Upset -- 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Measured Type No. ID feet feet inches 1 20.38 41.49 nominal 1.1 61.87 9.66 nominal Pup 1.2 71.53 4.07 nominal Pup 2 75.60 41.72 nominal 3 11 7.32 42.07 nominal 4 159.39 42.03 nominal 5 201.42 42.19 nominal 6 243.61 42.12 nominal 7 285.73 41.51 nominal 8 327.24 42.03 nominal 9 369.2 7 41.97 nominal 10 411.24 40.74 nominal 11 451.98 42.03 nominal 12 494.01 39.02 nominal 13 533.03 42.03 nominal 14 575.06 40.29 nominal 15 615.35 42.11 nominal 16 657.46 41.80 nominal 1 7 699.26 39.87 nominal 18 739.13 40.85 nominal 19 779.98 40.75 nominal 20 820.73 41.66 nominal 21 862.39 40.95 nominal 22 903.34 41.96 nominal 23 945.30 41.91 nominal 24 987.21 41.64 nominal 25 1028.85 41.92 nominal 26 1070.77 41.79 nominal 27 1112.56 42.01 nominal 28 1154.57 41.99 nominal 29 1196.56 41.53 nominal 30 1238.09 41.31 nominal 31 1279.40 41.82 nominal 32 1321.22 42.04 nominal 33 1363.26 42.22 nominal 34 1405.48 41.92 nominal 35 1447.40 42.01 nominal 36 1489.41 42.04 nominal 3 7 1531.45 41.82 nominal 38 1573.27 41.98 nominal 39 1615.25 41.11 nominal 40 1656.36 42.04 nominal 41 1698.40 41.65 nominal 42 1 740.05 42.20 nominal 43 1 782.25 41.44 nominal 44 1823.69 41.98 nominal 45 1865.67 41.92 nominal 46 1907.59 42.00 nominal 47 1949.59 41.54 nominal 48 1991.13 42.14 nominal Well: S-22bi Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA, INC. Country: USA Date: Dec. 15, 1999 Joint Depth Length Measured Type No. ID feet feet inches 49 2033.27 41.87 nominal 50 2075.14 40.63 nominal 51 2115.77 41.95 nominal 52 2157.72 42.11 nominal 52.1 2199.83 9.44 nominal Pup 52.2 2209.27 3.16 nominal Sssv 52.3 2212.43 9.64 nominal Pup 53 2222.07 42.05 nominal 54 2264.12 41.86 nominal 55 2305.98 41.85 nominal 56 2347.83 38.23 nominal 57 2386.06 41.80 nominal 58 2427.86 42.06 nominal 59 2469.92 42.00 nominal 60 2511.92 42.05 ~ nominal 61 2553.97 41.89 nominal 62 2595.86 40.18 nominal 63 2636.04 41.97 nominal 64 2678.01 42.10 nominal 65 2720.11 39.76 nominal 66 2759.87 40.99 nominal 67 2800.86 41.14 nominal 68 2842.00 42.12 nomina~ 69 2884.12 40.14 nominal 70 2924.26 41.81 nominal 71 2966.07 42.15 nominal 71.1 3008.22 9.86 nominal Pup 71.2 3018.08, 7.52 ~ nominal [ GIm6 71.3 3025.60 9.81 nominal I Pup 72 3035.41 42.05 nominal 73 . .3077.46 42.12 nominal 74 3119.58 41.10 nominal 75 3160.68 39.25 nominal 76 3199.93 42.02 nominal 77 3._241.95 42.11 nominal 78 3284.06 41.76 nominal 79 3325.82 42.09 nominal 80 3367.91 42.03 nominal 81 3409.94 41.95 nominal 82 3451.89 41.11 nominal 83 3493.00 42.02 nominal 84 3535.02 42.17 nominal 85 3577.19 41.86 nominal 86 3619.05 41.83 nominal 87 3660.88 41.89 norninal 88 3702.77 41.86' nominal 89 3744.63 39.53 nominal 90 3 784.16 42.01 nominal 91 3826.17 42.I8 nominal 92 3868.35 41.67 nominal RECEIVED Joint Tally page 1 d,, N 2& 000 PDSCALIPER JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 BTC~M Wall thickness. Body: 0.271 ins Upset = 0.271 ins Nominal ID: 3.958 ins Joint Depth Length Measured Type No. ID feet feet inches 93 3910.02 41.87 nominal 94 3951.89 42.05 nominal 95 3993.94 42.09 nominal 96 4036.03 42.19 nominal 97 4078.22 41.78 nominal 98 4120.00 40.66 nominal 99 4160.66 41.87 nominal 100 4202.53 42.09 nominal 101 4244.62 39.15 nominal 102 4283.77 39.69 nominal 103 4323.46 38.96 nominal 104 4362.42 41.97 nominal 105 4404.39 41.79 nominal 106 4446.18 41.80 nominal 107 4487.98 42.08 nominal 108 4530.06 41.21 nominal 109 45 71.2 7 42.00 norninal 110 4613.27 41.50 nominal 111 4654.77 42.16 nominal 112 4696.93 41.79 nominal 113 4738.72 41.73 nominal 114 4780.45 41.87 nominal 115 4822.32 41.70 nominal 116 4864.02 41.98 nominal 11 7 4906.00 38.54 nominal 118 4944.54 42.02 nominal 119 4986.56 41.85 nominal 120 5028.41 42.09 nominal 121 5070.50 41.97 nominal 122 5112.47 41.86 nominal 123 5154.33 41.49 nominal 124 5195.82 41.98 nominal 125 5237.80 40.21 norninal 126 5278.01 40.92 nominal 127 5318.93 41.79 nominal 128 5360.72 42.08 nominal 129 5402.80 41.97 nominal 130 5444.77 41.86 nominal 131 5486.63 41.89 nominal 132 5528.52 41.47 nominal 133 5569.99 39.73 nominal 133.1 5609.72 10.02 nominal Pup 133.2 5619.74 7.43 nominal GIm5 133.3 5627.1 7 10.01 nominal Pup 134 5637.18 41.95 nominal 135 5679.13 41.98 nominal 136 5721.11 41.45 nominal 137 5762.56 41.70 nominal 138 5804.26 41.80 nominal 139 5846.06 41.68 nominal Well: S-22bi Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA, INC. Country: USA Date: Dec. 15, 1999 Joint Depth Length Measured I Type No. ID / feet feet inches 140 5887.74! 40.05 nominal 141 5927.79 41.76 nominal 142 5969.55 42.04 nominal 143 6011.59 40.67 nominal 144 6052.26 39.56 nominal 145 6091.82 41.80 nominal 146 6133.62 41.99 nominal 147 61 75.61 41.84 nominal 148 6217.45 41.54 nominal 149 6258.99 42.04 nominal 150 6301.03 40.62 nominal 151 6341.65 41.76 nominal 152 6383.41 41.90 nominal 153 6425.31 4t .98 nominal 154 6467.29 41.1 6 nominal 155 6508.45 42.13 nominal 156 6550.58 40.69 nominal 157 6591.27 42.14 norninal 158 6633.41 40.83 nominal 159 6674.24 41.82 nominal 160 6716.06 . 41.97 nominal 161 6758.03 41.77 nominal 162 6799.80 42.08 t nominal 163 6841.88 41.94 nominal 164 6883.82 41.76 nominal 165 6925.58 41.79 nominal 166 6967.37 41.84 nominal 167 7009.21 42.20 nominal 168 7051.41 38.83 nominal 169 7090.25 41.44 nominal 1 70 7131.69 42.12 nominal 1 71 71 73.80 41.87 nominal 1 71.1 7215.67 9.85 nominal Pup 1 71.2 7225.52 7.30 nominal GIm4 1 71.3 7232.83 9.82 nominal Pup 1 72 7242.65 41.88 nominal 1 73 7284.53 41.70 nominal 1 74 7326.23 38.91 nominal 1 75 7365.14 I 41.89 nominal 1 76 7407.03 41.9t nominal 1 77 7448.94 42.12 nominal 1 78 7491.06 41.95 nominal 1 79 7533.01 41.93 nominal 180 ~ 7574.94 42.13 nominal 181 761 7.07 42.24 nominal 182 7659.31 41.91 nominal 183 7701.22 39.1 7 nominal 184 7740.39 41.99 nominal 185 7782.38 [ 4i.58 nominal 186 7823.96I 42.15 nominal Joint Tally page2 RECEIVED PDS , ALIPER JOINT TALLY SHEET Pipe: 4.5 ins 12.6 ppf L-80 BTC-M Wall thickness. Body: 0.2 71 ins Upset = 0.2 71 ins Nominal ID: 3.958 ins Well: S-22bi Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA, INC. Country: USA Date: Dec. 15, 1999 Joint Depth Length Measured Type No. ID feet feet inches 187 7866.11 41.44 nominal 188 7907.55 41.91 nominal 189 7949.46 42.19 nominal 190 7991.65 41.86 nominal 190.1 8033.51 8.80 nominal Pup 190.2 8042.31 8.38 nominal GIm3 1 90.3 8050.69 9.78 nominal Pup 1 91 8060.47 41.83 nominal 1 92 8102.30 41.94 nominal 1 93 8144.24 42.30 nominal 1 94 8186.54 40.32 nominal 195 8226.86 41.80 nominal 196 8268.66 41.96 nominal 197 8310.62 41.94 nominal 198 8352.56 39.55 nominal 199 8392.11 42.39 nominal 200 8434.50 41.84 nominal 201 8476.34 41.79 nominal 202 8518.13 41.99 nominal 203 8560.12 41.68 nominal 203.1 8601.80 9.87 nominal Pup 203.2 8611.67 7.34 nominal GIm2 203.3 8619.01 9.94 nominal Pup 204 8628.95 42.00 nominal 205 8670.95 41.99 nominal 206 8712.94 41.72 nominal 207 8754.66 42.05 nominal 208 8796.71 41.62 nominal 209 8838.33 41.98 nominal 210 8880.31 41.67 nominal 211 8921.98 41.11 nominal 212 8963.09 unknown nominal Joint Depth Length Measured Type No. ID feet feet inches I Joint Tally page 3 10/6/99 GeoQuest 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 AI"fN: Sherrie NO. 12830 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Open Hole) Well Job # Log Description Date BL Sepia CD S-11B L~icL., ~'~.'~..-~ 99366 DEPTH CORRECTED IMPULSE 990730 1 S-11B ,,L,, 99366 MD IMPULSE 990730 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Bivd. Anchorage, Alaska 99519-6612 Date Delivered: RECEIVED !"-'~'t I 0 1777 ~t~J t311 & Gas Co~s. Commisaon Schlumberger GeoQuest 3940 Arctic BI 3940 Arctic Blvd, Suite 300 Anchorage, / Anchorage, AK 99503-5711 ATI'N: Sherrie /""', Received by: _(~ / STATE OF ALASKA .,-~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended []Abandoned []Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 99-053 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20728-02 4. Location of well at surface ~ .................... :i ~.;/,~'~ 9. Unit or Lease Name 1646'SNL, 1855' EWL, SEC. 35, T12N, R12E, UM i ':~"~!~'L~]L?I i ! ~. -~'"'~'-' ii PrudhoeaayUnit At top of productive interval ,,.?,,J)~ '~/.~.~ '~ ~' ~ ~'~:- '~~ ~~ S-11Bi ~ ~ ,~ 10. Well Number 3255' SNL, 3614' EWL, SEC. 35, T12N, R12E, UM ~ At total depth ~ ~~ ~ ~.~r~.~; 11. Field and Pool 2545' SNL, 4624' EWL, SEC. 35, T12N, R12E, UM ~':;7;~-:E:: ¢ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. Pool KB = 66.40'~ ADL 028257 12. Date Spudded7/24/99 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re ~ 16' N°' Of cOmplete°ns7/29/99 8/2/99 N/A MSL. One 17. Total Depth (MD+~D) 18. Plug Back Depth (MD+~D)~19. Directional Su~ey ~20. Depth where SSSV set ~21. Thickness of Permafrost 10771 8839 FT 10682 8823 FT~ ~Yes ~No~ (Nipple) 2182' MD~ 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, PWD 23. CASING~ LINER AND CEMENTING RECORD CASING SE~ING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOSOM SIZE CEMENTING RECORD AMOUNT PULLED 20"X 30" Insulated Conductor Sudace 110' 36" 8 cu yds Concrete 13-3/8" 729 L-80 Sudace 2679' 17-1/2" 3767 cuff Arcticset II 9-5/8" 479 L-80 Sudace 9136' 12-1/4" 1240 cuff Class 'G', 130 cuff Arcticset I 7" 269 L-80 8627' 9138' 8-1/2" 390 cuft Class 'G' 4-1/2" 12.6~ L-80 8954' 10770' 6" 281 cuff Class 'G' 124. Pedorations open to Production (MD+~D of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.69, L-80 8959' 8903' MD ~D MD ~D 10430' - 10480' 8771' - 8780' 10495' - 10565' 8783' - 8799' 26. AC~D, F~CTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel ! 27. PRODUCTION TEST ~ :':; ~ ~ E:; Date First Production l Method of Operation (Flowing, gas lift, etc.) August 16, 1999I Water & Gas Injection -q~.%"3 ~://~ ~.q ~)~.;.:~. ~'~,~ ....... Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE S~ZE IGAS-O~:!~Sq,, ......... I TEST PERIOD Flow Tubing Casing Pressure CALCU~TED ;OIL-BBL GAS-MCF WATER-BBL O~L GRAW~-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 9164' 9164' Shublik 9209' 8672' Shublik 'B' 9270' 8722' Shublik 'C' 9284' 8733' Sadlerochit / Zone 4 9318' 8757' 31. List of Attachments Summary of Daily Drilling Reports, Surveys '32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble '~~ (~~-~_ Title Technical Assistant III Date 0~' IO'/' (~ S-11Bi 99-053 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Facility PBS Pad Progress Report Well S- 11B Rig Nabors 9ES Page Date 1 11 August 99 Date/Time 13 Jul 99 14 Jul 99 22:30-06:00 22:30-06:00 06:00 06:00-06:00 06:00-06:00 Duration 7-1/2 hr 7-1/2 hr 24 hr 24 hr Activity Move rig Rigged down Top drive Prep rig for move from A-Pad to S-Pad. PJSM. Remove stairs, landings, beaver slide, etc. RD floor, remove drawworks guards. Pull pit module away from rig. Release from top drive and secure same. Rig 0.0% moved. Equipment work completed Move rig Rig moved 10.00 % Move rig off A-Pad and down access road. Approaching 1/2 way point to Spine Road. Soft road conditions requiring plywood on both sides of road. Five loaders running. All hands PU/LD plywood. Cycling plywood around rig via D-Pad access road. 15 Jul 99 16 Jul 99 17 Jul 99 18 Jul 99 06:00-06:00 06:00-18:00 18:00 18:00-23:00 23:00 23:00-06:00 06:00 06:00-06:00 06:00-06:00 06:00 06:00-06:00 06:00-06:00 06:00 06:00-06:00 24 hr 12hr 5 hr 7 hr 24 hr 24 hr 24 hr 24 hr 24 hr Move rig Rig moved t0.00 % Finish L/D plywood on both sides of A-Pad access road and move sub base module to Spine Road. Rig off station Rig moved 10.00 % Move sub base module down Spine Road to CC2A parking area while being escorted by Security. No moving problems. Rig off station Rig moved 10.00 % L/D plywood with matting boards on the top of the plywood on both sides of the first of two Kuparuk River bridges. Estimated time to finish L/D plywood and matting boards is 0800 hrs. Rig off station Move rig (cont...) Rig moved 40.00 % L/D plywood and matting boards at 1st Kuparuk river crossing. Move sub base and pit modules across river. P/U matting boards and L/D at 3rd Kuparuk river crossing. Rig off station Move rig (cont...) Rig moved 60.00 % Begin moving sub base down Spine road towards S-Pad road. Broke thru road 1/2 mile from S-Pad road. Crib tires. Free after serveral attempts. Move sub base to S-Pad road. Start L/D plywood and matting boards on S-Pad road. Rig off station Move rig (cont...) Facility Date/Time 19 Jul 99 20 Jul 99 PBS Pad 06:00-06:00 06:00 06:00-19:00 06:00-19:00 19:00 19:00-06:00 19:00-23:30 23:30 23:30-04:30 04:30 04:30-06:00 04:30-06:00 06:00-06:30 06:00-06:30 06:30 06:30-09:00 06:30-09:00 09:00 09:00-15:30 09:00-13:00 13:00 13:00-14:00 14:00 14:00-15:30 15:30 15:30-18:00 15:30-18:00 Progress Report Well S- 1 lB Page 2 Rig Nabors 9ES Date 11 August 99 Duration 24 hr 13hr 13 hr llhr 4~1/2 hr 5 hr 1 ~ 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2~ 1/2 hr 6-1/2 hr 4 hr 1 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr Activity Rig moved 80.00 % Finish L/D plywood and matting boards on S-Pad. Move sub base to Y in road. P/U matting boards and re-position from sub base to S-Pad. Move sub base and pit modules onto S-Pad. Rig off station Move rig (cont...) Rig moved 100.00 % Raise derrick. L/D herculite and matts. Spot sub over well. Spot pit module. Connect service lines. Accept rig at 1900 hrs 7/19/99. At well location - Cellar Wellhead work Bleed down well PJSM - 40 psi on annulus. Bleed to 0 psi. Got back 2 1/2 bbls diesel. No gas. Completed operations Tested Hanger plug RFU lubricator. Pull BPV. Install TWC. Test TWC to 1000 psi. Hold pressure from the bottom. Leaking by from the top. No spare TWC or rebuild kit. Note: Bridge washed out due to high water. Pressure changed from 1000.0 psi to 0.0 psi in 0.00 hr - Downhole to, failure Removed Xmas tree N/D tree and adaptor. Removed Xmas tree Permission received to proceed forward. N/D tree and adapter spool. Wellhead work (cont...) Removed Xmas tree (cont...) Permission received to proceed forward. N/D tree and adapter spool. Equipment work completed Nipple up BOP stack Rigged up BOP stack Equipment work completed Nipple up Lubricator Installed Lubricator R/U lubricator and extension Began precautionary measures Monitor Annulus = 75 psi. Bled down while waiting on new 2-way check. Bled Annulus and Lubricator down to 0 psi. Removed Internal BOPs Pull 2-way check valve Began precautionary measures Opened bag. No fluid in sight - top off with 26 bbls to fill hole. Installed Internal BOPs Install new 2-way check valve. Equipment work completed Perform inte~ity test Tested Other sub-surface equipment - Via string 1',~3L ,,~- WCll..,y t-,IIUk.,I~ LU "'I'UUU 1,/31. i~.~3t [.~IIUI~. IIIO, IilIUIU. Facility Date/Time 21 Jul 99 PBS Pad 18:00 18:00-20:30 18:00-19:00 19:00 19:00-20:30 20:30 20:30-2l:30 20:30-21:30 21:30 21:30-00:00 21:30-00:00 00:00 00:00-06:00 00:00-00:30 00:30 00:30-02:00 02:00 02:00-03:00 03:00 03:00-04:00 04:00 04:00-04:45 04:45 04:45-06:00 06:00 06:00-07:15 Progress Report Well S-lIB Page 3 Rig Nabors 9ES Date 11 August 99 Duration 2-1/2 hr 1 hr 1-1/2 hr 1 hr 1 hr 2-1/2 hr 2-1/2 hr 6 hr 1/2 hr 1-1/2 hr 1 hr 1 hr 3/4 hr 1-1/4 hr 1-1/4 hr Activity to 250/4000 psi (well static). Function test completed satisfactorily Pull Single completion, 4-1/2in O.D. Retrieved Other sub-surface equipment Pull 2-way check, L/D lubricator and extensions. Completed operations Retrieved Tubing hanger Pull tubing hanger and single jr. of 4-1/2" tubing to floor, L/D same. Equipment work completed Derrick management Rigged up Top drive Change out 4-1/2" box by 4" Hitorq pin sub on top drive. Equipment work completed Test well control equipment Tested BOP stack Test BOPE to 250/4000 psi. Test Hydrill to 250/3500 psi. Function test completed satisfactorily Well static--fluid level stable for 6 hours. Wellhead work Held safety meeting In 0.10 hr had 56.000 bbl Gain - closed in well Hold PJSM. Prepare to install wear bushing. Blowdown secondary kill line- well flowed- shut in blind rams- observe 56 bbl gain to pits, some overflow of diesel to secondary containment, < 1 gallon on pad- excellent response. Monitor pressures Resumed operations Shut in drillpipe pressure @ 100 psi & constant for 1.5 hrs. Continue to clean up diesel from rigfloor and suck out secondary containment tanks on fig- clean up diesel on herculite and place absorbent down wind on pad. ( Weather conditions wet and windy) Bleed down well Completed operations Bleed down well- 100 psi bled down in 35 minutes- pressure not building when periodically shut in. Continue to bleed off until no further pressure- influx = air. Circulated at -0.0 ft Stopped: To flowcheck well Open blind rams- fill well with 56 bbls seawater ( equates to 760 ft, 270 psi diesel hydrostatic) Flow check Observed well static Observe well while continuing to clean up rig- well static. Installed Wear bushing Equipment work completed Install wear ring and prepare to pick up 8.1/2" slick drilling assembly with ported float. Well control Facility Date/Time 22 Jul 99 PBS Pad 06:00-07:15 07:15 07:15-06:00 07:15-12:00 12:00 12:00-13:00 13:00 13:00-15:00 15:00 15:00-15:30 15:30 15:30-17:30 17:30 17:30-22:00 22:00 22:00-00:00 00:00 00:00-00:30 00:30 00:30-01:00 01:00 01:00-06:00 06:00 06:00-10:30 06:00-09:30 09:30 09:30-10:30 10:30 10:30-06:00 Progress Report Well S- 1 lB Page 4 Rig Nabors 9ES Date 11 August 99 Duration 1-1/4 hr 22-3/4 hr 4-3/4 hr 1 hr 2 hr Activity Flow check Opened Blind Rams and well started flowing. Observed gain of 13 bbls. Shut in well at 6.0 psi Bled pressure to 0 psi. Opened blind rams and fill well with 13 bbls seawater. Observed well static. BHA run no. 1 R.I.H. to 65.0 fl In 0.10 hr had 14.000 bbl Gain - closed in well Shut-in well. Lubed fluid into well (14 bbl). Monitor well. Observed well static. R.I.H. to 215.0 ft In 0.10 hr had 5.000 bbl Gain Well began flowing. Circulated diesel out through choke. R.I.H. to 2200.0 ft Began precautionary measures 1/2 hr 2 hr 4-1/2 hr 2 hr 1/2 hr 1/2 hr 5 hr 4-1/2 hr 3-1/2 hr 1 hr 19-1/2 hr Circulated at 2200.0 ft Hole displaced with Seawater - 100.00 % displaced Circulated from surface to surface. R.I.H. to 4500.0 ft Began precautionary measures Circulate surface to surface. Small amount of gas observed. R.I.H. to 8531.0 ft On bottom Circulated at 8531.0 ft Hole displaced with Seawater - 100.00 % displaced Circulated surface to surface. Saw cement on shakers @ bottoms up. Monitor for gas influx. Observe well static. Held safety meeting Began precautionary measures Continue to circulate hole clean and monitor. Hole stable. Tested Packer - permanent tubing conveyed - Via string Test 9-5/8" csg to 3000 psi for 30 minutes. 0 psi loss. Pressure test completed successfully - 3000.000 psi Drilled cement to 8617.0 ft Up wt. = 200 klb, dn wt.= 145-165 klb w/70 rpm, 5-7 kft-lb, 5klb on bit. 150 spm @ 1400 psi. Tagged Packer assembly Tagged top of liner. Pump 30 bbl hi visc sweep and circulate hole clean @ 150 spm, 1400 psi. BHA run no. 1 (cont...) Pulled out of hole to 95.0 ft At BHA Pulled BHA BHA Laid out Clean and clear floor. BHA run no. 2 Facility Date/Time 23 Jul 99 Progress Report PBS Pad Well S- 1 lB Page 5 Rig Nabors 9ES Date 11 August 99 10:30-12:00 12:00 12:00-14:30 14:30 14:30-17:00 17:00 17:00-22:00 22:00 22:00-23:00 23:00 23:00-00:00 00:00 00:00-01:00 01:00 01:00-03:30 03:30 03:30-04:00 04:00 04:00-06:00 06:00 06:00-10:00 06:00-09:00 09:00 09:00-10:00 10:00 10:00-19:30 10:00-10:30 10:30 10:30-12:00 12:00 12:00-13:00 13:00 13:00-14:00 14:00 14:00-18:30 Duration 1-1/2 hr 2-1/2 hr 2-1/2 hr 5 hr 1 hr 1 hr 1 hr 2-1/2 hr 1/2 hr 2 hr 4 hr 3 hr 1 hr 9-1/2 hr 1/2 hr 1-1/2 hr 1 hr 1 hr 4-1/2 hr Activity Made up BHA no. 2 BHA no. 2 made up Made up BHA no. 2 P/U 3-1/2" HWDP, 42 jts. 4" DP. Completed operations R.I.H. to 8617.0 ft On bottom Drilled cement to 9078.0 ft ART = 4-1/4 hrs, ADT = 4-1/4 hfs Stopped to test casing Up wt = 210 klb, Dn wt = 150 klb, Rot tq - 175, Tq on = 9 k, Tq off= 8 k Circulated at 9078.0 ft Pump sweep to clean hole for pressure test. Hole displaced with Water based mud ~ 100.00 % displaced Tested Casing - Via annulus and string Close rams, test to 4000 psi for 30 min. Function test completed satisfactorily Drilled cement to 9118.0 ft ART = 1/2 hr, Total DT = 4-3/4 hr. At Window: 9118.0 ft Stopped drilling 10 ft above whipstock. Circulated at 9118.0 ft Hole displaced with Water based mud - 100.00 % displaced Pumped 25 bbl hi visc. sweep and circulate hole clean Pulled out of hole to 8420.0 ft At Top of liner: 8420.0 ft POH above liner top. Serviced Block line Line slipped and cut Slip and Cut 30' of drlg line and service top drive and drum. BHA run no. 2 (cont...) Pulled out of hole to 860.0 ft At BHA Pulled BHA BHA Stood back Electric wireline work Held safety meeting PJSM = RFLI Schlumberger wireline to run cement bond log. Completed operations Rigged up sub-surface equipment - Slickline / braided cable RJU e-line unit for cement bond log. Equipment work completed R.I.H. to 150.0 ft Cement bond log failed - Abort operation POOH to change out tools. Serviced Production logging tools Work completed, Logging/braided cable equipment changed out Change out logging tools Conducted electric cable operations RIH with USIT log (this was the only back-up l:J.. V (J. IIO. UI~.,]. Facility Date/Time 24 Jul 99 PBS Pad 18:30 18:30-19:30 19:30 19:30-06:00 19:30-19:45 19:45 19:45-20:30 20:30 20:30-23:00 23:00 23:00-00:30 00:30 00:30-05:00 02:00 05:00 05:00-06:00 06:00-11:30 06:00-10:00 10:00 10:00-11:30 11:30 11:30-06:00 11:30-12:00 12:00 12:00-12:15 12:15 12:15-14:00 14:00 14:00-14:30 14:30 14:30-18:00 18:00 18:00-18:30 18:30 18:30-19:00 19:00 19:00-00:00 Progress Report Well S- 1 lB Page 6 Rig Nabors 9ES Date 11 August 99 Duration Activity 1 hr 10-1/2 hr 1/4 hr 3/4 hr 2-1/2 hr 1-1/2 hr 4-1/2 hr hr 1/2 hr hr 1-1/2 hr 18-1/2 hr 1/2 hr 1/4 hr 1-3/4 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 5 hr Completed run with Cement evaluation tool from 6503.0 ft to 8572.0 TOC @ 7815' Rigged down sub-surface equipment - Slickline / braided cable Equipment work completed R/D Schlumberger and clear floor. BHA run no. 3 Held safety meeting PJSM-PFU mill ass'y. Completed operations Made up BHA no. 3 BHA no. 3 made up R.I.H. to 9110.0 ft On bottom Drilled cement to 9170.0 ft Cement drilled at 40-50 ft/hr, w/10-15 klb on bit. Completed operations Circulated at 9170.0 ft Obtained bottoms up (100% annulus volume) Began precautionary measures Change over to drlg fluid-pump hi-vis/lo-vis sweep. Obtained clean returns. Pulled out of hole to 8000.0 ft BHA run no. 3 (cont...) Circulated at 8627.0 ft Check for flow at liner top, pump pill. Hole swept with slug - 100.00 % hole volume Blow down top drive and remove blower hose. Continue to POOH. Pulled BHA L/D excess HWDP and steel dc' s. BHA Laid out BHA run no. 4 Removed Drillfloor / Derrick Clear floor and prepare to p/u BHA #4. Equipment work completed Held safety meeting PJSM = PFU BHA #4 Completed operations Made up BHA no. 4 BHA no. 4 made up BHA wt = 15,000 lbs. Tested MWD - Via string Function test completed satisfactorily R.I.H. to 8627.0 ft RIH w/4" DP in stands to liner top. Record baseline ECD data and orient tool face 20 degrees left. Stopped: To service drilling equipment Serviced Top drive Equipment work completed R.I.H. to 9170.0 ft On bottom Drilled to 9188.0 ft Time drill from 9170' (2'/hr for 2 hrs, 4'/hr for 2 hrs, 6'/hr for 1 hr). Facility Date/Time 25 Jul 99 26 Jul 99 PBS Pad 00:00 00:00-00:15 00:15 00:15-06:00 00:15-06:00 06:00-06:00 06:00-12:00 12:00 12:00-00:00 00:00 00:00-03:30 03:30 03:30-04:30 04:30 04:30-06:00 06:00-06:00 06:00-15:30 15:30 15:30-16:30 16:30 16:30-17:30 17:30 17:30-18:45 Progress Report Well S- 1 lB Page 7 Rig Nabors 9ES Date 11 August 99 Duration Activity 1/4 hr 5-3/4 hr 5-3/4 hr 24 hr 6 hr 12hr 1/2 hr 1 hr Stopped: To hold safety meeting Crew change. Held safety meeting Began precautionary measures PJSM = Check Crown 'O' Matic, continue drilling. Drilled to 9217.0 ft AST -- 10 hrs, p/u = 190K, s/o = 165K Drilled to 9217.0 ft Time drill to 9194'. Continue to drill while sliding (ROP = 15 ft/hr, WOB = 15klb). Drilled to 9217' MD at report time. BHA run no. 4 (cont...) Drilled to 9325.0 ft (cont...) Time drill to 9194'. Continue to drill while sliding (ROP = 15 ft/hr, WOB = 15klb). Drilled to 9217' MD at report time. Stopped: To hold safety meeting Crew change, PJSM = housekeeping. Drilled to 9567.0 ft ART - 2 1/4, AST = 6 1/2, p/u = 190K, s/o = 165K, Rot wt = 175K, Torq on = 5-6K, Torq off = 3-4K. Stopped: To hold safety meeting Crew change, PJSM = Check Crown 'O' Matic--OK. Drilled to 9620.0 ft Some wall stricking on slide @ 9,620 ft ( shale stringer). ECD climbed above 8.78 threshold. ( theroretical is 8.69 ppg. Began precautionary measures Circulated at 9620.0 ft Circulate hole clean with sweep, rotating @ 40 RPM. Also while making 30' mad pass. 1-1/2 hr Hole swept with slug - 50.00 % hole volume Drilled to 9627.0 ft Continue drlg at report time. p/u = 195, s/o -- 165, rot wt = 175. 24 hr 9-1/2 hr 1 hr 1 hr 1-1/4 hr No Losses. ECD @ 8.78 ppg. BHA run no. 4 (cont...) Drilled to 9893.0 ft Stopped: To circulate Directionally drill 6.1/8" hole to 9,893'. No drag, no losses. While sliding ahead observe loss in circulating pressure and loose returns. Circulated at 9893.0 ft In 1.00 hr had 90.000 bbl Loss Observe well- Loosing at 60 to 90 bblsPnr static. Work pipe and formulate strategy. Pulled out of hole to 9100.0 ft At Window: 9100.0 ft POOH to window. Hole in good shape. Static losses @ 60 BPH. Rest hole at 9893.0 ft Facility Date/Time 27 Jul 99 PBS Pad 18:45 18:45-19:30 19:30 19:30-20:15 20:15 20:15-20:45 20:45 20:45-21:15 21'15 21:15-22:00 22:00 22:00-22:30 22:30 22:30-00:30 00:30 00:30-03:15 03:15 03:15-04:15 04:15 04:15-04:45 04:45 04:45-06:00 06:00-02:00 06:00-11:00 11:00 11:00-12:15 12:15 Progress Report Well S-1 lB Page 8 Rig Nabors 9ES Date 11 August 99 Duration 3/4 hr 3/4 hr 1/2 hr 1/2 hr 3/4 hr 1/2 hr 2 hr 2-3/4 hr 1 hr 1/2 hr 1-1/4 hr 20 hr 5 hr 1-1/4 hr Activity In 1.25 hr had 90.000 bbl Loss Observe well while building mud and fresh water volume. 60 to 70 BPH static. R.I.H. to 9893.0 ft On bottom Drilled to 9941.0 ft Began precautionary measures DRill ahead 50 ft to cross fault. Dynamic losses @ 60 BPH while drilling ahead. Pulled out of hole to 9710.0 ft At top of check trip interval POOH three stands to above fault and place PBL sub at bottom of build. Functioned Circulating sub Equipment work completed Drop vinyl ball and circulate down @ 4.4 BPM/950 psi. Open PBL sub slowing pumps down towards the last 30% of drillstring volume. Circulated at 9710.0 ft 30.000 bbl LCM pill spotted downhole, LCM content 60.0 lb/bbl Spot LCM w/medium/coarse material @ 60 ppb @ 3 BPM/520 psi, dynamic losses @ 60 BPH. Pulled out of hole to 9100.0 ft At Window · 9100.0 ft Pull back to window. Static losses 12 BPH. Circulated at 9065.0 ft Circulate DP volume and monitor losses ( Began precautionary measures PJSM @ crew change = Check Crown 'O' Matic--OK. Functioned downhole tools at 9065.0 ft Check rates @ PBL open. Stage up rate to 260 gpm. No losses. Dropped steel ball, closed PBL. Stage up rate to 280 gpm. No losses. Equipment work completed Washed to 9941.0 ft Wash to bottom @ 40 stks/min, 530 psi, no losses. On bottom Circulated at 9941.0 ft Stage pumps up to 225. No losses. Began precautionary measures Drilled to 9964.0 ft Drill ahead 6.1/8" hole. Dynamic losses @ 20-30 bph. BHA run no. 4 (cont...) Drilled to 10100.0 ft Reached planned end of run - Maximum hours on bit Drill ahead 6.1/8" hole to 10,100 ft adding 12 sx/hr barafibre and loosing 35 bbls/hr dynamic. No drag. Circulated at 10100.0 ft In 0.25 hr had 80.000 bbl Loss Circulate bottoms up @ 220 GPM/1000 psi Facility Date/Time 28 Jul 99 Progress Report PBS Pad Well S- 1 lB Page 9 Rig Nabors 9ES Date 11 August 99 12:15-12:45 12:45 12:45-13:15 13:15 13:15-14:00 14:00 14:00-15:00 15:00 15:00-17:45 17:45 17:45-18:30 18:30 18:30-19:00 19:00 19:00-19:30 19:30 19:30-23:30 23:30 23:30-02:00 02:00 02:00-06:00 02:00-06:00 Duration 1/2 hr 1/2 hr 3/4 hr 1 hr 2-3/4 hr 3/4 hr 1/2 hr 1/2 hr 4 hr 2-1/2 hr 4 hr 4 hr Activity losses @ 30 BPH suddenly increase to 80 BPH. Flow check In 0.50 hr had 30.000 bbl Loss Flowcheck well- 60 BPH static losses. Pulled out of hole to 9710.0 ft At top of check trip interval Circulated at 9710.0 ft 30.000 bbl LCM pill spotted downhole, LCM content 60.0 lb/bbl Spot medium / coarse LCM pill. Dynamic losses 60 BPH. Pulled out of hole to 9040.0 ft At Window: 9040.0 ft Pull to window. Rest hole at 9040.0 ft In 2.75 hr had 100.000 bbl Loss Observe well- initial static @ 25 BPH climbing to 50 BPH and then dropping to 25 BPH. Circulated at 9040.0 ft 30.000 bbl LCM pill spotted downhole, LCM content 70.0 lb/bbl Spot 70 ppb pill, 50 ppb fine, 20 ppb medium @ 4 BPM/730 psi. Pulled out of hole to 8400.0 ft At top of check trip interval Flow check In 0.50 hr had 10.000 bbl Loss Observe well- 25 BPH static losses. Pulled out of hole to 300.0 ft At BHA Pulled BHA BHA Laid out BHA run no. 5 Made up BHA no. 5 Make up Drilling assembly w/1.37 deg motor. Surface test same and function test PBL sub. 06:00-06:00 06:00-06:30 06:30 06:30-10:30 10:30 10:30-11:30 11:30 11:30-12:00 12:00 12:00-13:00 13:00 24 hr 1/2 hr 4 hr 1 hr 1/2 hr 1 hr Static losses 0 BPH since midnight. BHA run no. 5 (cont...) Made up BHA no. 5 BHA no. 5 made up Make up BHA. Function test PBL- erroneous pressssures. Pull back and inspect bit- OK. All surface test OK. R.I.H. to 9050.0 ft At Window: 9050.0 ft RIH- no losses. Serviced Top drive Equipment work completed Changeout HT40c 4.1/2" IF Top drive. Service top drive. Serviced Block line Line slipped Circulated at 9050.0 ft Began precautionary measures Circulate @ window and establish drilling rate- impose ECD on well- no losses. Facility Date/Time 29 Jul 99 30 Jul 99 PBS Pad 13:00-14:30 14:30 14:30-15:30 15:30 15:30-06:00 06:00-06:00 06:00-15:00 15:00 15:00-16:30 16:30 16:30-17:00 17:00 17:00-17:30 17:30 17:30-18:30 18:30 18:30-19:30 19:30 19:30-21:00 21:00 21:00-21:30 21:30 21:30-00:00 00:00 00:00-01:00 01:00 Progress Report WellS-liB Page 10 Rig Nabors 9ES Date 11 August 99 Duration 1-1/2 hr 1 hr 14-1/2 hr 24 hr 9 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr 1 hr 1-1/2 hr 1/2 hr 2-1/2 hr 1 hr Activity Washed to 9805.0 ft Stopped: To circulate Wash down to above fault @ 40 SPM/530 psi- no losses. Circulated at 10100.0 ft Obtained req. fluid properties - 40.00 %, hole vol. Circulate above fault to string out any LCM up into casing, wash thru fault @ 9,893' and stage up pumps to drilling rate- no losses. Drilled to 10450.0 ft Directionally drill 6.1/8" hole f/10,100' to 10,450'. Losses steady @ 35 BPH until 10,255'- crossed interface, losses remain steady @ 45-65 BPH. No drag. 15 sx barafibre/hr. BHA run no. 5 (cont...) Drilled to 10771.0 ft Reached planned end of run - Section / well T.D. Directional Drill 6.1/8" hole to 10,771'. Cross fault #4 @ 10,652 ft- losses increase to 120 BPH dynamic, 80 BPH static. Drill to TD. Circulated at 10771.0 ft Obtained clean returns - 30.00 % hole volume Circulate 210 bbls- x 3 Open hole volumes while rotating pipe- Dynamic losses @ 110 BPH. Pulled out of hole to 9850.0 ft At top of check trip interval R.I.H. to 10646.0 ft Stopped: To circulate Wiper trip good. Dowell on location and setting up. Circulated at 10646.0 ft Began precautionary measures Rotate/clean Hole while Dowell set up and hold Operation/Prejob meetings. Circulated at 10646.0 ft 40.000 bbl LCM pill spotted downhole, LCM content 0.0 lb/bbl Mix and Pump 40 bbls Instanseal pill to fault #4 @ 7 BPM while rotating pipe. No problems. PWD tool not reading because of excessive surface noise. Pulled out of hole to 9050.0 ft At Window: 9050.0 ft Initial static losses 60 BPH. Pull first three stands real slow-and then rotate for 15 minutes with no reciprocation- losses same. Pulll back to shoe. Circulated at 9050.0 ft In 0.50 hr had 20.000 bbl Loss Static losses 40 BPH ( 33% improvement), Dynamic @ 100 BPH. Washed to 10646.0 ft At Loss zone: 10646.0 ft Wash into hole- no problems. Circulated at 10646.0 ft Obtained req. fluid properties - 30.00 %, hole vol. Circulate x 3 open hole volumes while Dowell Mixing instanseal Facility Date/Time 31 Jul 99 PBS Pad 01:00-03:00 03:00 03:00-05:00 05:00 05:00-06:00 06:00 06:00-16:30 06:00-08:00 08:00 08:00-09:00 09:00 09:00-10:00 10:00 10:00-14:30 14:30 14:30-16:30 16:30 16:30-06:00 16:30-17:30 17:30 17:30-19:30 19:30 19:30-20:00 20:00 20:00-00:30 00:30 00:30-01:30 01:30 01:30-04:00 04:00 Progress Report Well S-lIB Page 11 Rig Nabors 9ES Date 11 August 99 Duration 2 hr 2 hr 1 hr 10-1/2 hr 2 hr 1 hr 1 hr 4-1/2 hr 2 hr 13-1/2 hr 1 hr 2 hr 1/2 hr 4-1/2 hr 1 hr 2-1/2 hr Activity Circulated at 10646.0 ft 90.000 bbl LCM pill spotted downhole, LCM content 0.0 lb/bbl Pump 90 bbls Instanseal @ 8 BPM/3300 psi. Job shut down after 40 bbls instanseal displaced from bit- valve failre. Resume pumping @ 8 BPM. Pipe static throughout. Wait 30 minutes after displacement with pipe static ( oscillating pipe after 10 minutes). Pulled out of hole to 9050.0 ft At Window: 9050.0 ft POOH real slow. Static losses @ 35 BPH. Serviced Block line Line slipped and cut Dynamic loss while circulating string contents @ 2 BPM is 60 BPH. BHA run no. 5 (cont...) Circulated at 9050.0 ft Obtained bottoms up (100% annulus volume) Circulate bottoms up @ 6 BPM/1200 psi. Dynamic losses @ 80 BPH, static 35 BPH. No polymer/gel from bottoms up. Serviced Block line Line slipped and cut Held safety meeting Completed operations Hold Technical Limit Meeting on running 4.1/2" liner. Pulled out of hole to 300.0 ft At BHA Pulled BHA BHA Laid out Static losses increase to 50 BPH. Run Liner, 4-1/2in O.D. Rigged up Tubing handling equipment Equipment work completed R/U to run 4.1/2" and hold safety meeting. Static losses @ 35 BPH Ran Liner to 1800.0 ft (4-1/2in OD) Stopped: To change handling equipment P/U 4.1/2" Liner, check floats and bakelock shoetrack. RIH to hanger. Installed Liner hanger Equipment work completed Install liner hanger and circulate liner contents. Ran Liner in stands to 9150.0 ft At Window: 9050.0 ft Circulated at 9050.0 ft String displaced with Water based mud - 100.00 % displaced Circulate pipe volume @ 3.5 BPM/350 psi, 70 BPH dynamic losses. M/U cement head and lay down on skate. Ran Liner in stands to 10771.0 ft On bottom RIH breaking circulation every 4 stands. Static losses @ 20 BPH, no resistance. Facility Date/Time PBS Pad 04:00-06:00 06:00-07:00 06:00-06:30 06:30 06:30-07:00 07:00 07:00-13:00 07:00-07:15 07:15 07:15-07:30 07:30 07:30-08:00 08:00 08:00-08:30 08:30 08:30-13:00 13:00 13:00-17:00 13:00-17:00 17:00 17:00-21:30 17:00-21:30 21:30 21:30-22:00 21:30-22:00 22:00 Progress Report Well S-1 lB Page 12 Rig Nabors 9ES Date 11 August 99 Duration 2 hr 1 hr 1/2 hr 1/2 hr 6 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 4- I/2 hr 4 hr 4 hr 4-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr Activity Circulated at 10771.0 ft Circulate x 3 annlus volumes @ 4 BPM/590 psi, 50 BPH dynamic losses. Pipe not being reciprocated. BJ batch mixing 50 bbls 15.8 ppg cement. Run Liner, 4-1/2in O.D. (cont...) Rigged up Cement head Equipment work completed Install Tee at cement head to allow lines to be flushed prior to dropping dart. Circulated at 10770.0 ft Stopped: To circulate Circulate well while batch mixing cement. Dynamic losses @ 28 BPH, static @ 14 BPH. Cement: Liner cement Pumped Water based mud spacers - volume 10.000 bbl Required volume of spacer pumped Pump 10 bbl preflush and test lines to 4500 psi. Pump 10 bbls Viscosified spacer. Mixed and pumped slurry - 50.000 bbl Tail cement pumped Pump 50 bbls, 245 sx of 15.75 ppg Cement @ 4 BPM/ 700 psi. Displaced slurry - 116.000 bbl Plug bumped Displace slurry @ 5.5 BPM/1600 psi with 60 bbls Perforation pill and 56 bbls Mud. Observe dart shear and bump plug. 21 bbls lost during pumping cement and displacement.( 20 BPH) Functioned Liner hanger Equipment work completed Pressure upto 4000 psi, check floats. Release from liner. Slack off and observe packer shear. 10 bbls lost down backside after plug bump until packer set. Circulated at 8955.0 ft Hole displaced with Seawater - 100.00 % displaced Circulate bottoms up. Trace of cement seen. Displace well to seawater @ 7 BPM/800 psi. Final NTU reading= 34. Pull Drillpipe, 4in O.D. Pulled Drillpipe in stands to -0.0 ft At Surface: -0.0 ft BOP/riser operations - BOP stack Tested BOP stack Pressure test completed successfully - 4000.000 psi Run Hanger and test same to 4000 psi. OK. Run test plug and conduct BOPE test to 250 psi/4000 psi. Witness waived by John Spaulding- AOGCC. Perform integrity test Tested Liner Pressure test completed successfully - 4000.000 psi Test well bore to 4000 psi- good. While conducting ^1 ~I T~TO ,f test h,,,,~ running guns. Facility PBS Pad Date/Time Duration 22:00-06:00 8 hr 22:00-02:00 4 hr 01 Aug 99 02:00 02:00-06:00 4 hr 06:00-19:30 06:00-07:30 07:30 07:30-08:00 08:00 08:00-08:30 08:30 13-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 08:30-09:30 09:30 1 hr 09:30-11:00 11:00 1-1/2 hr 11:00-15:30 15:30 4-1/2 hr 15:30-19:30 19:30 4 hr 19:30-06:00 19:30-20:00 10-1/2 hr 1/2 hr 20:00 20:00-20:30 20:30 1/2 hr 20:30-03:00 02 Aug 99 03:00 6-1/2 hr Progress Report Well S- 11B Page Rig Nabors 9ES Date Activity 2-7/8in. Perforation assembly workstring run Ran Tubing to 1700.0 ft (2-7/8in OD) Completed run with Perforating tools to 1700.0 ft R/U and run 120' loaded guns and 1500' of 2.7/8" Fox tubing.M/U Halliburton packer/jar equipment. Ran Drillpipe in stands to 7000.0 ft RIH on 4" drillpipe. 03:00-04:30 04:30 04:30-05:00 05:00 05:00-06:00 1-1/2 hr 1/2 hr 1 hr Total Losses on S-11Bi = 3,572 bbls. 2-7/8in. Perforation assembly workstring run (cont...) Ran Drillpipe in stands to 10565.0 ft Stopped: To correlate depth RIH and tag no go on top of 4.1/2" liner on Depth. Set packer at 8884.0 ft with 0.0 psi Packer set at 8884.0 ft Set Packer and Hold PJSM prior to firing guns. Perforated from 10430.0 ft to 10565.0 ft Interval perforated Pressure up on annulus to 2800 psi. Release pressure. Fire guns- Positive indication. No Losses. Reverse circulated at 8884.0 ft String displaced with Seawater - 200.00 % displaced Reverse Circulate string contents- No losses. 5 BPM/455 psi. Circulated at 8884.0 ft Obtained bottoms up (100% annulus volume) Release Packer- guns free. Circulate bottoms up @ 9 BPM/700 psi- no losses. Pulled out of hole to 1700.0 ft At BHA POOH, Lay down excess drillpipe. Leaving 80 stands in derrick for rig move to S-04 Laid down 1700.0 ft of Tubing Completed operations L/D Howco BHA, 2.7/8" tubing. Hold PJSM. Lay down guns- all fired. 4 BPH static losses. Run Tubing, 4-1/2in O.D. Removed Bore protector Equipment work completed Held safety meeting Completed operations Hold Technical Limit meeting and PJSM for running completion. Ran Tubing to 8955.0 ft (4-1/2in OD) Observed loss of 5.00 klb string weight Run 4.1/2", L-80, 12.6 lb/ft, NSCT tubing. 218 joints and one pup. No GLM's. Tag 4.1/2" liner tieback sleeve on depth. Space out tubulars Completed operations Ran Tubing to 8955.0 ft (4-1/2in OD) Hanger landed Reverse circulated at 8955.0 ft · n,,,o~Led dowr, baci~side · ,~,,~,se Circulate: L:~_:, seawater 13 11 August 99 Facility Date/Time Progress Report PBS Pad Well $- 1 lB Page 14 Rig Nabors 9ES Date 11 August 99 06:00-07:30 06:00-07:30 07:30 07:30-10:00 07:30-10:00 10:00 10:00-14:00 10:00-11:15 11:15 11:15-13:00 13:00 13:00-14:00 14:00 14:00-15:00 14:00-15:00 15:00 15:00-06:00 15:00-18:30 18:30 Duration 1-1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 4 hr 1-1/4 hr 1-3/4 hr 1 hr 1 hr 1 hr 15hr 3-1/2 hr Activity @ 3 BPM/150 psi. Run Tubing, 4-1/2in O.D. (cont...) Reverse circulated at 8955.0 ft Hole displaced with Inhibited brine - 100.00 % displaced Revserse Circulate inhibited brine @ 3 BPM/150 psi Fluid system Freeze protect well - 150.000 bbl of Diesel Completed operations R/U HB & R. Freeze protect well with 150 bbls Diesel. Allow to U-tube. Run Single completion, 4-1/2in O.D. Set packer at 8902.0 ft with 4000.0 psi Packer set at 8902.0 ft Drop Ball and rod. Pressure upto 4000 psi and set packer. Test Tubing for 30 minutes- good. Tested Production packer - Via annulus Pressure test completed successfully - 4000.000 psi Bleed Tubing to 2500 psi. Test annulus to 4000 psi for 30 minutes- good test. Bleed off. While bleeding hold Technical Limit Meeting on Rig Move. Rigged up Hanger plug Equipment work completed Install and test TWC. BOP/riser operations - BOP stack Rigged down BOP stack Equipment work completed Wellhead work Installed Xmas tree Equipment work completed Install and test X-tree and adaptor to 5000 psi- good. Cleaer celler. Rig Released from S-11Bi @ 1830 hrs 2nd August 1999 ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : Prudhoe Bay Well ..................... : S-11Bi API number ............... : 500292072802 Engineer ................. : N. Rose ~ig: ..................... : Nabors 9es TATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Depth reference .......... : GL above permanent ....... : KB above permanent ....... : DF above permanent ....... : MSL Driller's Pipe Tally 37.90 ft 66.40 ft 66.40 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 57.89 degrees 30-Ju1-1999 06:32:35 Page ORIGINAL Spud date ................ : 21-July 1999 Last survey date ......... : 30-Jul-99 Total accepted surveys...: 147 MD of first survey ....... : 0.00 ft MD of last survey ........ : 10771.30 ft 1 of 6 .. · Geomagnetic data Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 21-Ju1-1999 Magnetic field strength..: 1146.74 HCNT Magnetic dec (+E/W-) ..... : 27.22 degrees Magnetic dip ............. : 80.70 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1146.74 HCNT Reference Dip ............ : 80.70 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 27.22 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.22 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 -"i~:~ :~.:~ .... [(c)1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLLIMBERGER Survey Report 30-Ju1-1999 06:32:35 Page 2 of 6 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) Course length (ft) 1 0.00 0.00 0.00 0.00 2 4.00 0.00 0.00 4.00 3 103.10 0.97 249.69 99.10 4 203.10 1.00 246.19 100.00 5 303.10 0.75 231.60 100.00 6 403.10 0.60 211.00 7 503.10 0.47 190.60 8 603.10 0.32 134.90 9 703.10 0.30 116.11 10 803.10 0.55 107.12 11 903.10 0.67 116.00 12 1003.10 0.60 120.00 13 1103.10 0.42 165.40 14 1203.10 0.62 207.60 15 1303.10 0.90 221.10 16 1403.10 0.92 253.10 17 1503.10 0.90 249.60 18 1603.10 0.87 256.79 19 1703.10 1.10 271.62 20 1803.10 1.12 280.00 21 1903.10 1.27 287.21 22 2003.10 1.67 285.31 23 2103.10 2.32 299.90 24 2203.10 3.43 317.12 25 2303.10 3.47 320.12 26 2403.10 3.42 326.21 27 2503.10 3.38 332.40 28 2603.10 3.07 335.12 29 2703.10 3.13 337.62 30 2803.10 3.62 344.71 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 100.00 TVD depth (ft) 0.00 4.00 103.10 203.08 303.07 403.06 503.06 603.06 703.05 803.05 903.05 1003.04 1103.04 1203.03 1303.02 1403.01 1503.00 1602.99 1702.97 1802.95 1902.93 2002.90 2102.84 2202.71 2302.53 2402.35 2502.17 2602.02 2701.87 2801.70 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type 0.00 0.00 0 0.00 0.00 0 -0.82 -0.29 -0 -2.51 -0.94 -2 -4.03 -1.70 -3 -5.14 -2.55 -4 -5.89 -3.40 -4 -6.11 -4.00 -4 -5.90 -4.32 -4 -5.45 -4.57 -3 -4.83 -4.97 -2 -4.28 -5.49 -1 -4.14 -6.10 -1 -4.72 -6.94 -1 -5 . 94 -8 . 01 -1 -7.47 -8.84 -3 -9.01 -9.34 -4 -10.50 -9.79 -6 -12.01 -9.94 -7 -13.54 -9.74 -9 -14.98 -9.24 -11 -16.69 -8.53 -14 -18.63 -7.14 -17 -20.14 -3.93 -21 -21.11 0.58 -25 -21.60 5.38 -28 -21.46 10.47 -31 -20.89 15.51 -34 -20.09 20.47 -36 -18.72 26.04 -38 .00 .00 .79 .38 .69 .47 .82 .70 .26 .57 .58 .61 .06 .22 .99 .27 .77 .25 .95 .87 .89 .35 .51 .31 .28 .88 .90 .40 .56 .44 0.00 0.00 0.00 0.00 0.00 0.00 0.84 249.69 0.98 2.56 248.50 0.07 4.06 245.32 0.33 5.15 240.30 0.28 5.90 234.76 0.23 6.17 229.55 0.39 6.07 224.64 0.10 5.80 217.97 0.26 5.60 207.48 0.15 5.72 196.31 0.08 6.20 189.85 0.43 7.04 189.96 0.42 8.25 193.92 0.33 9.42 200.31 0.50 10.49 207.07 0.06 11.61 212.55 0.11 12.72 218.66 0.34 13.87 225.38 0.16 15.06 232.15 0.21 16.70 239.28 0.40 18.91 247.83 0.82 21.67 259.54 1.39 25.29 271.32 0.18 29.38 280.56 0.37 33.58 288.17 0.37 37.73 294~28 0.35 41.90 299.24 0.15 46.42 304.12 0.64 TIP GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO [(c)1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLUMBERGER Survey Report 30-Ju1-1999 06:32:35 Page 3 of 6 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 31 2903.10 4.00 351.62 32 3003.10 3.62 23.78 33 3103.10 4.37 49.58 34 3203.10 5.63 73.19 35 3303.10 6.13 78.69 100.00 100.00 100.00 100.00 100.00 36 3403.10 7.32 94.00 37 3503.10 7.88 109.12 38 3603.10 9.62 121.20 39 3703.10 12.00 127.00 40 3803.10 13.92 130.81 100.00 100.00 100.00 100.00 100.00 41 3903.10 16.12 133.31 100.00 42 4003.10 18.17 134.20 100.00 43 4103.10 20.35 133.40 100.00 44 4203.10 23.02 133.00 100.00 45 4303.10 25.52 133.40 100.00 46 4403.10 27.22 132.70 100.00 47 4503.10 28.72 126.92 100.00 48 4603.10 29.17 127.00 100.00 49 4703.10 29.00 127.20 100.00 50 4803.10 28.75 129.12 100.00 51 4903.10 28.72 129.90 100.00 52 5003.10 28.62 130.40 100.00 53 5103.10 28.17 130.81 100.00 54 5203.10 27.82 130.90 100.00 55 5303.10 27.42 130.50 100.00 56 5403.10 27.35 130.62 100.00 57 5503.10 27.02 130.90 100.00 58 5603.10 26.75 130.81 100.00 59 5703.10 26.32 130.62 100.00 60 5803.10 25.68 130.90 100.00 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 2901.48 3001.27 3101.03 3200.66 3300.13 3399.45 3498.58 3597.42 3695.64 3793.09 3889.67 3985.22 4079.62 4172.54 4263.69 4353.28 4441.62 4529.12 4616.51 4704.08 4791.77 4879.51 4967.48 5055.78 5144.38 5233.17 5322.13 5411.32 5500.78 5590.66 -16.40 32.53 -12.38 38.87 -6.00 44.23 2.51 48.12 12.23 50.59 22.37 51.19 31.81 48.50 39.86 41.93 47.32 31.34 54.56 17.22 61.59 -0.16 68.77 -20.56 76.81 -43.38 86.19 -68.67 96.60 -96.81 107.99 -127.12 122.58 -157.07 139.87 -186.17 157.13 -215.49 173.43 -245.32 188.59 -275.91 203.21 -306.84 217.34 -337.79 231.09 -368.49 244.79 -398.73 258.49 -428.64 271.95 -458.46 285.19 -488.04 298.39 -517.19 311.30 -545.81 -39 -39 -34 -27 -17 .78 .01 .84 .24 .31 -5 7 20 36 53 .72 .12 .74 .19 .60 72 94 117 144 174 .81 .09 .91 .85 .80 207 243 281 320 358 .26 .29 .96 .73 .70 395 432 468 504 539 .79 .46 .56 .07 .21 574.16 608.77 642.97 676.83 710.03 Total displ (ft) 51 55 56 55 53 At DLS Srvy Tool Azim (deg/ tool qual (deg) 100f) type type .39 309.28 0.60 .07 314.90 2.14 .31 321.78 1.93 .30 330.49 2.39 .47 341.11 0.75 51 49 46 47 56 .51 353.63 2.14 .02 8.35 2.07 .78 26.32 2.52 .88 49.11 2.61 .30 72.19 2.10 72 96 125 160 199 .81 90.13 2.29 .31 102.33 2.07 .63 110.20 2.20 .30 115.36 2.67 .82 118.98 2.51 243 289 337 386 434 .14 121.52 1.73 .59 122.85 3.10 .88 123.44 0.45 .40 123.90 0.20 .56 124.37 0.96 482 530 577 624 670 .47 124.88 0.38 .26 125.36 0.26 .63 125.79 0.49 .40 126.17 0.35 .62 126.48 0.44 716 762 807 851 895 .51 126.74 0.09 .09 126.98 0.35 .21 127.20 0.27 .81 127.38 0.44 .57 127.55 0.65 GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO [(c)1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLUMBERGER Survey Report 30-Ju1-1999 06:32:35 Page 4 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS Srvy Tool depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (ft) (deg) I00f) type type 61 5903.10 25.63 131.40 100.00 5680.80 62 6003.10 25.57 131.40 100.00 5770.99 63 6103.10 25.22 130.31 100.00 5861.33 64 6203.10 24.77 129.31 100.00 5951.96 65 6303.10 24.57 128.12 100.00 6042.83 66 6403.10 24.18 127.12 100.00 67 6503.10 24.13 125.70 100.00 68 6603.10 23.87 124.50 100.00 69 6703.10 23.35 124.42 100.00 70 6803.10 22.67 123.92 100.00 71 6903.10 21.92 123.12 100.00 72 7003.10 21.12 122.92 100.00 73 7103.10 21.52 123.42 100.00 74 7203.10 22.07 125.50 100.00 75 7303.10 23.00 126.92 100.00 6133.92 6225.16 6316.52 6408.15 6500.19 6592.72 6685.74 6778.90 6871.75 6964.12 76 7403.10 23.75 130.70 100.00 7055.92 77 7503.10 24.62 133.40 100.00 7147.14 78 7603.10 25.75 136.31 100.00 7237.64 79 7703.10 26.47 137.81 100.00 7327.43 80 7803.10 27.07 139.31 100.00 7416.71 81 7903.10 27.85 140.12 100.00 7505.45 82 8003.10 28.32 142.50 100.00 7593.67 83 8103.10 29.05 145.12 100.00 7681.40 84 8203.10 29.27 145.31 100.00 7768.73 85 8303.10 28.42 145.50 100.00 7856.32 86 8403.10 27.47 146.12 100.00 87 8503.10 26.82 146.70 100.00 88 8603.10 26.68 147.40 100.00 89 8703.10 25.97 146.81 100.00 90 8803.10 25.62 146.50 100.00 7944.66 8033.65 8122.94 8212.57 8302.61 323.77 -574.29 742.63 938.79 336.03 -602.87 775.05 981.91 348.59 -630.92 807.48 1024.74 361.70 -657.98 839.94 1066.97 375.41 -684.08 872.50 1108.70 389.71 -709.28 905.19 1149.97 404.69 -733.56 938.12 1190.87 420.44 -756.95 971.39 1231.49 436.37 -779.61 1004.41 1271.47 452.09 -801.57 1036.75 1310.49 127.72 0.22 127.88 0.06 128.00 0.58 128.07 0.62 128.10 0.54 128.08 0.57 128.02 0.58 127.93 0.55 127.82 0.52 127.71 0.71 467.74 -822.52 1068.38 1348.32 127.59 0.81 483.16 -842.51 1099.14 1384.89 127.47 0.80 498.37 -862.41 1129.57 1421.15 127.36 0.44 513.12 -883.42 1160.17 1458.23 127.29 0.95 527.27 -906.07 1191.09 1496.54 127.26 1.08 540.21 -930.93 1221.97 1536.18 551.38 -958.38 1252.38 1577.00 560.95 -988.40 1282.52 1619.19. 569.21 -1020.62 1312.49 1662.62 576.51 -1054.39 1342.29 1706.89 583.06 -1089.57 588.45 -1126.31 591.85 -1165.05 594.12 -1205.06 596.21 -1244.78 1372.11 1401.52 1429.85 1457.65 1485.04 597.92 -1283.54 599.10 -1321.54 599.76 -1359.31 600.36 -1396.55 601.30 -1432.90 1511.37 1536.62 1561.10 1585.18 1609.10 127.30 1.68 127.42 1.41 127.62 1.68 127.87 0.98 128.15 0.90 1752.09 1798.01 1844.40 1891.27 1937.73 128.45 0.86 128.79 1.21 129.17 1.45 129.58 0.24 129.97 0.85 1982.86 2026.74 2069.97 2112.62 2154.62 130.34 0.99 130.70 0.70 131.05 0.34 131.38 0.76 131.69 0.38 GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO GYRO [(c)1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLUMBERGER Survey Report 30-Ju1-1999 06:32:35 Page 5 of 6 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 91 8903.10 24.82 147.40 92 9003.10 23.97 147.31 93 9103.10 23.27 149.31 94 9138.00 23.22 149.94 95 9154.04 24.28 144.00 Course length (ft) 100.00 100.00 100.00 34.90 16.04 96 9170.00 24.28 144.00 15.96 97 9185.15 26.40 140.00 15.15 98 9217.66 30.47 130.00 32.51 99 9246.59 35.32 125.00 28.93 100 9279.75 40.99 120.31 33.16 TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 8393.08 8484.15 8575.77 8607.84 8622.52 8637.07 8650.76 8679.36 8703.65 8729.72 101 9310.95 46.48 115.10 31.20 8752.26 102 9341.84 51.43 109.80 30.89 8772.55 103 9372.73 53.70 104.20 30.89 8791.33 104 9404.56 54.53 100.89 31.83 8809.99 105 9435.59 57.46 99.25 31.03 8827.35 602.01 -1468.61 602.39 -1503.39 602.11 -1537.47 601.69 -1549.35 601.80 -1554.76 1632.34 1654.62 1675.67 1682.64 1686.16 602.25 -1560.07 602.92 -1565.17 606.45 -1576.02 611.96 -1585.53 620.73 -1596.53 1690.02 1694.02 1704.99 1717.47 1734.72 631.61 -1606.51 645.13 -1615.36 661.19 -1622.51 679.54 -1628.10 698.60 -1632.59 1753.82 1775.35 1798.79 1823.96 1849.28 106 9467.15 58.58 98.11 31.56 8844.06 718.87 -1636.63 1875.75 107 9497.25 59.85 94.65 30.10 8859.47 739.10 -1639.50 1901.44 108 9528.35 62.93 92.10 31.10 8874.36 761.34 -1641.10 1928.69 109 9558.88 68.00 89.83 30.53 8887.04 784.61 -1641.55 1956.45 110 9588.79 73.70 88.37 29.91 8896.84 808.76 -1641.10 1984.69 111 9622.20 80.25 85.32 33.41 8904.37 837.23 -1639.30 2017.16 112 9652.79 86.26 82.77 30.59 8907.96 864.49 -1636.15 2047.36 113 9683.99 90.82 7'9.64 31.20 8908.76 893.12 -1631.38 2078.17 114 9715.89 91.75 78.37 31.90 8908.04 922.87 -1625.30 2109.48 115 9746.04 92.57 74.42 30.15 8906.91 951.43 -1618.21 2138.76 116 9778.11 93.98 71.36 32.07 8905.07 982.36 -1608.79 117 9809.67 98.19 68.57 31.56 8901.73 1013.03 -1598.05 118 9840.68 101.88 65.11 31.01 8896.32 1043.19 -1586.05 119 9874.45 106.19 61.16 33.77 8888.13 1075.79 -1571.26 120 9902.32 107.70 57.82 27.87 8880.01 1102.44 -1557.73 2169.35 2198.83 2226.89 2256.11 2279.08 2195.76 2235.61 2274.14 2287.31 2293.56 2300.00 2306.39 2321.81 2337.44 2357.58 2378.39 2400.26 2422.43 2444.90 2466.82 2489.37 2510.66 2532.40 2553.89 2575.30 2599.28 2620.81 2642.01 2662.98 2681.95 2700.80 2718.20 2733.97 2749.34 2760.56 131.98 0.89 132.26 0.85 132.54 1.06 132.64 0.73 132.68 16.30 132.71 0.00 132.74 17.98 132.75 19.23 132.71 19.20 132.62 19.19 132.49 21.03 132.30 20.59 132.05 16.16 131.75 8.82 131.44 10.41 131.11 4.69 130.77 10.74 130.39 12.24 130.00 17.93 129.59 19.61 129.10 21.53 128.63 21.32 128.13 17.72 127.61 4.93 127.11 13.37 126.56 10.49 126.01 15.97 125.46 16.19 124.86 17.08 124.35 12.68 Srvy Tool tool qual type type GYRO - GYRO - GYRO - MWDInterpreted AZI MWDInterpreted AZI MWDInterpreted AZI MWDInterpreted AZI" MWDInterpreted AZI MWDInterpreted AZI MWD 6 - axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis [ (c)1999 Anadrill IDEAL ID6 0C 04] ANADRILL SCHLUMBERGER Survey Report 30-Ju1-1999 06:32:35 Page 6 of 6 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD depth (ft) 121 9933.07 108.10 57.96 30.75 8870.56 122 9964.94 109.54 57.13 31.87 8860.28 123 9995.40 113.00 53.75 30.46 8849.22 124 10026.33 114.69 49.93 30.93 8836.72 125 10055.80 115.24 49.34 29.47 8824.28 126 10087.61 112.08 46.50 127 10118.10 109.98 45.71 128 10149.20 107.29 44.84 129 10181.05 105.32 44.53 130 10211.23 103.05 43.61 131 10242.60 99.30 41.83 132 10273.95 96.19 41.27 133 10302.54 93.16 41.23 134 10335.31 88.97 39.85 135 10366.91 85.88 39.05 136 10398.91 82.20 38.62 137 10430.31 79.57 35.71 138 10461.36 78.72 31.70 139 10493.45 78.00 27.33 140 10525.27 77.23 22.55 141 10556.73 77.20 20.74 142 10584.64 77.48 20.06 143 10617.18 78.11 20.67 144 10649.82 78.57 20.32 145 10680.48 79.10 20.55 146 10711.32 79.44 19.10 31.81 30.49 31.10 31.85 30.18 31.37 31.35 28.59 32.77 31.60 32.00 31.40 31.05 32.09 31.82 31.46 27.91 32.54 32.64 30.66 30.84 8811.51 8800.57 8790.63 8781.69 8774.30 Survey Projected to TD 147 10771.30 79.44 8768.22 8763.99 8761.66 8761.05 8762.47 8765.80 8770.77 8776.62 8783.10 8789.93 8796.89 8803.01 8809.89 8816.48 8822.42 8828.16 Vertical Displ Displ Total At DLS section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (deg) I00f) 1131.70 -1542.18 2303.86 2772.38 1161.87 -1525.99 2329.32 2784.66 1190.22 -1509.90 2352.69 2795.52 1218.34 -1492.43 2374.93 2804.93 1244.78 -1475.13 2395.29 2813.08 1273.47 -1455.60 2416.90 2821.38 1301.32 -1435.87 2437.41 2828.90 1330.08 -1415.13 2458.34 2836.55 1359.84 -1393.40 2479.84 2844.49 1388.25 -1372.38 2500.19 2852.08 1417.94 -1349.77 2521.06 2859.65 1447.75 -1326.52 2541.66 2867.00 1475.05 -1305.10 2560.44 2873.88 1506.31 -1280.21 2581.73 2881.72 1536.26 -1255.84 2601.79 2889.02 1566.33 -1231.05 2621.75 2896.38 1595.33 -1206.35 2640.47 2902.99 1623.14 -1180.99 2657.39 2908.00 1650.79 -1153.64 2672.87 2911.21 1676.86 -1125.47 2685.98 2912.24 1701.60 -1096.96 1723.21 -1071.44 1748.43 -1041.62 1773.83 -1011.68 1797.71 -983.49 2697.29 2911.82 2706.78 2911.13 2717.85 2910.62 2729.04 2910.53 2739.55 2910.73 1821.56 -954.98 2749.82 2910.93 19.10 59.98 8839.15 1867.52 -899.27 2769.12 123.80 1.37 123.23 5.15 122.69 15.36 122.15 12.55 121.63 2.60 121.06 12.87 120.50 7.30 119.93 9.05 119.33 6.26 118.76 8.08 118.16 13.19 117.56 10.08 117.01 10.60 116.38 13.46 115.77 10.10 115.15 11.58 114.55 12.40 113.96 12.98 113.35 13.53 112.73 14.87 Srvy tool type MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD 112.13 5.61 MWD 111.60 2.58 MWD 110.97 2.67 MWD 110.34 1.76 MWD 109.75 1.88 MWD 109.15 4.75 MWD 2911.48 107.99 0.00 MWD Tool qual type 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6 -axis Projected [ (c) 1999 Anadrill IDEAL ID6 0C 04] 8/10~99 GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AITN: Sherrie NO. 12740 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Job # Log Description Date BL Sepia CD iX-3A PRODUCTION LOG/GHOST 990727 1 1 N-15 .-l-L ~::~"~,,~ 99260 CNTD 990601 1 1 1 S-11B 99309 USIT 990723 1 Color PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Bivd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 3940 Arctic BI 3940 Arctic BIvd, Suite 300 Anchorage, t Anchorage, AK 99503-5711 Al-tN: Sherrie TONYKNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: ('907) 279-1433 FAX: (907) 276-7542 June 29. 1999 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-66.12 Re: Prudhoe Bay Unit S-1 I Bi BP Exploration (Alaska) Inc. Permit No: 99-53 Sur. Loc. 1646'SNL, 1855'EWL. Sec. 35. T12N. R12E. UM Btmholc Loc. 2771'NSL. 67453/EL. Sec. 35. T12N. R12E. UM Dear Mr. Stone: Enclosed is thc approved application for permit to redrill the above referenced well. Thc 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 ali other required permitting determinations are made. Thc blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and thc mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope p~er at 659-3607. Robert N. Christcnson. P. E. Chairman BY ORDER OF THE COMMISSION dlffEnclosurc CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .... STATE OF ALASKA ' ALASKA oIL AND GAS CONSERVATION COM~vllSSION PERMIT TO DRILL 20 AAC 25.005 ila. Type of work [] Drill [] Redrill lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil ' [] Re-Entryr ~ Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 70.90' Prudhoe Bay Field / Prudhoe !3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028257 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1646' SNL, 1855' EWL, SEC. 35, T12N, R12E, UM . Prudhoe Bay Unit At top of productive interval 8. Well Number Number 25100302630-277 2004' NSL, 1305' WEL, SEC. 35, T12N, R12E, UM S-11Bi At total depth 9. Approximate spud date Amount $200,000.00 2771' NSL, 674' WEL, SEC. 35, T12N, R12E, UM 06/30/99 12. Distance to nearest property line113. Distance to nearest well ~14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028260, 2771'I No Close Approach 2560 10807' MD / 8821' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9138' Maximum Hole Angle 115° Maximum surface 2725 psig, At total depth (TVD) 8675' / 3600 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-M 1867' 8990' 8474' 10807' 8821' 208 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Abandonment Plug #1 - 17 Bbls Class 'G' (12/98) Total depth: measured 11050 feet Plugs (measured) Abandonment Plug #2 - 30 Bbls Class 'G' (12/98) true vertical 8749 feet Effective depth' measured 8528 feet Junk (measured) 4" Drill Pipe with 4-3/4" BHA. Total length is 553' located from 9297' - 9850'. (12/98) true vertical 8056 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20"x 30" 8 cu yds Concrete 110' 110' Surface 2650' 13-3/8" 3767 cuft Arcticset II 2679' 2679' Intermediate 9107' 9-5/8" 1240 cuft Class 'G', 130 cu ft AS I 9136' 8605' Production Liner 1377' 7" 390 cu ft Class 'G' 8627' - 9138' 8144' - 8607' RECEIVED measured NoneORIGI^ ,4L, ,,., Perforation depth: true vertical None Alaska 0il & Gas Cons. C0mmissi0ft Annhnmoe 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch ~[] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements ,,, Contact Engineer Name/Number: Bill Isaacson, 564-5521 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Sto~ Commission Use Only Permit Number APl Number I Approval Date letter -~ ~ See cover /~/42~-- ~ 50-029-20728-02 I ¢~ ~-¢~, ~--- ' y for other requirements Conditions of Approval: Samples Required []Yes ~,l~No Mud Log Required ~_.Yes 'J~No Hydrogen Sulfide Measures []YesJ~No Directional Survey Required .l~Yes [] No Required Working Pressure for BOPE []2K; [-13K; ,.~4K; [] 5K; I--I 10K; [] 15K Other: by order of ORIGINAL SIGNED-BY Commissioner the commission Date Approved By Form 10-401 Rev. 12-01-85 Submit In Triplicate S-11 Bi Permit to Drill I Well Name: IS-11Bi Sidetrack Plan Summary I Type of Redrill (producer or injector): I Injector Surface Location- 3633' FSL 3425' FEL S35 T12N R12E Umiat Target Location: 2004' FSL 1305' FEL S35 T12N R12E Umiat Bottom Hole Location: 2771' FSL 674' FEL S35 T12N R12E Umiat I AFE Number: 14P1288 [Estimated Start Date: 16/30/99 I I MD: I~ 0,807' I I Rig: I Nabors9ES I Operating days to complete: 113 ITVD: 18821' I IBF/MsL: 139.4, I IRKs: [70.90' I Well Desitin (conventional, slimhole, etc.): I Horizontal Sidetrack I Obiective: I Restore injection into upper Zone 4 sands, targeting bypassed oil in the area. Mud Program: Production Mud Properties: Quickdril-n 16" hole section Density (ppg) Funnel vis LSRV LSR YP pH 8.3 - 8.6 40-55 <20,000 cP 10-20 8.5-9.0 Directional: KOP: I 9138'MD Maximum Hole Angle: Close Approach Well- 115° @ 10,051' (8753' TVD) None Logging Program: Production Hole(Horizontal) Drilling: MWD / GR / Resistivity / PWD Open Hole: None Formation Markers: Formation Tops MD TVDss Comments Kick-off Point 9138' 8540' Sag River 9147' 8547' Shublik 9194' 8587' Top Sadlerochit 9300' 8675' Est. pore pressure 3600 psi (8.0 ppg EMW) TZ4 9300' 8675' S-11 Bi Permit to Drill Maximum TVDss 9661' 8828' Maximum TVDss Planned TZ3 8852' Not Penetrated TZ2 8910' Not Penetrated HOT 8955' Not Penetrated OOWC 9000' Not Penetrated TZ1 Not Penetrated Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tb~l O.D. MD/TVD MD/TVD 6" 4 1/2" 12.6# L-80 IBT-M 1867' 8990'/8474' 10,807'/8821' Tubing 4 1/2" 12.6# L-80 NSCT 8907' -33'/33' 8940¥8427' NOTE: The 4 1/2" production liner will be a Bonzai style completion with the solid cemented section covering all but the end 400 to 450' of hole section, which will be left as an open hole barefoot completion. As a contingency, the liner will be a solid cemented liner all the way to TD. Cement Calculations: Liner Size 14 1/2" Production I Basis: Tail: Based on 1269' of 6" x 4.5" annulus over the solid cemented portion of the liner with 50% excess, 150' of 7" x 4.5" liner lap, and 200' of 7" x 4" DP annulus volume. Tail TOC' At linertop - 8990' MD (8474' TVD). Total Cement Volume' I Tail 137 bbl/208 f¢ / 176 sk of acid resistant Halliburton I I Premium 'G' at 15.8 ppg and 1.18 cf/sk. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. · Maximum anticipated BHP: 3600 psi @ 8675' TVDss - Zone 4 · Maximum surface pressure: 2725 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/fi) · Planned completion fluid: 8.5 ppg Seawater / 6.8 ppg Diesel Drilling Hazards/Contingencies: HYDROGEN SULFIDE- H2S Pad is not designated as an H2S drill site. The highest level of H2S measured on S-11 has been 100 ppm with recent measurements below 10 ppm. However, S-11 Bi Permit to Drill standard Operating Procedures for H2S precautions should be followed at all times. DRILLING CLOSE APPROACH: · None PRODUCTION SECTION: · Lost circulation is a concern based upon the prior history on the S-11Ai sidetrack. The S-11 Bi will cross one small fault, however the lost circulation risk is felt to be Iow. · Differential sticking will be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time. · The kick tolerance for the 7" shoe would be an infinite influx (annular volume) assuming an influx at section TD of 10,807'. This is a worst case scenario based on an 8.0 ppg pore pressure, a minimum fracture gradient of 10.0 ppg at the 7" window, and 8.3 ppg mud in the hole. Disposal'. No annular injection in this well. Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC- 2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. SUMMARY SIDETRACK PROCEDURES Pre-Ric~ Work: 1. Test the McEvoy 9-5/8" mandrel packoff and tubing hanger seals to 5000 psi for 30 minutes. 2. Bleed tubing and annuli pressures to zero. Set a BPV in the tubing hanger and test from below to 1000 psi. Secure well. 3. Remove the well house and flowlines. If necessary, level the pad. Please provide total well preparation cost on the handover form. Ri.q Operations: 1. MIRU Nabors9ES. 2. Nipple down tree. Nipple up and test BOPE. 3. RIH with 8-1/2" bit on clean-out assembly and drill cement from 8528' to top of 7" liner. Pressure test 9-5/8" casing against cement plug. P©OH. 4. RIH with 6" bit on clean-out assembly and drill cement from 7" liner top to -9123' (+/-15' from top whipstock). POOH. 5. RIH with 7" Baker whipstock window mills and clean out cement across whipstock face, as required. S-11 Bi Permit to Drill 6. RIH with 6" drilling asssembly. Kick-off and drill the 6" production hole section building 15.8°/100' to horizontal, targeting the Zone 4 sands. Drill ahead to an estimated total depth of 10,807' MD (8821' TVD). 7. Run and cement a 4 Y2", 12.6# Bonzai production liner (solid liner cemented above an ECP, with open hole barefoot section below), leaving the bottom -400' of the 6" wellbore open hole. As a contingency (for geologic reasons), the liner will be a solid cemented liner all the way to TD. 8. Test the 4 Y2", 7", and 9-5/8" casing from the 4-1/2" landing collar to surface to 4000 psi for 30 minutes. 9. Displace well to clean seawater above the 4-1/2" liner top and POOH laying down DP. 10. Run 4 Y2", 12.6# L-80 NSCT completion tying into the 4 Y2" liner top. 11. Test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes with 2000 psi on the tubing. 12. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 13. Freeze protect the well to -2200' and secure the well. 14. Rig down and move off. 15. The 4 Y2" liner will be cleaned out and the ES Cementer drilled out, with coiled tubing after the rig is moved off location. If the liner is a solid cemented liner, the well will be perforated post rig with coiled tubing. Estimated Pre-rig Start Date: 06/27/99 Estimated Spud Date: 06/30/99 William Isaacson Operations Drilling Engineer 564-5521 ..... S-1 1 / S-1 1 A WAG Iniect~.~~: Current Wellbore Status ~ [8-11 Wellhead: BF/MSL = 39.40' ~ Nabors 7ES: RT/MSL = 66.40' O) Tubing hanger landed in wellhead with ~ jt of 4-'1/2" tubing below hanger. , , I ~ i ~ 13-3/8", 72#, L-80 ~ Top of cement plug tagged with DP at 8582' and pressure tested to 3000 psi, Top of Cement @ 8528' ~ )~ ~~ Top of 7" 26, L-80 Buttress __ __ Rig i Suspension ! ~ement Plug 17./12/98 ~ · ~ ~ 9-5/8" 47# L-80 Buttress K.O.P @ 9138'(2' below 9-5~8" shoe) Buiid i.~ Sag ..River andJ Shublik ~o horizontal ir~ Zo~e ~. TD at Dressed Cmt Top ~ 315'of4"HT40DrilIP_ewithJarlNM-HW_PIMWDIMoIorlBit Bit 9850' ~. ;iI ~~. ~ ~,os0' q~t'~'') Perforations:~ 9288' - 9450' ~-~----- Jo450'J Cmt / Carbolite : 12/89 I I ! Sqz'd Sqz'd Perforations: i 9450' - 9580' PBTD ~ ~k ~ 7" 26# L-80 DATE REV. BY COMMENTS PRUDHOE BAY UNIT 06/03/99 WSI Current Wellbore WELL: S-11 A APl NO: 50-029-20728-131 SEC 35 .- T12N: R12E BP Exploration Alaska TREE: 4-1/16 "- 5M CIW L-80 WELLHEAD: 13 5/8" - 5M McEvoy 13-3/8", 72 #/ft, L80, BTC S-11 Bi Proposed Completion 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 2200' Cellar Elevation = 37.9' Base Flange = 39.4' Nabors 7ES RKB = 70.9' 4-1/2" 12.6# L-80, NSCT Tubing Top of 7" Liner at I 8627' 9-5/8", 47 #/ft, US0, BTC ~ Kick-off from existing Whipstock window at +/-9138' MD 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'S-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide spaced-out into 4-1/2" liner tie-back sleeve. I +~8988' I BAKER 5"x 7" Tie Back Sleeve ZXP Liner Top Packer 'HMC' Hydraulic Liner Hanger I +/-10,400' I 4-1/2" 12.6 #/ft, L-80, BTC-Mod w/Baker CTC ECP Open Hole Barefoot Completion to TD at I +/'10,807' I Date Rev By Comments PRUDHOE BAY UNIT 6/04/99 WSI Proposed Completion WELL: S-11 Bi APl NO: 50-029-20728-02 Shared Services Drilling 7", 26 #/ft, L80, IJ4S I 10,004' I i ....... H'ARED 'SERVI CE'S .... 'DRILLj i Narker Identification ND 8KB SECI'N IN~LN 8871 A) TIE-IN SURVEY B) TOP WHIPSIOtK C) BASE BHIPSTOCK K(]P/fiURVE i5,8/i00 HAX TVO El,lO :15.8/i00 C UFIVE G) CUPIVE 14/100 H) TARGE'I END i4J}O0 gURVE dt CURVE KJ TARGET 2 L] END ~4/i00 CURVE M) 4-i/2" LNR PT. N) TD 9103 9134 9i59 9~76 9661 9684 9706 9730 10051 10082 10263 i0455 ~0807 ~OBO7 8576 8604 8627 8642 8899 8898 8897 8896 8824 B77~ 8782 882i 8821 1959 1972 2341 233 2384 2407 265i 2666 Z762 2887 ~69 2869 23.27 23,22 26,39 26,39 90,00 93,36 93.36 90.00 ]15.32 i15.32 90.OO 63.62 83.§2 83.62 ~4nadr ~ 71 Sch] umber_qer (P6A) VERTICAL SECTZON .... . Section at: 10~.62 TVO Scale' 1 inch = ~50 ~eet Oep Scale ' 1 inch = ~50 feet Drawn ' ~2 May i999 .... i F:T;~,S,{':.2); iT'" D ' ' · , .,_.. . t.t..,-~,,i'.,1 ; ~'~.~ A.? /ED ~FOR E,"~ ~-...U T ON · ............ ~ '~ ......... _.,, ,~~. ~~get, _ .~ l~oint. ', ~ .. 2- [ .% ~ ..... ...... , ,. ~ ~~~~ ............... ~ FG q ....... ~ .... ~ , ...................... . ....... ~ . , ............. ,. ~ ~ ............ Section Departure mmm ....... . mm mmm mmmm m . .. : _2 .. m mm m m m mm mmm m mm, mm,, m mm i m . mm m mira . mmm I mm Imm Im m VIEW ~> Z ~> t~ IT1 ANADRILL DEC PAGE 08 SHARED , SERVZCES S-i~B (P6A) PLAN V[E~ i , , CLOSURE ' 8884 fee[ at Azisuth ~07.40 DECLINATION.' +27.487 (E} SCALE ' 1 inch = 200 feet DRAWN - 2~ Nay Jgg9 ... .4na~rj]] $ch]u~beng, er .,, DRZLLZNG Marker Identt ficat~on A) TIE-IN SURVEY MD N/S E/W C) SASE WHIPSTOCK 9~59 ~557 S~688 E O) KQP/CURVE iS.B/~O0 g~76 ~563 ~692 ~ .~XTV. 9~ ~TS ~054E Fi ~NO ~5.a/~o¢ cURVE 9~4 ~¢35 s~o~7 E 6] CURVE M/JO0 9706 ¢632 S2099 E ~] ENO t4/JO0 CURVE JOOS~ i500 $ 2398 E ~) CURVE ~4/~00 ~oo~ ~4.o s24m ~ K} TARGET 2 $0263 ~356 S254i E L) END M/lO0 CURVE ~045~ ~]g4 S26a~ E H) 4-]/~' LNR PT ~0807 88~ S 2752 E __ kEAS ~91LI'FY PLA,~.. ': --/ N()T APPR~]VE~) FOR. PLAN " . ...... . /.' ¢¢ / ..... ~~ ~z~~~ - ., , -., ~ , ~ % ...... ~ ~, .,, ~ .., ~, t500 1600 1700 t800 1900 2000 2100 2200 2300 2~00 2500 2600 2700 2800 2go0 EAST Anadril 1 Schlumberger Alaska District 3940 Arctic Blvd Anchorage AK 99503 (907) 273-1700 Fax $6L-8537 DIRECTIONAL WELL PLAN for 3I{ARED SERVICES DRILLIbrG ~ell ......... : S-lIB (P6A} Field ........ : Frudhc~ Bay Computation,,: MinimumCiu-va~ure Units ........ : FEET Surface tat..: 70,35356805 Surface Loo9.: 149.02543937 Legal Oescrip~io~ Surface ...... : 3633 FSL 3425 FEL S35 T12N R12E U~4 Tie~£~ survey: 2096 FSi 1751 F~ S35 T12N R12E UM Tar~e~ l ..... : 2004 FSL 1305 FEi S35 TL2N R12E UM Target 2 ..... : 22?7 ~91 886 FEL 935 T12N R12E LR~ B}tL .......... : 2771 ~L 67¢ FEi S35 T12N R12E ~ I_~TXO~S - ALASKA Zone: ~ X-Coord Y-Coord 620017.00 5979855,0D 621716.95 597S344.69 6~2165,0~ 5978260.~0 6225?9,00 5978548.0~ 6227~2.06 5979837.00 WELL PROFILE Prepared ..... : 12 May 1999 vert sect az.: KB elevation.: 70.90 f~ Magne~i= Dcln: +27.487 Scale Factor.: 0.99991636 Convergence..: ~0.91755573 ,N,'-',D~,~ L h AKA-:_.'~ ,_. FEASIBILITY' PLAN NOT APPROVED FOR EXECUTION PLAN ,:¢¢' STAT ~O~ ~~ ~N~ OI~ION ~TI~-DEPT~ SE~ON TIE-IN S~VBY 9103,10 23.27 149,31 8575.77 8~04.87 19~1.05 TOP ~[PST~K 9L3~. 06 25.22 149,87 86~%.I6 8~33.26 i959,21 B~S ~IPSTOCK 9159.0~ 26.39 145.1~ 8626,~6 8565.96 1966.66 KOP/C~ 1S.8/10O 9176.00 26.39 143.10 8642.09 8571,19 1972.32 9260,00 28,39 136. ~9 8663.40 8592.50 1981.03 COORDII~]ATES-Fk~OM WBGE,..qEAB 1537,47 $ 1675.67 1556.78 $ ~87,66 15~2.74 S ALASKk Zone 4 TOOL X Y FACE 621716.95 597834~.69 621723,29 5978334.28 621729,24 5978325.66 1692.2~ E 62~733.87 $978319,?0 3699.36 E 621~41.17 5978311.43 MAX TVD 9300.00 39.44 125.52 8746,53 8675.63 2D31 9400.00 52.66 103.39 $8lS ,91 8745.01 2102~80 9500.00 66.74 95.04 8866.31 ~795 . ~1 2185.7l 9600,00 81.17 88 ,32 8893 .91 8823.01 2283.02 9660.73 90 ,00 84 .~$ 8898 .58 8827- 68 2341,39 1602.13 S ~744,80 E 623787,09 5978281.I6 1625.17 S 15~2.56 E 621855.21 5978259.21 163~.49 3 1897.53 ~, 621940.38 597S247.25 1641.10 S 1993.28 E 622036~~5 5978246.18 ~637,33 S 9053.65 E 622~96,44 5978250.gl EI~D 15.8/100 CTFRVE 9683.85 93.36 83.13 8897,90 8827,00 2363.39 ~634.85 ~ 2076.62 E 622119.36 5978253,76 lO3R 451 0.73 ~S 17,00 611 0.00 555 ~5-80 381 15,80 291 15.80 25L 15.80 231 lS. 80 231 15,80 HS 15.80 (Anadrill (c)99 S1LBP6A 3.2C 8:31 ~Y.i P) STATfON IDKWTIFICATION TARGET END 14/[00 C93RVE CURVE 14/[00 TARGET 2 E~TD 14}100 Ct~Ua 4-[/2" L~R PT TO MEASURED INCLN DEPT~ ANGL~ 9705.94 93.36 9729,97 90,00 9800,00 95.92 9900.00 lOODO.O0 DIRECTION VERTICAL-DEPTHS AZ~MUT8 T993 SUB-SEA 83.33 8896,60 8825,~0 $3.~3 8895.90 8825.00 75.30 8692.28 852L.38 63.79 887~.81 8803.91 51.44 8843.87 8772.9? ~ECT[ON DEPART 2384.3~ 2471.66 2554.94 2623~38 10050.78 115',32 ~0081,97 115,3~ 10i80.00 l~2.80 10200.00 98-80 10262.83 90.00 [0300,00 ' 88.72 10400.00 85.3~ 10454.9~ 83.62 ~0807.2I 83,62 [0807.2[ 83,62 ,, COORDiNATES-FROM ALASKA Zone 4 WELLHEAD X Y 1632.2~ S 2098.52 E 6221~1.22 £g782~6.~5 ~629.3~ S 212Q.35 · 6~[65.00 $978~60.00 ~616-28 S 2190.97 E 622233.40 5978274.[6 [582.0~ S 2283.04 K 622324,S9 597S309,$3 1531.47 S 2363,24 E 622&04,27 $9~8361.71 44.70 8823,56 8752.66 2650,96 1500.42 S 44-70 $810.22 8739.32 2666.36 [480.38 $ 44.70 8802.87 8731.97 2675.34 146S.68 S 44.70 8775.7[ 8704,8~ 2727.73 1400.46 S 44.~0 8~70,90 8700.00 2761.89 1~55,g8 S 39.66 8771.31 8700.41 2780.79 [328.~5 S 26,05 8776.49 8705.59 2816.88 1244.78 $ 18.52 8781.77 8710,87 2826.99 1194.23 S [8.52 8820.90 ~75O.00 2869.06 862,26 S 18.52 8820.90 $750.00 2869,06 862.26 S TOOL OL/ FACE 10O 0 53L 14.~0 5SL 1~. OO sgL [4.00 2397.86 S 622438.39 5978393.~0 }tS 14.00 2417.70 E 622457.90 5978%13,66 LS 0-00 2429.27 E 622469.28 5978425.54 LS 14.00 2496.79 E 622535,70 5998494.82 LB 14.00 2540.82 E 622579.0O 59~8540.00 L04L 14.00 2565.77 ~ 622603.50 5978567,93 104~ 14.00 2619.82 E 6226S6.2[ 5978652.~5 ' 103L T4.0O 2640.55 E 622676.12 5978703.32 }tS 14,00 2751.77 E 622782.80 $979037~00 0.00 27~.77 E 622782.00 5979037.~0 O.D0 ~-,~ ,..' :. ..... AKA ~." ;'"C NOT APPROVED FOR EXECUTION PLAN Z H rq c'-) {Anadrill (c)99 SSSBP~A 3,2C ~:31 AM P) CD O3 hared e !ces Alaska )r il ng WELL NAME S-11Bi DRILLING PERMIT/SUNDRY/PRE-RIG COVER SHEET The attached work cannot commence without obtaining the required signatures in I the "APPROVAL TO PROCEED" section at the bottom of this cover sheet. "APPROVAL TO PROCEED" will signify AOGCC approval has been received. This cover sheet is applicable to: (only one categor.v per cover sheet) DRILLING PERMIT ~'~ Permit Documentation Prepared: ODE:I-~' ~. ~,, Date: [~-'] Permit Application Reviewed: SDE/ES: ~ .n,~. ~ Date: ~ Permit~Application~ Submitted: TA :~_~~ ~_~~ Date: ~'/~//~ PRE-RIG WORK D r"l Pre-Rig Memo Reviewed: SDE/ES: Date: Pre-Rig Memo Sent to Slope: ODE: Date: Pre-Rig Sundry Documentation Prepared: ODE: Date: Pre-Rig Sundry Application Reviewed: SDE/ES: Date: Pre-Rig Sundry Application Submitted: TA: Date: SUNDRY NOTICE D Sundry Documentation Prepared: ODE: Date' ~'] Sundry Application Reviewed: SDE/ES: Date: D Sundry Application Submitted: TA: Date: NOTE: IF SUNDRY IS FOR PRE-RIG WORK~ USE PRE-RIG WORK SECTION AT BELOW LEFT AND CHECK "ABANDON" BOX BELOW Reason for Sundry (Check all that apply) Abandon Alter Casing Suspend Repair Well Plugging Pull Tubing Variance Other(Explain): Change Approved Program Operation Shutdown Re-enter Suspended Well Time Extension Perforate Stimulate ~ ~,J N - 0 1999 APPROVAL TO PROCEED Alaska Oil & Gas Cons. Commission ~cnorago Approved AOGCC Permit/Sundry Received TA: Date: Approval to Commence Operations SDE/ES: Date: STATE OF ALASKA ALASKA O,~_AND GAS CONSERVATION COM; ...... ,JSION APPLICATION FOR SUNDRY APPROVAL I1. Type of Request: []Abandon [] Suspend [] Plugging [-]Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well []Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1646' SNL, 1855' EWL, SEC. 35, T12N, R12E, UM At top of productive interval N/A At effective depth 2978' SNL, 3396' EWL, SEC. 35, T12N, R12E, UM At total depth 4167' SNL, 5093' EWL, SEC. 35, T12N, R12E, UM Type of well: I'-I Development [--] Exploratory [--I Stratigraphic [~ Service 6. Datum Elevation (DF or KB) KBE = 66.90' 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number S-11Al 9. Permit Number 98-230 / 398-331 10. APl Number 50-029-20728-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11050 feet true vertical 8749 feet Effective depth: measured 8528 feet true vertical 8056 feet Casing Plugs (measured) Junk (measured) Length Size Cemented Structural Conductor 110' 20" x 30" 8 cu yds Concrete Surface 2650' 13-3/8" 3767 cu ft Arcticset I1 Intermediate 9107' 9-5/8" 1240 cu ft Class 'G', 130 cuft AS I Production Liner 1377' 7" 390 cuff Class 'G' Abandonment Plug #1 - 17 Bbls Class 'G' (12/98) Abandonment Plug #2 - 30 Bbls Class 'G' (12/98) 4" Drill Pipe with 4-3/4" from 9297' - 9850'. (12/98) MD 110' 2679' 9136' 8627' - 9138' BHA. Total length is 553' located 'l-VD 110' 2679' 8605' 8144' - 8607' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 1 Joint of 4-1/2" tubing to about 40' Packers and SSSV (type and measured depth) None 13. Attachments [~ Description summary of proposal F'-I Detailed operations program ~--I BOP sketch 4. Estimated date for commencing operation June 30, 1999 16. If proposal was verbally approved Name of approver contact Engineer Name/Number: Bill Isaacson, 564-5521 Date approved 15. Status of well classifications as: ~] Oil [] Gas [] Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.,... ,,~,..~. ~ Dan Stone Title Senior Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity_ BOP Test ~ Location clearance __ Mechanical Integrity Test__ Subsequent form required 10- I Approval No. ,,~-- Approved by order of the Commission Commissioner Date Form 10-403 Rev. 06/15/88 Submit In Triplicate H 1,5 0 2 91 I V~NDOR ALASKAST 14 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET O32&~5 CKO32&~gD 100. O0 100. O0 HANDLINO INST: S/H TERRI HUBBLE X4&~8 THE AWACHEO CHECK IS IN PAYME~ FOR ~MS DE~RIBED ABOVE. ~;e]f~l~ ] O0 ;:~,:':,::: .; CEEVEEAND QHIO ...... · ': ::: ' :?56-389 ': ' "'"' 412 PAY TO" The! Or d er .':;. :::'.:~OOli?'PORCUP INE:.?;DR' ::;":. ". ONE !!::HUNDRED. &. ::i:00/1.******************************************* ";US: DDLLAR " I °3/::'~/"~ I i ' ;[~-~' '°°1 · ' ?~;:;.. :::;: ..:~ "' NO~ VAL D A~ER 1~ DAYS .: . · .... ; '.' 'ALASKA STATE~DEPT OF REVENUE . :,::,: .~:.: :.,. ...:: ... mi' & 50 E ~ &Il' m'-O m., & E~I2) -~,q, qi Sm.' O0,q, m., m., & qll' FIELD & POOL ¢ d-//d~/~_t'~ INIT CI_ASS ADMINISTRATION 1. 2. 3. 4. 5. 6. o 8. 9. 10. 11. ,~R DATE 12. ENGINEERING 14. WELL NAME/~'~_,/ ,-~-///.,~,~' PROGRAM: exp ~ dev ~ redrll_~)~' serv ~ wellbore seg ann. disposal para req ~ (~P~ DA~E Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... //-__ .,, .~ ~_,.~ GEOL AREA N 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~Oc..J~ .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ~:'-,~ UNIT# ,///_/~.<~'~___) ON/OFF SHORE GEOLOGY 29. Is presence of H2S gas probable ................. Y 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory..e~ly] Y N APPR DATE 35. With proper cementing~cecords, this plan (A) will contain was~n a suitab,~J.e~'eceiving zone;/,,/'. ..... Y N (B) will not contajatinate fres~ater; or cause d/rifling waste... Y N to surface,;/ ,/ ~ (C) will not~pari mec~nicaHntegrity oHhe well used for disposal; Y N (D) will,,~t damage/Ffoducing formation or impair recovery from a Y N pe"01; and ~" (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N G E _0_L_O,,~, ENGINEERING: UlC/Annular / CO~MM.J__S.~ JDH --"'-'7_-- /' RNC-- Comments/Instructions: c:\msoffice\wordian\diana\checklist
