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Home My WebLink About201-165CAUTION: 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: WAG Injector M-13A (PTD #2011650) will lapse on AOGCC tests Date:Monday, April 29, 2024 9:40:21 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, April 26, 2024 1:42 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector M-13A (PTD #2011650) will lapse on AOGCC tests Mr. Wallace, WAG Injector M-13A (PTD # 2011650) is due for a WFL and AOGCC MITs per CO 736 in May of 2024. The well is currently shut-in and there are no plans to put the well on injection. It will now be classified as NOT OPERABLE for tracking purposes. 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, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: Date: 07/11/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL Well API # PTD # Log Date Log Company Log Type Notes BCU 18RD 50133205840100 222033 6/11/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/18/2022 Yellowjacket GPT-PERF + Report BCU 18RD 50133205840100 222033 6/7/2022 Yellowjacket GPT-PLUG + Report BCU 24 50133206390000 214112 6/16/2022 Halliburton PPROF BCU 24 50133206390000 214112 5/23/2022 Yellowjacket GPT-PERF + Report BCU 24 50133206390000 214112 5/26/2022 Yellowjacket GPT-PERF + Report BCU 7A 50133202840100 214060 6/21/2022 Yellowjacket CBL BCU 7A 50133202840100 214060 6/15/2022 Yellowjacket GAMMA RAY + Report BRU 232-26 50283200770000 184138 5/25/2022 Yellowjacket CBL CLU 01RD 50133203230100 203129 5/19/2022 Yellowjacket PERF + Report CLU 01RD 50133203230100 203129 5/24/2022 Yellowjacket PERF + Report CLU 09 50133205440000 204161 5/27/2022 Yellowjacket PERF + Report CLU-1RD 50133203230100 203129 5/28/2022 Halliburton PPROF + Report END 1-17A 50029221000100 196199 5/26/2022 Halliburton LDL END 1-45 50029219910000 189124 5/23/2022 Halliburton LDL + Report END 3-17F 50029219460600 203216 6/15/2022 AK E-Line PLUG CUT FALLS CREEK 3 50133205240000 203102 6/4/2022 Yellowjacket PERF + Report HVB B-16 50231200400000 212133 6/14/2022 AK E-Line CIBP KALOTSA 1 50133206570000 216132 7/7/2022 Yellowjacket PERF + Report KBU 11-07 50133205560000 205165 6/16/2022 Yellowjacket GPT-PERF + Report KBU 11-07 50133205560000 205165 6/20/2022 Yellowjacket GPT-PERF + Report KBU 33-06X 50133205290000 203183 6/22/2022 Yellowjacket CBL MPU B-28 50029235660000 216027 5/27/2022 Halliburton LDL MPU B-28 50029235660000 216027 5/27/2022 Halliburton MFC + Report MPU B-30 50029235710000 216153 5/18/2022 Halliburton PERF MPU E-06 50029221540000 191048 5/28/2022 Halliburton MFC + Report Kaitlyn Barcelona Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 564-4422 Received By: Date: MPU E-35 50029236150000 218152 6/15/2022 Halliburton MFC + Report MPU L-50 50029235550000 215132 6/24/2022 Read COIL FLAG PAXTON 10 50133206910000 220064 5/27/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton PPROF + Report PBU C-24B 50029208160200 212063 5/28/2022 Halliburton RBT PBU GNI-03 50029228200000 197189 6/25/2022 Read CALIPER PBU GNI-03 50029228200000 197189 6/25/2022 Read TEMP-PRESS PBU K-01 50029209980000 183121 6/21/2022 Halliburton PPROF + Report PBU M-13A 50029205220100 201165 5/27/2022 Halliburton TMD3D-WFL + Report PBU NGI-05 50029201960000 176014 6/7/2022 Halliburton CAST PBU W-01A 50029218660100 203176 6/8/2022 Halliburton RBT SRU 241-33 50133206630000 217047 6/13/2022 Yellowjacket PERF SRU 241-33B 50133206960000 221053 5/25/2022 Halliburton TEMP-PRESS SRU 32A-33 50133101640100 191014 6/11/2022 AK E-Line PPROF Please include current contact information if different from above. BCU 18RD PTD:222-033 T36747 BCU 24 PTD:214-112 T36748 BCU 7A PTD:214-060 T36749 BRU 232-26 PTD:184-138 T36750 CLU 01RD PTD:203-129 T36751 CLU 09 PTD: 204-161 T36752 CLU1RD PTD:203-129 T36751 END 1-17A PTD:196-199 T36753 END 1-45 PTD:189-124 T36754 END 3-17F PTD:203-216 T36755 Falls Creek 3 PTD:203-102 T36756 HVB B-16 PTD:212-133 T36757 Kalosta 1 PTD:216-132 T36758 KBU 11-7 PTD:205-165 T36759 KBU 33-06X PTD:203-183 T36760 MPU B-28 PTD:216-027 T36761 MPU B-30 PTD:216-153 T36762 MPU E-06 PTD: 191-048 T36763 MPU E-35 PTD:218-152 T36764 MPU L-50 PTD:215-132 T36765 Paxton 10 PTD:220-064 T36766 PBU C-24B PTD:212-063 T36767 PBU GNI-03 PTD:197-189 T36768 PBU K-01 PTD:183-121 T36769 PBU M-13A PTD:201-165 T36770 PBU NGI-05 PTD:176-014 T36771 PBU W-01A PTD:203-176 T36772 SRU 241-33 PTD:217-047 T36773 SRU 241-33B PTD:221-053 T36774 SRU 32A-33 PTD: 191-014 T36775 Kayla Junke Digitally signed by Kayla Junke Date: 2022.07.12 12:56:51 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-13A PRUDHOE BAY UNIT M-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 M-13A 50-029-20522-01-00 201-165-0 W SPT 8346 2011650 2086 818 829 828 827 2 2 2 2 OTHER P Adam Earl 5/26/2022 MIT-IA tested as per CO 736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT M-13A Inspection Date: Tubing OA Packer Depth 366 2406 2273 2234IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220529072415 BBL Pumped:1.6 BBL Returned:1.5 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 :$*LQMHFWRU,$FHPHQWVTXHH]HMEU 9 per CO 736 James B. Regg Digitally signed by James B. Regg Date: 2022.06.15 14:57:43 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector M-13A (PTD #2011650) AOGCC required MIT-T passed Date:Wednesday, May 25, 2022 9:24:21 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, May 23, 2022 7:40 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Injector M-13A (PTD #2011650) AOGCC required MIT-T passed Mr. Wallace, Slickline set a TTP and performed an AOGCC witnessed MIT-T on 05/22/22. The well will now be classified back to OPERABLE. Once the well is online, it will require a Waterflow log and an online AOGCC witnessed MIT-IA. 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 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, April 30, 2022 5:49 AM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector M-13A (PTD #2011650) will lapse on AOGCC required MIT-T Mr. Wallace, WAG Injector M-13A (PTD #2011650) is due for a 2-year MIT-T by the end of April. Slickline has been unable to access the well due to the Drilling Operations on M-201. The well is now classified as NOT OPERABLE and will be shut-in until the MIT-T has been completed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the 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. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-13A PRUDHOE BAY UNIT M-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 M-13A 50-029-20522-01-00 201-165-0 N SPT 8346 2011650 2086 502 2350 2275 2251 0 0 0 0 OTHER P Brian Bixby 5/22/2022 MIT-T as Per SUNDRY # 318-331 and Conservation Order 736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT M-13A Inspection Date: Tubing OA Packer Depth 514 649 657 655IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220522154509 BBL Pumped:2.6 BBL Returned:2.1 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 :$*LQMHFWRU,$FHPHQWVTXHH]HMEU MIT-T Conservation Order 736SUNDRY # 318-331 James B. Regg Digitally signed by James B. Regg Date: 2022.06.15 11:30:11 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 15, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC M-13A PRUDHOE BAY UNIT M-13A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/15/2022 M-13A 50-029-20522-01-00 201-165-0 N SPT 8346 2011650 2086 443 559 579 583 0 0 0 0 OTHER P Brian Bixby 5/22/2022 MITIA as per SUNDRY # 318-331 and Conservation Order 736 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT M-13A Inspection Date: Tubing OA Packer Depth 510 2344 2189 2151IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB220522155128 BBL Pumped:1.1 BBL Returned:0.8 Wednesday, June 15, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 :$*LQMHFWRU,$FHPHQWVTXHH]HMEU 9 MITIA SUNDRY # 318-331 Conservation Order 736 James B. Regg Digitally signed by James B. Regg Date: 2022.06.15 11:32:59 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector M-13A (PTD #2011650) will lapse on AOGCC required MIT-T Date:Thursday, May 5, 2022 12:20:10 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, April 30, 2022 5:49 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector M-13A (PTD #2011650) will lapse on AOGCC required MIT-T Mr. Wallace, WAG Injector M-13A (PTD #2011650) is due for a 2-year MIT-T by the end of April. Slickline has been unable to access the well due to the Drilling Operations on M-201. The well is now classified as NOT OPERABLE and will be shut-in until the MIT-T has been completed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance 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 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 responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 29, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. M -13A PRUDHOE BAY UNIT M -13A Ste: Inspector Reviewed B�yr:r�� P.I. Supry ilk Comm Well Name PRUDHOE BAY UNIT M -13A API Well Number 50-029-20522-01-00 Inspector Name: Lou Laubenstein InSp Num: mitLOL200515061145 Permit Number: 201-165-0 Inspection Date: 5/14/2020 - Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 M -13A - Type In W -TVD 8346 Tubing 437 437 837 437 p - PTD 2011650 T e Test SPT Test si 2086 - IA 435 2496. 2388 - 2339 1 yp -- — p I4 BBL Pumped: 1.5 BBL Returned: 1.4 OA 2 2 2 2 - Inter 8 OTHER - P/F P — Notes: MIT -IA every 2 -years per CO 736 (remedial inner Annulus cemented) ODA 300/300/300/300psig Friday, May 29, 2020 Page I of I Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:201-165 6.50-029-20522-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10896 8 9031 1RQH 8345 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 32 - 112 32 - 112 Surface 2670 13-3/8" 31 - 2701 31 - 2700 4930 2670 Intermediate 9183 9-5/8" 29 - 9212 29 - 8507 6870 4760 Intermediate 9318 7" 27 - 9345 27 - 8627 7240 / 8160 5410 / 7020 Perforation Depth: Measured depth: 10645 - 10735 feet True vertical depth:8711 - 8718 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 24 - 9197 25 - 8494 9031 8345Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 1740 3-1/2" x 3-3/16" x 29155 - 10895 8456 - 8760 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 00Shut-In 0Shut-In 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Worthington, Aras J Aras.Worthington@bp.com Authorized Name:Worthington, Aras J Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4102 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:3XPSEEORIVXUIDFWDQWZDVKEEORISSJPXGSXVKEEORISSJ&HPHQWZLWK &HP)LWEEORIPXGSXVK3XVKHGEEORIFHPHQWLQWR,,$72&LQ,,$a3XPSHGEEOV&ODVV*FHPHQWWKURXJKUHWDLQHUEEOVUHWXUQHGRQ VXUIDFHOHDYLQJDQ(72&LQWKH,$# )LQDO3UHVVXUHV$2*&&0,7,$3$66('WRSVL2$SVL,$SVL7%*SVL 13. Interventions & Integrity Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8761 Sundry Number or N/A if C.O. Exempt: 318-331 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028260 PBU M-13A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Operations shutdown Change Approved Program Other:IA Squeeze API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 11:23 am, Jun 11, 2020 Aras Worthington Digitally signed by Aras Worthington Date: 2020.06.11 05:10:38 -08'00' RBDMS HEW 6/12/2020DSR-6/11/2020 SFD 6/16/2020MGR11JUN2020 ACTIVITYDATE SUMMARY 12/19/2018 ***WELL S/I ON ARRIVAL SWCP 4518***(cement squeeze) DRIFT W/ 3.80'' CENT & S-BAILER TO PX-PLUG @ 8989' SLM. RAN 40 arm CALIPER FROM 8,978' SLM TO SURFACE. PASSING MIT-T. PULL P-PRONG FROM PX PLUG BODY FROM 8989' SLM. ***CONTINUE WSR TO 12/20/18*** 12/20/2018 ***CONTINUE WSR FROM 12/19/18 SWCP 4518***(cement squeeze) PULLED PX-PLUG BODY @ 8994' SLM(9012' MD). ***WELL LEFT S/I ON DEPARTURE*** 5/14/2019 ***WELL SHUT I ON ARRIVAL*** HES RELAY UNIT #46 LRS LOAD TBG W/ 200 BBLS CRUDE ATTEMPT TO SET 4-1/2" CBP ***CONT. ON 05/15/2019 WSR*** 5/15/2019 ***CONT. FROM 05/14/2019 WSR*** RAN MAXFIRE, DPU & 4-1/2" (3.66" O.D.) HES OBSIDIAN CBP, SET PLUG @ 8981' MD, CCL TO M.E. = 13.4', CCL STOP @ 8967.6' MD. PUNCHED TUBING FROM 8960.5' - 8965.5' USING 2" TITAN CHARGES, CCL- TOP SHOT=8.6' , CCL STOP @ 8951.9 MD. SET 4-1/2" (3.66" O.D.) HES FAS DRILL SVB RETAINER @ 8943' MD, CCL TO M.E. = 15.3', CCL STOP @ 8927.7' MD. ***CONT. ON 05/16/2019 WSR*** 5/16/2019 ***CONT. FROM 05/15/2019 WSR*** RIG DOWN HES RELAY UNIT #46 ***JOB COMPLETE, WELL LEFT S/I*** 6/21/2019 CTU #9 2" coil 0.156 WT Objective: 2 stage cement IIA/IA MIRU. MU BOT/HES cement stinger bha. ***In progress*** 6/22/2019 CTU #9 2" coil 0.156 WT Objective: 2 stage cement IIA/IA Roll coil to diesel before rih. At 2800' while rih, close choke and pressure up well to ~1000psi to verify FASDRILL retainer passes a PT. Continue in hole, sting in with no issues, pick up 10' and paint a white flag in prep for cleanout/reverse out. Stung in again no issues, stack 10k down at surface. PT down CTBS to 1000psi. Circulate IIA to diesel. Pumped a total of 181bbls. Stay stung in while standby for cementers. Decision made to pooh and RU a MM bypass and PT tools to ~6k. ***In progress*** Daily Report of Well Operations PBU M-13A Daily Report of Well Operations PBU M-13A 6/23/2019 CTU #9 2" coil 0.156 WT Objective: 1st stage cement IIA/IA POOH. Rerig iron to include a MM bypass. PT down to disconnect 6k. MU/RIH with cement stinger. RU/PT cementers. Circ well over to KCl on bottom. Sting back in and get a good 1000psi backside PT to confirm stung in. Establish 1:1 returns via IIA. Pump 10bbl of surfactant wash, 7bbl of 11ppg mudpush, 21.7bbl of 14.65ppg Cement with CemFit, 6.5bbl of mud push. Pushed 19bbl of cement into IIA. TOC in IIA ~7875. Unsting laying in the last 2bbl of cement. Reverse circulate a clean out down to 10' above the retainer. POOH. Well freeze protected with 38bbl of diesel. IIA/IA held a delta of ~80psi for the entire job. RDMO. ***Job Complete*** 7/10/2019 ***WELL SHUT IN ON ARRIVAL*** RUN RBT FROM TAG AT 8921' TO 7500', FOUND TOC AT 7874'. SET HES 4.5 OBSIDIAN CPB AT 8491' RIH WITH CH/WB/WB/CCL/FH/10' 2" 60 PHASE 6SPF JRC BH HSC ***JOB CONTINUES ON 11-JUL-19 WSR*** 7/11/2019 ***JOB CONTINUES FROM 10-JUL-19 WSR*** RIH W/ 2" X 10' PERF GUNS 6 SPF AND 60* PHASING PERFORATE FROM 8466-8476' RIH W/ 4-1/2" HES COMPOSITE FASDRILL SVB CEMENT RETAINER SET CEMENT RETAINER ME @ 8452'. TOP OF PLUG @ 8,451'. ***JOB COMPLETE/DSO NOTIFIED*** 7/12/2019 CTU #9. 2.0" Coil ***Continue from 7/11/19*** Job Scope: IA x OA Squeeze Repaired unit outrigger @ SLB shop. MIRU. Perform seven day BOP test. While making up MHA unit lost hydraulic pressure. ***Job in Progress*** 13 hrs NPT; 10 for outrigger repair, 1.5 for replacing inner reel vavle, 1.5 for trouble shooting hydraulics Daily Report of Well Operations PBU M-13A 7/13/2019 CTU #9. 2.0" Coil ***Continue from 7/12/19*** Job Scope: IA x OA Squeeze Finish replacing hydraulic pump valve body. RIH with stinger assembly and tag SSSVN. POOH and reconfigure tool string. RIH and sting in. Establish circulation and then roll IA over to diesel. Pumped 259 bbls Class G cement through retainer, 194.8 bbls returned on surface leaving an ETOC in the IA @ 856'. Well stayed on steady 0.4 bpm losses throughout job. IIA pressure began rising during pumping, attempted to bleed down through half inch bleed hose and losses increased to 0.6 bpm without a pressure drop. Unknown volume of cement most likely flowed into IIA. Cement returns never seen at surface. Shut down pump w/ one bbl cement left in coil and had a static circ pressure of 2500 psi and static WHP of 450 psi, unstung to lay in last bbl and retainer appeared to fail as tubing pressure increased up to 1800 psi. Came online w/ coil pump and laid in last bbl of cement keeping 2700 psi on tubing. Began POOH pumping 1/1 of 1% KCL keeping WHP above 2600 psi. F/P tubing w/ diesel from 2500' to surface. Trapped 2600 psi on well and shut in. Pumped 0.2 bbls diesel into IA to ensure valve cavity was clean even though no cement was returned. Popped off well and broke down tools. Pumped ten bbls inhibitor through coil and prepared to blow down reel w/ SLB N2 unit. ...In progress... 3 hrs NPT for hydraulic issues 7/14/2019 CTU #9. 2.0" Coil ***Continue from 7/13/19*** Job Scope: IA x OA Squeeze Blow down reel w/ SLB N2 unit. Complete rig down. Travel to SLB yard for pipe swap. ***Complete*** 7/22/2019 CTU#9 1.75" CT. Job Scope: Mill Cement/Plugs - Post Sqz MIRU CTU. Make up and RIH with 3.80" PDC mill and 2.875" motor. Tag cement at 8366 CTM and begin milling. Mill Cement & Plugs down to lower CBP at 8969' ctm. Pump 20 bbl gel sweep & chase ooh. MU & RIH w/ 2-7/8" Milling BHA w/ Venturi/Burnshoe. ***Continue Job on 7/23/19 WSR*** 7/23/2019 CTU#9 1.75" CT. Job Scope: Mill Cement / Plugs - Post Sqz Continue Rih w/ Venturi/Burnshoe. Mill CBP & push to LTP at 9163'. Pooh. Recover element and plug parts. MU & RIH with 3-1/8" Venturi w/ 3.80" Mule Shoe. Recover a screen full of rubber. Re-run same venturi. Tag at 9165 and venturi. Depth correction flag painted. OOH with venturi and had minimal debris. Make up and RIH with 2.35" mill. Tag LTP at 9165'. Attempt to mill/push plug thru LTP with no success. Not making progress. Pooh. ***Continue Job on 7/24/19 WSR*** 7/24/2019 CTU#9 1.75" CT. Job Scope: Mill Cement / Plugs - Post Sqz Pump 10 bbl gel sweep & chase ooh. Stack down & change packoffs. Make up & Rih w/ 3.70" centralizer & 2.31" Junk Mill. Stalled repeatedly, POOH. Marks indicate that the mill made it into the LTP. Make up and RIH with 2.300" burnover shoe and venturi BHA. Tag at similar depths and punch through. CBP debris pushed down to 10853. Pull out of liner and perform injectivity test. 3bpm @1037psi. Freeze Protect Tbg w/ 38 bbls 50/50 Methanol. Rig Down CTU. ***Job Complete*** Daily Report of Well Operations PBU M-13A 7/31/2019 ***WELL S/I ON ARRIVAL*** (Cement squeeze) DRIFT TUBING TO 9,050' SLM & BRUSH X-NIPPLES W/ 4-1/2" BRUSH, 3.80" G- RING. ***JOB IN PROGRESS, CONTINUED ON 8/1/19 WSR*** 8/1/2019 ***CONTINUED FROM 7/31/19 WSR*** (Cement squeeze) LRS LOADED TUBING W/ 200 BBLS OF DIESEL. SET 4-1/2" PX PLUG W/ FILL EXTENSION AT 9,002' SLM / 9,012' MD. LRS PERFORMED PASSING MIT-T TO 2577 PSI. LRS PERFORMED PASSING MIT-IIA TO 2,524 PSI. PULLED P-PRONG FROM PLUG BODY @ 9,012' MD ***CONT WSR ON 8/2/19*** 8/1/2019 T/I/O/OOA=O/Vac/Vac/0 Assist Slickline (Cement Squeeze) MIT-T PASSED to 2577 psi per SL WSL Lee Grey (2750 psi max, 2500 psi target). Loaded tubing with 200 bbls diesel. SL set plug. Pumped 3.4 bbls diesel down TBG to reach test pressure for MIT-T. 1st 15 min TBG lost 130 psi. 2nd 15 min TBG lost 44 psi, total loss of 174 psi in 30 min. Bled TBGP over to IA. MIT-IA PASSED to 2524 psi (2750 psi max, 2500 psi target). Final Test, pressured up IA with 1.3 bbls of DSL for a total of 7.5 bbls pumped. 1st 15 min IA lost 156 psi, 2nd 15 min IA lost 66 psi for a total of 222 psi over 30 mins. Bled back 1.6 bbls. Slickline in control of well. FWHP's 10/300/0/0. IA, OA = OTG. Tags hung 8/2/2019 ***CONT WSR FROM 8/1/19*** (cement squeeze) PULLED 4 1/2" PX-PLUG BODY FROM 9,012' MD ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 4/23/2020 ***WELL S/I ON ARRIVAL***(integrity) R/U SWCP 4521 & LRS ***CONT WSR ON 04/24/20 4/24/2020 ***JOB CONTINUED FROM 23-APRIL-2020*** (Pressure Test Integrity) SET 4-1/2" PX-PLUG BODY @ 8,995' SLM / 9,012' MD. SET P-PRONG IN PX-PLUG BODY @ 8,995' SLM / 9,012' MD. LRS ACHIEVED A PASSING PRE STATE WITNESSED MIT-T ON 5TH ATTEMPT (see LRS log for details). LRS ACHIEVED A PASSING PRE STATE WITNESSED MIT-IA ON 3RD ATTEMPT (see LRS log for details). LRS ACHIEVED A PASSING STATE WITNESSED MIT-T (see lrs log) LRS ACHIEVED A PASSING STATE WITNESSED MIT-IA (see lrs log) PULLED PRONG & PX PLUG BODY FROM X NIPPLE @ 9,012' MD (missing packing) RAN 5' x 3.0" PUMP BAILER TO LINER TOP PACKER @ 9,155' SLM / 9,155' MD (no recovery) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 4/25/2020 ***JOB CONTINUED FROM 24-APR-2020*** (Gas Lift Integrity) FINISH RIGGING DOWN SWCP 4521. ***JOB COMPLETE ON 25-APR-2020*** 5/11/2020 T/I/O/OO = 450/530/10/200. Temp = 118°. WHPs (Post POI/Pre MIT). On PWI. IA FL @ surface, OA FL @ near surface, OOA FL @ surface. OOAP increased 200 psi since Ops bled yesterday. SV = C. WV, SSV, MV = O. IA, OA, OOA = OTG. 13:10 Daily Report of Well Operations PBU M-13A 5/14/2020 T/I/O/OO = 437/435/2/300. Temp = 122°. AOGCC MIT-IA PASSED to 2339 psi, Max Pressure = 2500 psi, Target Pressure = 2250 psi (Regulatory compliance). On PWI. State witnessed by Lou Leubenstein. IA FL @ surface. Used 1.5 bbls of DSL to pressure up IAP to 2496 psi. IAP lost 108 psi in the 1st 15 minutes and 49 psi in the 2nd 15 minutes for a total loss of 157 psi in 30 minutes. Bled IAP to 430 psi (1.4 bbls), continued IA bleed to 130 psi. Hung tags. Final WHPs = 440/130/0+/300. SV = C. WV, SSV, MV = O. IA, OA, OOA = OTG. 12:00 5/16/2020 ***WELL INJECTING ON ARRIVAL*** MIRU E-LINE LOG BASELINE TEMPERATURE PASS FROM SURFACE TO 9000' LOG WARM BACK PASSES 1 HOUR AND 2 HOURS AFTER BRINGING WELL ONLINE FROM 9000' - 7500' TAKE IMPULSE SURVEYS AT 9000', 8500', 8000', AND 7500' RDMO E-LINE ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE Wallace, Chris D (CED) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Tuesday, May 19, 2020 10:53 AM To: AK, GWO SUPT Well Integrity; AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; 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 TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Infanti, Samuel; Stechauner, Bernhard; Wallace, Chris D (CED); Huber, Kenneth J Cc: Regg, James B (CED); AK, GWO DHD 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; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J; Lau, Jack; Mcmullen, John C Subject: OPERABLE: Injector M -13A (PTD #2011650) CO 736 testing complete All, Injector M -13A (PTD # 2011650) recently underwent an IA cement job, to repair a production casing leak and IAx0A communication. It passed an AOGCC witnessed offline MIT -T and MIT -IA on 04/24/20 and online AOGCC MIT -IA on 05/14/20. A water flow log was completed on 05/16/20. The well is now reclassified OPERABLE. Please reply with any questions. Ryan Holt BP Alaska Well Integrity (Alternate: Adrienne McVey) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Monday, May 4, 2020 5:40 AM To: AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AkOPSGC2Field PTL@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WeIIpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPadDFTN2@bp.com>; AK, OPS Well Pad HUQ <AKOPSWellPadHUQ@bp.com>; AK, OPS Well Pad LV <AKOPSWeliPadLV@bp.com>; AK, OPS Well Pad MN <AKOPSWellPadMN@bp.com>; AK, OPS Well Pad RJ <AKOPSWellPadRJ@bp.com>; AK, OPS WELL PAD S <AKOPSWELLPADS@bp.com>; AK, OPS Well Pad SW <AKOPSWellPadSW@bp.com>; AK, OPS WELL PAD W <AKOPSWELLPADW@bp.com>; AK, OPS Well Pad Z <AKOPSWeliPadZ@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Infanti, Samuel <samuel.infantil@bp.com>; Stechauner, Bernhard <Bernhard.Stechauner@bp.com>;'ch ris.waI lace @alaska.gov' <chris.waIlace @alaska.gov>; Huber, Kenneth J <Kenneth.Huber@bp.com> Cc: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen@bp.com> Subject: UNDER EVALUATION: Injector M -13A (PTD #2011650) Put on injection following IA cement job All, Injector M -13A (PTD # 2011650) recently underwent an IA cement job, to repair a production casing leak and IAxOA communication. It passed an AOGCC witnessed offline MIT -T and MIT -IA on 04/24/20. The well is ready to be put on injection, and is now reclassified UNDER EVALUATION. A waterflow log and an online AOGCC MIT -IA will be conducted, per CO 736. Plan Forward: 1. Operations — put well on injection 2. E -Line — Waterflow log 3. Downhole Diagnostics —AOGCC MIT -IA 4. Well Integrity — monitor IA, additional diagnostics as required Please reply with any questions. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, May 4, 2020 5:40 AM To: AK, GWO SUPT Well Integrity; AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; 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 TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Infanti, Samuel; Stechauner, Bernhard; Wallace, Chris D (CED); Huber, Kenneth J Cc: Regg, James B (CED); AK, GWO Well Integrity Well Information; AK, GWO DHD 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; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J; Lau, Jack; Mcmullen, John C Subject: UNDER EVALUATION: Injector M -13A (PTD #2011650) Put on injection following IA cement job All, Injector M -13A (PTD # 2011650) recently underwent an IA cement job, to repair a production casing leak and IAxOA communication. It passed an AOGCC witnessed offline MIT -T and MIT -IA on 04/24/20. The well is ready to be put on injection, and is now reclassified UNDER EVALUATION. A waterflow log and an online AOGCC MIT -IA will be conducted, per CO 736. Plan Forward: 1. Operations — put well on injection 2. E -Line — Waterflow log 3. Downhole Diagnostics — AOGCC M IT -IA 4. Well Integrity— monitor IA, additional diagnostics as required Please reply with any questions. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 MEMORANDUM TO: Jim Regg I \ � S �op,I Iv" P.I. Supervisor FROM: Austin McLeod Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 13, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. M -13A PRUDHOE BAY UNIT M -13A Sre: Inspector Reviewed By: P.I. Supry JJr '�— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT M -13A API Well Number 50-029-20522-01-00 Inspector Name: Austin McLeod Permit Number: 201-165-0 Inspection Date: 4/24/2020 Insp Num: mitSAM200424203300 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M -13A 'Type Inj N TVD 8346 "' Tubing 54 95 _ 111 122 II— -- - PTD -- 2011650 'Type 'fest, SPT ',Test psi'. 2086 IA 9 2512 2386 2345 - BBL Pumped: 1.6 113131, Returned: 1.4 OA 4 4 4 4 interval' INITAE �P/F P ' Notes: MIT -IA per "Conservation Order 736" post lA cement squeeze/pre-injection. Sundry 318-331. 2250psi target. CO 736 requires MIT every 2 years. Wednesday, May 13, 2020 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Austin McLeod Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 13, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. M -13A PRUDHOE BAY UNIT M -13A Sre: Inspector Reviewed By: 6rComP.I. Supry 06r— Comm m Well Name PRUDHOE BAY UNIT M -13A API Well Number 50-029-20522-01-00 Inspector Name: Austin McLeod Permit Number: 201-165-0 Inspection Date: 4/24/2020 ' Insp Num: mitSAM200424202215 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well M -13A Type InI N ",TVD 8346 Tubing 0 2530 2440 2404' PTD — - --- - - -- --- - _ - - -- __ 2011650 Type Test, SPT ',Test psi '� 2086 IA 6 165 160 156 BBL Pumped: L Returned: 2.4 OA 4 4 4 4 Interval INITAL P/F P Notes: MIT -T per "Conservation Order 736" post IA cement squeeze/pre-injection. Sundry 318-331. 2250psi target. 55 psi left on tubing once bled. Plug in X -nipple at 9012 ft MD. CO 736 requires MIT every 2 years. ✓ Wednesday, May 13, 2020 Page I of I WELL LOG TRANSMITTAL #905811344 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: M -13A Run Date: 7/10/2019 201165 31101 August 8, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 M -13A Data in LAS fonnat, Digital Log Image files 50-029-20522-01 RECEIVED AUG 13 2019 AOGCC 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com and GANCPDC@USAANC.hou Date: elvZow Signed: • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMOON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate 0 Repair Well H. Operations shutdown 0 Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Cement IA H _ 2. Operator Name: BP Exploration(Alaska),Inc 14. Current Well Class: t Exploratory ❑ Development5. Permit to Drill Number 201-165 3. Address: P.O.Box 196612 Anchorage,AK p ❑ H 6. API Number 50-029-20522-01-00 99519-6612 Stratigraphic ❑ Service • 7. If perforating: icy ala.. j y What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: ® i..�.s Will planned perforations require a spacing exception? Yes ❑ No H PBU M- 3A ' -F 12 2016 9. Property Designation(Lease Number): 10. Field/Pools: l }�/`�/1�1�'►U ADL 0028260 PRUDHOE BAY,PRU Fja•IL Al� ,►��I'�., �,_� 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: I Effective Depth TVD: I MPSP(psi): I Plugs(MD): Junk(MD): 10896 • 8761 9012 8328 Casing Length 9012 9 Size MD Burst Collapse Structural Conductor 80 20"x 30" 32-112 ! -112 Surface 2670 13-3/8"72#N-80 31-2701 31-2700 4930 2670 Intermediate See Attachment See Attachment See Attachment ee Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attac n See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12. L-80 L-80 I 23-9200 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Instated No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Sche 13.Well Class after proposed work: Detailed Operations Program H P 4 Exploratory 0 Stratigraphic ❑ Development 0 Service H 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: . Oil 0 WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG e / I L /3 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 \ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Interventions&Integrity Engineer Signature . at,/J--'A Phone +1 907 564 4102 Date 1/ 2/ ; COMMISSION USE ONLY J7/ J�� Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3\L — L( CQtf Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test 0 Location Clearance ❑ Other: j M�t 2t71u Post Initial Injection MIT Req'd? Yes „ No ❑ Spacing Exception Required? Yes 0 No d/ Subsequent Form R'gj44��'��tiire� O — o 4– Approved by: APPROVED BYTHE COMMISSIONER COMMISSION Date: ORIGINAL RED""S !,Lv ' ' '918 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attac ents in//Duplicate • ! Q O O O O O O ca ti � ON OO p CO Nu N- U o L• M ' r-- O M 3 O N CO co V N- 0000 coco N O CO O V' 't CV I- O I,- O Cr) c- 01 CO p) I` O in CO co co I` N CO CO CO CO 00 00 O I I I I I I I I I H " O V •- CO CO CO LO O) M Cr) Cr) N N O cr CO CO N CO CO CO CO tJ C N CM C� O N M co O N co CA CT O) C)) O V p I I I I I I I I I Q Q et) LO N �- (0 O COLI� C) M N M co co N N N- Cr) V' N C• C CO CA d) 0) • co a O O O O O O Z � c(?) O OOC>D0oo0 C d MZ N J �# . N O CO (i) N X " r--- O CO N Cl) O e0 N - CA O _ (0 N U NCO61` N � 0\oN M M t O co cr '- N. I)co N- C�) co ti I` g N N- C O CO CO M (fl J N O CA O '- C) W W Q Q y o w 0 0 ZrxwwwWWwm O � U Z_ _Z (n Z Z J J J J �-- • • 1 1 1 1 1 ar CO 00 CO 00 N t T- CO CV CO y D N- 1- p O co F a 0 I- 00 t CO Cr) fl. O p W p r-- • co co co 0 Lu F Lu p p 0 W Z UJ W p I-- H a W g g CO < " ° o CO O O W U U W a W 1LC) LO "-- M J J J ¢ (n W cc < ZCa)▪ 0 0 U U J W W W _ _ _ ° J a Jpp p p W t I Z Z Q 2 o ccnn c, ¢n (Jn w CU M 4-0 Q a _ � LC) LC) co CO o 0 L a. O acn Y = 0 co J d `2 2 2 O co cn cn co co d a. 0 U .2 co w is as N m m a 0 t al a. as H m 'd- V 0 c O O W J J Z O N N Z L 1 < W W N 00 CO ° W L p 11 LU L O W El- W O CO OYDY W J -137c , a 3 ¢ ° W W < ¢ mapocn LI (in (_ CJ) a a a) E as z Q Q M L.L. a co OJ a N cC tL Cl- m m u_ La m 2 ¢ 11) i Packers and SSV's Attachment ADL0028260 SW Name Type MD TVD Depscription M-13A TBG PACKER 8571.32 7938.37 7" Baker SAB Packer M-13A TBG PACKER 9034.75 8348.02 4-1/2" Baker S-3 Perm Packer M-13A PACKER 9158.25 8458.74 3-1/2" Baker KB Top Packer • • Well: M-13 M-13 IA Cement Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Matthew Bergene (907) 564-4849 History M-13A is a WAG injector originally completed in 1980. It had a RWO in 1990 and another RWO before a CST in 2001. In 2001 a leak in the 7" tubing was identified © -2215' MD. Instead of fixing the tubing leak 4-1/2" tubing was run inside of the leaking 7" tubing creating another annulus. M-13A has been shut in since 2005 after the PW flowline froze and split. The PW injection line was repaired in 2011 and then a PC leak was discovered when screening M-13A to bring back online. An LDL identifies the leak in the production casing at 2848' MD. Recent EOR development has identified M-13A as having higher value as a MIST injector in the current pattern. Reserves/Economics There are 118,000 bbls of oil estimated to be recovered as a result of bringing this well back on MI injection (PWI benefit is 61,000bo; Additional MI benefit is 57,000bo). This integrity repair is proposed to maintain integrity/operability of the well long term. Objective The purpose of this program is to return M-13A to operable status by fully cementing the 9-5/8" x 7" to seal off the PC leak, and leave the 7" x 4-1/2" as the new "IA" with a deep cement job. TOC in the 9-5/8" x 7" would be at surface, and the TOC in the monitorable IA (7" x 4-1/2") would be at 7900' MD. Post-Job Evaluation This well is an injector so an AA will be applied for to allow WAG/MI with the following proposed evaluation criteria: • MITIA and MITT to maximum anticipated injection pressure • SCMT to confirm Top of Cement (TOC) ➢ Temperature Warmback Log & Water Flow Log to verify no flow behind pipe Long-Term Integrity Monitoring ➢ Record WHPs and Injection rate daily (includes pressure-monitoring of the —7900' deep Inner annulus). • BPXA will submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report. • 2-year (biennial) MITTs and MITIAs to maximum anticipated injection pressure. • Maintain IA pressure below 2000 psi normal operating limit. • The well will be immediately shut-in and the AOGCC notified if there is any change in the well's mechanical condition. • After the well is shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 0 i 7183== 4-1/16'YCEVOY SAfElY NATE& L ANGLE>lie a 3Slr R2S WELLHEAD= MCEVOY IIII-13A Current READINGS AVIERASE 12S ppm MIMI EMI III""DELL ACTUATOR= O76 NKR/MESA SSSV WREN 014 if/""LEAK IN I'1DG a O10g 2"3D/= T 2215.4-1M711GWAS RUN 711111MOM r-MG ON ME ELE V= 26.43' RAU OF IWWL NOP'= 3150' Dm Ai I 19392" — 177-1$Poco SSSvr�D=3 x13- = JO Leak casing A22—22L1.:. ...... lik 14' 2105' —7"a16HVN.0=5 2'(130-0834-v2" I axim wan 2609' H 9-98'w rva 13318'CSG.771Q max D=12347- —1 2695 ' PC Leak in 9-5/8"casing A—2850' MD I n nunm=2371-@9423' Z X. I 8572' H9-s3'xTBlasSAB D=aar 3-3716-x2711rLNRXO, UNIQUE(I 1 E) I I 863T HT 0115 R M D=5_982"(MEMO 7BO) 87141' —I 9-90'x 7-LHt HGR W7 7®ACK SLY 871W —T NOT SEAL ASSY MO SEALS 7-70G.2 Mum.0=0278' — 8718' 9017 _H4-177-HTSxP*u=3113' 4-17r 1W5.tL6N L-SK_0152 6pf.D=3958' H 9032' 2 9012' —1 4-1112"NC PLUG(G4?W14) it ... qKF —I T X 4.117-BWt S-3 F1Qt.D=3.875' ti 9155 ---IBM 103 F10L D=2390' TOP OF 3172"LFit.D=2992- —1 916W r 91W —I a71P BIER OEPLOY SLY.D=3.00- 9176- H4-1/2"FES X HP,D=3.813' +172"nip.12 N.L-a0.A152 bpt.D=3_958' —I 9196 - / 919W —I4-1l7 WLB U=4ar 9-98-C*.1G.4711E N-80 PIIS.D=a OSP —I 9217 ---41 7'BUR WI-E 1OCKw7 RA TAG 43 H 9343' 7'LJIL MOUE MOM U 9345'-9350 T 010t K1 CNP RETAtet(09113801) H 9400' a g32r -I3 177-X 33115"LFR x0.D=278' RMF0RATON SUMMARY REF LOG I71.L-GR(CBL 12/22180) BRCS(12118180) 9423' —I 2-718'MI Uta.D=2.377' ANGLE ATTEND PEW: 25'Ifp 9458' Rolm ReTerio P1a08cfoe DB IxLidoIral?erldsb SL7E SPF INTERVAL OP&SSgz GATE 2-7RK' 4 9458-9543 S 01728190 2-7/r 4 9553-9590 C 0913A1 3-3RP' 4 9590-9617 S 06/28190 10 02 4 3-31r 4 9644-9648 5 06/21M90 2--718' 4 9666-9670 S 062890 2-718" 4 9679-9692 S 08228190 2-718- 4 9702-9735 S 062890MI MI 3-318" 4 9735-9750 C 09113101 10' 1886W —FWD 40 3-3# 4 9758-9760 S 06728190 3-31r 4 9760-9780 C 09/13101 3-3111 4 9784-9788 S 06/2890 2-718'LAR H.Si.L-80..0039 bpt.D=Z377" H 10895- 7 6 10645-10675 0 1V16101 7' 6 10705-10735 0 11/16101 1 It 7'LFR8.H 29 -80 BIBS.D=8_184- H 101/Q 1"4"•t" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDIOE BAY IMT 12/14888 OIIIGBIAL COMPLETION 12/28101 CIVIP COl LCIONS WELL II-13A /2122195 BMF RWO 01118104 ATO/RN CORRECTORS PERMT Noy X1011650 1501711 CNINAIC MMI (88 4-115 71118171 02710111 Nam ADDED SSSVSAFETY NOTE AR11x 50-029-20522-01 1111111 CIU SOETRACX( -13A) 01718112 ORURO ADD®IQS SAFETY NOTE SEC 1,T11N,R12E 193T SIL 3 605'NEI 03716101 SIS-CS FJIAL 0906/14 WFSI.NO SET PX RUG(04718114) 06103101 CHIME COIRRECTONS BP Eiior*ioo 3 • 717E= 4-1116"IICEVOY SAFETY NOTES:111111 ANGLE>Moe 9578""•112S WE_FF.D= IN3 VOY READINGS MIRAGE 125 ppm AMEN OMNI""WELL ACTUATOR= OTs M-13 Proposed REENJIRESA SSSV WHEN Ofd AN-''LEAK■7-TBS a OM ELEV= 55...7 2215".4-11r T11GWAS RIN11HU1 DOSING 7'TUG ON 8F-BEY= 26.43 ' a_ MOW 1111!7117 KOP= 3157 Na[0111 = 105'' 10057' ® 1939' 4-112"1-11m I-003 .D=3_013- Mani ND 2105" —{T 076 BNT4.D=5.962•(631114)4-112'7BG) , DalloliTVO= 9-5/8"x 7"Annulus cemented from production packer to surface 2609" —I 9318'W MR 13311-CM.72*1-10.D=12347' s 'TOC in 7"x 4-1/2" IA @ 7900' MD; Monitorable annulus 7900' Deep D 7 MEL iaC �.-r.nW . •-e.-'.1 • .r. I1N,N1i ini =2377-@ 9423. ►-4 ►4 3-3t16'�� x 2 7!r LIR XO, UNIQUE/11111 AHI Fl 8637- --IT 076 R MP D=5960'(BEI-91)IBG) 8714' --I 9-516-x r LFR HGR WI ME CK 5W • 7'IM.2611 L-s0.D=Bsi6' 8719 <I j 871W —17"110T SEAL ASSY WOOD SEALS 4-1G.task L-110._0152 bpi.D=3-958- H 9037 III 11111 IIlia r S 9012" --14-iFtFESxFi:D=arm- ?MG. , 9817 J-J4-1Q 13(PLUG(04HSf14) -9837 I T X4-12'UIQ S-3�D=1.875" la9155' -Hew/Ramat D=239G lOP of 31/2-Mt.D=2992' H 9166' 9160' —(3-70*SKR OBLOY SLY.D=3-00- 917W H4-v2"FE sxFap.D=3313' 4-117 TIP_1261ST 4110._0152 bpi.D=3_9511' — 9196' 9196 H4-172'WILEG.D=400' 9-518-CSCE 47*.N-Il DWtSS.D=8.681' H 9217 T mat Wt-PS IOCKwf RA TAG N 1395' 9345' 7'LIR IIIL1OOT WINDOW L. 9345'-3397 T BIQt Ki Cur BETAiwER(09113101) H 940W 9327' -1310-X 3-1176-LIR 3271 D=27r- PERFORATION SUMMARY RE LOQ DLL-DR(CUL 1212210) BINS(12118180) 9423' H 3-396"X 2-718-LFR AD.D=2377- ANGLE ATT01P PERE 25'1a 9458' Note=Reim-10 Psodads.<B for i skoical?odd/1a SIZE SW IFTERVAL OgalSqz DATE 2-718- 4 9458-9543 S 06118190 2-718- 4 9553-9590 C 0913101 3318' 4 9590-9617 S 06(790 2 t'e 3318' 4 9644-9648 S 06228190 2-718- 4 9666-9670 S 06128190 2-718"' 4 9679-9692 S 0928190 2-718- 4 9702-9735 S 06213190 3311'' 4 9735-9750 C 091131071 r+1 10860 FOTO 3-3 4 9758-9760 S 06/228190 ` 3318 4 9760-9780 C 0913101 331' 4 9784-9788 S 0828190 2-718'LFR 11.9*,L-80„..0039 mg.D=2377- H 10e95' 2' 6 10645-10675 0 1916101 2' 6 10705-10735 O 191601 1 eeiVe OWi#'t�1a"•' 7'LFR.29*.N-00 MRS.D=6_184' —{ 1014u .. s ... DATE REV BY COWEN'S DATE REV BY COMMENTS PWIOIK)E BAY UHF 1212488 OINGNIAL COtIPLET10N 1212901 CWIP CORRECTINIS WEII-111,-13A 02//22191 UT RAO 0111804 ATEIFTIN CORREClD115 PERMIT Noz 2011650 189791 OMAN RYE (RAM 4-112-111817 ) 02110/11 MOND ADDED SSW SAFETY NOTE MIND:50-029-20522-01 11/11111 CHI SIDETRACK(111-13A) 01118112 11111119113 ADDED 1125 SAFETY NOTE SEC 1,T1111,R12E,1937 SNL a 605'ion 0311614'1 S&-CS FINAL 0506114 KFS1.NN] SET PX PUIG(0411014) 0610381 CINI(N( CORRECTIONS BP E ploration 4 • TREE= 4-106'M CEVOY SAFETY NOTES TRILL ANGLE'7b 1a 957 '—112S WELLHEAD- YCE WY S AVERAGE 125 ppm WHEN OMNI"`ISL ACTUATOR=M UTE -13 Proposed P&A A ""' e�'LAK■r-mg OM 557 112'TUG WAS RUN TINNI COSTING r TNG ON BF_HEV= 26-43 :"::*,*:::::-.W':. ROOOF180701. KP= 3150' ,......};}:% On AssplO= 105Q1005T ¢ obi� Cement Plug#3 circulated down tubing, DamIO= � through perforations and up OA& IA from i I 8888 1000' MD to surface 1bI J 1-1 u-nar uv nets 1 13-313`CSG.72A,Ns0.U=12347' -I 269$ Cement Plug#2 circulated down tubing, through tubing punch @-7800' MD and up IA �r1i1NmD=2377"@9423. 3� ► 3-3/16-x 2719'LAIR XO, UNIQUE Int 1 J E 8637" -I r Ops R l�U=&98r(80-IND TOG) Cement Plug#1 pumped FB or laid in w/CT rii MEM 4 Pi 7'113G.2130.1.-MX 0=6276' - 071W ■ 9017 _-44-1rrFWsxPat,n=3813' 4-112'MG.1290.L-30.1152 bpi.n=3453- -[ 9032' 1,5r.� 9812• -4112'IK RUG(04118(14) I, 91137 —Ir x4-1FPBIM 5-3FIR.n=3175" 111111 9155' [—[HHB103F1QLn=2.3'90 U= 113F OF 311r LNR_ .'.9 Mtn=22• [H 916 916W 3-71iot'01cR OfLOY SLV_ 310` 917W -I4-1L2"FES XN*0=3113` 4-112'TIP_12.0*.L-30.1152 bpi_n=3453' - 9196' - 9191T H4-1/2'WLB.13=4.00` 9-513'C .4748.N-30 8125.n=3.680` H 9217 —A 7"SKR WI-N S1OCKwf RA TAG ft 1344 H 9345' 7"11111 r1OUE WINDOW 9345-9350' 11\;\ r Blot 161 cur RETAINER(09113111) H 9489" isio 932T H3-11.2 X3.3118`UR XC.n=2.73` PHN=ORATE N SUMMARY REF LOa 011-GR(SBH 12122040) ENCS(120808) 9423' —[3-3H9`X 2-718`UR AD.n=2377' ANTI.EATTUPPERE 25'in 9458' Nob:Refer Piododlos DB for Maxima lerfdffbi SRE SPF INTERVAL OpotSgz DATE 2-7M' 4 9458-9543 S 06128190 2-718' 4 9553-9590 C 0911301 3-30' 4 9590-9617 S 06124190 ,: 3347' 4 9644-9648 S 06128190 2-7/8- 4 9666-9670 S 0628190 2-718' 4 9679-9692 S 01/26090 g 2-718' 4 9702-9735 S 06.8190 NI 3W 4 9735-9750 C 0911301 ♦ 1D8611' -PM-3 i*A 3-318' 4 9758-9760 S 0628190 3-318' 4 9760-9780 C 0911311 3-318' 4 9784-9788 S 062803 2-TAT UM.6,510_L-30_4039 bpi.n=23"7"9- -I 10095 7 6 10645-10675 0 11116101 r 6 10705-10735 0 11116101 $144444, 7'LFR.290.N-SO 87RS_n=6-134- - 10141 Fri}I+1W& DATE REV BY COMMENTS DATE REV BY COMMENTS "RUIN DE BAY UNIT 1212+1818 OWGNIAL CONWLE11UIU 1212801 DRIP CORRECTIONS WEIL$-13A 11212208 OFF MU 0111804 ATTYRN CORRECTIONS REMIT No["2C11650 180701 OMAN 000 (FAN 4-117 TRIM 7') 02110/11 IMM) NEED SSSV SAFETY NOTE All No:50-029-20522-01 Minn CM S8EIRAICK(11-13A) 01118/12 7"7"88180 ADDED 12S SAFETY NOTE - SEC 1,T1111,R12E 1937 SIN-a 605'NE 03F1601 S6-CS Fi1uL 0506114 IFS/M) SET PX MPG(04118,14) - 0610301 CNNTAK COIRBCiE I1S MfflExploration ) 5 S • DRAFT AA: `'.044x • SP PP' - BP Exploration (Alaska) Inc. requests approval to continue WAG injection service with an IA cemented to 7900' MD into Prudhoe Bay well M-13A (PTD # 2011650). Well M-13 currently has a 9-5/8" production casing (PC) leak at 2847 MD' and a hole in the 7" casing @ 2215' MD which will be repaired, per attached Sundry, by cementing the 9-5/8" x 7" annulus to surface, and the 7" x 4-1/2" annulus to 7900' MD . An initial cement evaluation log (SCMT) will be run to verify cement placement after the first cement job. A temperature warm back and water flow log (WFL) will also be obtained to verify no flow behind pipe after the second cement job. A MIT-IA and MIT-T will be conducted to 2500 psi to confirm both the success of the repair, and that the tubing and 7" production casing are competent. If continued operation of the well is granted, the IA operating pressures shall be maintained below the MOASP of 2000 psi. In summary, BPXA believes Prudhoe Bay well M-13A will be safe to operate pending the successful completion of the planned work and testing outlined in the attached Sundry, and requests administrative approval for continued WAG injection service. If you have any questions, please call me at 564-4303 or Jack Lau/Adrienne McVey at 659-5102. Sincerely, Attachments Technical Justification TIO Plot Injection Plot Wellbore Schematic • Prudhoe Bay Well M-13A Technical Justification for Administrative Approval Request July 19, 2016 Well History and Status Prudhoe Bay injection well M-13A (PTD #2011650) has a 9-5/8" production casing (PC) leak at 2847 MD' and a hole in the 7" casing @ 2215' MD which prevents current injection service. There are 118,000 barrels (bbls) of oil estimated to be recovered as a result of restoring this well to WAG injection service (PWI benefit is 61,000-bo; Additional MI benefit is 57,000-bo). Repairing the PC leak by cementing the IA and IIA as an integrity repair is proposed in the attached sundry. A SCMT will verify cement placement after the initial IA cement job. A temperature warm back and WFL will be obtained to verify no flow behind pipe. Lastly, a MIT-IA and MIT-T to 2500 psi will be performed to confirm the success of repair and that both the tubing and production casing are competent. Recent Well Events: > 12/19/01: RWO ran 4-1/2"tubing inside 7" tubing > 12/03/11: MIT-IA Failed, LLR of.3bpm @ 2340 psi > 12/15/11: PPPOT-T, IC Passed. > 12/18/11: CMIT-IAxllA Failed LLR — 9.7 gpm @ —1050 psi > 05/12/12: LDL detected Leak @ 2847' MD > 04/18/14: Set PX Plug @ 9012' MD, MIT-T Passed to 2500 psi, CMIT-TxIAxIIA Failed, LLR=0.57 bpm @ 2500 psi Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A SCMT will verify cement placement after the initial cement job. A temperature warm back and WFL will be obtained to verify no flow behind pipe. A pressure test of the tubing and 7" production casing will be performed to 2500 psi pending successful sundry repairs, demonstrating competent primary and secondary barrier systems. Pressure on the inner annulus is maintained below the normal operating limit of 2000 psi when the well is on-line. Proposed Operating and Monitoring Plan 1. Allow water and gas (WAG) injection service. 2. Record wellhead pressures and injection rate daily. 3. Submit a monthly report of well pressures and injection rates to the AOGCC. 4. Perform a 2-year MIT-IA and MIT-T to maximum injection pressure. 5. The well will be shut-in and the AOGCC notified if there is any change in the well's mechanical condition. • • Well M-13 • 4 Me 3DOI LIipg 2.203- F� T 000 .- A MIN �---- =_sr`�.-jL 4.1 Job Notes: ➢ The PC leak is @ 2848' MD ➢ The PC leak rate —0.6 bpm @ 2500 psi ➢ The Tubing has recently passed an MITT to 2500 psi ➢ There is a hole in the 7" tubing @ —2215' MD. The last RWO ran 4-1/2" tubing across this leak to create an IIA/IA (7"x 4-1/2" and 9-5/8" x 7" annuli) Cement Calculations 1St cement job (7" x 4-1/2") 7" x 4-1/2" volume from 9000' MD to 7900' MD 20 bbls Total Cement to Pump (24 bbls excess) 22 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 5 hours 6 • • Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 2 Cement contamination 2 Safety 1 Minimum required thickening time: 5 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 2700 2:00 140 2700 3:00 150 2700 4:00 160 2700 7:00 160 2700 15:00 160 2700 2nd cement lob (9-5/8" x 7") 9-5/8"x 7"fillup volume to surface 218 Bbls Total Cement to Pump (22 bbls excess) 240 Bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 7 hours Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 4 Cement contamination 2 Safety 1 Minimum required thickening time: 7 7 • Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 2750 2:00 130 2100 3:00 110 1050 4:00 80 0 7:00 60 0 15:00 50 0 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 9-5/8"47#x 8.681" 9-5/8"x 7"annulus 0 8500' 7"26# X 7" 0.0256 8500' 218 7"26#x 4- 6.276 x 7"x 4-1/2"annulus 0 8500' 1/2" 4.5" 0.0186 8500' 4-1/2"tubing 0 8500' 4-1/2" 12.6# 6.276 0.0152 8500' 1582 129 Slickline 1. Pull PX plug @ 9012' MD. Eline w/ Fullbore 1. Set 4-1/2" CBP @ -9020' MD (in the middle of the first full joint of tubing above the packer). 2. MITT to 3500 psi to verify CBP is set and will hold cement hydrostatic pressure. 3. Punch tubing w/ 5' tubing puncher from -8998' - 9003' MD (across the top collar of the 10' pup joint above the packer). Note indication of TxIIA communication in AWGRS. If no indication is seen, then pump down tubing and verify pressure communication to IIA (7" x 4-1/2" annulus). 4. Set 4-1/2" HES Composite Fasdrill SVB Cement Retainer @ -8980' MD (middle of the first joint of tubing above packer). Note: All depths reference attached 4-1/2" tubing tally dated 10/7/2001. 8 • Coiled Tubing 1. Rig up a micromotion to IA returns. 2. RIH with HES Fasdrill SVB cement retainer stinger. Displace CT x TBG backside to heated 160F diesel while RIH. 3. Sting into retainer and establish diesel circulation down CT and take returns from the IIA (7" x 4-1/2") to tanks. Verify coil backside is SI. Pump the following fluid schedule. Note: Do not pump any freezable fluids through retainer into the /A as these fluids will remain in the IIA after the cement job. ➢ *170 bbls of heated diesel (160F) ➢ Minimal FW spacer ➢ 22 bbls cement per design ➢ CT volume of FW (unsting from retainer w/ last 1-2 bbls of cement in CT) *Note: There are two reasons for the heating the diesel: A. The cement in the IA acts as an extended packer. Tubing movement models indicate that heating the entire wellbore to -140F before setting a packer on a rig is the optimum temperature for locking the tubing in place in PBU (prevents buckling when the tubing is heated up via producing or injecting). Heating the entire wellbore for this type of job to 160F will approximate this (wellbore fluids will cool before cement sets). B. Heating the entire wellbore helps the cement to cure. There have been a couple of IA cement jobs where fluids were not heated prior to cementing and the cement took much longer to cure. In one case it took about 2 weeks before the well would pass an MITIA. 4. This should put the TOC in the IIA (7" x 4-1/2" annulus) @ -7900' MD. See Coil Contingency Procedure#1 below if cement locks up while pumping into the IIA. 5. Unsting from the cement retainer and lay the last 1-2 bbls of cement in the TBG @ 1:1. 6. Contaminate & reverse excess cement off the top of retainer and POOH. 7. Freeze protect CT with MEOH/water as needed with the well SI. Coil Contingency Procedure Contingency#1: If at some point cement locks up and cannot be pumped into the IA then cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1. Reverse the remaining cement out of the tubing. 9 • Eline wf Fullbore 1. Run SCMT log looking for TOC. Expected @ -7900' MD. 2. Perforate through 4-1/2" tubing and 7" tubing. 10' of HES 2.5" BH charges 0- deg phased charges from -8475' - 8485' MD (across the top collar of a full joint of tubing). Note indication of TxIA communication in AWGRS. If no indication is seen, then pump down tubing and verify pressure communication to IA (9-5/8" x 7" annulus). 3. CMIT TxIA to 3500 psi to verify CBP & Production Packers will hold cement hydrostatic pressures. Expect CMIT to fail at a LLR of -0.6 bpm @ 2500 psi due to the PC leak. If the LLR is substantially larger than this then call Interventions Engineer for plan forward. 4. Set 4-1/2" HES Composite Fasdrill SVB Cement Retainer @ -8460' MD (middle of the first joint of tubing above CBP set depth). Note: All depths reference attached 4-1/2" tubing tally dated 10/7/2001. 10 r i • lalli�lG,,,..f iim4.a YrAE, _:t::i':.,:lmnalanudozNidiiltatityatiliakferMSESO 1. Rig up a micromotion to IA returns. This will help determine if the PC leak is drinking any cement and track the cement top in the IA. Ensure that returns are rigged up from the IA (9-5/8" x 7") and NOT the IIA (7" x 4-1/2"). 2. PT CT connector & CT to -4800 psi in anticipation of high circulating pressures towards the end of the cement job. Note: usually pressures do not get higher than 4000 psi during IA cement jobs, but they have in isolated cases so best to be prepared. 3. RIH with HES Fasdrill SVB cement retainer stinger. Displace CT x TBG backside to heated 160F diesel while RIH. 4. Sting into retainer and establish diesel circulation down CT and take returns from the 9-5/8" x 7" annulus to tanks. Verify coil backside is SI. Pump the following fluid schedule. ➢ 220 bbls of heated diesel (160F) ➢ Minimal FW spacer ➢ 240 bbls cement per design ➢ CT volume of FW (unsting from retainer w/last 1-2 bbls of cement in CT) 5. The TOC in the IA (9-5/8" x 7") should be @ surface with 22 bbls of excess pumped. Monitor returns to verify good cement is returned. In order to keep a rate of-1 bpm be prepared for CT pressures to be over 4000 psi towards the end of the cement job (when water is displacing cement out the CT). See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. 6. Unsting from the cement retainer and lay the last bbl of cement in the TBG @ 1:1. Monitor CT x TBG pressure closely as the stinger is pulled out to ensure retainer seals. If it does not seal, the backside pressure should jump to 3700 psi. If this happens, leave the 3700 psi on the backside for the remainder of the job to keep the IA cement in place. POOH pumping only CT displacement down the CTxTBG backside in this case. This can be achieved by POOH and pumping just enough down the backside to maintain whatever pressure the CT X TBG backside equalized at in the first place and verifying that for every 100' of CT pulled -0.3 bbls of fluid are pumped into the well, but if there is any question err on the side of pumping more fluid into the well, not less. Also verify upon reaching surface that-25 bbls of fluid total have been pumped into the well since leaving bottom. 7. If the retainer does seal, contaminate and reverse cement off the top of retainer and POOH. 11 • • Coil Contingency Procedure Contingency#1: If at some point cement locks up and cannot be pumped into the IA then cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1. Reverse the remaining cement out of the tubing. Special Projects 1. Pump sealant (squeezecrete, micro-fine cement, Well Lok, or similar product) into the fully cemented IA (9-5/8" x 7" annulus) and squeeze to—4000 psi. Fullbore 1. Wait on Cement at least 5 days. 2. MIT-IA (7" x 4-1/2" annulus) to 3800 psi. Coil 1. MU 3.80" OD junk mill. RIH and tag TOC (expected —8400' MD). 2. Mill through cement, retainer, 2nd retainer, and the CBP. 3. Mill/Push CBP remnants down to —9155' MD (top of LTP) & POOH. 4. MU 2-1/8" OD junk mill. Mill/Push CBP remnants down to —10,800' MD. Slickline!Fullbore 1. Set Tubing Tail Plug in X-nipple @ 9012' MD. 2. MITT to 3800 psi. 3. Pull TTP. E_%`' 1. WFL and temperature warmback log to verify no-flow behind pipe. DHD 1. After Injection has stabilized, perform AOGCC witnessed MITIA to 2500 psi. Well Integrity Engineer 1. Add Biennial MITTs and MITIAs to AnnComm for additional monitoring of the well integrity. 12 III • North America-ALASKA-BP Page 1 of 1 Wellbore Equipment Report Common Well Name.M-13!OH Report no.:1 Report date:10/7/2001 Project:Prudhoe Bay Site:PB M Pad Spud Date/me:12/2/1980 12:00:OOAM Event Type:WORKOVER(WO) Start Date:10/4/2001 End Date:10/7/2001 AFE No: Rig Contractor:DOYON DRILLING INC. Rig Name/No.:DOYON 16 Rig Release:10/7/2001 4P1784(550,000.00 USD) UUlI:500292052200 Active datum:Kelly Bushing/Rotary Table @55.74usft(above Mean Sea Level) General Information ------ - -- ---- _ .-.-..--------- Assembly Name: TUBING Install Date: 10/07/2001 - - TMD Landed: 9,196.79 Suspended From: SURFACE EQUIPMENT Put Date: TMD Correction: 0.00(usft) Final String Weight: 100.0(kip) Top at: 20.71(usft) Landed Weight: 100.0(kip) Component Details Component type Component Detail 8 Jt& Body ID Body OD Weight Grade Length Top set Manufacturer Model€t ThreadComment-. Cm) (tr) (WO (usft) (usft) • Tubing Hanger TUBING HANGER 11 1.00 3-83 11.000 49.70 1-80 3.58 20.71 FMC NSCT in„L-80,49.7 Tubing Joint(s) TUBING JOINTS 4-5 in, 1.00 183 4500 12.60 L-80 39.93 24.29 APEX TUBING NSCT ,L-80,12_6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 L-80 5.70 64.22 APEX TUBING NSCT in,,L-80,12,6 Tubing Jomt(s) TUBING JOINTS 4S in, 47.00 3-83 4-500 12.60 L-80 1.858-92 69.92 APEX TUBING NSCT ,1-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4-5 1-06 3-83 4.500 12.60 L-80 9.33 1,928.84 APEX TUBING NSCT n,,1_80,126 Subsurface Safety SAFETY VALVE 45 at 1.00 3.81 4.500 15-00 1-80 2.90 1,938-17 CAMCO NSCT Valve 1-80 15 I INTERNATIONAL. Tubing Pup Joint TUBING PUPJOINT 4-5 1.00 3.83 4.500 12.60 1-80 9.86 1,941.07 APEX TUBING NSCT n,,1.40,12.6 Tubing Joint(s) TUBING JOINTS 4.5 in, 17700 183 4.500 12.60 1-80 7,050.41 1,950-93 APEX TUBING NSCT ,1-80.12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1_00 3.83 4500 12.60 1-80 9.87 9,001.34 APEX TUBING NSCT ii,,1-80,12.6 Profile Nipple PROFILE NIPPLE 4.5 1.00 181 4500 12.60 1-80 1.14 9,011.21 OTIS NSCT n„LA0,126 Tubing Pup Joint TUBING PUPJOINT 4.5 200 3.13 4560 12.60 L-80 18.85 9,01235 APEX TUBING NSCT n,,L-80,12.6 Packer PACKER 1.00 3.88 71100 49.70 L-80 3.80 9,031_20 BAKER OIL NBC! (PERMANENT)7 n, LA0,49.7 TOOLS Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4-500 12.60 1-80 9.86 9,035.00 APEX TUBING NSCT n,,L-80,12.6 Tubing Joint(s) TUBING JOINTS 4.5 m, 3.00 3.83 4.500 1260 LA0 119.87 9,044.86 APEX TUBING NSCT ,1-80,126 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 1-80 9.78 9,164.73 APEX TUBING NSCT in„1_-80,12.6 Profile Nipple PROFILE NIPPLE 4.5 1_00 3.81 4.500 12.60 LA0 1 15 9,174.51 OTIS NSCT in,,1-80,12.6 Tubing Pup Joint TUBING PUPJOINT4.5 1.00 3.83 4-500 12.60 1-80 19.80 9,175.66 APEX TUBING NSCT in, 1-80,12.6 Unknown WIRELINE GUIDE 4.5 100 4,00 4-500 12.60 L-80 1.35 9,195.46 OTIS NSCT I m„1-80,12.6 ( I I 1 I I Status Date and Time Status Reason 10/7/2001 12:00:00AM INSTALLED Remarks Printed 5/3/2016 3:34:07PM 13 • • ni_L: 'PO l/ i -/3 , DATE: - Q 4/. STQ Rzc //: 7:6r nn 1/ Orgy KB: to / f4Dool, 27/3 �� _Q__ JTS ON RACK. • a/R JTS RAN, JTS OUT. FT ON RACK. .fit4f,56 FT RRAN. �/++ FT OUT. LAST CASING STRING 5," C,../77 AT 90/€ ' ITEM , LENGTH TOP .. BOTTOM DESCRIPTION .__---- - 4,77-40-7z" TAsa «� G op87.E o Z. rA.rec,t. 7)1 ig / - _'■ —. ^3. e).7" 5e,-,40<.. yid o(4e a* . , !E ; - a,.r/T, 93Q '_ ii4 / -7'/ /J .5 77 4,(la3 , .' I , MIMI Si i w- Jr. 99_s • . , , 1111111111111 7P.27 pe.i.e7 Jr6l /o . 111ff, �, 7c . _ a -7 iJ s 97 754 !/lAi X 7' /1 S xv o-Y .r.,r. 34.ee�.0 Qs/$ . v e 7 --___— ,d. is , •A.ree '/(`' .1.cr ..e, to $3 • , , VP + . 74 Id S ,4o ✓-, fi.� :.:' ,/ x'"3 - /6 7' /J .5 78 .23 3' ; M" 4f f /GAO ch.' 9 le r4IEIRIIIIIIIIIIII 5.5".c V. % l' G 's / $L e NIIIIIIIIIIIIII --•_Af/68 - we s 7V6 20; - MMI 11lri11111111111 A".6. ----p -r.8�. ' Sib as G -7: /3 IIIIBVIIIIIIIIIIIIIII 11111111111111111111111 1111111111111110111 ,,,./ .- ....9e.e 0.6-~x 4 - CI J•,r exi i 4 4.. MEM - — � idTif�S 14 • • Carlisle, Samantha J (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, March 09, 2018 8:23 AM To: Carlisle, Samantha J (DOA) Subject: FW:Withdraw two additional sundries Sam, Please handle. I have placed the Sundries in your box. Thanx, Victoria From: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Sent:Thursday, March 08, 2018 4:02 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Worthington,Aras J<Aras.Worthington@bp.com> Subject: RE:Withdraw two additional sundries Victoria, Please also withdraw the following sundries: M-13A(PTD#201-165/Sundry#316-464) P1-04(PTD#193-063/Sundry#316-539) If you have any questions or need additional information, please let me know. Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 I Office: (907) 564-4091 .1"1,122A S I. l Subsurface&Wells Fay Irriudo`+i MAn g rat-fur BP Exploration Alaska 1900 E. Benson Blvd. I Room: 778C I Anchorage, AK From: Loepp,Victoria T(DOA) [mailto:victoria.Ioepp@alaska.gov] Sent:Thursday, March 8, 2018 2:20 PM To: Lastufka,Joseph N <Joseph.Lastufka@bp.com> Cc:Worthington,ArasJ <Aras.Worthington@bp.com> Subject:Withdraw two additional sundries Please also withdraw: • S i I PBU M-13A(PTD 201-165,Sundry 316-464)Cement IA PBU P1-04(PTD 193-063,Sundry 316-539) Cement IA Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a,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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent:Thursday, March 08, 2018 1:32 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Worthington,Aras J <Aras.Worthington@bp.com> Subject: Please withdraw 3 sundries Victoria, Please withdraw the following unapproved IA Squeeze sundries: G-11B(PTD#208-027) 15-48C(PTD#211-030) Y-24(PTD#186-113) If you have any questions or need additional information please let me know. Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 I Office: (907) 564-4091 .40 Subsurface i&Weils BP Exploration Alaska 1900 E. Benson Blvd. I Room: 778C I Anchorage, AK 2 • • trop Tq 4",\1//77,v THE STATE Alaska Oil and Gas y z�i�.- � 0 Conservation �®mrniSsi�r� -.. fLASKA `•,t 1it# 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh Main: 907.279.1433 ALASICP Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Wells Engineer r BP Exploration(Alaska), Inc. �G�N�E� �� L 3 P.O. Box 196612 17, Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-13A Permit to Drill Number: 201-165 Sundry Number: 316-259, 316-369, 316-376 Dear Mr. Worthington: The AOGCC denies the enclosed applications for sundry approval relating to the above- referenced well. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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 an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, 9CathP )7)-e--(714^--- Cathy y P Foerster Chair DATED this 3" of August, 2016. RBDMS (- AUG - 4 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMN APPLICATION FOR SUNDRY APPRO S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0• Operations shutdown 0 I Suspend ❑ Perforate o Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing m • Other Cement IA's 1Z • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 201-165 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ID 99519-6612 Stratigraphic ❑ Service 0• 6. API Number: 50-029-20522-01-00 • 7• If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No ® PBU M-13A E CEIVED 9. Property Designation(Lease Number): 10. Field/Pools: MAY 0 4 2016 ADL 0028260 • PRUDHOE BAY,PRUDHOE OIL • I tl 11. PRESENT WELL CONDITION SUMMARY /�.//� 1f cc Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Jun.(MD): 10896 • 8761 9012 8328 9012 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2670 13-3/8"72#N-80 31 -2701 31 -2700 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft: P Perforation Depth TVD(ft): Tubing Size: TubingGrade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 23-9200 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service ®. 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ❑ WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG RI ' GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer ' Signature �� Phone +1 907 564 4102 Date ‘-/./1/,� �� COMMISSION USE ONLY 'v Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3lli.- 26.9 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes 0 No V Subsequent Form Required: Approved by: APPROVED BYTHE y COMMISSIONER COMMISSION Date: ORU3INAL RBDMS (A, AUG - 4 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachme in Duplicate 4.6 s: /4- • • d O O o cD O O _ O �0 CO �t co O co C N U i o o o 0) CAI CO CO tN. (000 � 00 CAI ON- CO O d' d' N I� O CO A— O) CO O N- O LO CO CO CO f"- V N CO CO CO 00 CO CO CO F- N A— CO CO CO CO A— CA CO CO CO N N o 'Cr (0 CO N 00 00 CO CO 4.+ G1 " N CO CA N- 0O r (NI f� Co N CO CO 'cr coCV N N CO 0) 0) 0) 0) 0) V (Qi I I i I I I , i 4-1 Q M 10 00 r N •-- CO CO A— LO CO N CO M CON N N- '— CO 'Cr N • C CO 0) 0) 0) • co I— a. O O O O O O coa) _ a) 00 coco J 00 co O z = el co 2.1 Z .— Ncoco (n N X *k C° M N y 0 OO N - N O -- - O — c\I M ' M O i 1V L +' O CflI- C co CO co M - V J N 00 0) C4 0 O) W W Q _Q 0)IO W 0 0 •N 0 UJ W oouCCcCrYwcctrz z W W W W W W OD _ HZZZZD 0 u Z J J J 11 — • • a) 0 N CCI CO CO L M p. CO m - V- 0 N. N- 0 CO CO > H O. 0 I- CO N- .O (0 0) w m O V 0 0 r N- > 0 co co 0 > w cc 0 0 0 w Z W 0 H FW- OJ a W m g g Y v 0 > m (n O O 0 0 j w w ++ CO J J J Q Q C �' C o 0 0 U_ _0 _0 J W W ° Z ° CD Z 2 Z ° a CI J p J Q Q ¢ = a w a U = O w p 0 0 H 0 -C w W w a Q 0 Q V Q 2 2 2 0 co co co v) v) al M Qr a o C -C (n L() 0 = 0 0 0 L a d a 0 2 _x co Y = 0 0 co J dct 2 2 2 O (n v) v) U) (n a) O. a) v 0 0 c .2 Et CC 16 W W dELa 0. 0 t a) a 0 w -J J I- D W 0 .+ N a D J cia3 CD F. o Z a a a Q w w m � p w w W J w w l` a c7 w O. < 0 0 J J p nmO. W O m 0 cG Et J J 0 a w w < < 07 co LL it U) U) a w d E 16 Z Q Q co M U)i maaa0Jaaa' wa 2 2 ¢ ¢ m m a iL co vn a s • 0 Packers and SSV's Attachment PBU M-13A SW Name Type MD TVD Depscription M-13A PACKER 8571.32 7938.37 7" Baker SAB Packer M-13A TBG PACKER 9034.75 8348.02 4-1/2" Baker S-3 Perm Packer M-13A PACKER 9158.25 8458.74 3-1/2" Baker KB Top Packer • • M-13 PC Leak Cement Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer James Shrider (907) 564-4755 History M-13A is a WAG injector originally completed in 1980. It had a RWO in 1990 and another RWO before a CST in 2001. In 2001 a leak in the 7" tubing was identified @ -2215' MD. Instead of fixing the tubing leak 4-1/2" tubing was run inside of the leaking 7" tubing creating another annulus. M- 13A has been shut in since 2005 after the PW flowline froze and split. The PW injection line was repaired in 2011 and the a PC leak was discovered when screening M-13A to bring back online. An LDL identifies the leak in the production casing at 2848' MD. Recent EOR development has identified M-13A as having higher value as a MIST injector in the current pattern. The purpose of this program is to return M-13A to operable status by cementing the IA(s) past both the PC leak and the 7" tubing leak. Objective Cement the IA to cover a PC leak at -2850' MD and the original 7" tubing leak @ 2215' MD. Cement will be circulated down the production tubing and up both of the lAs. The proposed new cement top in the IA will be close to surface @ -500' MD. Procedural steps Slickline 1. Pull tubing tail plug. E-Line 2. Set bridge plug above production packer. 3. Perforate the 4-1/2" tubing and the 7" tubing directly above the bridge plug. 4. Set cement retainer above tubing perforations. Coiled Tubing 5. Pump Class G cement into both of the lAs to get the TOC in the inner IA up to -500' MD. Coiled Tubing 6. Mill out cement retainer, residual cement, and bridge plug. TREE= 4-1/16"MCEVOY 40SA NOTES: WELL ANSLE>70o{@ 9570'"'IQS OY AVERAGE 125 ppm ACTUATOR= OTIS NI—1 3A REQ�UIRREES A SSSVV WHEN ON MI***LEAKMIEN ON RN 7"TBG OKB E3EV= 55 r \` 2215'.4-112"TBG WAS RUN TNRU EXISTING r TOG ON BF B.EV= 26.43' RWO OF 10/07/01. KOP= 3150' 'r° Max Angle= 105°Q 10057 ,o` 0° 1939' j---14-1/2"HES HXO SSSV N,D=3.813" 'V 2106' Hr OTIS BV N,D=5.962"(BB NvD 4-1/2"TBG) Datum TVD= 8800'SS •+.• �J7 2609' H 9-5/8"DV PKR 13-3/8"CSG, 72#,N-80,D=12.347' -{ 2698' 1 , ,►1 `v s" :\` .sy 'VI' 1 8577 H9-5/8"X 7"BKR SAB PKR,D=6.00' Minimum ID =2.377"@ 9423' ''� �� 3-3/16"x 2-7/8" LNR XO, UNIQUE(MILLAB LE) !i 863T —17"011S R NP,D=5.962"(B6-M,0 TBG) air') � 8714' H9-5/8"X 7"LNR HGRWI TIEBACK SLV i 8718' ---17"BOT SEAL ASSY W/O SEALS 7"TBG,26#,L-80,D=6.276" !— 8718' 9012' H 4-1/2"HES X NP,0=3.813" 14-1/2"TBG,12.6#,L-80,.0152 bpf,D=1958" H 9037 _ 9012' —4112"PX PLUG(04118/14) .-.1 9032' H T.X 4-1/2'BKR S-3 PKR,D=3.875" I 9155' HBKR KB PKR,0=2.390' TOP OF 3-1/2'LNR,D=2.992" --{ 9166' 9160' —{3.70"BKR DEPLOY SLV,D=3.00' 9176' H4-1/2"hES X NP,D=3.813" {4-1/2"TTP,12.6#,L-80,.0152 bpf,D=3.958" -- 9196• 9198' 4-1/2'WLEG,D=4.00" 9-5/8"CSG,474,N-80 BTRS,D=8.681' --{ 9212' 7"BKR W-IPSTOCK w/RA TAG @ 9355' H 9345' CI. 7"LNR(br•LOIfT WM DOW 9345'-9350' 7'BKR K-1 CMT RETAINER(09/13/01) —{ 9400' 9327' H3-1/2"X 3-3/16'LNR XO,D=2 78' FERFORAT1ON S*JMW1RY REF LOG: DIS.-GR(CBL 12/22/80) BRCS(12118180) 9423' —{3-3116"X 2-7/8"LNR XO,D=2.377' ANGLE AT TOP PERF: 25°n 9458' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 12-718' 4 9458-9543 S 06/28/90 2-7/8" 4 9553-9590 C 09/13/01 3-3/8" 4 9590-9617 S 06/28/90 4i :i ` 3-3/8" 4 9644-9648 S 06/28/90 2-718" 4 9666-9670 S 06/28/90 2-718" 4 9679-9692 S 06/28/90 2-718" 4 9702-9735 S 06/28/90 NI 33/8" 4 9735-9750 C 09/13/01 It 10880' —{PBTD i 3-3/8' 4 9758-9760 S 06/28/90 4 3-318" 4 9760-9780 C 09/13/01 3-3(8" 4 9784-9788 S 06/28/90 2-7/8'LNR,6.54,L-80,.0039 bpf,0=2.377" H 10895' ! 2' 6 10645-10675 0 11/16/01 2' 6 10705-10735 0 11/16/01 '4174V'0 7"LNR,29#,N-80 B!Kb,11:1=6.t84' — 10140' +♦ 4 DATE REV BY COMENITS DATE REV BY i COMMENTS PFd1*10EBAY uN(T 12/24180 ORIGINAL COMPLETION 12/28/01 CWTP CORRECTIONS WgL M-13A 02/22190 DFF RWO 01/18/04 A1DITLH CORRECTIONS PERMIT No:`2011650 10/07/01 CWKAK RNO (RAN 7}#1117') + 02/10/11 MB/JM) ADD®SSSV SAFETY NOTE APF No: 50-029-20522-01 11/16/01 CTDSIDETRACK(M-13A) 01/18/12 TMWJMD AD ED1-QS SAFETY NOTE SEC 1,T11N,R12E,1937'SNL&605'WI3 03/16/01 SIS-CS FINAL 05/06/14 KFS/JMD SET PX PLUG(04/18114) 06/03/01 CWKAK CORRECTIONS BP Exploration(Alaska) k 2 STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMEIN APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well a Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plugfor Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing m Other Cement IA's m' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 201-165 • Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 3. 6. API Number 50-029-20522-01-00 • 99519-6612 Stratigraphic 0 Service IZI 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No RI PBU M-13A ' RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028260 • PRUDHOE BAY,PRUDHOE OIL li J .al I 1 5 2016 11. PRESENT WELL CONDITION SUMMARY ai v��1 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): J e ,.,�■ _i 10896 8761 9012 8328 9012 4A V Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2670 13-3/8"72#N-80 31-2701 31-2700 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 23-9200 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary IN Wellbore Schematic IR1 13.Well Class after proposed work: Detailed Operations Program LK rt G BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service IZi 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG ® GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer Signature / Phone +1 907 564 4102 Date A//....e9)..,‘"COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Integrity `Le ^�LQ 9 Plug g ty 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No r Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate AO 7(fr(- 7,( �4 • I CD O O O O O f� O N O fC CO O N U i (V) ( ,n o v CQ N.- CO � Do N O c- CO O Nr-- O co CA O CA O In CO CO CO N- N CO CO CO 00 Cao CO CO CI 111111111 V 03 .Zr N CO CO CO 0 N— O CO CO CO N N O Vt CO CO N CO CO CO 00 G) csi N CO O N- O O N vt CO N OO N- N M M O N N CO CA O 6) O O•-• O) O a 1 1 1 1 Q M CO r N CO CO U) M N CO M CON N N- CO cr N • C a) 0) O) d) 3 CO a O CD C) O O O CO CO os, Co CO CO CO _ 09 Z *kk *k *k = d OM N --a *k Z N Cfl N X *k co CO N V1 - - CO 6) C70 - CO c- U � 0!) ? M M N � w )O CO N- C0 B N CO N- � G co N co 0) CO O 0) J W W Q Q W D 0 U U 0 u_ Ct Ct Ct Z Z Q W W W W W W E _ D U u Z Z J J J J F- • • o N c0 m co co L ,- co p_ N• OO a> .,--. 0 N- N- D co co > I.- c). O I- CO N- -C CO 6) a O V 0 d ,– r- w 0 r > 0 CO CO 0 > 2 I— w cC 0 0 o w Z wFW O W 0 a vi <Y 0 0 > CO O O ¢ Y Y O m J 0 0 W w L Ln L !7Lil ch _I J J Q Q U) Wry cp C C.0 r--- 0_ 0_ U_ _1 W W Z CD .— Z Z Z 0 _, 0 o 0 0 ~ a - E 0 0 0 a De nt 0 H.0 0 I- F Q OJ Q v < 2 2 O co co cn m RS M Qa O C L Lf) LO O -- Ili • m o 0 0 is O E ct v) J = 0 0 co cr G) a 0 O 0 e O ,- as W W a O t a, d 0 w 0 a co H 0 CO oo 0 0 00 0 0 0W 0 0 Z W O CC 4. 0_ W N N W O W W W w W IY d Z a C7 0 0 w w W w O ma E E -1 -1 0 0 w W < < m m LL LL co co a w a) E co z < < co co i LL O co O LL N r' L.L. 2 2 ¢ o m ni LOL u_ 0 0 a o 1 • • Packers and SSV's Attachment PBU M-13A SW Name Type MD TVD Depscription M-13A PACKER 8571.32 7938.37 7" Baker SAB Packer M-13A TBG PACKER 9034.75 8348.02 4-1/2" Baker S-3 Perm Packer M-13A PACKER 9158.25 8458.74 3-1/2" Baker KB Top Packer bp • • Well: M-13 M-13 IA Cement Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer James Shrider (907) 564-4755 History M-13A is a WAG injector originally completed in 1980. It had a RWO in 1990 and another RWO before a CST in 2001. In 2001 a leak in the 7" tubing was identified @ -2215' MD. Instead of fixing the tubing leak 4-1/2" tubing was run inside of the leaking 7" tubing creating another annulus. M-13A has been shut in since 2005 after the PW flowline froze and split. The PW injection line was repaired in 2011 and then a PC leak was discovered when screening M-13A to bring back online. An LDL identifies the leak in the production casing at 2848' MD. Recent EOR development has identified M-13A as having higher value as a MIST injector in the current pattern. Reserves/Economics There are 118,000 bbls of oil estimated to be recovered as a result of bringing this well back on MIST injection. Current economics do not support a full blown rig-workover, therefore this alternative integrity repair is proposed to maintain integrity/operability of the well long term. Estimated IOR delivery for the well is 120 BOPD. Objective The purpose of this program is to return M-13A to operable status by cementing the IA(s) past both the PC leak and the 7" tubing leak. Cement will be pumped down CT and up both annuli (7" x 4- 1/2" & 9-5/8" x 7") simultaneously. The TOC in the IA (9-5/8" x 7") will be -500' MD for a monitorable annulus and the TOC in the 7" x 4-1/2" would be at surface. An AA will be requested to allow this well to be a WAG/MI injector. Post-Job Evaluation This well is an injector so an AA will be applied for with the following proposed evaluation criteria: ➢ MITIA and MITT ➢ SCMT to locate Top of Cement (TOC) ➢ Temperature Warmback Log & Water Flow Log to verify no flow behing pipe Long-Term Integrity Monitoring ➢ Daily pressure-monitoring of the 500' deep Inner Annulus (IA) ➢ 2-year (biennial) MITIAs and MITTs Contacts: Aras Worthington James Shrider 564-4102 (w) 907-564-4755 (w) 440-7692 (c) 907-699-2669 (c) ATREE= 4-1116'110EVDY • MD1EScWELL ANGLE>71/o a 9578""H25 = M-1310 Current cQ' WELL AVERAGE 175 �; 0G OIOL BEV= 95-7' 7215'.4-1ir TBG WAS RUN TIIOJ E%ISIMG T TOG ON BF_ELEV= 26.43 - R101:1 OF 111187At KDP= 3160' liar Aad= 106'4 10057 { 1939" -]4-112 Fri/OCC]SSSV14.D=3.313' Da�TVD= 8800 SS 21(W H7-076 BVN.Et=5962-(BB-N+D 4-1221W) Rat 2609' — 9.518' 13-318'CSG_721E N-80.D=12347' --I 2,896 -.,....A T Minim I=23717— 9423' ►� 8r� 1' -{x518'x 7-Slat sae Rat o=620 3-3/16"x 2718-LNR XO, UNIQUEE) 8637 H 076R P 'D=5.962 0311413 1W) a s 8714' --I 9-518'X 7-LNZ 1-10R WI rEELAcK SLV 8718' —r BOT SEAL ASSY WID SEALS 7'1W3.261*,L-80.D=6.778' — 0718' ■ 9017 —4-112 HES XNP,U=3213' 1111 4-112 7BG.12ett.L-80._0152 6p1.D=3.958' H 9032' 9017 H4-1/2=IK.R_UG(04F1&14) Ii. 9032' —17 X 4-112 81CR S-3 RIR =3.875' 9155' - Blas IM Rat D=2390' 7oP OF a v2 LFit D=2 H 9106' 9160' —13_70'Slat om-cw SW.D=3__00' 9176' -4-1121Esxtar.D=3213' 4-112 HP.12.0*.L-80.2152 bpi.D=3_958' H 9196' 9198' H4-112W1U3 U=4_0r 9-518'CSG.47*.N-80 0-IRS.D=8.681' H 9212' -, 7-Blot WI .STOCK%Id RA TAG 19'xiss H 9345' r L IR NILLDUT 1lIIQ]DW 934.5' I-13-1/2"-9350' Blot 14 7-B1 CUL RETA/$s(09/13/01) H 94921' 9327' X 3-3H6-List Xfl.D=278' PERFORATION SU■IARY WE LOG: DLL-GR(CBL 12122190) BRCS 412/10190) 9423 H 33/I6'x 2-718'1W X0.D=2377' ANGLE AT TOP PERF_ 25'f#9458' Mote Relerb Plodad ire DB Lorii/csl7erldola 5l E SPF 11TERVAL Opa,Sep' OATS 2-718' 4 9458-9543 S 06/10190 2-718' 4 9553-9990 C 031341 3-319' 4 9590-9617 S 06/28190 e 3-319' 4 9644-9648 S 06/20190 2-718' 4 9666-9670 S 06/20190 2-719' 4 9679-9692 S 06/28190 2-719' 4 9702-9735 5 06/20190 IN 39' 4 9735-9750 C 0613101 1oB$0 —FOTO -31 3319' 4 9758-9760 S 0628190 319' 4 9760-9780 C 061341 3319' 4 9784-9788 S 06/20190 2-718'LN/t 6.511 L-80.2039 INA.D=2377- H 10805 r 6 10645-10675 0 181641 r 6 10705-10735 0 181641 R 7-1W.2911,N-80 ems,D=618#- —I 10140 DATE REV BY CDRIBITS DATE REV BY CDINBITS I UJH OE BAY UNIT 12/2108 OINGNIAL CONPLE110N 1212841 CHffP CONNECTIONS if/131:-I1-13A 120219$ OFF R__ 0111844 ATDITIJI CONNECTIONS PERININo:2011650 1047181 CHINAN( ASND (RAN 4-112''T IBI T) 02,10/11 MOM ADDED SSSV SAFETY NOTE AR No=90-029-20522-01 11111101 CID SNBETRACK 0111-11A) 0111812 11111FM)ADDED IPS SAFETY NOTE SEC 1,T1111,R12E,193T SIN_S 606 SNL 031641 515-CS FINAL 0546,14 NEST M) SET INC.1 0 404110114) 06103101, CIRKAK CORRECTIONS OF Eiploration(Alaska) 2 TREE= 4146•MCEVOOY • O EAD Y M-13A Proposed ACTUATOR= OTS ................................................................................. 08B BLEV=...................................._55-T SwfacE -F1ij oemealed T x 4-112'Aarides 8F-BEV= 26.43 - IOP= 3150 SOW H IOC u1 I4(9816'x T Artr•ia) Max Am.- 106'In10057 Dov ND= ' - DleiNNIT VD= 8800'SS E r : '260W - 9818-W Flat 13317 GSG.721E N-IS.D=12341 -I 2696 1 rl►rl 0577 -J 9-51B X 1 BIER SAS MR =1340' Ilikiiixan CO=2.377-@ 9423- 3-3116-x2718-LNRXO, UNIQUE(11111ABE) I 063T HT Ols R Mt D=5-937(BOSD lSG) 8700 -Twig p* f,.+ L 8719 -T BOT sou_ASSY 1150 Sb4LS I 7'WS.2138.480.D=8278" - 0710 — — I 9017 I-4-1/2 FES X FIP D=3112 MG.G.DAL utak.0152 bp(.D=3.956' - 9032 g `� MT -4-117 IX FLOG(04118114) '.. 9037 -17-x 4-11r mat S-3 OCR.13=3875' ji-----------...H MP9155' HIINKR 1 MP.MP.0=2390' P OF 3112 LFR D=2937 (- 9166' �� 9160' -3.77 Blas OBWY SLV.D=3.40' I I 9175' -14-1Ir 1-11E5 X HP.0=3.613' 4-117 TIP,1264.450..4152 b40.D=3-95r - 9196' / , 9190' -4-112 MEG.U=485' 9-516-GIG.47#N-30 MS.ID=&BST H 9217 --4 7-Blot WI lOCKw7IIA TAG n 9399 H 9315" T LIR 1 1 OUF MEOW 9345-9350' T Slat K1 Cilli RLTAFet(09131O1) H 9 NI0' I 9327 H3-1/2 X 33118'LFR XIX o=27a- PERFORATION SIWLARY REF LOQ OLL-GR(CBL 1212200)ENCS 41218180) 942W -H33f'B'x 2-716'LFR JGQ D=2377 1 ANGLE ATTOP FERE 25'42 9458' Nom FFeierb Rodal:Foa DB for k._.=i midis is SIZE SW LiTERYAL Op&Sgz DATE 2-70 4 9458-9543 S 06/28190 2-716' 4 9553-9590 C 061310i 3-318" 4 9590-9617 S 0628190 C4 �, 3-31W 4 9644-9648 S 062690 2-718' 4 9666-9670 S 0628190 2-718' 4 9679-9692 S 0628190 2-718' 4 9702-9735 S 062690 1011 3-318 4 9735-9750 C 09113101 41 10060' -Imo 3-31W 4 9758-9760 S 0628190 3316' 4 9760-9780 C 0973101 3-31W 4 9784-9788 S 0628/90 2-7W LFR 6.58„L-80.4039 W.D=2-37r - 10893 2 6 10645-10675 0 11116101 I 2 6 10705-10735 0 11116101 Lif4#4 .4 7UV.29A.14-so MRS.D=6.154' H 101/0' i44*4♦ DATE REV BY COWIEN1S DATE REV BY COWEF1S 1813110E BAY UMW 1224188 OISGUTAL COUPLET= 12128101 CMP CORRECiDIIS WR 1-I6-13A 0722219/ OFF RWO 01/18104 AMY/LH COMPECIWINS PERM No:"2011650 1611671/1 CINUIK IMO QF884-1/2'711811) 02110111 MAO ADDED SSW SAFETY NOTE API No:50-029-20/122-01 1110111 CiD=SMACK(11-13A) 011181112 1188E O ADDED IRS SAFETY NOTE SEC 1,T11N,R12E,193T SNL 8 605 WS_ 03/16101 STS-CS FOIAL 05106/14 KFS/AID SET PX RUG(04118114) 06103101 C181TAK CORRECiINS O Exploration 3 Job Notes: • • ➢ The PC leak is @ 2848' MD ➢ The PC leak rate -0.6 bpm @ 2500 psi ➢ The Tubing has recently passed an MITT to 2500 psi ➢ There is a hole in the 7" tubing @ -2215' MD. The last RWO ran 4-1/2" tubing across this leak to create an IA/IIA (7"x 4-1/2" and 9-5/8" x 7" annuli) Cement Calculations 9-5/8" x 7" (IA)fillup volume to surface 218 bbls 7" x 4-1/2" fillup volume to surface 158 bbls Total Cement to Pump (24 bbls excess) 400 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 8 hours Activity Time(hours) Shearing time,quality control,PJSM 0 Cement displacement 5 Cement contamination 2 Safety 1 Minimum required thickening time: 8 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 2750 2:00 130 2100 3:00 110 1050 4:00 80 200 7:00 60 200 15:00 50 200 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 9-5/8"47#x 8.681" 9-5/8"x 7" annulus 0 8500' 7" 26# X 7" 0.0256 8500' 218 7"26#x4- 6.276x 7"x 4-1/2" annulus 0 8500' 1/2" 4.5" 0.0186 8500' 158 4-1/2"tubing 0 8500' 4-1/2" 12.6# 6.276 0.0152 8500' 129 4 Slickline • • 1. Pull PX plug @ 9012' MD. Eline w/ Fullbore 2. Set 4-1/2" CBP @ -8500' MD (in the middle of a full joint of tubing). 3. MITT to 3500 psi to verify CBP is set and will hold cement hydrostatic pressure. 4. Perforate through 4-1/2" tubing and 7" tubing. 10' of HES 2.5" BH charges 0- deg phased charges from -8475' - 8485' MD (across the top collar of the full joint of tubing in which the CBP was set). Note indication of TxIA communication in AWGRS. If no indication is seen, then pump down tubing and verify pressure communication to IA. 5. CMIT TxIA to 3500 psi to verify CBP & Production Packers will hold cement hydrostatic pressures. Expect OMIT to fail at a LLR of -0.6 bpm @ 2500 psi due to the PC leak. If the LLR is substantially larger than this then call Interventions Engineer for plan forward (most likely this would lead to setting another CBP). 6. Set 4-1/2" HES Composite Fasdrill SVB Cement Retainer @ -8460' MD (middle of the first joint of tubing above CBP set depth). Note: All depths reference attached 4-1/2" tubing tally dated 10/4/2001. 5 Coiled Tubing • 1. Rig up a micromotion to IA returns. This will help determine if the PC leak is drinking any cement and track the cement top in the IA. 2. Rig up via reverse-out skid such that returns can be taken from both the 9- 5/8" x 7" annulus and the 7" x 4-1/2" annulus. Also rig up so that returns can be taken from one or the other annulus, or both at the same time, plus a way to pump diesel down the IA (9-5/8" x 7") and take returns from the IIA (7" x 4- 1/2"). 3. PT CT connector & CT to -4800 psi in anticipation of high circulating pressures towards the end of the cement job. Note: usually pressures do not get higher than 4000 psi during IA cement jobs, but they have in isolated cases so best to be prepared. 4. Have a way to divert the FW spacer (ahead of the cement) upstream of the CT so that nothing but cement or diesel goes into the IA). 5. RIH with HES Fasdrill SVB cement retainer stinger. Displace CT x TBG backside to heated 160F diesel while RIH. 6. Sting into retainer and establish diesel circulation down CT and take returns from both the 7"x4-1/2" and the 9-5/8" x 7" annuli (simultaneously) to tanks. Verify coil backside is SI. Pump the following fluid schedule. Note: Do not pump any freezable fluids through retainer into the IA as these fluids will remain in the IA @ -500' MD after the cement job. ➢ *380 bbls of heated diesel (160F) ➢ Minimal FW spacer (divert this upstream of the CT so that nothing but diesel or cement goes into the IA) ➢ 400 bbls cement per design ➢ At 380 bbls of cement away, swap to taking returns from only the 7" x 4-1/2" annulus. Monitor returns until good cement is coming from the IIA. ➢ After good cement returns are seen from IIA (7" x 4-1/2" annulus), shut in IIA and swap to taking returns from the IA (9-5/8" x 7" annulus). When good cement returns are seen from the IA, then swap back to taking returns from both the IIA and IA simultaneously and pump the remainder of cement. ➢ CT volume of FW ( 9unstin from retainer w/ last 1-2 bbls of cement in CT) *Note: There are two reasons for the heating the diesel: 1. The cement in the IA acts as an extended packer. Tubing movement models indicate that heating the entire wellbore to -140F before setting a packer on a rig is the optimum temperature for locking the tubing in place in PBU (prevents buckling when the tubing is heated up via producing or injecting). Heating the entire wellbore for this type of job to 160F will approximate this (wellbore fluids will cool before cement sets). 2. Heating the entire wellbore helps the cement to cure. There have been a couple of IA cement jobs where fluids were not heated prior to cementing and the cement took much longer to cure. In one case it took about 2 weeks before the well would pass an MITIA. 6 ' Coil (cont'd) • 7. This should put the TOC in both the IA & IIA (9-5/8" x 7" and 7" x 4-1/2" annuli) @ surface with 24 bbls of excess pumped. In order to keep a rate of—1 bpm be prepared for CT pressures to be over 4000 psi towards the end of the cement job (when water is displacing cement out the CT). See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. 8. Unsting from the cement retainer and lay the last bbl of cement in the TBG @ 1:1. Monitor CT x TBG pressure closely as the stinger is pulled out to ensure retainer seals. If it does not seal, the backside pressure should jump to —3700 psi. If this happens, leave the 3700 psi on the backside for the remainder of the job to keep the IA cement in place. 9. PU to safety and pump 12.5 bbls of diesel down the IA (9-5/8" x 7") taking cement returns from the IIA (7" x 4-1/2"). This will create a 500' monitorable IA and is crucial to maintain operability of the well point-forward. 10. POOH pumping only CT displacement down the CTxTBG backside. This can be achieved by POOH and pumping just enough down the backside to maintain whatever pressure the CT X TBG backside equalized at in the first place and verifying that for every 100' of CT pulled —0.3 bbls of fluid are pumped into the well, but if there is any question err on the side of pumping more fluid into the well, not less. Also verify upon reaching surface that —25 bbls of fluid total have been pumped into the well since leaving bottom. 11. Freeze protect CT with MEOH/water as needed with the well SI. Coil Contingency Procedure Contingency#1: If at some point cement locks up and cannot be pumped into the IA then cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1. Reverse the remaining cement out of the tubing. Fullbore 1. Wait on Cement at least 5 days 2. MIT-IA (9-5/8" x 7" annulus) to 3800 psi. Coil 1. MU 3.80" OD junk mill. RIH and tag TOC (expected —8400' MD). 2. Mill through cement, retainer, cement and the CBP. 3. Mill/Push CBP remnants down to —9155' MD (top of LTP) & POOH. 4. MU 2-1/8" OD junk mill. Mill/Push CBP remnants down to —10,800' MD. 7 • • • Slickline/Fullbore 1. Set Tubing Tail Plug in X-nipple @ 9012' MD. 2. MITT to 3800 psi. 3. Memory SCMT to locate bottom and top of cement in IA. 4. Pull TTP. E-Line 1. WFL and temperature warmback log to verify no-flow behind pipe. DHD 1. After Injection has stabilized, perform AOGCC witnessed MITIA to 2500 psi. Well Integrity Engineer 1. Add Biennial MITTs and MITIAs to AnnComm for additional monitoring of the well integrity. 8 • • North America-ALASKA-BP Page 1 of 1 Wellbore Equipment Report Common Well Name:M-13/OHReport no.:1 Report date 10 7 2001 Project:Prudhoe Bay Site:PB M Pad Spud Date/Time:12/2/1980 12:00:00AM Event Type:WORKOVER(WO) Start Date:10/4/2001 End Date:10/7;2001 AFE No: Rig Contractor:DOYON DRILLING INC. Rig Name/No.:DOYON 16 Rig Release:10;712001 4P1784(550,000.00 USD) UWI:500292052200 Active datum:Kelly Bushing I Rotary Table raa55.74usft(above Mean Sea Level) General Information Assembly Name: TUBING Install Date: 10/07/2001 TMD Landed: 9,196.79 Suspended From: SURFACE EQUIPMENT Pull Date: 7MD Correction: 0.00(usft) Final String Weight: 100.0(kip) Top at: 20.71(usft) Landed Weight: 100.0(kip) Component Details Component type Component Detail #Jts Body ID Body OD Weight Grade Length Top set Manufacturer Model# Thread Comments (in) (in) (ppf) (usft) (usft) Tubing Hanger TUBING HANGER 11 1.00 3.83 11.000 49.70 4A0 3.58 20.71 FMC NSCT in,,L-80,49.7 Tubing Joint(s) TUBING JOINTS 4.5 in, 1.00 3.83 4.500 12.60 L-80 39.93 24.29 APEX TUBING NSCT ,Lam,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 1B0 5.70 64.22 APEX TUBING NSCT in„L-80,12.6 Tubing Joint(s) TUBING JOINTS 4.5 in, 47.00 3.83 4.500 12.60 L-80 1,858.92 69.92 APEX TUBING NSCT • ,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 1-80 933 1,928.84 APEX TUBING NSCT n„L-80,12.6 Subsurface Safety SAFETY VALVE 4.5 in, 1.00 3.81 4.500 15.00 L-80 2.90 1,938.17 CAMCO NSCT Valve ,L-80,15 INTERNATIONAL Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 1-80 9.86 1,941.07 APEX TUBING NSCT in,,L-80,12.6 Tubing Joint(s) TUBING JOINTS 4.5 in, 177.00 3.83 4.500 12.60 L-80 7,050.41 1,950.93 APEX TUBING NSCT • ,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 1-80 9.87 9,001.34 APEX TUBING NSCT • n,,L-80,12-6 Profile Nipple PROFILE NIPPLE 4.5 1.110 3.81 4.500 12.60 L-80 1.14 9,011.21 OTIS NSCT n„1-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 2.00 3.83 4.500 12.60 L-80 18.85 9,012.35 APEX TUBING NSCT n,,L-80,12.6 Packer PACKER 1.00 3.88 7000 49.70 L-80 3.80 9,031.20 BAKER OIL NSCT (PERMANENT)7 in,, TOOLS 1-80,49.7 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 L-80 9.86 9,035.00 APEX TUBING NSCT n,,L-80,12.6 Tubing Joint(s) TUBING JOINTS 4.5 in, 3.00 3.83 4.500 12.60 L-80 119.87 9,044.86 APEX TUBING NSCT ,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 L-80 9.78 9,164.73 APEX TUBING NSCT n„1-80,120 Profile Nipple PROFILE NIPPLE 4.5 1.00 3.81 4.500 12.60 L-80 1.15 9,174.51 OTIS NSCT n,,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT4.5 1.00 3.83 4.500 1260 L-80 19.80 9,175.66 APEX TUBING NSCT n,,L-80,12.6 Unknown WIRELINE GUIDE 4.5 1.00 4.00 4.500 1260 1-80 1.35 9,195.46 OTIS NSCT in„L-80,12.6 Status Date and Time Status Reason 10/7/2001 12:00:00AM INSTALLED Remarks °Anted 53•_015 3.34-07PNI 9 , . el • / ,.. �Ei... P,t / f')-/.3.. - DATE: - C-JQ 4/, gQ 4:c r1: i. Dr ? KB: /- .40opI; 2Zc _e_,...:-.-:0 TS ON RACK. • a/ JTS RAN. JTS OUT. __ FT ON RACK. $54/, 5 .., FT RAN. FT OUT. _ LAST CASING STRING /g C/Y7 AT 9?/0 ITE*2 LENGTH TOP • BOTTOM DESCRIPTION D 'Tom o.e 7,tea, ce de_ 4.o S7.zD ._ _ - /?�..%),77 Set.A� /l/iddcde .QVc...-* 7(09$ 3 1i 51 ,Pe qot V- Ilele Jo' 949 8 23 aien S7 ,A-, '4 / 7', ./Jys T '/'4"---3- :L 41 ZD __ Sr x-f /' 'p .../r. 9€1 ze,32 5 -- L q uip ,cry Ai/A d� / 7_- :4ia4 f 7D,0, pe../,dJr, /0 44-4f- 8426 6 7578 14,y x y' /Ji.s xo /D.1 • $.e . ,g . : z k,e,e Qs/s' .C4.6 �. '711:2 's li 179 A,6".,e 'K' ,44/4440,e, P dV !c710'9",. 7' /.4/5 .4', Jr-, /9 : .1.1 Rs , 77 4'3 - /‘7 7' /J y.5 78.4 .y33 3` z.12 g sil . 5.s.s-.V. 4r i=/c s /4 2[6 46 _ _ _ 74,,e1 Uzi,© ./T• 61/;4 oci ', a .I Ct. oel/P ys.. 4$4 'f 7 T4'4 19.14' 30 2f 7.3 I ,--- _- Aef. 4e(4)y ,14 /5.12 27 LI ,C'.6. ---- -:721 , spa e_ a 7. /3 S}. i f , . 6/"`/ fes./ /. . r'. 10 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMAN APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well H Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Cement IA's 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 201-165 Exploratory 0 Development ❑ 3. Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-20522-01-00 • 99519-6612 Stratigraphic 0 Service 0- 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 - PBU M-13A , RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: y rye( C ADL 0028260 PRUDHOE BAY,PRUDHOE OIL J U L 2 1 2016 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): AQQCC 10896 - 8761 • 9012 8328 9012 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2670 13-3/8"72#N-80 31 -2701 31 -2700 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment i See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 23-9200 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ ❑ WD PL 0 SSuspended 0 16.Verbal Approval: Date: GAS 0 WAG 4.3k GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer Signature .... 7 'II' hone +1 907 564 4102 Date �, , .1),..49/4( T COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No t/ Spacing Exception Required? Yes 0 No Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL46 zse ?z/-,( Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • 0 O O O o Q' r-- 0 N O O �aCO Lo p N L oNCO U L oo 0 CO rnNoo � Ca v (.0 00 � w O CO O N ti O I. O M O 0 I— O 0 0 0 CO r- �t N 00 00 co co co co co CI I i i i I . 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Packers and SSV's Attachment PBU M-13A SW Name Type MD TVD Depscription M-13A PACKER 8571.32 7938.37 7" Baker SAB Packer M-13A TBG PACKER 9034.75 8348.02 4-1/2" Baker S-3 Perm Packer M-13A PACKER 9158.25 8458.74 3-1/2" Baker KB Top Packer • • Well: M-13 M-13 IA Cement Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer James Shrider (907) 564-4755 Reservoir Engineer Vahid Nourpour Aghbash (907) 564-5565 History M-13A is a WAG injector originally completed in 1980. It had a RWO in 1990 and another RWO before a CST in 2001. In 2001 a leak in the 7" tubing was identified @ —2215' MD. Instead of fixing the tubing leak 4-1/2" tubing was run inside of the leaking 7" tubing creating another annulus. M-13A has been shut in since 2005 after the PW flowline froze and split. The PW injection line was repaired in 2011 and then a PC leak was discovered when screening M-13A to bring back online. An LDL identifies the leak in the production casing at 2848' MD. Recent EOR development has identified M-13A as having higher value as a MIST injector in the current pattern. Reserves/Economics There are 118,000 bbls of oil estimated to be recovered as a result of bringing this well back on MI injection (PWI benefit is 61,000bo; Additional MI benefit is 57,000bo). Current economics do not support a rig-workover, therefore this alternative integrity repair is proposed to maintain integrity/operability of the well long term. Estimated IOR delivery for the well is 120 BOPD. Objective The purpose of this program is to return M-13A to operable status by cementing the IA(s) past both the PC leak and the 7" tubing leak. Cement will be pumped down CT and up both annuli (7" x 4- 1/2" & 9-5/8" x 7") simultaneously. The TOC in the IA (9-5/8" x 7") will be —500' MD for a monitorable annulus and the TOC in the 7" x 4-1/2" would be at surface. t.Ow f�,nt%AIN, referee/ Ord /$94,- ,ncremieii/ '/ (V/ fate gllOci�/�r4' G�l " T CoAcw• r Ca�voh' 4 Oa werl�over 70 rcj r� well (0 Ic f r A ,'r y 1 orIgf4 ^y l hI'5 y✓G _prod feCaerf f,/.m ,"�'j �j Po/' 1l'D4 f? { arviCe� Pred work IbOII(s fwd to I TO 5 -(k c Pco I• 7/41 7/6 • 1110 Post-Job Evaluation This well is an injector so an AA will be applied for to allow WAG/MI with the following proposed evaluation criteria: ➢ MITIA and MITT to maximum anticipated injection pressure ➢ SCMT to confirm Top of Cement (TOC) ➢ Temperature Warmback Log & Water Flow Log to verify no flow behind pipe Long-Term Integrity Monitoring ➢ Record WHPs and Injection rate daily (includes pressure-monitoring of the 500' deep Inner annulus). ➢ BPXA will submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli. Bleeds to be flagged on the report. ➢ 2-year (biennial) MITTs and MITIAs to maximum anticipated injection pressure. ➢ Maintain IA pressure below 2000 psi normal operating limit. ➢ The well will be immediately shut-in and the AOGCC notified if there is any change in the well's mechanical condition. ➢ After the well is shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection. 2 DRAFT AA: 04, BP Exploration (Alaska) Inc. requests approval to continue WAG injection servicAh an IA cemented to 500' MD into Prudhoe Bay well M-13A (PTD # 2011650). Well M-13 currently has a 9-5/8" production casing (PC) leak at 2847 MD' and a hole in the 7" casing @ 2215' MD which will be repaired, per attached Sundry, by cementing both the 9-5/8" and 7" casing. The estimated top of cement (TOC) in the 9-5/8" by 7" annulus (IA) is —500', while estimated TOC in the 7" casing by 4-1/2" production tubing (IIA) is at surface. An initial cement evaluation log (SCMT) will be run to verify cement placement after the initial IA & IIA cement jobs. A temperature warm back and water flow log (WFL) will also be obtained to verify no flow behind pipe. A MIT-IA and MIT-T will be conducted to 2500 psi to confirm both the success of the repair, and that the tubing and 9-5/8" production casing are competent. If continued operation of the well is granted, the IA operating pressures shall be maintained below the MOASP of 2000 psi. In summary, BPXA believes Prudhoe Bay well M-13A will be safe to operate pending the successful completion of the planned work and testing outlined in the attached Sundry, and requests administrative approval for continued WAG injection service. If you have any questions, please call me at 564-4303 or Jack Lau/Adrienne McVey at 659-5102. Sincerely, Attachments Technical Justification TIO Plot Injection Plot Wellbore Schematic • • Prudhoe Bay Well M-13A Technical Justification for Administrative Approval Request July 19, 2016 Well History and Status Prudhoe Bay injection well M-13A (PTD # 2011650) has a 9-5/8" production casing (PC) leak at 2847 MD' and a hole in the 7" casing @ 2215' MD which prevents current injection service. There are 118,000 barrels (bbls) of oil estimated to be recovered as a result of restoring this well to WAG injection service (PWI benefit is 61,000-bo; Additional MI benefit is 57,000-bo). Current economics do not support a rig workover, therefore repairing the PC leak by cementing the IA and IIA as an alternative integrity repair option is proposed in the attached sundry. A SCMT will verify cement placement after the initial IA & IIA squeeze. A temperature warm back and WFL will be obtained to verify no flow behind pipe. Lastly, a MIT-IA and MIT-T to 2500 psi will be performed to confirm the success of repair and that both the tubing and production casing are competent. Recent Well Events: > 12/19/01: RWO ran 4-1/2" tubing inside 7" tubing > 12/03/11: MIT-IA Failed, LLR of .3bpm @ 2340 psi > 12/15/11: PPPOT-T, IC Passed. > 12/18/11: CMIT-IAxIIA Failed LLR - 9.7 gpm @ -1050 psi > 05/12/12: LDL detected Leak @ 2847' MD > 04/18/14: Set PX Plug @ 9012' MD, MIT-T Passed to 2500 psi, CMIT-TxlAxlIA Failed, LLR=0.57 bpm @ 2500 psi Barrier and Hazard Evaluation The primary and secondary barriers systems consist of the tubing and production casing and associated hardware. A SCMT will verify cement placement after the initial IA & IIA squeeze. A temperature warm back and WFL will be obtained to verify no flow behind pipe. A pressure test of the tubing and 9-5/8" production casing will be performed to 2500 psi pending successful sundry repairs, demonstrating competent primary and secondary barrier systems. Pressure on the inner annulus is maintained below the normal operating limit of 2000 psi when the well is on-line. Proposed Operating and Monitoring Plan 1. Allow water and gas (WAG) injection service. 2. Record wellhead pressures and injection rate daily. 3. Submit a monthly report of well pressures and injection rates to the AOGCC. 4. Perform a 2-year MIT-IA and MIT-T to maximum injection pressure. 5. The well will be shut-in and the AOGCC notified if there is any change in the well's mechanical condition. • Tuff= 4.1,116'NCE'UY SAFETY MUTE S L ANGLE>no 0 96711''-'025 WUJJFAD= MCEV YY IA Current IEAORIGSAVERAGE,26 ppm WHEN ONr"t IWLL ACTUATOR= OTS m REQLWILSA 55311 WHBV ON 1111"'LEAK N17'lOG OIL ELEV= 557 2215•.4-1,1r TOG WAS N011 71NI11 E7051NG r TOG ON OF.BEV= 26-43 MKT OF 10/8TI61. KDP= 3150' Ileo[Ample= 105'/n 10057' 1939' H4-112"FES I-103 SSSSN.o=3613' Dab=ND= 1 1 2105'11 —7-OW OVN.13=5862(PU-Ilu 4-112"MG) DalmeTVD= MOB SS 2609 — 9518'DV F1QI 13-318-CSG.7"21E N-SO.D=12347' --I 2691r 1--A I, 2 — 8677 —J9-511-xrPFa1 SADF#LD=liar Minimum ID=237T @ 942T 3-31116-x2-718-LNR XO, UNIQUE(I 1 JAB! E) 863,1 —{r 01!11 R NIP.D=58962(88-11.10 183) 87'14• —s-snr x r LP 1-UR w/11E8ACK SLY 1 8718 —Ir POT SEAL ASSY VIED SEALS r IPG.26Lk L-SD.D=6276- — 8718' ■ i I= 9012' H4-1R-1PSxW D=3813' 4-112 786.DM L-SO.8152 WC D=3-968- H 9032' ! 0117 —14-1,1,1 FA H LJG(04118/14) II11 a 9032- ^—Irx4- -PIRS-311CR.D=3/05' ' 9155' --IBM KP FMR13=2..390' IOP OF 3-112'mt.D=asaz —I 9166' 9160' —3J0'Plat D03i0Y SLY.D=380' 9176' H4-117HES XNW.13=3813- 4-G2'TIP.129/I.L-80.8152 44.13=3-9518- —I 9196' 9191r —14-1/2"WLB3.D=4.100' 9.516'CSC.47#.N-SO BIBS.D=6..5111' H 9217 r NKR WI-113IOCKwi RR TAG a 5' H 9315' Ihk 7-LIR INLOUT tIY6DOW 9345-9350' r Plus 141 cif mErAmER(09113101) H 940(11' 9327• —I 3-112 X 3-3116•UR XC).D=278' PERfORATUN SIN■IARY REF LOG: CIL-GR(CBL 12122160) BUS(12116180) 9423 H 3-3116'8 2-7m'LF84 XCi.D=2372' ANGLE AT TOP PERF_ 25'fa 9458' Nam Rater ID Radix:Wm DB Lariirkai perldela SHE SPF IITER'VAL Op&SSgz DATE 2-790' 4 945E-9543 S 092990 2-790' 4 9553-9590 C 09113101 3-310' 4 9590-9617 S 092990 e I:4 3-310' 4 9644-9648 S 06/28190 2-790' 4 9666-9670 S 06128190 2-790' 4 9679-9692 S 06228190 2-71x' 4 9702-9735 5 06128190 .1 3-31T 4 9735-9750 C 09113101 10060' —win 310' 4 9758-9760 S 06128/90 310' 4 9760-9780 C 09113101 3.310' 4 9784-9788 S 0028190 2-7111'LIM.6.5*.L-S0.8039 by.D=2377' — 10899 2" 6 10645-10675 0 11116101 2 6 10705.10735 0 11116101 MAW r 1.MR.29 N-SO PIKS.D=6.154 — 101412 122222244! tt DATE REV BY COMMENTS DATE REV BY COMMENTS PRRDIIDE BAY 11SF 121281/18 ORIGINAL CININLETIIMI 12128101 CORP CORRECTORS NIU L-N-134 112/22811 OFF MVO 01118104 ATORLN CORRECTORS PERINI No:5011650 189711111 CIINTAN RNNI (RANI-1/7111W 7-) 02/10/11 MAO ADDED SSSV SAFETY NEE All Noy 913-029-20522-01 1111691 CTO SNETRACI[(11-118) 01/11Y12 TINIIJO ADD®125 SAFETY NOTE SEC 1,T111,R12E,1937 SNL 8 605'WEL 03116101 SB-CS FNIAL 055106114 KFS/JO SET PX HMG(04118114) 0610301 CNNTAK CORRECTORS MP Exploration(!Alaska) 3 • • TREE= 4-1116'MCEVOIY ' WaLRFAO=._............_ ICEVOY ACTUATOR= CTs M-1310 Proposed ................................................................................. OI_REV= 95_7 SITILice —Far oeineded T A 4-1x2'Amid= BF-HPV= 26-43' J Ei. I ....................... ROP= 3150' 503' mc:,rk(9-516-x7at..r8) Max An. 105' 10057' d SND_ Dalin TVD= 9000'SS 2609' — 9-5E"6V 1#t 13316'CSG.72dt N-50,O=12347 -I 2695 ' 0571' —Is s16'x70�sae Ra o=cow anima D-2.37T 9423• 3-316-x 2-7/8-LNR XO, UNIQUE(RE1 1181 E) II 8637' —IT MIS R NIP,o=5.957 t1113-013 1a93 0701 —Tolling pati L8715 1—r NOT SEAL asst WO SEALS 7'IOC.20/L-00.D=6_276' — 8715 —�,MEN I 9017 —4-112'1-ES X Pp 10=31113• ? 4-1 1136.12.00.L-SOL_0152 bp1.D=3.955 H 01137 te5 - -H 9917 1-14-1/2"FK R.U['(04118114) "") 9032' H T X4-112'BIM S-3 PIR D=3.579' 9155' -[81021®1112[,I]=2..390' 110 F1 LFR 1'OF 3-1 13=2992' [— 9166' iit----'-''''---'-'''''--I..............._ 9165 —3.77 BIM OHLOY SW.13=3100' I I 9175' —I# ms x rm..,U=3_813' , 44/7 771.1201E L-50._0152120.D=3.995' — 9196' I , 9190' —{4-1/rMEG.D=4100' 9-518'CSG.470.FFM 9119.13=K061 —I 9217 —41 I k r MR WFf510CKwf ISA TAG 44 9354 — 9345' I7-111021•1001-WSW 934.0-9350' ■ 7 BIO[141 cur RETAPSOS(09113101) - 9405 9327' [3172 x3-3f18 LFR XC).D=278' PHWFORATON SBINIARY REF LOG O1L-CR(CUL 12122180)BRCS(1210700) 9423' I—3-3/110"X2-7/8"LFR 7127„D=2377' 1 ANGIE ATTOP FERE 2542 9450 Malec Radio Plad=CrOM OB For 10100/91 crfdslo SIZE SPF OITHRVAL OplSqz DATE 2-710' 4 9450-9543 S 0628190 2-710' 4 9553-9590 C 09113101 3318' 4 9590-9617 S 06120190 3318' 4 9644-9640 S 0620190 2-718" 4 9666-9670 S 002090 I I 4 2-7111' 4 9679-9602 S 0028190 2-718' 4 9702-9735 S 06/28190 litil 3-318' 4 9735-9750 C 09!13101 `!4 10865 FB7D 18' 3318' 4 9750-9760 S 0620190 3-318' 4 9760-9780 C 09113101 ! 1 3-318' 4 9784-9700 S 0620790 2-718'LFR 851E L-110.0039 bp1.D=2-377' —1 10093 r 6 10645-10675 0 11116101 r ' 6 10705-10735 0 11116101 144`0 ,14 7LR F291�PI-80BD 1RS. =&154 — 10145 44ii4♦ DATE REYBY COUNEiTS DATE REV BY COMMIS 18813110E BAY IMF 1214448 ORIGNNILCJ'LE11011 12120101 CNITP CORRECTORIS WHL-N-13A 1252280 OFF RIND 01710104 ATDITIH CORRECTORIS MINI No:x2011690 10187111 CNITAK RING IRAN 41-112'maw 77 02110111 IfaO AOS 55SY SAFETY NOTE API Roc 50-029-20522-D1 1111011/1 CFI)SIDETRACK(111-13A) 01110/12 TIMM AC0E13 1125 SAFETY NOTE SEC 1,T11N,R12E,1932 SIL S 605'WH. 03116101 S&-CS FISAL 05106114 86551W SET PXFLOG(04110114) 06103101 CIYRAK COCTONS IN,Exploration( 4 • • TREE= 4-1116•YCEVOY INEWIEAD= . .__._ MCEVOY M-13 Proposed P&A ACTUATOR= ME ORB ELEV.= 557 OEREV 26.43 •• z,w Cement Plug#3 circulated down tubing, w7'. ....-............................_...............3150' through tubing punches and up IA from Um Angle. ..- 105'n 1005_2................. O 500' MD to surface Oslo/NOD= DalmTYD= sew ss Cement Plug#2 circulated down tubing, 13818'0's .721E RIO.13=12347' —1 269f< through perforations @—1800' MD and up OA to surface 4 8612' —15sir xrfIQ4'' ■RU.D=000' lfiniFNm U=2377' *-14 . 3-3116'x 2 7l8'LNR XO, UNIQUE iy ABE) s@4 mx Cement Plug#1 pumped FB or laid in w/CT aun ,,y.7' +' 871W —r eor SEAL ASSY 910 SEALS r IBG.208,L-80.D=6_270' — j ..,%,"'.. : 871W v te:"°` ■ .:.`.;�le 9017 j-4-112'FESXF�D=8313' ai.?ter; 4-12'IBG.1z61F L-s0._0152 bpf.I7=3-E156' — 067 . `i 7'� li 9017 —4-111 Ix RIM(04111814) .+'t 9032' -Ir X4-111e161S-3 diu RO't,ID=3375' :` . IN miss. HEIMI0sRW.D=2.390' lop OF312'LNLEl=2.981 — 9166• Ip:a' I 9160 —3-70'MGR SOY SLY.D=300' his+ 9176' —I 4-1/2•FES X Ft:0=3313' I 4-12'TIF!1200.L-s0..1075¢bplD=3_960' — 9196' I ,* +a• I slog — 11 6,D 4 4-1W1E =COO" 9-518 C' 3.470 N-SO MRS.ID=8..901' - 9212' .V.,.. hoi. F:. r BRR WIU 1OCKw1 RR TAG 9355, — �%. T'LIR I 101ff W.1l]0W : «:. 9346-9350' rNKR icicur REIMEt(09113101) H 94108 _ ..-..' 9327" [-13111X3-3118'LFR703.D=278' PEiFDRATION SOIRIARY REF LOG O1tlR(CU-1222180)BIOS(12118180) .^:„ 942Y I—3-3118'X 2-719'LFR 7031,D=2.377' ANGIE ATTTP PERF_25'1§9458 Nate`Raw b Piodsdrr OB foriidorial lerfdass SEE SIF IRE VAL Opn&Sgz DATE 2-715 4 9458-9543 S 0628190 v. 2-778' 4 9563-9590 C 09/13101 3318' 4 9590-9617 S 062990 3-318' 4 9644-9648 S 0628190 2-715 4 9666-9670 S 0628..10 I I �\ 2-715 4 9679-9692 S 0528190 2-778' 4 9702-9139 S 06/26190 10 3318' 4 9735-9750 C 0913101 ` 10858 —IBM 3-318' 4 9758-9760 S 0528190 3-3W' 4 9760-9700 C 09113101 / 3-3' 4 9784-9788 S 0628190 2-718'LFR.0.5#L-80.0039 bpl.D=2377' — WNW 1 2' 6 10645-10675 0 11168!1 ' 2' 6 10 11610 705-10735 0 11 44,44.4 0 411141 3LFIL29k.Nam 0185.0=8..184• —I 1014Q 4Ik46<r44 DATE REV BY COMMENTS DATE REV BY COMMIS PRUDHOE BAY IMT 12/24100 MURAL cUW'LEION 1228101 CHAP CORRECTORS 'AUL-N-13A 02122190 OFF IRMO 01118104 ATD/IIN CORRECTIONS PERINI-Ikc'2011650 1067101 CHWA( 10113 flAR4-iir 11au/7') 02/10111 UMW ADDEO SSSV SAFETY NOTE MINA:50-029-20522-01 11111101 CRD SOIETRACK 011-13A) 01118112 1IOVAID MOD 1015 SAFETY NOTE SEC 1,T1111,R12E,1937 SNL&605'WE_ 03116101 SE-CS .NAL 05876114 KESF00)SET PX I IHG(04118114) 06103101 CREAK CORRECTIONS 101 Esploratioe(A 5 • i Well:M-13 -. :. DOA f � 1 7 +aea�s Job Notes: ➢ The PC leak is @ 2848' MD ➢ The PC leak rate —0.6 bpm @ 2500 psi ➢ The Tubing has recently passed an MITT to 2500 psi There is a hole in the 7" tubing @ —2215' MD. The last RWO ran 4-1/2" tubing across this leak to create an IA/IIA (7"x 4-1/2" and 9-5/8" x 7" annuli) Cement Calculations 9-5/8" x 7" (IA) fillup volume to surface 218 bbls 7" x 4-1/2" fillup volume to surface 158 bbls Total Cement to Pump (24 bbls excess) 400 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 8 hours 6 • ! Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 5 Cement contamination 2 Safety 1 Minimum required thickening time: 8 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 2750 2:00 130 2100 3:00 110 1050 4:00 80 200 7:00 60 200 15:00 50 200 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 9-5/8"47#x 8.681" 9-5/8" x 7"annulus 0 8500' 7" 26# X 7" 0.0256 8500' 218 7" 26#x 4- 6.276 x 7" x 4-1/2" annulus 0 8500' 1/2" 4.5" 0.0186 8500' 158 4-1/2" tubing 0 8500' 4-1/2" 12.6# 6.276 0.0152 8500' 129 1. Pull PX �u p g@9012' MD. Wifittilbore 2. Set 4-1/2" CBP @ -8500' MD (in the middle of a full joint of tubing). 3. MITT to 3500 psi to verify CBP is set and will hold cement hydrostatic pressure. 4. Perforate through 4-1/2" tubing and 7" tubing. 10' of HES 2.5" BH charges 0- deg phased charges from 8475' - 8485' MD (across the top collar of the full joint of tubing in which the CBP was set). Note indication of TxIA communication in AWGRS. If no indication is seen, then pump down tubing and verify pressure communication to IA. 5. CMIT TxIA to 3500 psi to verify CBP & Production Packers will hold cement hydrostatic pressures. Expect CMIT to fail at a LLR of -0.6 bpm @ 2500 psi due to the PC leak. If the LLR is substantially larger than this then call Interventions Engineer for plan forward (most likely this would lead to setting another CBP). 6. Set 4-1/2" HES Composite Fasdrill SVB Cement Retainer @ -8460' MD (middle of the first joint of tubing above CBP set depth). Note: All depths reference attached 4-1/2" tubing tally dated 10/4/2001. 7 • Coiled Tubing 1. Rig up a micromotion to IA returns. This will help determine if the PC leak is drinking any cement and track the cement top in the IA. 2. Rig up via reverse-out skid such that returns can be taken from both the 9- 5/8" x 7" annulus and the 7" x 4-1/2" annulus. Also rig up so that returns can be taken from one or the other annulus, or both at the same time, plus a way to pump diesel down the IA (9-5/8" x 7") and take returns from the IIA (7" x 4- 1/2"). 3. PT CT connector & CT to -4800 psi in anticipation of high circulating pressures towards the end of the cement job. Note: usually pressures do not get higher than 4000 psi during IA cement jobs, but they have in isolated cases so best to be prepared. 4. Have a way to divert the FW spacer (ahead of the cement) upstream of the CT so that nothing but cement or diesel goes into the IA). 5. RIH with HES Fasdrill SVB cement retainer stinger. Displace CT x TBG backside to heated 160F diesel while RIH. 6. Sting into retainer and establish diesel circulation down CT and take returns from both the 7"x4-1/2" and the 9-5/8" x 7" annuli (simultaneously) to tanks. Verify coil backside is SI. Pump the following fluid schedule. Note: Do not pump any freezable fluids through retainer into the IA as these fluids will remain in the IA @ -500' MD after the cement job. ➢ *380 bbls of heated diesel (160F) ➢ Minimal FW spacer (divert this upstream of the CT so that nothing but diesel or cement goes into the IA) ➢ 400 bbls cement per design ➢ At 380 bbls of cement away, swap to taking returns from only the 7" x 4-1/2" annulus. Monitor returns until good cement is coming from the IIA. ➢ After good cement returns are seen from HA (7" x 4-1/2" annulus), shut in IIA and swap to taking returns from the IA (9-5/8" x 7" annulus). When good cement returns are seen from the IA, then swap back to taking returns from both the IIA and IA simultaneously and pump the remainder of cement. ➢ CT volume of FW (unsting from retainer w/ last 1-2 bbls of cement in CT) *Note: There are two reasons for the heating the diesel: 1. The cement in the IA acts as an extended packer. Tubing movement models indicate that heating the entire wellbore to -140F before setting a packer on a rig is the optimum temperature for locking the tubing in place in PBU (prevents buckling when the tubing is heated up via producing or injecting). Heating the entire wellbore for this type of job to 160F will approximate this (wellbore fluids will cool before cement sets). 2. Heating the entire wellbore helps the cement to cure. There have been a couple of IA cement jobs where fluids were not heated prior to cementing and the cement took much longer to cure. In one case it took about 2 weeks before the well would pass an MITIA. 8 • Coil icord'd or t`d 7. This should put the TOC in both the IA & IIA (9-5/8"x 7" and 7"x 4-1/2"annuli) @ surface with 24 bbls of excess pumped. In order to keep a rate of—1 bpm be prepared for CT pressures to be over 4000 psi towards the end of the cement job (when water is displacing cement out the CT). See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. 8. Unsting from the cement retainer and lay the last bbl of cement in the TBG @ 1:1. Monitor CT x TBG pressure closely as the stinger is pulled out to ensure retainer seals. If it does not seal, the backside pressure should jump to —3700 psi. If this happens, leave the 3700 psi on the backside for the remainder of the job to keep the IA cement in place. 9. PU to safety and pump 12.5 bbls of diesel down the IA (9-5/8"x 7") taking cement returns from the IIA (7"x 4-1/2"). This will create a 500' monitorable IA and is crucial to maintain operability of the well point-forward. 10. POOH pumping only CT displacement down the CTxTBG backside. This can be achieved by POOH and pumping just enough down the backside to maintain whatever pressure the CT X TBG backside equalized at in the first place and verifying that for every 100' of CT pulled —0.3 bbls of fluid are pumped into the well, but if there is any question err on the side of pumping more fluid into the well, not less. Also verify upon reaching surface that —25 bbls of fluid total have been pumped into the well since leaving bottom. 11. Freeze protect CT with MEOH/water as needed with the well SI. Coil Contingency Procedure Contingency#1: If at some point cement locks up and cannot be pumped into the IA then cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1. Reverse the remaining cement out of the tubing. Fudbona 1. Wait on Cement at least 5 days 2. MIT-IA (9-5/8"x 7" annulus) to 3800 psi. Coil 1. MU 3.80"OD junk mill. RIH and tag TOC (expected —8400' MD). 2. Mill through cement, retainer, cement and the CBP. 3. Mill/Push CBP remnants down to —9155' MD (top of LTP) & POOH. 4. MU 2-1/8"OD junk mill. Mill/Push CBP remnants down to —10,800' MD. 9 • ! Slickline/Fullbore 1. Set Tubing Tail Plug in X-nipple @ 9012' MD. 2. MITT to 3800 psi. 3. Memory SCMT to locate bottom and top of cement in IA. 4. Pull TTP. E-Line 1. WFL and temperature warmback log to verify no-flow behind pipe. DHD 1. After Injection has stabilized, perform AOGCC witnessed MITIA to 2500 psi. Well Integrity Engineer 1. Add Biennial MITTs and MITIAs to AnnComm for additional monitoring of the well integrity. to • North America-ALASKA-BP Page 1 of 1 Wellbore Equipment Report Common Well Name:M-13 I OH Report no.:1 Report date:10/7/2001 Project:Prudhoe Bay Site:PB M Pad Spud Date/Time:12/2/1980 12:00:00AM Event Type:WORKOVER(WO) Start Date:10/4/2001 End Date:10/7/2001 AFE No: Rig Contractor:DOYON DRILLING INC. Rig Name/No.:DOYON 16 Rig Release:10/7/2001 4P1784(550,000.00 USD) UWI:500292052200 Active datum:Kelly Bushing/Rotary Table l 55.74usft(above Mean Sea Level) General Information Assembly Name: TUBING Install Date: 10/07/2001 TMD Landed: 9,196.79 Suspended From: SURFACE EQUIPMENT Pull Date: IMO Correction: 0.00(usft) Final String Weight: 100.0(kip) Top at: 20.71(usft) Landed Weight: 100.0(kip) Component Details Component type I Component Detail #Jts Body IDI Body OD Weight Grade Length Top set Manufacturer Model# Thread Comments (in) (in) (PPO (usft) (usft) Tubing Hanger TUBING HANGER 11 100 3.83 11.000 4970 L-80 3.58 20.71 FMC NSCT in,,L-80,49.7 Tubing Joint(s) TUBING JOINTS 4.5 in, 100 3.83 4.500 12.60 LA0 39.93 24.29 APEX TUBING NSCT ,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 LA0 5.70 6422 APEX TUBING NSCT n„L-80,12.6 Tubing Joint(s) TUBING JOINTS 4.5 in, 47.00 3.83 4.500 12.60 LA0 1,858.92 69.92 APEX TUBING NSCT ,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 L-80 9.33 1,928.84 APEX TUBING NSCT in,,L-80,12.6 Subsurface Safety SAFETY VALVE 4.5 in, 1.01 3.81 4.500 15.00 L-80 290 1,938.17 CAMCO NSCT Valve ,LA0,15 INTERNATIONAL Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4500 12.60 LA0 9.86 1,941.07 APEX TUBING NSCT n,,L.80,12,6 Tubing Joint(s) TUBING JOINTS 4.5 in, 177.00 3.83 4.500 12.60 L-80 7,05041 1,95093 APEX TUBING NSCT ,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 L-80 9.87 9,001.34 APEX TUBING NSCT n,,L-80,12_6 Profile Nipple PROFILE NIPPLE 4.5 1.00 3.81 4.500 12.60 LA0 1.14 9,011.21 OTIS NSCT in,,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 2.00 3.83 4.500 12.60 L-80 18.85 9,012.35 APEX TUBING NSCT n„L-80,12_6 Packer PACKER 1.00 3.88 7.000 49.70 L-80 3.80 9,031.20 BAKER OIL NSCT (PERMANENT)7 n,, TOOLS L-80,49.7 Tubing Pup Joint TUBING PUPJOINT 4-5 1.00 3.83 4.500 12.60 L-80 9.86 9,035.00 APEX TUBING NSCT n,,L-80,12.6 Tubing Joint(s) TUBING JOINTS 45 in, 3.00 3.83 4.500 12.60 L-80 119.87 9,044.86 APEX TUBING NSCT ,L.80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 L-80 978 9,164.73 APEX TUBING NSCT n„L-80,12_6 Profile Nipple PROFILE NIPPLE 4.5 1.00 3.81 4.500 12.60 L-80 1.15 9,17451 OTIS NSCT n,,L-80,12.6 Tubing Pup Joint TUBING PUPJOINT 4.5 1.00 3.83 4.500 12.60 L-80 19.80 9,175.66 APEX TUBING NSCT in,,L-80,12.6 Unknown WIRELINE GUIDE 4.5 1.00 4.00 4.500 12.60 L-80 1.35 9,19546 OTIS NSCT n„LA0,12.6 Status Date and Time Status Reason 10/7/2001 12:00:00AM INSTALLED Remarks Printed 5/32016 3:34:07PM 11 • — — ._ • �I.?.: / /"'/-43,_c., DATE: G? G'/, ' Q // pp RIC t1: Or•/y KB; h, /440.,/,, 2 7. /3 _e( ) TS ON RACK. • z/R JTS RAN. JTS// OUT. FT ON RACK. Z54/, 56 FT RAN.S FT OUT. LAST CASING STRING F C/ -7 AT 92'/0 IT as , LENGTH TOP • BOTTOM DESCRIPTION 4-0-0 tti�,a 7o"' , 137/ _ y 4'. Z. o,7 5 /l/id.4tee ?'t' 41593 3,872411 k h "}11/ 94f U.A.9 n 74) 7'/ /✓ys 7:96 V' g442.-124 J Sri Al/do Jr, 99s $A8 2.6 ,7ZA five ✓r, , /o .24g5$5 7" •✓ys 7c i42. 9-7 NO Si 754 t/ x y' Xo /oY SCT. J. 34REz gs/d . M ,4(640. g57j.t v9' SI6 7+ /J s A'' 4-, /ff. zsej xff , 41_3 - ,/ ) • /./ys 784 al2g1'4 1 a,- /4(4.9tj. �/r- 9 q 5.s.s:Vs, /4 535 ala 46 7 A/o ✓T• q , 495'52 r• '/68 - ,Cls 7z34 ,2034 n ,y. ct: Q S,L/7s.- 4 R41 7 34+ 1q.Y4' 32'.54 2L r ,C- -725G. S ao 2 7 /3 .94 c 06,0> cis .met 'Meet 61-14!2a-/ •F- E, s - • 12 • S Carlisle, Samantha J (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,August 03, 2016 1:57 PM To: Carlisle, Samantha J (DOA) Subject: FW: BP IA Cement Sundries From: Loepp, Victoria T(DOA) Sent: Tuesday, August 02, 2016 1:44 PM To: Ryan.daniel@bp.com Subject: BP IA Cement Sundries Ryan, The following sundries for IA cementing have been submitted by BP for approval. This work requires waivers from our existing regulations. Specifically,for the production wells 20 AAC 25.200(d) requires that all producing wells be completed with suitable tubing and a packer. And for the injection wells 20AAC25.412(a) requires the well be completed with tubing and a packer and that the packer be placed with 200 ft measured depth above the perforated injection interval unless the AOGCC approves an alternate design or packer setting depth. The AOGCC is viewing your proposed work as making the existing tubing a casing string since almost the entire annulus would now be filled with cement. Therefore,the AOGCC believes the best approach is to establish pool rules that outline the criteria for when and how these types of completions can be used. We will not be approving these sundries. We recommend that BP make a request for modification to the respective Conservation Orders and Area Injection Orders and proceed through this public process. PTD Sundry Sundry Sundry PBU PTM P1-21 193-059 316-375 316-371 316-264 PBU B-31 191-046 316-399 316-368 316-270 PBU M-13A 201-165 316-376 316-369 316-259 PBU Q-06A 198-090 316-372 316-370 316-233 PBU E-07A 201-034 316-380 316-288 Regards, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a 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 Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.aov 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg StdietiNEDAUG 2 LO12 Alaska Oil and Gas Conservation Commission 65. 333 West 7 Avenue O ` Anchorage, Alaska 99501 a 3P Subject: Corrosion Inhibitor Treatments of GPB M -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft " bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M - 10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 -"' M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 _50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 • Zoi 65 2.► 63o WELL i G TRA S ITTAL PROAcTiVE J iAgNOSric SERVICES, INC. To: AOGCC Christine Shartzer 333 VV. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) 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 : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Shay Phillips LR2 - 1 900 Benson Blvd. Anchorage, AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 11- May -12 M -13A BL / CD 50 -029- 20522 -01 2) Signed : Date : • • Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245 -8952 E-MAIL : ".i WEBSITE : _.,,..__....._.._. v._.,.._,.. r .....W_...._...,.....__.._ D Archives \ Distribution \TransmittalSheets\BP Transmit.docx Re: M-pad temperature logs . . Subject: Re: M-pad temperature logs From: Tom Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Nov 2001 09:43:56 -0900 To: "McLellan, Bryan J" <McLellBJ@BP.com> Brian, Thanks for the info. I'd like to get together as well. When is the key?? Performing the same procedure on M-13Ai is appropriate. For the present time, on the other wells, I suggest you send us the log copies and include a letter describing the why and then the what was determined. How does that sound? Also, is the reporting by Joe just until we have a chance to pass approval on the temperature logs?? Tom "McLellan, Bryan J" wrote: Tom, I would like to set up a time to get together to discuss the M-03Ai and M-38Ai temperature logs. Both logs would suggest that we have cement isolation uphole from the perfs. I can either come to your office when you have time, or send copies of the logs to you, whichever you prefer. Integrity Engineer) to add these wells should begin reporting injection rate ~ dQ\-\CoS- Also, we just finished drilling well M-13Ai and would like to use the same method to confirm cement integrity as we did with M-03Ai and M-38Ai. If you agree, we will run a baseline temperature log and follow up with a temp warmback after 1 month of injection in M-13Ai. I have also asked Joe Anders (BP Well to his monthly monitoring list and he and pressure to you each month. Thank you, Bryan McLellan Bryan McLellan BP Exploration, Alaska Production Engineer (907) 564-5516 ~CANNED JUN 2 5 2007 . .' ". fI' .,"'t-', .".!;.,~.,;,~.-' '. \..... ~~ ~4f- (tc..o(" 10fl 6/25/2007 12:33 PM . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfihn _ MatXer.doc ~ r-. dO /- /ç,S' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ~(.. 4 \ ~ 11J \ Ck DATE: January 15, 2004 P.l. Supervisor From: John Spaulidng Petroleum Inspector SUBJECT: Mechanical Integrity Tests BPXA M-Pad 13A Prudhoe Bay Unit Prudhoe Bay Field NON- CONFIDENTIAL 4 P Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details This well has a completion inside of a completion and the CMIT was done to establish integrity between the· two completions. As noted above integrity was proven. Total Time during tests: 1 cc:~ M.I.T.'s performed: 1 Number of Failures: Q Attachments: wellbore schematic MIT report form 5/12/00 L.G. mit pbu m-13a 1-15-04 jhs-2.xls 1/20/2004 I 'î D~ DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 MD 10895" TVD 8762 ,- Completion Date 11/17/2001..- Completion Status WAGIN Current Status WAGIN S¡twl 7 fJt.v ~ \ API No. 50-029-20522-01-00 GJ- Permit to Drill 2011650 Well Name/No. PRUDHOE BAY UNIT M-13A Operator BP EXPLORATION (ALASKA) INC ----------- REQUIRED INFORMATION Mud Log No Samples No Directional Survey No . ---- ---- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) - Log/ Electr Data Digital Dataset Type Med/Frmt Number ---fED D --'1Ô526 I c?ED D -10682 F D "1Ô648 ~ -roD ~ D ~ f-ED Name Pressure Log Log Run Scale Media No 1 Interval OH / Start Stop CH Received Comments 9104 10864 Case 1/15/2002 ~pJ~cl¡Ønl?r9fjIØ' ...-40649 --11J526 2 Blu 9146 10890 Case 3/26/2002 9336 1 0850 Open 3/4/2002 9146 10890 Case 7/3/2002 9336 10850 Open 3/4/2002 Revision 9104 10864 Case 1/15/2002 9146 1 0864 Case 7/3/2002 9336 1 0850 Open 5/9/2002 -"-------- C 2 Blu ~810 Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments .~c ADDITIONAL INFORMATION y/ij) Chips Received? CVi1:r" Daily History Received? '0D/N &N Well Cored? Formation Tops Analysis Received? ~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 11/25/2003 Permit to Drill 2011650 Well Name/No. PRUDHOE BAY UNIT M-13A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20522-01-00 MD 10895 TVD 8762 rmPletion Date 11/17/2001 Compliance Reviewed By: \~ Completion Status WAGIN Current Status WAGIN UIC Y Date: ') b ~ 3> ~~ -~""'. 8000 7000 13 6000 (/) E uJ :õ 5000 .Q Q) E :J 0 4000 > ~ '- . 3000 E: 2' "ãj 2000 0 1000 0 2000 1800 ü5 1600 ~ 1400 0... 1200 I 1000 ::;: 800 600 400 200 0 '---- 25 (i) 20 a. :a a. 15 .D = 10 5 0 DI 13:16:07 July 03 2002 CPE V2.0.14 D 2001 I I I 1 I I _I- ~-----------------~-----------------~-----------------~----------------~- 1 I I I I I -í---------------,-----------------,-----------------,-----------------,----------------,- _L_______________~_________________~_________________L_________________L________________~_ r I I 1 I I -----------------r----- --------,-----------------,-----------------1------------------r----------------,- I ________l_________________l_________________L_________________L_________ I I I I I I -----------1---- -------t ---1--- --t- I 1 1 1 I -------------1--- ---------1-----------------1- -----~----------------- I -1- -------------1-___ ---------~-----------------4--------- -----~-----------------~ ---------------~- I I I 1 1 I -------------í--- -----------,-----------------,--------- -----,-----------------, ---------------,- I I J F M A M J J 2002 1 I I I I I 1 I I I I I 1 I I I I I ------~------í---------------,------ -----,------ -----,-----------------,----------------,- I 1 I I I I I 1 1 I r I -------------r----- ---------,------ -------¡------ -----r-----------------r----------------,- I 1 1 I I I I I I I I I -------------1------ ---------t------ ------t------ -----I------------------I------------------t- I I I I I I I I I 1 1 I -------------1------ --------~------ ~------ - - - - -1- - - - - - - - -- ~ --------~- I I I I I I " I - ..r-- ~ " I I J F M A M 2002 I I Miscible Injectant I I Produced Water DLean Gas WELL Water M-13A D 2001 ~---------------~-------J(iE<:-E-~"1E~ I I 1 I I I ~___ I ~:~? I .:..... ., I I I ------,--- I I I 1---- I I 1 !..._-- I ¡i -I /; :1 I; i! : ~i~t!~i: ; :::~-:·~f~ _"_...-.:-..-"::' ~ .. -.>:. .. . -.v .~~.;.- ~Ìi"f~f~ M & Ga~ Gcns. AnchorafJe ~ ~- ~~ . '. . . ..._·r '.. -.11- :- ~ J:. _.~ ~ -~~ 1-· ¡.' 2002 -,/ -' j'Vi. ·:·"Y.~., A Alaska 011 ;...- ~t i I I 1 I I I __________L________________~_ I I I I I I I I CJ <C I- Daily Injection Plot ~ > (f) (f) WELL <C I- !l. M-13A/PRUDHOE Dates From f¡) CD U) !l. I- (f) 12/01/2001 to 07/03/2002 J-cJ t { ~ Sw Name M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A M-13A ( ( Report Dat Inj Vol Metered Inj Vol Engr Inj Vol Alloc Wellhead Pres Bh Inj Pres Inj Index 6/1/02 O. O. O. 646. O. O. 12/1/01 O. O. O. O. O. O. 12/2/01 O. O. O. O. O. O. 12/3/01 O. O. o. O. O. O. 12/4/01 O. O. O. O. O. o. 12/5/01 O. O. O. O. O. O. 12/6/01 O. O. o. R LOr F I \1 F f6t O. 12/7/01 O. O. O. - ro\.~ ,,=. ~ '-""~. O. 12/8/01 O. O. o. O. O. O. 12/9/01 O. O. O. JLO~ 3 2002 o. o. 12/10/01 O. O. O. O. O. O. 12/11/01 O. O. o. Alaska OiI8A!ias Cans. ComlliSsion o. 12/12/01 O. O. o. CAnchorage o. o. 12/13/01 O. O. O. O. O. O. 12/14/01 O. O. O. O. O. o. 12/15/01 O. O. O. O. O. O. 12/16/01 O. O. o. O. O. o. 12/17/01 O. O. O. O. O. O. 12/18/01 1,783. 1,783. 1,783. 1,510. 5,257.30714 2.14796 12/19/01 3,270. 3,270. 3,270. 974. 4,774.72891 2.08087 12/20/01 5,201. 5,201. 5,201. 1,661. 5,362.12078 2.40915 12/21/01 5,733. 5,733. 5,733. 1,892. 5,557.69915 2.43498 12/22/01 6,276. 6,276. 6,276. 1,911. 5,536.99056 2.68927 12/23/01 7,170. 7,170. 7,170. 1,955. 5,507.791 3.11127 12/24/01 7,182. 7,182. 7,182. 1,886. 5,437.74225 3.21418 12/25/01 6,504. 6,504. 6,504. 1,699. 5,307.24688 3.09129 12/26/01 3,420. 3,420. 3,420. 911. 4,705.61815 2.27643 12/27/01 3,683. 3,683. 3,683. 969. 4,752.24252 2.3777 12/28/01 3,688. 3,688. 3,688. 992. 4,775.01809 2.34643 12/29/01 3,691. 3,691. 3,691. 1,008. 4,790.88329 2.32487 12/30/01 3,326. 3,326. 3,326. 974. 4,772.47961 2.11954 12/31/01 2,914. 2,914. 2,914. 946. 4,760.13485 1.87171 1/1/02 2,988. 2,988. 2,988. 965. 4,776.47529 1.8993 1/2/02 3,119. 3,119. 3,119. 992. 4,798.60363 1.95507 1/3/02 3,772. 3,772. 3,772. 1,141. 4,920.2022 2.19694 1/4/02 2,874. 2,874. 2,874. 739. 4,554.54468 2.12688 1/5/02 2,872. 2,872. 2,872. 710. 4,525.61466 2.1719 1/6/02 2,870. 2,870. 2,870. 711. 4,526.68459 2.16863 1/7/02 2,870. 2,870. 2,870. 702. 4,517.68459 2.18348 1/8/02 2,810. 2,870. 2,870. 719. 4,534.68459' 2.1556 1/9/02 2,876. 2,876. 2,876. 738. 4,553.4 7 465 2.13004 1/10/02 2,874. 2,874. 2,874. 785. 4,600.54468 2.05686 1/11/02 2,876. 2,876. 2,876. 826. 4,641.47465 1.99971 1/12/02 2,876. 2,876. 2,876. 868. 4,683.4 7 465 1.94297 1/13/02 2,874. 2,874. 2,874. 867. 4,682.54468 1.94284 1/14/02 2,876. 2,876. 2,876. 871. 4,686.4 7 465 1.93904 1/15/02 2,874. 2,874. 2,874. 878. 4,693.54468 1.9285 1/16/02 2,874. 2,874. 2,874. 893. 4,708.54468 1.90928 1/17/02 2,874. 2,874. 2,874. 890. 4,705.54468 1.9131 1/18/02 2,876. 2,876. 2,876. 892. 4,707.47465 1.91197 1/19/02 2,874. 2,874. 2,874. 906. 4,721.54468 1.89294 ( ( M-13A 1/20/02 2,872. 2,872. 2,872. 901. 4,716.61466 1.89778 M-13A 1/21/02 2,872. 2,872. 2,872. 904. 4,719.61466 1.89403 M-13A 1/22/02 2,870. 2,870. 2,870. 911. 4,726.68459 1.88392 M-13A 1/23/02 2,872. 2,872. 2,872. 900. 4,715.61466 1.89904 M-13A 1/24/02 2,870. 2,870. 2,870. 897. 4,712.68459 1.9014 M-13A 1/25/02 2,872. 2,872. 2,872. 902. 4,717.61466 1.89653 M-13A 1/26/02 2,872. 2,872. 2,872. 913. 4,728.61466 1.88285 M-13A 1/27/02 2,870. 2,870. 2,870. 923. 4,738.68459 1 .8692 M-13A 1/28/02 2,872. 2,872. 2,872. 955. 4,770.61466 1.8324 M-13A 1/29/02 2,870. 2,870. 2,870. 952. 4,767.68459 1.83455 M-13A 1/30/02 2,870. 2,870. 2,870. 974. 4,789.68459 1.80911 M-13A 1/31/02 2,870. 2,870. 2,870. 988. 4,803.68459 1 .79328 M-13A 2/1 /02 2,872. 2,872. 2,872. 997. 4,812.61466 1 .78457 M-13A 2/2/02 2,874. 2,874. 2,874. 1,000. 4,815.54468 1 .78257 M-13A 2/3/02 2,876. 2,876. 2,876. 1,003. 4,818.47465 1 .78058 M-13A 2/4/02 2,872. 2,872. 2,872. 986. 4,801.61466 1 .79686 M-13A 2/5/02 2,874. 2,874. 2,874. 985. 4,800.54468 1.79931 M-13A 2/6/02 2,874. 2,874. 2,874. 993. 4,808.54468 1 .79035 M-13A 2/7/02 6,449. 6,449. 6,449. 988. -9,392.19481 o. M-13A 2/8/02 8,622. O. O. O. O. O. M-13A 2/9/02 8,622. O. O. O. O. O. M-13A 2/1 0/02 8,622. O. O. O. O. O. M-13A 2/11/02 6,112. 6,112. 6,112. 1,348. 3,903.51831 20.94822 M-13A 2/12/02 2,267. 2,267. 2,267. 1,206. 5,040.54732 1.23389 M-13A 2/13/02 2,876. 2,876. 2,876. 858. 4,673.47465 1.95619 M-13A 2/14/02 2,866. 2,866. 2,866. 813. 4,628.8243 2.01044 M-13A 2/15/02 2,874. 2,874. 2,874. 815. 4,630.54468 2.01362 M-13A 2/16/02 2,870. 2,870. 2,870. 798. 4,613.68459 2.03486 M-13A 2/17/02 2,870. 2,870. 2,870. 806. 4,621.68459 2.02338 M-13A 2/18/02 2,868. 2,868. 2,868. 817. 4,632.75447 2.00631 M-13A 2/19/02 2,872. 2,872. 2,872. 815. 4,630.61466 2.01212 M-13A 2/20/02 2,868. 2,868. 2,868. 829. 4,644.75447 1.98961 M-13A 2/21/02 2,868. 2,868. 2,868. 819. 4,634.75447 2.00351 M-13A 2/22/02 2,874. 2,874. 2,874. 822. 4,637.54468 2.0038 M-13A 2/23/02 2,870. 2,870. 2,870. 827. 4,642.68459 1 .99386 M-13A 2/24/02 2,870. 2,870. 2,870. 834. 4,649.68459 1.98421 M-13A 2/25/02 2,866. 2,866. 2,866. 828. 4,643.8243 1.98951 M-13A 2/26/02 2,866. 2,866. 2,866. 836. 4,651.8243 1.97852 M-13A 2/27/02 2,870. 2,870. 2,870. 823. 4,635.63356 2.06372 M-13A 2/28/02 2,874. 2,874. 2,874. 815. 4,630.54468 2.01362 M-13A 3/1/02 2,874. 2,874. 2,874. 815. 4,630.54468 2.01362 M-13A 3/2/02 2,876. 2,876. 2,876. 824. 4,639.47465 2.0025 M-13A 3/3/02 2,872. 2,872. 2,872. 788. 4,603.61466 2.05092 M-13A 3/4/02 2,872. 2,872. 2,872. 780. 4,594.77168 2.0812 M-13A 3/5/02 2,868. 2,868. 2,868. 776. 4,590.02832 2.10346 M-13A 3/6/02 2,870. 2,870. 2,870. 747. 4,562.68459 2.1112 M-13A 3/7/02 2,716. 2,716. 2,716. 645. 4,465.923 2.15102 M-13A 3/8/02 2,876. 2,876. 2,876. 759. 4,574.47465 2.09742 M-13A 3/9/02 2,876. 2,876. 2,876. 787. 4,602.47465 2.05545 M-13A 3/1 0/02 2,874. 2,874. 2,874. 777. 4,592.54468 2.0687 M-13A 3/11/02 2,876. 2,876. 2,876. 749. 4,564.47465 2.11283 M-13A 3/12/02 2,874. 2,874. 2,874. 777. 4,592.54468 2.0687 ( ( M-13A 3/13/02 2,874. 2,874. 2,874. 789. 4,604.54468 2.05099 M-13A 3/14/02 2,870. 2,870. 2,870. 797. 4,612.68459 2.0363 M-13A 3/15/02 2,872. 2,872. 2,872. 774. 4,589.61466 2.07163 M-13A 3/16/02 2,870. 2,870. 2,870. 818. 4,633.68459 2.00641 M-13A 3/17/02 2,868. 2,868. 2,868. 838. 4,653.75447 1.97727 M-13A 3/18/02 2,866. 2,866. 2,866. 843. 4,658.8243 1.96901 M-13A 3/19/02 2,868. 2,868. 2,868. 827. 4,642.75447 1.99238 M-13A 3/20/02 2,882. 2,882. 2,882. 859. 4,674.26427 1 .95922 M-13A 3/21/02 2,870. 2,870. 2,870. 871. 4,686.68459 1.93472 M-13A 3/22/02 2,872. 2,872. 2,872. 874. 4,689.61466 1.93225 M-13A 3/23/02 2,870. 2,870. 2,870. 861. 4,676.68459 1.94785 M-13A 3/24/02 2,870. 2,870. 2,870. 869. 4,684.68459 1.93733 M-13A 3/25/02 2,868. 2,868. 2,868. 890. 4,705.75447 1 .90884 M-13A 3/26/02 2,872. 2,872. 2,872. 893. 4,708.61466 1.90787 M-13A 3/27/02 2,872. 2,872. 2,872. 898. 4,713.61466 1.90155 M-13A 3/28/02 2,870. 2,870. 2,870. 891. 4,706.68459 1.90898 M-13A 3/29/02 2,874. 2,874. 2,874. 888. 4,703.54468 1.91565 M-13A 3/30/02 2,874. 2,874. 2,874. 855. 4,670.54468 1.95873 M-13A 3/31 /02 2,870. 2,870. 2,870. 847. 4,662.68459 1 .96654 M-13A 4/1/02 2,866. 2,866. 2,866. 860. 4,675.8243 1.94627 M-13A 4/2/02 2,862. 2,862. 2,862. 662. 4,477.96383 2.24524 M-13A 4/3/02 2,832. 2,832. 2,832. 539. 4,356.00402 2.45676 M-13A 4/4/02 2,873. 2,873. 2,873. 605. 4,420.57967 2.36012 M-13A 4/5/02 2,881. 2,881. 2,881. 592. 4,407.29936 2.39279 M-13A 4/6/02 2,891. 2,891. 2,891. 678. 4,492.94788 2.24164 M-13A 4/7/02 2,754. 2,754. 2,754. 682. 4,497.54468 2.22054 M-13A 4/8/02 2,911. 2,911. 2,911. 684. 4,498.24126 2.24792 M-13A 4/9/02 2,874. 2,874. 2,874. 730. 4,545.54468 2.14114 M-13A 4/1 0/02 2,896. 2,896. 2,896. 714. 4,528.77168 2.18483 M-13A 4/11/02 2,878. 2,878. 2,878. 761. 4,576.40457 2.09593 M-13A 4/12/02 2,902. 2,902. 2,902. 720. 4,534.55984 2.17984 M-13A 4/13/02 3,121. 3,121. 3,121. 746. 4,552.52764 2.31312 M-13A 4/14/02 3,036. 3,036. 3,036. 771. 4,580.71452 2.20408 M-13A 4/15/02 2,905. 2,905. 2,905. 761. 4,575.45376 2.11706 M-13A 4/16/02 3,157. 3,157. 3,157. 839. 4,644.15137 2.19102 M-13A 4/17/02 2,431. 2,431. 2,431. 519. 4,348.85558 2.12205 M-13A 4/18/02 2,872. 2,872. 2,872. 889. 4,704.61466 1.91295 M-13A 4/19/02 2,872. 2,872. 2,872. 905. 4,720.61466 1 .89278 M-13A 4/20/02 2,870. 2,870. 2,870. 890. 4,705.68459 1.91026 M-13A 4/21/02 2,870. 2,870. 2,870. 853. 4,668.68459 1 .95849 M-13A 4/22/02 2,870. 2,870. 2,870. 795. 4,610.68459 2.0392 M-13A 4/23/02 2,870. 2,870. 2,870. 831. 4,646.68459 1 .98834 M-13A 4/24/02 2,870. 2,870. 2,870. 878. 4,693.68459 1 .92564 M-13A 4/25/02 2,874. 2,874. 2,874. 881. 4,696.54468 1.92463 M-13A 4/26/02 2,870. 2,870. 2,870. 886. 4,701.68459 1.91535 M-13A 4/27/02 2,872. 2,872. 2,872. 896. 4,711.61466 1 .90407 M-13A 4/28/02 2,876. 2,876. 2,876. 902. 4,717.47465 1.89934 M-13A 4/29/02 2,876. 2,876. 2,876. 895. 4,710.47465 1.90817 M-13A 4/30/02 2,872. 2,872. 2,872. 884. 4,699.61466 1.91934 M-13A 5/1/02 2,874. 2,874. 2,874. 860. 4,675.54468 1 .95208 M-13A 5/2/02 2,880. 2,880. 2,880. 851. 4,666.33444 1.96847 M-13A 5/3/02 2,880. 2,880. 2,880. 869. 4,684.33444 1 .94454 (" ( M-13A 5/4/02 2,874. 2,874. 2,874. 884. 4,699.54468 1.92077 M-13A 5/5/02 2,880. 2,880. 2,880. 871. 4,686.33444 1.94192 M-13A 5/6/02 2,874. 2,874. 2,874. 832. 4,647.54468 1 .98992 M-13A 5/7/02 2,872. 2,872. 2,872. 802. 4,617.61466 2.03062 M-13A 5/8/02 2,870. 2,870. 2,870. 700. 4,515.68459 2.18681 M-13A 5/9/02 2,870. 2,870. 2,870. 697. 4,512.68459 2.19182 M-13A 5/1 0/02 2,870. 2,870. 2,870. 752. 4,567.68459 2.10346 M-13A 5/11/02 2,872. 2,872. 2,872. 808. 4,623.61466 2.02204 M-13A 5/12/02 2,872. 2,872. 2,872. 838. 4,653.61466 1.98022 M-13A 5/13/02 2,872. 2,872. 2,872. 828. 4,643.61466 1.99396 M-13A 5/14/02 2,872. 2,872. 2,872. 816. 4,631.61466 2.01072 M-13A 5/15/02 2,872. 2,872. 2,872. 807. 4,622.61466 2.02347 M-13A 5/16/02 2,868. 2,868. 2,868. 815. 4,630.75447 2.00913 M-13A 5/17/02 2,874. 2,874. 2,874. 825. 4,640.54468 1.99961 M-13A 5/18/02 2,870. 2,870. 2,870. 835. 4,650.68459 1 .98284 M-13A 5/19/02 2,872. 2,872. 2,872. 791. 4,606.61466 2.04654 M-13A 5/20/02 2,870. 2,870. 2,870. 795. 4,610.68459 2.0392 M-13A 5/21 /02 2,681. 2,681. 2,681. 675. 4,497.07326 2.07218 M-13A 5/22/02 2,870. 2,870. 2,870. 780. 4,595.68459 2.06116 M-13A 5/23/02 2,870. 2,870. 2,870. 772. 4,587.68459 2.07308 M-13A 5/24/02 2,874. 2,874. 2,874. 769. 4,584.54468 2.08068 M-13A 5/25/02 2,876. 2,876. 2,876. 773. 4,588.47465 2.07622 M-13A 5/26/02 2,872. 2,872. 2,872. 788. 4,603.61466 2.05092 M-13A 5/27/02 2,872. 2,872. 2,872. 793. 4,608.61466 2.04362 M-13A 5/28/02 2,870. 2,870. 2,870. 788. 4,603.68459 2.04939 M-13A 5/29/02 2,872. 2,872. 2,872. 751. 4,566.61466 2.10658 M-13A 5/30/02 2,872. 2,872. 2,872. 753. 4,568.61466 2.10349 M-13A 5/31 /02 2,872. 2,872. 2,872. 775. 4,590.61466 2.07014 M-13A 6/2/02 3,000. 3,000. 3,000. 61. 3,872.03773 4.48585 M-13A 6/3/02 2,870. 2,870. 2,870. 620. 4,434.8422 2.34984 M-13A 6/4/02 2,874. 2,874. 2,874. 631. 4,446.54468 2.31163 M-13A 6/5/02 2,876. 2,876. 2,876. 644. 4,459.47465 2.28943 M-13A 6/6/02 2,872. 2,872. 2,872. 675. 4,490.61466 2.23094 M-13A 6/7/02 2,870. 2,870. 2,870. 726. 4,541.68459 2.14432 M-13A 6/8/02 2,870. 2,870. 2,870. 721. 4,536.68459 2.15237 M-13A 6/9/02 2,872. 2,872. 2,872. 749. 4,564.61466 2.10968 M-13A 6/1 0/02 2,872. 2,872. 2,872. 763. 4,578.61466 2.0882 M-13A 6/11 /02 2,876. 2,876. 2,876. 659. 4,474.47465 2.26242 M-13A 6/12/02 2,872. 2,872. 2,872. 660. 4,475.61466 2.25725 M-13A 6/13/02 2,879. 2,879. 2,879. 756. 4,571.36951 2.10438 M-13A 6/14/02 2,872. 2,872. 2,872. 758. 4,573.61466 2.09582 M-13A 6/15/02 2,872. 2,872. 2,872. 738. 4,553.61466 2.12686 M-13A 6/16/02 2,866. 2,866. 2,866. 716. 4,531.8243 2.15723 M-13A 6/17/02 2,743. 2,743. 2,743. 834. 4,654.02546 1.89074 M-13A 6/18/02 2,929. 2,929. 2,929. 1,058. 4,871.60114 1 .75564 M-13A 6/19/02 2,916. 2,916. 2,916. 1,042. 4,856.06384 1 .76428 M-13A 6/20/02 2,886. 2,886. 2,886. 1,023. 4,838.12377 1 .76529 M-13A 6/21/02 2,982. 2,982. 2,982. 1,006. 4,817.69342 1.8471 M-13A 6/22/02 2,938. 2,938. 2,938. 1,018. 4,831.2796 1.80466 M-13A 6/23/02 2,942. 2,942. 2,942. 1,034. 4,847.13637 1 .78968 M-13A 6/24/02 2,969. 2,969. 2,969. 1,010. 4,822.16452 1.83396 M-13A 6/25/02 2,504. 2,504. 2,504. 879. 4,706.66182 1 .66556 ( (' M-13A 6/26/02 2,366. 2,366. 2,366. 622. 4,453.7543 1.89206 M-13A 6/27/02 2,636. 2,636. 2,636. 803. 4,626.53025 1.85208 M-13A 6/28/02 2,918. 2,918. 2,918. 1,069. 4,877.37552 1.83501 M-13A 6/29/02 2,956. 2,956. 2,956. 1,083. 4,895.63356 1.74667 M-13A 6/30/02 3,012. 3,012. 3,012. 1,090. 4,900.59841 1.77455 M-13A 7/1/02 3,021. 3,021. 1,074. 4,884.26778 1.79714 M-13A 7/2/02 3,004. 3,004. 1,112. 4,922.89149 1.74689 ( ( WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 To: March 6, 2002 RE: MWD Formation Evaluation Logs: M-13~ AK-MW-11188 qOJ-llo5 IO?) 10 M-13A: Digital Log Images: 50-029-20522-01 1 CD RotTI PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNI.NG A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 S¡gn& ú-OQt¿p~ RECEIVED ~,.1 ,1.\/ r; r) 0 '..lOì I ¡,~~., l; :. L..... M ~Iaska OU & Gas Cons. Commission Anchorage g 33G,.../ocg'5ô 55,. K O~/à '6lo~ ck3s \, -----.--..-..-...--.--..--..-.--. ! . wt--L LOG TRANSMITTAL ( ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W- 7j¡ Street Suite # 700 Anchorage, Alaska 99501 RE: ~istribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT .WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM COLOR Open Hole 1 1 1 M-1 3Ai 2/12/02 Res. Eva!. CH 1 1 1 dOJ-llo5 Mech. CH 1 Caliper Survey -- Signed: ~~o~"puJ Date: IVED Print Name: r} 1\ [.ì '¡ I. 000? ! ~:..;: \. ,~ U L"~...~_.. .Alaska Oil & Gas Cons. Commission .Anchorage PRoAcTiVE DiAGNOSTic SERVicES, INC., } 10 K STREET SUiTE 200, ANCHORAGE, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: www.melrLoryloMom ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Add Perfs 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown- Pull tubing 708' FNL, 4496' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 932'FNL, 2421'FEL, Sec. 27, T12N, R12E,UM At effective depth 684'FNL, 2594'FEL, Sec. 27, T12N, R12E,UM At total depth 585' FNL, 2666' FEL, Sec. 27, T12N, R12E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Size 20" Length 109' 3022' 9-5/8" Surface PFt~CEIVED2' 7" MAR 0 7 20D¿ Stimulate - Alter casing - 5. Type of Well: Development _X Exploratory- Stratigraphic- Service (asp's 618930, 5980775) (asp's 615639,5985779) (asp's 615461,5986025) (asp's 615388,5986123) Plugging - Perforate _X Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-103 9. Permit number / approval number 200-1680 / 302-024 10. API number 50-029-22981-00 11. Field / Pool Prudhoe Bay Field / Aurora Pool 1 0079 feet 7009 feet Plugs (measured) Tagged PBTD @ 9919' (12/24/2001). 9919 feet 6906 feet Junk (measured) Measured Depth 174' 3087' True Vertical Depth 174' 2830' Cemented 260 sx AS 562 sx AS Lite III, 260 sx Class 'G' 582 sx Class 'G' 10057' 6994' PÃfækitti~~coos.commissiowasured Open Perfs 9551' - 9572', 9578' - 9598', 9608' - 9620', 9632' - 9642', 9652' - 9660', Anchorage 9762' - 9787', 9798' - 9814', 9822' - 9832' true vertical Open Perfs 6670' - 6684', 6688' - 6700', 6708' - 6715', 6722' - 6729', 6735' - 6740', 6806' - 6821', 6828' - 6839', 6844' - 6850' Tubing (size, grade, and measured depth) 3-1/2",9.2#, L-80 TBG @ 9432'. 3-1/2" 9.2# Tubing Tail to 9489'. Packers & SSSV (type & measured depth) 7" x 3-1/2" Baker S-3 Packer @ 9432'. 3-1/2" HES 'X' Nipple @ 2110'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl 324 306 1151 Prior to well operation 02/16/2002 Subsequent to operation 02/24/2002 15. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations Oil X Gas 17. '.Æ:b~rtifY that t:;egOiõ isðue and correct to the best of my knowledge. ~~~..Æ:Y ¿~ Title: Technical Assistant DeWayne R. Schnorr 899 Form 1 0-404 Rev 06/15/88 . Casinç¡ Pressure Gas Lift Tubinç¡ Pressure 239 273 621 16. Status of well classification as: 1381 Gas Lift ORIGINAL Suspended Service Date March 01. 2002 Prepared by DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLlC~ ( ( S-103 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/07/2002 PERFORATING: PERFORATING 02/10/2002 PERFORATING: DRIFT/TAG; PERFORATING 02/22/2002 PERFORATING: PERFORATING EVENT SUMMARY 02/07/02 RIH WITH 2.511 201 HSD PJ GUN LOADED 4 SPF, 180 DEGREES PHASING, SET DOWN AT 82231 JUST BELOW GLM #2 AT 82131, WORK GUNS UP AND DN (30 MINUTES), STILL SETTING DOWN AT 82231. POOH, DISCUSS OPTIONS WITH PE, DECIDE TO RIG DOWN AND BRING IN SLlCKLlNE, NOTIFY PAD OP OF WELL STATUS IIFLOWINGII. 02/1 0/02 DRIFTED W/2.5011 X 111 DUMMY GUN & SAMPLE BAILER TO 98751 WLM, (TARGET DEPTH FOR ADD PERFS=9572I). SMALL AMOUNT OF HYDRATES IN BAILER. RDMO. 02/22/02 COMPLETED ADPERF. PERFORATED C4 ZONE: 95521 - 95721 WITH 2.511 HSD 4 SPF POWERJET AND 95511 - 95711 WITH 2.511 HSD 4 SPF HYPERJET. BOTH GUNS ARE 180 DEG PHASED, ORIENTED 40 DEG CLOCKWISE FROM THE LOW SIDE. WELL WAS SHOT BALANCED DUE TO THE HYDRATING PROBLEM PREVIOUSLY ENCOUNTERED. WELL WAS TURNED BACK TO OPERATIONS TO POP WHEN JOB WAS COMPLETED. FLUIDS PUMPED BBLS 1 PRESSURE TEST LUBRICATOR W/ 2 BBL OF DIESEL, (1 TEST) 1 TOTAL ADD PERFS 02/22/2002 THE FOLLOWING INTERVAL WAS PERFORATED WITH THE 2-1/211 PJ 2506, 4 SPF, 180 DEGREE PHASED GUN, ORIENTED 40 DEGREES CLOCKWISE FROM THE LOW SIDE OF THE CASING. 95511 - 95711 95521 - 95721 Page 1 ,( il WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7ili Avenue, Suite 100 Anchorage, Alaska March 4, 2002 RE: MWD Formation Evaluation Logs M-13A, AK-MW-11188 1 LDWG formatted Disc with verification listing. API#: 50-029-20522-01 BDJ-lloS PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed~~ Date: Note: This data replaces any previous data for well: (M-13A). Mad Pass data adjusted to MWD data. I~ECE'VED t I ~;--, ;"'¡ ! O002 ,i. .;.!..... I; .,'. f... ,I , ,: \'~ \ '-' '~ ... Alaska on & Gas Cons. Commission AnchOrage WELL LOG TRANSMITfAL To: State of Alaska Alaska Oil and Gas Conservation Corom. Attn.: Lisa Weepie 333 West 7ili Avenue, Suite 100 i\nchorage,Alaska February 28, 2002 RE: MWD Fonnation Evaluation Logs M-13A, AK-MW-11188 1 LDWG fonnatted Disc with verification listing. API#: 50-029-20522-01 ¿:),DJ-/ &'S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO TB.E ATTENTION OF: Speny-Sun Drilling SeIVices Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed~,^~ Date: RECEIVED t"::~r: 0 .~ 2002 Alaska Oil & Gas Cons, Commission Anchorage WELL LOG TRANSMITTAL ~ c:;f'o-~ I ~5 ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7thStreet 00 ( I J d \ Suite #~ 1 OnG H l{ Y\ d ré'.... ) 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 I this transmittal letter to the attention of: Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole 1 1 1 M-13Ai 12/17/01 Res. Eva!. CH 1 1 1 Mech. CH 1 Caliper Survey Signed: ~ j t Qooþ-- l Print Name: Date: ----RéGE-WED J.AN 1 5 2002 Alaska OU & Gas Cons. Cormnis.'ioo Anmorage PRoAcTivE DiAGNOSTic SERvicES, INC., } 10 K STREET SUiTE 200, ANC~ORAGE, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage@memorylog.com Website: ~~\Y.~!!!.~TI.QIY..t9MQ!T . '\. ( STATE OF ALASKA ( ALASKA ülL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned !HI Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1937' SNL, 605' WEL, SEC. 01, T11N, R12E, UM ~<>,;';;:"::".,/'; fOcAl¿~ At top of productive interval ;~;\ ,'; .i. . \.i ' ..-: 731' SNL, 3275' WEL, SEC. 01, T11N, R12E, UM '-Il:ll~..??Li ¡. . Y~.Ac; At total depth !}E:~~ì:.::.~;, i 'J\,¡rf.c;;,;J' , 10. Well Number 307' SNL, 2666' WEL, SEC. 01, T11 N, R12E, UM '. __.~1.J2..-- .~ ; i\ H. -~, r , , . 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Leasè"'DE~sigriätìon and Sêríål'Nô. . Prudhoe Bay Field / Prudhoe Bay Pool KBE = 55.74' ADL 028260 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 16. No. of Completions 11/7/2001 11/12/2001 11/17/2001 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set 1 21. Thickness of Permafrost 10895 8762 FT 10860 8748 FTI !HI Yes 0 No (Nipple) 1938' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run GR, RES, MWD 23. CASING SIZE WT. PER FT. 20" X 30" Insulated 13-3/8" 72# 9-5/8" 47# 7" 29# 3-1/2" x 3-3116" 8.81 # /6.2# x 2-7/8" / 6.16# 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 6 spf MD TVD 10645' -10675' 871' - 8712' 10705' - 10735' 8715' - 8718' Classification of Service Well Water & Gas Injector 7. Permit Number 201-165 8. API Number 50- 029-20522-01 9. Unit or Lease Name Prudhoe Bay Unit M-13A GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 36" 8 cu yds Concrete Surface 2698' 17-1/2" 3255 cu ft Arcticset II Surface 9212' 12-1/4" 1280 cu ft Class 'G' 130 cu ft AS I 8710' 9345' 8-1/2" 374 cu ft Class 'G' 9155' 10895' 3-3/4" 92 cu ft Class 'G' AMOUNT PULLED MD TVD TUBING RECORD SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 9197' 7",26#, L-80 8710' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 33 Bbls MeOH 10645' - 10735' Acid Stimulation - See Attached Summary PACKER SET (MD) 9031' 8572' 25. 27. Date First Production December 18, 2001 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Water Injection PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL CHOKE SIZE 1 GAS-OIL RATIO OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. F,,¡I"""'" .îJ: 1'.Þ'l" ;to. ~~\~:tm!\r.i~ JJ\N 1 1 2002 o' Form 10-407 Rev. 07-01-80 ,Alaska Oil :& G;J¡s Gems. Commission, . n.! n..! i~;' "":::I''''' 0 RIG I N A L RB DMS BFl ~ *\1 ~u2m~œ Duplicate ( ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Shublik A 9362' 8712' Shublik B 9416' 8686' Shublik C 9454' 8642' Sadlerochit 9478' 8727' Zone 4A 10342' 8712' Zone 4A 1 0412' 8710' iA!!\I' 1 '1 'ì(]"'ì 'IJ "u'~1 '" --- L Uc ~¡aska em 3: G~s Cons. Commission Anci1oraç)\e 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 Date 0 { P { /. M-13A Well Number 201-165 Permit No. / A roval No. Prepared By Name/Number: Terrie Hubble, 564-4628 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 1 0-407 Rev. 07-01-80 CJ IGINAL BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: M-13 Common Well Name: M-13Ai Spud Date: 12/2/1980 Event Name: REENTER+COMPLETE Start: 11/6/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/6/2001 02:00 - 05:00 3.00 RIGU P PRE Accept rig 02:00 hrs 11/6/2001. RU. 05:00 - 06:00 1.00 BOPSUE P DECOMP Pull BPV. Set TWC. 06:00 - 07:30 1.50 BOPSUE P DECOMP RU for BOP test. 07:30 - 15:45 8.25 BOPSUE P DECOMP BOP test. Witness waived by AOGCC's John Crisp. Pulled and redressed blind ram seals and replaced hyd hose. 15:45 - 17:00 1.25 BOPSUE P DECOMP M/U MHA pull test to 30K. (wait on valve crew to remove TWC) 17:00 - 18:00 1.00 BOPSUE P DECOMP Pull TWC. 18:00 - 19:00 1.00 BOPSUE N RREP DECOMP Repair fifth wheel trailer used to move the methanol pup. 19:00 - 20:00 1.00 BOPSUE P DECOMP PJSM with new coil crew and Nabors hands. Also discussed the upcoming window milling operation. 20:00 - 22:00 2.00 BOPSUE P DECOMP Pressure test coil, MHA, inner reel valve, return lines, etc. 22:00 - 23:00 1.00 STWHIP P WEXIT MU Window milling BHA. 23:00 - 00:00 1.00 STWHIP P WEXIT RIH with window milling BHA. 11/7/2001 00:00 - 01 :45 1.75 STWHIP P WEXIT Continue to RIH with milling BHA. 01 :45 - 02:00 0.25 STWHIP P WEXIT Tag pinch point of whipstock at 9346.5' ELM (pinch pt approx 18" below top of whipstock). Subtract 10.5' from the coil depth to put on depth with e-line. 02:00 - 09:25 7.42 STWHIP P WEXIT Start milling window. Free spin at 2.5 BPM is 2350 psi. Mill through 7" casing at 9350.1' at 0630 hrs. Window TOP at 9344.9' and BOTTOM at 9350'. Drilled formation to 9360'. 09:25 - 10:30 1.08 STWHIP P WEXIT Making passes through window 0 cleanup. Prep to swap hole to FloPro. 10:30 - 11 :00 0.50 STWHIP P WEXIT Swapping hole to mud 10 bbls around POH 1: 1 flag pipe at 9000'. 11 :00 - 12:40 1.67 STWHIP P WEXIT TOH 12:40 - 13:15 0.58 STWHIP P WEXIT UD milling BHA. 13:15 - 14:05 0.83 DRILL P PROD1 M/U BHA #2. 14:05 - 16:25 2.33 DRILL P PROD1 RIH shallow test MWD at 1200' - okay RIH to 3100' and test Sperry orienter 3 for 3 clicks -okay. Continue RIH correct to EOP flag -6'. 16:25 - 18:00 1.58 DRILL P PROD1 Orienting 18:00 - 19:50 1.83 DRILL P PROD1 Directionally drilling build section f/ 9360' TF 13L 3400 PP on bottom 2.5/ 2.4 19:50 - 20:00 0.17 DRILL P PROD1 Tie-in coil depth with gamma ray at 9262'. Added 11' to coil length to tie-in. 20:00 - 22:00 2.00 DRILL P PROD1 Directionally drill build section to 9440'. 22:00 - 22:30 0.50 DRILL P PROD1 Short trip to window while giving the orienter one click. 22:30 - 00:00 1.50 DRILL P PROD1 Drill ahead from 9440' to 9470'. 11/8/2001 00:00 - 00:20 0.33 DRILL P PROD1 Drill ahead from 9470' to 9476'. 00:20 - 00:30 0.17 DRILL P PROD1 Pick up for directional survey. Could not get good signal to surface. Will drill another 5' and try again. 00:30 - 00:50 0.33 DRILL P PROD1 Drill ahead from 9476' to 9481'. 00:50 - 01:10 0.33 DRILL P PROD1 Pick up for another directional survey. First survey not good data. Completely shut-down the pumps and tried again. Still not getting good data. Problem with vibration (G-total) 01 :10 - 01 :30 0.33 DRILL P PROD1 Drill ahead from 9481' to 9488.5'. 01 :30 - 02:30 1.00 DRILL P PROD1 Attempt to get survey. Still getting poor signal to surface. Pulled up hole and tried to get survey repeats at previous survey depths. The repeat surveys did not match the originals. From what we can tell from the few good surveys that we have captured, our build rate in too low. We are only getting about 21 degree dog legs with the 2 degree motor. 02:30 - 04: 15 1.75 DRILL P PROD1 POOH to trouble shoot MWD and to increase motor bend to ( (' Printed: 11/19/2001 10:21:12AM (' ( - BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: M-13 Common Well Name: M-13Ai Spud Date: 12/2/1980 Event Name: REENTER+COMPLETE Start: 11/6/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/8/2001 02:30 - 04:15 1.75 DRILL P PROD1 2.57 degrees. Sperry claims MWD functioning fine, G-total (vibration measure) is the problem with the inclination data and we are too close to the parent wellbore for a good azimuth. 04:15 - 05:15 1.00 DRILL P PROD1 Lay down BHA. Found Baker motor to have wear pad nearly worn off. Sperry MWD checks out okay. 05:15 - 06:30 1.25 DRILL P PROD1 PU new Baker motor with 2.57 degree bend. Check service breaks. 06:30 - 08:45 2.25 DRILL P PROD1 RIH shallow test MWD and orienter at 3100' all looks good. Continue RIH 08:45 - 09:30 0.75 DRILL P PROD1 Log tie-in at RA tag +3' correction. 09:30 - 09:40 0.17 DRILL P PROD1 RIH to bottom. 09:40 - 12:00 2.33 DRILL P PROD1 Directionally drill build section section f/ 9488' to 9555' 50-60'/hr 3460 pp on bottom 3300 freespin. No mud losses. 12:00-12:15 0.25 DRILL P PROD1 Survey at 9530'. Showing 19 deg DLS. Should be getting close to 30's. Project TVD at bit 8707' and 68.7 deg 12:15 -14:30 2.25 DRILL N DPRB PROD1 TOH to inspect BHA and bit. No problems with motor wear pad shows very little wear, bit < 1/16" out on outside cutting structure and several cutters chipped. 14:30 -15:10 0.67 DRILL N DPRB PROD1 Wait on town for desision to increase or stay with same motor setting 2.57..stay 15:10 -15:45 0.58 DRILL N DPRB PROD1 PT the MHA. P/U rebuild M-09. 15:45 -16:15 0.50 DRILL N DPRB PROD1 Replace outside chain tensioner accumulator on injector. 16:15 -18:10 1.92 DRILL N DPRB PROD1 RIH to 3250. Shallow pulse test Sperry MWD and orienter- okay. RIH 18:10 - 20:45 2.58 DRILL P PROD1 Orient to highside and drill ahead to 9598'. 20:45 - 20:55 0.17 DRILL P PROD1 Pick up off bottom and pump up directional survey. 20:55 - 21:10 0.25 DRILL P PROD1 Directionally drill starting at 9598'. TF 22R. 21 :10 - 21 :30 0.33 DRILL P PROD1 At 9616', PU off bottom and pump up another survey. Having Gtotal problems again. Pick up 2 more feet and get a good survey at 9588'. Orient the tool face around to highside. 21 :30 - 22:05 0.58 DRILL P PROD1 Orient tool face to 1 L. 22:05 - 22:30 0.42 DRILL P PROD1 Drill ahead from 9616' to 9640'. 22:30 - 23:00 0.50 DRILL P PROD1 Pump up directional survey. We are only getting a 9.95 degree build rate with the tool face at 1 L. Pump up 3 more surveys to confirm. 23:00 - 00:00 1.00 DRILL N DPRB PROD1 Consult with Geologist, DD, and Dowell (coil cade) to come up with a workable plan to get the well back on track. Hole is loosing about 4 BPH. 11/9/2001 00:00 - 02:30 2.50 DRILL N DPRB PROD1 POOH with BHA. Will change out motor with 2.57 degree bend to motor with 3.06 degree bend. Flag pipe at 9000' EOP. 02:30 - 03:00 0.50 DRILL N DPRB PROD1 Lay down BHA. 03:00 - 04:00 1.00 DRILL N DPRB PROD1 PU BHA with 3.06 degree motor. 04:00 - 05:30 1.50 DRILL N DPRB PROD1 RIH to 3100'. Shallow hole test the MWD and orienter. OK. 05:30 - 06:20 0.83 DRILL N DPRB PROD1 Continue to RIH with BHA. Correct to EOP +3'. 06:20 - 06:45 0.42 DRILL P PROD1 Crew change out and safety meeting. 06:45 - 07: 15 0.50 DRILL N DPRB PROD1 RIH and orient to 70L prior to exiting window. RIH to 9626'. 07:15 - 07:30 0.25 DRILL N DPRB PROD1 Orient to highside 3R. 07:30 - 08:30 1.00 DRILL P PROD1 Directionally drilling f/ 9640' at 2 bpm 2700 FS 3200 on bottom. Drilled to 9688' 08:30 - 09:15 0.75 DRILL P PROD1 Survey. Still having problems with Gtotal but finally recieved good data. Getting acceptable 22 DLS for the motor to follow this mornings game plan Printed: 11/19/2001 10:21:12 AM BP EXPLORATION Page 3 of7 Operations Summary Report Legal Well Name: M-13 Common Well Name: M-13Ai Spud Date: 12/2/1980 Event Name: REENTER+COMPLETE Start: 11/6/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: NABORS 38 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/9/2001 09: 15 - 09:25 0.17 DRILL P PROD1 Drill to 9692 but stacking out. 09:25 - 09:40 0.25 DRILL P PROD1 Short wiper trip. 09:40 - 11 :00 1.33 DRILL P PROD1 Directionally drilliing ahead f/ 9692' to 9704' with build section 3R TF. 30-40' hr. orient over to 60R at 9704' and having problems stalling drilled to 9714', 11 :00 - 11 :20 0.33 DRILL P PROD1 Orient around to 20R 11 :20 - 13: 15 1.92 DRILL P PROD1 Drill ahead f/ 9717' to 9745' trying to get some righthand turn but 3 deg motor hanging up on bottom at 45+ TF. Pump lube sweep but no help. Mud losses 5-8 bph 13:15 - 15:00 1.75 DRILL P PROD1 TOH for 2.57 deg motor. 15:00 - 15:55 0.92 DRILL P PROD1 UD 3.06 motor P/U 2.57 deg motor and DS49 bit. 15:55 - 17:55 2.00 DRILL P PROD1 RIH to 3180' shallow test MWD and orienter--okay--RIH 17:55 - 18:05 0.17 DRILL P PROD1 Orient to SOL. 18:05 - 19:00 0.92 DRILL P PROD1 RIH and log tie-in at RA tag. Subtracted 11' from coil depth (-3' for coil stretch and -8' for log tie-in). 19:00 - 19:10 0.17 DRILL P PROD1 Tag TD at 9742'. Free spin at 3400 psi. 19:10 - 20:00 0.83 DRILL P PROD1 Orient tool face to 83R. 20:00 - 20:35 0.58 DRILL P PROD1 Drill ahead to 9779'. 20:35 - 20:45 0.17 DRILL P PROD1 Pump up directional survey. Hole loosing about 18 BPH. 20:45 - 21 :40 0.92 DRILL P PROD1 Drill ahead to 9830'. Free spin at 3400 psi. Tool face at 83R. 21 :40 - 22:00 0.33 DRILL P PROD1 Pick up off bottom to survey. Fighting Gtotal again. Did not get a survey. Will orient and drill ahead a few more feet and try to survey again. 22:00 - 22:35 0.58 DRILL N DFAL PROD1 Could not get orienter to orient on bottom. Pick up to window and try again. 22:35 - 23:40 1.08 DRILL N DFAL PROD1 Hung up at 9336' when picking up through the window. Drop back down to 9390' several times and pick back up to 9336'. Drop back down and stack out at 9345'. Pick up again and BHA passed through window up to 9286'. 23:40 - 00:00 0.33 DRILL N DFAL PROD1 Tested the orienter at 9268' (inside the casing). Got 1 click out of 3 tries. 11/10/2001 00:00 - 01 :15 1.25 DRILL N DPRB PROD1 Drop back down to TD at 9830' and tried again to get a survey. Gtotal problems again. Finally got a survey that indicated we were building 40.7 degree dog legs with the 2.57 degree motor. 01 :15 - 03:25 2.17 DRILL N DPRB PROD1 Pull out of hole to replace orienter and pick up a motor with a less agressive bend. 03:25 - 04:30 1.08 DRILL N DPRB PROD1 Lay down orienter and change out MWD. MWD internals were stuck inside the housing. Pumped steam into the housing and got them seperated. The bit looked good. 04:00 - 05: 15 1.25 DRILL N DPRB PROD1 Adjust motor bend to 1.69 degrees. Pick up new sperry orienter. Lost 1 BBL of mud to the hole while laying down the BHA. 05:15 - 06:00 0.75 DRILL N DPRB PROD1 RIH to 3200'. 06:00 - 06:30 0.50 DRILL N DPRB PROD1 Shallow hole test MWD and orienter. Sperry MWD dead. 06:30 - 07:00 0.50 DRILL N DFAL PROD1 TOH 07:00 - 07:45 0.75 DRILL N DFAL PROD1 Change out MWD ( impellar on pulser bound up). 07:45 - 10:00 2.25 DRILL N DPRB PROD1 RIH to 500' shallow test MWD -ok RIH to 3200' shallow test the orienter - ok RIH to 9405'. No problems going through window. 10:00 - 10:30 0.50 DRILL P PROD1 Log tie-in -13' correction. 10:30 -11:15 0.75 DRILL P PROD1 Orient to 11 OR 11:15 -14:30 3.25 DRILL P PROD1 Directionally drill f/9830' to 9996'.3350 free-spin 3800 on bottom. Mud losses 10-12 bph 14:30 - 15:25 0.92 DRILL P PROD1 Wiper trip to 9400'. Overpull at 9870'-9850' and 9450'. (' (" Printed: 11/19/2001 10:21:12AM ( (' BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: M-13 Common Well Name: M-13Ai Spud Date: 12/2/1980 Event Name: REENTER+COMPLETE Start: 11/6/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/10/2001 15:25 - 18:30 3.08 DRILL P PROD1 Directionally drill f/ 9996' to 10,120'. 3350 free-spin 3850 on bottom. Mud losses 10 bph. 18:30 - 19:30 1.00 DRILL P PROD1 Wiper trip to window. No overpull observed. 19:30 - 20:00 0.50 DRILL P PROD1 Orient tool face to 139R. 20:00 - 21 :15 1.25 DRILL P PROD1 Directionally drill from 10,120' to 10,205'. Having problems with weight transfer to the bit. Appears that we may have crossed a fault at 10,100' (cutting samples also indicate a fault crossing). Launch a 5 barrellubetex pill (6% Lubetex). The pill seemed to help. 21 :15 - 21:40 0.42 DRILL P PROD1 Pump up a directional survey. Still fighting the Gtotal. It took 3 attempts, but finally got an acceptable survey. 21 :40 - 22:00 0.33 DRILL P PROD1 Drill ahead from 10,205' to 10,225'. Drilling at 100+ fPH until +/- 10,218' when the ROP slowed to about 45 fPH. Hole loosing about 10 BPH. 22:00 - 22:15 0.25 DRILL P PROD1 Pump up directional survey. 22:15 - 00:00 1.75 DRILL P PROD1 POOH with coil and BHA. Flag pipe at 9000' EOP. 11/11/2001 00:00 - 00:30 0.50 DRILL P PROD1 Continue to POOH with coil. 00:30 - 01 :30 1.00 DRILL P PROD1 Lay down MWD and 1.69 degree motor. Bit still in gauge. One chip missing from one of the carbide side cutters. Plan to re-run. 01 :30 - 02:15 0.75 DRILL P PROD1 Cut 205' of coil from the reel. 02: 15 - 03:00 0.75 DRILL P PROD1 Re-head coil and pull test. PU New MHA and pressure test. 03:00 - 05:00 2.00 DRILL P PROD1 Make up and surface test new MWD with Sperry resistivity tool. Make up Baker motor with 1.04 degree bend. 05:00 - 08:20 3.33 DRILL P PROD1 RIH to 3411' and shallow test MWD. Ok. RIH correct to flag depth problem hanging up at 9421'. Turned out to be window area. Made it through. Depth way off after cutting pipe. 08:20 - 08:55 0.58 DRILL P PROD1 Log tie-in -61' correction. 08:55 - 09:25 0.50 DRILL P PROD1 RIH 09:25 - 09:40 0.25 DRILL P PROD1 Orient 09:40 - 11 :05 1.42 DRILL P PROD1 Directionally drill f/1 0225' to 10323' 3530 on bottom 3050 fS 2.4/2.3 11 bph loss 11 :05 - 14:00 2.92 DRILL P PROD1 Wiper trip into casing. Replace oiler pump on Nabors tri-plex. Orient 40L to get through window. Tight spots at 9450', 9850'-70', 10110'-10135', 10220'-10230' 14:00 - 17:50 3.83 DRILL P PROD1 Directionally drill from 10323' to 10425'. Lost circulation. 10% returns. Reduce pump rate to 2.2 bpm. Slowly regaining returns back to 40% by 10455' (1700hrs). Ordered 3% KCL from hotwater plant. Have 600 bbls on location in upright tanks. Prep to transfer fluids to rig. Drill to 10500' 2.3 in/1.2 out. 17:50 - 20:30 2.67 DRILL P PROD1 Wiper trip through window. Hung up going back down through window. Pick up bit and then dropped through at a tool face of 30R. 20:30 - 22:00 1.50 DRILL P PROD1 Drill ahead to 10,555'. Drilling with 3% KCI brine. free spin of 2600 psi. Drilling with a 45R tool face. Having some weight transfer problems and having to do frequent short wiper trips and pumping flo-pro pills. fluid loss rate of about 30 BPH. 22:00 - 23:30 1.50 DRILL P PROD1 Drill ahead from 10,555' to 10,626'. Still having some weight transfer difficulties. Pumping 5 to 10 barrel flo-pro pills helps. 23:30 - 00:00 0.50 DRILL P PROD1 Launch 10 bbl flo-pro pill and wipe hole up to 10,000'. 11/12/2001 00:00 - 00:30 0.50 DRILL P PROD1 Orient tool face to 115L. 00:30 - 01 :25 0.92 DRILL P PROD1 Drill ahead from 10,626' to 10648'. The hole got very sticky. Wipe the hole up to 10,480'. Saw motor work at 10,550' when Printed: 11/19/2001 10:21:12 AM BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: M-13 Common Well Name: M-13Ai Spud Date: 12/2/1980 Event Name: REENTER+COMPLETE Start: 11/6/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/12/2001 00:30 - 01 :25 0.92 DRILL P PROD1 pulling up hole. Drop back down and started stacking out at 10,624'. Hole is sticky from 10,624' to TD at 10,648'. 01 :25 - 02:20 0.92 DRILL P PROD1 Drill ahead from 10,648'-10,720'. Weight transfer still an issue. 02:20 - 04:30 2.17 DRILL P PROD1 Wiper trip from 10,648' to the window. The hole was sticky and motor work was observed on the way out of the hole at 10,556' and 10,125'. On the way back to bottom the hole was sticky and motor work was observed at 10,125' , 10,370' , and 10,624'. 04:30 - 05:20 0.83 DRILL P PROD1 Drill ahead from 10,720' to 10,770'. Hole still loosing about 30 BPH. 05:20 - 05:45 0.42 DRILL P PROD1 Orient tool face to 176L to start the drop section of the hole. 05:45 - 06:35 0.83 DRILL P PROD1 Drill ahead f/10,770' to 10828'. Hole still loosing about 30 BPH. Pumping 5 bbl pills w/ 3% Lube-tex and Flo-vis. 06:35 - 07:15 0.67 DRILL P PROD1 Orienting 07: 15 - 08:45 1.50 DRILL P PROD1 Directionally drill f/10828'. Having difficulty holding TF, wild swings. Beginning to drill rathole section so may not be an issue. Drill ahead to 108'5' TD. 08:45 - 10:15 1.50 DRILL P PROD1 Wiper trip out to 9450'. Very tight at 10556' Others: 10290-10270,10230-10190,10110-10035,9870-9850. 10: 15 - 11 :00 0.75 DRILL P PROD1 Log tie-in +9' correction. 11 :00 - 11 :45 0.75 DRILL P PROD1 Wiper trip IN. Tagged at 10895'. TD revised to 10995' 11:45-14:15 2.50 DRILL P PROD1 Log MAD pass from TD to 9480'. Losses at 35 bph. 14:15 -17:30 3.25 DRILL P PROD1 Wiper trip in. Fair ratty on bottom. Pump 15 bbl vis-pill and chase out. Pull to 9800 then back to bottom. Tight at 10100, 10850', 10750, 10556'. 17:30 - 20:20 2.83 DRILL P PROD1 TOH laying in pill (5% Lube-tex, 4ppb Clay-gaurd, 4 ppb Flo-vis) through the openhole 20:20 - 21 :20 1.00 DRILL P PROD1 Lay down drilling BHA. 21 :20 - 21 :50 0.50 EVAL P PROD1 Down load resistivity tool data. 21 :50 - 22:25 0.58 EVAL N MISC PROD1 Could not get the Sperry MWD orifice holder out of the flow tube (and as a result, could not remove the sonde from the flex collar. Tried pulling on the orifice holder with the tuggers without success. After exhausting all other options, we unscrewed the flow tube from the flex collar. The orifice holder remains in the flow tube. Then pulled the sonde from the flex collar and finished laying down the BHA. 22:25 - 22:45 0.33 CASE P COMP Pump dart through coil. 22:45 - 23:45 1.00 CASE P COMP MU Baker coil connector and test. 23:45 - 00:00 0.25 CASE P COMP Lay down injector and prep floor for liner pickup. 11/13/2001 00:00 - 00:30 0.50 CASE P COMP Continue to prep rig for liner pickup. 00:30 - 01 :00 0.50 CASE P COMP Pre-job safety meeting prior to pick up of liner. 01 :00 - 03:30 2.50 CASE P COMP Pick up 2-7/8" x 3-1/2" liner. 03:30 - 04:30 1.00 CASE P COMP Make up connection to liner and stab on injector. 04:30 - 08:00 3.50 CASE P COMP RIH with liner on coil. Stopped at 9346', top of whipstock. Worked various attempts to get through. Confer with town group. Will standback liner and try bullnose guide shoe (crayola tip now) with turbo centrilizer above. 08:00 - 10:30 2.50 CASE N DPRB COMP TOH 10:30 - 12:15 1.75 CASE N DPRB COMP Stand back liner. float shoe has 2 gouges on sides at 4 & 8 oclock (Iowside). No marks on nose. 12:15 -13:15 1.00 CASE N DPRB COMP Crew change out for SLB. PJSM and transfering fluids from uprights to rig tanks. 13:15 - 14:30 1.25 CASE N DPRB COMP Cut 100' of coil. M/U MHA pull test to 25K, PT 3500. ( ( Printed: 11/19/2001 10:21:12 AM BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: M-13 Common Well Name: M-13Ai Spud Date: 12/2/1980 Event Name: REENTER+COMPLETE Start: 11/6/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/13/2001 14:30 - 15:45 1.25 CASE N DPRB COMP Pick up 2-7/8" x 3-1/2" liner. 15:45 - 16:10 0.42 CASE N DPRB COMP Pick up injector and m/u. 16:10 - 17:45 1.58 CASE N DPRB COMP TIH w/liner made it throught the window okay RIH liner stopped at 10425'. 17:45 - 19:45 2.00 CASE N DPRB COMP Try working beyond 10425'. Just appears solid. Does not appear to be fill. 19:45 - 21 :30 1.75 CASE N DPRB COMP TOH to make cleanout run with 1.06 motor and MWD. Received 24 hr extension from AOGCC rep Jeff Jones for weekly BOP test. 21 :30 - 22:00 0.50 CASE N DPRB COMP Strip-off and stand back injector. 22:00 - 23:00 1.00 CASE N DPRB COMP Standback liner 23:00 - 00:00 1.00 CASE N DPRB COMP PU BHA 10. 11/14/2001 00:00 - 04:05 4.08 CASE N DPRB COMP RIH orientate 65L set down once at whipstock RIH to 10425 wash thru continue to RIH to 10460. 2.5 bpm free spin 3100 psi. 04:05 - 12:30 8.42 CASE N DPRB COMP Wash to 10,553'. Backream to 10,408'. Set down 10425 pop thru. RIH stack out at 10,487'. Back ream to 10,000'. Pumping 5 bbls high-vis pills at 50 bbl intervals. Wash and ream to bottom 2.4 in /1.7 out. Backream out, orient to lowside in 10425' area. RIH at min. rate, hole in fair condition went through 10425' okay and on to bottom. Making 1 more wiper to 9700'. RIH min rate. Hole okay. 12:30 - 15:05 2.58 CASE N COMP TOH 15:05 - 16:00 0.92 CASE N COMP UD BHA #9 16:00 - 17:25 1.42 CASE N COMP RIH with liner from derrick. (removed turbo above guide shoe) 17:25 - 17:55 0.50 CASE N COMP P/U and stab-on injector. 17:55 - 20:00 2.08 CASE N COMP RIH wlliner set down at 10,226 10,414 10,571 10,67410,792 10,800 10,832 10,862 10,846 10,883. 20:00 - 20:30 0.50 CASE P COMP Drop 5/8" ball and circulate down to setting tool. Set liner hanger with 3200 psi. 20:30 - 22:30 2.00 CASE P COMP Wait on cementers. 22:30 - 23:40 1.17 CASE P COMP RU cementers. 23:40 - 23:50 0.17 CASE P COMP PT cementing lines 23:50 - 00:00 0.17 CASE P COMP Pump 16.4 bbl cement. 11/15/2001 00:00 - 00:52 0.87 CASE P COMP Pump cement. PU dart 51.4 bbl versus 53.3bbls bump liner wiper plug with 1000 psi. Launch liner wiper plug bump plug with 1800 psi total of 61.2 bbls displacement. Floats held. 00:52 - 02:20 1.47 CASE P COMP POH LD liner running tools. 02:20 - 03: 15 0.92 CASE P COMP Flush BOP stack. Freeze protect coil. 03:15 - 04:15 1.00 CASE P COMP Set TWC and grease valves. 04:15 -14:00 9.75 CASE P COMP Test BOP equipment. Bind/shear rams not holding. Teardown and inspect. Replace 1 seal. Continue testing. (rebuild Nabors pump fluid end) Witnessing test waived by Chuck Shieve AOGCC. 14:00 - 14:30 0.50 CASE P COMP Pull 2 way check. Well on vacuum. 14:30 - 15:30 1.00 CASE P COMP Fill casing with KCL took 20 bbls to catch. Unable to keep full. Injectivity 2.5 bpm 550 psi. 15:30 -16:10 0.67 CASE P COMP RIU and displace coil to KCL. 16:10 -16:45 0.58 CASE P COMP M/U KB packer assembly. Stab-on injector. 16:45 - 19:30 2.75 CASE P COMP RIH with Baker liner top Packer. 19:30 - 21 :30 2.00 CASE P COMP Locate in to tieback sleeve. PU and circulate ball to seat. Stab back into liner tie-back recipitical. Set packer and test backside to 2500 psi. Release from packer and test casing and lap to (' ( Printed: 11/19/2001 10:21:12 AM BP EXPLORATION Page 7 of7 Operations Summary Report Legal Well Name: M-13 Common Well Name: M-13Ai Spud Date: 12/2/1980 Event Name: REENTER+COMPLETE Start: 11/6/2001 End: 11/17/2001 Contractor Name: NABORS Rig Release: 11/17/2001 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 11/15/2001 19:30 - 21 :30 2.00 CASE P COMP 3000 psi for 30 minutes. OK. 21 :30 - 23:00 1.50 CASE P COMP POH 23:00 - 23:30 0.50 CASE P COMP LD BHA 23:30 - 00:00 0.50 CASE P COMP MU 56 joints of 1-25 CSHD with nozzle. 11/16/2001 00:00 - 02:00 2.00 CASE P COMP Picking up 1.25 CSHD 02:00 - 02:20 0.33 CASE P COMP PU injector and strip down on to well 02:20 - 04:30 2.17 CASE P COMP RIH to 10728 sit down pull6k over. Landing collar at 10859' Bleach was already in coil. 04:30 - 06:20 1.83 CASE P COMP POH lay in 15 bbls of 2%KCL with 6ppb bleach. 06:20 - 06:45 0.42 CASE P COMP Setback injector. 06:45 - 08:00 1.25 CASE P COMP PJSM standing back 1 1/4" CSH. 08:00 - 09:50 1.83 CASE N DPRB COMP M/U Baker motor and mill and CSH 09:50 - 10:15 0.42 CASE N DPRB COMP Pick up stab on injector. 10:15 - 13:00 2.75 CASE N DPRB COMP RIH tag at 10730' small amount of motor work to PBTD 10860'. 13:00 - 16:00 3.00 CASE N DPRB COMP Wash back to TOL. RIH and dry tag 10860'. Lay-in 2% KCL w/ 6ppb bleach to TOL. 16:00 - 17:20 1.33 CASE N DPRB COMP TOH 17:20 - 18:00 0.67 CASE P COMP Setback injector. 18:00 - 18:30 0.50 CASE P COMP PJSM for standing back work string. 18:30 - 19:50 1.33 CASE P COMP Stand back 1-1/4" CS Hydril tubing. 19:50 - 21 :35 1.75 CASE P COMP PJSM and pu 60' of perforating guns and Hydril work string. 21 :35 - 22:05 0.50 CASE P COMP PU injector,Stab onto well, strip down 22:05 - 23:40 1.58 CASE P COMP RIH tag TD correct depth and Drop ball 23:40 - 23:45 0.08 CASE P COMP PU to shooting depth 23:45 - 00:00 0.25 CASE P COMP Circulate ball to firing head. 11/17/2001 00:00 - 00:30 0.50 PERF P COMP Pressure to 4000 psi to fire guns. 00:30 - 02:30 2.00 PERF P COMP POH with coil. Set off injectorhead. 02:30 - 04:00 1.50 PERF P COMP LD 1-1/4" CS Hydril tubing. 04:00 - 04:30 0.50 PERF P COMP PJSM for laying down perf guns. 04:30 - 05: 15 0.75 PERF P COMP LD perf guns. All fired. Ball recovered in firing head. PERF intervals: 10645'-10675' md' & 10705'-10735' md 6 shots/ft everyother "Big Hole" shot 05:15 - 07:30 2.25 DEMOB P COMP P/U nozle and RIH to 2200'. Injectivity test 1.2 bpm @ 3000 psi. Freeze protect with 33 bbls SO/50 methonal from 2200' to surface. 07:30 - 07:45 0.25 DEMOB P COMP Install valve to MHA setack injector. 07:45 - 08: 1 0 0.42 DEMOB P COMP Install BPV. 08:10 - 12:30 4.33 DEMOB P COMP RID DS unit #4. N/D BOPE. Install wellhead cap and test to 4000 psi. Rig Released at 1230 hrs 11-17-2001 RID Nabors 3S Move to U-15A Last report..... ( ( Printed: 11/19/2001 10:21:12AM Well: Field: API: Permit: ( ( M-13A Prudhoe Bay Unit 50-029.20522-01 201-165 Rig Accept: 11/06/01 Rig Spud: 11/07/01 Rig Release: 11/17/01 Drilling Rig: Nabors 3S ~-~---~-,---_._---~-_._------------~.._.-._,------_._~--------_.__._------------~.^-,--_._._--,---_.__.,_._-------------",--..,--- POST CTD RIG WORK - Acid Stimulation 12/13/01 Ran 2.25" swage with sample bailer to 9300' slm. Did not set down. 12/17/01 Run in hole with Temp / CCl / Pressure / GR, taking returns to tiger tank to ensure no fluid movement across perfs. log static temp / pressure down from 9100' ctm to TO. Pull up hole 10', circulate 265 bbls 135 DEGF non-slick 2% KCL. Pull up hole above perfs. Conduct step-rate test per program. Pull out of hole and freeze protect. Consult with town engineer for Acid Stimulation. Run in hole with 2" JSN. 12/18/01 Unable to get below 10490'. Pull out of hole. Change out BHA for 1.75". Run in hole without problems. Pump 25 bbls NH4Cl, 100 bbls 7.5% HCl, 40 bbls 9:1 mud acid, 150 bbls 3% NH4CL. Good reaction with acid on the perfs. Over displace acid into perfs with 3% NH4CL. Injectivity at end of NH4Cl stage = 1.7 bpm, 780 psi whp. left well shut-in and freeze protected to 4000'. í ~t 05-Dec-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well M-13A ¿j,oJ-II1:5 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 9,300.00' MD Window / Kickoff Survey 9,345.00' MD (if applicable) Projected Survey: 10,895.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) RECEIVED OEC 'j 1 2001 Alaska Oil & Gas Con~ C^mm' , >JJ" \" ESSlCm Anc~oíage .- DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA M Pad, Slot M-13 M-13A Job No. AKMW11188, Surveyed: 12 November, 2001 ~ SURVEY REPORT 5 December, 2001 Your Ref: API 500292052201 Surface Coordinates: 5974419_00 N, 628211.00 E (700 20' 18.0509" N, 148057' 34. 7375" W) Kelly Bushing: 55. 70ft above Mean Sea Level .--- 5pa""""'y-5UI! DRIL.L.ING seRVices A Halliburton Company Survey Ref: 5vy11032 Sperry-Sun Drilling Services . Survey Report for M-13A Your Ref: API 500292052201 Job No. AKMW11188, Surveyed: .12 November, 2001 Alaska Drilling & Wells North Slope Alaska PBU_WOA M Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 9300.00 26.550 311.110 8530.53 8586.23 1145.30 N 2586.04 W 5975519.91 N 625605.75 E -301.16 Tie On Point .-. MWD Magnetic "-... . 9345.00 26.200 311.420 8570.85 8626.55 1158.48 N 2601.07 W 5975532.84 N 625590.50 E 0.836 -297.26 Window Point 9375.66 32.430 306.600 8597.57 8653.27 1167.87 N 2612.76 W 5975542.03 N 625578.66 E 21.714 -294.97 9399.76 37.380 305.100 8617.33 8673.03 1175.94 N 2623.94 W 5975549.90 N 625567.34 E 20.845 -293.58 9425.71 44.010 303.600 8637.00 8692.70 1185.47 N 2637.91 W 5975559.19 N 625553.21 E 25.824 -292.31 9447.83 48.160 302.200 8652.34 8708.04 1194.11 N 2651.28 W 5975567.61 N 625539.69 E 19.306 -291.51 9494.12 57.130 299.430 8680.40 8736.10 1212.89 N 2682.88 W 5975585.84 N 625507.78 E 19.950 -291.04 9530.29 63.980 299.910 8698.17 8753.87 1228.48 N 2710.22 W 5975600.96 N 625480.17 E 18.973 -291.22 9550.22 67.350 301.500 8706.38 8762.08 1237.75 N 2725.83 W 5975609.97 N 625464.40 E 18.405 -290.99 9569.57 70.460 304.370 8713.34 8769.04 1247.57 N 2740.98 W 5975619.52 N 625449.09 E 21.207 -290.06 9588.07 72.850 308.450 8719.17 8774.87 1257.99 N 2755.10W 5975629.70 N 625434.79 E 24.597 -288.10 9618.62 75.890 310.600 8727.40 8783.10 1276.72 N 2777.79 W 5975648.03 N 625411.79 E 12.039 -283.23 9639.25 79.530 309.960 8731.79 8787.49 1289.75 N 2793.17 W 5975660.80 N 625396.19 E 17.903 -279.63 9656.59 83.100 311.400 8734.41 8790.11 1300.92 N 2806.16 W 5975671.75 N 625383.00 E 22.164 -276.45 9685.54 86.920 314.850 8736.93 8792.63 1320.63 N 2827.20 W 5975691.09 N 625361.63 E 17.748 -269.90 9707.54 90.960 319.440 8737.33 8793.03 1336.75 N 2842.16 W 5975706.95 N 625346.40 E 27.788 -263.42 9752.94 100.220 333.060 8732.90 8788.60 1374.16 N 2867.21 W 5975743.93 N 625320.72 E 36.131 -243.55 .-.... 9803.69 100.480 354.040 8723.68 8779.38 1421.75 N 2881.26 W 5975791.28 N 625305.85 E 40.663 -209.36 '--- 9835.71 99.670 0.910 8718.07 8773.77 1453.23 N 2882.65 W 5975822.73 N 625303.92 E 21.275 -182.79 9860.62 96.770 4.770 8714.51 8770.21 1477.85 N 2881.43 W 5975847.36 N 625304.73 E 19.253 -160.86 9895.96 96.330 3.190 8710.48 8766.18 1512.87 N 2878.99 W 5975882.42 N 625306.56 E 4.613 -129.31 9919.59 98.700 8.110 8707.38 8763.08 1536.17 N 2876.69 W 5975905.76 N 625308.4 7 E 22.948 -107.98 9971.92 99.670 19.890 8699.00 8754.70 1586.21 N 2864.22 W 5975956.00 N 625320.08 E 22.298 -58.41 10013.57 103.090 25.870 8690.78 8746.48 1623.81 N 2848.37 W 5975993.87 N 625335.29 E 16.293 -17.92 10057.32 104.500 37.640 8680.31 8736.01 1659.87 N 2826.06 W 5976030.31 N 625356.97 E 26.321 24.46 10089.62 103.620 43.620 8672.46 8728.16 1683.63 N 2805.67 W 5976054.42 N 625376.96 E 18.164 55.24 10101.94 103.270 46.610 8669.59 8725.29 1692.09 N 2797.18 W 5976063.01 N 625385.30 E 23.774 66.80 10159.54 97.680 58.920 8659.09 8714.79 1726.23 N 2752.16 W 5976097.92 N 625429.73 E 23.138 118.88 10202.29 91 .760 68.410 8655.56 8711.26 1745.09 N 2714.03 W 5976117.43 N 625467.53 E 26.091 154.28 1024G.81 89.070 70.800 8655.25 8710.95 1760.25 N 2673.25 W 5976133.29 N 625508.05 E 8.268 187.80 5 December, 2001 - 10:58 Page 20f4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for M-13A Your Ref: API 500292052201 Job No. AKMW11188, Surveyed: 12 November, 2001 Alaska Drilling & Wells North Slope Alaska PBU_WOA M Pad Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10276.66 90.220 74.850 8655.44 8711.14 1769.36 N 2643.78 W 5976142.90 N 625537.35 E 13.647 210.42 .-., 10311.38 88.370 79.960 8655.87 8711.57 1776.93 N 2609.91 W 5976151.04 N 625571.09 E 15.651 233.91 10350.61 90.930 83.490 8656.10 8711.80 1782.57 N 2571.10 W 5976157.35 N 625609.80 E 11.115 258.20 10394.61 92.510 91.770 8654.78 8710.48 1784.39 N 2527.20 W 5976159.92 N 625653.66 E 19.149 281.73 10434.46 90.930 97.230 8653.58 8709.28 1781.27 N 2487.50 W 5976157.47 N 625693.40 E 14.257 298.87 10469.04 88.550 101.640 8653.74 8709.44 1775.60 N 2453.40 W 5976152.39 N 625727.60 E 14.491 311.01 10512.83 88.550 106.920 8654.85 8710.55 1764.81 N 2410.99 W 5976142.32 N 625770.18 E 12.054 322.87 10537.74 89.780 108.860 8655.21 8710.91 1757.16 N 2387.29 W 5976135.08 N 625794.01 E 9.221 328.10 10582.93 90.750 116.260 8655.00 8710.70 1739.83 N 2345.59 W 5976118.47 N 625836.01 E 16.515 333.94 10606.33 90.750 119.960 8654.70 8710.40 1728.81 N 2324.96 W 5976107.80 N 625856.83 E 15.811 334.71 10647.24 88.280 118.200 8655.04 8710.74 1708.93 N 2289.21 W 5976088.54 N 625892.91 E 7.413 335.37 10685.76 84.850 114.320 8657.35 8713.05 1691.92 N 2254.74 W 5976072.12 N 625927.66 E 13.430 337.88 10716.49 83.610 112.030 8660.44 8716.14 1679.89 N 2226.63 W 5976060.57 N 625955.97 E 8.441 341.51 10751.46 81.530 106.140 8664.97 8720.67 1668.55 N 2193.88 W 5976049.80 N 625988.91 E 17.728 348.07 10796.71 76.390 104.810 8673.63 8729.33 'l656.70 N 2151.10W 5976038.68 N 626031.89 E 11.719 359.20 10824.83 73.040 105.510 8681.04 8736.74 1649.61 N 2124.92 W 5976032.04 N 626058.19 E 12.153 366.14 10859.33 69.470 107.700 8692.13 8747.83 1640.28 N 2093.62 W 5976023.24 N 626089.64 E 11.966 373.72 10895.00 69.470 107.700 8704.64 8760.34 1630.13 N 2061.79 W 5976013.63 N 626121.64 E 0.000 380.83 Projected Survey ~ --- All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.386° (07 -Nov-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 30.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 1089S.00ft., The Bottom Hole Displacement is 2628.36ft., in the Direction of 308.331° (True). 5 December, 2001 - 10:58 Page 3 of 4 DrlllQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for M-13A Your Ref: API 500292052201 Job No. AKMW11188, Surveyed: 12 November, 2001 . North Slope Alaska Alaska Drilling & Wells PBU_WOA M Pad Comments ---~ Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment /~----.... 9300.00 9345.00 10895.00 8586.23 8626.55 8760.34 1145.30 N 1158.48 N 1630.13 N 2586.04 W 2601.07 W 2061.79 W Tie On Point Window Point Projected Survey Survey tool program for M-13A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 9300.00 0.00 9300.00 8586.23 10895.00 8586.23 AK-1 BP _HG - BP High Accuracy Gyro (M-13) 8760.34 MWD Magnetic (M-13A) ..-.... ., -----. 5 December, 2001 - 10:58 Page 4 of4 DrillQuest 2.00.08.005 t ~~~~Œ (ffi~ &\~&\~[K(~ (' AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION .I / ¡ / TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit M-13A BP Exploration (Alaska), Inc. Pennit No: 201-165 Sur Loc: 1937' SNL, 605' WEL, SEC. 01, TllN, RI2E, UM Btmhole Loc. 318' SNL, 2698' WEL, SEC. 01, TllN, R12E, UM Dear Mr. McCarty: Enclosed is the approved application for pennit to drill the above referenced well. The pennit to drill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit M-13A. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integyity (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 perfonned before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. rx~y¥ \~~. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this 220d day of August, 2001 . jjclEnclosures cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ~b .,' r" ( STATE OF ALASKA ~, ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Open: 9553' - 9590" 9735' - 9750', 9760' - 9786' Sqzd: 9458' - 9543', 9590' - 9735', 9758' - 9760', 9786' - 9788' true vertical Open: 8814' - 8848', 8979' - 8993', 9002' - 9026' Sqzd: 8728' - 8805', 8848' - 8979', 9000' - 9002', 9026' - 9028' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the ~Oing is true and correct to the best of my knOWledge. Signed Thomas McCarty",. ",i"'7 C( ~--r Title CT Dnlllng Engineer . '. : '. ' . . ,:;:::Ç~:~"i:§~!lp.~:.Y$e~Ø~;I.y:!::::::':.:';!;.: :,:::: Permit Number API Number .20/- 50- 029-20522-01 Conditions of Approval: Samples Required 0 Yes No Hydrogen Sulfide Measures 0 Yes gNo Required Working Pressure for BOPE tJ 2K 0 3K Other: ~ \\ OR/GINA Rev. 12-0 -8 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1931' SNL, 605' WEL, SEC. 01, T11 N, R12E, UM At top of productive interval 741' SNL, 3242' WEL, SEC. 01, T11 N, R12E, UM At total depth 318' SNL, 2698' WEL, SEC. 01, T11 N, R12E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028257,318' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 9345' MD Maximum Hole Angle 18. Casin~ Program Specifications Grade L-80 1 b. Type of well 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 10149 feet 9358 feet 9588 feet 8846 feet Length Size 110' 20" x 30" 2698' 13-3/8" 9212' 9-5/8" 1430' 7" Perforation depth: measured 20. Attachments 0 Exploratory 0 Stratigraphic Test 0 Development Oil Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 55.70' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028260 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number M-13A 9. Approximate spud date 09/15/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10767' MD / 8701' TVDss 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 105 Maximum surface 2237 psig, At total depth (TVD) 8800' I 3300 psig Setting Depth 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Plugs (measured) A/ask, ¡ / aO/flle <001 Tagged fill at 9588' (08/99) II Gas Co/] "/]ell s. C Oran Ofl1fh' ~e "1/88'- Fish: See Diagram, at 9951' (07/90) 'Io/] Junk (measured) Cemented MD TVD 8 cu yds Concrete 110' 110' 3255 cu ft Arcticset II 2698' 2698' 1280 cu ft Class 'G', 130 cu ft AS I 9212' 8507' 374 cu ft Class 'G' 8710' - 10140' 8060' - 9349' Commissioner Date ~ ( BPX M-13Ai Sidetrack Summary of Operations: A CTD sidetrack of well M-13Ai will be drilled. Specific prep work, (Phase 1), Addition of a string of 4-1/2" tubing (Phase 2), and drilling, (Phase 3) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Drift/caliper liner and set whipstock. Squeeze the perforations below the whipstock. Planned for August 15, 2001 . Drift tubing and liner, and run a caliper across the liner at the proposed whipstock setting depth. . Liquid pack and Integrity test IA. . Set through tubing whipstock using coil at approx. 9,345' MD (8,571' TVDss). . Squeeze the perforations 9553' -9590' with approximately 14 barrels of cement. Phase 2: Install string of 4-112" tubing with workover rig. Mill window if service coil is available. Planned for September 10, 2001 . A string of 4-1/2" injection tubing will be installed by a workover rig. . Mill window with service coil if available. Phase 3: Drill and Complete CTD sidetrack: Planned for September 15, 2001 2-3/8" coil will be used to drill a ,..,2000 foot, 3-%" open hole sidetrack, (as per attached plan) and run a solid, cemented & perforated 3-3/16" x 2-7/8" liner completion. Mud Program: . Phase 1: Seawater . Phase 2: Seawater . Phase 3: Flo-Pro (8.6 - 8.7 ppg) Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . A combination 3-3/16" x 2-7/8", L-80, solid liner will be run from approximately 9, 150'md (8396' TVDss) to TD at approx 11 ,365'md. Liner will be cemented in place with approximately 20 bbls (annular volume plus 25% excess in OH) of 15.8ppg class G cement. Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2200 psi. Directional . See attached directional plan . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray log will be run over the open hole section. . A memory CNL will be run inside the liner. Hazards (' ( The H2S concentration for M-13 has not been recently recorded. However, the maximum concentration of H2S on "M" pad is 120 ppm at M-04. The well-path will cross 2 mapped faults, both having about 30' of throw. The risk of lost circulation from the first fault is considered to be moderate, while the risk from the second fault is considered low. Both faults will be crossed by the proposed wellbore perpendicular to their orientation. Reservoir Pressure Res. pressure is estimated to be 3300 psi at 8800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2237 psi. (' F~ ~TES . TREE = 6" WCEVOY WB.LHEAD= WCEVOY ÄCïï.:iA:to~- - . '---Otis KB. 8.-ËV-;----55~4' BF: ELEV;; .. . 2Ef43' KOP= 3150' Mâx'Ängië'= 32°@7900' oätû-m 1.0-;-"'---- "'.-"-9599' Datum'ìv~s;---- 8800 M-13i PROPOSED RWO I P&A I 2200' 1-1A"oposed 4-1/2" SSSV LANDING NIP, 0=3.813' I 113-318" CSG, 72#, NBO, 10=12.347 I Minimum 10 = 3.813" @ 2200' & 9100' (4-1/2" Nipple's) 19-5/8" x 7" Liner Hanger w / Tieback SL V I 17" Tubing, 26#, L80, .0383 bpf, 10=6.276 I I A"oposed 4-1/2" lBG, 12.6#, L80 N\! AM 1-1 9200' I 19-5/8" CSG, 47#, NBO BTRS, 10=8.681" I 9212' I A"oposed Mechanical Whipstock I I Tagged Fill on 8/20/1999 I PERFORATION SUMMARY BHCS (12/18/80) REF LOG: DLL-GR (CBL 12/22/80) ANGLE A TTOP PERF: ~ 9458' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DJ\ TE 2-7/8 4 9458-9543 S 6/28/1990 2-7/8 4 9553-9590 0 7/13/1990 3-3/8 4 9590-9617 S 6/28/1990 3-3/8 4 9644-9648 S 6/28/1990 2-7/8 4 9666-9670 S 6/28/1990 2-7/8 4 9679-9692 S 6/28/1990 2- 7/8 4 9702-9735 S 6/28/1990 3-3/8 4 9735-9750 C 6/25/1994 3-3/8 4 9758-9760 S 6/28/1990 3-3/8 4 9760-9780 C 6/25/1994 3-3/8 4 9784-9788 S 6/28/1990 7" lBG, 29#, NBO, .0371 bpf, Ð=6.184 -17" OTIS 'R' LANDING NIP, 1D=5.962 I -f 7" BOT SEAL ASSY w /0 SEALS I -17" x 4-1/2" 011S 'wrY A<R. 10=4" I -14-1/2" OTIS 'X' NIP, 10=3.813 I -14-1/2" OTIS 'XN NIP, 10=3.725 I -14-1/2" XXN A..UG, SET 6/25/94 I FISH - Sch. 3-3/8" perf gun was stuck in WD A<Ron 7/13/90. Gun has since been driven to bottom -1 FISH - 6' Arrerada Terrp Gauge I -1 FISH - 7" EZ DRILL I DJ\ TE REV BY COM\£NTS ? ORIGINAL COrvA..EOON 02/22/90 DFF RNO 01/24/01 SI5-SL T CON\!ffiTED TO CAN\! AS 06/20/01 pcr proposed RNO / P&A draw ing (plus corrections) ffiUDHOE BAY UNIT W8.L: M-13i ÆRMIT No: 180-1240 API No: 50-029-20522-00 Sec. 1, T11 N, R12E BP Exploration (Alaska) :TREE = 6" r./CEVOY WRU-EAO= r./CEVOY ACTUA TOR= ----'--btis ------- .--.-.--- KB. REV = 55.74' BF~ 'ËlEV = 26.43' KOP-;--- ------. ""3150' MaXArÏQlë";- - -32õ @-7900' Datum M) = -- 9599' DatuïTilVDss= -------SSOO' M-13Ai PROPOSED CTD SIDETRACK ~ÆN NOTæ I 2200' I-iProposed 4-1/2" SSSV LANDING NIP, 10=3.813' I 113-3/8" CSG. 72#, NaO, 10=12.347 I Minimum 10 = 3.813" @ 2200' & 9100' (4-1/2" Nipple's) PERFORATIONS P&A'd w/ CEMENT 8572' -19-5/8" x 7" BKR SAB A<R w /K-Anchor, 10=6' -17" OTIS 'R' LANDING NIP, 10=5.962 I 19-5/8" x 7" Liner Hanger w / Tieback SL V I 17" Tubing, 26#, L80, .0383 bpf, 10=6.276 I -17" BOT SEAL ASSY w /0 SEALS I Proposed4-1/2"lBG,12.6#, L80 NVAM 1-1 9200' I 19-5/8" CSG, 47#, NaO BTRS, 10--8.681" I 9212' Mech Whipstock ¡Tagged RII on 8/20/1999~588' ÆRFORATION SUM\1ARY BHCS (12/18/80) RS= LOG: DLL-GR (æL 12/22/80) ANGLEATTOPÆRF: 1250 @ 9458' I Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-7/8 4 9458-9543 S 6/28/1990 2-7/8 4 9553-9590 0 7/13/1990 3-3/8 4 9590-9617 S 6/28/1990 3-3/8 4 9644-9648 S 6/28/1990 2-7/8 4 9666-9670 S 6/28/1990 2-7/8 4 9679-9692 S 6/28/1990 2-718 4 9702-9735 S 6/28/1990 3-318 4 9735-9750 C 6/25/1994 3-3/8 4 9758-9760 S 6/28/1990 3-3/8 4 9760-9780 C 6/25/1994 3-3/8 4 9784-9788 S 6/28/1990 17" lBG, 29#, NBO, .0371 bpf, 10=6.184 I FISH - Sch. 3-3/8" perf gun was stuck in WD A<Ron 7/13/90. Gun has since been driven to bottom. -i FISH - 6' Amerada TerT"p Gauge I -i FISH - 7" EZ DRILL I DATE REV BY COMrvENTS ? ORIGINAL COMPlETION 02122/90 DFF RV'VO 01/24/01 SIS-SL T CONVERTED TO CANVAS 06/21/01 pcr Proposed M-13Ai Sidetrack PRUDHOE BA Y UNIT WRL: M-13Ai Proposed ST PERMIT No: 180-1240 API No: 50-029-20522-01 Sec. 1, T11N, R12E BP Exploration (Alaska) ( ( ObP BP Amoco Baker Hughes INTEQ Planning Report Míi. BAKDt HUGHES --.----.....-..-.-.,..--.--.--- INTEQ -----------'------'---'--"----- -------'--------'----'---J Date: 4/10/2001 Time: 15:05:30 Page: 1 Co..ordinate(NE) Reference: Well: M-13, True North Vertical (fVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N.0.00E,30.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle - ~ ~- --,--,--,--------~.._,-. ._-- '._-'-----'------'~- -..- - ..---.' - -~- . - .-. ~ ,,-.-..._-- - '-------'---------'''-'----, Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB M Pad M-13 Plan#8 M-13A --------------",_.,--~---, ---.."--,-- - --_'--0"_-"_--- - Prudhoe Bay North Slope I UNITED STATES J Map System:US State Plane Coordinate System 1927 I Geo Datum: NAD27 (Clarke 1866) I SysEatum: Mea~~~__~-~_v~~-----_u_--_.._----- - ! Field: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2000 I i - -- .---.--- ----.--.----.--J "---.-----. -----.-..--..---.-------- ---.--.-.-.-.-'-'----'-----'.----.---,----'-----"'--"---. ê;,;~:~:~A~~~~;:~:;~~~~~~:;~ .;-~§~1;:::~1~~. -~~.~~~~~~:eg.. ...~ .- ...~._~~J [Well: M-13 SlotName:---~------- ] M-13 Well Position: +N/-S 3139.65 ft Northing: 5974419.00 ft Latitude 70 20 18051 N Position un<ert~W ~o~:~ ~as6ng ~_~~~2~~ Lo~gItU~e: 148 57 34~~___- ----------------------.------"---------'----'----'--'---'-'----------'------ Wellpath: Plan#8 M-13A Drilled From: M-13 500292052201 Tie-on Depth: 9345.00 ft Current Datum: 23: 13 12/2/198000:00 Height 55.70 ft Above System Datum: Mean Sea Level Magnetic Data: 3/12/2001 Declination: 26.59 deg Field Strength: 57464 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~---------~-_._----_..__......._.._-_._------_.__.__..---~--"~'--'-'-"--'---"--'-----"----"------_._"--.-------....--.-..-.-.-.-.-.---.,.....---------.----.------..-- 0.00 0.00 0.00 30.00 -~--~--.-----_._._----_.._._-----.,,----_.._---------,-----.-----------.--,-,.----.---. --.-. --'--'---'----------"--'-----"'-""'-"-'-'---'-'--'---,_..'"--~----- --_.~------------_._-_._._,_._..._,._..__..._""._------ ~~=-!g~~~d~n~~~~:~~~;-==-1~:E~:=~~r:~=~t:==~~ Targets M-13A T7.1 -----~-~-------'--'-'-'------'~M-;p---Map ~~=~-i;tib;d~--=~~--Z=-L~:git~de.~ Description TVD +N/-S +E/-W Northing Easting Dcg Min See DegMin Sec ft ft ft ft ft . 8650.00 1726.48 -2382.48 5976104.36 625799.55 70 20 35.027 N 148 58 44.340 W Name M-13A T7.2@TD 8701.30 1629.43 -2024.03 5976013.45 626159.57 70 20 34.073 N 148 58 33.867 W ------'-----_._--'~_.'-'---------""--------"__'_M__''---------______M__-__Ø_--"--'---'---'-------"----"----..---_ø_---..-.-...-------.-.--.--.-------- Annotation n~;~-=--L ... ,... ~......-=-=~.---=--~..- --- ...-=-=.:2JL--- 9300.00 8530.54 TIP 9345.00 8570.85 KOP 9616.49 8707.02 1 9866.49 8707.02 2 9922.24 8702.16 3 10090.24 8664.79 4 10199.58 8650.69 5 10524.58 8650.69 6 i 1 07~~~~70 1 :~~----_!~----_._---______n____--._----------_.- ----------------- .-.-------u"--------'-------_u.-.---.-------.- --'---"'-.'-"--'-- -.-.-...---- -..----- .-.----..-J Plan Section Information MI) InCl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft degl1000 degl1000 deg/10OO dèg -"------.---- .--------..--.-------------- 9300.00 26.55 311.11 8530.54 1145.24 -2586.31 0.00 0.00 0.00 0.00 I 9345.00 26.20 311.42 8570.85 1158.42 -2601.34 0.84 -0.78 0.69 158.66 9616.49 90.00 311.42 8707.02 1303.15 -2765.38 23.50 23.50 0.00 0.00 9866.49 90.00 10.17 8707.02 1529.03 -2844.07 23.50 0.00 23.50 90.00 I I 9922.24 100.00 18.68 8702.16 1582.71 -2830.29 23.50 17.94 15.26 40.00 L._____-.--.---.--.----.-...-------_o.--...- ____n__.___---.------.- -....-.----.----------------------....---...------------..----------...-. -"'''''-''''U-''---'''-'--''-----'---' "-___0.._.- uJ ( { ObP BP Amoco Baker Hughes INTEQ Planning Report Bíí8 BAlCER HUGItIS ----.--....--...,....,....-.--.,.-..-...... INTEQ í . - . - --.--. -.. ..-.. ......-- --..- --. -- . ..--.. - - - .- -.--. -. ---'.. -. . ] i Company: BP Amoco Date: 4/10/2001 Time: 15:05:30 Page: 2 I Field: Prudhoe Bay Co-ordinate{NE) Reference: Well: M-13, True North Site: PB M Pad Vertical (fVD) Reference: System: Mean Sea Level l..~;~~~~~__~~1~..~-1_~~__.._._. .... --.--------.-.--....---.....-....----.....----- ~;:; ~~U~~;;:!hOd_~___;i~~I~~'~~~~~r~~O.O~~~k~..._9..~~~~_._.__.._. Plan Section Information i MD Incl Azim TVD +N/-S +EI- W l___~___._-~~---~~---~---~--- ft ,10090.24 104.69 58.86 8664.79 1708.10 -2730.26 : 10199.58 90.00 80.18 8650.69 1745.39 -2629.43 10524.58 90.00 112.68 8650.69 1709.46 -2310.79 ~ 10767.22 65.74 112.68 8701.30 1618.67 -2093.56 L__.__.-----.-------...------..--------..--.-- --------u_-. d~~~OOft d~~dOOft d~~fOOft T:'~ Targel___=-=J 23.50 2.79 23.92 79.00 23.50 -13.43 19.50 123.00 I 10.00 0.00 10.00 90.00 i 10.00 -10.00 --~:9~-~-~~?~---------------______n_______..J Survey L~_~ __~i~g_.__-~;~ ss;::- 9300.00 26.55 311.11 8530.54 9325.00 26.36 311.28 8552.92 9345.00 26.20 311.42 8570.85 9350.00 27.38 311.42 8575.31 9375.00 33.25 311.42 8596.89 9400.00 39.13 311.42 8617.05 9425.00 45.00 311.42 8635.61 9446.31 50.01 311.42 8650.00 9450.00 50.88 311.42 8652.35 9475.00 56.75 311.42 8667.10 9500.00 62.63 311.42 8679.71 9525.00 68.50 311.42 8690.05 9550.00 74.38 311.42 8698.01 9563.58 77.57 311.42 8701.30 9575.00 80.25 311.42 8703.50 9600.00 86.13 311.42 8706.46 9616.49 90.00 311.42 8707.02 9625.00 90.00 313.42 8707.02 9650.00 90.00 319.29 8707.02 9675.00 90.00 325.17 8707.02 9700.00 90.00 331.04 8707.02 9725.00 90.00 336.92 8707.02 9750.00 90.00 342.79 8707.02 9775.00 90.00 348.67 8707.02 9800.00 90.00 354.54 8707.02 9825.00 90.00 9850.00 90.00 9866.49 90.00 9875.00 91.53 9900.00 96.02 0.42 8707.02 6.29 8707.02 10.17 8707.02 11.46 8706.91 15.25 8705.26 9922.24 100.00 9925.00 100.12 9950.00 101.18 9975.00 102.12 10000.00 102.93 18.68 8702.16 19.33 8701.68 25.21 8697.05 31.13 8692.00 37.09 8686.57 10025.00 103.61 10050.00 104.14 10075.00 104.53 10090.24 104.69 10100.00 103.43 43.09 8680.83 49.11 8674.83 55.16 8668.63 58.86 8664.79 60.84 8662.42 10125.00 100.15 10150.00 96.79 10175.00 93.38 10199.58 90.00 10200.00 90.00 65.81 8657.31 70.69 8653.63 75.49 8651.41 80.18 8650.69 80.18 8650.69 N/S ft 1145.24 1152.57 1158.42 1159.91 1168.25 EIW ft -2586.31 -2594.69 -2601.34 -2603.03 -2612.49 MapN ft MapE ft DLS deg/100ft 0.00 0.84 0.84 23.50 23.50 .----- VS ft -301.35 -299.19 -297.45 -297.00 -294.51 Tool 5975519.76 625605.70 5975526.95 625597.19 5975532.68 625590.45 5975534.14 625588.73 5975542.32 625579.13 TFO deg 0.00 TIP 158.66 MWD 158.51 KOP 0.00 MWD 360.00 MWD -291.58 360.00 MWD -288.27 0.00 MWD -285.16 360.00 M-13A -284.60 0.00 MWD -280.60 0.00 MWD -276.33 0.00 MWD -271.83 0.00 MWD -267.14 360.00 MWD -264.53 0.00 M-13A -262.31 360.00 MWD -257.40 360.00 MWD -254.13 0.00 1 -252.30 90.00 MWD -245.26 90.00 MWD -235.81 90.00 MWD -224.03 -210.07 -194.05 -176.16 -156.57 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 1178.02 -2623.55 5975551.89 625567.90 23.50 1189.09 -2636.11 5975562.75 625555.16 23.50 1199.48 -2647.89 5975572.94 625543.21 23.50 1201.37 -2650.02 5975574.78 625541.04 23.50 1214.71 -2665.14 5975587.87 625525.70 23.50 1228.98 -2681.32 5975601.86 625509.28 23.50 1244.03 -2698.38 5975616.61 625491.97 23.50 1259.70 -2716.14 5975631.98 625473.94 23.50 1268.42 -2726.02 5975640.53 625463.91 23.50 1275.83 -2734.42 5975647.79 625455.38 23.50 1292.25 -2753.03 5975663.88 625436.50 23.50 1303.15 -2765.38 5975674.57 625423.97 23.50 1308.89 -2771.66 5975680.21 625417.59 23.50 1326.97 -2788.91 5975697.99 625400.04 23.50 1346.73 -2804.21 5975717.48 625384.40 23.50 1367.94 -2817.42 5975738.46 625370.84 23.50 1390.40 -2828.38 5975760.73 625359.49 23.50 1413.86 -2836.98 5975784.04 625350.49 23.50 1438.08 -2843.14 5975808.14 625343.92 23.50 1462.80 -2846.79 5975832.80 625339.85 23.50 1487.77 -2847.89 5975857.74 625338.32 23.50 1512.71 -2846.42 5975882.70 625339.36 23.50 1529.03 -2844.07 5975899.06 625341.43 23.50 1537.39 -2842.47 5975907.44 625342.89 23.50 1561.65 -2836.72 5975931.79 625348.23 23.50 1582.71 -2830.29 5975952.96 625354.29 23.51 1585.28 -2829.41 5975955.54 625355.13 23.50 1608.01 -2820.10 5975978.43 625364.05 23.50 1629.58 -2808.55 5976000.19 625375.23 23.50 1649.78 -2794.87 5976020.62 625388.55 23.50 1668.39 -2779.21 5976039.49 625403.89 23.50 1685.21 -2761.74 5976056.61 625421.08 23.50 1700.07 -2742.62 5976071.79 625439.93 23.50 1708.10 -2730.26 5976080.03 625452.16 23.50 1712.85 -2722.07 5976084.93 625460.26 23.50 1723.83 -2700.21 5976096.27 625481.93 23.50 1732.98 -2677.25 5976105.82 625504.72 23.50 1740.22 -2653.44 5976113.46 625528.41 23.50 1745.39 -2629.43 5976119.04 625552.33 23.50 1745.46 -2629.02 5976119.12 625552.74 0.00 -135.50 -113.16 -97.86 -89.82 -65.93 90.00 MWD 90.00 MWD 90.00 2 40.00 MWD 40.02 MWD -44.48 -41.81 -17.48 6.98 31.31 40.28 3 79.00 MWD 79.11 MWD 80.20 MWD 81.40 MWD 55.26 82.69 MWD 78.57 84.07 MWD 100.99 85.52 MWD 114.13 86.94 4 122.34 123.00 MWD 142.77 123.48 MWD 162.18 124.50 MWD 180.36 125.22 MWD 196.84 125.70 5 197.11 0.00 MWD .---.--.-----.---------------.----.-.----.-.--.---.--"_.".,-----_._--,----------~-----------------,_..~---_.-,.-..- ! ( ( O.'b , P BP Amoco Baker Hughes INTEQ Planning Report Ilia. BAICD!. HUGHES . ........_.-._.._.._...._..._..._.......~..,._..... lNTEQ -.---..- - - - -. --.-.--.---..- - -~ --. I Date: 4/10/2001 Time: 15:05:30 Page: 3 ¡ Co-ordlnate(NE) Reference: Well: M-13, True North .1 Vertical (fVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.OON.0.00E,30.00Azi) I ......__._._--__~~_rvey Calc~~~n Method: ____~inim~_"-,_~~-~!~~~._------~ Oracle ____I I Company: BP Amoco I Field: Prudhoe Bay ¡ Site: PB M Pad I Well: M-13 L~~!~~h: -~!~~_~=-1_~~_.. ...---,.-.---..--.----...----.--.---__._..0. Survey MD Incl - Azim -SSTVD--~-----EIW ---'-----M;¡;¡,i--M;pE----Dis-------yS------- TFo--T~I--l L~._.- deg ._...______deg____~_._----~-----_!!.._--------~-----~-- deg/10~.__~---------~:~--------J i 10225.00 90.00 82.72 8650.69 1749.17 -2604.29 5976123.25 625577.39 10.17 212.68 90.00 MWD I ! 10250.00 90.00 85.22 8650.69 1751.79 -2579.43 5976126.29 625602.20 10.00 227.38 90.00 MWD . 10275.00 90.00 87.72 8650.69 1753.33 -2554.48 5976128.26 625627.12 10.00 241.19 90.00 MWD 10300.00 90.00 90.22 8650.69 1753.78 -2529.49 5976129.13 625652.10 10.00 254.07 90.00 MWD 10325.00 90.00 92.72 8650.69 1753.14 -2504.50 5976128.92 625677.09 10.00 266.01 90.00 MWD 10350.00 90.00 95.22 8650.69 1751.41 -2479.56 5976127.62 625702.06 10.00 276.98 90.00 MWD 10375.00 90.00 97.72 8650.69 1748.59 -2454.72 5976125.22 625726.94 10.00 286.96 90.00 MWD 10400.00 90.00 100.22 8650.69 1744.69 -2430.03 5976121.75 625751.69 10.00 295.93 90.00 MWD 10425.00 90.00 102.72 8650.69 1739.72 -2405.53 5976117.20 625776.27 10.00 303.87 90.00 MWD 10450.00 90.00 105.22 8650.69 1733.68 -2381.27 5976111.58 625800.63 10.00 310.78 90.00 MWD 10475.00 90.00 107.72 8650.69 1726.59 -2357.30 5976104.90 625824.71 10.00 316.62 90.00 MWD 10500.00 90.00 110.22 8650.69 1718.47 -2333.66 5976097.18 625848.49 10.00 321.41 90.00 MWD 10524.58 90.00 112.68 8650.69 1709.46 -2310.79 5976088.56 625871.51 10.00 325.04 90.00 6 10525.00 90.00 112.68 8650.69 1709.30 -2310.40 5976088.41 625871.90 0.00 325.09 0.00 MWD 10550.00 87.46 112.68 8651.25 1699.66 -2287.34 5976079.17 625895.12 10.17 328.28 180.00 MWD 10575.00 84.96 112.68 8652.91 1690.04 -2264.33 5976069.95 625918.29 10.00 331.46 180.00 MWD 10600.00 82.46 112.68 8655.65 1680.46 -2241.40 5976060.76 625941.37 10.00 334.62 180.00 MWD 10625.00 79.96 112.68 8659.47 1670.94 -2218.61 5976051.63 625964.33 10.00 337.77 180.00 MWD I 10650.00 77.46 112.68 8664.36 1661.49 -2195.99 5976042.56 625987.10 10.00 340.89 180.00 MWD . 10675.00 74.96 112.68 8670.32 1652.12 -2173.59 5976033.59 626009.66 10.00 343.99 180.00 MWD Il10700.00 72.46 112.68 8677.33 1642.87 -2151.45 5976024.72 626031.95 10.00 347.04 180.00 MWD 10725.00 69.96 112.68 8685.39 1633.75 -2129.62 5976015.97 626053.93 10.00 350.06 180.00 MWD _~l;~:~_~ J~:j~ ~ ~ ~:~~--- ~~~~:jt_J~i~:~; _~~6~~)~__- ~~~;]~I1t- ~~~~~~~~;____~It.._.._---~.~~~;----_J ~~:~~ -~~...._-_.- BP Amoco ,8nfttTl':'::: It.,. D.= WWLU'ATH DRTAIU =.::~ 11.13 1348.00 n 112 1Z/2f1... 00r00 V.a8Ctlen Anl'8 Ort"n 081.ln +HI'" +III-W "- Fre", TVD REFERENCE INFORMATION ",,="J@ ~=: Well~~i.;; l::. North Sedi>n~¡ Reference: ~.13 (O.OON,O.OOE) Meas>.nd D.;f.th Refe<enœ: 23: 13 121711980 00:00 55.70 CaIcuIa1i>n MeIhod: MiniTun CUVature SECTION IJoETALS 1'VII ....,.. +EJ.W DLe-8 TFac8 t noo.oo K55 ~t1.tt 8S3G.S4 ttau .UM.3It 0.00 0.00 ! == ::: ~!~~ :!:~: ::~~ :~~: ::: '::: 5 ..22.2.,00.00 ,.... 8702.18 1582.71 .2130.8 2150 _00 i ~~~¡rEg ~~i! !æã g~* ~~~~ ~ :~ä vs.c T.,...t """.35 .287.'" -254.13 -87." ...... 1t4.12 ''''04 325.0. 3-55.03 UH..U. ''''H Till U7...' Iu..OO KO' 1787.82 HiLa 1 8707..2 '''La 2 8702.1' .~ 3 ......71 1008O..2f, .. HIU'101""" I ::~.: ~:;~ ~ 1VD ....s .a-w ~ ~~T7.1 ØiO.oo 1net. -2:3ð2.48 Pod u..13A. TI2QTO 1N1.30 1629.0 -2Q24..O] Pon bp Ba;ß( Hùghes ,~i:£1\' ;mHr~~~iU!"qC<)nt T l LEGEND - M-13 (M-13) - PIaró!8 M-13A - Plan IUI Azimuths to True North I Plan; PIon t8 (M-IM'1arM8 M-13A) Magnetic North: 26.59° Ct8ated By. Bt1 PoIris Dale: 4/1012001 Æ~K0~ (I Magnetic Field Strength: 57464nT DiB~~~~~; Model: BGGM2000 Gcnwr;tlnlornuJtior!. .L~TEQ _1 C ~1 = 0 11)1 - ~14 .c 1::1 0 ~1 'i"' :ë'1 .. :J 012 fn --- --~. ¡----J I il'!1 I I , , I . . . . . . -3150 -3100 -3050 -3000 -2950-2900 -2850 -2800 -2750 -2700-2650 -2600-2550 -2500 -2450 -2400 -2350 -2300 -2250-2200 -2150 -2100 -2050 -2000 -1950 -1900-1850 West(-)/East(+) [50ft/in] -60 -40 -20 0 20 40 60 80 100 120 140 160 Vertical Section at 30.00. [20ft/in] 4/10/2001 3:14 PM ( 0'.... b , p BP Amoco Anticollision Report ~, Raw BA.KÐt HUGHES N..-..~.......~_.~......... .m',' lNTEQ :- Co~~an~-:-----------SPA~~~~--------------'---'----------Date: 4/10/2001 ------. -Ti~~:---15~04-:-28 ---------------;-~~~.;.__. -- --. '--1 I Field: Prudhoe Bay I Reference Site: PB M Pad Co-ordinate(NE) Reference: Well: M-13. True North I Reference Well: M-13 Vertical (fVD) Reference: 23: 13 12/21198000:0055.7 i Reference Wellpath: Plan#8 M-13A ._---_.__~~__~racle .__J .---,--~,..- -,--" '-"-------------,-,---- ---'---'---'-"----"- ..-- .-- ------..---.. -'------'-"'------'-'--'-------"-------"" -- ---""-'--~----'--'----,--- - -._,----'-__._~_n --" -- '---'-- .-- GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There arðŒl9iiiè8'fells in thii~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100,00 ft Error Model: ISCWSA Ellipse Depth Range: 30,20 to 10767,22 ft Scan Method: Trav Cylinder North Maximum Radius: 1273.70 ft Error Surface: Ellipse + Casing ----------------.---- -----.---.----.--,---.-- --- -------- ._.. --- ._'-_...._--- -,--~-------_._-_.._------ --'--.---- --.. --_.- .--.---,-.-----."-.--.-.-..-,---- -. --- --- ~-- ...---- ..-- r---'.-'-"-- -,,-----_. ._--,--_._._._._---_._-----~---_.__._.- ---~-- ---. ----... .~- -.------ - -------"'-'--'--'---.---------.---.- -- -.- -------.---.---- - -- ""--~-_.- ---.-- - -----.- ---. ..------..--- : Survey Program for Definitive Wellpath I Date: 3/12/2001 Validated: No I Planned From To Survey I ft ft r 9~~~:g~--~~~:~f---~,~~~:fp~~~:80:1S gy~~-~~IÙ--- ---. ------~~~-GYRO--------~~~rY:~~~~~~~-gŸr~ -';~~i~h~--------'----- - 1 L_____.---.-.---.---.---.------.- . -----.-------------------.--------------.---.---------.-.------------.-.--.--------- -.--.----- ---_.-----_.- - --I Version: Toolcode Casing Points L:__:~_=:~::_~ Summary 2 Tool Name <~~-Offset Wellpath Site Well > Wellpath Reference MD ft 3775.81 3798.13 3798.13 2187.59 2187.58 2995.06 1070.98 2995.43 2991.91 9399.05 2903.44 3406,54 1702.65 3742.17 3742.17 3742.17 10500.00 10382.59 7072.71 5402.33 5402,67 3700.00 2896.67 2099.29 ----.---------- .-.-..----"------- PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad PB M Pad M-04 M-06A M-06 M-09A M-09 M-10 M-11 M-12 M-12 M-13 M-14 M-15 M-16 M-18A M-18B M-18 M-19A M-19 M-22 M-26A M-26 M-30 M-31 M-32 M-04 V1 M-06A V1 M-06 V1 M-09A V4 M-09 V1 M-10 V1 M-11 V1 M-12 V12 M-12A V2 M-13 V1 M-14 V1 M-15 V1 M-16 V1 M-18A V1 M-18B V1 M-18 V1 M-19A V1 M-19 V1 M-22 V1 M-26A V1 M-26 V1 M-30 V1 M-31 V1 M-32 V1 Offset MD ft 4100.00 3900.00 3900.00 2200,00 2200.00 3000.00 1100.00 3000,00 3000.00 9400.00 2900.00 3400.00 1700.00 3900,00 3900.00 3900.00 9700.00 9800,00 7600.00 5800.00 5800.00 3800.00 2900.00 2100.00 ~~~~~~~.=y - '-"-______n._..._.--..--....----.------.--------.---.-'---. --.-..-J ---."----'--' Ctr-'Ctr No-Go Allowable I Distance Area Deviation Warning I ft. --~-_._._..__.~-_._._._._---_._---_._~-------_._J 468,08 No Reference Casings I 613.04 No Reference Casings I 613.04 No Reference Casings I 452.09 No Reference Casings i 445.52 No Reference Casings I 357.87 No Reference Casings ¡ 232.30 No Reference Casings' 132.19 No Reference Casings 132.06 No Reference Casings 6.33 No Reference Casings 89.24 No Reference Casings 192.81 No Reference Casings 320.29 No Reference Casings 82.07 No Reference Casings 82.09 No Reference Casings 82.09 No Reference Casings 1072.68 No Reference Casings 992.30 No Reference Casings 807.53 No Reference Casings 241.45 No Reference Casings 241.73 No Reference Casings 945.56 No Reference Casings 153.50 No Reference Casings 38.36 No Reference Casings M-13/Plan#8 M-13A r---'I G:: ........... d .8 150 ~ c\S ~ c\S ~ Q) r./'J Q) 100 ~ ~ d Q) U 0 ~ Q) ~ 1:= Q) u 20°"113:¡(M-]8) " / .~,,~ , ¡ ¡ -~ ¡ I I I \1-:1 2A.r(M~19 A}' J .Nt=t9ukM.<=i:~).:/:. I~...:19..' ~.:. .'-;})A} ~......itY...'................'..".'.:: .: --, . . . ; -. ; -'1 I .-., . -.. . -I. . Î I ¡--r 50 ..., -. I I 9800 10000 10200 10400 10600 10800 --~" -I _/...AtIJ(~PI1J Measured Depth [ft] I M-06A (M-06A) M-09 (M-09) M-12 (M-12) M-14 (M-14) M-18A (M-18A) M-19A (M-19A) M-26A (M-26A) M-31 (M-31) M-06 (M-06) M-10 (M-10) M-12 (M-12A) M-15 (M-15) M-18B (M-18B) M-19 (M-19) M-26 (M-26) M-32 (M-32) 9200 9400 9600 M-04 (M-04) M-09A (M-09A) M-11 (M-11) M-13 (M-13) M-16 (M-16) M-18 (M-18) M-22 (M-22) M-30 (M-30) 1 ,( 'I ( 3S CTD BOP Detail -- CT Injector Head u 109 Box (Pack-Off), 10,000 psi Wor1<ing Pressure <f - 7" Riser Methanol Injection Otis 7" WLA Quick Connect - Annular BOP (Hydril),7-1/16" 10 5000 psi working pressure 7-1/~"JPf~Oßm ~ß~ing pressure Manual ov~9fy!traUlic 8 Flanged Fire Resistant Kelly Hose to Dual Choke Manifold I Blind/Shear I 13 1/2" Combi PipelSIi~ Fire resistant Kelly Flange by Hammer u Valve on OS Hardline t manifold 7 -1/~"JPF~Oß&ðt ~ß~ing pressure Manual ovJ1.9fytiraulic I TOT I I 2 7/8" Combi Pipe/Slip I 23/8" Combi Pipe/Slip MOJ 5/16/01 XO Sp004 as necessary 2 flanged gate valves Single Manual Master Valve 7" Annulus 9 5/8" Annulus I I 1.1 , ..,. ,J. " H 19332.7 " . DATE INVOICE I CREDIT MEMO DESCRIPTION 070201 CK070201N PYMT OMMENTS:' HANDL NG INST: GROSS 100.00 Per it to Drill ee S/H - Terrie Hub Ie X4628 or Sondra Ste man X4750 (Vl-/3A- 'HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY To The ORDER O-f ~l DATE 07/06/01 CHECK NO. 00193327 VENDOR DISCOUNT NET 100. 00 No.H 1'93327 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO CONSOLIDATED COMMERCIAL ACCOUNT ONE HUNDRED & OO/10d~***:************~~*~it7~~**¥*********** Ù$ DC)LLAR .... DATE. ': AMOUNT ~?/Q'6/01.. ,<j~G'¡+ ,; ~~ O~fi~;~ ~i1[þ~1k. ..' , """ " , " , , ..'ALASt(Ã OIL éN[)G~S . ,'. tOI\l~ERVfflT I ON~OM~I S8.ION: 333,,'WES~ 7'THPtVENUE '. SUITE1:00 :' . ANCHORA~E AK 99501 56~389 412 III ~ ~ ~ ~ 2 ? III I: 0... ~ 2 0 ~ 8 ., 5 I: 0 0 8 ....... ~ g III 00193327 ~-~'._.. ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRlli~ EXPLORATION INJECTION .WELL ,;-, INJECTION WELL REDRILL V WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last. two (2) digits are between 60-69) PILOT HOLE (PH) ~ ANNUL~OSAL <¥NO ANNULAR DISPOSAL <--> YES ANNULAR DISPOSAL THIS WELL M-\~~ "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <--> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved' subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. ( ~l.{ WEll PERMIT CHECKLIST COMPANY WELL NAME ,/t1- /5A PROGRAM: exp - dev - redrll2S.- serv - wellbore seg _ann. disposal para req - FIELD & POOL r:; '76/ ,,<;'r'1 INIT CLASS GEOL AREA ðl ¿J UNIT# //h..Ç'r'1 ON/OFF SHORE r~/l) ADMINISTRATION 1. Pennitfee attached. . . . . . . . . . . . . . . . . . . . . . . N 2. Lease number appropriate. .. . . . . . . . . . . . . N 3. Unique well name and number. .. . . . . . . . . . . . . . . . N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells. . . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . N- 8. If deviated, is wellbore plat included.. . . . . . . . . . . .'. . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . Y N 11. Pennit can be issued without conservation order. . . . . . . . Y N A R E~9 12. Pennit can.be issued without administrative approval.. . . . . Y N ~ I 13. Can permit be approved before 15-day wait.. . . . . . . . . . Vi N ENGINEERING ~i: ~~~~~~~~~;~:~~~~~~~i~~rt"~g":":":":": ~ ~(~~\~<-'c~~~~~A~o--~~((\\ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y N) 18. CMT will cover all known productive horizons. . . . .'; . . . . ~ N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . èY5 N ~~: ~~e~~~~I~~~~a;~g.r;~:~:;:~~:~d~n~~~t b~e~ ~pp~o~~d: : : Y ~ þCL~~ ~O\-d d-~ . 22. Adequate well bore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . ~þ.. 24. Drilling .fluid program schematic & equip list adequate. . ~ . . N 25. BOPEs. do they meet regulation. . . . . . . ~.............. . . . . . N " -~. '" ..QðT~. E . 26. BOPE pres~ rating app'ropriate; test to ~~~ Dsig. N ~S? ~~~ ~:19-"'3> '")~~" I ~ \ 27. Choke mamfold comphes w/API RP-53 (May 84). . . . . . . . N . 28. Work will occur without operation shutdöwn. . . . . . . . . . . ~ ~ ~ ~ :b) . ~' '8 .' ~ 29. Is presence ofH2S gas probable.. . . . . . . . . . . . . . . . Y 'CU ~ ~"O...;)\: ~c..\'-o) c. \.\~~ o~~\.<t ~~ ' ~,c;...~';,,:)\\,ptJ ~/~~-> GEOLOGY ;~. 6e~itcanbt~SSued~/orhrdrOgenSUlfidemeasures. '.' ... )t~ ~ ~. ". . ala.~ A PR JJNf:, ~~: ~:~SE~*in~~::~~ ii~E:~7 ;7~~ : : : : : : : Y N 0. . ~ 34. Contact name/phone for weekly progress reports [exploratory onl Y N ANNULAR DISPOSAl35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate frèshwater; or cause drilling waste. .. to surface;' .' (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N G~: ENGINEERING:UIC~ COMM~: ~ WM. '9~~/t' / ( APPR DATE Y N Y N Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) c 0 Z 0 -4 ~ ::0 -4' m Z -t :t: en > ::0 m » / --" (, Well History File APPENDIX Infonnation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end. of the file under APPENDIX. No special' effort has been made to chronologically . . organize this category of information. Sperry-Sun Drilling Services LIS Scan Utili~y ;~Revision: ~~ ~~ LisLib $Revision: 4 $ Wed Feb 27 12:04:04 2002 Keel Header Service name.. .... .......LISTPE Date........ -.,. -., -. - - - .02/Ci2/2~ Or i gin. . . . . . . . . . . . . . . . . . . ST S Reel Name............ - . . .LJNKNOkJN Continuation Number.... ..01 Previous Reel Name.. .... . UNKNOWN Comments. . . . . . . . . . . . - . . . . STS LIS Tape Header Service name. ...... ......L1ST2E Date...... -"""""" - - 02!02/27 Origin. . . . . . . . . . . . . . . . . . . STS Tape 'Name. . . - . . . . . . . . . . . . UNKNOWN Continuation Number..... .01 Previous Tape Name.......UNKNOWN Comments..... ............8TS LIS Physical EOF Comment Record TAPE HEADER Prudhoe Bay W01\ MWD!MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: ,JOB NUI"IBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHI P: RANGE: FNL: FSL: FBL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD MWDRUN 1. AK-M'V\T-11188 S. LATZ FEKETI!CUBBO MWD F<:.UN 4 AK-MW-11188 S. LATZ FEKETI!CUBBO MWD RUN 7 AI<:-MW-11188 J. PANTER FEKETI!CUBBO MSL 0) Writing Library. Writing Library. Scientific Technical Services Scientific Technical Services ]V!-13A t:1002920~)2201 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services :27-FEB-02 MWD I:ZUN 2 AK-MW-11188 S. LATZ FEKETI!CUBBO MWD RUN 5 AK-MW-11188 S. LATZ FEKETI!CUBBO MAD RUN 7 1~K-MW-11188 ~T. PANTEH FEKETI!CUBBO 1. llN 1.2E 1937 60S 55.70 ]v!WD RUN 3 AK -]V!'V\T-lll8 8 S. LATZ FEKETI!CUBBO MWD RUN (') AK -]V!W-1l18 8 J. PANTER FEKETI/CUBBO OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) aOJ-/foS l.ST STRING :~ND STRING .3RD STRING ?RODUCTION STRING 8.500 3.750 3.750 9.625 7.000 4.500 9212.0 9350.0 9196.0 REH.:è,.RKS : 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOT ED. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH-SUBSEA (TVDSS) . 3 - Mt'iID RUNS 1 - 6 COMPRISED DIRECTIONAL WITH NATURAL G,~MA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 4. MWD RUN 7 COMPRISED (DGR) UTILIZING GEIGER-MUELLER TUBE WAVE RESISTIVITY- PHASE 4 ( EWR4 ) . DIRECTIONAL; DW'IL Gl'IMMA RAY DETECTORS; AND ELECTRO~~GNETIC 5. AFTER REACHING TO, A MEASUREMENT AFTER DRILLING (MAD) PASS ACQUIRED DATA FROM TO TO 9374'MD / 8596'TVDSS. 6. MWD DATA ARE CONSIDERED FDC PER E-MAIL FROM D. SCHNORR, GEOQUEST(BP), TO R.KALISH DATED 02/20/02 . "7. MWD RUNS 1 - "7 HEPRESEN'I' WELL M-13A WITH API#:50-029-20522-01. THIS WELL REACHED A TOTAL DEPTH (TO) OF 10895'MD / 8"705'TVDSS. SROP = SMOOTHED HA'I'E OF PENETHATION WHILE DRILLING. SRAT = SMOOTHED RUNNING SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA. RAY. SEXP = SMOOTHED PHASE SI-IIF'T-DEIUVED FŒSISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED 1'H.1-\SE SHIFT-DERIVED RESISTIVITY (SHALJ"OTA1 SPACING) . SEMP = SMOOTHED PHJ\SE SlUFT-DERIVED RESISTIVITY (MEDIU~1 SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .02/02/27 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DE PTH INCREMEN'r: jl FILE SUMMARY PBU TOOL CODE GR ROP RI?M RPS FET RPD RPX 1 clipped curves; all bit runs merged. .5000 START DEPTH 9336.0 9366.5 10194.5 10194.5 10194.5 10194.5 10194.5 STOP DEPTH 10850.0 1. 08 %.5 10864.0 10864.0 10864.0 10864.0 10e64.0 ( , ~l $ BASELINE CURVE FOR SHI FTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # HERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP HERGE BASE lv1~\1D 1 933(i. 0 9488.0 HWD C:Jc1SS.0 9555.0 Mí.-.JD 3 9555.0 9640.0 MWD 4 9640.0 9744.5 MWD 5 9744 . 5 9830.0 MWD 6 9830.0 10224.5 MWD 7 10224.5 10895.5 $ ff REMARKS: MERGED MAIN PASS. c .,' H Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Speci ficati.on Block sub-type... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP M1i\ìD F'r/H 4 ] 68 4 GR MWD API 4 1 68 8 .3 RPX MWD OHM¡VI 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 613 20 6 RPD MWD OHMM 4 1 6B 24 7 FET MWD HOUR 4 1 613 20 B Fi.r:st Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9336 10895.5 10115.8 3120 9336 10895.5 ROP MWD FT/H 0.03 3911.92 75.9673 3059 9366.5 10895.5 GR MWD A.PI 21.27 ~33 4 . ~31 63.1982 3001 9336 10850 RPX MWD OHMM 1.14 2000 82.8147 1340 10194.5 10864 RPS MWD OHMM 1 . Ot~ 455.09 12.8722 1340 10194.5 10864 RPM M1i\ìD OHMM 1.12 67.65 1 L 1673 1340 10194.5 1086,Q RPD M1i\ìD OHMM 0.77 2000 76.0683 1340 10194.5 10864 E'E'T MWD HOUR 0.236333 .12.5715 1.64045 1340 10194.5 10864 First Reading For Entire File..........9336 Last Reading For Entire File...........10895.5 File 'Trailer Service name.............S'TSLIB.OOl Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.002 Physical EOF Fi le Heade)~ Service name............. STSLIE:. Service Sub Level Name... Version Number.......... .1.(1.1 Date of Generation.......02/02/ Maximum Physical Record..65535 Fi le Type................ LO Previous File Name.......STSLIB.OOl Comment Record FILE HLZ\DER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPS FET RPM RPX RPD RAT ~: clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 9374.0 9384.5 9384.5 9384.5 9384.5 9384.5 9417.5 STOP DEPTH 10857. :) 10871.0 10£171.0 10871.0 10871.0 10871.0 10895.5 $ # MERGED PBU MWD $ DATA SOURCE 'l'OOl, CODE MAD RUN NO. MAD PASS NO. MERGE TOP 7 1 9374.0 # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.............. ...Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Se.rv.i.ce Ord.er Units S.ize Nsam R~"p Code Offset Channel DEPT FT 4 1 68 0 1 RlW MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 6cJ 12 4 RPS MAD OHI'1M 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 6e 28 B Name Service Unit Min Max DEPT FT 9374 10900 RAT MAD FT/H 10 16% GR MAD ]-\P1 16.55 434.35 RPX MAD OHMM 1. 26 2000 RPS ¡VIA D OHfVlM 0.92 2000 RPM MAD OHMM 1.05 2000 RPD MAD OHMM 0.71 2000 FET MAD HOUR 3.62683 115.229 Mean 10137 616.573 59.3502 75.8593 38.1572 33.1749 60.3542 45.338 First Reading For Entire File..........9374 Last Reading For Entire Fi1e...........l0900 [\Is am 3053 ;2966 2936 2974 2974 2974 2974 2974 MERGE BASE 10895.5 First Reading 9374 9417.5 9374 9384.5 9384.5 9384.5 9384.5 9384.5 Last Reading 10900 10900 10857.5 10871 10871 10871 10871 10871 F'ile Trailel.- Service name........ .....STSLIB.OO~ Service Sub Level Name... Versi.:-n Number.......... .1. CI. I.' Date of Generation.. .....02/02/27 Maximum Physical Record..65535 F'i 1 e Type................ LO Next File Name.. ........ .STSLIB.OO3 Physical EOF File Header Service name.... .........STSLIB.003 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .....STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 header data for each bit run in separate files. 1 .5000 8T]'\RT DEPTH 9336.0 9366.5 STOP DEPTH 9458.0 9488.0 II LOG HEADER DATA DATE 1,088ED: SOFTWARE SURFACE SOFTWARE VERSION: DOítiJNHOLE SOF'TWJ..\FŒ: VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAl. (FT): BIT ROTATING SPEED (RPM): HOLE INCLINA'I'ION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NG P NA'I'URAL GAMJvLA PROBE $ # BOREHOLE AND CASING DATI\, OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESIS'nVI'I'Y (OHMM) AT TE:MPERf\TUEE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: OB-NOV-OJ. Ins.i-te 0 Memory 9488.0 9336.0 9488.0 28.0 32.4 TOOL NUMBER 2271RF3 Flo Pro 8.60 65.0 9.2 24000 10.8 .000 .000 .000 .000 .0 J.42.0 .0 .0 ~. HOLE CORRECTION (IN): TOOL STl\NDOFF (IN): EWR FREQUENCY (HZ': REMl\RKS: $ # Data Format Specification Record Data Record Type..... .............0 Data Specification Blod: Type..... (I Logging Direction................ . Down Optical log depth units-_........ .Feet Data Reference Point..............Undefined Frame Spacing.....................60 .lIN Max frames per record.............Undefined Absent value- - - -. - -.............. .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Uni.ts Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1. ROP t-IIWDO 1 0 FT/H 4 1 68 4 2 GR MWDOlO API 4 1 68 8 3 First Last Name Service Unit Min Max Mean N:::3am Reading Reading DEPT FT 9336 9488 9412 305 9336 9488 ROP MWDOlO FT/H 0.03 3911.92 55.5436 244 9366.5 948e GR MWDOlO API 36.24 834.81 151.051 245 9336 9458 First Reading For Entire File..........9336 Last Reading For Entire File...........9488 File Trailer Service name.............STSLIB.OO3 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/02/27 Maximum Physical Record..65535 File TY],.!e................ LO Next File Name...........STSLIB.004 Physical. EOF File Header Service name.............STSLIB.OO4 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......02/02/27 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name.......STSLIB.OO3 Comment Record FILE HEADER FI LE NUMBER: RAW MWD CurvE'S and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9458.5 ROP 9488.5 $ header data for each bit run in separate files. ") .5000 STOP DEPTH 9525.0 9555.0 # LOG HEADER DATA D.~TE LOGGED: SOF'T\rV\RE SURFACE SOFTWARE VERSION: DOlrJNHOLE SOFTW.~RE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUH ANGLE: I'IAXIMUJ'1 '/\N(JLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE y # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): II BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PFM): FLUID LOSS (C3): RESISTIVITY (OI-IMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMFERATUHE: MUD FILTRATE AT MT: MUD CAKE AT MT: II NEUTRON TOOL MATRIX: MATRIX DENSrry: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): II REHARKS: $ it Data Format Specification Record Data Record 'Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing................. ....60 .1IN Max frames per record.............Undefined Ab s en t val u e . . . . . . . . . . . . . . . . . . . . . . - 9 9 9 Depth Units....................... Datum Specification Block sub-type...O 08-NOV-02 Insi t.'" l Vlemory 9555.0 9488.0 9555.0 37.4 64.0 TOOL NUMBER 2271RF3 Flo Pro 8.60 65.0 9.2 24000 10. tl, .000 .000 .000 .000 .0 142.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 1 68 0 1 ROP HWD020 FT/H 1. 68 4 GR MWD020 API 1 68 8 3 First Last Name Service Unit Min Hax Mean Nsam Reading Reading DEFT FT 9458.5 %55 9506.75 194 9458.5 9555 ROP JvTWD020 FT/H 0.97 67.55 45.846 134 9488.5 9555 GR HWD020 API 25. :34 645.13 87.0893 134 9458.5 9525 First Reading For Entire File..........9458.5 Last Reading For Entire File........ ...9555 :ile Trailer Service name.......... ...STSLI8.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 FU e Type................ LO Next File Name...........STSLIB.OO5 Physical EOF File Header Service name.............STSLIB.005 Service Sub Level Name... Version Number.... .......1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OO4 Comment Record tILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT': # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9525.5 ROP 9555.5 $ 5 .5000 header data for each bit run in separate files. 3 STOP DEPTH 9609.5 9640.0 # LOG HE.ADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSI.ON: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOH 1,OG IN'I'ERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: Jt TOOL STRING (TOP 'TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL, GAMM,l\ PROBE <' " # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (O]-]MM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (M'I'): MUD AT MAX CIRCULATING TERHPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: OS-NOV-01 Insite 0 Memory 9640.0 9555.0 9640.0 67.3 75.9 TOOL NUMBER 2271RF3 Flo Pro 8.60 65.0 9.2 24000 11. 0 .000 .000 .000 .000 .0 141.7 .0 .0 ( HATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST.i:\.NDOFF (IN): SWR FREQUENCY (HZ): REr-'!ARKS: $ Data Format Specification Record Data Record Type..................c, Data Specification Block Type.....0 L09';Jing Direc:tion................. De.\,¡n Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record..... .... ....Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel. DEPT F1' 1 68 0 1 ROP MWD030 FT/I-I 1 68 4 2 GR MWD030 API 1 68 8 :3 F:Lrst Last Name Service Unit Hin Max Mean Nsam Reading Reading DEPT FT 9525.5 9640 9582.75 230 9525.5 9640 ROP MWD030 FT/H 0.85 100.7 62.1634 no 9555.5 9640 GR MWD030 API 26.48 69 37.1322 169 9525.5 9609.5 First Reading For Entire File..........9525.5 Last Reading For Entire File...........9640 File Trailer Service name..__.........STSLIB.OO5 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO6 Physical EOr File Header Service name.... .........ST3LI8.006 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 File Type......_.........LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9610.0 ROP 9640.5 $ 6 header data for each bit run in separate files. 4 .5000 STOP DEPTH 9714.5 9744.5 LOI~ HE-,\DER DATl\ DATE LOGGED: SOFT\^JARE SURF.'\CE SOFTi!JARE VERSION: DOi!JNHOLE SOFTW.I\RE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG 1'1INIMUI'-I ANGLE: I"IAXIMUtv1 ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OI-lMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERNruRE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT M'I': MU D CAKE A.T M'I': NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ II Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing. ....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O ü9-NOV-O: Insits 0 Ì'1emory 9745.0 9640.0 97<15.0 79.5 91.0 TOOL NUMBER 2271RF3 Flo Pro 8.60 65.0 9.2 24000 8.8 .000 .000 .000 .000 Name Service Order Units S:Lze Nsarn Rap Code Offset Channel DEPT F'1' 4 1 68 0 1 ROP MWD040 fT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 j .0 142.0 .0 .0 FLrst Last Name Service Unit Min ]vlax Mean Nsam Reading Reading DE PT FT 9610 9744.5 9677.25 270 9610 9744.5 ROP MWD040 FT/H 0.7 102.83 54..6662 209 9640.5 9744.5 GR MWD040 API 23.67 100.28 38.3851 210 9610 9714.5 First Reading For Entire File..........9610 Last Reading For Entire File...........9744.5 Comment Record fILE HEADER F'I LE NUMBER: RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMEJF.R: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9715.0 ROP 9745.0 $ ~'i 1 e T r a i 1. e r Service name......... ....STSLI8.006 Service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generatic'n....... 02/02! 27 Maximum Physical Record..65535 File Type............... .LO Next File Name....... ....STSLI8.007 I:"hysical EOf file Header Service name..... ...... ..STSLI8.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 file Type................ LO Previous File Name.......STSLIB.006 7 5 .5000 STOP DEPTH 9800.0 9830.0 # LOG HEI-\DER DATA DATE LOGGED: SOFTWARE SURFACE SOF'rWARE VERSION: DOWNHOLE SOFTWARE VERSION: Dl\TA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL S'rRING (TOP '1'0 BOTTOM) VENDOR TOOL CODE TOOL TYPE NG P NATURÞ,L GAMMJ.\ PROBE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHHM) AT TEHPERATURE (DEGF) HUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FIl,TRATE AT HT: HU 0 Cl\.KE AT WI': NEUTRON TOOL ( 10-NOV-0l Insite 0 Memory 9830.0 9745.0 9830.0 100.2 100.5 TOOL NUMBER 2271RF3 Flo Pro 8.60 65.0 9.0 24000 8.8 .000 .000 .000 .000 .0 142.0 .0 .0 ( Ì"IATRn:: 1"IATRIX DENSIT';:-: HOLE CORRECTION (IN): TOOL STANDOFF (IN): ~WR FREQUENCY (HZ): REHARKS: $ Data Format Specification Record Data Record Type.................. Data Specification Bloc].: Type..... (I Logging Direction.................Down Optical log depth units.... ... ....Feet Data Reference Point..............Undefined frame Spacing..................... 60 .IIN Max frames per record.... .........Undefined Ab s en t val u e. . . . . . . . . . . . . . . . . . . . . . - 999 Depth Units................... . . . . Datum Specification Block sub-type...O Name Service Orde.r Units S.ize Nsam Rep Code Offset Channel DEPT FT 4 I 68 0 I ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 F:Lrst Last Name Service Unit Min Max Mean N::,am Reading Readinq DEPT FT 9715 9830 97'7:2.5 231 9715 9830 ROP J'o11rifD050 FT/H 6.06 En9.86 r36. 5047 171 9745 9830 GR MWD050 API 21. 88 102.11 45.6443 171 9715 9800 First Reading For Entire File..........9715 Last Reading For Entire File...........9830 File Trailer Service name.............STSLI8.007 Service Sub Level Name... Versi_on Number.......... .1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 File Type................LO Next File Name...........STSLIB.OO8 Physical EOF File Header Service name. ............STSLIB.OO8 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OO7 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT': # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9800.5 ROP 9830.5 $ 8 header data for each bit run in separate files. 6 .5000 STOP DEPTH 10194.5 10224.5 LOG HSADER DATA :!r\TE LOGGED: SO rT~-JARE SURFACE SOFTl~ARE VERSION: DŒ;JNHOLE SOFTlr-JARE VERSION: DATA TYPE O'1EJI.'IORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOH LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: M;L\XIMUM ANGLE: TOOL STRINi3 (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CI-11,OR1DES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD .A.T MEASURED TEMPERATURE (MT): MUD AT HAX. CIRCULATING TE,RHPER7-\'1~ur-Œ: MUD FILTRATE }-\'r HT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSI'I'Y: HOl,E CORREC'I'ION (IN): ':l'OOL STi'\NDOFF (IN): EWR FREQUENCY (HZ): # REHARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specifi.cat.ì,on Bl()ck Type..... 0 Logging Direction.................Down Optical log depth units...........Feet Data Reference Point. .............Undefined Frame Spacing................ .....60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Uni.ts....................... Datum Speci ficati.on Block sub-type... 0 10-NOV-Ol I ]1 sit e JI.'!en"¡C,ry 10::::::::5. (, 9830.0 10225.0 96.3 104.5 TOOL NUJv1BER 2271R1:3 Flo Pro 8.60 65.0 8.9 24000 9.6 .000 .000 .000 .000 Name Serv,ice Order Units Size Nsam H,ep CodE~ Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 ::3 .0 142.0 .0 .0 F:L rst Last Name Service U¡Üt Mi.n Max Mean N.~~ a Tn Reading Reading DEPT FT 9800.5 10224.5 10012.:) 849 9800.5 10224.5 ROP MWD060 E'T/H 0.66 148.03 74.9037 n9 9830.5 10224.5 GR MWD060 API 21. 66 194.74 45.5965 789 9800.5 10194.5 First Reading For Entire File..........9800.5 { Last Reading For Entire File...........10224.5 :ile Trailer Service name.............STSLIB.OOS Service Sub Level Name... Version Number...........1.0.ll Date of Generation.. .....02/02/21 Maximum Physical Record..65535 Fi 1 e Type................ LO Next File Name...........STSLIB.009 Physical EOF File Header Service name. ............8T8LIB.009 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 File Type................ LO Previous File Name. .... ..8T8LIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: II FILE SUMMARY VENDOR TOOL CODE: FET RPD RPM RPS RPX GR ROP 9 header data for each bit run in separate files. 7 . ~)O()() START DEPTH 10194.5 10194.5 10194.5 10194.5 10194.5 10195.0 10225.0 $ II LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-'I'IME): TO DRILl,ER (FT): TOP LOG INTERVAL (F'l'): BOTTOM LOG INTEEVl-\L (F'I'): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ 8TOP DEPTH 10864.0 10864.0 10864.0 10864..0 10864.0 10850.0 10895.5 12-NOV-01 Insite 4.30 Memory 10895.0 10225.0 10895.0 69.5 92 .5 BUl"l'OM) TOOL TYPE DUAL GAtvIMA EAY ELECTROMAG. RESIS. 4 TOOL NUMBEF:. 2271EF3 2271RF3 II BOREHOLE AND CASING DA1'A OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD 'rYPE: MUD DENSITY (L8/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): F10 Pro 8.60 65.0 8.9 24000 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF1 MUD AT MEASURED TEMPERATURE (MT): HUD }'l.T 1'-1.1'1.:: CIRCUL.:"I.TING TERJv1PERATURE: HUD FILTRATE AT MT: MUD CAKE AT MT: .280 55. I: 1 'J 7 . ( .131 .23(1 .310 65 ~ 1- 65.IJ ì'-iEUTRON TOOL J'-IIATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type. .... ...... .......0 Data Specification Block Type.. ...0 Logging Direction.... .............Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Sped. fi.cation Block sub-type... () Name Se.cvice Order Uni-ts Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR M'i\m070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 .1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 .1 68 28 8 First Last Name Service Unit Min .Max Mean Nsam Reading Reading DEPT FT 10194.5 .10895.5 10545 1403 10194.5 10895.5 ROP MWD070 FT/H 6.54 f333.38 87.037 1342 10225 10895.5 GR MWD070 API 21.27 436.1 64.585tj 1283 10195 10850 RPX MWD070 OHMM 1.14 2000 82.8147 1340 10194.5 10864 RPS MWD070 OI-IMM 1. 08 455.09 12.8722 1340 10194.5 10864 RPM HWD070 OH.MM 1.12 67.65 11.1673 1340 10194.5 10864 RPD MWD070 OHJVIM 0.77 2000 76.0683 .1340 10194.5 10864 FET MWD07 0 HOUR 0.236333 12.5715 1.64045 1340 10194.5 10864 First Reading For Entire File..........10194.5 Last Reading For Entire File...........10895.5 File Trailer Service name.............STSLIB.009 Service Sub Level Name... Version Number. ...... ....1.0.0 Date of Generation... ....02/02/27 Maximum Physical Record..65535 Fil e Type................ LO Next File Name...........STSLIB.010 Physi.cal EOF File Header Service name.............STSLIB.010 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation.......02/02/27 Comment Rer.:::ord rILE HEADER ~ILE NUMBER: :;;AíriJ MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 j'.IAD RUN NUMBER: Ì'IAD PASS NUMBER: # fILE SUMMARY VENDOR TOOL CODE GR RE'X fET RPD RPM RPS RAT Maximum Physical Record..65535 Fi 1 e Type................:LO Previous File Name... ....STSLIB.OOG 10 START DEPTH 9374.0 9384.5 9384.5 9384.5 9384.5 9384.5 9417 . 5 STOP DEPTH 10857.5 10871.0 10871.0 10871.0 10871.0 10871.0 10895.5 " y # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOlríJNHOLE SOFTViJARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (F'r): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG HINIjvlUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) '1'OOL TYPE DUAL GAMMA RAY ELECTRO¡V¡AG. RESIS. 4 BOREHOLE AND CASINC; DAT.J\ OPEN HOLE BIT SIZE (IN): DRILLER! S CJ\SING DEPTH (F'r): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): 1'-1UD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESIS'rrVI'I'Y (OHMM) A'l' TE¡V¡PER}\TURE (DEGf') HUD AT MEASURED TEHPERATURE (MT): MUD AT MAX CIRCULATING 'l'ERMPERA'rURE: MUD FILTRATE AT MT: MUD CAKE AT M'I': # NEUTRON TOOL M}.\TRIX: MATRIX nENSrI'Y: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O i{ 12-NOV-Ol Insite ,1.30 Memory 10895.0 9374.0 10895.0 69.5 92. .5 TOOL NUMBER 227J.RE'3 2271RF3 Flo Pro 8.60 65.0 8.9 24000 7.6 .280 .131 .230 .310 65.0 147.0 65.0 65.0 ( ( Logging Direction.............. ...Dow~ Optical log depth units...........Fee: Data Reference Point..............Undefined !:~rame Spacin,;¡..................... 60 .In: Max frames per record.............Undefinea ,~bsent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 RAT MAD071 FT/H 4 1 68 GR 1'-1.Z\D071 ,Z\PI 4 1 68 8 '-' RPS MAD071 OHMM 4 1 68 12 RPM MAD071 OHMM 4 1 68 16 5 RPD MAD071 OHMM 4 1 68 20 6 rET MAD071 HOUR 4 1 68 24 "7 RPX MAD071 OHMM 4 1 68 ')Q 8 ¿~I First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9374 10900 10137 3053 9374 10900 RAT MAD071 FT/H 10 1695 616.573 2966 9417.5 10900 GR MAD071 API 16.55 434.35 59.3502 2936 9374 10857.5 RPS MAD071 OHMM 0.92 ~~ ()O 0 38.1572 2974 9384.5 .10871 RPM MAD071 OrIMM J..05 2000 33.17 49 2974 9384.5 10871 RPD MAD071 OHMM 0.71 2000 60.3542 2974 9384.5 10871 FET MAD071 HOUR 3. 626EU 115.229 4:).338 2974 9384.5 10871 RPX MADon OHMM 1. 26 2000 75.B593 2974 93B4.5 10871 First Reading For Entire File..........9374 Last Reading For Entire Fi1e...........10900 File Trailer Service name.............STSLIB.OI0 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/02/27 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.Ol1 Physical EOF Tape Trailer Service name....... .... ..LISTPE Date.....................02/02/27 Origin. . . .. . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel 'Trailer Service name...... .......LISTPE Da t e. . . . . . . . . . .. . . . . . . . . . 02/0:2/2 '7 Origin. . . . . . . . . . . . . . . . . . . s'rs Reel Name................UNKNOWN Continuation Number......Ol Next Reel. Nam.e........... UNKNOWN Comments......... .... ... .STS LIS Writi.ng L:i.brary. Scientific Technical Services Physical Eor Physical EOF Sod Of LIS File t ( ( ( éJ) /0 "- I} ~(/( Jð ~ .aOJ- )05 þ!~j¿ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Feb 28 15:07:35 2002 Reel Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/02/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/02/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay WOA MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-11188 S. LATZ FEKETI/CUBBO JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 AK-MW-11188 S. LATZ FEKETI/CUBBO JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 7 AK-MW-11188 J. PANTER FEKETI/CUBBO # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: M-13A 500292052201 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 27-FEB-02 MWDRUN 2 AK-MW-11188 S. LATZ FEKETI/CUBBO MWDRUN 5 AK-MW-11188 S. LATZ FEKETI/CUBBO MAD RUN 7 AK-MW-11188 J. PANTER FEKETI/CUBBO 1 11N 12E 1937 MWDRUN 3 AK-MW-11188 S. LATZ FEKETI/CUBBO MWD RUN 6 AK-MW-11188 J. PANTER FEKETI/CUBBO ( {' FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 605 MSL 0) 55.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.500 3.750 3.750 CASING SIZE (IN) 9.625 7.000 4.500 DRILLERS DEPTH (FT) 9212.0 9350.0 9196.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH-SUBSEA (TVDSS) . 3. MWD RUNS 1 - 6 COMPRISED DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 4. MWD RUN 7 COMPRISED (DGR) UTILIZING GEIGER-MUELLER TUBE WAVE RESISTIVITY- PHASE 4 ( EWR4) . DIRECTIONAL; DUAL GAMMA RAY DETECTORS; AND ELECTROMAGNETIC 5. AFTER REACHING TD, A MEASUREMENT AFTER DRILLING (MAD) PASS ACQUIRED DATA FROM TD TO 9374'MD / 8596'TVDSS. MAD PASS EWR4 DATA WERE MERGED WITH MWD DATA FROM 10194'MD TO 9380.5'MD. 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHNORR, GEOQUEST(BP), TO R.KALISH DATED 02/20/02 . 7. MWD RUNS 1 - 7 REPRESENT WELL M-13A WITH API#:50-029-20522-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10895'MD / 8705'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED RUNNING SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. $ File Header ~. Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRD SROP SEMP SESP SFXE SEDP SEXP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 9336.0 9366.5 9380.5 9380.5 9380.5 9380.5 9380.5 STOP DEPTH 10850.0 10895.5 10864.0 10864.0 10864.0 10864.0 10864.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----. BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 9336.0 9488.0 MWD 2 9458.5 9555.0 MWD 3 9525.5 9640.0 MWD 4 9610.0 9744.5 MWD 5 9715.0 9830.0 MWD 6 9800.5 10224.5 MWD 7 9370.0 10899.5 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD FET MWD OHMM HOUR 4 4 1 68 1 68 7 8 24 28 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9336 10895.5 10115.8 3120 9336 10895.5 ROP MWD FT/H 0.03 3911.92 75.9673 3059 9366.5 10895.5 GR MWD API 21.27 834.81 63.1982 3001 9336 10850 RPX MWD OHMM 1.14 2000 81.7852 2968 9380.5 10864 RPS MWD OHMM 1.08 2000 38.9758 2968 9380.5 10864 RPM MWD OHMM 1.12 2000 33.3904 2968 9380.5 10864 RPD MWD OHMM 0.77 2000 66.0208 2968 9380.5 10864 FET MWD HOUR 0.236333 115.229 38.686 2968 9380.5 10864 First Reading For Entire File......... .9336 Last Reading For Entire File.......... .10895.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date òf Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRC SESP SFXE SEMP SEXP SEDP SRAT $ 2 clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 9370.0 9380.5 9380.5 9380.5 9380.5 9380.5 9413.5 # MERGED PBU MWD $ DATA SOURCE TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP 7 1 9370.0 MERGE BASE 10899.5 STOP DEPTH 10857.0 10870.5 10870.5 10870.5 10870.5 10870.5 10899.5 !( ( # REMARKS: MERGED MAD PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9370 10899.5 10134.8 3060 9370 10899.5 RAT MAD FT/H 10 1695 616.472 2973 9413.5 10899.5 GR MAD API 16.55 434.35 59.4045 2943 9370 10857 RPX MAD OHMM 1.26 2000 77.1439 2981 9380.5 10870.5 RPS MAD OHMM 0.92 2000 38.0765 2981 9380.5 10870.5 RPM MAD OHMM 1.05 2000 33.1037 2981 9380.5 10870.5 RPD MAD OHMM 0.71 2000 60.8376 2981 9380.5 10870.5 FET MAD HOUR 3.62683 115.229 45.2964 2981 9380.5 10870.5 First Reading For Entire File......... .9370 Last Reading For Entire File.......... .10899.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SGRD SROP $ 3 ( header data for each bit run in separate files. 1 .5000 START DEPTH 9336.0 9366.5 STOP DEPTH 9458.0 9488.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down 08-NOV-Ol Insite 0 Memory 9488.0 9336.0 9488.0 28.0 32.4 TOOL NUMBER Flo Pro 8.60 65.0 9.2 24000 10.8 .000 .000 .000 .000 .0 142.0 .0 .0 (' Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9336 9488 9412 305 9336 9488 ROP MWD010 FT/H 0.03 3911.92 55.5436 244 9366.5 9488 GR MWD010 API 36.24 834.81 151.051 245 9336 9458 First Reading For Entire File......... .9336 Last Reading For Entire File.......... .9488 File Trailer Service name............ .STSLIB.OO3 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type...... . . . . . . . . . . LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum physical Record. .65535 File Type........ . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRD 9458.5 SROP 9488.5 $ 4 header data for each bit run in separate files. 2 .5000 STOP DEPTH 9525.0 9555.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 08-NOV-01 ( SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Insite 0 Memory 9555.0 9488.0 9555.0 37.4 64.0 TOOL NUMBER Flo Pro 8.60 65.0 9.2 24000 10.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit DEPT FT Min 9458.5 Max 9555 Mean Nsam 9506.75 194 ~,"" , .0 142.0 . 0 .0 First Reading 9458.5 Last Reading 9555 . . ROP MWD020 FT/H GR MWD020 API 67.55 645.13 0.97 25.34 First Reading For Entire File......... .9458.5 Last Reading For Entire File.......... .9555 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH SGRD 9525.5 SROP 9555.5 $ 5 45.846 87.0893 134 134 9488.5 9458.5 9555 9525 header data for each bit run in separate files. 3 .5000 STOP DEPTH 9609.5 9640.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 08-NOV-01 Insite 0 Memory 9640.0 9555.0 9640.0 67.3 75.9 TOOL NUMBER I( # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( Flo Pro 8.60 65.0 9.2 24000 11.0 .000 .000 .000 .000 .0 141.7 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9525.5 9640 9582.75 230 9525.5 9640 ROP MWD030 FT/H 0.85 100.7 62.1634 170 9555.5 9640 GR MWD030 API 26.48 69 37.1322 169 9525.5 9609.5 First Reading For Entire File......... .9525.5 Last Reading For Entire File.......... .9640 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 F i 1 e Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.006 . . Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SGRD SROP $ 6 header data for each bit run in separate files. 4 .5000 START DEPTH 9610.0 9640.5 STOP DEPTH 9714.5 9744.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 09-NOV-01 Insite 0 Memory 9745.0 9640.0 9745.0 79.5 91.0 TOOL NUMBER Flo Pro 8.60 65.0 9.2 24000 8.8 .000 .000 .000 .000 .0 142.0 .0 .0 . . (' ( # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9610 9744.5 9677.25 270 9610 9744.5 ROP MWD040 FT/H 0.7 102.83 54.6662 209 9640.5 9744.5 GR MWD040 API 23.67 100.28 38.3851 210 9610 9714.5 First Reading For Entire File......... .9610 Last Reading For Entire File.......... .9744.5 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 7 header data for each bit run in separate files. 5 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SGRD SROP $ .5000 START DEPTH 9715.0 9745.0 STOP DEPTH 9800.0 9830.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( 10-NOV-01 Insite 0 Memory 9830.0 9745.0 9830.0 100.2 100.5 TOOL NUMBER Flo Pro 8.60 65.0 9.0 24000 8.8 .000 .000 .000 .000 .0 142.0 .0 .0 ,,0" If" ( ( Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9715 9830 9772.5 231 9715 9830 ROP MWD050 FT/H 6.06 819.86 86.5047 171 9745 9830 GR MWD050 API 21.88 102.11 45.6443 171 9715 9800 First Reading For Entire File......... .9715 Last Reading For Entire File.......... .9830 File Trailer Service name............ .STSLIB.007 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SGRD SROP $ 8 header data for each bit run in separate files. 6 .5000 START DEPTH 9800.5 9830.5 STOP DEPTH 10194.5 10224.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): 10-NOV-Ol Insite 0 Memory 10225.0 9830.0 10225.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ( 96.3 104.5 TOOL NUMBER Flo Pro 8.60 65.0 8.9 24000 9.6 .000 .000 .000 .000 .0 142.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9800.5 10224.5 10012.5 849 9800.5 10224.5 ROP MWD060 FT/H 0.66 148.03 74.9037 789 9830.5 10224.5 GR MWD060 API 21.66 194.74 45.5965 789 9800.5 10194.5 First Reading For Entire File......... .9800.5 Last Reading For Entire File.......... .10224.5 File Trailer Service name............ .STSLIB.008 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name............ .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . .LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SFXE SEDP SEMP SESP SEXP SGRC SROP $ 9 ( header data for each bit run in separate files. 7 .5000 START DEPTH 10194.5 10194.5 10194.5 10194.5 10194.5 10195.0 10225.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS STOP DEPTH 10864.0 10864.0 10864.0 10864.0 10864.0 10850.0 10895.5 12-NOV-01 Insite 4.30 Memory 10895.0 10225.0 10895.0 69.5 92.5 TOOL NUMBER I( MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Flo Pro 8.60 65.0 8.9 24000 7.6 .280 .131 .230 .310 65.0 147.0 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10194.5 10895.5 10545 1403 10194.5 10895.5 ROP MWD070 FT/H 6.54 833.38 87.037 1342 10225 10895.5 GR MWD070 API 21.27 436.1 64.5855 1283 10195 10850 RPX MWD070 OHMM 1.14 2000 82.8147 1340 10194.5 10864 RPS MWD070 OHMM 1.08 455.09 12.8722 1340 10194.5 10864 RPM MWD070 OHMM 1.12 67.65 11.1673 1340 10194.5 10864 RPD MWD070 OHMM 0.77 2000 76.0683 1340 10194.5 10864 FET MWD070 HOUR 0.236333 12.5715 1.64045 1340 10194.5 10864 First Reading For Entire File......... .10194.5 Last Reading For Entire File.......... .10895.5 File Trailer Service name............ .STSLIB.009 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.010 Physical EOF File Header Service name............ .STSLIB.010 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.009 Comment Record FILE HEADER FILE NUMBER: RAW MAD Curves and log DEPTH INCREMENT: MAD RUN NUMBER: MAD PASS NUMBER: # FILE SUMMARY VENDOR TOOL CODE SGRC SFXE SEDP SEMP SESP SEXP SRAT $ 10 header data for each pass of each run in separate files. .5000 7 1 START DEPTH 9370.0 9380.5 9380.5 9380.5 9380.5 9380.5 9413.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): STOP DEPTH 10857.0 10870.5 10870.5 10870.5 10870.5 10870.5 10899.5 12-NOV-01 Insite 4.30 Memory 10895.0 9374.0 10895.0 69.5 92.5 TOOL NUMBER Flo Pro 8.60 { I ~ MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 65.0 8.9 24000 7.6 .280 .131 .230 .310 65.0 147.0 65.0 65.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD071 FT/H 4 1 68 4 2 GR MAD071 API 4 1 68 8 3 RPX MAD071 OHMM 4 1 68 12 4 RPS MAD071 OHMM 4 1 68 16 5 RPM MAD071 OHMM 4 1 68 20 6 RPD MAD071 OHMM 4 1 68 24 7 FET MAD071 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9370 10899.5 10134.8 3060 9370 10899.5 RAT MAD071 FT/H 10 1695 616.472 2973 9413.5 10899.5 GR MAD071 API 16.55 434.35 59.4045 2943 9370 10857 RPX MAD071 OHMM 1.26 2000 77.1439 2981 9380.5 10870.5 RPS MAD071 OHMM 0.92 2000 38.0765 2981 9380.5 10870.5 RPM MAD071 OHMM 1.05 2000 33.1037 2981 9380.5 10870.5 RPD MAD071 OHMM 0.71 2000 60.8376 2981 9380.5 10870.5 FET MAD071 HOUR 3.62683 115.229 45.2964 2981 9380.5 10870.5 First Reading For Entire File......... .9370 Last Reading For Entire File.......... .10899.5 File Trailer Service name............ .STSLIB.010 Service Sub Level Name... Version Number.......... .1.0.0 ( ( Date of Generation...... .02/02/28 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.011 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/02/28 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. . . . . . . . . . . . .LISTPE Da te. . . . . . . . . . . . . . . . . . . . . 02/02/28 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File