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182-009
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 2, 2026 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/02/2026 13-20 50-029-20705-00-00 182-009-0 W SPT 8390 1820090 2098 1040 1044 1043 1042 57 152 151 147 REQVAR P Guy Cook 11/9/2025 2 year MIT-IA per CO 736. PWI header pressure is 2000 psi. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 13-20 Inspection Date: Tubing OA Packer Depth 52 2500 2391 2363IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC251109155654 BBL Pumped:3.6 BBL Returned:3.5 Friday, January 2, 2026 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/23/2025 13-20 50-029-20705-00-00 182-009-0 N SPT 8390 1820090 2250 1 2506 2436 2414 0 0 0 0 OTHER P Bob Noble 5/15/2025 2 year MIT-T 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 13-20 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250516160344 BBL Pumped:2 BBL Returned:2 Wednesday, July 23, 2025 Page 1 of 1 IA remedial cement Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 11/28/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231128 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU-13 50133205250000 203138 11/13/2023 HALLIBURTON RMT3D MPU B-28 50029235660000 216027 11/20/2023 HALLIBURTON LDL MPU B-28 50029235660000 216027 11/21/2023 HALLIBURTON MFC MPU C-20 50029219140000 189015 11/21/2023 HALLIBURTON LDL NS-24 50029231110000 202164 11/20/2023 READ LeakPointSurvey PBU 13-20 50029207050000 182009 11/16/2023 HALLIBURTON WFL-TMD3D PBU L-216 50029232060000 204065 7/20/2023 PROBE MSIL (CBL) PBU S-09A 50029207710100 214097 7/7/2023 PROBE MSIL (CBL) PBU S-32A 50029220990100 212082 7/13/2023 PROBE MSIL (CBL) PBU S-124 50029233230000 206136 7/15/2023 PROBE MSIL (CBL) Please include current contact information if different from above. T38150 T38151 T38151 T38152 T38153 T38154 T38155 T38156 T38157 T38158 11/29/2023 PBU 13-20 50029207050000 182009 11/16/2023 HALLIBURTON WFL-TMD3D Kayla Junke Digitally signed by Kayla Junke Date: 2023.11.29 11:22:45 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/12/2024 13-20 50-029-20705-00-00 182-009-0 W SPT 8390 1820090 2098 932 933 933 933 60 112 115 115 OTHER P Austin McLeod 11/13/2023 Two year. 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 13-20 Inspection Date: Tubing OA Packer Depth 0 2499 2387 2359IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM231113193221 BBL Pumped:4.1 BBL Returned:3.3 Friday, January 12, 2024 Page 1 of 1 IA remedial cementing MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 16, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/16/2023 13-20 50-029-20705-00-00 182-009-0 N SPT 8390 1820090 2250 362 2490 2392 2360 0 0 0 0 OTHER P Brian Bixby 5/16/2023 MIT-T 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 13-20 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230516120102 BBL Pumped:2.4 BBL Returned:2.4 Friday, June 16, 2023 Page 1 of 1 IA cement squeeze MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 13-20 50-029-20705-00-00 182-009-0 N SPT 8390 1820090 2250 803 2512 2355 2239 0 0 0 0 OTHER F Bob Noble 5/13/2023 2 year MIT-T to 2250 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 13-20 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230513154859 BBL Pumped:1.5 BBL Returned:1.3 Tuesday, July 25, 2023 Page 1 of 1 2nd attempt - fail; pressure loss during 30 minute test exceeded 10% -- jbr MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 25, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2023 13-20 50-029-20705-00-00 182-009-0 N SPT 8390 1820090 2250 749 2493 2337 2228 0 0 0 0 OTHER F Bob Noble 5/13/2023 2 year MIT-T to 2250 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 13-20 Inspection Date: Tubing OA Packer Depth 0 0 0 0IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN230513154409 BBL Pumped:4.3 BBL Returned:1.6 Tuesday, July 25, 2023 Page 1 of 1 Pressure loss during 30 min test exceeded 10%; jbr MEMORANDUM TO: Jim Regg —I P.I. Supervisor I FROM: Bob Noble Petroleum Inspector Well Name PRUDHOE BAY UNIT 13-20 Insp Num: mitRCN211112163623 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 18, 2022 SUBJECT: Mechanical Integrity Tests Hilcotp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Src: Inspector Reviewed By: P.I. Supry�^ Comm API Well Number 50-029-20705-00-00 Inspector Name: Bob Noble Permit Number: 182-009-0 Inspection Date: 11/12/2021 ' Tuesday, January 18, 2022 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-20 — T e In yp W TVDp 8390 Tubing 1 849 f 851 849 849 - PTD 1820090 Type Test, SPT test sil YP J 2500 IA 609 2786 2693 1 2663 BBL Pumped: 3.6 BBL Returned: 3 - ', QA 388 � I 612 j 603 i 594 Int-erval OTHER p/F P v Notes: Online MIT -IA to 2500 psi post IA cement repair per Sundry 321-059 f Tuesday, January 18, 2022 Page 1 of I MEMORANDUM TO: Jim Regg P.I. Supervisor IS' Y11 FROM: Bob Noble Petroleum Inspector Z��,e�4LI Well Name PRUDHOE BAY UNIT 13-20 IRsp Num: mitRCN211112163623 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 8, 2021 SUBJECT: Mechanical Integrity Tests Fhlcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-20705-00-00 Inspector Name: Bob Noble Permit Number: 182-009-0 Inspection Date: 11/12/2021 Wednesday, December 8, 2021 Page I of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-20 'Type Ini W -'T`ID 8390 - Tubing 849 851 849. 849 - PTD 1820090 Type see see t l SPT' !Test psi 2098 IA 609 2786 2693 - 2663 ' BBL Pumped: 3.6 IBBL Returned: 1 3 - OA 388 612 603 594 { Intervali OTHER P/F t P - Notes: Online MIT - _ -IA to 2500 psi post IA cement repair per Sundry 321-059 Wednesday, December 8, 2021 Page I of 1 From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector 13-20 (PTD #1820090) Ready for Injection Date:Thursday, November 18, 2021 10:51:22 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, November 7, 2021 4:25 PM To: Wallace, Chris D (CED) <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: OPERABLE: Injector 13-20 (PTD #1820090) Ready for Injection Mr. Wallace, Injector 13-20 (PTD #1820090) is ready for Injection. The well is now classified back to OPERABLE. An AOGCC witnessed MIT-IA will be performed when the well is on stabilized injection. 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 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, October 6, 2021 4:07 PM 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 13-20 (PTD #1820090) for tracking purposes Mr. Wallace, Injector 13-20 (PTD # 1820090) has not been online since being made Operable due to the surface kit not being fit for service. The well will be classified back to NOT OPERABLE for tracking purposes until the surface kit is ready and the well can be placed on Injection for an AOGCC witnessed MIT-IA. 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 From: Alaska NS - PB - Field Well Integrity Sent: Monday, May 31, 2021 9:28 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: OPERABLE: Injector 13-20 (PTD #1820090) Passing MIT-T & IA post IA cement Mr. Wallace, Injector 13-20 (PTD #1820090) passed AOGCC witnessed MIT-T and MIT-IA post IA cement job on 05/13/21 which verifies two competent well barriers. The well is now classified as OPERABLE and can be put on injection. A water flow log is scheduled for 06/05/21 and an AOGCC MIT-IA will be conducted once thermally stable in accordance with approved sundry 321-059. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, D&C Well Integrity Coordinator Sent: Monday, January 11, 2016 2:02 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; Pettus, Whitney Subject: NOT OPERABLE: Injector 13-20 (PTD #1820090) Due for AOGCC MIT-IA All, Injector 13-20 (PTD #1820090) will be due for an AOGCC MIT-IA next month. However, the well will not be available to place on injection before the due date. The well is reclassified as Not Operable until ready to be placed on injection and has been added to the Quarterly Not Operable Injector Report. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska - Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 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 herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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. 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 9:02 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 13-20 (PTD #1820090) for tracking purposes From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, October 6, 2021 4:07 PM To: Wallace, Chris D (CED) <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 13‐20 (PTD #1820090) for tracking purposes Mr. Wallace, Injector 13‐20 (PTD # 1820090) has not been online since being made Operable due to the surface kit not being fit for service. The well will be classified back to NOT OPERABLE for tracking purposes until the surface kit is ready and the well can be placed on Injection for an AOGCC witnessed MIT‐IA. 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 From: Alaska NS ‐ PB ‐ Field Well Integrity Sent: Monday, May 31, 2021 9:28 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: OPERABLE: Injector 13‐20 (PTD #1820090) Passing MIT‐T & IA post IA cement Mr. Wallace, Injector 13‐20 (PTD #1820090) passed AOGCC witnessed MIT‐T and MIT‐IA post IA cement job on 05/13/21 which verifies two competent well barriers. The well is now classified as OPERABLE and can be put on injection. A water flow log is scheduled for 06/05/21 and an AOGCC MIT‐IA will be conducted once thermally stable in accordance with approved sundry 321‐059. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance 2 Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 From: AK, D&C Well Integrity Coordinator Sent: Monday, January 11, 2016 2:02 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, D&C DHD Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA) (jim.regg@alaska.gov)'; Pettus, Whitney Subject: NOT OPERABLE: Injector 13-20 (PTD #1820090) Due for AOGCC MIT-IA All, Injector 13‐20 (PTD #1820090) will be due for an AOGCC MIT‐IA next month. However, the well will not be available to place on injection before the due date. The well is reclassified as Not Operable until ready to be placed on injection and has been added to the Quarterly Not Operable Injector Report. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska ‐ Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 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 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. David Douglas Hilcorp Alaska, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: Hilcorp North Slope, LLC Date: 06/16/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL: FTP Folder Contents: Log Print Files and LAS Data Files: Well API PTD # Log Date Log Type Log Vendor 13-20 500292070500 182009 05/08/2021 RCBL HALLIBURTON E-34A 500292243701 214096 06/06/2021 RCBL READ CH G-18B 500292062002 214071 05/23/2021 RCBL HALLIBURTON S-201A 500292298701 219092 05/29/2021 IPROF-WFL and ANALYSIS HALLIBURTON S-210 500292363000 219057 04/27/2021 IPROF-WFL and ANALYSIS HALLIBURTON V-117 500292315600 203090 05/02/2021 PPROF and ANALYSIS HALLIBURTON V-117 500292315600 203090 05/02/2021 RCBL HALLIBURTON Z-11A 500292205301 205031 05/18/2021 RCBL HALLIBURTON Z-31 500292187100 188112 06/07/2021 RCBL HALLIBURTON Please include current contact information if different from above. Received By: 06/16/2021 37' (6HW By Abby Bell at 10:04 am, Jun 16, 2021 MEMORANDUM TO: Jim Regg P.I. Supervisor �Pf 41 /jai 'L(� FROM: Guy Cook Petroleum Inspector Well Name PRUDHOE BAY UNIT 13-20 Insp Num: mitGDC210513062745 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 3, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Sre: Inspector Reviewed By; r P.I. Supry Comm API Well Number 50-029-20705-00-00 Inspector Name: Guy Cook Permit Number: 182-009-0 ' Inspection Date: 5/13/2021 - Notes: MITT post cement job per Sundry 321-059. Testing completed with a Little Red Services pump truck and calibrated gauges. Thursday, June 3, 2021 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-20— !Type Id Y_PJ N . TVD 8306 Tubin g 137 2742 - 2654 2628 -- PTD Iszao90 -peTest Slur-Testpsi _ 2500 IA 0 - 5. 7 8 - BBL Pumped: —_ za - BBL Returned: 2.6 - OA 0 0 0 - 0 Interval i OTHER P/F Notes: MITT post cement job per Sundry 321-059. Testing completed with a Little Red Services pump truck and calibrated gauges. Thursday, June 3, 2021 Page I of I MEMORANDUM TO: Jim Regg �nd P.I. Supervisor FROM: Guy Cook Petroleum Inspector FJ/ l D(uizi NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 3, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Sre: Inspector Reviewed By: 9p P.1. Supry Comm Well Name PRUDHOE BAY UNIT 13-20 API Well Number 50-029-20705-00-00 Inspector Name: Guy Cook Permit Number: 182-009-0 Inspection Date: 5/13/2021 Insp Num: mitGDC210513162818 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-20 Type Inj N -TVD s3oe - Tubing 245 422 - 454 - 465 PTD szoo90 Type Test SPT Test psi—' IA o z244 zoos - z5e3 - BBL Pumped- 3 BBL Returned: 3- OA o 0 0_ 0 Interval OTHER'P/F P� i Notes- MIT -IA post cement job per Sundry 321-059. Testing completed with a Little Red Services pump truck and calibrated gauges. Thursday, June 3, 2021 Page I of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector I Well Name PRUDHOE BAY UNIT 13-20 tnsp Num: mitGDC2t0513062745 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 18, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 Ste: Inspector Reviewed By: P.I. Sup" .7gk— Comm API Well Number 50-029-20705-00-00 Inspector Name: Guy cook Permit Number: 182-009-0 Inspection Date: 5113/2021 ✓ Packer Well 13-20Type Inj I N • TVD PTD 1820090 Type Test sPT Test psi BBL Pumped: 1 2.6 - BBL Returned: Interval OTHER - P/F Notes: MITT post cement job per Sundry 321-059.1 T's 3epth Pretest Initial 15 Min 30 Min 45 Min 60 Min 8306 L Tubing 131 2742 2654 2623 - 2076 IA 0 5 7 _ R 2.6 - OA 1 a 1 o Io o P completed with a Little Red Services pump truck and calibrated gauges Tuesday, May 18, 2021 Page I of I MEMORANDUM To: JimRegg i`et, 5'?f(�( P.I. Supervisor ' FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 18, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 13-20 PRUDHOE BAY UNIT 13-20 See: Inspector Reviewed By: P.I. sup" 133?— Comm Well Name PRUDHOE BAY UNIT 13-20 API Well Number 50-029-20705-00-00 Inspector Name: Guy cook Permit Number: 182.009-0 Inspection Date: 5/13/2021 ' Insp Num: mitGDC210513162818 Rel Insp Num: Packer Depth Pretest Initial IS Min 30 Min 45 Min 60 Min pe Inj h' TVD 8306 - Tubing 245 422. 454 465 -- VIntervalOTTHYEPR Tye Test sPf `Test psi 2076 IA 0 2744 - 2605 - 2563 3- BBL Returned: 3 OA o 0 0 0 p/P P post cement NO[¢S: MIT -Lk Po J per Sundry 321-059. Testing completed with a Little Red Services pump [rack and calibrated gauges. Tuesday, May 18, 2021 Page 1 of I Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:182-009 6.API Number:50-029-20705-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028311 Property Designation (Lease Number):10. n/a 8. PBU 13-20 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown IA cement repair Op Shutdown GAS GSTOR5WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10426 Effective Depth MD: 17# L-80 / 12.6# N-80 11. 2-15-2021 Commission Representative: 15. Suspended Contact Name: Ryan Thompson Contact Email: Ryan.Thompson@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9252 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9329 , 9505 / 8227 , 8391 No SSSV Installed Date: Liner 873 7"9543 - 10416 8426 - 9242 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 32 - 2501 32 - 2501 14. Estimated Date for Commencing Operations: BOP Sketch 33 - 116 Structural Proposal Summary 13. Well Class after proposed work: 5-1/2" Basker S-3 / 5-1/2" BOT 3-H 9843 - 10237 8705 - 9074 5-1/2" / 4-1/2"30 - 9478 / 9461 - 9589 Production 9432 8323 9432 10099 , 10109 33 - 116 470 13-3/8" Contact Phone:(907) 564-5280 Date: 1-27-2021 83 149020"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2469 5380 9815 9-5/8" 30 - 9845 30 - 8707 6870 / 8150 4760 / 5080 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2356 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:09 am, Jan 28, 2021 321-059 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.01.28 08:01:05 -09'00' Bo York Post job MIT-IA, MIT-T, SCMT & WFL as indicated. MIT-IA to 2500 PSI. Biennieal MIT-T, MIT-IA & WFL. 10-404 DSR-1/28/21SFD 1/28/2021MGR03FEB21 , ADL 028315 SFD 1/28/2021 Yeon Required? Comm 2/3/21 dts 2/3/2021 JLC 2/3/2021 RBDMS HEW 2/3/2021 IA Cement Job 13-20 PTD: 182-009 Well Name: 13-20 (Injector) API Number: 500292070500 Current Status: Shut-In Rig: Interventions Kit Estimated Start Date: 02/15/2021 Estimated Duration: 1 Month Reg.Approval Req’std? 10-403, 10-404 Date Reg. Approval Rec’vd: N/A Regulatory Contact: Carrie Janowski Permit to Drill Number: 182-009 First Call Engineer: Ryan Thompson 907-564-5280 / 907-301-1240 Second Call Engineer: Dave Bjork 907-564-4672 / 907-440-0331 AFE Number: 205-03595 Current Bottom Hole Pressure: 3236 psi @ 8,800’ TVD 7.1 PPGE |Based on offset well 12-20A from 8/18/16 Max. Anticipated Surface Pressure: 2356 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 550 psi (Taken on 3/16/17) Min ID: 3.813” ID @ 9603’ MD Max Angle: 54 Deg @ 8,664’ UG4 Marker: 4847’ MD Surface Casing Shoe: 2501’ MD / 2500’ TVD 1500’ TVD below SCS: 4,135 MD’ / 4000’ TVD History Well 13-20 is a WAG injector that was completed in 1982. A RWO was completed in 2002 running new 5 ½” L-80 tubing into the well. The last time the well was on MI injection was 2014. The well was shut-in in 2015 due to erosional concerns with the surface flowline. In 2020 a plan was developed to triple the surface choke with two nearby injectors in order to re-establish PW injection back into 13-20. Prior to surface work execution, a MIT-IA was performed which failed. A LLR of 1.7 bpm @ 2070 psi was established down the IA. In December 2020 an LDL was run establishing a PC leak at 6585’ MD. We will now attempt an IA squeeze to establish integrity on the IA. The purpose of this program is to return 13-20 to “operable” status by remediating the PC leak. Current Status The well is classified as “Not Operable.” Objective Repair the well with an IA cement job that is estimated to provide an incremental 250 mbo of production over the next several years. Without an IA cement repair the well has no utility in the foreseeable future. Cement the IA to cover the PC leak at 6,585’ MD meeting the regulatory criteria (Conservation Order 736). Cement will be circulated down the tubing and up the IA through the tubing punch at ~9,305’ MD. The proposed TOC in the IA is ~4,400’’ MD which is >1,500’ TVD deeper than the surface casing shoe and 447’ MD shallower than the estimated top of UG4. Installing IA cement to ~4400’ MD ensures that the repair of the PC leak is sound and that any future PC leaks do not compromise the barriers in the well. This leaves the well with an IA that is ~4400’MD deep that will be monitored. The CO 736 required Biennial MITTs and MITIAs will provide additional assurance that barriers have integrity in the future. ~4,200 TVD ~ 5957' TVD IA Cement Job 13-20 PTD: 182-009 Post-job Evaluation o MIT-T and MIT-IA o SCMT to confirm the Top of Cement (TOC) Long-Term Integrity Monitoring o Biennial MIT-T’s and MIT-IAs for injectors o Record WHPs and Injection rate daily o AOGCC Required Waterflow Logs Procedure: Slickline 1. Pull Tubing Tail Plug. E-Line & Fullbore 1. Set 5-1/2” CBP just above the production packer. a. Fullbore: Perform PT of tubing to 2000 psi to verify CBP set. 10 minute test, no more than 10% pressure loss. 2. Punch tubing in the middle of the first collar above the CBP. a. Fullbore: Pump diesel down the tubing while taking returns up the IA, to confirm circulating rates and pressures through tubing punch. Circulate tubing and IA to diesel. 3. Set 5-1/2” cement retainer in the joint of tubing above the tubing punch. Fullbore 1. Pumping down Tubing, establish returns up the IA and pump the following schedule: ¾ 216 bbls 15.8 ppg Class G cement ¾ Drop Retainer-ball, Foam-ball ¾ FW spacer ¾ ~200 bbls diesel ¾ Bump ball on retainer with ~500 psi excess. Slickline & Fullbore 1. Log Memory SCMT from ~9250’ MD to surface to identify TOC. 2. Conduct AOGCC witnessed MIT-T and MIT-IA to 2500 psi. Ensure 24-hour notice provided for AOGCC. Coiled Tubing 1. Mill out retainer/cement/CBP and push to TD. E-Line 1. Perform water-flow log. Well Diagnostics & WIE 1. AOGCC witnessed warm MIT-IA. 2. Update AKIMS and add biennial MIT-T’s, MIT-IAs, and WFL’s. SCMT to AOGCC for review. IA Cement Job 13-20 PTD: 182-009 Cement Calculations 9-5/8” x 5-1/2” volume from 9,329’ to 4,400’ MD 216 bbls IA Cement Job 13-20 PTD: 182-009 Current Schematic IA Cement Job 13-20 PTD: 182-009 Proposed Schematic IA Cement Job 13-20 PTD: 182-009 Proposed P&A Schematic STATE OF ALASKA iiIECEIACED ' A OIL AND GAS CONSERVATION COM^ON RE OF SUNDRY WELL OPE DEC 0 3 2011 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other AQGCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown"' Stimulate - Other ❑ Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development . Exploratory ❑ a 182 -009 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029- 20705 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028311 PBU 13 -20 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 10422 feet Plugs measured None feet true vertical 9247 feet Junk measured See Attachment feet Effective Depth measured 10362 feet Packer measured See Attachment feet true vertical 9191.57 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 83 20" 91.5# H -40 33 - 116 33 - 116 ...r.44469r" 470 Surface 2469 13 -3/8" 72# L -80 32 - 2501 32 - 2500.93 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 873 7" 29# L -80 9543 - 10416 8425.89 - 9242.31 8160 7020 Perforation depth Measured depth See Attachment feet same) 1 12013, True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment . See Attachment'''"' Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9843' - 9865', 9954' - 9980', 9990' - 10000', 10013' - 10033', 10054' - 10064', 10073' - 10083', 10092' - 10132', 10158' - 10178', 10207 - 10237' Treatment descriptions including volumes used and final pressure. 3221 Gallons EC9360A Surfactant, 15073 Gallons EC9398A Polymer, 1000 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 12018 0 1131 Subsequent to operation: 0 0 9592 0 1046 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service © Stratigraphic ❑ Daily Report of Well Operations x 16. Well Status after work: Oil ❑ Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature 10aAAt £ Phone 564 -4424 Date 11/30/2012 -f ), ,, DEC 0 1 +� !Z *rE -rU Form 10 -404 Revised 10/2012 S gifie/y Submit Original Only • • • Packers and SSV's Attachment ADL0028311 SW Name Type MD TVD Depscription 13 -20 PACKER 9329 8142.98 5 -1/2" Baker S -3 Packer 13 -20 PACKER 9505 8306.53 5 -1/2" BOT 3 -H Packer • • 13 -20 182 -009 -0 Junk Attachment SW Name MD Date Description 13 -20 10099 5/16/11 1" IBP Stiffner Ring 13 -20 10109 7/11/10 59 -1/2" Cutter Bar Casing / Tubing Attachment ADL0028311 Casing Length Size MD TVD Burst Collapse CONDUCTOR 83 20" 91.5# H -40 33 - 116 33 - 116 1490 470 LINER 873 7" 29# L -80 9543 - 10416 8425.89 - 9242.31 8160 7020 PRODUCTION 8712 9 -5/8" 47# L -80 32 - 8744 32 - 7704.78 6870 4760 PRODUCTION 1101 9 -5/8" 47# S00-95 8744 - 9845 7704.78 - 8706.75 8150 5080 SURFACE 2469 13 -3/8" 72# L -80 32 - 2501 32 - 2500.93 4930 2670 TUBING 9448 5 -1/2" 17# L -80 30 - 9478 30 - 8365.41 7740 6280 TUBING 128 4 -1/2" 12.6# N -80 9461 - _ 9589 8349.6 - 8468.69 8430 7500 • • 1 1 Perforation Attachment ADL0028311 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 13 -20 5/10/2010 BPP 9843 9844 8704.89 8705.82 13 -20 5/10/2010 APF 9844 9864 8705.82 8724.43 13 -20 5/10/2010 BPP 9864 9865 8724.43 8725.36 13 -20 7/10/2010 BPP 9954 9980 8808.38 8832.72 13 -20 7/10/2010 BPP 9990 10000 8842.1 8851.48 13 -20 7/10/2010 BPP 10013 10033 8863.68 8882.45 13 -20 7/10/2010 BPP 10054 10064 8902.16 8911.56 • 13 -20 7/10/2010 BPP 10073 10083 8920.01 8929.4 13 -20 7/10/2010 BPP 10092 10132 8937.86 8975.44 13 -20 7/10/2010 BPP 10158 10178 8999.87 9018.67 13 -20 7/10/2010 BPP 10207 10217 9045.92 9055.31 13 -20 7/10/2010 BPP 10217 10237 9055.31 9074.11 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • ` I 1I Daily Report of Well Operations ADL0028311 ACTIVITYDAT T /I /O = 1000 / 500 100 Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 10,000 bwpd. Pumped 458 gal. EC9360A (Surfactant) Average of 45.8 gph for 10 hrs. Pumped a total of 458 gal. since start of project. Pumped 1751 gal. EC9378A ( Polymer) Average of 194.5 gph for 9 hrs. Pumped a total of 1751 gal. since start of project. 11/3/2012 ** *Continued on WSR 11- 04- 2012*** T /I /O = 1000/500/50 ** *Continued WSR from 11- 03- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 10000 bwpd. Pumped 76 gal. EC9360A (Surfactant) Average of 38 gph for 24 hrs. Pumped a total of 534 gal. since start of project. Pumped 418 gal. EC9398A ( Polymer) Average of 209 gph for 24 hrs. Pumped a total of 2169 gal. since start of project. 11/4/2012 ** *Continued on WSR 11 -04- 2012 * ** T /I /O = 1000/420/50 ** *Continued WSR from 11 -04- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 10000 bwpd. Pumped 956 gal. EC9360A (Surfactant) Average of 39.8 gph for 24 hrs. Pumped a total of 2487 gal. since start of project. Pumped 4723 gal. EC9398A ( Polymer) Average of 196.8 gph for 24 hrs. Pumped a total of 11034 gal. since start of project. • 11/5/2012 ** *Continued on WSR 11 -06- 2012 * ** T /I /O = 1000/400/100 ** *Continued WSR from 11 -05- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 10000 bwpd. Pumped 734 gal. EC9360A (Surfactant) Average of 34.9 gph for 21 hrs. Pumped a total of 3221 gal. since start of project. Pumped 4039 gal. EC9398A ( Polymer) Average of 192.3 gph for 21 hrs. Pumped a total of 15073 gal. since start of project. Job Complete 11/6/2012 FWHP = 1000/450/50 SW= CLOSED SSV, WV, MV = OPEN IA, OA= OTG 125 TREE _ ' 5-1/T GRAY • 13-20 S WHEN ON H2S READINGS S AVERAGE S ACTUATOR = AXELSON SSW WELLHEAD = GRAY KB. ELEV = 84' WHEN ON ML 5-1/2" TBG LANDED WITH BKR BF. ELEV = NA SEAL ASSY 2 -3' OFF TOP OF PBR PER RWO KOP= 2800' ' CONDUCTOR, 81' HANDOVER FORM. Max Angle = 39° @ 6700' Datum IVO = 10035' 91.5 #. H-40 , Datum TVD = 8800' SS . ID = 19.124" 2076' —15 -117" CAM BAL -O SSSV NIP, ID = 4.562 I 13 -3/8" CSG, 72#, L -80 BTC, ID = 12.347" H 2501' 1 9-5/8" CSG, 47 #, S0095 XO TO L -80 BTC —1 8744' f/ 9318' H5 -1/2" HES X IMP, ID = 4.562" Minimum ID = 3.813" @ 9603' 4 -1/2" CAMCO DB -5 NIPPLE 9329' {9 -5/8" X5 -1/2" BKR S-3 PKR, 10= 4.750" 9432' H5-1/2' HES XN NIP, ID = 4.455" 15 -1/2" TBG, 17 #, L -80, .0232 bpf, ID = 4.892" 1-1 9449' I 9470' — 5-1/2" BKR SEAL ASSEMBLY w /OUT SEALS, ID = 4.875" 9487' 1 - 15 - VV7' BOT PBRASSY 1 - ' �, 9505' H8 -5 /15'X5- 1/2 " BOT 3- HPKR, ID= 4.865 "I 9517' —16-5/8" NILLOUT EXTENSION, ID = ? ??" I 9517' H6 -5/8" X 4-1/2' XO, ID = 3.958" TOP OF T' LINER H 9543' 9543' — 19 -5/8 " X 7" BOY HY D SET LNR HGR, ID = ? ?? I 9566' H7" MARKER JOINT 4-1/2" TBG, 12.6#, N-80 BTC, —{ 9615' , I 9603' — 4-112" CAM 08 -5 NIP, ID = 3.813" I .0152 bpf, ID = 3.958 1 9 -5/8" CSG, 47 #, L -80 BTC, ID = 8.681" —I 9845' 9615' H4 WLEG, ID = 3.958" PERFORATION SUMMARY REF LOG: BHCS ON 02/03/82 ' I 9602' H ELMO TT LOGGED 08/08/82 I ANGLE AT TOP PERF: 22' 9843' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9843 - 9865 0 12/26/91 3-3/8" 6 9844 - 9864 0 05/10/10 10109' HFISH - 1" IBP STIFFNER RING (058/16/11) 3-1/8" 4 9954 - 9980 0 08/08/82 3-1/8" 4 9990 - 10000 0 08/08/82 10109' H FISH - 59-12' X 1.90" GO DEVIL (07/11/10) I 3-1/8" 4 10013 - 10033 0 08/08/82 3.1/8" 4 10054 - 10064 0 08/08/82 3-1/8" 4 10073 - 10083 0 08/08/82 3-1/8" 4 10092 - 10132 C 08/08/82 3-1/8" 2 10158 - 10178 C 03/21/93 3-3/8" 2 10207 - 10217 C 03/21/93 3-3/8" 2 10217 - 10237 C 03/21/93 IPBTD — 1 10362' 1 ••4 4 4 . 4•4 I T" LNR, 29#, L - 80 BTC, .0371 bpf, ID = 6.184" I 10417' 1 i I TD H 10426' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/08/82 ORIGINAL COMPLETION 02/09/11 MB /JMD ADDED SSSV SAFETY NOTE WELL: 13-20 01/21/02 RWO 05/21/11 MILAN PJC PULL IBP/ LEFT FISH DH (5/16/11) PERMIT No: 182 -0090 04/26/10 PJC DRAWING CORRECTIONS 01/16/12 TMWJMO ADDED H2S SAFETY NOTE API No: 50- 029 - 20705 -00 05/18/10 JED/SV REPERF /SET IBP (05/11/10) SEC 14, T1 ON, R14E 2639' FM- & 131' FEL 05/18/10 WEC/SV DUMP SLUGGITS (05/12/10) 07/28/10 BSE/PJC TAG IBP- FISH (07/12/10) BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 14, 2012 TO: Jim Regg 215 it 7 ,,, P.I. Supervisor (C SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13 -20 FROM: John Crisp PRUDHOE BAY UNIT 13 -20 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprw.." NON CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT 13 - 20 API Well Number: 50 029 - 20705 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr120213134426 Permit Number: 182 - 009 - Inspection Date: 2/13/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-20 ' Type Inj. W ' TVD 8227 IA 380 2510 2470 2470 - P.T.D 1820090 ' TypeTest SPT Test psi 2056 ' OA 80 150 " 150 150 Interval 4YRTST p/F P , Tubing 1000 1000 - 1000 1000 ' Notes: 4,6 bbls pumped for test tAtiti aP M /\R h+ 7 LU FL Tuesday, February 14, 2012 Page 1 of 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS ~~G~~u~~ MAY ~ ~ 210 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Othe r ~ ~(itffllSSIU( Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ ~~ yy~~ ~~ Time Ex~lf' Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^~R(~10~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Dnll Number: Name: Development ^ Exploratory ^ 182-0090 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ ~ API Number: Anchorage, AK 99519-6612 50-029-20705-00-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028311 PBU 13-20 10. Field/Pool(s): PRUDH OE BAY FIELD / P UDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 10426 feet Plugs (measured) 9920' 5/11/10 feet true vertical 9252 feet Junk (measured) None feet Effective Depth measured 10362 feet Packer (measured) 9329 9505 true vertical 9192 feet (true vertical) 8227 8391 Casing Length Size MD TVD Burst Collapse Structural Conductor 81 20" 91.5# H-40 SURFACE - 81 SURFACE - 81 1490 470 Surface 2501 13-3/8" 72# L-80 SURFACE - 2501 SURFACE - 2501 5380 2670 Intermediate 9845 9-5/8" 47# S0095/L-8(SURFACE - 9845 SURFACE - 8707 Production Liner 874 7"29# L-80 9543 - 10417 8246 - 9241 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 SURFACE - 9449 SURFACE - 8336 6# NN=80 4-1/2" 12 9517 - 9615 8402 -8493 Packers and SSSV (type, measured and true vertical depth) . 9-5/8"X5-1/2" BKR S-3 PKR 932 'f$'~ 8227 8-5/16"X5-1/2" BOT 3-PKR 9505 8391 12. Stimulation or cement squeeze summary: Intervals treated (measured): )Cr`('sr Treatment descriptions including volumes used and final pressu re: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 14817 1257 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service ^~ Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WA~ GINJ ^ WINJ, SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ b • ' Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ~ Phone 564-4944 Date 5/13/2010 vnn iu-~ru-r i~cviacu nwua ~wVq~y i`IHI 1 Z __Q _ ••••••~•~•• •.•~~y~~~••~ ••~~~~ °/~ S'!G' !v ~ ~j~a 13-20 182-009 PERF ATTACHMENT • • Sw Name O eration Date Perf O eration Code Meas De th Top Meas Depth Base Tvd Depth Top Tvd Depth Base 13-20 8/8/82 PER 9,954. 9,980. 8,808.38 8,832.72 13-20 8/8/82 PER 9,990. 10,000. 8,842.1 8,851.48 13-20 8/8/82 PER 10,013. 10,033. 8,863.68 8,882.45 13-20 8/8/82 PER 10,054. 10,064. 8,902.16 8,911.56 13-20 8/8/82 PER 10,073. 10,083. 8,920.01 8,929.4 13-20 8/8/82 PER 10,092. 10,132. 8,937.86 8,975.44 13-20 12/26/91 APF 9,843. 9,865. 8,704.89 8,725.36 13-20 3/21/93 APF 10,217. 10,237. 9,055.31 9,074.11 13-20 3/21/93 APF 10,207. 10,217. 9,045.92 9,055.31 13-20 3/21/93 APF 10,158. 10,178. 8,999.87 9,018.67 13-20 6/19/93 BPS 9,484. 9,485. 8,371. 8,371.93 13-20 6/22/93 BPP 9,484. 9,485. 8,371. 8,371.93 13-20 3/12/94 BPS 9,480. 9,482. 8,367.27 8,369.14 13-20 3/19/94 BPP 9,480. 9,482. 8,367.27 8,369.14 13-20 3/15/97 BPS 9,550. 9,555. 8,432.4 8,437.05 13-20 4/4/97 BPP 9,550. 9,555. 8,432.4 8,437.05 13-20 4/8/97 BPS 9,519. 9,526. 8,403.56 8,410.07 13-20 5/16/97 BPP 9,519. 9,526. 8,403.56 8,410.07 13-20 10/25/97 BPS 9,519. 9,526. 8,403.56 8,410.07 13-20 10/31/97 BPP 9,519. 9,526. 8,403.56 8,410.07 13-20 1/15/98 BPS 9,526. 9,527. 8,410.07 8,411. 13-20 1/21/98 BPP 9,526. 9,527. 8,410.07 8,411. 13-20 1/3/99 BPS 9,550. 9,552. 8,432.4 8,434.26 13-20 1/5/99 BPP 9,550. 9,552. 8,432.4 8,434.26 13-20 10/17/00 BPS 9,058. 9,060. 7,979.98 7,981.77 13-20 3/18/01 BPP 9,058. 9,060. 7,979.98 7,981.77 13-20 5/23/01 BPS 9,478. 10,132. 8,365.41 8,975.44 13-20 6/15/01 BPP 9,440. 10,132. 8,330.06 8,975.44 13-20 10/7/01 BPS 9,545. 10,132. 8,427.75 8,975.44 13-20 10/15/01 SPS 9,507. 9,545. 8,392.39 8,427.75 13-20 11/7/01 BPP 9,545. 10,132. 8,427.75 8,975.44 13-20 11/15/01 BPS 9,540. 10,132. 8,423.1 8,975.44 13-20 2/24/02 BPP 9,540. 10,132. 8,423.1 8,975.44 13-20 2/24/02 BPS 10,134. 10,144. 8,977.32 8,986.72 13-20 5/8/02 BPP 10,134. 10,144. 8,977.32 8,986.72 13-20 5/10/10 APF 9,844. 9,864. 8,705.82 8,724.43 13-20 5/12/2010 SPS 9928 9954 8784.08 8808.38 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE . - ~ • 13-20 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY -'"""""' ~~*** WELL INJECTING ON ARRIVAL*** (ELINE PERF IBP) INITIAL T/I/O = 1100 / 700 / 250. PERFORATE INTERVAL 9844 - 9864 WITH 20 FT 3-3/8" 3406 POWERJET TA: PENETRATION 38.6 IN, ENTRANCE HOLE 0.45 IN, 6 SPF, 60 DEG '...PHASING, MAX SWELL IN LIQUID 3.66 IN. RIG UP IBP AND FREEZE PROTECT FLOWLINE. ***JOB IN PROGRESS AND CONTINUED ON 11 MAY 2010*** 5/10/2010 T/I/0=250/400/100 (post Perf) Freeze Protect tbg and flowline. Ice Plug in tie in Iline on manifold bldg, pressured up on plug.*"*Continued on 5-11-10 WSR*** . ~ _ ~ ~_ ~. ~ ~ __ _ __ ~ _._~W_._. _.. 5/11/2010***Continued from 05-10-10 WSR*** Freeze protect flowline and tbg from manifold bldg to well. Thawed ice plug in tie in line then pumped 160 bbls 60/40 Ito well down tbg. Final WHP=800/400/100 E-line on-well on depature 5/11/20101***CONTINUED FROM 10 MAY 2010*** STANDBY FOR LRS TO PUMP FREEZE PROTECTION FROM MANIFOLD ;BLDG. SE BAKER IBP AT 9920 FT. TIED"1N TO PERFORATION RUN. 4800# ;SHEAR RELEASE, 1-3/8" FISHING NECK. FINAL T/I/O = 250/700/250 VALVE POSITIONS ON DEPARTURE: SWAB, WING -CLOSED. ***JOB COMPLETE.*** 5/12/2010!***WELL S/I ON ARRIVAL**"* (perf) ~ LOC TT @ 9595' SLM =(+T CORR 9602' ELM). STAG BAKER IBP @ 9928' SLM (9935' ELM) W/ 3.75" LIB. DUMPED 4 BAGS SLUGGITS (-10') TOP OF SLUGGITS @ -9918' SLM ***WELL LEFT S/1 ON DEPARTURE*** ___________ FLUIDS PUMPED BBLS 162 60/40 METH 1 DIESEL 163 Total WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 84' BF. ELEV = NA KOP = 2800' 30" CONDUCTOR, -1 81' Max Angle = 39 @ 6700' Datum MD = 10035' 91.5#, H-40, Datum TV D = 8800' SS ID = 19.124" 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 2501' 9-5/8" CSG, 47#, S0095 XO TO L-80 BTC 8744' Minimum ID = 3.813" a~ 9603' 4-1i2" CAMCO DB-5 NIPPLE 5-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" I-j $449' TOP OF 7" LINER ~ 9543' 4-112" TBG, 12.6#, N-80 BTC, 9615' .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681" 9$45' PERFORATION SUMMARY REF LOG: BHCS ON 02/03/82 ANGLE AT TOP PERF: 22 @ 9843' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-318" 4 9843 - 9865 O 12/26/91 3-1/8" 4 9954 - 998x' O 08/08!82 3-1/8" 4 9990- 10000 O 08/08!82 3-1/8" 4 10013 - 10033 O 08/08!82 3-1/8" 4 10054 - 10064 O 08/08/82 3-1i8" 4 10073 - 10083 O 08/08/82 3-1/8" 4 10092 - 10132 O 08/08/82 3-i/8" 2 10158 - 10178 O 03/21/93 3-3/8" 2 10207 - 10217 O 03/21/93 3-318" 2 10217 - 10237 O 03/21/93 PBTD 10362' 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" 10417' TD 10426' DATE REV BY COMMENTS DATE REV BY COMMENTS 02/08/82 ORIGINAL COMPLETION 03/19104 PWEITLH IBP PULLED 05(08/02 01/21/02 RWO 04/26!10 PJC DRAWING CORRECTIONS 09110101 RN/TP CORRECTIONS 10/15(01 DAVTLH IBP RESET & SAND DUMP 11/15101 TMN/KAK SEf IBP 02/01102 CH(fP CORRECTIONS PRUDHOE BAY UNff WELL: 13-20 PERMIT No: 182-0090 API No: 50-029-20705-00 SEC 14, T10N, R14E 2639' FNL & 131' FEL BP Exploration {Alaska) 13 2 0 SAFE?Y : 5-112" TBG LANDED W ITH BKR ~ SEAL AS -3' OFF TOP OF PBR PER RWO HANDOVER FORM. ~. 2076' ~-i 5-1/2" CAM BAL-O SSSV NIP, ID = 4.582" 9318' I-j 5-1/2" HES X NIP, ID = 4.562" 9329' 9-5/8" X 5-1/2" BKR S-3 PKR, ID = 4.750" 9432' 5-112" HES XN NIP, ID = 4.455" 9470' 1~5-112" BKR SEAL ASSEMBLY I w JOUT SEALS, ID = 4.875" 9487' S-1/2" BOT PBR ASSY 9505' 8-5/16" X 5-112" BOT 3-H PKR, ID = 4.865" 9517' 6-518" MILLOUT EXTENSION, ID = ???" 9517' -~6--518" X 4-112" XO, ID = 3.958" 9543' 9-5/8" X 7" BOY HY D SET LNR HGR, ID = ??? 9566' 7" MARKER JOINT 9603' 4-1/2" CAM DB-5 LANDING NIP, ID = 3.813" 9~ 615' I-14-1(2" WLEG, ID = 3.958" i 9602' ELMD TT LOGGED 08!08/82 181° e~t9,~~ Mn `~ _ ~~. PrtoAcrivE Dinqnosric SeavicES, Inic. ~~LL L[7~ T~~4~StVlf7?"~L To: A~C Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99~01 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing 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 folfowing : BP Exploration (Alaska), Inc. P~trotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~~~~~ PraActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~ ~ Anchorage, AK 99518 Fa~c (907j 245-8952 1 J Injection Profile 10 Aug-09 13-20 BL / EDE 50-029-20705-00 z~ ~~ i' ~~ % ,; Signed : ~ Print Name: PROACTIVE DiAGNOSTIC SERV~CES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAQE, AK 99578 PHONE: (907)245-8951 Fax: (90T)245-88952 E-MAIL ' _~~~-~~" r~,~~ WEBStTE: ~ ~. ~ ~~~ CSS~ -OJ~ C:lDocumen~s and Settings\Owner!Desktop\Transmit_BP.docx MEMORANDUM TO: FROM: Jim Regg ~ P.I. Supervisor ~\~1~0/ ~ ~2-J~C;L%; Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 07, 2008 SUBJECT: MechanicalInteg~ityTests BP EXPLORATION (ALASK 1) INC 13-20 PRUDHOE BAY U'N'IT 13-20 Src: Inspector NON-CONFIDENTIAL Reviewed Bv- P.I. Suprv ~j~.l= Comm Well Name PRUDHOE BAY UNIT 13-20 Insp Num: micRCN080305080500 Rel Insp Num: API Well Number: 50-029-20705-00-00 Permit Number: 182-009-0 Inspector Name: Bob Noble Inspection Date: 3i2~2008 Packer Depth Pretest Initial 15 Min. 30 Min. 451VTin. 60 Min. 13-20 ; W Well Type Inj.. I TVD ~ 8226 40 4000 ~ ~ TA - , - - T --~--~- - - 3980 3970 -- --- -----~----T- P.T '~ t8zoo9o 'TypeTest ' sPT Test psi ^ 4000 OA ~ o j too ~ took too __~~ _ Interval 4YRTST p~F• P _ __ ,/ Tubing I, uoo t too t too t too Notes: ~ MAY ~ ~ 200 Friday, March 07, 2008 Pale l of 1 MIT Forms for 13-20 (PTD #1820) and X-20A (PTD #2071130) Page 1 of 2 Regg, James B DOA • From: Regg, James B (DOA) Sent: Thursday, March 27, 2008 10:15 AM ~~,e'~ ~~~ ~ ~ ~ To: 'NSU, ADW Well Integrity Engineer' ` Subject: RE: MIT Forms for 13-20 (PTD #1820090 and X-20A (PTD #2071130) ~- Thankyou for checking; I selected wrong packer. Our calculations agree with yours. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Wednesday, March 26, 2008 3:49 PM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: RE: MIT Forms for 13-20 (PTD #1820090) and X-20A (PTD #2071130) Jim, All of our data indicates the packer depth to be 8227` TVt}. The submitted MIT form listed packer TV as 8226° which was a rounding error. !have attached the most recent 10-404 for your reference. Thank you, Andrea Hughes -w 0'R HC [1 ~ ~ L~U~ From: Regg, James B (DOA) [maiito:jim.regg@alaska.gov] Sent: Friday, March 07, 2008 9:33 AM To: NSU, ADW Well Integrity Engineer; Fleckenstein, Robert J (DOA) Cc: NSU, ADW WI Tech; DOA AOGCC Prudhoe Bay Subject: RE: MIT Forms for 13-20 (PTD #1820090) and X-20A (PTD #2071130) Please verify the Packer TVD for PBU 13-20. Based on data in our files, we calculate TVD to be 8383 ft. No problem with the test pressure. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phane: 907-793-1236 fax: 907-276-7542 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Thursday, March 06, 2008 8:43 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: NSU, ADW WI Tech; NSU, ADW Well Integrity Engineer Subject: MIT Forms for 13-20 (PTD #1820090) and X-20A (PTD #2071130) 3/27/2008 MIT Forms for 13-20 (PTD #1820) and X-ZOA (PTD #2071130) Page 2 of 2 Jim; Tom and Bob, Please see the attached MIT forms for the passing MITIAs on 13-20 and X-20A. Both tests were witnessed by Bob Noble. «MlT PBU 13-20 03-02-08.x1s» «MIT PBU X-20A 03-02-08.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/27/2008 ( ( MEMORANDUM State of Alaska TO: Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, March 10,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-20 PRUDHOE BAY UNIT 13-20 THRU: Jim Regg í<;'¿4C1 3{'5104~ P.I. SupervisQr ( t Src: Inspector NON-CONFIDENTIAL I API Well Numbe 50-029-20705-00-00 InspN mitCS040305154127 Inspection Date: 3/5/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 13-20 Type Ioj. P TVD 8226 IA 50 4000 3960 3960 P.T. 1820090 TypeTest SPT Test psi 2056.5 OA 250 620 620 620 Interval Other (describe in P/F Pass Tu bing 1180 1180 1180 1180 -nJ'\f1'i~ I Notes: Pre Wag swap MIT. Pretest pressures observed and found stable. Type INJ. Fluid Codes F ==FRESH WATER INJ. G==GAS INJ. S==SALT WATER INJ. N==NOT INÆCTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=Internal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test Interval l==Initial Test 4=Four Year Cycle. V=Required by Variance W=Test during Work over O=Other (describe in notes) Wednesday, March 10,2004 Page 1 of 1 ~(ÇA\!~NE[) MAH 1 frl 2004 Re: FW: 13-20 (PTD 1820090), Cancel Sundry #397-078 Subject: Re: FW: 13-20 (PTD 1820{190), Cancel Sundry #397-078 Date: Mon, 20 May 2002 11:34:18 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "NSU, ADW Well Integrity Engineer'' <NSUADWWelllntegrityEngineer@BP.com> Joe, Thanks for the edit. Your request is appropriate since the tubing has been repaired and the well will now pass a normal MIT. You may put this well back on the normal 4 year schedule. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hello Tom. Please note them is a typo in the note below. Injection actually started on 5/10/02, not 2/11/02. Thanks! Joe ..... Original Message ..... From: NSU, ADW Well Integrity Engineer Sent: Saturday, May 18, 2002 4:22 PM To: AOGCC Tom Maunder (E-mail) Subject: 13-20 (PTD 1820090), Cancel Sundry #397-078 Hello Tom. We request Sundry #397-078 for well 13-20 (PTD 1820090) be canceled. Dudng 01/02, the tubing was replaced. Injection started 02/11/02 5/10/02 and an AOGCC MITIA passed on 05/16/02. Recent events: > 01/21/02: RWO complete, tubing replaced. > 05/10/02: Injection started. > 05/16/02: MITIA passed, AOGCC witnessed. Unless advised differently, we will cease sundry compliance testing and retum the well to a 4-year MITIA schedule. Attached is the updated we//bore schematic. Please call if you have any questions. <<13-20. ZIP>> Thanks! Joe Joe Anders, P.E. /Kevin Yeager Well Integrity Engineer BP Exploration, (Alaska) Inc. (907) 659-5102 em aih N S UA D WWelll ntegrityEngineer~ bp. com Name: 13-20. ZIP 1 of 2 5/20/02 11:45 AM Re: FW: 13-20 (PTD 1820090), Cancel Sundry #397-078 > 13-20. ZIP Type: Zip Compressed Data (application/x-zip-compressed) > Encoding: base64 Tom Maunder <tom maunder(~.admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of 2 5/20102 11:45 AM · , 'IREE: 5-1/8" ~¥ , /~,, .~ SAFETY NOTEB: 5-1/2" TBG LANDED ' ,W~'HEAD~ , GRAY 13 20 WITH BKR SEAL ASSY 2-3' OFF TOP OF ACTUATOR = AXB.SON ~ PBR PER RWO HANDOV ER FORM. a:. a. EV: NA -- -- '"']'----"-- '-- '"1 ' .O~=x ~" ~oo.~°°' I H~ Ma?An- 2076' -1/2; C^M BAL-O SSSV I~P, ID = 4.562" Datum ~D = ' , .10035, m, tumWD= ," 0000~,, Minimum ID = a.~aa BTMOF'I~KR SF_~'LA'SSY 'W/o SF_AI..~,D '-4.~ ~ 9470' ] ~ ~ BOT.F~,R^$SY ] ~ 9505' J--~9-5/8"X5-1/2"BOT3-H~R, ID=4J,85" t..gs~' H~.,~. x,.~,~.xo{0~,~ ~m I I.-~;~- x i-.oT u...o. ~. I;::a - I ----I 9533'elm, . , I PERFORATION SUlVlVlARY REF LOG: BHCS ON 02103182 ANGLE AT TOPPERF: 22 @ 9843' Note: Refer to Production DB for histo, rical perf data SIZE SPF INTERVAL om/sm,,_ DATE I 3-318" ~ 9843-~865 O 12/26/91 ! I 3- 4/8" 4 9954-9980 O 08/08/82 3-1/8" 4 9990-10000 O 08/08/82 3-1/8" 4 10013-10033 O 08/08/82 3-1/8" 4 10054-10064 O 08/08/82 I 3-1/8" 4 10073-10083 ' O 08/08/82 3-118" 4 10092-10132 O 08/08/82 ~ 3-1/8" 2 10158-10178 O 03/21193 3-3/8" 2 10207-10217 O 03/21/93 3-3/8".! 2 ~ 10217-10237 O 03/21/93 , , , ! , . ~, ~o~a~" I,, · I", mTE REV BY COMIVENTS' ' DAntE I~ BY' '' ,COMIVENTS PRUDHOEBAY UNIT 02/08/82 oRIGINAL cOMpLETION' 11/15~01 TMN,~AK SET BP WELL: 13-20 '10/17/00 JLM INSERTED ~Bp 01/21/02' ' RWO ' ' PERI~r No: 182-0090 '01/16/01 $IS-CL FINAL ' ' 0;~/01/02 cHrI-P (~RI~cTIONS ' ' APl No: 50-029-20705-00 '~39/10/01 RNfTP CO~REC'flONS ...... SEC 14, T10N, R14E 2EG9'FNL& 131'EEL i 10/'~5/01 'DAV~Ih IBPRESET&SAI~) DUIVP ...... BP Expl°rallon (Alaska) , , SIZE SPF INTERVAL Om/Sqz, ,~ 3-3/8" ~ 9843-~865 O 1 2/26/91 3-4/8" 4 9954-998O O O8/O8/82 3-1/8" 4 9990-10000 O 08/08/82 3-1/8" 4 10013-10033 O 08/08/82 3-4/8- 4 40054-400s4 0 os/os/s2 3-1/8" 4 10073-10083 O 08/08/82 3-1/8" 4 10092-10132 O 08/08/82 3-1/8" 2 10158-10178 O 03/21/93 3-3/8" 2 10207-10217 O 03/21/93 3-3/8" 2 10217-10237 O 03/21/93 , , , ~ " DATE REV BY COMIVENTS' DAntE I;~-VBY' ' COMIVENTS 02/08/82 oRIGINAL COMpLETION' 11/15~01 TMN,~AK SET BP ' ' '10/17/00 JLM INSERTED ~BP 01/21/02 ' RWO ' ' '01/16/01 SIS-O- FINAL ' ' 0;~/01/02 cHrrP ddRI~cTDNS " i b~0/o4 R,rm cO~EC~Om ..... 10/"15/01 'DAV~lh IBPRESET & sam Du~P' ' ' ,,---,, STATE OF ALASKA ALASKA _ AND GAS CONSERVATION COMM, .,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: ~ ~rl-Operation Shutdown I-I Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Convert to WAG Injector 2. NameiofOPeratOr~' ' 5. Type of well: 6. Datum Elevation (DF or KB) BP EXplorations(Alaska) Inc. [] Development RKB = 84' 3. Address ' [] Exploratory 7. Unit or Property Name · - .. [] Stratigraphic Prudhoe Bay Unit P.O. BOx 196612, Anchorage, Alaska 99519-6612 I~! Service z~. Location of well at surface 8. Well Number 2638' SNL, 130' WEL, SEC. 14, T10N, R14E, UM 13-20i At top of productive interval 9. Permit Number / Approval No. 182-009 301-261 197' NSL, 2369'EWL, SEC. 12, T10N, R14E, UM 10. APl Number At effective depth 50-029-20705-00 106' NSL; 2248~'EWL, SEC. 12, T10N, R14E, UM 11. Field and Pool At totaldepth~- Prudhoe Bay Field / Prudhoe Bay 303' NSL, 2496' EWL, SEC. 12, T10N, R14E, UM Pool 12. PresentWell condition Summary Total depth: measured 10426 feet Plugs (measured) Baker IBP at 9533' (11/2001) true vertical 9252 feet Effective depth: measured 9533 feet Junk (measured) · · true vertical 8417 feet Casing Length Size Cemented M D TVD struCtural Conductor 81' 20" 440 sx Arcticset II 81' 81' Surface 2501' 13-3/8" 2400 sx Fondu, 400 sx Permafrost 2501' 2501' Intermediate 9845' 9-5/8" 500 sx Class 'G' 9845' 8707' Production 871' 7" 350 sx Class 'G' 9543' - 10414' 8426' - 9240' Liner Perforation depth: measured 9843'- 9865', 9954' - 9980', 9990' - 10000', 10013' - 10033', 10054' - 10064', 10073' - 10083', · 10092'- 10132', 10158'- 10178', 10207'- 10237' true vertical 8705' - 8725', 8808'- 8833', 8842' - 8851', 8864' - 8882', 8902' - 8912', 8920' - 8929', 8938' - 8975', 9000'- 9019', 9046'- 9074' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 9470'; 4-1/2", 12.6#, N-80 from 9487' to 9615' Packers and SSSV (type and measured depth) Baker '3-H' packer at 9505'; Baker 'S-3' packer at 9329'; Camco 'BaI-O' SSSV Nipple atl 2076' ~1~'~' i~/~ r, 13. Stimulation or cement squeeze summary Intervals treated (measured) MAR 0 Treatment description including volumes used and final pressure Alaska 0ii & Gas Cons. Commission Anchorage , 14. Representative Daily Avera,qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments .... 16. status of well classifications as: I"1 Copies of Logs and Surveys run [] Oil [] Gas !-! Suspended Service WAG Injector [] Daily Report of Well Operations 17. I hereby certify that the for.egoing is true and correct to the best of my knowledge TerrieHubble '~.' ~ Technical Assistant Signed ~ .. _ Title Date Prepared By Name/Number: Terrle Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplica'te.. Well: 13-20 Rig Accept: 01/13/02 Field: Prudhoe Bay Unit Rig Spud: N/A APl: 50-029-20705-00 Rig Release: 01/21/02 Permit: 182-009 Drilling Rig: Doyon 16 PRE-RIG WORK 10/01/01 MITOA PASSED/PPPOT-IC PASSED (PRE-RWO) 10/06101 ATTEMPTED TO SET 2-1/2" IBP, UNABLE TO GET THRU PATCH @ 9072'. SWAPPED TO 2-1/8" IBP AND STILL COULDN'T GET THRU. PULLED OFF WELL, WILL HAVE POINTED BOTTOM NOSE MADE AND ATTEMPT AGAIN TOMORROW. 10/07/01 SET NON-RETRIEVABLE 2-1/2" IBP @ 9546' W/CENTER OF ELEMENT @ 9550'. 10/14/01 DUMPED BAILED ONE LOAD OF SLUGGETS ON TOP OF IBP @ 9515' SLM. 10/15/01 DUMP BAIL 8' OF SLUGGITS (2 FULL BAGS) ON TOP OF IBP FROM 9515' SLM TO 9507' SLM. WELL LEFT SI. 10/23/01 RAN 10 X 2-1/2" PUMP BAILER & BAILED 2 1/2 GALLONS OF SLUGGIT FROM TOP OF IBP @ 9502' WLM. 10/24/01 BALLED SLUGGETS OFF I.B.P. ATTEMPTED TO DEFLATE I.B.P. W/SPEAR, COULD NOT GET PAST TBG PATCH. RAN LIB, GOOD IMPRESSION OF I.B.P. FISH NECK. HAVING TOOL BUILT TO PUNCTURE RUBBER ELEMENT OF I.B.P. 10/26/01 ATTEMPTED TO PUNCTURE I.B.P. UNABLE TO DRIVE THE SPEAR THROUGH TO REACH THE IBP RUBBER ELEMENT. 10/29/01 MIRU DS CTU #3. RIH WITH 2" DOWN JET NOZZLE. JET 5 BBLS ACID FROM 9524 TO 9543' CTD & BACK. LET ACID SIT 1 HR. JET REMAINING 5 BBLS ON IBP AT 9543' CTD. LET ACID SIT 1 HR. JET 30 BBLS 1% XSL KCL OUT NZL ON IBP, POOH CHASING RETURNS AT 80%. FP W/63 BBLS 60/40 MW. I 0/30101 RU SLICKLINE. RIH W/3" GR. 10131/01 ATTEMPTED TO PUNCTURE & PULL BAG ON IBP. ONLY ABLE TO GET SPEAR TO GO 18" DOWN @ 9515' SLM. 11/02/01 RAN 55" DECENTRALIZED SPEAR TO IBP @ 9517' SLM. RAN 2.95" TWO POINTED SLEEVE TO 9516' SLM. TT PINS UNTOUCHED. IMPRESSION OF F.N. ON TOP OF SLEEVE MULESHOE (F.N. APPEARS TO BE UP AGAINST HIGH SIDE OF TBG). 11/03101 MADE SEVERAL ATTEMPTS AT PUNCTURING BAG OF IBP (IN PROGRESS). 13-20, Rig Workover, 01/13/02 /21/02 Page 2 11/04101 MADE SEVERAL ATTEMPTS AT PUNCTURING IBP BAG (IN PROGRESS). 11/05101 ATTEMPT TO PUNCTURE BAG ON NON-RETRIEVABLE IBP. 11/06101 PUNCTURED BAG ON NON-RETRIEVABLE IBP. FISH IBP FROM 10,123' SLM (IN PROGRESS). 11/07/01 PULLED NON-RETRIEVABLE IBP (RECOVERED BOTH ELEMENTS). DRIFT TO TOP OF PATCH W/4.5" CENTRALIZER. RDMO. 11/15/01 SET BAKER IBP @ 9540' ELM (CENTER OF ELEMENT). IBP OAL = 11.05', FN = 1.375'. TAG TOP OF IBP @ 9533'. RDMO. 11/20101 TAG IBP @ 9514' WLMD. -- DUMP 50 LBS OF SLUGGITS. ( THREE 2.25" BAILER TRIPS ) -- FINAL DEPTH 9512' WLMD. 12/06/01 FUNCTION TESTED TUBING LDS - ALL GOOD 12/08/01 CUT TUBING @ 9020' ELM (MIDDLE OF FIRST FULL JOINT ABOVE TBG PATCH). GOOD CUT INDICATION. 1 2/1 2/01 CIRC OUT: PUMP 5 BBLS OF METH SPEAR, FOLLOWED BY 580 BBLS OF SEAWATER, FOLLOWED BY 170 BBLS DIESEL DOWN TBG TAKING RETURNS UP IA AND TO WELL 13-01, SHUT DOWN AND U-TUBE FOR 2 HRS. FREEZE PROTECT AND BLEED T, IA, & OA PRESSURES TO 0 PSI. WELL READY FOR BPV. NOTIFY PAD OPERATOR OF STATUS. RDMO. Legal Well Name: 13-20 Common Well Name: 13-20i Spud Date: 11/30/2001 Event Name: REPAIR Start: 1/22/2002 End: 1/21/2001 Contractor Name: Rig Release: Rig Name: Rig Number: 1/12/2002 22:00- 00:00 2.00 MOB P DECOMP MOVED IN FROM 13-18 1/13/2002 00:00 - 01:00 1.00 MOB P DECOMP FINSIH MIRU 01:00 - 02:00 1.00 WHSUR P DECOMP TAKE ON SEA WATER, RIG UP CIRCULATING HOSE RIG ACCEPTED AT 0100 HOURS 02:00- 02:30 0.50 WHSUR P DECOMP PULLED BPV 02:30 - 04:00 1.50 WHSUR P DECOMP DISPLACED OUT FREEZE PROTECTION WITH SEA WATER 04:00 - 04:30 0.50 WHSUR P DECOMP BLOW DOWN HOSES AND CLEAR CELLAR 04:30- 05:00 0.50 WHSUR P DECOMP SET BPV 05:00 - 06:30 1.50 WHSUR P DECOMP NIPPLE DOWN XMAS TREE 06:30 - 15:00 8.50 BOPSUI;.P DECOMP NIPPLED UP 13 5/8" BOPE 15:00 - 22:00 7.00 BOPSUI~.P DECOMP PRESSURE TESTED BOPE 250 PSI LOW AND 3500 PSI HIGH ( UNABLE TO TEST LOWER PIPE RAMS AND BLIND/SHEAR RAMS, WILL TEST AFTER POOH WITH TUBING ) 22:00 - 23:00 1.00 BOPSUI; P DECOMP PULLED BPV 23:00 - 00:00 1.00 BOPSUIq P DECOMP UNSCREW HANGER HOLD DOWN SCREWS, REMOVE SSSV CONTROL LINE STINGERS FROM HANGER AT REPORT TIME 1/14/2002 00:00 - 00:30 0.50 BOPSUIq P DECOMP BACKED OUT HANGER LOCK DOWN SCREWS 00:30 - 01:30 1.00 PULL P DECOMP UNLAND HANGER ( PULLED 175,000 AND HEATED HANGER BOWL TO FREE ) PULLED 218,000 TO FREE TUBING 01:30 - 04:00 2.50 PULL P DECOMP PUMPED BOTTOMS UP PLUS ONE FULL HOLE VOLUME TO CLEAR OUT GAS 04:00 - 04:30 0.50 PULL P DECOMP OBSERVED WELL DEAD 15 MIN, BROKE OUT HANGER 04:30 - 08:30 4.00 PULL P DECOMP POOH WITH 5 1/2" TBG AND SSSV TO JOINT # 51 ( SPOOLED UP CONTROL LINE ) ( RECOVERED 25 CLAMPS AND 3 BANDS ) PROGRAM LOGGED 27 CLAMPS AND 4 BANDS ) 08:30 - 16:00 7.50 PULL P DECOMP CONTINUE POOH WITH 5 1/2" COMPLETION STRING TO JOINT # 230 16:00 - 16:30 0.50 PULL P DECOMP PULLED JOINT # 231, TBG PATCH IN THIS JOINT STICKING UP 16:30 - 18:00 1.50 PULL ~ DECOMP WAIT ON TUBING MECHANICAL CUTTER 18:00- 18:30 0.50 PULL ~ DECOMP CUTTUBING PATCH 18:30 - 19:00 0.50 PULL 3 DECOMP CONTINUE POOH WITH ALL COMPLETION STRING INCLUDING SEAL ASSEMBLY 19:00 - 19:30 0.50 PULL 3 DECOMP RIGGED DOWN TUBING EQUIPMENT 19:30 - 21:00 1.50 BOPSUIq ~ DECOMP SET TEST PLUG, PRESSURE TEST LOWER PIPE RAMS AND BLIND/SHEAR RAMS TO 250 LOW PSI AND 3500 PSI HIGH PRESSURE 21:00 - 21:30 0.50 BOPSUR P DECOMP PULLED TEST PLUG, SET WEAR BUSHING 21:30 - 00:00 2.50 CLEAN P DECOMP MADE UP 8 1/2" BIT/9 5/8" SCRAPER BHA, RIH PICKING UP 3 1/2" DRILL PIPE FROM SHED 1/15/2002 00:00 - 09:30 9.50 CLEAN P DECOMP CONTINUE TO P/U 3 1/2" DP & RIH W/BIT & SCRAPER, TAG @ 9425'. 09:30 - 10:30 1.00 CLEAN P DECOMP KELLY UP & WASH DOWN TO 9476', TAG SEAL RECEPTACLE. 10:30 - 13:00 2.50 CLEAN P DECOMP PUMP & CIRCULATE 50 BBL HI VIS SWEEP AROUND. 13:00 - 18:30 5.50 CLEAN P DECOMP POOH W/BIT/SCRAPER. TIGHT F/9461'-9400', WORK AREA TILL SMOOTH. TIGHT ALSO (~ 360', 240' & 27'. WEAR RING CAME UP W/SCRAPER..(GRAY). Printed: 1129/2002 8:17:27 AM Legal Well Name: 13-20 Common Well Name: 13-20i Spud Date: 11/30/2001 Event Name: REPAIR Start: 1 ~22~2002 End: 1/21/2001 Contractor Name: Rig Release: Rig Name: Rig Number: 1/15/2002 18:30 - 19:30 1.00 CLEAN P DECOMP CLEAR FLOOR AREA, INSPECT WEAR BUSHING & RE SET, OK. 19:30 - 21:00 1.50 CLEAN P DECOMP P/U 8 1/2" STRING MILLTO DRIFT/REAM SHALLOW TIGHT SPOTS. KELLY UP ON BHA & RIH TO 40', NO SIGN OF TIGHTNESS. RIH TO 877', SMOOTH. 21:00- 22:30 1.50 CLEAN P DECOMP POOH & LD DCs & BHA. 22:30-23:00 0.50 CLEAN P DECOMP M/U RTTS. 23:00 - 00:00 1.00 CLEAN P DECOMP RIH W/RTTS ON 3 1/2" DP. 1/16/2002 00:00 - 01:00 1.00 REST P DECOMP i PJSM. SET RTTS. PJU & TEST 9 5/8" CASING F/1475' TO SURFACE, 3000 PSI/30 MINUTES, CHARTED, OK. 01:00 - 06:00 5.00 REST P DECOMP 'RELEASE RTTS & RIH TO 9453'. TOOK WEIGHT, (5-7K), F/ 9422'-9455'. NO OVERPULLS. 142K UP WT, 113K DOWN. 06:00 - 07:30 1.50 REST P DECOMP CIRCULATE PRIOR TO TESTING. PACKED OFF INITIALLY, P/U 10', ESTABLISH CIRCULATION & RIH BACK TO 9453', CIRCULATE 15 BBLS, OK. SET RTTS. PJSM. TEST 9 5/8" CASING F/9453' TO SURFACE @ 3000 PSI/30 MINUTES, OK. MONITOR 13 3/8" x 9 5/8" ANNULUS, NO INCREASE IN PRESSURE THROUGHOUT TEST. CHARTED. BLEED OFF & RELEASE RTTS. 07:30- 09:30 2.00 REST P DECOMP CIRCULATE BTMS UP. 09:30 - 18:30 9.00 REST P DECOMP POOH LAYING DOWN DP. BREAK KELLY F/IMPENDING MOVE. 18:30 - 19:00 0.50 REST P DECOMP L/D RTTS. NOTED A GOODLY AMOUNT OF PARAFIN ON ELEMENT & AROUND PORTS, NO DOUBT FROM AREA OF 9422'-9453'. 19:00 - 19:30 0.50 REST P COMP PULL WEAR BUSHING. 19:30 - 21:00 1.50 RUNCOI~ COMP RIG UP FLOOR TO RUN TUBING, TONGS & GATORHAWKS. 21:00 - 21:30 0.50 RUNCOI~ COMP PJSM ON RUNNING TUBING W/GATORHAWKS. REVIEW i PROPER TORQUES. EMPHASIS ON HAND PLACEMENT. 21:30 - 00:00 2.50 RUNCOI~ COMP P/U & RIH W/JEWELRY & 5 1/2" COMPLETION STRING AS PER PROGRAM. 1/17/2002 00:00 - 15:00 15.00 RUNCOI~P COMP CONTINUE TO RIH W/5 1/2", SLHC, 17#, L-80 TBG, TORQUE TURNING & GATORHAWKING EACH CONNECTION. LAID DOWN JTS # 51 & #111 DUE TO GATOR HAWK TEST FAILURE ON LOWER HALF OF EACH CONNECTION, (THREADS DAMAGED AT THE MILL). 15:00 - 16:00 1.00 RUNCO~ P COMP P/U CAMCO SSSV & M/U CONTROL LINE, TEST TO 5000 PSI, OK. 16:00 - 21:30 5.50 RUNCO~ COMP CONTINUE IN HOLE W/COMPLETION STRING & CONTROL LINE. 21:30 - 00:00 2.50 RUNCOI~ COMP P/U JOINT # 227 & RIH, TAG @ 9475'. 125K DOWN w-r, 160K UP. RIG UP TO CIRCULATE 150 DEGREE WATER W/ CORROSION INHIBITOR & CIRCULATE SAME @ 3 BPM, 250 PSI SPP. ATTEMPT TO STAB INTO TOP OF PBR AFTER CIRCULATING TUBING VOLUME PLUS 50 BBLS. TAGGING UP W/MULE SHOE @ 9475'. WORK PIPE W/ CIRCULATING. 111812002 00:00 - 04:00 4.00 RUNCOI~ COMP CONTINUE CIRCULATING 140 DEG SEAWATER W/ CORROSION INHIBITOR. A'I-FEMPT TO GET DEEPER IN PBR DURING CIRCULATION. ACHIEVE MAX DEPTH OF 9477' W/50K SLACKED OFF ON STRING. 160K UP WT, 125K DOWN. APPEARS TO BE TAGGING UP @ 9474 +/- Printed: 1/29/2002 8:17:27 AM Legal Well Name: 13-20 Common Well Name: 13-20i Spud Date: 11130/2001 Event Name: REPAIR Start: 1/22/2002 End: 1/21/2001 Contractor Name: Rig Release: Rig Name: Rig Number: 1/18/2002 00:00 - 04:00 4.00 RUNCOI~P COMP AND POPPING INTO TOP OF PBR WlHT CORRESPONDING INCREASE IN PUMP PRESSURE. 04:00 - 06:30 2.50 RUNCO~ I~1 DPRB COMP CALL OUT SLICKLINE & SPACE OUT TO LAND COMPLETION STRING. TAGGED UP 21' IN ON JT # 227. #226 IS 41.46', PULL SAME. RKB IS 21.27', TBG HANGER & PUPS = 4.43'. P/U 37' OF SPACE OUT PUPS. TORQUE TURN & GATOR HAWK. 06:30 - 09:30 3.00 RUNCOP~I DPRB COMP CHECK SPACE OUT, CHECK TUBING TALLY, SPACE OUT W/(2) PUPS, 7.89' & 5.78' ON TOP OF JT # 224, P/U JT # 225 & 226 & MIU PUPS TO R/U SLICKLINE. 09:30 - 15:00 5.50 RUNCOI~I DPRB COMP RIG UP SLICK LINE. RIH & PULL SSSV DUMMY @ 2080', OK. RIH & PULL RHC SLEEVE @ 9467', OK. RIH W/3" BAILER @ TAG UP @ 9453', POOH W/BAILER FULL OF PARAFIN/SLUG-IT, 2-3 GALLONS. 15:00 - 22:00 7.00 RUNCOI~I~I DPRB COMP ATTEMPT TO WASH DOWN, GET MULE SHOE TO MAX DEPTH OF 9475', APPROXIMATELY SAME DEPTH AS WE WERE AT @ 0600 HRS. TAGGING UP W/20' OF PUPS ON TOP OF JT # 226. PRESSURING UP, P/U & WASH DOWN SLOWLY TO CLF_AN UP. STACK 30K & PICK UP, CLOSE BAG & REVERSE OUT (1) TUBING VOLUME @ 3.5 BPM/250 PSI. VERY DARK, BUT NOT MUCH IN THE WAY OF SOLIDS BACK. REPEAT PROCESS. 22:00 - 00:00 2.00 RUNCOItI~I DPRB COMP R/U SLICKLINE & RIH W/3" BAILER. 1/19/2002 00:00 - 01:00 1.00 RUNCOItlXl DPRB COMP RIH W/3" BAILER, TAG UP @ 9318', BAILER FULL. RECOVERED PARAFIN/SLUG-IT, 2-3 GALLONS. 01:00 - 03:00 2.00 RUNCO~ I~1 I DPRB COMP STACK OUT ON FILL IN PBR, SET DOWN 30K @ 9476'. RIG UP & REVERSE CIRCULATE, 4 BPM @ 250 PSI. PUMP 1000 STKS & STACK OUT AGAIN @ 9476' W/30K SETTING DOWN, PICK UP & CONTINUE REVERSE CIRCULATING. AT BTTMS UP SEE DARK DISCOLORATION, BUT NO SIGNIFICANT AMOUNT OF SOLIDS, SOME FINE SILT. 03:00 - 15:00 12.00 RUNCOI~I DPRB COMP MIX & PUMP 20 BBLS HI VIS SWEEP FOLLOWED BY 25 BBLS SEAWATER W/(4) DRUMS BARASCRUB, FOLLOWED BY 20 BBLS SEAWATER W/(1) DRUM DIRT MAGNET, FOLLOWED BY 30 BBLS HI VIS SWEEP. PUMP AROUND THE LONG WAY, SLOWING PUMP DOWN WHEN BARASCRUB PILL IS IN LAST 500' OF TUBING TAIL & COMING BACK AROUND, THEN BRINGING PUMP BACK UP TO 3-4 BPM, (MAX RATE W/PACKER), WHEN SWEEP IS COMING BACK UP. 15:00 - 20:00 5.00 RUNCOItl~I DPRB COMP MAKE (3) BAILER RUNS W/3" BAILER, TAG @ 9484', 9487', & 9490'. BAILER 2-3 GALLONS EACH RUN & PART OF (1) STAINLESS STEEL BAND. 20:00 - 21:00 1.00 RUNCOI~I~I DPRB COMP PULL OUT OF PBR, (PULLING HEAVY), 25-50K OVERPULLS. PRESSURE UP TUBING TO 300 PSI & PULL FREE. BRING ON PUMP @ 3 BPM/250 PSI & WASH DOWN, SEE PRESSURE INCREASE @ 9474', SHUT DOWN PUMP & OPEN BLEEDER VALVE, RIH TO 9477' BEFORE TAKING ANY WEIGHT. STACK 15K. PICK UP, OVERPULL TO 220L, (70K OVER), WORK PIPE W/300 PSI ON TUBING, WORK FREE. PICK UP & CIRCULATE ABOVE PBR. 21:00 - 23:00 2.00 RUNCOI~I DPRB COMP RIH W/3" BAILER & CONSULT W/TOWN. OPT TO SPACE OUT & LAND HERE. BAILER MADE IT DOWN TO 9485' & Printed: 112912002 8:17:27 AM Legal Well Name: 13-20 Common Well Name: 13-20i Spud Date: 11/30/2001 Event Name: REPAIR Start: 1/22/2002 End: 112112001 Contractor Name: Rig Release: Rig Name: Rig Number: 1/19/2002 21:00 - 23:00 2.00 RUNCOI~ DPRB COMP CAME BACK W/1-2 GALLONS OF SAME STUFF, (PARAFIN/SLUG-IT). 23:00 - 00:00 1.00 RUNCOI~I DPRB COMP SLACK OFF TO SPACE OUT, TAG @ 9474', PICK UP HEAVY, PRESSURE TUBING TO FREE UP. APPEARS AS IF PACKER ELEMENT MAY BE DRAGGING. MAY HAVE SOLIDS ON TOP OF PACKER AS WE PULL FREE EVERY TIME WE KICK ON THE PUMP & PULL HEAVY, (30-50K), WITH IT OFF. KEEPING PUMP PRESSURE BELOW 400 PSI DURING ALL PUMPING OPS. ATTEMPT TO GET DEEPER THAN 9475, PUMP ON, PUMP OFF, ROTATE (3) TURNS, GET (1) BACK & TRY AGAIN, NO GOOD, STACKING OUT @ 9473' NOW. OBVIOUSLY JUNK/FILL IN WELLBORE. 112012002 00:00 - 01:00 1.00 RUNCOI~I~I DPRB COMP CONSULT TOWN. OPT TO MIX & PUMP SWEEPS & CLEANOUT PILL & LAND TUBING AS DEEP AS IT WILL GO. 01:00 - 05:00 4.00 RUNCOI~I~I DPRB COMP MIX SWEEPS & PILLS. RIH W/SLICKLINE & SET RHC i SLEEVE @ 9445' WLM. RIH & SET DUMMY IN SSSV, PT CONTROL LINES TO 5000 PSI, OK. RDNVL. 05:00 - 09:00 4.00 RUNCOr I~1 DPRB COMP PJSM. R/U TO CIRCULATE & PUMP 10 BBLS HI VIS SWEEP, 25 BBLS SEAWATER W/(2) BBLS BARASCRUB, 20 BBLS SEAWATER W/(2) BBLS DIRT MAGNET & CHASE W/30 BBLS HI VIS SWEEP. PUMP DOWN TUBING @ 3-4 BPM KEEPING SPP BELOW 400 PSI. 09:00 - 09:30 0.50 RUNCOI~I DPRB COMP ATTEMPT TO GET INTO PBR. STACKING OUT @ 9474'. PULLING HEAVY W/O PUMP AS BEFORE, BRING ON PUMP, PULL FREE. 130K DOWN, 155K UP WT. OPT TO SPACE OUT AS CLOSE TO PBR AS POSSIBLE. 09:30 - 13:00 3.50 RUNCOI~P COMP SPACE OUT TO LAND. M/U PUPS, GATOR HAWK & TORQUE TURN EACH CONNECTION. M/U HANGER & CONTROL LINES & PRESSURE TEST TO 5000 PSI, OK. LAND TUBING & PICK UP I 1/2' TO F/P WELL. WITH TUBING LANDED, & PACKER SET, SHOE ON LINER @ 9471', APPROXIMATELY 2'-3' OFF OF TAG UP. SPACE OUT PUPS INSTALLED 1 FULL JOINT BELOW HANGER INCLUDE, FROM BOTTOM UP, 5.78', 7.89', 3.80', 5.69', & 7.79'. (30.95' TOTAL) **56 STAINLESS STEEL BANDS USED ON C-LINE** 13:00 - 18:00 5.00 RUNCOr~!~ COMP PUMP 100 BBLS DIESEL, 167 BBLS SEAWATER, & 53 BBLS DIESEL. CHASE W/10 BBLS SEAWATER TO CLEAR LINES & ALLOW TO EQUALIZE BETWEEN TUBING & ANNULUS. RELAND. DROP ROD/BALL TO SEAT UP IN RHC SLEEVE @ 9445'. 18:00 - 19:00 1.00 RUNCO~ P COMP PJSM. PRESSURE 5 1/2" TUBING TO 3500 PSI TO SET PACKER & HOLD FOR 30 MINUTES W/IA OPEN, OK. CHARTED. 19:00 - 20:00 1.00 RUNCOI~P COMP BLEED TUBING & LEAVE OPEN. PRESSURE 9 5/8" x 5 1/2" IA TO 3000 PSI F/30 MINUTES, OK. CHARTED. BLEED OFF PRESSURE. 20:00 - 20:30 0.50 RUNCOI~ COMP L/D LANDING JOINT. SET BPV. 20:30- 00:00 3.50 RUNCOI~ COMP N/D BOPE. 1/21/2002 00:00 - 06:00 6.00 RUNCOI~ COMP CONTINUE NIPPLING DOWN BOPE. N/U & TEST TREE @ 5000 PSI/15 MINUTES, CHARTED, OK. PULL 2 WAY CHECK, SET BPV, SECURE WELL. RELEASE RIG @ 0600 Printed: 112912002 8:17:27 AM Legal Well Name: 13-20 Common Well Name: 13-20i Spud Date: 11/30/2001 Event Name: REPAIR Start: 1/22/2002 End: 1/21/2001 Contractor Name: Rig Release: Rig Name: Rig Number: 1/21/2002 i00:00- 06:00 6.00 RUNCOr~P COMP 01-21-02. COMPLETION EQUIPMENT SET AT THE FOLLOWING DEPTHS: (TOP) (BOTTOM) ITEM DEPTH DEPTH SEAL ASSEMBLY 9452.00' 9469.67' "XN" NIPPLE W/RHC 9431.66' 9433.09' (2) JTS 5 1/2" 17# NSCT 9343.35' 9421.98' S-3 HYDRO SET PACKER 9328.75' 9333.70' "X" NIPPLE 9317.59' 9319.05' (176) JTS 5 1/2" 17# SLHC 2,093.69' 9308.30' (TOP) (BOTTOM) DEPTH DEPTH CAMCO 5 1/2" BAL-O 2,076.36' 2083.49' (48) JTS 5-1/2" 17# SLHC 1,968.31' 98.01' PUP JT$ 5-1/2" 17# SLHC 67.06' 98.01' (1) JT 5-1/2" 17# SLHC 25.70' 67.06' TUBING HANGER 21.27' 22.60' Printed: 112912002 8:17:27 AM Well: 13-20 Rig Accept: 01/13/02 Field: Prudhoe Bay Unit Rig Spud: N/A APl: 50-029-20705-00 Rig Release: 01/21/02 Permit: 182-009 Drilling Rig: Do¥on 16 POST - RIG WORK 01/31/02 PULLED CA- DSSSV @ 2045' SLM. 02/01102 PULLED BALL & ROD, UNABLE TO PULL RHC PLUG BODY DUE TO SLUGGITS ON TOP. MADE 4 BAILER RUNS W/10' OF 3" PUMP BAILER ( FULL ON EVERY RUN ). 02/02/02 MADE 4 BAILER RUNS W/10' OF 3" PUMP BAILER ATTEMPTING TO BAIL OF THE TOP OF RHC PLUG. UNABLE TO LATCH. 02/03/02 MADE 10 BAILER RUNS. BAILED FILL FROM 9400' SLM TO 9417' SLM. RECIEVED MARKS ON LAST BAILER RUN INDICATING POSS. FISH NECK OF RHC PLUG. 02/06/02 BAIL SLUGGITS OFF TOP OF RHC. PULL 5 1/2" RHC. BAIL MORE SLUGGITS & FILL. BAILED TOTAL OF ABOUT 5 GALLONS OF SLUGGITS/FILL. 02/07/02 MAKE 5 MORE BAILER RUNS. ABLE TO GET DOWN TO 9431' SLM. IBP @ 9533' MD. TALK W/CO REP. WILL HAVE CTU COME & DO CLEANOUT. RDMO. 02/18/02 MIRU CTU #5; RIH W/2 1/2" JSN. CLEAN OUT FROM 9,465' - 9,538' (CTM)---SUSPECTED IBP DEPTH---W/ BIO AND SLICK WATER. CHASE ALL FILL OUT AT 80%. RIH W/BAKER HYD. JDC OVERSHOT. UNABLE TO GET DOWN PAST 9520'- JETTED DOWN TO 9530', CLEANING OUT FILL. POOH, BO FISHING STRING, RIH W/2" BDN, NO CHECKS, TO REVERSE OUT REMAINING FILL. 02/19/02 RIH W/2" BIG HOLE NOZZLE. ATTEMPT TO REVERSE OUT FILL @ -9,500'. PLUG COIL. PULL TO SURFACE AND CUT PIPE. RIH W/SAME. ATTEMPT TO JET THROUGH AND WORK PAST 9,511' (CTM)---UNABLE TO MAKE PROGRESS. POOH FOR NOZZLE CHG.-(2 1/2" ROUNDED MULE SHOE). UNABLE TO WORK PAST 9,500'. ADD BS CENTRALIZER ASSEMBLY TO BHA. RIH ATTEMPT TO REVERSE OUT AGAIN. GET TO 9508' AT 3 FPM, AND PLUG COIL. RIH AGAIN W/2" BDN, 02/20102 FISH IBP-- RIH W/2" BD NOZ, JET DOWN FROM 9400' TO 9536' CTM. PUMP 25 BBL BIO SWEEP. REVERSE OUT. POOH, GOT A PIECE OF METAL AND RUBBER OFF OF TOOLS. RIH W/BAKER JARS AND JDC OVERSHOT. TAG FISH @ 9543', GET 12 JAR LICKS, APPEAR TO HAVE FISH, POOH WITH DRAG. ON SURFACE, NO FISH, NO LATCHING INDICATIONS. RBIH W/NEW BARREL AND JDC WITH 3 TATTLE TAILS, 6.5", 11.75", AND 1.5' UP FROM BOTTOM OF OVERSHOT. TAG FISH @ 9544' GET 9 DN JAR LICKS, 6 UP JAR LICKS, AND 6 RELEASES, POOH AFTER LAST RELEASE. 13-20, Rig Workover, 01/13/02 /21/02 Page 2 02/21/02 FISH IBP--AFTER SEVERAL APPARENT LATCH AND RELEASES OF FISH.POOH. BO TOOLS, NO FISH, AND ONLY TATTLE TAIL MISSING WAS THE ONE 1.5' UP FROM BOTTOM?( 3RD ONE UP) APPEARS TO BE MORE FILL OR JUNK THAT WAS STICKING TOOLS, AND JUST KEPT JARRING TILL FREE. NO LATCHING INDICATION. RBIH, FREEZE PROTECT TUBING. PERFORM WEEKLY BOP TEST. RDMO. 02/23/02 RAN 3.50 L.I.B. TO 9,493' WLM, NO FISH NECK. INSTALLED W/L TIE IN VALVE TO SSV. LOCATE EOT, LOOKS LIKE 40' SPACE BETWEEN EOT & PBR ASSY. RAN 3.5" PUMP BAILER TO 9488~/LM, TAP DOWN, WENT TO 9498' WLM. BAILED & GOT HUNG UP. JAR LOOSE. RIG UP RETRIEVING HEAD (EQUALIZING SLEEVE). 02/24102 RAN 2.0" RS INSIDE EQUALIZING SLEEVE. UNABLE TO LATCH IBP. RAN 3.48" LIB BELOW 4.35" CENTRALIZER. SAT DOWN @ 9480' WLM (IDENTIFIED DEPTH OF 5.5 X 4.5 X-OVER). MADE ATTEMPT TO LATCH UP USING 2.50 BAKER SLEEVE W/2" PULLING TOOL, NO LATCH. GOT PICTURE OF FISH @ 9,500' WLM USING 3.625 BAR BELL W/2.50" LIB. LATCHED FISH @ 9,495' WLM USING 3.625 BAR BELL & 2 .... RB" W/3.60 BELL. TOOL SHEARED. RAN 2" JDS IN 3.60" BELL GUIDE. LEFT BAITED BELL GUIDE ON IBP. RAN 3.625" BARBELL W/4-1/2" GS & BRASS PIN. LATCH @ 9493' WLM. JARRED JD OFF IBP. RAN 2" JDS W/ 2.50" EQ. SLEEVE. UNABLE TO LATCH IBP. 02/25/02 RAN 3.625" SWAGE, 2' X 1-7/8", 4-1/2" GR, 3.72" CENTRALIZER, BAITED 2-1/2" EQUALIZING SLEEVE & 2" JDS.TO 9498' WLM. UNABLE TO LATCH IBP. TOOK OFF CENTRALIZER. RAN SAME W/3.65" SLEEVE W/ 2.25" LIB INSIDE TO 9498' WLM. NO MARKS. RAN 4-1/2" GR & BAITED 3.65" BELL GUIDE. PUT 2-1/2" EQUALIZING SLEEVE W/2" JDS INSIDE BELL GUIDE. RAN FARRIS I.B.P. SPEAR TO 9,498' ATTEMPTED TO PULL I.B.P. RAN L.I.B., NO FISH, MAY BE COVERD. RETURNED ALL EQUIP, RETURNED WELL TO DSO, LEFT S/I STATE OF ALASKA ALASKA ,.)IL AND GAS CONSERVATION COMM,&SION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: r'l Abandon I"1 Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Convert to WAG Injector 2. N~me of Operator ' BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 '4. Location of Well 'at' surface v 2638' SNL, 130' WEL, SEC. 14, T10N, R14E, UM At top of productive interval 197' NSL, 2369' EWL, SEC. 12, T10N, R14E, UM At effective depth 244' NSL, 2426' EWL, SEC. 12, T10N, R14E, UM At total depth 303' NSL, 2496' EWL, SEC. 12, T10N, R14E, UM 5. TyPe of well: [] Development [] Exploratory I [] Stratigraphic [] Service 12. Present well condition summary 10426 feet ~ Plugs(measured) 6. Datum Elevation (DF or KB) RKB = 84' ~. Unit or Property Name Prudhoe Bay Unit 8. Well Number . 13-20i 9. Permit Nu.rn~,l,l~r 182-009 w 10. APl Number ~' 50- 029-20705-00 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool PBTD tagged at 10159' (09/~J)E [ E I V E D Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical 9252 feet 10159 feet 9001 feet Length Size Junk (measured) Cemented SEP 07 2001 Alaska 0il & Gas Cons. Commission Anchorage MD TVD 81' 20" 440 sx Arcticset II 81' 81' 2501' 13-3/8" 2400 sx Fondu, 400 sx Permafrost 2501' 2501' 9845' 9-5/8" 500 sx Class 'G' 9845' 8707' 871' 7" 350 sx Class 'G' 9543' - 10414' 8426' - 9240' Perforation de,h: measured 9843'-9865', 9954'-9980', 9990'-10000', 10013'-10033', 10054'-10064', 10073'-10083', 10092'-10132', 10158'-10178', 10207'-10237' true vertical 8705'-8725', 8808'-8833', 8842'-8851', 8864'-8882', 8902'-8912', 8920'-8929', 8938'-8975' 9000'-9019', 9046'-9074' Tubing (size, grade, and measured depth) 5-1/2",17#, ~80to 9517'; 4-1/2",12.6#, N-80from 9517'to9615' Packers and SSSV (type and measured depth) Baker '3-H' packer at 9505'; Camco 'BaI-O' SSSV Nipple at 2041' 13. Attachments [] Description Summary of Proposal [] Detailed Operations Program I-I BOP Sketch 14. Estimated date for commencing operation October 22, 2001 16. If proposal was verbally approved Name of approver Date Approved 15. Status of well classifications as: [] Oil I"i Gas [] Suspended Service MI Injector, converting to WAG Injector Contact Engineer Name/Number: Archie Poleschuk~..5. ..64~O Prepared By Name/Number: Terde Hubble, 564-4628 17. I hereby certify that the foreggJ~s true,~d~r_j;ec~e best of my knowledge Signed Archie Poleschuk ~____m--~- ~ Title Drilling Engineer Date J~.~ ~,- /4) ~.~,~ ~,~ .... ~ ,, . - . .- ,~ ~ ~ ~ ,~ Conditions of Approval: Notify Commission so representative may witness (~)r~,,.~ ~C3'~' r ^pprova~ mo. · Plug integrity ~ BOP Test .. '~ Location clearance ~ Mechanical Integrity Test _,~ , ,,~.ubs~tc&ient form required 10- Approved by order of the Commission r.~mmv I~echsl~' r'~ ! r", I !~,1 ^ .ev. ' U i I L 1~ Tri~l'cate ARCO ALASKA, INC. sSssvNIP Tubing-PC Casing Casing 9072~ MIN ID= 31000". (5-1/2" Alpha Soft Set TP) PATCH PBR - PKR '-- Tubing-PC · · NIP Liner SOSUB .... TTL Perf ~ Perf Perf ' ~ Perf- .':::- :: :: ~ Perf -.. '.i.;;: -- Perf-. ".' ~ : Perf A Prudhoe Bay t 3-21 APl: 500292070500 Orig Compltn: 2/8/82 Angle @ TD: 20 deg ~ 10426 SSSV Type: Last W/O: 2/7182 Rev Reason: Safety Note (Ikak) Annular Fluid: Diesel/9.7.0 NaCI Ref Log Date: 2/3/82 Last Update: 2/23/00 Reference Log: BHCS RKB: 84 ft LastTag: 10159'ELM TD: 10414ftKB Last Tag Date: 9114/99 Max Hole 39 deg @ 6700 Angle: Well Type: INJ Angle {~ TS: 21 deg (~ 9945 Depth Comment 9072 S072' MIN ID = 3.000" (5-1/2" Alpha Soft Set TP) :Safe, Notes::: :' : :: Date Note 2/23/00 WAIVERED WELL - T x IA Communication; holes in tubing. Patch in tubing; IBP required for annual CMIT. LDL 03/15/94 indicates leak @ 9223' ~erai.NOtes:: :: Date Note TTL ELM ~ 9602: ELM Tubing Tail (Logged 08/08/82) Daterun: 1982-02-08 other{PlUgS; ~Uip~ etc.). JEWELRY Depth TVD Type Description ID 2041 2041 SSSSVNIP 5-1/2" Camco BAL-O SSSV Nipple 4.562 9072 7993 PATCH 5-1/2" Alpha Soft Set Tubing Patch (Set 10/02/93) 3.000 9487 8374 PBR 5-1/2" BOT PBR Assembly 0.000 9505 8390 PKR 9-5/8" x 5-1/2" BOT 3-H Packer 0.000 9517 8402 XO Crossover (6-5/8" MOE) 5-1/2" x 4-1/2" 0.000 9603 8482 NIP 4-1/2" Camco DB-5 Landing Nipple 3.813 9614 8492 SOSUB 4-1/2" BOT Shearout Sub 0.000 9615 8493 TTL 4-1/2" Tubing Tail 0.000 Size Weight Grade 7.000 29.00 L-80 9.625 47.00 L-80 13.375 72.00 L-80 TUb!rig Strings ~NI : Size Weight Grade 5.500 17.00 L-80 4.500 12.60 N-80 :pe~rations: :: :: Interval TVD 9843 - 9865 8705 - 8725 9954 - 9980 8808 - 8833 9990 - 10000 8842 - 8851 10013 - 10033 8854 - 8882 10054 - 10064 8902 - 8912 10073 - 10083 8920 - 8929 10092 - 10132 8938 - 8975 10158 - 10178 9000 - 9019 10207 - 10217 9046 - 9055 10217 - 10237 9055 - 9074 Top Btm Feet Description 9543 10414 871 Liner 0 9645 9645 Casing 0 2501 2501 Casing Top Btm Feet Description 0 9517 9517 Tubing-PC 9517 9615 98 Tubing-PC Zone Status FeetSPF Date Type SAG O 22 4 12/26/91 APERF ZONE 4 O 26 4 8~8~82 IPERF ZONE 4 O 10 4 8~8~82 IPERF ZONE 4 O 20 4 8/8182 IPERF ZONE 4 O 10 4 8~8~82 IPERF ZONE 4 O 10 4 8/8/82 IPERF ZONE 4 O 40 4 818/82 IPERF ZONE 4 O 20 2 3/21/93 APERF ZONE 3 O 10 2 3/21/93 APERF ZONE 3 O 20 2 3/21/93 APERF Comment DS 13-20 Pr sed Completion 13-3/8" 72# L-80 (2501' MD) ~ 7" 29# L-80 Liner (9543' MD) 9-5/8" 47# L-80 (9845' MD) 29# L-80 Liner (TD @ 10414' MD) 5-1/2" SSSV Nipple (-2200' MD) 5-1/2" 17# L-80 tubing 9-5/8" x 5-1/2" Packer/PBR with overshot tailpipe 5-1/2" BOT PBR Assembly (9487' MD) 9-5/8" x 5-1/2" BOT 3-H Pkr (9505' MD) 5-1/2" x 4-1/2" X-Over w/6-5/8" MOE (9517' MD) 4-1/2" Camco 'DB-5' Nipple, ID--3.725" (9603' MD) 4-1/2" BOT Shearout Sub (9614' MD) 4-1/2" 12.6# N-80 'l~ubing Tail (9615' MD) Perforations 9843-9865' MD 9954-9980' MD 9990-10000' MD 10013-10033' MD 10054-10064' MD .... 10073-10083' MD 10092-10132' MD 10158-10178' MD 10207-10237' MD Attachment 17 DS 13-20 Proposed Completion Schematic To: From: Subject: Bill Mathews, DS 13 Engineer Barbara M. Holt, WO/Drilling Engineer 13-20i RWO Scope of Work Scope of Work A Kinley caliper survey was run in 3une 2000 to evaluate the condition of the tubing in preparation for the conversion to a WAG injector. The survey identified seven joints with possible holes and characterized 23 joints as being in poor condition. Corrosion is most prevalent in the lower half of the tubing. An LDL in October 2000 identified holes at 8894', 8872', 8250', 7500', and possible holes from 5850' to 5750'MD. The work scope includes cutting and pulling the corroded 5 1/2" L-80 completion and re-completing with a new 5 1/2" L-80 Premium tubing and stacker packer assembly. The estimated cost of is $1.10 MM and will take approximately 9 days, not including rig move, to complete. Pre-Riq Work 1. Test the 9 5/8" mandrel packoff and tubing hanger (through test port) to 5000 psi. If the packoff tests, completely back out and check each 9 5/8" x 5 1/2" lock down screw for breakage (check one at a time). If tested recently, email or fax in test report. 2. RU wireline and an IBP at approximately 9550'MD. This is in the 4 1/2" tubing tail above the Camco DB-5 landing nipple and below the 5 1/2" x 4 1/2" crossover. Top the plug with sluggit to protect the fishing neck from debris. 3. Chemical cut the 5 1/z" tubing in the middle of the first joint above the Alpha soft set tubing patch set at 9072'MD. 4. Freeze protect tubing and casing with diesel from 2000' to surface. 5. Set a BPV and remove well house and flowlines. 6. Clear and level pad in preparation of rig move. Assure annuli are freeze protected. .Riq Workover Procedure Option #1 Stacker Packer (9 davs)~ 1. MIRU. ND tree. NU and test BOPE. Circulate out freeze protection fluid and circulate well to clean seawater through cut. (1 day) 2. Pull and LD 5 1/z" tubing string to chemical cut at approximately 9050'MD. (1 1/2 days) 3. RIH on drillpipe with overshot. Latch fish; take over-pull equal to tubing weight below approximately 5000 - 7000 lbs. Put LH turn and blind backoff. Tubing is severely corroded and may part. (1 day) 4. If the tubing parts and the seal assembly is left in the hole, RIH with o~ershot. RU wireline and chemical cut tubing at approximately 9450'MD. RD wireline. POOH with tubing. (1 day) 5. PU R'l-rS. RIH to 9440'MD and test 9 5/8" casing to 3000 psi. Notify town with results. (1 day) 6. RIH with 5 1/2" L-80 premium tubing with a new 5 1/2" x 9 5/8" packer and Unique overshot. (1 day) Attachment 22 DS13-20 Drilling Cost Estimate 7. RU slickline. Drift tubing to ensure access through original packer. RD slickline. (z day) 8. Circulate in freeze protect fluid to 2000'. 9. Set the 5 1/2" x 9 5/8" packer at +/-9420'MD. (1/2 day) 10.Test tubing to 3000 psi, test annulus to 3000 psi. (1/2 day) 11. SetBPV. ND BOPE. NU and test tree. RDMO. (1/2day) Post-Riq Work 1. RU slickline and retrieve RHC sleeve. 2. RU wireline to pull IBP. 3. Install flowline and reset the well house. Please call 564-579:L or 240-8044 if you have any questions. Barbara M. Holt Workover/Drilling Engineer Attachment 22 DS13-20 Drilling Cost Estimate NOTE to FILE Prudhoe Bay Unit DS 13-20i PTD 182-009 Sundry 301-261 DS 13-20 was originally completed in February, 1982. It was subsequently converted to an injector in April, 1993. In the original oil completion, a 7" liner was set with the liner top at 9543' md and the packer was set at 9505' md. As presently conf*~ured, the shallowest perforation begins at 9843' md (Sag River) which is essentially at the 9-5/8" shoe depth. As presently configured, the packer is about 340' md above the shallowest perforation. This well has documented tubing leaks and a workover to recover and replace the tubing is proposed. After cleaning out the well, a new packer is proposed to be set at about 9420' md. AOGCC regulation 20 AAC 25.412 (b) proscribes that [in an injection well] the packer must be placed within 200' md of the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone. The confining zone in the Prudhoe Bay Unit is the Kingak Shale. This shale exhibits considerable thickness above the Shublik, Sag River and Sadleroshit formations. Examination of the bond log shows that cement isolation exists behind the 9-518" casing to above the proposed packer depth. It is likely that the injection water will be confined to the intended intervals and that setting the packer as proposed is acceptable. ARCO Alaska, Inc. /~" Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 19 January, 2000 Mr. David Johnston, Chairman Alaska Oil & Gas Conservation Commision 3001 Porcupine Drive Anchorage, AK 99501 Fax 276-7542 RE: DS 13 MI Expansion Dear Mr. Johnston, The purpose of this letter is to notify you of changes to the injected fluids into wells 13-17, 13- 18 and 13-20. These injectors have been injecting produced water since the 1985. Facility modifications are currently underway to enable these wells to inject miscible injectant (MI) in addition to produced water. The expansion of MI to these patterns is for EOR purposes and offset producers are expected to capture an additional 3 MMBO. Facility work is expected to be completed in March, and the wells are expected to begin their first MI injection cycles in April. If notification beyond this letter is required, or you need additional information please let me know. I can be reached at 265-1614 with questions. Sincerely, R. Andrew Parker Senior Drillsite Production Engineer Prudhoe Bay Resource Development cc: M. Bill ATO-1530 Oil & Gas Cons. Commission ARCO Alisa, Inc. is · Subsid~ of Atl~nticRichfleldCom~ny Pmdh'°e Bay Unit Well 13-17i Appl...,Form 1~'"~3. Supplemental Information] ~,.~, ~¢>0 e.~ Subject: [Fwd: Prudhoe Bay Unit Well 13-17i Application for Sundry Approvals,Form 10-403. Supplemental Information] Date: Thu, 09 Dec 1999 14:11:50-0900 From: Blair Wondzell <blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: aogcc north slope address <aogcc_prudhoe_bay~admin.state.ak.us> Subject: Re: Prudhoe Bay Unit Well 13-17i Application for Sundry Approvals,Form 10-403. Supplemental Information Date: Thu, 09 Dec 1999 14:11:10 -0900 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Michael R Niznik <MNIZNIK~mail.aai.arco.com> CC: Robert Crandall <bob_crandall~admin. state.ak.us>, Stephen F Davies <steve_davies~admin. state.ak.us>, Jack Hartz <jack_hartz~admin.state.ak.us>, Tom Maunder <tom_maunder~admin.state.ak.us> Michael, Thanks for the e-mail. We agree with your proposal and will therefore process the 10-403. Thanks, Blair Wondzell 12/9/99 Michael R Niznik wrote: Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission Per our conversation on 12/08/99 regarding the planned annular isolation squeeze of well 13-17i. To demonstrate a competent Inner Annulus (IA) in a well where cement is brought to surface, we propose the following two diagnostic methods. (1) Run an Ultra-Sonic Imaging Tool (USIT) after cement is placed to demonstrate IA fillage. Two cement blends will need to be used in the IA, an arctic set in the permafrost region and a neat cement below. The two cement blends have varying compressive strengths so the threshold settings on the USIT log will be adjusted to compensate for the differences. (2) A spinner survey will be run after the USIT log to demonstrate that all of the flow is out the end of the tubing tail. Repeat spinner surveys will be conducted every four (4) years in lieu of the Inner Annulus MIT. We appreciate the AOGCC working with us on this very new and different approach to repairing injection wells and look forward to working with you on our various projects in the future. Sincerely, Michael R. Niznik Workover Engineer ARCO Alaska, Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X 2. Name of Operator 5. TYpe of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development_ RKB 84 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service __x Prudhoe Bay Unit 4. Location of well at surface ~' v"" ,~ 8. Well number _ 2635' FNL, 130' FEL, Sec. 14, T10N, R14E, UM 13-20 ~ At top of productive interval 9. Permit number / approval number 196' FNL, 2369' FWL, SEC. 12, T10N, R14E, UM 82-9v/ At effective depth 10. APl number 50-029-20705 At total depth 11. Field / Pool 4975' FNL, 2782' FEL, Sec. 12, T10N, R14E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10426 feet`/ Plugs (measured) PBTD tagged @ 10159' MD (9/14/1999) true vertical 9252 feetv/' Effective depth: measured 10159 feet Junk (measured) true vertical 9001 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 440 Sx AS, 110' 110' Surface 2417' 13-3/8" 2400 Sx Fondu & 400 Sx PF 2501' 2501' Production 9761' 9-5/8" 5oo Sx C~ass G 9845' 8707' Liner 871' 7" 350 Sx C~ass G 10414' 9240' ORIGINAL Perforation depth: measured 9843'-9865'; 9954'-9980'; 9990'- 10000'; 10013'- 10033'; 10054'- 10064'; 10073'- 10083'; 10092'- 10132'; 10158'- 10178'; 10207'- 10237'. true vertical 8705' - 8725'; 8808' - 8833'; 8842' - 8851'; 8864' - 8882'; 8902' - 8912'; 8920' - 8929'; .8938' ~ 8975'~" 9000' - 9019'; 9046' - 9074'. : ~ · Tubing (size, grade, and measured depth 5-1/2", 17#, L-80 PCT @ 9517' MD; 4-1/2", 12.6#, N-80 PCT @ 9615' MD. ' ' i Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BOT 3-H PACKER @ 9505' MD. 5-112" CAMCO BAL-O SSSV @ 2041' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __X ' 14. Estimated dat~ for commencing operation 15. Status of well classification as: November 23, 1999 16. If proposal was verbally approved Oil __ Gas __ Suspended _ Name of approver Date approved Service MI Injection , 17. I hereby certity that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Nlznli( @ 263-4561. Erin Oba Prepared b~, Paul Rau1263-49~0 ' ~ FOR COMMISSION USE ONLY Conditions of approval: PlugN°tify Commission so representative may witneSSintegrity_ BOP Test_ Location clearance_ I Approval no.~_ ~-~ ~") Mechanical Integrity Test ~ Subsequent form required 10- · Original Signed By Approved by order of the Commission David W. Johnston Commissioner Date I1-}% Approved Copy ~.~. Return.~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 13-20 Annular Isolation Squeeze Primary Objective Cement the tubing x inner annulus with 15.8 ppg LARC cement to eliminate annular communication caused by a tubing leak. o . . RU Slickline and drift/tag. RU CTU. Place sand plug over perforations and in tubing up to -9550'. RU E-Line. Shoot circulation holes in tubing from 9450'-9460'. . ° ° . RU Slickline and drift/tag. RU cementers (fullbore job). Circulate 285 bbls of 11 ppg LiteCRETE cement into the inner annulus from -3000' to 9505'. The cement will be balanced by 11 ppg drilling mud in the tubing. Wait on cement 5 days. RU CTU. Mill out cement to sand interface & pressure test inner annulus. FCO to TD. 8. RU Slickline and run SSSV. 9. Put well on MI injection. Calculations Chart Subject Sheet number of File By Date · ^.co ~,~ QUALITY LITHO PRINTING. ANCHORAGE, AK (907} 563-4743 159-5881 6 5 4 .3 2 //BLIND ~" $~uFr~ eox COILED 'i'UB'INI~ 'UNIT I~C~ E0U l PHENT 1/t6" PIPE RAMS ~" HYDRAULIC SLIPS 'HEAR RAU$ · 3 2 RECEIVED . . . 1999 H ] REL ].NE BOP .EOU ] PMENT - i I __ 1. 5DOD PSI ?" WELLHEAD CONNEC10R rLANG ~. 5ODD PSI WlRELIN£ RAuS (VARIABLE ) 3. 5DD0 PSI 4:1/6" L UB'RICAiOR ~' I 4. 5000 PSI 4"1/6'; rL~ TUBE PACK-OFF ARCO ALASKA, INC. SSSSVNIP Tubing-PC Casing Casing (5-1/2" Alpha Soft Set PATCH PBR PKR XO Tubing-PC NIP Liner SOSUB q-fL Perf Perf Perf ........ Perf -...-.~.,::..-.-.-.. ................ Perf ....... .~.~: Perf -.-../i/ Perf...../: -- Prudhoe Bay 13-20 ................... ~P'i': 500292070500 Orig Compltn: 2/8/82 Angle ~ TD: 20 dog @ 10428 SSSV Type: Last W/O: 2/7/82 Rev Reason: Tag Nisual Annular Fluid: Diesel/9.7.0 NaCl Ref Log Date: 2/3/82 Last Update: 6/7/99 Reference Log: BHCS RKB: 84 ft Last Tag: 10159' ELM TD: 10414 ftKB Last Tag Date: 9/14/99 Max Hole 39 deg ~ 6700 Angle: Well Ty~: INJ Angle (~ TS: 21 deg (~ 9945 Depth Comment 9072 9072' MIN ID = 3.000" (5-1/2" Alpha Soft Set TP) Date Note LDL 03/15194 indicates leak @ 9223' Date Note TTL ELM @ 9602: ELM Tub ng Ta (Logged 08~08~82) Daterun: 1982-02-08 Depth TVD Type Description ID 2041 2041 SSSSVNIP 5-1/2" Camco BAL-O SSSV Nipple 4.562 9072 7993 PATCH 5-1/2" Alpha Soft Set Tubing Patch (Set 10102/93) 3.000 9487 8374 PBR 5-1/2" DOT PBR Assembly 0.000 9505 8390 PKR 9-5/8" x 5-1/2" DOT 3-H Packer 0.000 9517 8402 XO Crossover (6-5/8" MOE) 5-1/2" x 4-1/2" 0.000 9603 8482 NIP 4-1/2" Camco DB-5 Landing Nipple 3.813 9614 8492 SOSUB 4-1/2" DOT Shearout Sub 0.000 9615 8493 TTL 4-1/2" Tubing Tail 0.000 l [~ ~i.:lli[':. ~i~.ili~] [ii]~iiiii:]i:l;:l ii:li::ii?li]i:l ii ! I i i !! iii :: i~ : : i! ::: :::: ' Size Weight Grade Top Btm Feet Description 7.000 29.00 L-80 9543 10414 871 Liner 9.625 47.00 L-80 0 9845 9845 Casing 13.375 72.00 L-80 0 2501 2501 Casing [~j~!~.[~:~. ~;;;~ii?.i:.i.::.::;.::d.i.i, :.. :?; ::: I: : Size Weight Grade Top Btm Feet Description 5.500 17.00 L-80 0 9517 9517 Tubing-PC 4.500 12.60 N-80 9517 9615 98 Tubing-PC Interval TVD Zone Status Feet$PF Date Type 9843 - 9865 8705 - 8725 SAG O 22 4 12/26/91 APERF 9954 - 9980 8808 - 8833 ZONE 4 O 26 4 8/8/82 IPERF 9990 - 10000 8842 - 8851 ZONE 4 O 10 4 8/8~82 IPERF 10013- 10033 8864- 8882 ZONE 4 O 20 4 818/82 IPERF 10054 - 10064 8902 - 8912 ZONE 4 O 10 4 8/8/82 IPERF 10073 - 10083 8920 - 8929 ZONE 4 O 10 4 8/8/82 IPERF 10092 - 10132 8938 - 8975 ZONE 4 O 40 4 8/8/82 IPERF 10158 - 10178 9000 - 9019 ZONE 4 O 20 2 3121/93 APERF 10207 - 10217 9046 -9055 ZONE 3 O 10 2 3/21/93 APERF 10217 - 10237 9055 - 9074 ZONE 3 O 20 2 3/21193 APERF Comment ) ) ARca Alaska Inc. Attn: Problem Well Specialist, PRB 24 Post Office Box 100360 Anchorage, Alaska 99510-0360 ~~ ~~ October 2, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: 03-11 Monthly Pressure Data, Per State Sundry Approval #399-084 ~C\-~~~.j 11-29 Monthly Pressure Data, Per State Sundry Approval #398-035 ~ ""\ -~s ~ "/,,.... 13-15 Monthly Pressure Data, Per State Sundry Approval #399-091 ~') -\::'\S'\.I 13-17 Monthly Pressure Data, Per State Sundry Approval #298-275 ~:,) - ()C:'}..~ / 13-20 Monthly Pressure Data, Per State Sundry Approval #397-078 ~~ -<J~(J~\ vi' P1-01 Monthly Pressure Data, Per State Sundry Approval #398-188 qs -t)~ ~ (;)'J P2-34 Monthly Pressure Data, Per State Sundry Approval #398-243'~\) -C)Q'J.' ~ \~;}.:'ooq Dear Mr. Wondzell: Attached please find daily injection reports on Wells 03-11, 11-29, 13-15, 13-17, 13-20, P1-01 and P2-34 for the month of September 1999. This report is submitted to comply with the State Sundry Approvals listed above. Also attached are MITIA reports conducted on injectors. If you require any additional information, please contact Jerry Dethlefs or me at (907) 659-5102. Sincerely, SCANNEr.) ~JAN 11 2.005 !u{~ ) Joe Anders Problem Well Specialist \; k>.\. '" \ - " t:> \ Ù,~Q. S;! -\~ o.,Q. C3....-..}\-CJ~c.\l· '- _ <-~'~ ~,~s'S.·~'\~~ ~rt ''-<::1..~ ~'l ð\?~~~~ _ \o..\-~ ~ ~~s.~'~ ~ Q. 'Q. \ ~ \ \~<i:"-.~) ~'I c:...<:. \. ~ Ç,,\'- '-,. Ö""' <::>~"«S ~"- \ \", <.... S 1.. {"",,«..\\ ~a\"--\ _ .. . , ... \"'- \._ - ~s·~c...,\ c·~ 0' '- ,<¿ ~C2.'\\-..:;.. G... c..a '~'Y0"c~o~?i:,'¡; '"\"~~ \ -:>\ 'I'-~~ . _ c. ~ '\ Ù'-:A..,\-~t"' "S ""'-:..~~_ Wi, \-\r..... i.\,~ d ~0 \/'-J\t)",-\-\"''- o.-Ç (., S~J\'\G.. ç- -t-c;.::; Cü ~'^-~c..\\R ¡. v \K,,.......,:> \-~ ,"-_~,>0~ \J...,l O",,'-\i.......~ \\..)"S. ç> \'"x_ ~~u \€. L C- \.--"'-.ç." ~ \ ~ ·s-oa ~ç\. o (" \ « ~ ~ ~ """ 'i \ <\.. '-.) ~ ~ \\ ~ ~- .. . . . . -.. 09(L~-0..~\~ ~~ ~Ct:- \- u\(.}~\"'~ G~ \. '4'-..~\~~\2>.~.)().\~ ç:.\.\ ~~'Z.~~0 ,(.~ ~ ~-CX~~ "ç \-~'( ~c..'\,,\- \-0 \N\(:);¡<\. \-0, ~C)\"'~ c.\o':::..Q.\,. ~1 ) \ ~d -{)O~ ) ARGO Well 13-20 September 1999 Injection Data Date of Injection Volume Injected (BWPD) 2,744 __.____m ?!_ª~z._. .... ...... ..' 3,201 - -'-'-'--'---'.'---'--~- .,,,.,..,,,...- "'.'~"'.. 3,236 .".--.."---....-..... ".......,_.,. 3,282 _ _. ""_·_.·_m.·~__·.~."..·_·,,·.,·,· _.~ ?_!.9 5Z....._.._...._ .._... 2,214 1,324 o ...-.--..-...--".--........ ,,- o o o o o 1_1.~~.~.m... .. ~"ª'ºª-_.. 3,207 - . ~,_._..._..____ __., ,.,_..____. "_,.,_,,,_,. .,_n _~LQ.ª_1. ..... 2,973 . .....---..-.--...--,--.-,---.....--....--,.. "---' .... ~L80!___..___..____. _ _. 3,087 - "".,.~~--.,_._.._------- 3,250 ª,.1.4_ª.... ........... 3,290 ...-.- ,,,.""---~,~....,-.._. 3!?~ª_ 3J..ª-1.ª-. __ _ __. 4,074 - -. _.._-_.~,_... '-"'. .---. 3,519 3,326 3,311 Tubing Pressure (psi) 1,.929 1,029 1,029 1,029 990 1,ºªº. 1,030 .-,- ..-,--_........ ........ ..1 ,_º ªº.. _ 1,320 o o 30 o o 985 984 990 993 993 976 1,048 1,048 995 910 1,030 1,.ºª0 1,050 1,040 1,020 1,020 9-5/8" Pressure (psi) 960 ...'. ". -" .._.~.._-. -. --,,,. _.-.--"..... ,-,,-~_.- 960 1,ººº 1,000 1,.9Qº-_ 1,000 1.,.Q.ºº 1,-ººº.. 1,000 o ..'-"_.,."'.....,."".,-,...._..~....,......,,..,,-..,_...- o 20 o o 900 900 900 900 900 950 .-.'-~._-,-~--_."- 950 990 990 880 880 880 1,000 1,000 .- --'---.---.-..- 950 950 9/1/99 9/2/99 9/3/99 9/4/99 9/5/99 9/6/99 9/7/99 ..-." .".--..-,....-..,.-. ._"". 9/8/99 --"-. ._-----_.~.. 9/9/99 9/10/99 9/11/99 9/12/99 9/13/99 9/14/99 9/15/99 9/16/99 9/17/99 9/18/99 9/19/99 9/20/99 9/21/99 9/22/99 9/23/99 9/24/99 9/25/99 9/26/99 9/27/99 ---"...",,---_.._._,,-- 9/28/99 9/29/99 9/30/99 ....."..-..-..-,."....,..... u¡ - [. I . . - I Joe Anders/Jerry Dethlefs Problem Well Specialists ARCO Alaska, Inc. ARCO Alaska Inc. Attn: Problem Well Specialist, PRB 24 Post Office Box 100360 Anchorage, Alaska 99510-0360 May 3, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry Approval #397-078 P1-01 Monthly Pressure Data / Per State Sundry Approval #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P1-01 and P2-34 for the month of April 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Joe Anders at (907) 659-5102. Sincerely, Anders Problem Well Specialist ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 March 3, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry Approval #397-078 P 1-01 Monthly Pressure Data / Per State Sundry Approval #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P1-01 and P2-34 for the month of January, 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Steve Schudel or Jim Styler at (907) 659-5102. Sincerely, Steve Schudel Problem Well Specialist Attachments: 5 pages ~laska Oil& Gas Cons. Cot, ~ncl~or~.qe ~n,toSton ARCO Well 13-20 April 1999 Injection Data Volume Injected Tubing Pressure 9-5~8" Pressure Date of Injection (BWPD) (psi) (psi) 4/1/99 2,219 960 940 4/2/99 2,050 939 940 4/3/99 2,072 934 1,050 4/4/99 2,031 938 1,050 4/5/99 2,959 1,001 1,050 4/6/99 2,694 974 1,125 4/7/99 3,380 1,024 1,125 4/8/99 3,485 1,041 1,200 4/9/99 3,457 1,043 1,200 4/10/99 3,611 1,053 1,200 4/11/99 3,361 1,042 1,200 4/12/99 3,462 1,056 1,200 4/13/99 3,494 1,055 1,200 4/14/99 3,610 1,066 1,220 4/15/99 3,750 1,075 1,250 4/16/99 3,363 1,065 1,200 4/17/99 3,602 1,079 1,200 4/18/99 4,347 1,100 1,250 4/19/99 5,316 1,135 1,250 4/20/99 5,213 1,139 1,250 4/21/99 5,626 1,151 1,250 4/22/99 6,857 1,199 1,250 4/23/99 4,052 1,052 1,250 4/24/99 2,969 1,025 1,150 4/25/99 3,280 1,046 1,150 4/26/99 4,482 1,095 1,150 4/27/99 4,614 1,108 1,150 4/28/99 4,549 1,114 1,150 4/29/99 4,651 1,121 1,275 4/30/99 4,260 1,098 1,275 Joe Anders/Jerry Dethlefs Problem Well Specialists ARCO Alaska, Inc. ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 February 4, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 11-29 Monthly Pressure Data / Per State Sundry Approval #398-035 13-17 Monthly Pressure Data / Per State Sundry Approval #298-275 13-20 Monthly Pressure Data / Per State Sundry Approval #397-078 P 1-01 Monthly Pressure Data / Per State Sundry Approval #398-188 P2-34 Monthly Pressure Data / Per State Sundry Approval #398-243 Dear Mr. Wondzell: Attached please find daily injection reports on Wells 11-29, 13-17, 13-20, P 1-01 and P2-34 for the month of January, 1999. This report is submitted to comply with the State Sundry Approvals listed above. If you require any additional information or clarification, please feel free to contact Jerry Dethlefs or Steve Schudel or Jim Styler at (907) 659-5102. Sincerely, Steve Schudel Problem Well Specialist Attachments: 5 pages RECI: iVED '~:L:, 09 19!J9 0il & 6as Cons. Commission Anchora.qe ARCO Well 13-20 January 1999 Injection Data Date of Injection Volume Injected Tubing Pressure (BWPD) (psi) 9-$/8" Pressure (psi) 1/1/99 1,730 919 1,150 1/2/99 1,838 924 1,150 1/3/99 632 969 1,050 1/4/99 0 0 1,050 1/5/99 972 884 1,000 1/6/99 2,043 927 1,000 1/7/99 2,035 940 1,100 1/8/99 2,095 947 1,100 1/9/99 1,988 924 1,100 1/10/99 2,055 933 1,100 1/11/99 2,000 917 1,100 1/12/99 1,886 912 1,100 1/13/99 2,082 941 1,100 1/14/99 2,051 953 1,100 1/15/99 2,040 949 1,140 1/16/99 2,110 960 1,140 1/17/99 2,168 965 1,120 1/18/99 2,171 969 1,120 1/19/99 2,126 966 1,100 1/20/99 2,122 956 1,100 1/21/99 2,087 953 1,100 1/22/99 2,174 955 1,100 1/23/99 2,003 921 1,100 1/24/99 1,899 898 1,100 1/25/99 1,962 903 1,100 1/26/99 2,013 922 1,100 1/27/99 2,189 947 1,100 1/28/99 2,201 950 1,050 1/29/99 2,349 966 1,050 1/30/99 2,267 957 1,050 1/31/99 2,211 940 1,050 Jerry Dethlefs/Steve Schudel Problem Well Specialists ARCO Alaska, Inc. ARCO Well 13-20 February 1999 Injection Data Date of Injection Volume Injected Tubing Pressure (BWPD) (psi) 9-5/8" Pressure (psi) 2/1/99 2,182 929 1,125 2/2/99 2,017 917 1,125 2/3/99 1,954 928 1,125 2/4/99 1,875 898 1,025 2/5/99 2,014 907 1,025 2/6/99 2,081 910 1,025 2/7/99 2,002 914 1,125 2/8/99 2,213 933 1,125 2/9/99 3,699 931 1,125 2/10/99 6,711 913 1,125 2/11/99 2,546 893 1,100 2/12/99 2,981 907 1,100 2/13/99 3,617 928 1,100 2/14/99 3,582 936 1,120 2/15/99 3,400 924 1,120 2/16/99 4,606 913 1,050 2/17/99 4,801 907 1,100 2/18/99 2,066 885 1,100 2/19/99 3,616 921 1,050 2/20/99 3,125 936 1,050 2/21/99 2,000 881 1,050 2/22/99 2,963 1,009 1,050 2/23/99 3,072 1,039 1,100 2/24/99 2,952 1,101 1,100 2/25/99 3,020 1,116 1,100 2/26/99 2,827 1,071 1,100 2/27/99 3,174 1,132 1,325 2/28/99 3,127 1,110 1,325 Jerry Dethlefs/Steve Schudel Problem Well Specialists ARCO Alaska, Inc. ARCO Alaska Inc. Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 July 23, 1997 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: 13-20 Monthly Injection Data / Per State Sundry Approval #397-078 Dear Mr. Wondzell: Attached is an updated report for Well 13-20 for the month of June. As per your request and State sundry approval #397-078 you will find a table showing injection rates as well as tubing and 9-5/8" pressure data for the month of June 1997. The wellhead pressure data is collected and entered daily by the drill site operator and the injection rates are taken from our engineering data base. The well was placed back on injection on 6/5/97. If you require any additional information or clarification, please feel free to contact either Dave Smith or myself 'at (907) 659-5102. Very Truly Yours, Richard A. Ortiz / Da~djD. Smith Problem Well SpecialdM RAO Attachment 7/23/97* Well 13-20's June 1997 Injection Data WELL DATE OF HOURS ON VOLUME Tubing 9-5/8" NUMBER INJECTION INJECTION INJECTED Pressure Pressure (BWPD) (psi) (psi) 13'20' 06/01/97 0. 0 Shut-In 1 0 13-20 06/02/97 0. 0 Shut-In 1 0 13-20 06/03/97 0. 0 Shut-In 1 0 , 13-20 06/04/97 12.1 985 Shut-in 1 0 13-20 06/05/97 24. 1999 1060 1300 .,., 13-20 06/06/97 24. 1956 1060 1300 13-20 06/07/97 24. 2053 1060 1300 13-20 06/08/97 24. 2137 1060 1300 ,, 13-20 06/09/97 24. 2232 1060 1300 13-20 06/10/97 24. 2207 1060 1300 13-20 06/11/97 24. 2164 1034 1350 13-20 06/12/97 24. 2216 988 1250 13-20 06/13/97 24. 2218 1057 1250 13-20 06/14/97 24. 2156 1018 1250 13-20 06/15/97 24. 2197 1025 1250 13-20 06/16/97 24. 2220 1051 1250 13-20 06/17/97 24. 2446 1059 1250 13-20 06/18/97 24. 2370 1054 1250 13-20 06/19/97 24. 2387 1024 1250 13-20 06/20/97 24. 2422 NOt Recorded Not Recorded 13-20 06/21/97 24. 2475 1024 1250 13-20 06/22/97 24. 2366 1063 1250 13-20 06/23/97 24. 2370 1050 1250 , ,,. ,, ,,, ... 13-20 06/24/97 24. 2442 1068 1250 ,, 13-20 06/25/97 24. 2719 1065 1250 , 13-20 '06/26/97 24. 2953 1051 1250 , ,, 13-20 06/27/97 24. 2514 1065 1250 , 13-20 06/28/97 24. 2187 1021 1250 13-20 06/29/97 24. 2310 995 1225 13-20 06/30/97 24. 2260 1077 1225 ,,, Richard Ortiz/Dave Smith Problem Well Specialist ~LRNNING F~UDHU~_ 1U' ~l~O ~IIIIKI Po~ Offi~ Box 10-0860 Anchorage, Alaska 99610-0360 Telephone (907) 276~1215 April ]4, 1997 Mr. Blair Wondzell Alaska ()il & Gas Conservation Commission 3.;01 Porcupine ])rive, Anchorage, Alaska 99501-3192 Rc: 13-20 Sundry Notice and waiver request Dcar Mr. Wondzcll: Attar:bed is a State sundry application for well 13-20. This application requests approval for resumption of PWI injection. Tile 9 5/8" casing continues to demonstrate integrity by the CMIT and we believe control and proper monitoring of PWl injection can be maintained. Details of the proposed monitoring and testing routines to assure isolation are included. If you require any additional information or clarification, please fee] fi'ce to contact either Dave Smith or Richard Ortiz at (907) 659-5102. Very Truly yours, I)i)S/RAO Attachments P~_RNNING PRUDH[JE 12, ],~' HI"K .I. b ' '-'J ,' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION OOMMI~SION APPLiOATION FOR 8UNORY APPROVAL8 ^band~n .... Alter teeing Ohange e~roved program, ARO0 Alllh~.}~ ...................... A~ P,O. Box 1~ An~r~e A~ ~6lO~eO 1~' FNL~ 29eD' FWL, See, 12, TION, R14E, UM At ~t~ ~plh INU · ut,JO r · 9u~pend ...... Oper~on shutdown, He-enter euepe~ed Well Repair weft PlUgOtng ~ TI~ ~e~bn Pull tub~g~ Veda~ Pe~ele Stimulate ~hm X TYI~ d Well Development, I~KplMetmy__ ~tmtlgraphl¢ 10426 feet Plugs (measured) g2~1 fe~t Datum d Elevation (DF OR KB) RKB 64' ?, LJr~ or PI~tlIHy Prudhc~ B.y Unit Well numbs! DB 19-20 I~, Permit number 10, APl number 60-0~g-2070S 11, Fteld/Po~l Prudh~e Bay OII Pool Effective depth: measured truo verik;al 10a62 feet 8191 feet dunk (m~asumd) Measured depth TYue v~lfl~l Oq~k Oonduotor 110~ 20" Production gB45) 0-5/8" t In~ 871' 7" 250 eX PF tl 110' 110' 2300 ex FolldU & 400 sx PF 'C' 9501' 2601' 500 ox el 'G' & 300 ex PF 'C' 0848' 8707' 760 ex oB 'G' 10414' PellofallOl~ dgpth: mea~ured true yJrlJ~nJ Tubing (slze, grade, end measured depth) Peekers and 8BeV (type al~(J ,masutad deplh) 9e4~-oees, eo,;4.ggso, ~Q~O. lOOOO, 1001 ~.1003;, 10064.10084, t~~,E l V ED 10092-10192s 10169-10178, 10207-10317, 1~17-10~37 '- e70~.726, eeoe.e~2, ~41~Sl, eees~ee2, e~1401~, eo20~ ~ ~", C~mco BAL-O ~66V O 2041'~ BeT ~H Peeker O O~S' ~~~ 13, Att~otwne nt~ Dee~rtpllon summary ol proposal ~X Detailed opefMIohe pmgf,,.In ~ T~P ,~kalah~ 14, Estimated date for ~ommenclng operation 16, StatUe eT Welt Na~ ~ s~f~[ .......... DAte fl~prov~ ~ . FOR COMMISMON U6E ONLY ~ae -.---,, SuN)Onded .......W A 'IN ......... OondiUon of appmw,: Notify Oomrnlss,o,, ,o mpm.e,d.,i¥, m.¥ wltne~ Plug integrity ~/ BOP lesI .... looatlon ~oara~o Origina qian~d By ~p~v~by~qfthoCom~s~ioner David W. Johnston ORIGINAL Approvecl C.opy., Returned - t -) P~ANNING PRUDHOE ID: HFK lb 14 :/-I.'-J PlO .UU~ I-' .UO D8 11~-20 SUNDRY NOTICE APPLICATION 4/11/97 mSCUSS~ON Well 13~20 is a WAG injection well that has tubing x IA communication. Thc well had a tubing patch installed over a previously located tubing leak on 10/2/93. Since that time another leak developed in the tubing which was located wl~ a temperature su~ey on 3/15/94. P~ttnent information is as follows: · The leak Is below ~c ~ts~g permm~cnt patch: pulling tubing would be required t.o repair the leak. · Average wellhead b0ccfion pressure on water injec~on is 1200 to ] 400 psi. · The 9-5/8 casing and packer have integrity per a 3000 psi CMIT (Combo ~g and IA MIT) on 4/10/97. {State ~tncsscd - Copy Attached) · The 13-3/8 casing has integri~ per a 2000 psi MIT on 4/~2/97. REOUEST/..ACTION PLAN 1. Allow well to continue watcr-only injection, 2. Cancel 10-403 SundlT Notice dated (3/18/94), since there are no plans lo do 3, Monthly submit to AOGCC: daily Tbg, lA and OA pressures, along wtlh injection rat.es. 4, Compleie Annual CMIT's to confirm continued 9 5/8 casing and packer integrity, {Expected annual cost to ensure integrity is cstimatcd at: $37M/yr.} STATE OF ALASKA ALASKA OIL AND GA8 CONSERVATION COWlSalON Mechet~ical Integrity Test OPERATOR: ,A, Gv'~C~ FIELD I UNIT ! PAD: ,z~L/- D._~. ,?- ~70 DATE: : ::: :::: : ;!:;i:. :" :: ~;:~ :!:: :..'::::.:.-:.-:-::.- i::::: :'(i::::;; 'i:.i : .-' :J: :.-: .[.:::~ .:'.: i':- i :. '. :::: i:!.Ji:.-.'.:.::.::i :..-:; :::.: -::.:-..-..: i-:::F:::: -'.': i; ::::::::::::::::::::::::::::::::: :::.~. ~:::, ..-:~:--?-::?.: :::.::::- ::.--:-: ::: :: .-:::. :,: ::: :.--:;:¥. .::: :: --:: .::: -:- :-: :_ :::: :- : --.-- :. ::.::: :::,;::::ii: ::::: :::;::' ::::' :::: .::,~S ::"~. .;ss..:: ::::'_:::.:-~:..." ":, ....... ...=:::: ?.=...::.:-:::: ~OMh'ENT$' TROUBLE t,~/ELL,r. Th/s m'l has a tub~nF to casing leek. - A pt.'Jg hacl t~,~n set '.~ tubi¢~ in o~der to perl'orm ttle casfr~ MtT test. t _L I , , .... I .... [__.o ·" I ' ' "' "" COMMENTS: OOMMENTS: . I i , _. o ....... ,,, ,,,, ,, ,, ........... 'DBG. INJ. FI. IJID CODES TEST TYPE: ANNULAR FLUID: P.P.G. Grad. WELL TEST: F = FRESH WATER ;NJ. M = .ANNULUS MONITOf~.tNG DIESEL E~'-' E,?5' Initial G = GAS INJ. P = STDANNULI~ P.~ESSURE TEST GLYCOL E~9~;z 4- Year S = ~ T VVATER I N,J. R = INTERNAL RAD TF~RCER SURVEY ~ALT WATER ~ ~ ! ~?_,t~ Worlcover N = .NOT INJECTING A=TEM.c~F-~T~i=~EANOMALYTEST DRILLING MUD '. E~nvJ Other D -- DFFERENT"AL TEMPEi::~T'U-"I:~E TEST OTHER E~ OPERATOR REP S~GNATURE: DA V~,O SMITh' · AOC-,C'C REP SIGI',IATUI:~E: JG~DJEE.XLS BOBBY D FOSTER (Re~ ~. 17/96) GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO.9296 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay . Flopp? ,~Well Job # Log Description Date BL RF Sepia Mylar Disk D.S. 1-2~""~ LEAK DETECTION 021 995 I 1 D.S. 4-1~ TUBG PUNCHER RECORD 021 895 I 1 ,, D.S. ~_~, , RESERVOIR SATURATION 0 2 21 9 5 I ! . D.S.4"'--2,,6,'~ CNT-G 022195 1 1 D.S. 4-19``````) PERF RECORD 021795 1 1 D.S. 4-3,'~ PERF RECORD ' ' 021 995 1 ........ ,1, D.S. 4-48'''''''D PERF RECORD 021 395 I 1 , , D.S. 6- 3',,,"--,-~ PRODUCTION LOG 022195 1 1,, DIS., 7-4A"'"'~ PERF RECORD 021 595 1 1 D.S. 9-2~"'"-,,, ( INFLATABLE BRIDGE pLUG 021 795 1 1 D.S. 9-11"~ PERFRECORD 021 8951 1 I , , , , , , ~D.S. 9-45 '"'-,~ PERF RECORD 022095i I 1 D.S. 13-20~'~-,-~ INFLATABLE BRIDGE PLUG ' ' 021795~ ,!, ' ..... i .... D.S. 11-4A'~,~ PROD PRORLE ....... 022095: 1 1 D.S. 15-11-,~ ~ PROD PROFILE 022095 1 1 D.S. i8-1~...,. _~. DUAL.BURST TDT-p ' '' ... 021895 1 I .. "' D.S. 11-0~ 95.058 DUAL BURSTTDT-P. 021195 1 D.S. 4-t-9~-q5 95057 'DUALBURSTTDT-P 020595 1 , , , , .............. , ,, ,, ,,, ,, Please Sign and return one copy of this transmittal to Sherrie at the above address. RECEIVED · ~A~E: 3. !995 Alaska 0tl & Gas Cons. Commission Thank you. Anchorage ARCO Alaska, Inc. Date- Apr 14, 1994 P.O. Box 100360, . .horage, AK Transmittal #: 94034 99510~ ~, Subject: ARCO Cased Hole Finals From/Location- Telephone: To/Location: John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well Log Date Number (M-D-Y) 04-02-94 i Tool Type i,/' Pen`Record TDT-P i / TDT-P 03-25-94 03-28-94 01-09A 01-11~i 01-33 03-01 i03-27-94i,~ Pen`Record 03-02 i 03-22-94 !~ Leak Detection 03-19 i 03-22-94 ~,/03-29 03-18-94 03-29 03-27-94 03-31 i 03-27-94 Bridge Plug .~ Leak Detection Bridge Plug 1¢' Bridge Plug i /04-43 i 03-29-94!¢ TDT-P -~-.t5!~/ 04-43 03-29-94 !/ CNTG i \.04-43 03-10-94! v' USIT i '~14-28 I 14-35 16-04A l~3-Zq~ 16-18 ~--- ~07_ i 16-28 ~-75 ~' 18-08 03-13-94 !v' USIT 03-29-94 !,,- USIT Cement 03-14-94 iv' Prod Profile 03-18-94 j,/ Perf Record 04-03-94 !-, Perf Record 03-21-94 i,/ Bridge Plug 03-30-94 1,,' Prod Profile Run, Scale 1, 5" 1,5" 1,5" 09-02 03-17-94 03-29-94 1, 2" 1,5" 1 5" 5" 5" 5" 5" 5" 5" 5" 5" 5" 1"&5" i,/ Prod Profile i 1, 5" i./ Prod Log i 1 1"&5" 04-01-94 iv' Pen` Record i 1, 5" 03-16-94 i/ Prod Log c~_._, t 0i 04-44 .... pl~-:Su~ i 04-45 j77-zqi o5-o8 .~z.,-i ~,,i o6-19 ~'?, - (o~ 07-23 '~5'-?(~i 09-01 -/~-tt,, i ?(~---5~ 09-03 '/'7- ~toi 09-19 ~;%-2_~ 09-27 ~,-(¢0i 11-04 ;~o-~FI i 11-17 f~).-Z0~. 11-24A tz.-5~ 12-06A ~2.-Oc~ ¢ 13-20 '~--37..¢ 14-03 ~?_-~'[ ¢ 14-23 !//14-28 32.- i 7....;(/r 14-28 03-22-94 03-16-94 03-29-94 03-18-94 03-15-94 Leak Detection 03-28-94 !-- CNL 03-19-94 t ~ Prod Profile 03-15-94 03-28-94 j ," Perf Record i 1, 5" ,,' Patch setting I 1, 5" i~ PerfRecord i 1,5" Prod Profile i 1, 1"&5" 1, 1"&5" Leak Detection Patch Setting Bridge Plug CNL Pen` Record Leak Detection Pen' Record 03-21-94 03-17-94 03-15-94 03-14-94 03-14-94 03-20-94 TDT-P Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch : Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Scl~ Number of Records: 38 ~V ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany ARCO Alaska, Inc. Date: Subject: From/Location: Telephone: To/Location: P.O. Box 100360, /t orage, AK Mar 18, 1994 Transmittal #: ARCO Cased Hole Finals John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution 94032 Well ~Log Date Tool Type i Run, Contractor Numberf (M-D-Y)I Scale 4-43 i 03-10-94 _ USIT- ! 1,5" C~ement/Corrosio Sch 4-44 I 03-10-94 / USIT- 1, 5" Sch Cement/Corrosio ,. 11-4A ~ 03-10-94 ,/' USIT- 1, 5" Sch Cement/Corrosio ," I 11'24A I03'11'94 / uSIT'Cement/Corrosio t1'5" Sch I 13-20 i 03-12-94 ~lnflatal~ie Bridget 1, 5" Sch ~ w~ plug 5" i ~ 14-20 I 03-11-94 t '/ TDTP ! l r Sch i l 17-16 ~ 03-10-94 1/ Perf record ~ 1, 5" Sch Number of Records: 7 '-"J;Ohn E. DoGroy Distribution: Central Files Phillips Chevron ANO-8 Geology BPX Exxon '~~.~~ Mobil Please acknowledge receipt by signing and returning a copy of transmittal. By: .~('~ (~~'_/h Date: ARCO AI~ Inc. I$ a 8ul~ldlary of AllmnllcRlehfleldCompmny STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 12. 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Change approved program Pull tubing Vadanc( Perforate Name of Operator ARCO Alaska, Inc Address P.O. Box 100360 Anchorage Ak 99610-0360 Location of well at surface 2639' FNL, 131' FEL, Slc. 14, T10N, R14E, UM At top of productive Interval 196' FNL, 2369' FWL, Sec. 12, T10N, R14E, UM At effectNe depth At total depth 301' FSL, 2497' FWL, Sec. 12, T10N, RI$E, UM Type oi Well Stratigraphic, Service 6. Datum of Elevation (DF OR KB) RKB 84' 7. Unit or Property Prudhoe Bay Unit Wal number 13-20 g. Perml number 10. APl number 60-02~-20706 Prudhoe Bay 011 Pool Stimulate O~her X PreSent well condition Summary Total depth: measured true vertical 10426 feat 9251 feet Plugs (measured) Effective depth: measured 10~2 feat true vertical 9191 feet Junk (measured) None Casing Length Size Cemented True verltleal Depth Surface 110' 20" Intermediate 2501' 13.3/8" Production 9845' 9-5/8" Liner 871' 7" 250 ex PF II 110' 110' 2300 ax Fondu & 400 sx PF 'C' 2601' 2501' 500 8x cl 'G' & 300 sx PF 'C' 0845' 8707' 750 sx cl 'G' 10414' 9240' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 9843-9865, 9954-5980, 9990-10000, 10013-10033, 10064-10064, 10073-10083, 10092-10132, 10158-10178, 10207-10217, 10217-10237 8705-5726, 8808-8832, 8841..8851, 8863-5882, 8901-8011, 8920-8020, 8937-8975, 9000-9018, 9046,.9056, 9055-5077 6~1/2", L-80, 9417'; 4-1/2", N-80, 9616' 6-1/2" Camco BAL-O SSSV 0 2041'; BeT 3.H Packer 0 9606' RECEIV£T) 13. Attachments Description summary of proposal X Detailed operations program BOP 8kMch 14. Estimated date for commencing operation 16. If proposal was verbally approved BLAIR WONDZELL 3118194 15. Status of well classification as: OII Name of approver . Date approved 17. I hereby certify that the foregoing is true and correct to the best of my krmwledge. signed ~:::~f,44~_ ~/ ~ . Tit le /¢~t/I/~///~'~,/~' ' FOR COMMISSION USE ONLY Ataska Oil & Gas Cons. Commissb Anchormie Gas Suspended Condilion of approval: Notify Commission so representative may wilness Plug integrity BOP test Location clearance Mechanical Integrity Test Subsequent form required 10- IApproval No. Approved by order Of the Commissioner Form 10403 RevOW15/88 ORIGINAL SIGNED BY RUSSELL A, DO.!:BLASS SUBMIT'IN TR(PLICATE Approved Copy Returned .~ ~ ~-§~, DS 13-20 SUNDRY NOTICE APPLICATION 3/18/94 DISCUSSION Well 13-20 is a WAG injection well that has tubing x 9-5/8 communication. The well had a tubing patch installed over a previously located tubing leak on 10/2/93. Since that time another leak developed in the tubing which was located with a temperature survey on 3/15/94. Pertinent information is as follows: · The leak is small: 3.2 GPM @ 2750 psi differential. · The leak is below the existing permanent patch; p~_d!ing tubing is required to repair the leak. · Average wellhead injection pressure on water injection is 1200 to 1400 psi. · The 9-5/8 casing and packer have integrity per a 3000 psi combination MIT on 3/13/94. · State witnessed MIT passed 3/18/94: (Copy attached) Tbg/9-5/8:2020/2425 psi to 2190/2380'psi in 30 minutes. · The 13-3/8 casing has integrity per a 2000 psi MIT on 3/13/94. · The wellhead has integrity per packoff testing on 2/9/94. ACTION PLAN 1. Allow well to cOntinue water-only injection temporarily until rig repairs can be carried out. Estimated rig arrival: 4th quarter 1994. 2. Record wellhead pressures daffy. RECEIVEO MAR 2~ 1~94 Alasl~ Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: ARCO ALASKA FIELD I UNIT I PAD: PB - PBU - DS 13-20 DATE: 3/18/94 DS 13 -'20 8396' ;5o5' 9. 625 - 47# - L - 80 c~)MMENTS: Plug set in tubing at packer" hole detected 'a~ 922~~ . this is below tubing patch se~ at 9 072'- request weiver till rig can move in and repla.ce T i weiv~r f°r water iijecti°n °nT COMMENTS: COMMENTS: COMMENTS: COMMENTS: II *TUBING INJECTION FLUID: ~' ,... P = PRODUCED WATER INJ. ~. S = SALT WATER INJ ~ ~ M = MISCIBLE INJ. ;0 ~> r'n I = INJECTION 3,. =) ~ ~ N = NOT INJECTING =' Distribution: odg - Well File c o Operator c - Database c - Trip Rpt File c - Inspector ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 6.8 0.35 0.00 0.00. AC)GCC REP SIGNATURE OPERATOR REP SIGNATURE JGglCRBD.XL$ WELL TEST: Initial 4 - Year Workover Other BOBBY D. FOSTER JIM STYLER FI-05i (Rev. 3/93) ARCO Alaska, Inc. Date: Feb 11, 1994 ~-~ P.O. Box 100360, .tchorage, AK Transmittal #: 94021 99510~g~ ~ Subject: From/Location: BHP Report John Degrey/ATO- 1529 Telephone: (907) 263-4310 To/Location: Distribution Well Log Date Tool Type Run, Scale Contractor Number (M-D-Y) 1-9 12-17-92 BHP - Camco 1-14 ' 8-11-92 BHP - Camco 1-14 8-11-92 BHP - Camco 2-2 1-10-93 BHP - Camco 2-13 2-12-93 BHP - Camco 2-35 5-21-92 BHP - Camco 3-15A 3-20-93 BHP - Camco 3-20 12-18-92 BHP - Camco 4-7ST 5-17-92 BHP - . Camco 4-14 1-9-93 BHP - Camco 4-29 12-28-92 BHP - Camco 4-42 4-27-92 BHP - Camco 5-9 2-21-93 BHP Camco 5-16 2-21-93 BHP - Camco 5-25 2-21-93 BHP - Camco 5-31 2-21-93 BHP - Camco 5-33 1-29-93 BHP - Camco 5-35 1-29-93 BHP - Camco 5-36 1-29-93 BHP - Camco 9-24 2-15-93 BHP - Camco 9-40 1-25-93 BHP - Camco 9-51 3-20-93 BHP - Camco 12-7A 12-6-92 BHP - Camco 12-7A 12-10-92 BHP - Camco 12-9 12-10-92 BHP - Camco 12-29 12-14-92 BHP - Camco 13-15 7-3-92 BHP - Camco 13-20 7-4-92 BH P - Camco 13-23A 7-4-92 BHP - Camco 13-32 7-3-92 BH P - Camco 14-11 11-23-92 BHP - Camco 16-19 10-19-92 BHP - Camco 16-21 10-19-92 BHP - Camco 16-30 9-28-92 BH P - Camco 17-3 12-12-92 BHP - Camco 17-10 11-8-92 BHP - Cam(x) 17-11 2-8-93 BHP - Camco 17-20 12-21-92 BHP - Camco 17-21 12-21-92 BHP - Camco 18-15 6-14-92 BHP - Camco MlCO ~ IIio. Is · I~ ~ AlanlloRl~ll~14Comliny RECEIVED FE~ /< 1994 Alaska Oil & (~as Cons. Anchorage C°rr~i$$ion STATE OF ALASKA ALASKA~-'' AND GAS CONSERVATION C~ISSION RI=PORT SUNDRY WELL OP ,'IATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing ..---- Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2639' FNL, 131' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 196' FSL, 2369' FWL, Sec. 12, T10N, R14E, UM At effective depth At total depth 301' FSL, 2497' FWL, Sec. 12, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service 10426 feet Plugs(measured) 9251 feet 6. Datum of elevation(DF or KB) 84 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-20i 9. Permit number/approval number 82-9 i10. APl number 50 - 029-20705 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 10362 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 110' 20' 440 sx AS II 110' 110' Surface 2417' 13-3/8" 2400 sx Fondu & 400 sx PFC 2501' 2501' Production 9762' 9-5/8" 500 sx Cl G 9845' 8707' Liner 871' 7" 350 sx CIG 10414' 9240' Perforation depth: measured 9843-9865'; 9954-9980'; 9990-10000'; 10013-10033'; 10054-10064'; 10073-10083'; 10092-10132'; 10158-10178'; 10207-10237' true vertical 8705-8725'; 8808-8832'; 8841-8851'; 8863-8882'; 8901-8911'; 8919-8929'; 8937-8975'; 9000-9018'; 9046-9074' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 9417' MD; 4-1/2", 12.6#, N-80, PCT @ 9615' MD Packers and SSSV (type and measured depth) 5-1/2" Camco BaI-O SSSV @ 2041' MD; BeT 3-H Packer @ 9505' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation RECEIVED NOV Representative Dail_v Averaae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure .... 11500 -- 1219 .... 11275 -- 1187 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 t n~A/~: ~,AII.-I~ r,r,..qW . IWP Date SUBMIT IN DUPLICAT~ 13-20i TUBING PATCH INSTALLATION DESCRIPTION OF WORK COMPLETED ._ 10/2/93: RIH & set a 3.00" ID Alpha Soft Set Tubing Patch in the 5.5" tubing, from 9073' to 9103' MD (seal to seal), across tubing holes located at 9078' & 9091' MD. PT 9-5/8" @ 2500 psi OK. POOH w/running tool. Rigged down. Returned well to produced water injection & obtained a valid injection rate. RECEIVED NOV 2 A!3'~ka Oii& Gas Cons. Commission Anchorage ARCO Alaska. 1~c. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO ~FINALS 1-22 ~;/- I-I4 /10-1-93 1-29 / 10-8-93 2-16A c[~--l/t~ ,/9-29-93 3-9 ~10-6-93 3-29 ~;~ /10-6-93 3-31 ~10-5-93 3-32 ~07 ~0-5-93 3-33 ~0-10-93 4-4 ~-~ ~0-9-93 Perf Record Run i~rf_Red:~d Run Prod Profile/~; ~e] ~%l~> Run USIT(~e~ t ~olor Run Perf Record ltt~-~i~7 Run Perf Record ~ ~ - ~ ~ R~ Completion R~ Peri Record R~ lnJ ~offie }~~1~1~ R~ ~ ~tectl~~~/~ R~ '7~.-- ~ 4-12'/ 10-2-93 4-24 ~- ~0, ~10-10-93 .l,~...~?.¢-4~ 9-30-93 - 10-1-93 6-12A ~{~- ~ ~9-29-93 I~9 ~O 6-13 10-1-93 7-5 7~-~ 10-6-93 -28 10-9-93 -28 10-9-93 9-11 ~ ~J~ / 10-4-93 9-13 /10-3-93 9-20 '77~ ~ ~ 10-7-93 ** --"11-165T ~10-1-93 12-22 ~t~(~O /9-28-93 /13-20 0-2-93 13-20 ~10-10-93 14-3 ~ ~.~ ~ ~ ~-25-93 14-3~ ~-28-93 14-32 ~10-2-63 15-22 ~~ ~9-30-93 16-17 ~ 10-8-93 16-22 ~ ~10-10-93 17-15 ~ 10-8-93 17-16 ~ ~0-3-~3 17-21qZ~ ~10-4-93 Prod Profile{f~,a Perf Record ~ / 00o ~ ~ I~l~ Run Perf Depth Control/~-~cc~ Run Completion Run Leak Detect I ~ Urm~el ~ Run ~Prod Profile/~ 1~-~1~ ~ Run /Completion Run ~Prod Proffie/~nl~~l~ Run ~Dual Burst TDTP Run Leak Detect{~~cl ~-ff~[ ~ ~ Run InJ Profile I~l~el~e%[~- Run Dual Burst TDTP Run Da~__~__]~ / ~I~m~ ~m~ Run Patch Setting ~(~o-C~Cfl3 Run InJ Proflle]~N~P)~l a~ Run CNTG/GR/CCL Run HLDT[~{¢cL~ Run Prod Proffie/se~at~~ Run Completion %t ~ct-~l~ Run Completion R~ ~od ~offie ~f~nl ~ ~~ R~ Inj ~o~~i ~oduction~t~]~~/~ 1, 5"~t~OO'' tc~o 8ch 1, 5" 8ch 1, 5" '~,~-~ -~.~6o 8ch 1, 5" ~o~--- c~o 8ch 1.2" o-'ctl~ · % Sch 1.1"~" ~%~ 1, ~' ~8~-~o~o0 Sch 1, ~' ~2~- I~%~ ~ch 1, ~'~"o~ ~ 8ch 1, ~'t~~ ~ ~ch 1, 1"~" ~ch 1, ~'~~~ ~ch 1, ~'~-~ Sch 1, ~' io~ -~ ~ch · L ~' Sch 1,~'~l°~ Sch 1, 1"~''~' ~?o Sch 1, 1"~' ~h Please sign and return~ ~. / ~th~ .ttache.d copy/, r~ceipt of data. RECEIVED BY Have A Nice Day! 8onya Wallace ATO-1529 # CENTRAL FILES # CHEVRON #BPX # STATE OF ALASKA The correct APl# for 1-22 is 50-029-20848-00. The correct API# for 11-16.qT is 50-029-21581430. The correct API# for 17-16 is 50-029-22286-00. ARCO ,Uuk~, Inc. P.O.Box 100S60 Anchorage, ~~ ~510 DATE: 7-20-93 REFERENCE: ~CO/C~ED HOLE F~ ~ ~0 * 1-1B~l~v~6-20-93 ~od ~offie 1-16 ?~;~ 6-25-93 Pe~ Record 1-22 ~ ~ .~ 6-29-93 ~ucflon ~g 1-30 ~' ~ ~ 6-29-93 ~ ~tect ~ 6-27-93 Pe~ Record 3-30 ~-~ 6-23-93 3-31 ~-0~6-23-93 3-33 ¢¥-~/o 6-29-93 3-36 ~-!~ 6-28-93 4-37 ~/~7 6-20-93 4-40 ~ I~ 1~6-20-93 5-3A ~3~f 6-18-93 5-26 ~'q ~ ~ 6-25-93 6-4 ?~~ ~z~6-26-93 6-1.3 ~ -30 6-25-93 9-49 c} ~.t3~ 6-22-93 9-50 ~-~ 6-26-93 12-26¢~ 6-22-93- 13-17 ¥~o 6-27-93 13-14 ?~-~ 6-28-93 13-20 ~ ~? 6-19-93 16-12 ~ 6-21-93 17-20 ~ ~-n~6-26-93 ~:~AGI-6 ~ ~-~ 4-25-93 AGI-8 ~ ~- ~ ~ 6-19-93' *'* AGI-Io0~$~ 6-18-93 *** AGI- 6-18-93 Leak Detect Bridge Plug Setting Completion Record Peri Record Dual Burst TDTP (Borax) Completion Record SBT/C~/CCL TDTP (Borax) Production Log Peri Record Production Log .Production Log CNL Leak Detect Leak Detect Plug Depth Record Prod Profile Production Log ~oustic CBT, ~:'~' peri Ree~'rd Peri Record R-r~ 1.5" Sch R-n 1.5" Sch Run 1.5" Sch R._n I 5" 8ch R-n 1, 5" Sch R.~ 1, 2"&5" Sch R._~ 1, 5" Sch R._n 1.5" Sch R.~ 1.5" Sch Run 1, 5" Sch R~m 1, 5" Sch Run 1, 5" Atlas Run 1.5" 8ch Run 1, 5" Sch Run 1, 5" 8ch Rim 1, 1"&5" Sch Run 1, 2"&5" Sch Run 1, 5" Sch R~_m 1, 2" Sch R~m 1, 2" Sch Run 1, 5" Sch R!m 1, 1"&5" Sch R.n 1, 5" Sch Run 1, 5" Atlas Run 1, 5" Sch Run 1, 5" Sch Run 1, 5" Sch Please sign and return the attached .c~p~. u receipt of data. Have l Nice Day~// ' / /~. / Sonya Wallace APPROVED_ ATO-1529 Trans# I)3074 # CENTRAL FILES # CHEVRON RECEIVED # mn,u~s 'dUL 3 0 1993 # CLINT CHAPMAN ## r. XXONMoBIL Alaska 011 & ~as Cons. Commis, ion AnChorage #BPX # STATE OF ALASKA The correct name for-this log is l-lB. This is a revised log, please discard previous copy receive~L The correct APl# for AGI-10 is 504Y29-22353-00. 1. Type of Request: STATE OF ALASKA ALASKA~'L AND GAS CONSERVATION C(.~vllSSION APPLICA¢ION FOR SUNDRY APPROVALS Abandon. Suspend Alter casing Repair well Change _%~prOved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2639' FNL, 131' FEL, Sec. 14, TION, R14E, UM At top of productive interval 196' FSL, 2369' FWL, Sec. 12, TION, R14E, UM At effective depth At total depth 301' FSL, 2497' FWL, Sec. 12, TION, R14E, UM Operation shutdown Plugging Pull tubing Variance 5. Type of Well Development ~ Exploratory ~... ~mtigrephic Service X Re-enter suspended well Time extension Stimulate Perforate RECEIVED JUL - 6 199 Alaska 0JJ & Gas Cons. Commission ;~choraga Olher X 6. Datum of elevation(DF or KB) 84' RKB 7. Unit or Property Prudhoe Ba}t Unit 8. Well number DS 13-20 9. Permit number 82-9 10. APl number 50 - 029-20705 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured : true vertical Effective depth: measured true vertical Caeing Structural Conductor Surface Intermediate Production- Liner Perforation depth: 10426 feet Plugs(measured) 9251 feet 10362 feet 9191 feet Junk(measured) ORIGIn~/iL Length Size Cemented Meaeured depth True vertical depth 110' 20" 250 sx PF II 110' 110' 2300 sx Fondu & 2500' 2500' 2500' 13-3/8" 400 sx PF 'C' 500 sx C~ 'G' 9938' 8969' 9938' 9-5/8" 300 sx PF 'C' 1208' 7" 750 sx Cl 'G' 10848' 9429' measured 9954-9980', .9990-10000', 10013-10033', 10054-10064', 10073-10083, 10092-10132' true vertical 8808-8832', 8841-8851', 8863-8882', 8901-8911', 8919-8929', 8937-8975' Tubing (size, grade, and measured depth) 5-1/2", L-80, 9417', 4-1/2", N-80, 9615' Packers and SSSV (type and measured depth) 5-1/2" Camco BaI-O SSSV @ 2204'; BOT 3-H Packer @ 8709' 13.' Attachments Description summary of proposal X Detailed operations program , BOP sketch 14. Estimated date for commencing operation ~ 15. Status of well classification as: N/A 1 16. If proposal was verbally approved I Oil Gas ~. Suspended Blair Wondzell 06-25-93 I Name of' approver Date approved Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~Z,.¢.(/ ~, ~~ Title Annular C°mmunication Engineer Date FOR COMMI-~-~ION lJ~F ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- .. Original Signed By Approved by order of the Commissioner David W. Johnston Commissioner Form 10-403 Rev 06/15/88 Approved Copy Returned ~. Date SUBMIT IN TRIPLICATE ~I~ION WELL ANNULA~ COMMUNICATION ~ NOTIFICATION OF AOGC~ PER ~ ~ON ORDI~ #4 DATE: June 25, 1993 TIME: 11:00 A.M. NOTIFIED BY: Cathy P. Foerster AOGCC CONTACT: Blair Wondzell ~N: Injection Well 13-20 Annular Communication Per Rule 7 Requirements 'of Area Injection Order No. 4 DISCUSSION: Well 13-20 is a WAG injection well that has tubing x 9-5/8" communication. A leak detection log mn on 4/25/93 indicated leaks in the tubing at 9078', 9088' and 9096' ELM. There is no indication of a wellhead leak per tests conducted 4/9/93 and 3-Pen pressure chart data indicate no communication to the 13-3/8" casing string. A 3000 psi tubing x 9-5/8 combination MIT passed on 6/20/93 indicating competent 9-5/8 casing and packer; a 2000 psi MIT of the 13-3/8 also passed on the same date. ACTION .PLAN: Continue water injection only until a tubing patch is placed over the tubing leaks or, should the patch fail, completion of a rig workover to replace the tubing. A State witnessed MIT will be conducted upon completion of the tubing patch insta~atton and/or workover. Wellhead pressures will continue to be recorded on a daily basis until the tubing x 9-5/8" communication problem is resolved. ~ RESPONSE: Verbal approval granted to inject water only. Sundry Notice Req'd at. this time? '/'ES X NO SIGNED: Well Services Su~)erintendent Orig: Annular Communication Engineer, Styler / Ortiz, PRB 24 cc: Well Services Superintendent, Begnaud / Foerster, PRB 20 Area Operations 'Supervisor, Kennedy / Lash, PRB 20 Area Field Eng, Cooper/Shelden, PRB 24 FS 3 DS Supvervisor, Fausett / Piggott, PRB 13 FS 3 Superintendant, Richards / Roach, PRB 15 DS 13 .Engineer, Easley, ATO 1560 (5/13 / 93) (Sa~d Z o/so/92~ RECEIVED d U L - 6 199 Ala'~a Oil & Gas Cons. (;ornmjsslo~'~ Anchoraoe ARCO ~l, sk,; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ARCO CASED HOLE FINALS ~~0A 4-13-93 ~/.~3-20A 4-28'93 4-23-93 4-23-93 ¥~t;~ 4-22-93 , 4-16 T~-~ 4-18-93 -10 ~Z- ?~1-2-93 7-4A ~ 4,23-93 7-7A ~?~ 4-21,93 ~-27 ~ ~- ~F 4-20-93 ~-31A ~-~ 4-19-93 ~~~~2-13 ~/~ V ~ 1-2-93 ~-- **~2-14~~4-27-93 ~3-20~ 4-25-93 · ~13-25 ~2-~/ 12-26-93 ~~-43 ~-/d~ 1-3-93 ~6-27 ~ ~i 12-27-92 ~7-13 ~V~7~ 4-1~-93 OI-~ ~fl~>~ 4-11-93 Please sign and GR/CCL/Jewelry/Temp Run 1. [~' Camco Tubing Cutter Run 1, [~' Atlas 8BT/GR/CCL Run 1, [~' Atlas Perf Record Run 1, lY' 8ch Jewelry/GR/CCL Tie-In Run 1, 5" 8ch CNL/GR Color Run 1, 5" Sch USIT/GR Color Run 1, 5'* Sch Leak Detect Run 1, 5'* Camco Static Press/Temp Run 1. 5" 8ch Leak Detect Run 1, 2"&~' 8ch Prod Profile Run 1. 5" Camco Production Log' Run 1. 5" 8ch Pressure Build-Up Run 1. 5" 8eh Press/Temp Run 1, 5" 8ch Perf Record Run 1, 5" 8ch Production Log Run 1, r'&5" 6ch Dual Burst TDTP (Borax). Run 1, 5" 9ch Perf Record -- Run 1, ~' 9eh PFC/GR (Packer Set) Run 1, ~' Atlas InJ Profile Run 1, aY' Camco Leak Detect Run 1, 5" Cameo Leak Detect Run 1, ~' 8ch Leak Detect Run 1, [Y' Sch InJ Profile Run 1, ~' Cameo Prod Profile Run 1, ~' Cameo Prod Profile Run 1, ~'8dY' Camco Leak Detect Run 1, 2'&5' 8ch 6BT/GR/CCL Run 1, ~*8d~* Atlas RECEIVED Have A Nice 8onlm Walhce ~ ATO-1529 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # EXXON # MOBIL as re~ of data. 9305 # PB WELL FILES. # BPX # STATE OF AIASKA The correct well -,me for this log is 1-24A. The correct Al)IS for 3-20A is 504)29-209804)1, The correct APl# for 12-148T is 504)29-206594X). ,,..--., STATE OF ALASKA ~.~., ALASKA AND GAS CONSERVATION CC ilSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing ~ Alter casing 2. Name of Operator ARCO ~ska Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2639' FNL, 131' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 196' FSL, 2369' FWL, Sec. 12, T10N, R14E, UM At effective depth ~ Plugging Perforate ~ Repair well .,,.-- Other X~ 5. Type of Well 6. Datum of elevation(DF or KB) Development ' RKB 84' Exploratory Stratigraphic 7. Unit or Property serve, ~ Prudhoe Bay Unit RECEIVED APR ? 199 At total depth Alaska 0il & Gas Cons. C0mm'tss~0~ 301' FSL, 2497' FWL, Sec. 12, T10N, R15E, UM Anchorage 12. Present well condition summary Total depth: measured 10426 feet Plugs(measured) true vertical 9251 feet 8. Well number 9. Permit number/approval number 10. APl number 50 - 029-20705 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 10362 feet true vertical 9191 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Sudace 110' 20" 250 sx PF II 110' 110' Intermediate 2501' 13-3/8" 2300 sx Fondu & 400 sx PF 'C' 2501' 2501' Production 9845' 9-5/8" 500 sx cl 'G' & 300 sx PF 'C° 9845' 8707' Liner 871' 7" 750 sx cl 'G' 10414' 9240' Perforation depth: measured 9843-9865', 9954-9980', 9990-10000', 10013-10033', 10054-10064', 10073-10083', 10092-10132', 10158-10178', 10207-10237' true vertical 8705-8725', 8808-8832', 8841-8851', 8863-8882', 8901-8911', 8919-8929', 8937-8975',9000-9019', 9045-9073' Tubing (size, grade, and measured depth) 5-1/2", L-80, 9417'; 4-1/2", N-80, 9615'. Packers and SSSV (type and measured depth) 5-1/2" Camco BaI-O SSSV @ 2041'; BeT 3-H Packer @ 9505'. 13. Stimulation or cement squeeze summary 14. Intervals treated(measured) Treatment description including volumes used and final pressure Reoresentative Daily Ayeraae Production or Inie~tion Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 9338 BWPD 10053 BWPD 16. Status of well classification as: ,X Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Tubing Pressure 849 psi 615 psi Gas..._ Suspended_._ Service, WAG 17. I hereby certify that the fo~eg,~ng is true and correct to the best of my knowledge. Signed ~ O.~ )k'''-~''~ Title Sr. Operations Engineer Form 10-404 Rev 06/15/88 ,,// cc: s. Wallace/DS Ena" Date ~'/~$/~ SUBMIT IN DUPLICATE WELL 13-20 SUMMARY FOR ADD-PERFORATING AND CONVERSION OF WELL TO WAG INJECTION 3/21/93 MIRU E-line unit and pressure tested lubricator. Perforated zone 4 interval 10158-10178' MD at 2 spf and zone 3 interval 10207-10237' MD at 2 spf reference SWS BHCS dated 2/3/82. RD ELU. 4/2/93 Completed MI line functional check-out. 4 / 3 / 9 3 Converted well to MI. 4/9/93 MIRU Slickline and pressure tested lubricator. Ran SSSV. RD SLU. RECEIV£D Alaska Oil & Gas Cons. CommissiO~ Anchorage ARCO Alask~ Inc. P.O~Box 100360 Anchorage, ALaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS ~S~(~ 1-9 3-29-93 1-11 '7~--~'~ 4-2-93 ~.- I~-S 1-19 3-22-93 1-22 ~--~-7~ 4-6-93 ~--~ 1-29 4-6-93 1-33 ~ ~ 4-4-93 ~~2;8 3-27-93 2-~11 ~~ 4-9-93 7~~ 3-8 3-28-93 3-10 ~-~ 3-28-93 '~ 0 -(o~ 4-2 3-20-93 4-29 ~~3-26-93 ~(~--~3 4-33 3-25-93 5-11 '~';-~O S-29-SS ']~ ~'~ 6-3 4-5-93 6-9 ~c~7~ 4-5-93 ~ ~ 6-18 3-30-93 -4A ~~ ~-4A 4-3-933'22'93 q ~ ~ 5 ~ ~--~-3sa 4- ~ ~ ~ ~ ~ ~-~3A 4-9-~3 ~~!2-11 ~~ 3-31-93 ~3-20 3-2~-~3 ~4-~5 ~q 3-30-~3 q~4-~ 4-=-~3 4-22A 4-2-93 ~6-30q~-~ s-21-~3 ~~~v-=o 3-==-~3 ~7-20 4-3-93 q~5~s-=~ ~s-26 s-24-~3 ~ ~s-27 Leak Detect Run 1. 1",5"&25'* Sch Production Run 1, ~* Sch Production Run 1, fy' Sch Perf Record Run 1, ~' Sch Production Run 1. ~' Sch Perf Record Run 1, ~' Sch InJ Profile Run 1, ~' Sch Perf Record Run 1. fy' Sch Production Run 1, ~* Sch Tubing Puncher Run 1. fy' Sch CNL Run 1, ~* Sch Static Pressure Run 1, ~' Sch Press/Temp/Spin Run 1, :F'&5" Sch Static Pressure Run 1. ~' Sch Production/Gas Entry Run 1. ~' Sch Perf Record Run 1. ~' Sch Leak Detect Run 1, l'&5" Sch Production Run 1. fy' Sch Perf Record Run 1, fy' Sch Perf Record Run 1, ~* Sch Static Pressure Run 1. ~' Sch Perf Record Run 1. fy' Sch Production Run 1. 5' Sch Perf Record Run 1, fy' Sch Production Run 1, ~' Sch PITS Run 1, fy' . Sch Perf Record Run 1, fy' Sch Perf Record Run 1. ~* Sch Perf Record Run 1, ~* Sch Perf Record Run 1, fY* Sch Static Pressure Run 1, fY' Sch GR/CCL Run 1. fY' Sch Static Pressure Run 1. fY' Sch GR/CCL Run 1. fY' Sch Have A Nice Day~ ATO-1529 Tmns# 93050 # ~ ~,-~ # STATE OF ALAS~ ARCO Alaska, Inc. P.O.Boz 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINALS ??-.- ,¢/ 12-s 1-2,3-92 1-18-92 1-34-92 1-18-92 3-8-92 1-26-92 1-26412 1-20-92 3-7-92 3-3-92 1-36-1~ ~/~-/z/_ 13,.6 13-16 ~/-~',t o 13-19 2-9-92 $~-r3 ~ ~~ ~-~ 1~-1 1-~ Pl~e s~ Production Profile l~m L Static Tempemt'm,e Run 1, ~" InJ Profile Run 1. Leak Detect Run 1, Prod Profile Run 1, ~" Leak Detect Run 1, :~'&lO' prod prof/Jewehy mm L Prod Profile Run 1., ~" Prod Profile Run 1, ~" InJ Profile Run 1., znJ Profile Run 1, lnJ Profile Run 1, InJ P.rofl~e ~ 1, IS" lnJ Profile ]h.m 1, Prod Profile .Run 1, IS'* Prod Profile Run 1, and return the attached copy as receipt of data~ RECEIVED BY Have A Nice Day! Cam©o Cameo Cameo Cameo Camco Cameo Camco Cameo Cameo Cameo Cameo Camco Camco Cameo Camco Sonya Wallace ATO- 1529 RECEIVED & Gas Cons. Commission APPROVED _-.~_~' Anchorage Trans# 9205,~-I--- # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON M&RATHON # MOBIL * The R~_~_n Date on this log is 1-23-92. # PB WELL FILF~ R&D #BPX # STATE OF ALASKA TEXACO ~-. STATE OF ALASKA ~ '"~ ALASKA' ~.,~. AND GAS CONSERVATION C( '~vllSSlON APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Perforate X Pull tubing Variance " Other 1. Type of Request: Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address_ P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2639' FNL, 131' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 196' FSL, 2369' FWL, Sec. 12, T10N, R14E, UM At effective depth At total depth 301' FSL, 2497" FWL, Sec. 12, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well Development Exploratory Stratigraphic Service ~X RECEIVED MAR 1 1 199 Alaska Oil & Gas Cons. 60mm'tss[o Anchorage 10426 feet Plugs(measured) 9251 feet 6. Datum of elevation(DF or KB)~ RKB 84' 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-20 9. Permit number 82-9 10. APl number 50 - 029-20705 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured 10362 feet true vertical 9191 feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Surface 110' 20" 250 sx PF II 110' 110' Intermediate 2501' 13-3/8" 2300 sx Fondu & 400 sx PF 'C' 2501' 2501' Production 9845' 9-5/8" 500 Sx cl 'G' & 300 Sx PF 'C' 9845' 8707' Liner 871' ~ 7" 750 sx cl 'G' 10,414' 9240' Perforation depth: measured 9843-9865', 9954:9980', 9990-10,000', 10013-10033, 10054-10064', 10073-10083', 10092-10132' true vertical 8705-8725', 8808-8832', 8841-8851', 8863-8882', 8901-8911', 8919-8929', 8937-8975' Tubing (size, grade, and measured depth) 5-1/2", L-80, 9417'; 4-1/2", N-80, 9615' Packers and SSSV (type and measured depth) 5-1/2" Camco BaI-O SSSV @ 2041°; BOT 3-H Packer @ 9505' 13. Attachments Description summary of proposal X.~ Detailed operations program BOP sketch X.,, 14. Estimated date for commencing operation March 1993 16. If proposal was verbally approved .~/~ ZJ 9.~ , Injector Name of approver ~l,~,'/ bJ~::~_e (} Date approveo Service 17. I hereby certify that the fdr~ing is true and correct to the best of my knowledge. Signed ~ (:~.~~/ Title Senior Engineer ~ FOR COMMIf~;~ON U~E ONLY Conditions of approval: N ~y/Commission so representative may witness Plug integrity ,. BOP Test ,,. Location clearance Mechanical Integrity Test Subsequent form required 10- /-/o ~ Approved by order of the Commissioner 15. Status of well classification as: Oil Gas Suspended ,, Date I Approval Origina~ .... ,~,2ned By David W. johnston Commission~F ........... Date~'~-/ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE.~ Proposed Work to Convert Well 13-20 from H20 Service to WAG Service , . . . Se . Install and pressure test MI line. Perform annular communication testing of wellbore. MIRU slick-line unit, pressure test lubricator, RIH and pull SSSV. Tag bottom with dummy gun. RD and move off location. MIRU E-line unit, pressure test lubricator, RIH and perforate the Sadlerochit sand 10145-10237' MD (ref. BHCS 2/3/82) as necessary to meet target injection. RD and move off location. MIRU slick-line unit, pressure test lubricator, and run SSSV. RD and move off location. Swap well to MI injection. RECEIVED MAR 11 199 Alaska Oil & Gas Cons. Commission Anchorage 1. SO00 P~ 7" w[LL)~.M) 2. SO(X) t)SI WI~CI. INC NMI$ 3. SO00 1)~, 1/t' 4. SO00 I)SI 4 l/e)" rLC~ TUll: R EIE E I,:.V... E.D MAR 11 Alaska 0il .& Bas Cons. ~Anchorage .~.~. STATE OF ALASKA ~ I ALASKA ~ 'AND GAS CONSERVATION CO :ISS Oj~ REPORT OF SUNDRY WELL OPE ATIOI 1. Operations performed: Operation shutdown ~ Stimulate Plugging Perforate X , Pull tubing Alter casing Repair well ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 2639' FNL, 131' FEL, Sec. 14, T10N, R14E, UM Attop of productive interval 196' FSL, 2369' FWL, Sec. 12, T10N, R14E, UM At effective depth At total depth 301' FSL, 2497' FWL, Sec. 12, T10N, R15E, UM Other 6. Datum of elevation(DF or KB) 84' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-20 9. Permit number/approval number 82-9 10. APl number 50 - 029-20705 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Sudace 110' Intermediate 2501 Production 9845' Liner 871 10426 feet Plugs(measured) 9251 feet 10362 feet 9191 feet Junk(measured) None Size Cemented Measured depth True vertical depth 20" 250 sx PF II 110' 110' 13-3/8" 2300 sx Fondu & 400 sx PF 'C' 2501 2501 9-5/8" 500 sx cl 'G' & 300 sx PF 'C' 9845 8707 7" 750 sx Cl 'G' 10414 9240 Perforation depth: measured 9843-9865', 9954-9980', 9990-10,000', 10013-10033, 10054-10064', 10073-10083', 10092-10132' true vertical 8705-8725', 8808-8832', 8841-8851 ', 8863-8882', 8901-8911', 8919-8929', 8937-8975' Tubing (size, grade, and measured depth) 5-1/2", L-80, 9417', 4-1/2", N-80, 9615' Packers and SSSV (type and measured depth) 5-1/2" Camco BaI-O SSSV @ 2041, BOT 3-H Packer @ 9505 13. Stimulation or cement squeeze summary RECEIVED Intervals treated(measured) Treatment description including volumes used and final pressure JAN 2 2 1t 92 14. Re0resentative Daily Averaoe Production or Iniection De~t~ ........................ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Arlcll~i~g Pressure Prior to well operation 7900 1135 Subsequent to operation 8200 1140 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~,~~.~ (~ ' ~~'J-~ Title Form 10-404 Rev 06/15/88 cc: S.Wallace/DS Eng Senior Engineer Service Water Injection Date ~/c,~o/~ SUBMIT IN DUPLICATE SAG RIVER WELL 13-20 PERFORATING COMPLETED 12/26/91 · e e e Rigged up E-line unit and pressure tested lubricator. RIH with perforating guns and tied in to Reference Log. Perforated the Sag River interval 9843'-9865' (Ref. BHCS 2/3/82) at 4 SPF. RD ELU and returned well to injection. RECEIVED JAN 2 2 $¢J92 Alaska Oil & 6as Cons. C~mm~i~n ~flchorage 2 3. SO00 PSI 4 1/6" ~~TOR 4. SO00 PSI 4 ~/~" FI. OW TUll: PACX-M'F RECEIVED JAN 2 2 ~992 Oil & 6as Cons, ~mmissio. Anchorage ARCO ALAg'KA, INC F'~O. BOX ~.0360 ANCHORAGE, ALASKA 995t DATE' t--t 5-92 REFERENCE' ARCO CASED HO~E F~S ~'~,/lll t-S~, ~ 2-29-9t CCL/FERF~.-/' r~ ~ ~-2~ .~ 2-2 ,-9~ CCL/F'ERF' ~ .~ 4-~ ~ 2-28-~ CCL/F'ERF RUN t , 5" RUN t , 5' RUN t , 5 · RUN t, 5" RUN t , 5" RUN t, 5' RUN t, 5 ' RUN t , 5' RUN t , 5 ' PLEASE SIGN AND RETURN tHE ATTACHED COPY AS RECEIPT OF DATA. RECEIV'EI) BY _ _ '__-__ HA~:E A NICE DAY! $ONYA WALLACE ATO-t 529 DISTRIBUTION ATLAS ATLAS ATLAS ATLAS A'~LR~ AILA$ AILA$ ATLAS ATLAS ECEIVED AF"F'RO'v'E~ 2 1 1992. TRAN$~ Alaska 011 & Gas Cons. Commission Anchorage CENTRAL FILES CHEVRON ,,TENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILE~' R & ~ BF'X STATE OF ALASKA TEXACO THE COF..'RECT AI~'].-~: FOR D,S''''~-,,-~-3i- IS s,.q_~oq~_.-.~o,-~,:.~r~ · Type of Request: STATE OF ALASKA ALASKA: AND GAS CONSERVATION CC .JIISSION APPLICATION FOR SUNDRY APPROVAL Abandon , Suspend Operation shutdown ..._ Alter casing -- Repair well Plugging Change approved program , Pull tubing Variance 5. Type of Well Development ,, Exploratory ,, Stratigraphic Service X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2639' FNL, 131' FEL, Sec. 14, T10N, R14E, UM At top of productive interval 196' FSL, 2369' FWL, Sec. 12, T10N, R14E, UM At effective depth At total depth 301' FSL, 2497" FWL, Sec. 12, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Su dace 110' Intermediate 2500' Production 9938' Liner 1208' 10426 feet Plugs(measured) 9251 feet 10362 feet 9191 feet Junk(measured) Size Cemented 20" 250 sx PF II 13-3/8" 2~oo sx Fondu & 400 sx PF 'G' 9-5/8" ~oo sx cl'~ & 300 Sx PF 'C' 7" 750 sx CI 'G' None Re-enter suspended well Time extension Stimulate Perforate X Other ,, 6. Datum of elevation(DF or KB) RKB 84' feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 13-20 9. Permit number 82-9 10. APl number 50 - 029-20705 11. Field/Pool Prudhoe Bay Oil Pool Measured depth True ve~icaldepth 110' 110' 2500' 2500' 9938' 8696' 10,848' 9429' Perforation depth: measured 9954-9980', 9990-10,000', 10013-10033, 10054-10064', 10073-10083', 10092-10132' true vertical 8808-8832', 8841-8851 ', 8863-8882', 8901-8911', 8919-8929°, 8937-8975' Tubing (size, grade, and measured depth) 5-1/2", L-80, 9417'; 4-1/2", N-80, 9615' Packers and SSSV (type and measured depth) 5-1/2" Camco BaI-O SSSV @ 2204'; BOT 3-H Packer @ 8709' 13. Attachments Description summary of proposal X. Detailed operations program BOP sketch X 14. Estimated date for commencing operation ~ 15. Status of well classification as: December 1991 ~ Oil Gas Suspended 16. If proposal was verbally approved I Name of approver Date approvedI Service Injector 17. I hereby certify that the forego~j~is true and correct to the best of my knowledge. Signed ~ ~,[ ~ ~,4/~.,/~___.-- Title Wellwork Coordinator ' ~// FOR C{3MMIfifilON Ufil= ONLY Conditions of approval: Notify ~e~mission So representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test. Approved by order of the Commissioner I Approva' o?~ i . - Subsequent form required 10- L01~NIE C. SMITH Commissioner Date Form 10-403 Rev 06/15/88 c...c;W SUBMIT IN TRIPLICATE ~,~ WELL 13-20 PERFORATING PROCEDURE 1. MIRU ELU and test lubricator. . Perforate the Sag River interval 9845'-9865' MD, (Ref. BHCS 2/3/82) at 4 SPF. 3. RD ELU. -6 5 4 3 2 ¢OILID TIJSI~ UHI! 1. S000 PSi 7' qKLL~ 4X)M~CTOR IrLld~GE 2. SO00 PSI 4 1/1&' PiPE RAMS 3. SO00 PSi 4-1/S# HYDRN~IC: SLIPS 4. S000 PSI 4 1/S'~ RAMS S000 PSI 4 l/r Bi.N) RAMS SO00 PSi 4 1/li# STUFIrlNG BOX 4 I I 3 II 2 ,NIREL liCE, ,,BOP EGUIPI~NT 1. ~)00 PSI?" IKLLHr. AD CONN[C10R 2. ~KXX)PSIW~[LIN[ RAMS (VARL~BL[ 3. ~K)O0PSJ4 1/~" LUBRICATOR 4. SO00 PSI4 1/~" FLow TUB[ PACK-Or !::', O. ~'}:0 X t r.J (~ S 6 A N C I..I C R (:, G Ii:., A l.. A S K A 9 9 5 t DATE: 4-4"'9~ ,',..I:.FI::I',,I::.NbliE' ARCO CASED HOLE I::INALS' 2'-'t 9 2'"t i -9t PRODUCTION F'ROF"II..Ei ~'5 "' 2 :'5 '-' t 6 - 9 t I.. E A K ID IE '1' E C '1" I 0 N 3 '"' 7, t ..... I 8 -" 9 t $ F:' I N N E: R / T I:.:: i"l F:' 3 "" 4 3 - I 7 - 9 t I N ,.J E C T I 0 N 3 .... t (') 3 '" 1 7 '" 9 t I N J E: C T .1:0 N 4-26 t-5-9t F'IT$ 6 "" '2 t 3 '" 6 '"' 9 '1 F' I T $ 7 .... t6 3-t 4-9t F'I'I',~ '7 '"' ;54 5 .... 'l '5 "" ? t I N,.J E: C T I 0 N / 'T E H P 'l t .... 9 'l '""7'"' 9 t F' I '1' $ t i "" ::~: 8t .... I 2 "9 t F' R 0 D LJ C T I 0 N F' R r'}l::'I L I.'.!: t 3'- t 9 3 '- t 6 - 9 t I N ,J F' C '1" I ['l N t 5'"20 3""t 7'"9 ~ INJECTION t L~"-23A 3-t 6--9t INJEC'I'ION t '5""t i 2'"t 2;--9t F'ERF BREAK-DOWN t 6'-2 2-25-9~ ,~F'INNER/INJECTiON ~ Iii .... ~ ~ 3'" 8"' 9 ~ F' 11"5' F;,'UN i, 5" I:;:UN t, 2"&5" F:.LJN1 , 5" FtI. J N t, I:~'.UN t, 5'" F:,'UNt, 5" !::: U N '"~ '::'" · ,.'.. ) ,.:' RUN t, 5" RUN t, 5" RUN i, 5" RL.IN t, .5" R U N i , '5" RUN t, 5" H:UN i ..'5" [;,'UNi, 5:" RUN i ,.'5" RUN 'i ,5" HAVE A NICE DAY. I .................. I"t I:;,' ~' CAHCO H t:~: 5' C AH C [:] [::: ,,':.~ i'q C 0 i..I i:;..' L, i:; ':,'~ · I Ii':,.,~ C A H C 0 C:: A H C 0 1..i F;: ;S' !..i I:;.: ,.~.' CAHCO C A H C 0 C A d C 0 I-.i R $ ~ ~. :', .;.-, ~ , ]1,,,.~ 1"11-;,'5' .,~- . D I .'.'.'."¥ R :1: B I_I'¥ ]: {) N o'f da t'a, F',O. Box ~)~6(~ Ancl'~orage, AI.a.s'ka DATE: REFERENCE: i 3-'i7 5-'i-8T t3-20 5-2-87 i3-22 5-3-87 ,.JuLy t4, i987 ARC(] F're.ssure Da~a Surface F'rem'sure FatLoff Surface F'res.sure FaLLoff Surface Pressure F'a[[off Arco Arco Arco F'Lem.s'e sign and return the atSached copy as receipt of data, Received By ........................................................... H6VE ~ NICE DAY! Rosanne Peek ATO-t 52~ Approved .......................................... Alaska Oil & Gas Cons. Commission Anchorage D I $ T R I B tJ'r I 0 N F'hi Ltipm' PB k'~.:. ~ ;. ;";l.e$ ~ R & D · ~,-'"' I e x a ~. O ARCO ALm.s'ka, Inc, F'.O. Box ~00560 Anc:horage, ALa.s'ka DAI'E: N. ovember t 7, 1986 REF'EF;:FNCE' ARCO Ca,;'ed Hol. e F ina L '""~ '.~-.'?.. 8-27-86 5'pinne¥' ,S'urvey R. un l, ~.~' F:'LopetroL ~ ~- t 5 "~ "' 8-.~Z-86 5'pinner Zurvey Run t, .~" F[ope'tro[ ~ 2-'.t 8 8--~ S-.8~ Temp "' o, F topetro t , .,urvey Run l, .~ ~3-4 o ,.)-)oz. Spir~ner Survey~Temp. ~urvey Run t, .~ '~" F i. ope~'r o L ~3-.6 8-.23-86 ,?p:~r~e¥' Survey Rur~ l, ~ ~ 3-~ 8-22-86 ~'pinner Survey (HuL¢i-ra¢e) Run l, 2" F[opeCro'l. ~ 3_.~-~ . , . .~ 8-23-86 Spi¥~ner Survey/Temp. Survey Ruin ~ 2" F'l. opeCroL ~ 6--9 8-~-86 Temp..~urvey (F'ump in) Run ~ , _2" FLope-tro[ ~ 9-".3t 8-4-86 Spi~nner Ruin l, 2" FLopet'roL ~ 9 32 8-6-86 FBb/,Spinner ~urvey Run t 2" - . ' I ' , :. FLope'troL ~t3-t7 8-2i-86 Spi~her $'urvey Ruin t, ~ FLopetroL ~ t3-2e 8-2~-86 Spinner Survey Run ~, 2" FLope~'roL ~ t=~-.'~ 8-2e.-86 Spi~ner ~.urvey Run ~, 2" FLopetroL F'Leam'e ..~ign mhd reCurn 'the at'l'ached copy am' receip~ of dat'a. Receivecl By. HAVE A NICE DAY! Ro~a~e Peel< ATO-t 529 'i"F:AN $ ~:86736 DISTRIBUTION · ,-'"PhilLips F'B Well Fi le~ R & D :..~ ........ 3. ohio ·.....'"' :! ;:}' $'t-~'.'l.' e' .-o f'A L a ~ k a ' · ~-'"' Texsco ARCO Alaska, Inc. Post Office B~00360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 5, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 13-15 Permit No. 82-157 13-19 81-180 13-20 82-09 13-21 82-53 13-23A 82-23 13-24 82-65 13-25 82-91 13-32 82-123 Attached are the "Intention" Sundry Notices detailing work proposed on the above-mentioned wells. Very truly yours, D. F. S cheve DFS:JEB:dp Attachment CC: SOHIO Alaska Petroleum Co. File Pi(DS 13-15)Wl-3 Pi(DS 13-19)Wl-3 PI(DS 13-20)Wl-3 Pi(DS 13-21)Wl-3 PI(DS 13-23A)Wl-3 Pi(DS 13-24)Wl-3 Pi(DS 13-25)W1-3 Pi(DS 13-32)W1-3 ARCO Alaska, Inc. Is a Subsidiary o! AllanticRichfleldCompany STATE OF ALASKA ALASKA (~ AND GAS CONSERVATION cO~F~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~x OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-9 3. Address 8. APl Number P.O. BOX 100360, Anchorage, Alaska 99510 50- 029-20705 4. Location of Well 2639' FNL, 131' FEL, Sec. 14, T10N, R14E, UM (surf) 196' FSL, 2369' FWL, Sec.12, T10N, R14E, UM (Top Prod) 301' FSL, 2497' FWL, Sec.12, T10N, R14E, UM (TD) 5. Elevationinfeet(indicateKB, DF, etc.) 84' RKB 6, Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-20 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate I'~X Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Arco Alaska, Inc. proposes to perforate well 13-20 at selected intervals within the Sadlerochit sand of the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator tested to 1.5 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 10150-10170'MD Ref: BHCS 02-03-82 RECEIVED Nov 0 ? Alaska 0it & Gas Cons. Commission Anchorage 14. I hereb~ertify thtt~fore~ng~true and correct to the best of my knowledge. I/ //j/ 2,'. i/. Signed ,~ /,,~'~K~-,,"~, ~,~ ~"r~4~'~.--~'~' Title Operations Engineering Mgr. The space below for Commission use Date Conditions of Approval, if any: itl'! I~IItAL SltGIIE:B B'T LOHt~IE C. SMITTI By Order of Approved by COMMISSIONER the Commission Approved Copy Ret~r~ Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~..~ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date: August 20, 1985 Reference: ARCO CH Finals 4-32 Temp Log 8-12-85 Run 11-11 Temp Log 8-12/13-85 13-20 Spinner 8-11-85 '13-98 DIL 3-4-85 13-98 DIL 12-15-83 13-98 DIL 12-27-84 13-98 DIL 11-23-84 13-98 DIL 9-12-84 13-98 DIL 10-28-84 13-98 DIL 6-27-85 13-98 CNL 6-28-85 1 5" Camco 1 5" Camco 1 5" Camco 19 5" Sch 9 5" Sch 19 5" Sch 18 5" Sch 15 5" Sch 17 5" Sch 22 5" Sch 14 5" Sch Please sign Received by Pam Lambert ATO 1429C Trans 275 as receipt of data. ~ .,,~,.,~.., Chevron Phillips D & M PB Well Files Expl. Services R & D Ext. Exploration Sohio Exxon State of Alaska Marathon Texaco Mobil ARCO At.a.~:ka, :Inc'~- F',.O, Bc, x t00368 """ An(::hor..-':~ge, ALaska 995t ,3 I:;,' Iii] F: iii: F;.: Iii] J'"..! [-: E ' A R C !.-.) F:' r e .?..:'.: u, ';- ,:-:-, D .:':': '? ._--~ / .,..n ... ,? ., ~: ..... .'!. ~, (..':, ... 22 --84 ... D,.,?;',. '5: ..... '!'i / 8 ..... ! .... ::i4 D~S~., 6-i 5:~ i !-~5'-~4 r", 2';' 6 .... i 7 ~/ ~ I ....~ =''- o .4. .*.,* ~. .,, , .,..' :..,, , D., S , '; ........ 'J S J 'i i ... ,~, .~".'.., .... :z,,.. z~_. / / :/ D., ,?., ~ :..";-"':'i']i!:: ~/ 'j ({:,-'"2iii .... 84 F:J::'O ;?t.,.',"'...:'ey J:' I. E' .:':'J .5' e ..ii.' i .::j Ti .:'ii i'i CJ T' (.:.:, -l.' U. 'i- T'i '~: J"i .".-::: .:a 4.....:? .-Z i": vZ:: Ci .-Z ,::? !::' 'y' .:':'; Ji.' ':.-" E' C: -'.::-) i l::' '( ;!'? ~:.: A S' 0 i'4 ';.:.' '-' ~'' ~::' ~ :' "" T ,.I r' ,?? ~ · ..,... ~..',- ~ '.. ~ ....... . ~ :: .:~ . AlaSKa 0il & GaS Cons. Commission r-, '.:-'..:, i. i. ':::" ?,,::: !::'..":'1 i" J, ~'~'r'ld Ancho;'sge A T CJ .... ~ :'i. 29 F:' C) '? :... .'..., .:':'i ..-"it C C) H,.'.-., i_-, i i. !-d (::, i::: ! : :!: ~'!-. I", I- ' ' ' ,-;t i L L i j::.'Z .... ,...-i ¥-:', .::, {:.i .? i. I--' T' .-',.t ,..~ [5 -'.] E' . .... 'i::" ,.,.,:. b Yoh i o 'State of' ALas'ka f:' i L e .-r.-: o c:, ,::.' t ..- ......' ;. J:~.'. LL 'A i:;.', u.'n ..i F.,' u.'n"~ I'"-. Li '!"i " J".'~ ,'.i 'rl F.'. u. n -.i i::: 4 :'.. U. i'i J;.'.' L-'.. '~"[ ~... h.i U. ¥i ,.. !'~..' U. '["[ ~ ,. Li '..:",: .") .:t :.. 2" ,.. I::: !1 ... i::.' .:! ... ARCO Alaska, Inc Prudhoe B~'t-,c'-~gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 29, 1984 Mr. C. V. Chatterton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: RE: DS 13-6 Permit No. 81-121 DS 13-9 Permit No. 81-158 DS 13-15 Permit No. 82-157 DS 13-16 Permit No. 82-148 DS 13-17 Permit No. 82-26 DS 13-18 Permit No. 82-35 DS 13-19 Permit No. 81-180 DS 13-20 Permit No. 82-9 DS 13-21 Permit No. 82-53 DS 13-22 Permit No. 82-77 DS 13-23A Permit No. 82-23 DS 13-24 Permit No. 82-65 DS 13-25 Permit No. 82-91 DS 13-32 Permit No. 82-123 In 1983, several Prudhoe Bay Unit producing wells were Converted to injection as part of the Flow Station 3 Injection Project. By review of our records, we have found that intent sundry notices for these conversions were submitted, but no subsequent sundry notices were filed to confirm the conversions. Attached are subsequent sundry notices which provide formal notification of the completed injection well conversions. The dates of the first injection included for each well correspond with data previously submitted in the semiannual progress reports for the Flow Station 3 Injection Project. Very truly yours, D. F. Scheve DFS/RSS/STATE/lmi cc: Sohio Petroleum Company File 100.0 RECEi ED 1984 ARCO Alaska, Inc. t8 a Subsidiary of AllanllcRIchfleldCompany STATE OF ALASKA ALASK~._~!I L AND GAS CONSERVATION ~/IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-9 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20705 4. Location of Well 2639' FNL, 131' FEL, Sec. 14, T10N, R14E, DM (surf) 196' FSL, 2369' FWL, Sec. 12, T10N, R14E, UM (top prod) 301' FSL, 2497' FWL, Sec. 12, T10N, R14E, UM (TD) 5. Elevationinfeet(indicateKB, DF, etc.) 84' RKB 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 13-20 11. FieldandPool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs. Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other ] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted DS 13-20 to a Water Injection well. The date of first injection was 12/15/82. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. , eer The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Office BC~"3~60 Anchorage. Alaska 99510 Telephone 907 277 .5637 May il, 1983 Reference: Arco Cased Hole Finals D.S. 4-15 4-9-83 D.S. 7-7A~ 3-30-83 .D.S. 7-22--- 3-21-83 D. S.~13-20~''- 3-20-83 D.S. 13-25/~ 3-13-83 D.S. 14-6j 4-21-83 ~"-,' --- 3-27-83 D.S. 14-11,.-" 3-25-83 CH CNL ACBL/VDL/S ig/GR/CNL ACBL/VDL/S ig/GR/CN~. EPL . EPL PLS GLV Temp Survey GLV 'Temp Survey Run 1 5" GO Run 1 5" DA Run 1 5" DA Run 1 5" Sch Run 1 5" Sch Run 1 5" DA Run 1 5" Otis Run 1 5" 'Otis Please sign and return the attached copy as receipt of data. Kelly McFarIand AFA-403 Trans. 9 322 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY OF ALAS STATE DALLAS ~ .. CAROL I RE S~ I TH ARCO Alaska, In¢ Post Offic~"'lS"Jx 360 Anchorage, Alaska 99510 July 14, 1~983 Reference: Arco C'aSed Hole Finals D.S. 1-21~--~ 7-2-83 D.S. 2-12---' 5-11-83 D.S. 5-12~'- 5-12-83 D.S. 6-19 6-30-83 D.S. 6-22'-' 7-2-83 D.S. 7-22~- 3-18-83 D.S. 11-4~ 5-27-83 D.S. 13-6' 5-13-83 D.S. 13-6 J~ 5-13-83 D.S. 13-108~. 5-19-83 D.S. 13-2 5-20-83 D.S. 13-26/ 5-21-83 D.S. 13-27/ 6-17-83 D.S. 14-13~ 5-21-83 D.S. 14-22 6-13-83 D.S. 18-1-~ 5-18-83 ~se sign and return the Spinner CH CNL CH CNL Spinner Spinner GR EPL 5" Camco Run 2 5" Sch Run 9 5" Sch Run 1 5" Otis Run 1 5" Otis Run 1 2" & 5" Run 1 5" Sch Hydrostatic Pressure Survey, Drawdown and Gradients EPL Temperature Survey Temperature Survey EPL Collar Log. Temperature Survey Diff Temp Log EPL Run 1 Sch Run 1 5" Sch Run 1 5" Camc¢ Run 1 5" Camc~ Run 1 5,, Sch Run 1 5" GO Run 1 5" Camco Run 1 5" GO Run 1 5" Sch attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. 9 421 Chevron D & M Dallas Drilling Exxon Getty Marathon Mobil DISTRIBUTION North Geology Phillips - .Caroling Smith State of Alaska ARCO Alaska, Inc. Post Office i 360 Anchorage. '~aSka 99510 Telephone 907 277 5637 June 23, 1983 Reference: Arco PressUre Data D.S. 2-25 3-25-83 3-23-83 D.S. 2-26 3-24-83 3-24-83 D.S. 7-7A, 5-29-83 ~.S. 13-6" 4-17-83 D.S. 13-18-' 5-19-83 D.S. 13-20 5-20-83 D.S. 14-13'" 5-21-83 D.S. 18-10c 5-19-83 5-!9-83 Pressure Build-up Pressure Build-up Survey Report Pressure Build-up Pressure Build-up Survey Report Static Survey Ihjectlon Fall-Off Pressure Survey Pressure Draw-down Pressure Draw-down Pressure Fall'off Pressure Build-up Pressure Build-up Survey Report DA¸ DA DA Camco Camco GO sign and return the attached .copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 391 NORTH GEOLOGY R&D DRILLING PHILLIPS SOH I 0 MARATHON CHEVRON DISTRIBUTION EXXON MOB I L GET STATE OF ALAS~ DALLAS CAROLINE SMITH ARCO Alaska, Inc, Post Office B ~60 Anchorage. A~-"~cka 995 i0 Telephone 907 277 5637 April 21, 1983 Reference: Arco Pressure Data D.S. 13-18 ,D'S. 13-20 D.S. 13-23A D.S. 13-25 3-24-83 3-20-83 3-11-83 3-13-83 Pressure Gradient Survey Sch Pressure Gradient. Survey Sch Pressure Fall-Off Survey Pressure Fall-Off Survey Sch 'Sch Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. # 303 ,¥. DISTRIBUTION .. NORTH GEOLOGY R&D DRILLING PHILLIPS EXXON MOB I L GETTY D&M SOHIO STATE OF 'ALASKA MARATHON DALLAS CHEVRON CAROLINE SMITH Anchorage. Alaska 99510 Telephone 90? 7 5637 October 15, Reference: 1982 ARCO Pressure Data .S. 13- 3-5 9-3-82 P~Up Survey GO Pressure Gradient survey D/A Please sign and return the attached copy as receipt of data. Becky Benedict AFA- 403 Trans. #554" .. NORTH GEOLOGY · EXXO .' [ ~ 1 _ DRILLING GETTY · PHILLIPS '. D&M Alaska Oil & L~as Cun~. L;ommissio,~ ' . Aachorage SOHIO '~OL~Y CH~RON DALES ARCO Alaska, Inc. Prudhoe Bay~ lineering Post Office B~360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer November 12, 1982 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D.S. 12-4A D.S. 13-7 D.S. 13-20 D.S. 13-23A Permit No. 81-187 Permit No. 81-129 Permit No. 82-9 Permit No. 82-23' Enclosed are Completion Reports for work done on the above- mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/TKKW/1 mi ~_ncl osures cc' Sohio Petroleum Co. ARCO Alalka, Inc. II a Sublldlary of AtlentlcRIchfleldCompany STATE OF ALASKA ALASKA~ AND GAS CONSERVATION C~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [X~]x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Nameof~Ooerator 7. Permit Number ARCO Alaska, :[nc. 82-9 8. APl Number 3'Ac~r?6s. BOX 360, Anchorage, AK 99510 5o- 029-20705 4. ~) ~, ~u~f~CleFEL, Sec. 14, T10N, R14E, UM Prudhoe Bay Lo a i ~ II at 9. Unit or Lease Name At~6P[°~ilno, In~e~)'FWL, Sec. 12, T10N, R14E, UM 10. Well Number 13-20 At~.I'DF~ 2497'EWESec. 12 T10N R14E UM 11. Field and Pool , , , , , Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc., 16. LeaseDesiclnation and Serial No. Prudhoe Bay 0il Pool 84' RKB J ADL 2r8311 12'Df~2S~d 13'DateT'D'Reached2/4/82 14. DateComp. Susp. orAband.2/19/~2 Il$' water Depth' if °ffsh°reN/A feetMSk 116'N°'°fC°mpleti°nsl ,, 17. Total Depth {MD+TVD) 18.Plug Back Depth{MD+TVD} 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10426'MD,9252'TV[ 10362'MD,9191'TICEsl]~(X NO[]]I 2048 foetMD 1750' (approx) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, GR/CBL "23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20:: 9i.5~ H-40 Surf. ~i' 3U" 440 Sx Arcticset II 13-3/E" 12.0~ L-80 Surf. 2501' 17½" 2400 sx Fondu & 4(10 sx Permafrost 9-5/8" 47.0~ S00-9!./ Surf. 9845' 12¼" 500 sx Class "G" cmt. L-80 .... /,. 20.0 L-80 9543' 10414' 8½- 350 sx Class ,,G,, cmt. ,. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Ref' BHCS 2/3/82 5½" 9615' 9511' 9954- 9980' MD 9990-10000' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.' 10013-10033' MD ...... DEPTH INTERVAL (MD) AMOUNT &:KINDOF MATERIAL USED 10054-10064' MD 10073-10083' MD r 10092--10132' MD 8724' TVD- 8923' TVD 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gastift, etc,) 8/15/82I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 9/30/82 6 I TESTPERIOD I~ 81.9 ' 674 52 27° 823 ~"'Flow Tubing Casing Pressure cALCULATED..~ OIL-SBL GAS-MCF :WATER-BBL OIL GRAVITY-APl (corr) Press. 1262 N/A 24-HOUR RATE I~ : 3225 2653 204 · 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NOV 2 21982 -Alaska Oil & Gas Cons, C°mrnis3tor,~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS· NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Fop Sadlerochit 9945' 9800' )il/Water Contact 10262' 9097' , _ 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~__~_ ~~. ~~ TiceRegional Engineer Date ---- 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 e!evation is used as reference (where not otherwise shown) foridepth 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 onlythe interval reported in item 27. Submit a separate form for each additional interval to be separately produced, shOwing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well' should show the details of any multiple stage cement- lng and the location of the cementing tool. tem 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- Jection, Gas Iniecti.nn, Shut-in, Other-e×plain. November 8, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton- 3-!8 ,- Permit No. 82-35 3-20 - Permit No. 82-9 3-17 Permit No 82-26 ,~DDD] S. 1 3L'~'7~-< Permit No. 82-65 · S. 13-25~'- Permit No 82-91 · S. 13-9z:-'Permit No 81-158 (~ D. _S...,.1 3-2.!~..a- Permit No 82-53 Attached are ~Si~'bsequen~Sundry Notices detailing work done on the a bo v e-me n t ~'i-on~d-~-weTl~'. Very truly ycurs, D. F. Sc heve Reoional Engineer DFS- MAM: ml c Attachments cc- Sohio Petroleum Co. RECEIVED NOV 0 9 1982 Alaska Oil & Gas Cons. Cormnissior~ Anchorage ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany STATE Of ALASKA ALASKA~II, L AND GAS cONSERVATION C(~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER I--I 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-9 3. Address 8. APl Number P.O. Box 360; Anchorage, AK 99510 50-029-20705 9. Unit or Lease Name Prudhoe Bay Unit 4. Location of Wel'l 2639' FNL, 131' FEL, Sec. 14, T~ON, R14E, UN (surf) 196' FSL, 2369' FWL,.Sec. 12, TION, R14E, UM (top 301' FSL, 2497' FWL, Sec. 12, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) RKB 84' 6. Lease Designation and Serial No. ADL 28311 prod) 10. Well Numar D.S. 13-20 11. Field aM Pool Prudhoe Bay Field Prudhoe Oil Pool 12. Check Appropriate Box TO Indicate' Nature of Notice, Report, qr Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13, Describe Proposed or Completed Operations (Clearly state aH pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to convert this well to produced water injection service. The well is presently cOmpleted and perforated in the Sadlerochit; no rig work or additional Perforating ~s required to make the conversion. The choke and check valve direction will be reversed and the necessary instru- mentation changes will be made at the surface. A downhole safety valve will remain in service in this well follewing conversion to injection. A non-freezing fluid was left in all Uncemented annuli within the permafrost interval. RECEIVED NOV 0 9 1982 Alaska 0il & Gas Cons. C0mmissl0r Anchorage 14. I hereby c~ify that the foregoing is true and correct to the best of my knowledge. // Signed ~//~ ~~~~' Title Reaional Ooerations Enaineer The spac~el~;Iow for Commission use v . _ Date ///~C~"/~ -/ / Conditions of Approval, if any: Approved by ORIGINAL SIGNED BY H~RRY W, KUG[ER COMMISSIONER Approved ~opy Returned By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office F' · 360 Anchorage, ~..,~ka 99510 Telephone 907 277 5637 October 15, 1982 Reference: ARCO Pressure Data D.S. 13-20 9-26-82 - _-_i_ '- !_~ n qr "" D.S. 13-5 9-3-82 Pressure Build-Up Survey Pressure Gradient Survey GO ---Tf'lm Please sign and return the attached copy as receipt of data. Becky Benedict AFA - 403 Trans. #554 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON GETTY Alaska 0il & Gas Cons. Commission D&M Anchorage GEOLOGY i~!STATE 0FALAS~ DALLAS Post Office Box 360 Anchorage._ Jaska 99510 Telephon~7 277 5637 October 22, 1982 Reference: ARCO Cased Hole Fi nals D.S. 7'6 9-17-82 D.S. 12-4A 9-6-82 D.S. 13-17 8-3-82 D.S. 13-19 10-2-82 D.S. 13-20 9-26-82 D.S. 13-23A 9-30-82 Completion Record Collar and Perf. Log Collar and Perf. Log Completion Record SPinner Completion Record 11 5" 5" 1! 5" 5" Run 1 Run 1 Run 1 Run 2 Run 1 Run 1 SCH Gearhart Gearhart SCH ' Gearhart SCH /~s.e sign and return the attached copy as receipt of data.' Becky Bendi'ct AFA - 403 Trans. #573 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON · MOBIL GETTY D&M GEOLOGY · sTATE OF/~%ASKA . ,.. m ~, Alaska Oil & Gas (ions. O, . Anchorage. Alaska 99510 Telephone ~ !77 5637 September 14, 1982 Reference: ARCO Pressure Data \. / D.S. 13-7J 8-15-82 D.S. 13-12/8-20-82 D.S. 13-20/ 8-9-82 D.S. 13-10~8-16-82 D.S. 13-8 ~/8-15-82 D.S. 13-17 8-8-82 D.S. 13-18 / 8-3-82 Pressure Survey Pressure Survey · Pressure SurveY ...pressure Survey Pressure Survey Pressure Survey Pressure Survey Gearhart CAMCO D/A Gearhart Gearhart c Co CAMCO ease sign and return'the attached~copy as receipt of data. Becky Benedict AFA- 403 · Trans. # 465 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON ARCO Alaska, Inc. Post Office~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 10, 1982 Mr. C. V. Chat Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D.S. 13-20 - Permit No. 82-9 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned well s. Very truly yours, D. F. Scheve Regional Operations Engineer DFS:TKKW:skh Enclosures cc' Sohio Petroleum Co. ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA'-, /L AND GAS CONSERVATION C ' vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, ]]nc. 82-9 3. Address 8. APl Number P. O. Box 360; Anchorage, AK 99510 5o_029-20705 4. Location of Well 2639'FNL, 131'FEL, Sec. 14, TION, R14E, UM (Surf) 196'FSL, 2369'FWL, Sec. 12, TION, R14E, UM (Top Prod) 301'FSL, 2497'FWL, Sec. 12, TION, R14E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) RKB 84' 6. Lease Designation and Serial No. ADL 28311 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-20 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating operation 8/7/82. RU perforating unit, pressure tested surface equipment. RIH with gun #1, shot 10111-10131'MD 4 spf (20' ref. CNL 2/17/82), flowed to tank for cleanup, monitored rate and took shakeouts. Switched well to HP system. POH -- all shots fired. RIH with gun #2, shot 10091-10111'MD 4 spf (20' ref. CNL 2/17/82), flowed to HP separator for cleanup. POH -- all shots fired. RIH with gun #3, shot 10072-10082'MD, 10052-10062'MD 4 spf (10' and 10' ref. CNL 1/17/81), flowed to HP separator for cleanup. POH -- all shots fired. RIH with gun #4, shot 10012-10032'MD 4 spf (20' ref. CNL 2/17/82), flowed to HP separator for cleanup. POH -- all shots fired. RIH with gun #5, shot 9988-9998'MD, 9973-9979'MD 4 spf (10' and 6' ref. CNL 2/17/82), flow to-separator for cleanup. POH -- all shots fired. RIH with gun #6, shot 9953-9973'MD 4 spf (20' ref. CNL 2/17/82), flowed to separator for cleanup. POH -- all shots fired. Recorded BHP. RD. Ran SSSV. Secured well 8/15/82. 14. I hereby c~ify that the foregoing is true and correct to the best of my knowledge. Signed ....... Title Regional O?ratinn Engino~r Date The space below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate July 21, 1982 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: RE: D.S. 13-17 D.S: 13-18 iD. S ' 13-20~ Permit No. 82-26 Permit No. 82-35 Permit No. 82-9 Enclosed are the "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, I). F. Scheve Reg-[onal Eng±neer DFS:TKKW Enclosures Distribution: Sohio Petroleum Company ARCO Alask;J. Inc ,s a 'Subs,di.ir'i ol Ai'l~nlicRichlieldCo,,~pany :Alaska 0il & Gas Cons. Anchora.qe ~ STATE OF ALASKA ALASKA t .~I'L AND GAS CONSERVATION C(~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-9 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50- 029-20705 4. Location of Well 2639'FNL, 131'FEL, Sec 14, T10N, R14E, UM (~urf) 196'FSL, 2369'FWL, Sec 12, T10N, R14E, UM (top producing interval) Sec 12, T10N, R14W., UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 84' I ADL 28311 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 13-20 11. Field and Pool Prudhoe Bay Field Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate} (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe proposed Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit Sand for production from the Prudhoe Bay Unit. Upon perforating, the well will be flowed to the flow station for clean-up and production. Should additional drawdown be necessary to unload the wells, it may be flowed to a tank for initial clean-up. The perforated intervals will be given in the subsequent report. All wireline work. will be done through a 5000 psi WP BOP/Lubricator, tested to working pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. on Form No. ~ Dated RECEIVED J U L 2 '~. i~82 Alasl(a 0il & 6as Cons. 6mnmJssion Anchorage 14. I hereby ~p~jtify that the~,~regoi~is true and correct to the best of my knowledge. I/l/ Signed ~f/~ ,~j~~'~ ~,~ Title ~Reg, The space below for Commission use Opts. Engineer Date ~~/~'~Z.~ Conditions of Approval, if any: Approved by ORIGINA! SIGNED BY [OH:iIE C. SMITH- ApProved Copy Refurned COMMISSIONER the Commission Form 10~403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate April 28, 1982 Reference: ARCO MAGNETIC TAPES & LISTINGS D.S. 14-29 2/28/82 D.S.6-97''// 3/18/81 D.S.2-19 ~3/24/82 D.S.7-1? 1/11/81 s D;S:~13-.?..0 ~{'17/82 D.S. 15-3 ~/2/82 D S 1-17 2/26/S2 D.S.I-10/ ~8/18/80 D S 14-28 '~ 3/28/82 D.S.7-14 '~'~1/82 D.S 12-1 ,~~2/23/82 D.S 7-11 3/31/82 Tape# ECC 1232 Open Hole Tape# ECC 884 DDNLL Tape# ECC 1255 CN Tape# ECC 878 DDNLL Tape# ECC 1225 CN Tape# ECC 1266 CN Tape# ECC 876 DDNLL Tape# ECC 733 DDNLL Tape# ECC 1262 CN Tape# ECC 1265 CN Tape# ECC 1231 CN Tape# ECC 1264 CN ., Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 131 DISTRIBUTION NORTH GEOLOGY R&D DRILLING MARATHON CHEVRON. ARCO Alaska. Inc. ~s · $~c~,:J.ary cf A?lanl,cRichf~elciCompany MOBIL GETTY D&M GEOLOGY a.as~ 0ii & ~as Co.s. ~nchota~e - · March 26, 1982 Reference: ARCO CASED HOLE FINALS D.S.15-1 2/6/82 CNL Run 1 '5" D~S.13-20 · 2/3/82 CNL Ru~ 1 5" D.S.14-30 2/5/82, CNL Run 1 5" lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmi'ttal# 68 DISTRIBUTION . NORTH GEOLOGY EXXON R&D ,. MOBIL DRILLING GETTY PHILLIPS ~ D&M SOHIO 'GEOLOGY MARATHON STATE OF CHEVRON ~z2 E~C~E3 V E D ~ At-zt~-O 6 lC'q/ ~ Oil & Ba~ Cons. Commission Anchorafle March 25, 1982 Reference: ARCO OPEN HOLE FINALS D.S.15-1 2/7/82 FDC Run 1 5" D.S.15-1 2/7/82 FDC/CNL Run 1 5" D.S.15-1 2/6/82 DIL/SFL Run 1 2" & 5" D.S.15-1 2/6/82 BHCS Run 1 2" & 5" DOS.15-1 2/7/82 Cyberlook Run 1 5" · D.S,!¢3:20 2/3/82 FDC Run'l 5" D.S.13~20 2/3/82 . FDC/CNL Run 1 5" D.S.13~20 2/3/82 DIL/SFL Run 1 & D.s.l%2p 2/3/82 BHCS Run 1 2" & 5" ~; ' ~ "6 ~ D.S 1,3~ 2/3/82 Cyberlook Run 1 5" D.S.14-30 2/5/82 FDC Run 1 5" D.S.14-30 2/5/82 FDC/CNL Run 1 5" D.S.14-30 2/5/82 BHCS Run 1 2" & 5" DS..14-30 2/5/82 DIL/SFL Run 1 2" & 5" D.S.14L30 2/5/82 Cyberlook Run 1 5" ._ ,/~~Please sign and return the attached copy as receipt of data. Mary Fo Kellis North Engineering Transmittal # 66 DISTRIBUTION NORTH GEOLOGY R&D ~ DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBIL GETTY DAM GEOLOGY STATE OF ALASKA ""~" ' 9~,.? .Alaska 0il & Gas Corls. ", ¢"°" Anchorar, F'. March 25, 1982 Reference: ARCO CASED HOLE FINALS D.S.15-15 1/11/82 CBL/:VD Run 1 5" ~,D~:S~I"~'O~ 2/7/82 CBL/VD Run ! 5" DOS.14-30 2/9/82 CCL W/Scient.ific Gyro D. S. 14-30 2/8/82 CBL/VD Run 1 5" D. S. 14-30 -2/8/82 CNL Run 1 5" Run I 5" ~e sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 67 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON March 24, 1982 - Reference: ARCO CASED HOLE FINAL LOGS D.S.14-29 2/29/82 D.S.11-7 2/26/82 D.S.12-14 2/23/82 D.S.11-7 2/.19/82 D.S.13-20 2/17/82 D.S.15-1 2/17/82 CNL Run 1 2'" & 5" CNL Run 1 5"' CNL Run 1 2"/5" ACBL/VDL/GR Run 1 5" CNL Run 1 2"/5" CNL Run 1 2"/5" '-~"· Please· sign and return the attached copy as receipt of data. Mary F. Kell'is North Engineering : Transmittal # 59 DISTRIBUTION NORTH GEOLOGY EXXON '.. R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON Niu.',,? .'.,~, i -.~ Gar; Cons. Commission · ~ '~ ;~'~ STATE OF ALASKA ALASKA C." AND. GAS CONSERVATION CO ~,41SSION WELL COMPLETION OR RECOMpLETION REPORT AND LOG '-1-..Status ef Well ...... Classification of Service Well :' ' '::: : : L ' ~ : . , ' '.OIL [] GAS [] SUSPENDED [] . ABANDONED [] SERVICE [] .... 2. Name of Operator 7. Permit Number ARCO Alaska, ]:nc. 82-9 .... 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 so-029-20705 ,,. 4. Location of well at surface - 9. Unit or Lease Name 2639' FNL, 131' FEL, Sec. 14, TiON, R14E, UM ~v, ,,~ , Prudhoe Bay At Top Producing Interval '_~RIF'~'1 196' FSL, 2369' FWL, Sec. 12, TiON, R14E, UM su~.-- '"' '~--- : 10. Well Number13_20 At.Total Depth 'B. ~. F_- i ' ' ~; 11. Field and Pool 301' FSL, 2497' FWL, Sec. 12, TION, R14E, UM Prudhoe Bay Field I' 5. Elevation in feet {indicate KB, DF, etc. I 6. ,.ease Designation and Serial No. Prudhoe Bay 0i ] Pool 84' RKB ADL 28311 12. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffsho~e ' 116. No. of'Completi°n$ 01-21-82 02-04-82 02-19-82I IN/A feet MSt 1 ,1-~,TotalDepth(MD+TvD, 18.Plug Back Depth ,MD+TVD)19. DirectionalSurvey I 20. Depth where SSSV set I 21.Thickness°fPermafro~'t 10426'MD 9252'TVD 10362'MD 9191'TVD YESJ~] NO[l] 2048 feetMD 1750' (approx.) 22. Type Electric or Other Logs Run DIL/SP/BHCS/GR, FDC/CNL/GR/Cal, GR/CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED :20" 91.5# H-40 Surf 81' 30" 440sx Arctic,s_t ~! 13-3/8" 72.0# L-80 Surf 2501' 17,1/2,, 2400sx Fondu & 40~lsx Permafrn~t 9-5/8" 47.0# S00-95 & SUrf :9845'~ i12'1/4". 500sx. Class G cmt L-80 :' 7" 29.0# L-80 9543' 10414' 8-1/2" 350sx Class G Cmt 24. PerfOrations open to Production. (MD+TVD of TOp:and Bottom and 25. TUBING RECORD interval, size and number) siZE ,, DEPTH SET (MD) PACKER SET (MD)' fi-l/?" 96]5' ~11' N/A, 26. ACID, FRACTURE, CEMENT sQuEEZE, ETC. · . ~. · - . ~ . : , '_ D, EpT.H I.NTE.RVAL.(MD) AMOUNT& KIND OF MATERIAL USED , .- N/A. , ,, . . 27. PRODUCTION TEST , , Date First:Production ,., · : :- : IiMethod,of Operation (Flowing, gaS. lift, etc.) . N/A. ...... ' ' I DateofTest ,our~Tested pRODUCTiON ~OR O~,.-BB,. ~AS-~¢F WATER-DB' ¢.oKES~zE ~AS-O~LRAT~O TEST PERIOD ]~ FIow'Tubing .~ Casing Pressure CALCULATED. OIL-BBL GAs-McF.' WATER-BBL OIL GRAVITY-APl (corr) Press. J : 24.HODR RATE. :.~ ' ' ' 28· CORE DATA " Brief description of lithology, porosity', fractures, apparent dips and presence of oil, gas or water. Submit core chips.i: ~ ' ~ ;i :: i. ~ .~ N/A. , . , ~ ~.-~:, ~::,:, , · f,";:' :? :i; :!, ~ ': '!::' ,,, Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9945' 9800' 0/W Contact 10,262' 9097' N/A. - .... 31. LIST OF ATTACHMENTS Drilling Hi story ._ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,,~~"~~~ T~tleArea Drlg. Enginee~te-~//~/~-, INSTRUCTIONS General' This form is designed for submitting a Complete and correct well completion report and log on all types of lands a~Jd 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: !.ndicate 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. ARCO Alaska, Inc./'''~'' Post Office b~x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Si r' Enclosed are Well Completion Reports for the following drill sites- 13-20 15-1 1A-14 1A-15 WS 23 Also enclosed are monthly reports for February on these drill sites' 11-7 13-23A 14-29 14-30 15-2 Ei leen No. Oliktok Pt. 1 No. I Copies of the DS 13-20 gyroscopic survey were sent to you under separate cover. Si nc ere 1 P. A. Van Dusen District Drilling Engineer PAV-JG/hrl Enclosures GRU2/B14 RECEIVED A!aska 0il & Gas Cons. Comrnissio~ ~chorage ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany DS 13-20 Drilling Hi story NU 20" Hydril and diverter. Spudded well @ 1730 hrs, 01/21/82. Drld 17 -1/2" hole to 2501'. Ran 59 jts 13-3/8" 72#/ft, L-80, BTC csg, w/shoe @ 2501'. Cmtd 13-3/8" csg w/2400 sx Fondu cmt & 400 sx Permafrost. _ ND 20" diverter Instld 13-3/8" packoff &' tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok Tstd csg to 1500 psi ~ ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 9'65'. Ran'238 jts 9-5/8" 47#/ft,s00-95 & L-80, BTC csg w/shoe @ 9845'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok' Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld 'FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,426'. Arctic packed 9-5/8" x 13-3/8" annulus. 'Ran 21 jts 7" 29#/ft, L-80, BTC csg fr/9543'-10,414'. Cmtd 7" lnr w/350 sx Class G cmt. Drld cmt to 10,362' PBTD. Ran GR/CBL. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. 5 DS 13-20 Drilling History Cont'd Ran 5-1/2" completion assy w/tail @ 9615' & pkr @ 9511' Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. ' NU tree & tstd to 5000 psi - ok. Displaced well to diese). Dropped bail & set pkr Tstd tbg to 3000 psi & annl to 200 psi - ok. · Tstd tbg to 200 psi & ann] to 3500 psi - ok - · Closed SSSV @ 2048' MD. Inst]d tree cap & tstd to 5000 psi - ok. Secured we!) & re)eased rig @ 2400 hrs, 02/08/82. Gyro-Multishot survey ran 02/19/82. JG:hrl 03/18/82 GRU2/B5/6 DS 13-20 Drilling History NU 20" Hydril and diverter. Spudded well @ 1730 hrs, 01/21/82. Drld 17-1/2" hole to 2501'. Ran 59 jts 13-3/8" 72#/ft, L-80, BTC csg, w/shoe @ 2501'. Cmtd 13-3/8" csg w/2400 sx Fondu cmt & 400 sx Permafrost. ND 20" diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 12-1/4" hole to 9 ~65'. Ran 238 its 9-5/8" 47#/ft,S00-95 & L-80, BTC csg w/shoe @ 9845'. Cmtd 9-5/8" csg w/500 sx Class G cmt. Instld 9-5/8" packoff & tstd to 5000 psi - ok. Tstd csg to 3000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 10,426'. · la~ im~lsPl~c~le~-, Arctic packed 9-5/8" x 13-3/8" annulus. Ran 21 jts 7" 29#/ft, L-80, BTC csg fr/9543'-10,414'. Cmtd 7" lnr w/350 sx Class G cmt. Drld cmt to 10,362' PBTD. Ran GR/CBL. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. DS 13-20 Drilling History Cont'd Ran 5-1/2" completion assy w/tail (a 9615' & pkr @ 9511' Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. ' NU tree & tstd to 5000 psi - ok. Displaced well to diesel. Dropped ball & set pkr Tstd tbg to 3000 psi & annl to 200 psi - ok. · Tstd tbg to 200 psi & annl to 3500 psi - ok. Closed SSSV (a 2048' MD. Instld tree cap & tstd to 5000 psi - ok. Secured well & released rig @ 2400 hrs, 02/08/82. Gyro-Multishot survey ran 02/19/82. JG'hrl 0 / 8/8Z GRU2/B5/6 JOB NUMBER A0282G0285 ~~ l Eastman f , ~-~, Whipstock l A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TIONA L SURVEY ARCO ALASKA, INC. COMPANY DS 13, Well ?Tumber: 20 WELLNAME Prudhoe Bay, North Slope, ,Alaska LOCATION TYPE OF SURVEY Gyro-Multi Shot DATE 19-Feb-S2 SURVEY BY A Hickman OFFICE Alaska March 3, 1982 ARCO ALASKA, INC. P.O. Box 360 Anchorage, Alaska 99510 Well Number: DS 13-20 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Gyro-Multi Shot Date: 19-Feb-82 Method of Computation: Radius of Curvature Surveyor: A Hickman Job Number: A0282G0285 Attn: Bob Hines Dear Mr. Hines, We are enclosing the original and sixteen copies of the Gyro-Multi Shot Survey run on the above mentioned well. To date, the following distribution has been accomplished: A. 1 copy telecopied to E/W North Slope office for delivery to ARCO field r'epresentives. B. 16 copies delivered to drilling for in-house distribution. C. 3 copies for E/W permanent well files. We wish to take this opportunity to thank you for calling on our services and we trust that we may continue to serve your needs in the future. Sincerely, District Operations Manager ST/bb cc: file enclosure Directional Drillers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO ALASKA, INC. ......... DS--1-~"~-W£'L~'L~'- N O: ........ 20 F'RUDHOE BAY, NORTH SLOPE, AI_ASKA GMS, 0-10~00 MD, SURVEYOR; A HICK~AN, DATE RIJN; ]9-FEB-B2 C~MER~ .... NO'~ ....... 1~1'0~ 90 DEG,' A/IJ'NO. 1..]0 GYRO NO; 624 FORES)GHT; N49W .. VERTICAl. SECTION CAI_CUL. ATED IN F'L. ANE OF~PROPOSAI- , DIRECTION~ N 45 :DEG 48: HIN ° RECORD OF SURVEY RADTUS OF CURVATURE METHOI] 50 ALASKA, INC. COMi::'UTATION I::'AGE NO. .1 13, WELL NO; 20 GMS ,lOB NO; A0~.8,=60~8,~ TIME DATE JDHOE-BAY, NORTH SLOPE, Al:ASEA : :-:'~ , 09:45:4'4 ......... Oil=MAR=82: TRUE ~$URED-DRIFT DRIFT COLIRSE' VERT!t:CAI: VERTICAI~ SUBSEA R E C T A N G U [. A R C L~ O'S~U R E ~DOGLEG" EF'TH ANGLE DIRECTION L.ENC~TH DEPTH SECTION TVD C 0 0 R D ~ N A T E S rIISTANCE DIRECTION SEVERIT' FEET Ir; M D M O. 0 0 0 0 100. 0 0 0 0 200. 0 15 S 16 0 W 300. 0 15 S 15 0 W 400. 0 ~0 S 28 0 E 500. 0 0 0 0 600. 0 30 S 11. 0 E 700, 0 0 0 0 800. 0 0 0 0 900, 0 15 S 36 0 E 1000. 0 15 S 20 0 E 1100. 0 0 0 0 1,200.. 0 0 0 0 J300, 0 15 N 56 0 E 1400. 0 15 S 80 0 E ]500. 1600. 1700, 1800, 1900. 0 0 0 0 0 30 S 20 0 E 045 S 4 0 E 0 30 S 4 0 E 0 15 S 13 0 E 2000. 2100, 2200, 2~00. 2400. 0 30 S 64 0 E 1 0 S 42 0 E 0 30 S 48 0 E 0 45 S 31 0 E 045S 16 0 E 2500, 0 45 S 16 0 E 2600. 5 0 N 5 0 E 2700. 5 15 N 5 0 E 2800. 9 30 N 5 0 E 2900. 12 15 N 34 0 E FEET FEET FEET FEET FEET O. 0.00 0.00 -84.00 0,00 ~00. 100,00 0,00 16.00 0,00 100. 200',00 0',19 116~00 0,21 S 100. ~00.00 -0.57 216,00 0.6~ S 100. 400.00 -0.96 ~16.00 1.27 S 100, 500,00 -],08 4]6,00 100, 599,99 -1,S2 515,?? ]00.-, 699-,,~99 ....... 1.,56 6]5,99 100. 799.99 -].56 715.99 ]00. 899.99 -~.59 815.99 ]00. 999.99 -1.7] 9]5.99 1.65 S 2.08 S 2.5i S 2.51 S 2,68 S 3.07 S 100. 1099.99 .1.00. 1199.99 ]00o 1299.99 100. 1399.99 100. 1499.99 100. ]599.99 -loBO 1015,99 - ,1:,. 80 ] 115/,99 -1 ~.58,, 12,15,99 - 1 ;:2 2 "] 3~],~, · 99 -1.10 :1415.99 -1.28 15:15.99 100. 1699.98 ....... -1,85 ~615.98 ],00. 1799.98 -2,56 :1.715.98 100. ]899,97 -2.94 18].5.97 ]00, 1999.97 -3.00 1915.97 100. 2099.96 -2.80 2015.96 100. 2199.95 -2.79 '2115.95 100. 2299.95 .100. 2399.94 100. 2499.9~ 100. 2599,78 100. 2699.38 100. 2798,53 ]00. 2896.7~ -2.88 2215.95 -3.34 2315.94 -3.96 2415.93 -1.18 2515,78 5.58 2615.38 15,30 2714,53 32.03 2812.73 3,27 S 3.27 S 3.15 S 3.06 S 3,10 S 3.51S 4.57 S 5,66 S 6.31S 6.80 S 7.59 S 8.51S 9.35 S 10.55 S ]1.80 S 11.46 S 2.56 S 10.22 N 27,8] N FEET D M DG/IOOF' 0,00 0,00 0 0 0.00 0.00 0.00 0 0 0.00 0.06 W 0'o'22 ....... S 16 ........ O~ W 0',25 0..1.8 W 0.65 S 15 40 W 0.00 ().JO W :1.27 S 4 42 W -0.36 0.10 E 1.65 S 3 30 E 0,50 0.:18 E 2.09 S 5 4 E 0~g~ 0.27 E 2,52 ....... S 6 5'-"E 6 .~ 0.27 E 2.52 S 6 5 E 0,00 0.40 E 2.7:1 S 8 23 E 0.25 0.60 E 0.67 E 0.67 E 0.85 E 1.27 E 1.48 E 1.63 E 1.86 E 1.94 E 2.03 E 2.43 E M.47 E 4.39 E 5.08 E 5.60 E 5.96 E 9.50 E 10.28 E 11.40 E ]7.63 E 3.13 S 11 3 E 0.07 3.34 S 11 38 E 0.25 3~34 S 1'1 38 E 0,00 3.26 S 15 10 E 0.25 3.31 S. oo~. 32 E 0.19 3,44 S 25 35 E 0.25 3.87 S 24 57 E 0.50 4,94 'S"22-' 8 E 5,98 S 18 53 E 0.25 6.63 S 17 51 E 0.26 7.22 S 19 38 E 8.34 S 24 33 E 0."~7 9,58 S 27' 17 E 0,51 10.64 S 28 31 E 0.31 11.94 S 27 58 E 0,20 13.22 S 26 48 E 0.00 14,89 S 39 39 E 5.71 10.59 S 76 O'E 0.25 15.31 N 48 7 E 4,25 32.93 N 32 22 E 6,04 :CO ALASKA~ ]'NC, COHPUTAT ]' ON PAGE NO, 2 ; 13, WELL NO~ 20 GMS .!OB NO AO.~8~GO.~ 8., T I ME DAl~E ~UDHOE-BA¥'~ .... NORTH'""SI,OPE'~ ...... AI_A. KA TRUE ;A'SURED'~'~DRIFT .............DRIFT ............ COURSE'"'VERTI'CAE'"VERTICAL SL;BSEA R E C T' A N G U l. A R C L' 0 S'U R"E DOGLEG ~EPTH ANGl. E DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECT]'ON SEVERIT FEET [~ H D M FEET FEET FEET FEET FEET FEET D H DG/iOOF' , 3000, 15 O. N 35 0 E 100~ 2993,90 55,12 2909,90 47,23 N 30.97 5 3100. 17 30 N 34 0 E 100, ~089,90 82,56 3005,90 70,29 N 46.82 E 3200'~ I8'30~'N 36 O'E I00~ .......3]'85¥0] 112+92 310],01 95~60 N 64,54 E 3300, 20 15 N 37 0 E 100, 3229,34 ]45,65 3195,34 122,26 N 84°27 E 3400, 23 ]5 N 37 0 E ]00. 3372,21 182.27 3288,2]. ]52.85 N 106o57 E 56,47 N 3S 15 E 2,76 84,45 N 33 40 E 2,52 115,'34 .... ]48,49 N ~4 35 E 1,78 185,52 N ~5 4 E 3500, 25 0 N 36 0 E 100, 3463,47 222,60 ~379o47 184,71N ]30,88 E 3600, 27 15 N 37 0 E 100, 3553,25 266,05 3469,25 220,10 N ]57,07 E 3700'~ 30 ...... 0N'36 0 E 1'00, 364]~02 3"13~32' ~3557,02 258;61N 185.56 E 3800. 32 30 N 36 0 E 100. 3726,50 364,44 3642,50 300.57 N 216o05 E 3900, 34 45 N 37 0 E 100, 3809.76 419,08 3725,76 345,09 N 248.99 E 226,38 N 35 19 E ],80 270,40 N 35 3]. E 2 "~ 318,30 N-..35 -40..-E ......... ~..~ 370.17 N 35 43 E 2,50 425,53 N 35 49 E 2.32 4000, 36 ]5 N 37 0 E 4100, 37 0 N 37 0 E 4200,36'45-N'37 0 E 4300, 37 0 N 37 0 E 4400, 37 0 N 37 0 E 100, 3891.]7 100, 397]..43 100, 4051.42 100. 42.32°42 100. 4211,28 476,47 3807,17 535,42 3887~'4~ 594,72 3967.,42 654,02- 4047,42 72.3°50 4127'28 391,46 N 283.~4 E 439,11N 319.84 E 487',03 N 355,95 E 534.95 N 392,06 E 583,01 N 428,28 E 483,5? N 35 57 E 1,50 543,24 N 36 4 E 0,75 603,24 N 36 ]0 E 0~25 ........ 663.24 N 36 ]4 E 0,25 723.42 N 36 18 E 0.00 4500, 37 0 N 37 0 E 4600, 37 ].5 N 37 0 E 4700, 36 ]5 N 38 0 E 4800, 36 0 N 38 0 E 4900, 35 30 N 38 0 E 5000, 35 45 N 39 0 E 5100, 36 ]5 N 39 0 E 5200, 36 0 N 39 0 5 5300. 36 0 N 39 0 E 5400. 36 15 N 40 0 E 5500, 36 45 N 40 0 E 5600, 36 45 N 41 0 E 5700. 36-30-N 41 0 E 5800. 36 30 N 42 0 E 5900. 37 0 N 42 0 E 100. 4291.15 772,97 4207.2.5 631.08 N 2.00, 4370,88 832,6] 4286,88 679,28 N 100. 4451,00 89],82 4367,00 726.75 N 100. 4531,77 950,23 4447,77 773,20 N 100. 46]2,93 1008.]1 4528,93 819,24 N 100, 4694.22 1065.89 46]0.22 864,83 N 100. 4775.12 1124.26 4691.12 910.51 N 100, 4855,89 '1282,79 '4771,89 956,33 N 100, 4936.79 1242..16 4852.79 1002.00 N 200. 50]7,57 1299.76 4933,57 1047.49 N 100. 5097,95 1358.93 502.3,95 1093,06 N 100, 5178.08 ]418,51 5094,08 ]138,56 N 100, 5258.33 1477.96 5174.33 2183.58 N 100, 5338,72 ]537.27 5254.72 ]228.13 N 100. 54]8.84 1596.97 5334.84 ]272.59 N 464.50 E 500,82 E 537.24 E 573,54 E 962,70 N 36 34 E 609,5] E 1021.11 N 36 39 E 645.77 E ]079.33 N 36 45 E 682.76 E 1138.07 N 36 52 E 7!9,86 E 1196.98 N 36 58 E 756.85 E 1255.72 N 37 4 E 794°35 E 1314,62 N 37 1~ E 783,59 N 36 21 E 0,00 843,95 N 36 24 E 0,25 903.77 N 36 '28 E ],17 0,25 0,50 0 Oo 2.=;" 0o00 0,64 832,59 E ]374.04 N 37 18 E 871,45 E 1433.78 N 37 26 E 9!0.58 E 1493.33 N 37 34 E 950.00 E 1552,67 N 37 43 E 990.03 E 26J2.35 N 37 53 E 0.50 0,60 0.25 0.59 0.50 ALASKA, INC. COMPUTATION F'AGE NO. 3 ; 13, WELL NO; 20 [.~tt$ ,lOB NO: A,O282G0285 TIME DATE ~UDHOE-BA'Y', .........NORTH "SL OPE ,'~ AI:ASK'A ~ ()9".~ 45':'4'4 ............. O.~='MAR=B2 ......................................................................... TRUE !,ASUR, ED~-DRIFT DRIFT COURSE~ VERTICAI:"-VFRTICAI,: ....... St. JBSEA R'"E"'C T A N G li L A R C l.: O"S"LI'"R'"'E ......... DOGLEE IEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TV]:i C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERII FEET D M D M FEET FEET FEET FEET FEET FEET D M DG/100F 6000. 37 30 N 43 0 E 6100. 37 45 N 43 0 E 6200, 38.15 N 43 0 E 6300. 38 15 N 44 0 E 6400. 38 30 N 44 0 E 6500. 38 45 N 44 0 E 6600. 39 15 N 45 0 E 6700, .... 39 15 N 45 0 E 6800. 39 0 N 45 0 E 6900. 39 0 N 45 0 E 7000. 38 30 N 45 0 E 7100. 38 30 N 45 0 E -7200, 38 15 N 44 0 E 7300° 38 0 N 44 0 E 7400. 37 30 N 43 0 E 7500. 37 15 N 43 0 E 7600. 37 0 N 43 0 E 7700.' 36 30 N 43 0 E 7800. 36 15 N 43 0 E 7?00. ~5 15 N 43 0 E 8000. 35 0 N 43 0 E 8100, 34 15 N 43 0 E 8200. 33 45 N 42 0 E 8300. 32 30 N 42 0 E 8400. 32 15 N 42 0 E 8500. 31 30 N 42 0 E 8600. 31 0 N 41 0 E -8700. 30 45-N 41 0 E 8800. 30 0 N 41 0 E 8900. 29 0 N 40 0 E 100. 5498,44 ~657.40 5414.44 ~317.22 N 1030.~2 E ~672.68 N 38 3 E 0.79 100. 5577.65 17~8.38 5493.65 1361.87 N 1072.56 E 1733.52 N 38 13 E 0.25 100. 5656,45 ..........t'???'.'87 5592',45 ~406~90 N ~114.55 E ~794~87 N"'38"23 E 0,50 100. 5734.98 ~841.73 5650.98 1451.80 N ~57.~6 E ~856.54 N 38 33 E 0.62 100. 5813.37 1903.78 5729.37 1496.46 N 1200.29 E 1918.36 N 38 44 E -0.25 100. ,,891.,,,0 2966.17 5807.50 1,:41.36 N ~,=43.6~.~ E 1980.52 N 38 54 E 0.25 100. 6046'~'6,~ >:09z.,'c ,~ ~962"'~'65 1630.99 N 13:?;2 o 50 E 2]06"i"I0 ......... N'"'39 .... 1-o'-'E O, 100. 6124.23 2J55 44 6040.23 J675.60 N 1377.1~ E ~J68.89 N 39 25 E O.$~ 100. 6201.94 2218.37 6J17.94 1720,10 N ~421.62 E 2231.54 N 39 34 E 0.00 100, 6279,93 ....... 2280.95 6]95.93 1764.36 N 1465.87 E 2293,85 N 39 43 E 0.50 100, ~6358, ,38 N ~509.89 E ~.....~,'~s 85 N 39 52. E 0,00 100 · 6436. ':::i:' 1852,66 N ] ~- 24 ,~,.3 JO0:' i::6515.26 246:i~ 64~1.26 189Y.OY N J596.30 E 24Y9.32 N 40 5 E 0.25 100o 6,~94o ::: ~ 33 ~ :1:941'4B N 1638.44 E ~,~540.44 ~ 40 10 E 0.79 100. 6673.79 2588.77 6589,7?- 1985.88 N ~679.83 E 2601.07 N 40 14 E 0.25 100. 6753.~.,,. 2649.06 6669.52 2030.02 N 172].00 E ..9661.35 N 40 17 E 0.25 100. 6833.65 270B'~826749~65 2073.77 N ]76].80 E 2721,12 N'40'-'21"E 0.50'- 100. 6~]4o 17 2768.05 6830o17 2117.15 N 1802. . ~.., E 2780.36 N 40 24 E 0 25 100. 6995.32 282'~o41 6911.32 2159.88 N 1~42.]0 E 2838.73 N 40 28 E 1.00 JO0. 7077.11 2883.88 699~.11 2201.96 N ]88J.34 E 2896.21 N 40 3] E ~00. 7159.40 2940.63 7075.40 2243.51 'N ~920.09 E 2952.98 N 40 34 E 100. 7242.30 2996.45 -7158o30 2284.74 N 1957.86 E 3008.86 N 40 36 E 100. 7326.05 3050.98 7242.05 2325.35 N 1994.43 E 3063.4~ N 40 37 E 100. 7410.51 3104.4J 7326.51 2365.14 N 2030.26 E 3117.03 N 40 39 E JO0. 7495.4~ 3157.10 7411.43 2404.39 N 2065,59 E 3J69.82 N 40 40 E 100. 7580.92 3208.83 7496.92 2443.24 N 2099.97 E 3221.69 N 40 41 E JO0. 7666.75 3259.97 7582.75 2481.97 N 2133.64 E 3273.01 N-40'41E JO0. 7753.02 3310.36 7669.02 2520.13 N 2166.81 E 3323.57 N 40 41 E 100. 7840.05 3359.39 7756.05 2557.58 N 2J98.79 E 3372.81 N 40 41 E 0.~5 0.75 1..25 0.25 0.75 0.72 0.25 0.75 I .11 ALASKA, INC. 13, WELL NO: 20 GMS ~JOB NO; AO,~8,.GO,:85 JrHOS! BAY, NORTH SLOPE, Ai_ASKA COHPtJTAT:I'ON PAGE NO. 4 'T I PiE DA TRUE ~SURED"'DRIFT DRIFT ................ COtJRSE~'VERT"ICAI:'~-VERTICAI, SUBSEA R E C T A N G U L. A R C-"[7"~'O-S'~'~U~R""E BOGLEG EF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT~ ;EET D M D M FEET FEET FEET FEEl' FEET FEET D M DG/100Fl ?000. 27 30 N 4J 0 E 100. 7928.14 3406.,.,. 7844.J4 2593.57 N ~9.53 E 3420.14 N 40 41E 1.57 7100. 25 45 N 42 0 E 100. 80J7.53 3451.20 7933.5~, ,.~6~7.J3,. N 2259.,.~ E 3464.95 N 40 42 E 1.81 ~200. 24 ...... 0 N 44 0 E 100; 8~'08;"25 ......... 3493.2~ 8024.25 2657.89 N 2287,9J E 3506~¥98 ........ N'-~O~43~"-'E 1,94 9300. 22 45 N 46 0 E 100. 8200.04 3532.88 8116.04 2685.94 N 23J5.96 E 3546.54 N 40 46 E 1.48 ~400. 21 30 N 48 0 E 100. 8292.68 3570.53 8208.68 27~1.63 N 2343.50 E 3583.98 N 40 50 E 9500. 21 30 N 50 0 E 100. 8385.72 3607.12 8301.72 2735.67 N 2371.J6 E 3620.26 N 40 55 E 0.73 ~600 21 ~0 N ~.~ 0 E 100. 8478 76 ~643 62 8~94.76 2758.7~ N ,.~9.64 E ~6,~6.3~ N 41 I E 0 9700. 21 30 N 52 0 ~ 100, 8571'~·c80 ~680,06 8487.80 2781.30 N 2428;~52'~E 3'692¥~3~ ........N-4"~ ......... 8"~E 0, 9800. 21 45 N 54 0 E 100. 8664.76 3716.62 8580.76 2803.47 N 2457.95 E ~728.41 N 4~ 15 E 0.78 9900. _ ~1 15 N 54 0 E 100. 8757.81 3752.89 8673.81 2825.02 N 2487.60 E 3764.16 N 41 22 E 0 0000. 20 15 N 51 0 E 100. ~885~.~2~ , ~788.08 8767.3~-~. 2846.~8 N ,_~.1~..71 E 3798.92 N 41 28 E 1.46 0100. 20 0 N ~1 0 E 100..~894~.,.~.~,~,~.,34~ ~ ~'~-~ 8861. 21 2868 .24 N 2542. ..45 E ~8~2.86 N 4~ 3~ E 0.25 0200. 20 0 N 51 0 E 100. :,9039.]8 ..,.,:~8,6 40 89,~o 18 2889 76 N 2569 03 E 3866'~'60 N"41 38"E 0.00 0300. 20 0 N 49 0 E 100. :::91~3.~5 ~890.51 9049.15 29~1.74 N 2575123 E 3900.44 N 41 4~ E 0.68 , E FOLLOWING STATIONS ARE F'ROJECTED~:FOR,,.INTERPOLATION VAI.LIES '362 MD - F'BTD 0362. 20 0 N 49 0 E ~426 MD- TD 0426. 20 0 N 49 0 E 62. 9191.41 391~.68 9107.41 2925.66 N 2611.23 E ~921.48 N 41 45 E 64. 9251.55-' ~93~.54 9167.55 2940.02 N 2627.75 E ~943~19 N 4] 47 E 0.00 0.00 FINAL CLOSURE - D~RECTION; D~STANCE; N 4] DEGS 47 MTNS 24 SECS E 3943.]9 FEET ARCO ALASKA, 1NC.o ~ I:S~ ...................... ::L;~, WELL NOo· "* .~0~' GMS ,JOB NO,' ..... ,',A6~'~Qn~5~...~,~..., .... .................. ~ F'RUDHOE BAY, NORTH SLOPE, AI. ASKA GMS, 0-~0300 MD~ SURVEYOR~ A HICKMAN, DATE RUN~ 19-FEB-82 CAMERA-NOt ........ 1'~:'06 90-DEG,-'',A/U NO~ ] I]0 GYRO NO; 624 FORESIGHT; N49W RECORD OF INTERPOLATED SURVEY CO ALASKA, INCo. COMPUTATION PAGE NO. 1 13, WELl. NO: 20 GMS ,JOB NO; 'AO282G0285 TIME l)ATE" UDHOE"'"-"BA'Y~ ........ NORTH- SI:OPE'"~ ...... AI~A SE A ': ....... ................. 09"1' 50":0~ ........... 0 S~ M AR ~82 MARKER ....... TRUE SU~SEA ......................................... ~D~'- .................................................. MEASURErs"' VERTICALS' MD~]'V~ 'VERTICAI~ R' E-"C'-T'-A'~'N'"G'~"U"[:" A'~'R C"L 0" S U" R~ E VERTZ'CAI~ NAME DEPTH T~EF'TH [~IFF 3.~EF'TH C 0 0 R D I N A T E S DTSTANCE [IIRECTION THICKNESS FEET FEET FEET FEET FEET FEET D M OP OF SADLEROCHIT 9~45,00 8799,89 ~45,] BTJ. 5,89 28~4.72 N 2500,25 E 777~.80 N 4~ 25 E /W CONTACT ~0262.00 ~097.44 ~J64.6 90~,44 290~,79 N 2585.27 E ~887.58 N 4] 4~ E BTD ~"0362';00 9J. gJ.,4]. 1170,"6 9]07','4J 392i+48 .... N 41 45""E D J0426.00 9251.55 1174.4 9167,55 2940.02 N 2627,75 E ~94~,]9 N 4J. 47 E i"" I .... i NORTH '2 40;01, ERST CiOSuREF3943. lg: N 41. ARCO Alaska, Inc. /'~ Post Office Bo..,60 Anchorage. Alaska 99510 Telephone 907 277 5637 March 16, 1982 Mr. C. V. Chatterton Stat'e of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' DS 13-20, Gyro-Multishot Survey Dear Si r' Enclosed are two copies of the. completed gyro-multishot survey for DS 13-20. Sincerely, J', Gruber Associate Engineer JG:hrl Enclosures GRU2/B15 ARCO Alaska. lnc is a $[Jl~.~;idia~¥ ,;f AllanticRich,qeldCompa;]y ....·' .... WhiPstoCk 1 ;..-..t;_:.-;.:::;;_':.'-:~:..'~.:_~.-.-.-_;.._-~.;.-....-; ..... -;.-.-~-.;.:~.~.;.2..._:~..%_·.-- ;-.;-..:.=-~;:;-_:..;.7~_'.:;'.;:.-..;--:'_~.-:_.."....:s.::*.'-- .;:'-', '--- -':.--:.:. 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'----',','---'-::-' ...... -',"'.--.~'~:' ..... :':-'~" -:::-::-' .... '----- ": ~' '- .... ~chorage --' ' -,..-' ..... -~=:=.-~:::::V:-,::::'::~-''"':-~-'"----'::::":'"·::' ~-,.;._:_,:~:.,-.. .... _-__-.~:_-_-.-_:-,-_-:-:::~-~--~-=,..·:....- ..................... . ..... _ - -......- .: .... - ........ :~'.:~'_':--;~-'::::::_"..;:':~-.'-' ;;-i:---' ---*-':'-i; '"':.-"-'.-~.Y':.:-.((:..:-.}'f-;:/'::}:-.f::'"'S-uI~'V'E~" B'Y"-;i;;';;;'~'i~::;:.-:_:.;'.;'i:}::!(~?.:;:: ':' :'-'i'.-.-?:':::'-" ":* :" -: '--. OFFICE ' · :.".;:~::: ::: ::':.'-:7:::.. :7.: .', _~..::.::'-7:,-~-.:.;.:.:~:-::_.::-: . .:~; ...... :' '_ .-~.:'.-JL'.': :..:- t'-'. '.'.' :..-:.~. ..: .' -_.- .':.: :-:::-7 .: : ': '_ ' --. . · '. · . .. .................................................. :: .'~;~'.:_'::;: :..t¥~:v.L '?F.'F.*.t:-'.Tt'.L'.':-"::'..'.'.:7:' . · ::;-~:t.:: .... :" . . .: .... 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DRIFT- .............. COLIRSE "VERT-ICAI,-"VERT]'CAI: ...... SUBSE-A ...... R' E 'C"T""A ~N-"G-"I;I-L;'"'-A-R ............... C-I~:'"O"'-S U R E DOGL~E8 !F'TH ANGLE D~RECTION L.ENGTH DEF'TH SECT.TON TVD C 0 0 R D I N A T 5 $ DISTANCE DIRECTION SEVERIT :LET D M D H FEET FEET FEET FEET F'EF.;T FEET D M .rfG/100F O, : 0 O' 0 0 O, 0,00 0,00 -84,00 0,00 0,00 0,00 0 0 0,00 100, 0 0 0 0 :100. 100,00 0.00 16.00 0,00 0,00 ~ ' 0,00 0 0 0.00 -.200.-.----0-&5,.S-.--t-6 ............ O--W ............... 100. .................. 200.00 .................... 0...19 ................ 6...- 00 ....................... 0.'.21' ..... S 300, 0 15 S 15 0 W 100, 300,00 -0,57 216,00 0,6~ S 0,18 W 0,65 S 15 40 W 0,00 400, ' 0 ~0 S 28 0 E 100, 400,00 -0.96 ~16,00 1,27 S (),JO W ],27 S 4 42 W 0,~6 500, 0 0 0 0 100, 500,00 -],08 4J6,00 1,65 S 0,10 E ].,&5 S. 3 70 E 0,50 600, 0 ~0 S 11 0 E 100, .59~ 99. -1o,2. .,=-15.99 ..-~,08 S 0'o]8 E -700-.: ....... 0 .... 0 .............. 0 ............ 0 ] 00. ........ 699..99 ..................... 1.56 .......... 6] 5 .-99 ................... 2 o.-51 ......... S ........ 800. 0 0 0 0 100. 799.99 -:J.56 715.99 2.51 S 0.2Y E 2.52 S ~ 5 E 0.00 900. 0 15 8:36' 0 E JO0. 899°99 -J.59 815.99 2.68 S 0.40. E 2.Y:J $ 8 2~{ E 0.25 · LO00, . 0 15 S 20 ' 0 E JO0+ 999o99.~:~...~-1o7J 9J5,99 :3,07 S 0,60 E S,17 S lJ ~ E 0,07 : 99 ~.:~<,:.,:...1.+80 ~ 27 S ~ 0J67 E ~ ~4 S 11 S8 E 0 25 ' .: . ~ ~ · ' [300, 0 15 N 56 0 E J00~'~:.::':1299,99 -1,58:.~'~:.:1215,99 ~:. 3,15::S ~(~85 E S,26 -S 15 10 E 0,25 4 O0 0 1 5 S 80 1500, 0 0 0 0 100, 1499,99 -1,10 J415~:9.9~y:~/.:/:::'S:,.::lO./~'S 1,48 E ~,44 S 25 S5 E 0,25 [600, 0 ~0 S 20 0 E 100. J599,99 -1,28 15J5,99 ~.51 S 1~6~ E ~,87 S 24 57 E 0,50 ~700, ........... 0-'-45"S'~ 4 0 'E 100," 1699,98 .... -1,85 J615,98 4,57' S .................. t800, 0 ~0 S 4 0 E' 100, 1799.98 -2,56 1715,98 5,66 S 1,94 E 5,98 S 18 5~ E 0,25 ~900, 0 15 S 1~ 0 E 100, J899,97 -2,94 18J. 5,97 6,~1 S 2,0~ E 6,6~ S 17 5J E 0,26 2000, 0 30 S 64 0 E 1.00, 1999,97 -3,00 1915,97 6,80 S 2,43 E 7,22 S 19 38 E ~100, I 0 S 42 0 E 100, 2099,96 -2,80 2015.96 7,59 S [f,47 E 8,34 S 24 ~ E ~200, ........... 0--'"~0-'" S"'48 ..... 0-'E ....... 100, 21~9~ 95 ............ 2,7~ ....... 2t'J 5, ~5 ............. 8,51 S ................. 4'~'~-E ......... ~e58 .... S' '27' 17 E 2300~ ~400, 0 4~ $ 31 0 E 100. 2299,95 -2,88 2215.95 9,35 S 5°08 5 10,64 S 28 31 E 0 45 S 16 0 E 2.00. 2399.94 -3.34 2315.94 10.55 S 5.60 E 11.94 S 27 58 E ~500. 0 45 $ 16 0 E 100. 2499.93 -3.96 2415.93 ]1,80 $ 5.96 E 13,22 S 26 48 E 0.00 2600, 5 0 N 5 0 E 100, 2599,78 -1,18 2515,78 11,46 S 9,50 E 14,89 S 39:39 E 5,71 0.57 0,51- 0,31 0.20 2700.~--5--15--N .... 5 ..... O"E ..... 100. 2699~'38. ........... 5'.58 ........ 2615~'38 ........ 2~'56-'-$ ......... 10-¢28-'E~10~'57 .... 8-76 0 E 0'~=-. ~.. 2800, 9 30 N 5 0 E 100, 2798,53 15,30 2714,53 10,22 N 11,40 E 1= .,,31 N 48 7 E 4,25 2900. 12 15 N 34 0 E ].00. 2896.73 32.03 2812.73 27.82 N 27.63 E ~2.93 N 32 22 E 6.04 ~0 ALASKA, INC0 ~ COMPUTATION PAGE NO. 2 - . )~ % .~ '~ =- . 13, WELL NO,' .20 GMS ,0 JOB N(). A(,,8~GO,,8J TIME .DATE TRUE ISURED DRIFT DRIFT COURSE VERT..CAI, VERIlCAI- SLIBSEA R ............... C-[ ..... 0'I'S' IJ R E DOGLEG :F'TH ANGLE DIRECTION I..ENGI'tt DEPTH SECTION TVD C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT~ 'EET II M D M FEET FEET FEET FEET FEET FEET D M DG/100F~ ;0000 15 0 N 35 0 E 100. ,~99~,90 55.12 ~909.90 47.2~ N ~0.97 E 56.47 N BB 15 E 2.76 ;100. 17 ~0 N ~4 0 E 100. ~089.90 82.56 B005.90 70.29 N 46.82 E 84.45 N BB 40 E ~.~.~. ;~00 20 15 N ]7 0 E 100. ~279 ~4 345.65 ]195.E4 1~.~.26 N 84.27 E ]48.49 N ~4 B5 E 1.78 1400. 2~ 35 N ~7 0 E 300. E~72.21. 182,27 ~288.21 ]=~,1.85 N 106.57 E 185.52 N ~5 4 E ~.00 ;500. 25 0 N ~6 0 E 100. E46E.47 ,.,.~°~.60 ~79.47 184.71 N 3~0.88 E ,~,~ · . ~":' 220 10 N ],.,7. · · ;6000 27 15 N ~7 0 E 100 ~55E.25 266 05 ~469.,~,. . = 07 E 270 40 N ~5 71E 2 [800o ~2 ]0 N ~ 0 E 100. ~72&.50 ~64.44 ~642.50 ~00.57 N ,,1~."~ 05 E ~70.17 N ~5 4~ E 2..50 · . ~= 76 S45.09 N 1248.99 E 425.5E N ~900. S4 45 N ~7 0 E 100 ~80907& 419 08 ~91.46 N 283.94 E 439.11 N: 319.84 E 95,: E 06~E 28: E ;500. 37 0 N 37 0 E 100. 4291.15 772,97 4207,./]:5,",'~:?/,~6'~1,",08f,:N 464'.50 E 783.59 N 36 21E ;800. ~7 15 N ~7 0 E 3.00. 4370.88 8~2.6J 4286.88 879,28 N 500.82 E 84~.95 N ~8 24 E ]TOOl ........ ~6"35N B8'O E 100. 4451',00 B93.824167.00 726.75 N ...... 537.24'E ......... 903,77 ...... N36 28 E ~800. 36 0 N 38 0 E 100. 4531.77 950.2~ 4447.77 773.20 N 573.54 E 962,70 N 36 ~4 E ;900. ~5 ~0 N ~8 0 E 100. 4812.9~ 1008.]1 4528.97 819.24 N 809.5] E 1021.11 N ~8 ~9 E ~000. ]5 45 N ~9 0 E 100. 4694.22 1065.89 4630.22 864.8] N 645.77 E 3.079.3~ N ]6 45 E ~100. ~6 ]5 N ~9 0 E 100. 4775.12 1124.26 4891.12 910.51 N 882.76 E 11~8.07 N ~6 52 E 483,59 N 35 57 E 1.50 543.24 N 36 4 E 0.75 603'~24 ...... N"-36'30 E 0'25 88~.24 N ~8 ]4 E 0,25 72~.42 N ~8 18 E 0.00 0,25 ].17 0.25 0.50 0.50 ~200i ..... 36 ......0-N-"39 .... 01[ ...... ]I00i 4855,18~ ........ 1382'""79 ....... 4771"89 ..... 956','~3~N ...... ?19,86-E---I'198'~98 ...... N-"36 58 E' 0'~" ..... 5300. 36 0 N 39 0 E 100, 4936.79 1241.16 4852.79 1002.00 N 756.85 E 1~==,..,~.72 N ~7 4 E 0.00 5400. 36 15 N 40 0 E ]00. 50].7.57 1299.76 4933.57 3047.49 N 794.35 E 1314.62 N 37 10 E 0.64 5500. 36 45 N 40 0 E 100. 5097.95 1358.93 503.3,95 1093,06 N 832.59 E 3.374,04 N 37 18 E 5600. 36 45 N 41 0 E 100. 5178.08 ]418.5] 5094.08 3138.56 N 871.45 E. 3433.78 N 37 26 E 5700~36-"]0--'N-'41 ..... O-"E ........... 100. 5258~33'"1477','96 ..... 5174,~ .... 3'18~,58--N ..... 910158'-E-'--I493~'~3 .... N"'37'34 E ~800. 36 30 N 42 0 E 100. 5338.72 3537.27 5254.72 ]228.13 N 950.00 E 1552.67 N 37 43 E 5900. 37 0 N 42 0 E 100, 5438.84 ].596.97 5334.84 3272,59 N 990.03 E 3632.35 N 37 53 E 0.50 0,60 0,25-- 0.59 0.50 0 ALASKA, INC. COHPUTATION FAGE' ~ NO. · 13, WELL NO; 20 GMS JOB NO: A0~8~G0~.8o · TIME DATE. DHOE--BAY', ...... NORTH -..c 09 .~LOPE, 'AI.ASKA : I'RUE ~SURED-DR,IFT ................... DR I FT ....... COURSE VERT I CAl, :PTH ANGLE DIRECTION LENGI'H · I)E:'PTH 'EET D H D H FEEl' ,000. ~7 30 N 43 0 E ,100. 37 45 N 43 0 E' ,200.. .......... 38--,15-N*..-4~ ..... 0 .-,E ............... ,300. 38 15 N 44 0 E ,400, 38 30 N 44 0 E VERTICAl. SUBSEA R 'E' 'C l'-"-'A '-N""'D'-"LI'-'L-A-'R ............... C-L-"O'-"S' LI' R E DOGLEG' SECTION TVD C O 0 R D ]' N A T, E S DISTANCE DIRECT.TON ~EVERIT' FEET FEET .. FEET FEEl' FEET D Pi DG/100F' 100. 5498.44 ]6~'.,7.40 ..,414.~ 44 ]317.m2~ N 1030.92 E ],672.68 N 38 3 E 0.79 100. 5577 65 1718 38 5493.65 1361 87 N 1072.56 E 1733.52 N 38 13 E O.°~ 100 ~; ~ ~',~' a . ....... ~6.,6'.'45 ....... 1779.87 .~.~7~.,45 ]406-~0'-N ........ ]114w"55"E ........ ]7~4'w-87 ....... N'~8 2~ E 0.50 100. 57~4.98 ]841.73 5650.~8 1451.80 N ]]57.]6 E ]856.54 N ~8 33 E 0.62 100. 581~.37 190~.78 ="'~ ~,7~9.~7 14~6.46 N 1200.2~ E 1918.~6 N ~8 44 E 0.25. ,600. 39 15 N 45 O E ,700:. ..... 39-.--t5-,.N.-~,45 ...... O--.-E ,800. 39 0 N 45 0 E .500. 38 45 N 44 0 E 100 100 100 100 ,900. 39 0 N 45 0 E 100. 6201.94~.~.,."°t8.37 6117.94 1720.10 N ]421.62 E 2231.R4.. N 39 ~' ~.5. 5891..,0 ]966.17 5807.50 1541.36 N 1°,:43.65 E 1980.52 N 38 54 E O. 5969.21 2029 08 .,88.,.21 1586.~ N 1287.76 E 904~.16 N ~9 4 E O, 6046'.65 '~n~o S5 5962~65 .... 1630,99-"N ........ ].'S32",'50"'E ..... 2],06'i'10 ...... N"S9 15 E O, 6124,2~ · 2155.44 6()40.2~ ]675.60 N 1377.12 E 2168.89. N 34 E' 0.00 '000. 38 30 N 45 0 E '100. 38 30 N 45 0 E '200-. ........ 38 ..... 15..N 44 .... 0 E '300. 38 0 N 44 0 E '400. 37 30 N 43 0 E '500. 37 15 N 43 0 E '600. 37 0 N 43 0 E '700.. .... 36-'-30 N 43 0 E '800. 36 15 N 43 0 E '900. 35 15 N 43 0 E )000. 35 0 N 43 0 E ]00. )100. 34 15 N 43 0 E ]00. )200~ ..... 33'-'45-N 42' 0 E ].00. )300. 32 30 N 42 0 E 100. )400. 32 15 N 42 0 E 100. 1007, 6279.9~;;,;~:2280.95 6]95.93 1764.36 N 1485.87 E 100;~:: :6358.19~:i,,234~,'20!;L¢~6274~1,9;!!,¢71808o38 N ] 509.89 E 100'" 6436 59~ 2405';'2.7 ?' 6352~;;59, .i;!718,,~. 66 ~.;N,'.';.d,,~ ~,41 E ]00' 8515.26 2466.:~8:,,~,,84~1.26 1897.07¢N ]596~30 E 100. 667~.79 2588.77 6589. i,79,'r,¢/].:985:.88A, N ]679.83 E 2601.07 N 40 100. 6753.52 2649.06 6669.52 2030.02 N 172]..00 E 2661.35 N 40 100. 6833.65 2708.82 6749.65 ' 2073.77 N ]76]',80' E ....... 2721','12 "N 40 100. 6914.17 2768.05 6830.17 2].17.15 N 1802.25 E 2780.36 N 40 100. 6~95.32 2826.41 6911.~2 2159.88 N ].842.]0 E 2838.7~ N 40 7077.11 2883.88 6993.11 2201.96 N ].88].34 E 2896.21 N 40 7].59.40 2940.63 7075.40 2243.51N ].920.09 E 2952.98 N 40 7242.~0' 2996.45 7158.30' 2284.74"N 1957.86"E .... ~008,86"'N 40 7326.05 3050.98 7242.05 2325.35 N 1994.4~ E ~063.49 N 40 7410.51 3104.4] 7326.51 2~65.14 N 2030.26 E 3117.03 N 40 2293.85 N 39 43 E 2~55.85 N 39 52 E 24].7,'73' N ~9 59 E 2479.32' N 40 5 E 2540.44 N 40 10 E 14 E 17 E 21E 24 E 28 E 3:1 E ;34 E 36 E 37 E 39 E 0.50 0.00 O. 25 0.79 0.25 0.25 0.50 O.~ 1.00 0.75 0.75 1.25 0.25 1500. 31 30 N 42 0 E 100. 1600. 31 0 N 41 0 E 100. 1700-.'~'30-45--N-41 .... O-E 100. )800. 30 0 N 41 0 E ]00. )900. 29 0 N 40 0 E 100. 7495.43 3157.10 7411.43 2404.39 N 2065.59 E 3169.82 N 40 7580.92 3208.83 7496.92 2443.24 N 2099.97 E 3221.69 N 40 7666.'75' 3259,97 ..... 7582~'75 ...... 2481',97"-N ..... 2133'~64'-'E-"3273~01 ...... N-"40 7753.02 3310.36 7669.02 2520.13 N 2166.81E 3323.57 N 40 7840.05 3359.39 7756.05 2557.58 N 2]98.79 E '3372.81 N 40 40 E 41 E 41 E 41 E 41 E 0.75 0.72 0.75 C OMF'I..IT A T :[ ON PAGE 13, WELL NO: 20 GMS , JOB N(]~ AO282G0285 TIME [_mATE,' · IDHOE-:BAY- NORTH ,SLOPE, AI.ASKA 0? .. TRUE [SUREI:;-DRI'FT .... DRTFT ....... C, OI. JRSE'VERTICAI::'"'"VERTIeAI2 ........ ,St. JBSEA' ..... R E C T A N iS LI [. A R C,, 'l.:--O""L. ..... U' R'E :F'TH ANGLE DIRECT.TON LENGTH DEPTH SECTION TVD NO. 4 DOGLEG~ C 0 0 R D I N A T E S DISTANCE DIRECTION SEVERIT' 'EET D M D M FEET FEET FEET FiEEI' FEET FEET D M '000. 27 30 N 4] 0 E 100. 7928.14 `3406,52 7844.]4 2593.57 N 2229.5~5 E 3420.14 N 40 41 E '100. 25 45 N 42 0 E 100. 8017,53 3451.20 79~5,5S 2627.]~ N 2259.22 E S464·95 N 40 42 E ~200'~ .......... 24 ...... 0-N'"'44 ......... O"E ................. 100~ 8] 08~ 25 ...... ,'3493 ~2.1 ........ 8024',"25 ....... 2657'~ 89-N ......... 2287"~"9:1 ...... E .......... 5506'T98 ....... N-40 4,'3 E 8116.04- 2685.94 N 2,3]=~,,96 E ,3546.54 N 40 46 E 8208.68 27.11.63 N 234S.50 E S583.98 N 40 50 E o~ 45 N 46 0 E 100. 8200.04 ,35,32,88 ~400. 21 ,30 N 48 0 E 100. 8292.68 3570,53 ~500. 21 ,30 N~,~0 0 E' 100. 8,385.72 ~607,12 >600. ~1 ,30 N ~') ,. ~,~ 0 E 100. 8478.76 ~643.62 >700w ........ 21 ..... 30"N'52 .... O'E 100, 8571,80 3680,06 >800. 21 45 N 54 0 E 100· 8664.76 3716·62 ~900. 21 15 N 54 0 E 100. 8757'.81 ,3752.89 8301.72 2735.67 N 2371.]6 E `3620.26 N 40 55 E 8394.76 2758.7`3 N 2399.64 E 3656.`35 N 41 I E 8487',80 2781'~30'-N ........... 2428~'52'-E ..... 3692'T33 ....... N 4] 8 E 8580.76 2803·47 N 2457.95 E `3728.41 N 4] 15 E 8'67`3.8.1. 2825.02 N 2487.60 E ,3764.16 N 41 22 E OG/iOOF' 1~,57 1.81 · 1,94 1·48 0.73 0.73 0, I' O. 50 1·46 0.25 0.00 0·68 · 5 . . ~ . 2846. 8 N 25.15 71 E >000. 20 15 N 51 0 E 100 88~] S2 3788 08 8767.32 5 . )100. 20 0 N ~,1 0 E 100. 8945 2] `3822'i`34 ~'8861";2i,?: ~868.~4 N ,~,~4~..45 E )200"; ..... 20 ......... O"N' 51' 0 E 100'. 9039.]8 .. 3856.40 : 89~,.,.18 )~00, 20 0 N 49 0 E' 100. 913`3.]5 3890.51 '9049.15 29]1.74/;N 25957~2~ E ~. ,, . . ~ . E FOLLOWIN8"STATZONS ARE FROJECTEZ .... FOR: ~NTE .... ,,:! i f '/I ((')/,'! S798.92 N 41 28 E ~8S2.86 N 4] SS E 386~'i'"60 ..... N 41 38 E ~900.44 N 41 43 E ~62 MD -"-PBTD ...... )362. 20 0 N 49 0 E ~126 MD - Th 62. 9191.41 S911.68 9107·41 2925.66 N 2611.2`3 E ~921.48 N 41 45 E .... ~':' 55 )426",' .......... 20 ........ O-'N 49-' O"E .............. 64. 9,:.,.,1. ...... 39`3,3~,54 9167.55''2940.02-'N ....... 2627';"75-'E .....,"t:943-~19 ........ N"4:I 47 E 0·00. ) 0,00 ..... FINAL'-CLOSURE-"--DIRECTTON; DISTANCE; .... N-4J DEGS 47' MINS 24"-SECS E .......................................................................... S94~.]9 FEET ARCO ALASKA, INC.. DS ..... 1'3'~ ..... WEL:L--NO',' ...... 20 ....... GMS. , JOB ...... NO,' ........ AO,~.8,~ F'RUDHOE BAY, NORTH SI. OF'E, AI~ASKA GMS, 0-]0300 HD, SLIRVEYOR; A HICKHAN, DATE RUN.* 19-F'EB-82 -'"CAMERA--'NO"~* '1"106 90'-"DEG~ ...... A/U""NO.' :1'1'] 0 GYRO NOI 624 FORESIGHT: .N4~W . " 13, WELL NO; 20 GMS ,JOB NO:. AO282G. 0285~ . TIME "' DATE. ...... MARKER- ' TRLIE SUBSEA .................. COD~ ................................. MEASLIR.ED VERTICAl,'-HD'TVD'"VERTICAI.-'R-'E~' C"-7 .... A'-N G 'U-'Li'~'A'-'R ................... C-~"O--S-LI R'E VER,TICAi, ..... NAME ........ ))EF'TH DEPTH DIFF DEPTH C 0 0 R D I N A T E S D~STANCE DIRECTION THICKNESS FEET FEET 'FEET" FEET FEET FEET D H ~F' OF SAE~LEROCHIT ~45,00 87~,8~ 11.45,J 87J.5,8~ 28~4,72 N ~.,00,,.,~ E ~77~, 80 N 41~",.~ E' zW CONTACT 10262,00 ~0~7,44 1J64,& ~01~,44 2~0~,7~ N 2585,27 E ~887,58 N 41 41 E ~TD .................................................. 1'0362;'00 919J.':~"41' 1'1'70 ~ 6 9J. 07'~"4 ~. ,.~-,.., ~'~,'6'-'N-"26'J'l'"~'23' -'E ............... 3921-';'48 ..... N-41-"45 E ........... ) ]0426.00 ~251.55 1174.4 ~167.55 ,.c~940.02 N 2627.75 E ~4~.J~ N 41 47 E '-:---~ .......... : ................ '-~: · , :'--: ,- ..... ~ -t~'~:~:''- c~''::-~- ',' '': ' "' "' ' .'t · t ~O0t ' ' ' ,--"-:-::.zu~_::_x.:s~:_.DS_,t~,_:_._.NEL~I:---NO,.,--20:--;GM5~-., ........ ~-~--::--:~-*--- :---, ..... ,-:-, : .... :---:'--,, :5CRLE I. 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'" ' ' : ::::::::::::::::::::: :::::::::::::~ :::::'.;:~;:.-.,::1 ::::::::-.--':'--:'_-;-J:'..::_:.i_:i!~.-:~ ~-_~.-.?..~-... ~"! ~.._~.--.=::~ ::"':: ~: ::::: r:.:;::,::::~,'%.-/~:':~:~::'%':':::~':'-::::z': F:~::: ::': .:: ::-.-r::_-~ ::::--'?._~., .-.* ..... ~~'~---~-:r: :..,.:: ~-.- ..... :m--,'_-_-: .-:z-'.-z~.: .~-,::-;:4--::,-':] ::: ::;:'-~:.i-:t-- ~'- _--: :?. ::-:: ::::::::'.t:z:: :::: :t ::p:~::: ,.. :X- ;[- ~ .':.~? ..-~.. ~z~:'"""'"'-" ' '----: ::::~::~:--: .: ::: .~': 1' ' Si '.2'..':'.',S' - - . . . ... _ ..:.. . .. . - -;. -::.: -7:_-".£:': .... :-.~:., :..,!?.'~i ..; _ ...... j .... :.. . .._ . _ · . A PETROLANE COMPANY REPORT of SUB-SURFACE DIREC TiONA L SURVEY ARCO ALASKA, INC. COMPANY DS 13, Well Number: 20 ' JOB NUMBER A0182D0220 WELL NAME Prudhoe Bay~ North Slope, Aiaska LOCATION TYPE OF SURVEY Directional Single Shot DATE 03-Feb-S2 SURVEY BY D Prescott OFFICE Alaska Eastm. an Whtpstock A PETROLANE COMP~,'~" P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349.4617 February 5, 1982 ARCO ALASKA, INC. P.O. Box 360 'Anchorage, Alaska 99510 Well Number: 13-20 Location: Prudhoe Bay, North Slope, Alaska Type of Survey: Directional Single Shot Date: 03-Feb-82 Method of Computation: Radius of Curvature Surveyor: D Prescott Job Number: A0182D0200 Attn: Bob Hines Dear Mr. Hines, I am enclosing the original and one copy of the Directional Single Shot Survey run on the above mentioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Di~3~~echniCal Services Coordinator · Tj/] cc: file enclosure Directional Drillers/Sub-SUdace Surveyors/Instrument & Tool Rentals/Sales/Worldwide : : : ARCO ALASKA, INC, DS 1J, WELL NO,~ 20 DSS ..... F'RODHDE"'BA'Y"~--"NORTH'"'SLOPE, ALASKA DSS, 0-10376 MD, DRILLER~ D PRESCOTT ROWAN' 26 .... I)ECLINATION~ 30 1/2 BEG. EAST .... JO.B-_N 0.,*_A01.82 I:tO 220 VERTICAL SECTION CAL. CULATED.:~,:'~":~IN PLANE OF ~OE'O.~AL ~ ~ ~' ~:;'.:'~:~:;~:~F~ A F>E'T'~OLANE CO~,4F~V,zy RECORD OF SURVEY R~AI]'IFU S--O F'CL1RV'~TU RE-' ME T FrO D ARCO "AIZ'A SKA, ..... I NC ', ..................................................................... "' ' 'C-OR]s'[J'T-A-T'i ON PAGE NO. DS 15, WELL NO: 20 DSS' JOB NO** A018250220 TIME DATE FRU[HOE BAY, NORTH SLOF'E, AL. ASEA 1~;28;~'14, 05-FEB 8~. ' · TRUE - ~dI!._'ASURED DRIFT DRIFT COURSE VERTICAL VERTICAL SUBSEA R F C T A N G U L A R C L 0 S U R E OOGLI 'DEF'TH ANGL'E DIRECTION'-LENGTH ....... DEPTH ........... SECTION ......... : 'TV1'i ............ 'C--O'-'-'O'-'~f~'"]'.F-~'--~ ..... A'-:I'-'E-"S' '[£i'STAN~.:'E' DI~i!-EiC;]~]~}i~-EO'Ei~!] D M ' D Pi FEET FEET FEET IrE:ET FEET F:EET D i'i DE;/IOi ~5500 I 0 S ~ _ ~ 0 E 2550. 2549.87 -7.51 2465.87 2706, 7 0 N 5 0 E 156. 2705.42 -0.68 2621,42 2800'~ ..... 9 15'N'27 50'"E ............. 94, ........ 2798';-~'7 ................ ~O'TS'l---271'4T~7 289©~, 1]. 45 N 58 0 E 92, 2888.92~°7,11 2804,92 03-00- ................. 20,16 S 9,40 E 22.24 S 25 0 E 0,0. 18,76 S 17,50 E 25,52 S 42 41 E ~' 5,0'. "',~ 0-9--S .... 2-1'TOO-E ........ 2'1--,' 8'6 ...... S-'75-'4'9--E----4-~: 7.99 N 30.05 E 31.10 N 75 7 E 3,4 FEET · i.ii~ g 015";' ......... 1'5 ..... 1'5 ""i~ --S 9'"- ,~'O--E .............. 1' 2'Z] ......... S 008";' :'-~ .................. .:;,~--.z ~ ....... .-~ o 243' 51 .............. '50-T'58 N ......... -48-TO-2--E .............. 5'6",-'8 ~. ...... N'-57-TFI--E- ....... 3108, 17 45 N :39 0 E 95. 3097,67 81.85 S0].3.67 50.88 N 64.78 E 82.S1 N 51 52 E 2.6 '.:'.':.,~'~-~,,_..... 19 15 N S8 0 E 124, :3"'15,26.. :1.90,87... :3181,96,.. 81,62 N 89,"""'z.~ E ]. 9o~.. _. , 98. . N a7, ._,~S E 1,2 ........................ ' ..... '~ .................. 1., .~. 4'1'- N ............... 11 ~FFS 4"% 1 o.~ · o ~'-1 4... ~. 4 E .:. ~: :'"~ :3:355~"-":"02._ 0 N :39 SO [:' 1°'.-4..,-. .......... :3:3:30"~"S-~' ....... 16:3'~-86 ..... ..$2'4~.:,6 i-~"'- .............. "-' c.'~- ......... .~ ....... ~ .............. ",--.",-' ~'i~' 5479. ~4 45 N 38 :30 E 3444,17~..~..:1-..~1.. ~860.17 1~3,64 N 14~0:30 E 21'2 84 N 48 48 E 2°2 '8604'; .......... 27 SO N S8 ......... O-'E 1 5727 31 0 N 38 30 E 10 366~,69 ¢~;6,~.:84.¢; 3.~79+69 ,~;~, ,_44,0~¢~N /~18.,58 E :30-¢ 69 N 41 .,1 E 8 3911, 35 15 N 38 30 E 6~ ~'"~8~1'~i-'-8:} ......."4~,~3'. ¢G-7~?~81; .... ''S~'-.~':~t9 ~ ...... =-M0,41 b 7.88 N--:t'0-"57-E ............ 2-75' 4~69, ~7 SO N ~8 0 E ~ 695,60 41'~','-55'~C)/.~,5'S"~'~'-4:9'~'"N 448.57 E 699 S1 N ~9' 54 E O,~ ..,.c, 4-;5-10, ~.8 I008,;3~ 4.~.- & 0-.D 781 ,...6 N ....... 6'4'6'T78'"E ..... 1'-C, 1'4';'2'4 .... N-._'39--'ST'"E ........O-F4 ........ 4897; 55-' 45 '-N 'z~O ..... O-'E .......~o'R ........... '~ ................ ~. ............ :'o ;--~,', ............... o .... 5386. 37, 0 N 41 30 E 489. 5004.00 1297,22 4920.00 1000.95 N 836,08 E 1:304,2:0 N 39 52 E 5984, 38. 15 N 43 SO E 598, 5477,62 1661,66 5395,6.°,_ 1270,09 N 1082,70 E 1668,94 N 40 27 E O,'~... 6482-; ...... 39 ........ O'-N--4-4'-S'O-'-E .... 4'9-8-';--5'b~6-77ES- I'97'2-;~ 7 578'2T6'8---i-4'gS'TTO--N----I-29'8-7-&-4--E~'£V79T-ZO .... N-4-1- O--E------C;T'2 24 E 6835, 39 15 N 45 30 E 353, 6140,5'~ °195 08 6056 '"o "' ~ .,.-. 1651,~0 N 1456,14 E °.01 55 N 41 ..' _, ..... 74607 .... 58'15-N .... ~ ................ o~ ...... ~'-,- ~ ..... o ........... ~ .............. 4~ 0 E ~.~, ~/,9~ ~86,~6 6~43,94 I926~I ..... N ....... I7S3-¥97-E----2592~'00- N'-~l-59"E ........ 0'7': 8278, 33 45 N 44 0 E 818. 7289,55 3066,81 7205,55 2269,45 N 2070.88 E 3072.28 N 42 23 E 0,5 ~o , 24 . ~ ~ . 42 ~' 8816, :30 50 N 45 50 E 558, 7745.11 58~.68 7661 11 76,08 N 2268 68 E ~5~8 26 N ¥0 E 0,6 ....... 98'110~ .... 22-45-N-50 ..... O-E .... 495] ...... 8187]-29----5574T20---8105¥29~-2627Y88-N ...... 2480Z05-E ..... S579'72~ .... N-42--4'6-E ....... 13-~ 9785 MB- CASING DEF'TH 9785, oo 0 N 50 30 E 474. 8 o¢ - 6~u.60 3754,09 8541.60 ~74~ o6 N 2568.78 E ~758 °1 N 43 7 E 0,1 '--1-057~F;----20 ..... O-"-N 51- 3'0-' E ...... 5913- ......9177 ~"31---3965';--00 ....... 9095'; 5'1- ..... 2876-;-5-4'-'N ..... 2788-;-37-E---._'59-~871-0 .... N'-45'-'32-E ......... 0-73 ,. ......... F I NAE'- CL'OSURE a---D I RECT I-ON',' N-'~;'3-DEGS""S2-"M I NS-'I 7-SECS-'E l';l, .,gT¢;f.~FI.F; ~ ."49/,8 .. 1. O F'FF"i' DRIFT CHART'S RE[..ATED DATA ~ILE ' :)S 13, WELL. NO** 20 DSS. ' JOB NO** AO182D0220 PRUDHOE BAY, NORTH SLOPE, ALASEA _ . !;URVEY FILE NUMBER 255 BOTTOM HOLE ASSEMBLY VAEUES-USED-'-'FOR'"'DEFTH-ARE'-HD ............................ DEF'TFI 2464;00 3961,00 8358,00 8884,00 9865,00 E S C R IF'TI ON PACKED HOLE: ASsEmBLY SLIGHT BUILD ASSEMBLY DRILLING DAYS VALUES USED FOR DEF'TH ARE OAY fiEF'TH 0o00 ..................... 2500,00 2500,00 2500'700 6 ~&04oO0 7 5386,00 .......... 8 ............ 68~5;00 ........ 9 7460,00 10 8816,00 ............ ~1 ................... 9~11"~00 ............................. WEIGHT IS GIVEN PER 1000 F'OUNI~S VALUES USED FOR DEPTH ARE HD \ f_IEF'TFI [,JE I GHT 2464,00 8358,00 8884,00 .... 9865~00-- 60,00 65,00 70,00 70o00 50,00 .............................................................................................. ~.~ALUES °464~ · O0 70, O0 ~" ?~:'~;~'"'~.-.,., ~""'."' ";'" ': :':: :~" 8358,00 &40,O0 8884,00 ~ZO,O0 9865 · O0 90 -'.J_l .... :..!; a~C'o' hLns, n,:--.-tNC; :--I .... ~ ....... -;i ':' ............... H0R IEONTRErPRO'J~'CTT6I' -1~-- X'-t~:)$u.~-'.:;NEL L'NNo:i ;20 :~$S :."~.: ;:';'t: L':: ' I ~'~': ~; '=RUD.~IO[!.-:BRY-,.-NORTIt-,,LOPE,-RL.RoKR '__LL_J ' :~ ~%.'.t.~ ..... ,_~**-J---: .... ':,-..+ .- ,...'~.:'-7;-t ' ....... ' .... 1: .' '':::,::.: ......... t ::.:: .- -:--:- t jI' , ' / '-%' '-Ft i J__ , , ~ ...L..i-;- ~..4----~ ; ....................... ...... ......... , . . 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' : ' , 'i ,,:~'~_..~_~__L,~.. i._L+ri....t.+. _'~_. ;.I~.~ l,,t" i ~ i l'i i. ~t ~-~--~l~,l! ' ' ~ --b-b' ~ ~ ..... ~ '+-~-1-.~ ...... ' ..~.-!., ..... ~ ~'"~I'-'~ ..... ~'~r'? ..... ~"'r-t--, i ~ i '-~ .... , ...... ~ ......~?-'r-T~,. ..... ~ I I''-T'x'~--1 "' ~ ~ ' '. , i ;, ; , , i , . , *, ......... -+ - ,i-- t,.~ ......... ? .... t ............. ---4-: ; i - ' '. ~ i t : , i t ~ i : i ~ ----i--4-~----;-i--!..-;--~4-~-s-. · ; , ~ . - .... L' · ~-.;-.-~ ~ - ~ ~" ! ~ ~ " '-' ~~-~- : ~ H-' -:-'~''' ..... .,-~.-~ ..... H-~-.~-'.--,-+-: .--'~ ...... ~.-; ;-,'i-+.'--'--d'.'":- -i-~ ~ ........ -~-.'.-,--i-'.*-.l--.' ....... ++.~"-t-.'-; ......... r-~-'-'r [: . -:'~-. ? ~---4...=. '.---;-=~! ~',i! '.ili ,,, ---~, .... ",~ ..' :--~ ' " ~ ~-i~'-: ~ ~---~ .... ~.-+ i--~,-~- ~-~-T --~---;'-i-~ ,..i -~--, =--* *,,- ";.:Z~'": ........... ~ .--14--- _~:.._,___ ~. ~, ' !~ _... ~t ,,._ ._~. ._i_'.._l._L..* i-~--.' ..... '-- 4.4,--L-;-- i .. ..... . ...... ·..,. ....... :.~.;..;. i-T'N I Ti L;F;_L.',.,i..:;.. .... ...~_,. ' . .- ~ . . . _ .. - , *-; . - , i ...... '. ~; ...... ' ............ - ....... - ...... -. , ...... ' ...... ' .. ' -.. RU[ Y','½NOP, Tli J i LOCATED IN THE APPENDIX Gl WFL [21 IPR LOG Gl CALIPER SURVEY [21 VOLAN ffi CURVE DATA Gl STRATIGRAPHIC HIGH RESOLUTION DIPMETER Gl OTHER: Suggested 'form to be insertcd in each "Active" well folder to check for timely compliance with our regulations. .... Operator,' Wel 1 N~une and Numbe~' Reports and Materials to be received by: Date Required Date Received Remarks Completion Report Yes · We!l-' History' ' Yes .~,,,:~ _Samples ~us, ~m ,-, . . ..... ~ _ p~ ~~ - , ...... .. , .......... ., &~ ~'~' ,, "-7 .... ~/~ ............... Dire~ional Su~ey Drill St~ Test Repros ~W W/c_,, ~ . ~/~~ Pr~u~ion T~t Re~rts ..... ..... , , , F " March 17, i982 Reference: ARCO DIRECTIONAL SURVEY DATA DoS.11-7 - 2/16/82 Single-Shot Job No. AO182D0244 .... D,S~13'20 2/19/82 Gyroscopic Multi Job No. AO282G0285 ~~ease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal # 37 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON February 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- State Reports Dear Sir' Enclosed please find Well Completion Reports for the following drill sites' 11-6, 12-4A, 13-19, 14-9A, 14-26, 15-15, lA-12, lA-13, and B-11GI. Also included are Monthly Reports for January on drill sites' ::-i3zg0,~13-23, 14-30, ]_5-1, and lA-14. Since re ly, P. A. VanDusen District Drilling Engineer Enclosures PAV/GLA' sms AIqCO Alask,1. hr'*c, is a $iJr',s~:li .tV o! A;I;,nlicJu'ich!;ehclL:of'r'~pai'ly ~: STATE OF ALASKA ~ ALASKA (:/"~ AND GAS CONSERVATION CC/-'"~,4 ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 8 2 - 9 3. Address 8. APl Number Post Office Box #360, Anchorage, Alaska 99510 50- 029-20705 4. Location of Well at surface 2639' FNL, 131 FEL, Sec. 14, T10N, R14F., UM 5. Elevation in feet (indicate KB, DF, etc.) 84' RKB 6. Lease Designation and Serial No. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 15-20 11. Field and Pool Prudhoe Bay Field Pru~hoe Oil Pool For the Month of January ,19~2 i~12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1730 1/21/82. Ran & cmtd 13-3/8" casing w/shoe @ 2501'. Drld 122" hole to 9398' as of 1/31/82 See Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 20" 94# H-40 conductor to 110'. Cmtd w/250 sx P.F. II cmt. 13-3/8" 72# L-80 casing to 2501'. Cmtd w/2400 sx Fondu and 400 sx Permafrost cmt. See Drilling History t4. Coring resume and brief description '15. Logs run and depth where run None To Date. ~11 6. DST data, perforati'ng data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate DS 13-20 Drilling History NU 20" Diverter. Spudded well @ 1730 hrs, 1/21/82. Drld 17~" hole to 2501'. Ran 59 jts 13-3/8" 72#/ft L-80 casing w/shoe @ 2501'. Cmtd 13-3/8" csg w/2400 sx Fondu & 400 sx Permafrost cement. ND 20" Diverter. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EM~ - ok. Drld 122" hole to 9398' as of 1/31/82 RECEIVED FEB A ]9 Oi~ & G~s Oons. C;ommi$~sion February 18, 1982 Reference: ARCO DIRECTIONAL SURVEYS D.S.15-14 D. S. li3=20'~ D.S. 14-30 D.S.15-1 12/25/81 Multi-Shot Job No. A1281GO175 2/3/82 SingIe-Shot Jon No. A0182D0220 2/5/82 Single-Shot Job No. A0182D0215 1/22/82 to 2/7/82 Single-Shot Job No. 0282-007 Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal /t 970 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON February 12, 1982 Reference: ARCO MAGNETIC TAPES & LISTINGS D.S.14-26 ;.D.S.13-205 D.S. 14-30 1/11/82 Tape #62531 1/29/82 Tape #62540 2/3/82 Tape #62543 2/5/82 Tape #62551 e sign and return the attached copy as receipt of data. Mary 'F. Kellis North Engineering Transmittal #959 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF CHEVRON , ~,./ ALASKA OiL A~D GAS CONSERVATION COMMISSION Chat Chatterto4 ~ Chairman T~RU: Lonnie C. Smi Commi ssioner Ben LeNorma n Petroleum Inspector January 28, 1982. Witness BOPE Tests on ARCO's DS 13-20, Sec. 14, T10N, R14E, UM ?.r.. udhoe _.. Bay. Unit 'Saturday, January 23- I departed my home at 7:15 a.m. for a 7:45 ~m," ShowUP a~d"' 8'~5 a.m. departure via Alaska Airlines flight 455 for Deadhorse arriving at I0~25 a.m. Weather.' -12"F, light snow, 1 ight wind. Sunday, January 24 - Tests began on ARCO's DS 13-20 at 8:00 a.m. ~h~-~re c~p'Ie{~ at 1:15 p.m. BOPE inspection report is attached. Monday, January 25 - BOPE tests on ARCO's DS 15-1 were completed, ~he"'S;abje¢%'~f a ~eparate report. ..... ~g~nTUesday"at 'iJanuary01~'5 p'm~26 ~ .BOPE .tests on Conoco's Milne Point B-2 Wednesday, January 27 - . · . and were completed at 1:00 a.m., %~he~ s~bjeCt' of'" a se~rate re,rt. I departed Deadhorse via Alaska Airlines flight %66 at 11:10 a.m. arri~ving in. Anchorage at 12:50 p.m. and at my home at 1:20 p.m. In summary, I witnessed successful BOPE tests on ARCO's DS 13-20. .~"~TATE OF ALASK: ALASKA OIL ,~ JAS CONSERVATI¢?'~ CCMMISSION B.O.P.E. Inspection Report Operator. /~ ~ Representative.~_~/~4' ~_t'~_~,,'J'd. ~-'-"~ ~ ~ ~tion: Sec /~ T/~~~bI'~ /~~asing Set 0 2~~ ft. ~illinq ~n~a~or ~~~ Rig ~Repre~ntative ~l, ~1~ ~~~/q~=~ Location, C~neral_ _~ ~ Well Sign ~Q~_ Ceneral Housekeepi. ng c9/~._. Reserve pit ~ ~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves-- H.C.R. Valve Kil 1 T,i ne Valves ... Check Valve Test 'Pressure ACCU~IUIATOR SYSTEM Full Charge Pressure ~~ psig Pressure After Closure /~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: N2 _~_.~-~,. ,~a~,. ~~. ,/~ psig Controls: ~ster Remote ~9/~_B_l.~_n_d_.s ._s3f_ i. t ch cover~.~ min ~ sec. min ~ sec. Test Results: Failures ~ Repair or Replacement of failed equipment to be made within , days and Inspector/Ccmmission office notified. Adjustable Chokes. i Hydrauically operated choke Test Time~f'_~__hrs Distribution orig. - AO&GSC . CC - C~e rator CC - Supervisor Inspect°r ~J Kelly and Floor Safety Valves · Upper Kelly. Test Pressure Lo~er Kelly Test Pres sure_ Ball Type _~.~ Test Pressure Ins ide BOP. C~ ~--- Test Pres sure Choke Manifold Test Pressure Va w- ..... No. flanges__ 4Z~) January 13, 1982 Mr. Charles B. Ross Senior Drilling l~ngineer ARCO Alaska, Inc. P. O, Box 360 Anchorage, Alaska 99510 Re: Prudhoe Bay Unit DS 13-20 AR(X) Alaska, Inc. Permit 1~o. $2-9 Sur. Lea.: 2659~FlqL, 131~FEL, Sec 14, T10N, R14B, Bottomhole Loc.: 4?5'FSL, tlg0'FI~L, Sec 12, T10N, R14E, Dear i~..Ross Bnelosed is the approved application for permit to drill the above referenced wel 1. Well samples and a mud log are not required. A continuous directional survey is ~e-quired as per 20' AAC 25,050(b)(§). If available, a tape' containing the digitized log information shall be submitted on all logs for copying except experimental logs. velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadx, omous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordtnatorts office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Charles Il. Ross Prudhoe Bay Unit DS 15-~-0 -2- January 13, 1982 .o~notng operations you' may be ~ontacted by a representative of the Department of Environmental Conservation. To aid us in sehedulin~ field work, we would appre0iate your notifying this office within 48 hours after the well is spudded, We would also like to be notified so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casin~ shoe is dr t I I ed, In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present o Very truly yours, ! Harry W. Kugler Commt ss lo.net o f BY ORDE. R OF THE COMMISSION Alaska Oil & Gas Conservation Co~z~ission Eno I o sure cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/anti. ARCO Alaska, Inc. ~'~ Post Office B~.._ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 8, 1982 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- DS 13-20 Permit to Drill Dear Sir- Enclosed please find our application for Permit to Drill DS 13-20 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore, a proximity plat showing the subject wellbore's position to the nearest well drilled, and a sketch and description of the BOP equipment and testing procedure, including anticipated pressures. As we anticipate spudding this well on or around January 24, 1982, Your prompt review of this application would be greatly appreciated. Very truly yours, C. E. Ross Sr. Dril 1 lng Engineer CER:JBK-ltc Enclosures Gas Cons. Commissio~ Anch0ragQ ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA "~, ALASKA ..iL AND GAS CONSERVATION C(~,VIMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] I b. Type of well EXPLORATORY [] DEVELOPMENT OIL;~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO A1 aska, !nc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 2639'FNL, 131'FEL, Sec. 14, T1ON, R14E, UN At top of proposed producing interval REC~J VED 200'FSL, 2490'FEL, Sec. 12, T10N, R14E, UM At total depth JA ?j ] ] ]L~:;;;z 475'FSL, 2190'FEL, Sec. 12, T10N, R14E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designatj~ ~Ii~ ~S CONS, 84' KB ADL 28311 Anchorage 12, Bond information (see 20 AAC 25.025) lvp~ Statewide Sur~tv,nd/or,,mb~rFed Ins Co. ~8080-26-27 9. Unit or lease name Prudhoe Bay Unit 10. Well number DS 13-20 11. Field and pool Prudhoe Bay Fi eld .. Prudhoe 0il Pool Amount $500,000 13. Distance and direction from nearest town 1½ miles NW of Deadho~es 16. Proposed depth (MD & TVD) 10,848'MD 9429'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2600 feet. 21 14. Distance to nearest property or lease line South Line ADL 28311-200 feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 37 o I (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 15. Distance to nearest drilling or completed well TD-1117' to 6-10 feet 18. Approximate spud date 1/24/82 ~/-Jr2 .. psig@ .... Surface 4599 ..ps~g@.9_429_ft. TD (TVD) SIZE Hole I Casing Weight 30 120 94# 17½ 13-3/8 72# 12k I 9-5/8 47# 85 9-5/87 47# 29# 22. Describe proposed program: CASING AND LINER Grade Coupling Length H-40 PEB I R-3 L-80 BUTT R-3 1 L';80 ~ BUTT R-3 S00-95 BUTT R-3 L-80 BUTT R-3 SE~ lING DEPTH MD TOP TVD 0 0 0 0 0 0 9640 8457 MD BOTTOM TVD llO' ~ 110' 2500' II ' 2500 9938' 18696' I 10,848J 9429 QUANTITY OF CEMENT (include stage data) 250sx PF II to surf. 'l 2300sx Fondu + 400 PF 500sx "G" - 1st stage' 300sx PF "C" 2nd stagb 750sx Class "G" cmt, ! ARCO Alaska, Inc. proposes to directionally drill this well to 10,848'MD (9429'TVD) to pro duce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 ps RSRRA BOP stack will be installed and tested to 5000 psi. The BOP equipment will be press ure tested each week thereafter. A string of 4½" 12.6# L-80 tubing, packer & necessary provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all'uncemented annuli' within the permafrost interval. The packer will be set above the Sadlerochit. The downhole safety, valve will be tested and installed upon conclusion of jo NOTE: Permafrost base at DS 13 is 1850'TVD. *Bottom hole pressure based on virgin reservoir pressure. Surface pressure calculated wit unexpanded gas bubble at surface including temperature effects. 23. , hereby certify that th~Ting~ue and correct to the best of my knowledge SIGNED ~/~,~~ J TITLESr, Drilling Engineer The space below for Commission use Samples required []YES ~qO Permit number Mud log required [-]YES Approval date 01/13/82 CONDITIONS OF APPROVAL I D irectional Survey required [ APl number [~YES r-]NO 50- SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY Form 10~,01 I~ ~ 7.1 -~ ,COMM I SS I ON ER DATE by order of the Commission January 13, 1982 Submit in triplicate ..... i -" :soo i: :-:;-::-'u "i .... ~-""~oo' 'I .... ~ ..... ~ :: ~ ~: :'-:-: ~ · t' ~- -'~ ...... .............. ~"', .......~. ..... , ...... I-:--:::-':'~' . ~' "'::"':':"-'": "~- i "~' ' I ",'~- I ", "_ ..... 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'. .... : ~ "~ ..... ~. . ~ , · ~ ~-. - · -~+~-.~ ~ ....... ,--~---~ .... ~ ........ ~ .... ~--~ ..... ~-~-? ......... ~.-~-~ ...... - ....... ~--~--, ...... t ~--~--.,~.-~ ~ ~- ~ ~ ~ ~ ~ · :--~-~ -~~.~~ ..... ~. ~ , t-~.-~ ~ .-~-w~--~--~-.~-~ .... -~--~-~ --.~-?~--~-~-~t--~ ---~"r~ .... :'k~-~-~-~-~--t- ~---F~'~S- ~ f. . w ' .--~..~-.~-.~ .... ~-F-~-(~-~--~ ........ ; ~ '~ -~-+j ........ +d~ .... ~-~-+---~-- ~--?~ ..... =-~--P~-~~ -~-~--~+---' ......... f-~~--~ .... SURFACE HOLE D IVERTER SYSTEM SCHEMATIC ARCO ALASKA INC'. //.~ IO" HYD. OPR. BALL VALVE WE,L,L BORE (SEE DETAIL) ./'/~/'"'"~, I0' HYD. OPR. BALL VALVE /' ,/'/" I ALL 90° TURNS ARE "TEE" ~ ICUSHION ~LL ) BORE I ! I RESERVE PIT AREA FLOWL INE DR ILL ING R I SER 20" 2000 PSI VVP ANNULAR PREVENTOR I0" HYDRAULIC OPERATED BALL ~--~~10" D IVERTER LINE ING SPOOL 20" CONDUCTOR PIPE "DETA IL" VALVES 2026O102O3 ,.~VZ - PREVENTER 3. BLIND~RRMS . PIPE RRHS SPOOL PIPE RRHS Maximum Anticipated Bottom Hole Pressure, psi. Maximum Pressure to which BOP's could be subjected. Calculated by allowing a gas bubble at reservoir pressure to rise w/o expanding but cooling to 80~F, psi. P, ECEIVED Alaska 0il & Gas Cons. Coiumissio~ · A 13-5/8" BOP STACK DIAGRAM Accumulator Caoacit¥ Test Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. Observe time, then close all units simultan- eously and record the time and pressure re- maining after all units are closed with charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining, pressure.) 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non- freezing liquid. 2. Check that all hold down screws are fully re- tracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws in head. 3. Close annular preventer and chokes and Bypass valves on manifold. 4. In each of the following tests, first hold a .250 psi low pressure test for a minimum of 3 minutes, then test at the high pressure. 5. Increase pressure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe "rams. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 7. ClOse valves directly upstream of chokes & open chokes. Increase press, to 5000 psi & hold for at least 3 min. Bleed pressure to zero. 8. Open top'set of pipe rams then close bottom set of-pipe rams. Increase press, to 5000 psi below the bottom set of pipe rams & hold for at least 3 minutes. .9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe ramq., ll. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold & lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of De Gasser. 16. Record test information on Blowout preventer test form. Sign and send to Drilling Super. 17. Perform complete BOPE test once a week and functional operate BOPE daily. CHECK LIST FOR NEW WELL PERMITS Company ~ ~ Lease & Well No.. ~, ~, ~ ITEM APPROVE DATE (3) Admin -(9/thru 11) (4) C_ a sg ~ '//~/~ Z (12 thru 20) ' (2l thru 24) (6) Add: le me 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO ,, Is well to be located in a defined pool ............... ~ ~ Is well located proper distance from property line ......... ' Is well located proper distance from other wells ...... Is sufficient undedicated acreage available in this poo ./~f~ . Is well to be deviated and is well bore plat included ..... '~- J Is operator the only affected party .................... Can permit be approved before ten-day wait ............ ii Does operator have a bond in force .................... Is a conservation order needed ............ ............ Is administrative apprOval needed ..................... Is conductor string provided ............ , ................. Is en°ugh cement used t° circulate °n c°nduct°r and surface~iiiiii!~i~'' ~~_ Will cement tie in surface and intermediate or production s Will cement cover all known productive horizons ................. ''.~.- Will surface casing protect fresh water zones ..................... Will all casing give'adequate safety in collapse, tension and burs Is this well to be kicked off from an existing wellbore .......... Is old wellbore abandonment procedure included on 10-403 ......... Is adequate well bore separation proposed ........................ · · ·, e · e REMARKS Is a diverter system required ................... ~ Are necessary diagrams of diverter ;~ ~0~ ;qu;~ie~t a~;;g~;~ ..i~.1 ~ ' Does BOPE have sufficient pressure rating - Test to ~~ psig-1 Does the choke manifold comply w/API RP-53 (Feb.78) ................... ~,~.f~;~ Additional requirements ............................................. __ ~ Additional Remarks: Geology_: En_gin~.e__r ing: k~V~ JKT --'-'-- RAD .---. JAL ~-~ rev: 03/10/81 ..... TNZTIAf. 6~.'0. UNIT ON/0~ POOL CLASS STATUS AREA NO. SHORE .... ,,, Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX: .. No Special'effort has been made to chronologically organize this category of information. CURVE Company ARCO ALASKA, INC. Well ~ D.S. 15-20 Field PRUDHOE BAY. N. SLOPE, ALASKA Date. 2-17-82 Curve ~ame (Abbrev.) Standard Curve ~ame GR . CCL Gamma Ray Casin~ Collar Locator Long Spaced CN-Mult~spaced LSN " SSN Short Spaced " CN Compensated Nuetron 0-100, ] 00-2 O0 0-10 0-1250 0-1000 60-0 -' '" ~a$ Con. PAGE i ARCO ALASKA INC. O.S. 13'20 DEPTH LONG SPACE SHORT SPACE CO~P. GA~A CCL 9~10.0 2'70.5 232.8 ~9.62 6i.3 0.80 9~0,0 ~8~,5 ~2,1 ~,0~ 55,7 o,80 9~50.0 288.i 226.6 ~5~'i0 59.5 0.80 9~70,0 250.6 206.5 ~0,13 50.9 0,80 ~ ~: .... ~.,~1~~ ~<~?~:~:~ :' ~?::;~T~?::~:~-?-T'~-:-~:~ -~- ,,~ ~-:.` ;.~. ~:.::/~..~:~ 9490,0 262,1 257.8 ~, 17 32,0 0.77 9510.0 230,0 175,3 3~,88 56,9 0,80 9550.0 25~.6 [68.6 ~7,0[ 58.5 0.80 9550.0 2~3,0 177,1 ~1,09 ql.6 0,80 I 9570,0 2~4.4 42.92 9590,0 9 10,0 9 0,0 9! 96' 0,0 339,2 27q,9 33,19 52,5 0,80 ~..- . ~..~... ~!:i ~. ~ .~.:~-~:~ ~ .. ~ ......... ~6'9~--,-'E ....... ~51,6 285.9 ~,~8 5~.6 0,80 9710,0 30~,1 263,9 ~6,97 ~3,5 0.80 9750,0 289,6 2~9.9 ~7,60 51,3 0,80 9770.0 310,2 269.~ ~4,11 49.0 0.66 9790,0 298,0 2~9.9 ~5,~7 ~8,2 0,80 9810,0 289,6 2~9.3 ~7.16 52,~ 0,80 ~8~0,0 ~01.8 257.8 ~5,25' 5~! 0,79 : ~sso.o ~o8.,~ ~ ~A~ ~.~ i.1 0.80 ............... -~'-~'?"~'.'0 ~ 837,~ 556.[ !,,~. ~636.5 0.80 ......... ~9o. ~.,~~o.~ ~7.~ ~.8~ 2~9.9 0.80 PAGE 2 ARCO ALASKA iNC. D.S, 13-20 DEPTH LONG SPACE SHORT SPACE* COHP, GANNA CCL ]~:~:ii~ .?i!::~i!:~-~_R.]A~:_!L_.~:_L_. .................................... L_~ ~ ~_,: '.":.'~, ~::¥: ~?. FT, ~ API 99)0,0 ~ ~q',9 586,1 13,29 .7~ · 7 0,80 ~,.~.:,...,.=~=.:~-=: ......:~~~ ~.. ,..,. :.~" 9950,0 9970.0 ~ 56S.5 6~<~ 91.~ ,~ 2[.7 0.8L 999'0.0 556.2 ~18.6 [[,~8 ..?,...~ ~ · 1 ~77. loOZO,O ..... .=...~. ~;....~. ....,<.=,.~ :.~-...-.~[.~ ... ~:.:......~r.;~3,..!~~ .... . ......... ~:.=¢~ .?=.<~.=-_. [0050,0 562,5 ~[5,5 ~,55 28,[ 0,76 10050.0 6~1.0 ~90.7 ~0.58 55.7 0.80 10090,0 5~ 10110.0 51: lol 10150,0 5.01 10170,0 519.6 ~06.3 ~5,63 27,~+ 0,80 10190,0 651,7 q. 56,5 16,7N. 25,6 0,80 ~.. ' .......... ~; .L. .......... :~:.:~ ....~. ...... ~ ?? ....~.~ ................ :~.;~-:~ ,.., ............ :. 10210.0 560.1 ~0,6 ~0,3~ 25,3 0,80 .. 10250.0 592.1 ~5~.6 ~2.25 2~,9 0,80 ~0250.0 375.2 298.2 ~7.79 26.9 0.60 [0270~0 ~ 506~ ~. ~[5~[ ~5~Z5 27.5 0.60 10290.0 50~.~ ~19.8 ~3,35 29,7 0,80 10~10,0 511.9 ~: ..~..~.~.~ .~.;~.: :: ::. : :, ~. ,;~ 10550,0 596.5 ~5.9 ~.86 90.6 0.80 [0570,0 505,8 ~06,3 ~6,[~ 55,[ 0,80 ECC NUt~tBER 1225, O0 ~co ~.~s~<~ ~.c. LEVEL SPAC[NG 0,5000 ~mmmmmmmmmmmmmmmm~m~m~ ~ .... SCH~UMBERGER----~ $m.mmmmmmmmm.mmmmm~m--~ LIS TAPE VERIFICATION LISTING LVP 009.H05 VERIFICATION LISTING PAGE ** REEL HEADER SERVICE NAME :SERVIC DATE :82/02/ ORIGIN : REEL NAME :REEL ~D CONTINUATION ~ :01 PREVIOUS REEL COMMENTS :R~EL COMMENTS ** TAPE HEADER ** SERVICE NAME :SERVIC DATE :82/02/ 6 ORIGIN :1070 TAPE NAME :62543 CONTINUATION ~ :01 PREVIOUS TAPE : COMMENTS :TAPE COMMENTS EOF ** ~'IbE HEADER FILE NAME :SERVIC.O0! SERVICE NAME VERSION ~ DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE ** INFORMATION RECORD8 ** MNEM CONTENTS CN : ATLANTIC RICHFIELD CO. WN : DS 13-20 FN : PRUDHOE BAY RANG: TOWN: 1DM SECT: 14 COON: NORTH SLOPE STAT: ALASKA CTRY: USA MNEM CONTENT8 PRES: NED~T4F ** RECQRD TYPE 047 UNIT TYPE CATE SIZE CODE 000 000 022 065 000 000 008 065 000 000 012 065 000 000 003 065 000 000 003 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 004 065 U~IT TYPE CAT£ SIZE CODE 000 000 00'7 065 ~VP 009 H05 VERI~ iCATION LISTING PAGE RECORD TYPE 047 ~ ** RECORD TYPE 047 ** ~, COrM~' . ENT8 ** ************************************************ ]OB ~ 10707.62543 20MPANY NAME JELL NAME ~IELD .~OUNTY ~ECTION [OWNSHIP = ATLANTIC RI. CMFIEbD CO, = DS 13-20 = PRUDHOE BAY =NORTH SLOPE : 10N RANGE =I4E )IL RUN #1, LOGGED 03'F£~'82 ~OTTOM LOG INTERVAL = 10422 FT. top LOG INTERVAL 2ASlNG-bOGGER ~IT SiZE fYPE HOLE FLUID DENSITY ~ISCOSlTY FLUID bOSS RM ~ SEAS. TE~P, R~F ~ SEAS. TEMP. RMC @ ~EAS. TEMP. 9841 FT, 9,625 IN, ~ 9841 FT, 8,5 IN, bIGNOSULFANATE 9.8 LB/G 37.0 $ 11 0 7,~ C3 1.950 OHMS @ 63,0 DF 1.680 OHM~ 9 63,0 DF 2,060 OM~M ~ 64,0 DF 0,692 OhM ~ 190, DF LVP 009.H05 VERIFICATION LISTING PAGE MATRIX SA.DSTONE ************************************************ ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZE REPR CODE 4 ! 66 8 4 73 9 ~ 65 0 1 66 DATOM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API AP1 API API FILE iD ORDER # LOG TYPE CLASS MOD NO. DEPT FT 0 0 0 0 0 SFLU bib~ OHMS 7 0 0 0 0 IbM OIL~ OHMS 7 0 0 0 0 ILD OIL~ OHMS 7 12 46 0 0 SP DIL~ MV 7 1 0 0 0 GR DIb~ GAPI 7 31 32 0 0 DT SHE- US/F 60 52 32 0 0 GR BHC ~' GAPI 60 31 32 0 0 ,NPHI CNb--' PO 42 68 2 0 0 GR ESL~ GAPI 42 31 32 0 0 NRAT CNb 42 42 1 0 0 NCNb CNb 42 34 92 0 0 FCNL CNb 42 34 9] 0 0 -NPHI FDC PU 45 68 2 0 0 RHOB FDC.< G/C3 45 35 1- 0 0 DRHO FDC z G/C3 45 44 0 0 0 CALI FDC/ IN 45 28 3 0 0 GR FDC~ GAPI 45 ~1 32 0 0 NRAT FDC 45 42 i 0 0 NCNb FDC 45 34 92 0 0 FCNL FDC 45 34 93 0 0 ENTRY 1 6O ,lin 0 SIZE PROCESS SAMPLE REPR LEVEL CODE 4 0 1 68 4 0 1 68 4 0 1 68 4 0 i 68 4 0 i 68 4 0 % 68 4 0 I 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 I 68 4 0 I 68 ~ 0 1 68 4 0 I 68 4 0 1 68 4 0 i 68 4 0 1 68 DEPT 10444.000 BFbO -999.250 IbM BP -999.250 GR -999.250 DT NPHI -99~ 250 GR -999.250 NRAT FCNb -99~250 NPHI 9.6t9 RHOB CALI 8.500 GR 137.500 NRAT FCNL 2190.000 DEP£ 10400.000 SFbO 3.906 IbM -999.250 -999.250 -999.250 2.406 1.201 1.957 IbP -999.250 GR -999,250 NCNb -999,250 DRHO -0'246 NCNb 2812.000 I5P 1.820 JVP 009.F{05 VERIFICATION LISTING ;P -77.563 GR iPHi -999.250 GR nCNb -999.250 NPHI---- :ALi 8,1i7 GR PCNL 1122,000 28,984 -999,250 31,445 29.391 )EP~r 10300,000 SFLU ~P ~92,625 GR ~PHi -;99.250 GR ~CNL -~99.250 NPHI ~ALi 8,242 GR ~CNL 1311.000 ~,402 20,281 -999.250 27,051 20.766 )£PT 10200.000 SFbU ~P -73.938 GR ~PHi -999 250 GR ~CNL -999~250 NPHI ~-~ ~ALI 8.445 GR FCNL 2392.000 9.922 26.359 -999.250 1~,967 2 .625 )£PT 10100.000 SP -86.~000 GR ~PHI -999.250 GR ?CNb -999,250 NPH~ CALl 8.~30 GR FCNL 1346.000 24.234 26.719 -999.250 24.951 28.000 DEPT 10000.000 SFLU $~ -80.875 NPSI -999.250 GR FCN~ -999.250 CALI 8.477 GR FCNL 1573.000 43.406 29.047 -999.250 23.145 26.766 DEPT 9900,000 $f'5~ SP -23.250 GR NPHi -999.250 G~ FCNL -999.250 NPHI CAnI 9.516 GR FCNL 1355.000 27.266 i41.875 -999.250 26.5~4 182.1~5 DEPT 9800.000 SFLU SP 110.312 GR NPHI 48.438 GR FCNL 341,000 NPHI CALl -999.250 GR FCNL -999.250 2000.000 55.094 59.875 -999.250 -999.250 DEPi 9700.000 SFDU SP -999,250 GR NPMI 43.89~ GR FCNb 33~,750 NPHi CALl -999,250 GR FCNL -999.250 -999.250 -999.250 59.281 -999.250 -999.250 DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT I5~ DT NRAT RH08 NRAT DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT 90.750 -999,250 2,363 2,805 2.090 92.750 -999,250 2,301 2,521 5.844 78,563 -999.250 2,322 I~800 18.266 92,000 -999.250 2,293 2.398 27.141 83.750 -999.250 2'301 2,281 11.922 72.188 -999.250 2.555 2.592 2000.000 56,781 4.059 -999,250 -999.250 -999.250 -999.250 3.813 -999.250 -999.250 NCNb DR~O NCNb GR NCNb NCNb NCN~ DRHO NCNb DRHO NCN~ NCNb DRHO NCNn NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb PAGE 28.984 -999'250 0 003 3358 ooo 1.962 20 281 -999:250 3440.033 4.000 5 195 26!359 -999 250 0.001 4584'000 29.469 26.719 -999.250 0.021 3520,000 52.531 29,047 -999.250 0.027 3854,000 17.875 141 875 -999:250 -0.012 3974.000 4.719 55.094 138i.000 -999.250 -999,250 -999.250 -999.250 i549.000 -999.250 -999.250 LVP 009.W05 VERIFICATION LISTfNG PAGE 5 DEPT 9600.000 SFLU $B -999.250 OR NPHI '53.271 GR FCNL 272.750 NPHI CALl -999.250 GR FCN5 -999.250 DEPT 9500.000 SFLU SP -999.250 GR NPHI '53.174 GR FCNb 270.500 NPHI CALl -999.250 GR FCNL -999.250 DEPT 9400.000 SFLU $P -999'250 GR NPHI 55.078 GR FCNb 285.500 NPMI CALf -999,250 GR FCN~ -999,250 DEP'I ~300.000 SF~U SP 999.250 GR NPHI 50.879 GR FCNb 328.250 NPHI CALl -999.250 GA FCNb -999.250 DEPT ~200.000 SFLO SP 999.250 GR NPMI "'55.762 GA FCNL 312.250 NPHI CALf -999.250 GR FCN5 -999.250 DEP~ 9100.000 SP -999,250 GR NPHI 42.188 GA FCNL 368.250 NPHi CALf -999.250 FCNb -999.250 DEPT 9000.000 $FLU SP -999.250 GR NPHI 45,068 GR FCNb 353.000 NPHI CALf -999.250 GR FCNb -999.250 DEPT 890f),000 SFLU SP -999,250 GR NPHi 40.674 GR FCNL 368.250 NPHI -999.250 -999.250 55.405 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 57 656 -999~250 -999.250 -999.250 -999,250 98.375 -999.250 -999.250 -999 250 -999 250 80 750 -999 250 -999 250 -999.250 -999,250 . 64,000 999.250 -999.250 -999.250 -999.250 68.063 -999.250 -999.250 -999.250 -999.250 59,719 -999,250 NRAT NRAT RHOB NRAT NRAT RHOB NRAT D~ NRAT RHDB NRAT D~ NRAT RHOB NRAT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT IbM DT NRAT RHOB -999.250 -999,250 4.324 -999.250 -999.250 -999.250 -999.250 4.320 -999.250 -999.250 -999.250 -999.250 4,422 -999.250 -999.250 -999.250 -999.250 4.~95 -999.250 -999.250 -999,250 -999.250 4.461 -999.250 -999.250 -999.250 -999.250 3,~17 -999. 50 -999.250 -999.250 -999.250 3.875 -999.250 -999.250 -999.250 -999.250 3.633 -999.250 GR NCNb DRHO NCNb GR NCNb DRHO NCNb ILD GR NCNb DRHO NCNb NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb NCNb DRHO ~999i250 999 250 1347000 -999.250 -999.250 -999.250 -999.250 1251.000 -999.250 -999.250 -999.250 -999.250 1394.000 -999.250 -999.250 -999.250 -999'250 1468 000 -999!250 -999 250 -999 250 -999 250 1422 000 -999 250 -999 250 -999. 250 -999. 250 1631'000 -999,250 -999,250 -999,250 -999,250 1624,000 :999,250 .999.250 -999.250 -999.250 1350.000 -999'250 ,VP 'CND IPHi ~ALI )EPT ~PHI 'CNL )EPT ;P ~PHi ;ALI ~CNL )EPT ~PHi rCNb 2ALI ~CNb ~P '~PHi FCNh 2ADI D EP'r FCNb ~ALI FCNL DEPT SP NPHI FC~ L DEPI SP 009.H05 VERIFICATION LISTING -999.250 GR -999.250 8SO0,O00 SFbU -999.250 GR 32,471 GR 49i"000 NPHI -999,250 GR -999.250 8700,000 SF~U -999,250 GR 36.572 GR 511.000 NPHI -999.250 GR -999,250 8600,000 SFLU -999.250 GR '36'914 GR 444,250 NPHI -999.250 GR -999~250 8500,000 SF~U -999,250 GR '40.283 GR 42~,750 NPHI -99~.250 GR -999,250 8~00,000 SFbU -999.250 GR 35.742 GR 483.250 NP~I -999.250 G~ -~99.250 8300.000 SFLO -999.250 GR ~42.041 GR 500.000 NPHI -999,250 GR -999.250 8200,000 SFDU -999.250 GR 43.994 G~ 355.000 N~HI -999.250 GR -999.250 8100,000 SFDU -999.250 GR -999.250 NRAT -999,250 IbM -999'250 DT 8i,188 NRAT -999 250 RHOB -999[250 NRAT -999,250 IbM -999.250 DT 67.188 NRAT -999,250 RHO~ -999,250 NRAT -999,250 IbM -999,250 DT 51.,719 NRAT -999.250 RHOB -999,250 NRAT -999.250 IbM -999,250 DT 44,688 NRAT -999,250 RHOB -999,250 NRAT -999,250 IbM -999.250 DT 51,34~ NRAT -999.250 RNOB -999,250 NRAT -999.250 IbM -999.250 DT 47.844 NRAT -999.250 RHOB -999,250 NRAT -999.250 IbM -999.250 DT 54,938 NRAT -999.250 RHOB '999.250 NRAT -999,250 IBM -999.250 DT -999,250 -999,250 -999,250 3,186 -999,250 -999,250 -999,250 -999,250 3'410 9:250 -999,250 -999,250 3,42@ -999,250 -999,250 -999.250 -999,250 3.613 -999,250 -999,250 -999,250 -999,250 3.363 -999,250 -999.250 -999,250 -999.250 3,711 -999,250 -999,250 -999.250 -999,250 3.618 -999,250 -999.250 -999,250 -999,250 NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb IbP GR NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb ILD GR PAGE -999.250 -999,250 -999,250 I~84.000 -999,250 -999,250 -999.250 -999.250 1726,000 -999,250 -999,250 -999,250 1999,250 592.000 -999,250 -999,250 -999.250 ,~999 250 g:ooo -999.250 -999,250 -999,250 -999,250 1683,000 -999,250 -999,250 -999,250 -999.250 1633.000 -999,250 -999.250 -999,250 -999,250 1556.000 -999,250 -999,250 -999,250 -999,250 LVP 009.H05 VERIFICATION 5ISTING PAGE 7 NPHI 42,969 GR FCN5 355.000 NPHI CALl -999,250 GR FCN~ -999'250 DEPT 8000.000 SFLU SP -999,250 GR NPHI 43,750 GR FCNL 315,750 NPHI CAbI -999.250 GR FCNL -999,250 DEPI 7903.000 SFbU SP -999,250 GR NPHI 50,146 GR FCN5 284,250 NPHI CALI -999,250 GR FCN& -999,250 DEPT 7800,000 SFLU SP -999,250 GR NPHi 47,070 GR FCNL ~51.500 NPHI CAhI -999,250 GR FCNL -999,250 DEPT !700,000 SFLU SP 999,250 GR NPHI 45,459 GR FCNL 355,500 NPHI CALI -999,250 GR FCNL -999.250 DEPT 7600,000 SFbU SP -999,250 GR NPHI '48'193 GR FCN5 ,285,500 NPHI CALI 999'250 GR FCNL -999,250 DEPT 7500.000 SFLU SP -999,250 DR NPHI '45.752 GR FCNL 371,500 NPHI CAbI -999,250 GR FCNb -999,250 D£PT 7400.000 SFbU SP -999,250 GR NPHf '49,121 GR FCNL 29~,000 NPHI CALl -999,250 GR FCN5 -999.250 49.435 :999,250 999,250 -999.250 -999,250 50.938 -999,250 -999,250 -999,250 -999,250 42,813 -999,250 -999.250 -999.250 -999,250 76 375 -999~250 -999,250 -999.250 -999,250 55,8~3 -999,250 -999,250 -999 · 250 -99 250 5~:750 '999,250 '999,250 -999,250 -999,250 . 48,625 999,250 -999,250 -999,250 -999,250 44,688 -999,250 999,250 NRAT IbM DI NRAT RHOB DT NRAT RHOB NRAT DT NRAT NRAT IbM DT NRAT RHOB NRAT DT NRAT RHOB NRAT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT 3.760 -999,250 -999.250 -999,250 -999,250 ~,803 -999.250 -999,250 -999.250 -999,250 4.152 -999.250 -999,250 -999,250 -999.250 3,984 -999,250 -999.250 -999 250 3.898 -999,250 -999,250 -999,250 -999.250 4,047 -999,250 -999,250 -999,250 -999'250 3,912 -999'250 -999.250 -999.250 -999,250 4,098 -999,250 -999,250 NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRMO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb NCNb DRHO NCNb ILD GR NCNL DRHO NCNb GR NCNb DRHO NCNb 1437,000 -999,250 -999,250 -999.250 -999,250 1614.000 -999.250 -999.250 -999,250 -999,250 1404.000 -999,250 -999,250 -999 250 -999;250 ~.512i000 999 250 -999 250 -999 250 -999 250 1386 000 -999 250 -999 250 -999 250 -999 250 1294 000 -999 250 -999 250 -999.250 -999,250 1469'000 -999,250 -999,25O -999.250 ~999,250 421,000 -999,250 -999,250 ,VP iEPT ;P i'PHi 'CN~ )EPT 'CNL ~CNL )EPT ~PHI ~CNL ,'ALI ~CN~ ~P ~PHi ~CNL %ALi ~CND DEPT 5P ~PHI %ALI ?CNL SP I~PHI FC~L CAbI DEPT SP FCNL CALl FCNU DEPT SP NPHI FCNb CALi 009,H05 V~RIFICATION LISTING 7300,000 SFDU -999,250 GR ~44,434 Ga 358,000 NPHi -999,250 GR -999,250 -999,250 -999,250 49,563 -999,250 -999,250 7200.000 SFLU -999.250 GR 38,574 GR 424.500 NPHI -999,250 GR -999,250 -999.250 -999.250 37,438 -999'250 -999,250 7100.000 SFLU -999'250 GR 46,43~ G~ 322,000 NPHI -999,250 GR -999,250 -999.250 '999.250 34.750 -999,250 -999'250 '7000.000 SFLU -999'250 GR ]9,600 GR 412.750 NPMI -999.250 GR -999.250 .-999 250 4~.094 -999,250 -999.250 6900.000 -999.250 G~ 51,172 GR 269,250 NPHI -999,25O GR -999.250 -999.250 -999.250 51.375 -999.250 -999.250 6BOO.OOU $FbU -999.250 GR 4~.727 GR 330.250 NPHI -999.250 GR -999.250 -999.250 -999.250 32.781 -999.250 -999.250 6700.000 SFLO -999.250 GR 57.275 GR 330.25~ NPHI -999.250 GR -999.250 -999.250 -999.250 45.438 -999.250 -999.250 6600.000 SFbU -~99.250 GR 42.773 GR 471.500 NPMI -999.250 GR -999.250 -999.250 3b.281 -999.250 -999.250 DT NRAT DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT RHOB NRAT -999,250 -999.250 3,840 -999,250 -999.250 -999.250 -999,250 3,520 -999'250 -999'250 -999,250 -999.250 3,949 -999'250 -999'250 -999.250 -999,250 3.576 -999.250 -999.250 -999.250 -999,250 4,211 -999,250 -999.250 -999.250 -999,250 ~.~57 -999.250 -999,250 -999.250 -999.250 4,543 -999.250 -999.250 -999.250 -999,250 3,750 -999,250 -999.250 GR NCNb DRHO GR NCNb DRHO NCNb IbD GR NCNb DRHO NCNb GR NCNb DRHO NCNb ILO NCNb DRHO NCNL NCNb DRHO NCNb NCNb DRHG GR NCND DRHO PAGE -999,250 -999,250 [347.000 -999,250 -999.250 -999.250 -999,250 1528.000 -999.250 -999.250 -999.250 -999 250 '999,250 '999,250 -999.250 -999 250 1445i000 -999 250 -999,250 -999.250 -999.250 1263'000 -999.250 -999,250 -999.250 -999.250 i339.000 -999.250 -999.250 -999.250 -999.250 1~21.000 -999.250 -999.250 -999.250 -999.250 ~729.000 -999.250 -999.250 bVP 009.H05 VERIFICATION LISTING PAGE 9 FCNb -999.250 DEPT 6500,000 SFLU SP -999.250 GR NPHI 34,961 GR FCNL 428,750 NPHI CALl -999,250 GR FCNb -999,250 DEPT ~400,000 SFbU SP -999,250 GR NPHI '50.342 GR FCNb 313.250 NPHi CALi -999,250 GR FCN~ -999,250 DEP'f 6300.000 SFLU SP -999,250 GR NPHI 43,262 GR FCN5 377,500 NPHI CALf -999,25u GR FCNb -999,250 DEPT 6200.000 SFLU SP -999,250 GR NPHI 51,221 GR FCNb 345,500 NPHI CAbI -999.250 GR FCNb -999,250 DEPT ~i00,000 SFLO SP 999.250 GR NPHI 49.t70 GR FCNL 277.000 NPHI CALl -999.250 GR FCNb -999.250 DEPT 6000,000 SFbU SP -999.250 GR NPHI 58.154 GR FCN~ 229.500 NPHI CALI -999,250 GR FCNb -999.250 DEPT 5900.000 SFbU SP -999,250 GR NPH! 48.096 GR FCNL 285.500 NPHI CALI -999.250 GR FCNL -999.250 DBPT 5~00,000 SFbU Sp -999.250 GR NPHI 52.637 GR -999,250 -999.250 16.391 -999,250 -999,250 -999.250 -999,250 39.406 -999,250 -999,250 -999,250 -999.250 30.688 -999.250 -999,250 -999.250 -999.250 22.375 -999,250 -999.250 -999 250 -999,250 -999.250 -999.250 -999.250 44.438 -999.250 -999.250 -999.250 -999.250 31.219 '999,250 -999.250 '999.250 -999.250 46.031 IbM DT NRAT RHOB NRAT IbM NRAT RHOB NRAT IbM OT NRAT NRAT IbM DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT IbM DT NRAT -999.250 -999.250 3.320 -999,250 -999,250 -999,250 -999.250 4.164 -999.250 -999.250 -999,250 -999,250 3,775 -999,250 -999.250 -999.250 -999.250 4,211 -999,250 -999.250 -999.250 -999,250 4.098 -999,250 -999.250 -999,250 -999,250 4,594 -999,250 -999,250 -999,250 -999.250 4,043 -999.250 -999,250 -999.250 -999.250 .4.289 GR NCNb DRHO NCNb GR NCNb DRHO NCNb IbD GR NCNb DRHO NCNb IbP GR NCNb DRHO NCNb GR NCNb DRMO NCNb GR NCNb DRHO NCNb NCNb DRHO NCNb IbD GR NCNb -999.250 -999.250 1632.000 -999,250 -999.250 -999.250 -999.250 1451.000 -999.250 -999.250 -999,250 -999,250 1476,000 -999.250 -999.250 -999 250 -999 250 1589 000 -999 250 -999 250 -999 250 1246.000 -999,250 -999.250 -999,250 -999,250 1041,000 -999.250 -999.250 -999,250 -999.250 1107,000 -999,250 -999,250 -999,250 -999,250 1303.000 :ALI ~CN~ )EPT ~P ~PHi "CNL ]AI~I ~CNL )EPT 5P ~PHi rCNb ?CNb )EPT ~P gPHi FCND ."ALI FCN5 DEPT SP NPHI FCNL CALl FC~b DEP.j~~ SP NPHI FCNu CALl FCNb DEPT SP NPHI FCNL CALi FCNL DEPT SP NPHY FCNL CAL~ FCNb 009.H05 VERIFIC,ATION 5ISTING 267.750 NPHI -999,250 GR -999,250 -999,250 -999,250 5700.000 SFLU -999,250 GR 56,543 GR 285.000 NPHI -999,250 GR -999.250 -999.250 -999.250 4~.500 -99 ,250 -999.250 5600.000 SFLU -999.250 GR -46,682 GR 380.750 NPHI -999,250 GR -999.250 -999.250 -999 250 24~125 -999.250 -999.250 5500 000 SFLU -999~250 GR -43,408 GR ~96,500 NPHi -999,250 GR -999,250 -999,250 -999,250 33,875 -999,250 -999,250 5400.000 SFLU -999,250 GR -41,699 GR 347.000 NPHI -999,250 GR -999.250 -999.250 -999.250 37.750 -999.250 -999,250 5300.000 -999,250 GR 75,244 GR 170.500 NPHI -999.250 GR -999.250 -999,250 -999.250 23.922 -999.250 -999.250 5200.000 SFDU -999,250 GR 50,584 GR 27~,750 NPHI -999.250 G~ -999.250 -999,250 -999,250 32.688 -999.250 -999.250 5100.000 SF5U -999,250 GR 55,566 GR 301.500 NPHI -999.250 G~ -999.25O -999,250 -999.250 36.000 -999.250 -999.250 RHOS NRAT DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT NRAT RHOB Ib~ DT NRAT RHOB NRAT IBM DI NRAT mRAT -999,250 -999,250 -999.250 -999,250 4'504 -999.250 -999.250 -999,250 -999,250 4,074 -999,250 -999,250 -999,250 -999,250 3,783 -999.250 -999,250 -999.250 -999.250 3.691 -999.250 -999.250 -999,250 -999.250 5.53~ -999,250 -999.250 -999,250 -999,250 4,184 -999,250 -999,250 -999,250 -999,250 4,449 -999,250 -999,250 DRHO NCNb NCNb DRHO NCN~ IbP GR NCNb DRHO NCNb ILL GR NCNb DRHO NCNb IbP GR NCNb DRMO NCNb GR NCNb DRHO NCNb NCNb DRHU NCN~ GR NCNb DRHD NCNb PAGE -999,250 -999,250 -999.250 -999.250 1211'000 -999,250 -999.250 -999.250 -999.250 i593.000 -999.250 -999.250 -999,250 -999,250 151'1'000 -999,250 -999,250 -999,250 -999,250 1422,000 -999,250 -999,250 -999.250 -999.250 1091.000 -999.250 -999.250 -999,250 -999,250 1289,000 -999,250 -999.250 -999.250 ~999 250 223~000 -999,250 -999,250 DEPT 5000.000 SFLU -999.250 IbM -99g.250 IbP -999.250 bVP 009.H05 VERIFICATION bISTING PAGE 11 SP -999.250 GR NPHI '30.322 GR FCNb 479,250 NPHi CALl -999.250 GR FCNL -999.250 D~P~ 4900.000 SFLU SP '~99,250 GR NPHI 27.002 GR FCNL 663.500 NPHI CALl '999.250 GR FCNb '999.250 DEPT 4~00.000 SFLU BP '999.250 GR NPHI -'55.371 GR FCNL 260.250 NPHI CALl '999.250 GR FCNb '999.250 DEPT 4700,000 SFLU SP '999,250 GR NPHi -57.568 GR FCNL 263.000 NPHI CALl -999.250 GR FCNb -999.250 DEPT 4bO0.O00 SFDU SP -999.250 GR NPHI 37,891 GR ~FCNL 478'750 NPHI CALI '999,250 GR FCNb '999.250 DEPT 4500.000 SFLU SP '999.250 GR NPHI ~'4b.875 GR FCNL 316.000 NPHI CAbl '999,250 GR FCNb '999,250 DEPT 4400.000 SFLU Sp '999.250 GR NPHI -70.459 GR FCNb 21~,375 NPHI CA~i -99 ,250 GR FCNb '999.250 DEPT ~300,000 BF'[,U SP -999,250 GR NPHI '44.092 GR FCNb 350.000 NPHi CALl -999.250 GR FCNb -999,250 -999.250 19.188 -999.250-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 33.156 -999.250 -999.250 -999.250 -999,250 44.844 -999.250 -999.250 -999 250 -999~250 16.469 -999,250 -999.250 -999.250 -999~,250 33.688 -999,250 -999.250 -999 250 39.312 -999.250 -999.250 -999.250 -999,250 32.625 -999,250 -999.250 DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT DT NRAT RHOB NRAT DT NRAT RHOB NRAT D~ NRAT RHOB NRAT DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT -999.250 GR 3.066 NCNb -999.250 DRHO -999.250 NCNb -999.250 IbP -999.250 GR 2.883 NCNb -999.250 DRHO -999.250 NCNb -999.250 -999.250 GR 4,438 NCNb -999.250 DRHO -999.250 NCNb -999.250 -999.250 GR 4,559 NCNb -999'250 DRHO -999,250 NCNb -999,250 -999,250 GR 3.480 NCNb -999,250 DRHO -999.250 NCNb -999.250 ILL -999'250 GR 3.977 NCNb -999,250 DRHO -999,250 NCNb -999 ~50 IUD -999:50 GR 5'266 NCNb -999,250 DRHO -999,250 NCNb -999.250 lbD -999,250 GR 3,820 NCNb -999,250 'DRMO -999,250 NCNb -999.250 1586.000 -999.250 -999.250 -999.250 -999'250 1956.000 -999.250 -999.250 -999.250 -999.250 1370.000 -999,250 -999.250 -999.250 -999,250 1368.000 -999'250 -999.250 -999,250 -999.250 1578'000 -999.250 -999,250 -999.250 -999,250 1.513,000 999 · 250 -999,250 -999.250 -999'250 1232,000 -999,250 -999'250 -999.250 -999'250 1516.000 -999,250 -999,250 )EPT ;P {PHi )EPT ~P ~PHI ~CNL cCNb )EPT ~P 9PHI ?CNL ."AL1 ?CNb 5P VPHI 2A~i DEPT NPHI FCNL CALX FCNb DEPT SP NPHI FCNb CAbi FCi~L DEPT SP NP~I FCNb CALl FCN~ DEPT SP NPtiI FCNL O09.HU5 VERIFICATION 5ISTING 4200,000 SFLU -999,250 GR 46.729 GR ~07.000 NPHI -999.250 GR -999,250 4100.000 SFLU -999.250 GR ~52.051 GR 327.500 NPHI -999.250 GR -999,250 4000.000 SFLU -999'250 GR 49.805 GR 310.250 NPHI -999.250 GR -999.250 3900.000 SFLU -999'250 GR 58.887 GR 206,375 NPHI -999,250 GR -999,250 3800,000 SFLU -999,250 GR '~48.242 GR 255.750 NPHI -999.250 GR -999,250 3700.000 SFEU -999.250 GR 55,o64 GR 240.750 NPHi -999,250 GR -999,250 ~bO0.O00 SFLU -999,250 GR ~61.719 GR 257.500 NPHI -999.250 Ga -999.250 3500.000 SFLU -999.250 GR -59.814 GR 252.525 NPHI -999,250 -999,250 43'000 -999,250 -999,250 -999.250 -999.250 23.047 -999.250 -999.250 -999.250 -999,250 44"375 -999.250 -999,250 -999,250 -999.250 46.656 -999,250 -999,250 -999.250 -999.250 35.688 -999.250 -999.250 -999.250 -999,250 40.688 -999.250 -999,250 -999.250 -999.250 39.156 -999.250 -999.250 -999.250 -999.250 43,281 -999.250 IbM DT NEAT RHOB NEAT DT NEAT RHOB NEAT IbM NEAT RHOB NEAT DT NEAT RHOB NEAT DT NRAT RHOB NEAT DT NRAT RHOB NRAT DT NEAT RHOB NEAT IbM DT NRAT RHO~ -999.250 -999,250 3.967 -999.250 -999.250 -999,250 -999.250 4,258 -999,250 -999,250 -999.250 -999'250 4,133 -999,250 -999.250 -999.250 -999.250 4.633 -999,250 -999.250 -999,250 -999,250 4.047 -999,250 -999,250 -999.250 -999.250 4.457 -999.250 -999,250 -999.250 -999.250 4.789 -999.250 -999.250 -999.250 -999.250 4.684 -999.250 GR NCNb DRMO NCNb NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb IbP GR NCNb DRHO NCNb ILD GR NCNb DRHO PAGE 12 -999.250 -999.250 1313.000 -999,250 -999.250 -999,250 '999'250 1396,000 -999.250 -999,250 -999.250 -999'250 1431.000 -999.250 -999.250 -999 250 '999i250 1101 000 -999 250 -999.250 -999,250 -999.250 1091.000 -999.250 -999,250 -999,250 -999,250 1066,000 -999,250 -999,250 -999,250 -999,250 1218,000 -999.250 -999,250 -999.250 -999.250 ~2~6 000 999:250 LVP 009.H05 VERIFICATION LISTING PAGE 13 CALl -999.250 GR FCNL -999.250 D£PT ~00 000 SFLU SP -999:250 GR NPHI -46.094 GR ~c~ 30~.250 N~Z CALl -999.250 GR FCNL -999.250 DEPT 3300.000 SFLU SP -999.250 GR NPHi *'74.414 GR FCNL 2~3.37b NPHI CALl -9 9.250 GR FCN~ -999.250 DEPT 3200.000 SFLU SP -999.250 GR NPHI -66.113 GR FCN5 226,500 NPH~ CALI -999.250 GR FCNG -999.250 DEPT 3100.000 SFLU SP -999.250 GR NPHI "52.637 GR FCN5 226.000 NPHI CALl -999.250 GR FCNG -999.250 DEPT 3ooo.ooo s~Lu SP -999.250 GR NPHI 59.375 GR Fc~ 227 ooo ~P~z CALl ~999~'250 GR FCNu 999.250 DEPT 2900.000 SFLU SP -999.250 GR NPHI -61.230 GR FCNL 192.875 NPHI CALl -999.250 GR FCNL -999.250 DEPT 2800.000 SFLU SP -999.250 GR NPHI -52.783 GR FCNL 24i,875 NPHI CALl -999.250 GR FCNL -999.250 DEPT 2700.000 SFLU Sp -999.250 GR -999.250 -999.250 '999.250 30.609 -999.250 -999.250 -999.250 '999.250 41,156 99,250 -999.250 -999 250 42:000 -999.250 -999.250 -999.250 -999.250 38,813 -999,25O -999.250 :999.250 999.250 31 234 -999:250 -999.250 -999.250 -999.250 27.578 -999,250 -999.250 -999.250 -999.250 24.063 -999.250 -999.250 '999,150 '999. 50 NR~T DT NRAT NRAT IbM D~ NRAT RHOB NRAT IbM DT NRAT RHOB NRAT DT NRAT NRAT DT NRAT RHOB NRAT DT NRAT RHO5 NRAT I~M DT NRAT RHOB NRAT I~ DT -999.250 -999.250 -999.250 3.932 '999.250 -999.250 -999.250 -999.250 5.484 -999.250 -999.250 -999.250 -999.250 5.031 -999.250 -999.250 -999.250 -999.250 4,289 -999.250 -999.250 -999.250 -999.250 ~ 4,660 - 99.250 -999.250 -999.250 -999.250 4.762 -999.250 -999.250 -999.250 -999.250 4.297 -999.250 -999.250 -999.250 -999.250 NCNb GR NCNb DRHO NCNb GR NCNb DRHO NCNb I~D GR NCNb DRHO NCNb GR NCNb DRHO NCN~ GR NCNU DRHO NCNb GR NCNL DRHO NCNb GR NCNb DRHO NCNb I LD GR -999.250 -999.250 -999.250 1370.000 999:250 -999.250 -999.250 1165.000 -999.250 -999.250 -999.250 -999,250 1010,500 -999.250 -999.250 -999,250 -999'250 1165.000 -999,250 -999.250 -999.250 -999.250 1048 000 -999~250 -999.250 -999,250 -999.250 1.122 000 -999.250 -999.250 11 '000 -999.250 -999,250 -999.25O -999.250 ,VP 009,H05 VERIFICATION LISTING IPHI 53.906 GR 'CNL ~08 250 NPH~ FALl -999~250 GR ~CNL -999,250 . )EPT 2000,000 SFLU ~P -999,250 GR ~PHI 66.699 GR ~CNL 242.~75 NPHZ :ALi -999*250 GR ~CNL -999,250 )EPT 2500.000 SFLU ~P -999.250 GR ~PHi '63,574 GR ~CNL 225.000 NPHI ~ALI -999,250 GR ~CNb -999.250 )EPT 2491,000 SF~U ~P -999,250 GR ~PHI "7i,4~6 GR FCN~ 243,375 NPHI ~ALI -999,250 GR ~CNL -999.250 ~7.047 -999'250 -999,250 -999,250 -999,250 24.469 -999.250 -999'250 -999,250 -999,250 14'438 -999'250 -999,250 -999.250 -999,250 18'203 -999,250 -999'250 ~ FILE TRAILER ~ FI~E NA~ :SERVIC.O01 SERVICE NA~E : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 NEXT FILE NAME : EOF ** TAPE TRAILER *~ SERVICE NAME :SERVIC DATE :~2/02/ 6 ORIGIN :1o70 TAPE NAME :62543 CONTINUATION # 101 NEXT TAPE NAME : COMMENTS :TAPE COMMENTS SERVICE NAME :SgRVIC DATE :82/02/ 6 ORIGIN : REEL NAME :REEL ID NRAT RHOB NRAT IbM DT NRAT RHOB NRAT IbM DT NRAT RHOB NRAT DT NRAT RHOB NRAT 4.359 -999.250 -999,250 -999.250 -999.250 5,059 -999.250 -999.250 -999.250 -999,250 4,887 -999.250 -999,250 -999.250 -999,250 5.320 '999.250 -999*250 NCNb DRHO NCNb IbD GR NCNb DRHO NCNb NCNb DRHO NCNb GR NCNb DRHO NCNb PAGE 14 1421.000 -999,250 -999.250 -999 250 -999 250 1350 000 -999 250 -999 250 -999.250 -999250 1142!000 -999 250 -999 250 -999.250 00'000 -999.250 -999.250 LVP 099.H05 VERIFICATION 6ISTING PAGE CONTI~UATION # :01 NEX~ R£~6 NA~E : COMNENf6 :REEL COMMENTS EOF
