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Home My WebLink About177-037MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, June 12, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-16 PRUDHOE BAY UNIT 09-16 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/12/2024 09-16 50-029-20257-00-00 177-037-0 W SPT 8118 1770370 2280 1249 1251 1257 1261 390 584 583 591 REQVAR F Kam StJohn 5/4/2024 2 Year MIT per AIO 4E.015 max anticipated pressure 2280 psi Failed to have stabilizing trend 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 09-16 Inspection Date: Tubing OA Packer Depth 114 3000 2948 2916IA 1257 590 45 Min 2885 60 Min Rel Insp Num: Insp Num:mitKPS240504175651 BBL Pumped:6.1 BBL Returned:6 Wednesday, June 12, 2024 Page 1 of 1 9 9 9 9 9 9 9 9999 9 9 9 9 AIO 4E.015 Failed to have stabilizing trend F James B. Regg Digitally signed by James B. Regg Date: 2024.06.12 14:24:19 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector 09-16 (PTD # 177-037) Failed MIT-IA"s Date:Wednesday, May 15, 2024 8:21:44 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, May 15, 2024 8:20 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: NOT OPERABLE: Injector 09-16 (PTD # 177-037) Failed MIT-IA's Mr. Wallace, Produced water injector 09-16 (PTD# 177037) failed recent online and shut in MIT-IA’s. The well has no further immediate utility and is now classified as NOT OPERABLE. The well will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Saturday, May 4, 2024 7:03 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Injector 09-16 (PTD # 177-037) Failed AOGCC MIT-IA Mr. Wallace, Produced water injector 09-16 (PTD# 177037) failed AOGCC witnessed MIT-IA on 05/04/24. The well operates under AIO AA 4E.015 for slow IAxOA communication and will be shut in as soon as pad snow removal is complete to allow for freeze protection of the tubing and flowline. The failing MIT- IA indicates loss of integrity of one or more well barriers. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan forward: 1. DHD: PPPOT-T & IC 2. Fullbore: Offline MIT-IA 3. Well Integrity / OE: Further action as required 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: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, February 24, 2021 12:46 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com> Subject: OPERABLE: Injector 09-16 (PTD # 177-037) Tubing x IA communication repaired Mr. Wallace, Produced water injector 09-16 (PTD# 177-037) was made UNDER EVALUATION on 01/30/2021 to monitor for TxIA communication post tubing hanger green stick sealant treatment on 01/28/2021 executed under sundry #320-531. Follow up monitoring of the IA pressure with the well on injection has shown that the TxIA repair was successful. This well operates under AIO 4E.015 for slow IAxOA communication, per the AA requirements AOGCC permission was granted to resume injection on 2/24/2021. This well is now classified as OPERABLE. Please respond with any questions. Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, June 8, 2020 4:01 PM To: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector 09-16 (PTD # 1770370) Tubing x IA x OA communication All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015 for IAxOA communication. It was placed Under Evaluation on 04/27/20 to evaluate Tubing x IA communication. It was reclassified Operable after passing an MIT-T, CMIT-TxIA, and MIT-OA. However, since brought back online, the IA has required frequent bleeds to maintain pressure below the AA-specified IA NOL of 1000 psi. Pressure trends indicate Tubing x IA x OA communication. The well is now classified NOT OPERABLE, and must be shut in as soon as operationally feasible. Please reply with any questions, Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 16, 2020 10:40 AM To: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE: Injector 09-16 (PTD # 1770370) MIT-T & CMIT-TxIA Passed All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015. On 04/29/20 an MIT-OA Passed to 1094 psi and on 05/15/20 an MIT-T and CMIT-TxIA Passed to 2500 psi which verifies integrity of both primary and secondary well barriers. The well is now classified as OPERABLE. The well will requires 24 month AOGCC MIT-IA in the month of June 2020. Please reply if in conflict. Ryan Holt BP Alaska Well Integrity (Alternate Adrienne McVey) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, April 27, 2020 11:37 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector 09-16 (PTD # 1770370) IA exceeded Normal Operating Limit All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015. On 04/26/20, the inner annulus (IA) pressure exceeded 1000 psi, the limit specified by AIO 4E.015. Maximum recorded IA pressure was 1083 psi. The well was shut in. Pressure trends indicate a failure of one or more well barriers. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan Forward: 1. Operations: leave well shut in. Per AIO 4E.015, the well must remain shut in until AOGCC grants approval to restart injection. 2. Downhole Diagnostics: MIT-IA, MIT-OA 3. Well Integrity: additional diagnostics as required. Please reply if in conflict. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 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. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector 09-16 (PTD # 177-037) Failed AOGCC MIT-IA Date:Monday, May 6, 2024 11:52:01 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, May 4, 2024 7:03 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com> Subject: UNDER EVALUATION: Injector 09-16 (PTD # 177-037) Failed AOGCC MIT-IA Mr. Wallace, Produced water injector 09-16 (PTD# 177037) failed AOGCC witnessed MIT-IA on 05/04/24. The well operates under AIO AA 4E.015 for slow IAxOA communication and will be shut in as soon as pad snow removal is complete to allow for freeze protection of the tubing and flowline. The failing MIT- IA indicates loss of integrity of one or more well barriers. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Plan forward: 1. DHD: PPPOT-T & IC 2. Fullbore: Offline MIT-IA 3. Well Integrity / OE: Further action as required 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: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Wednesday, February 24, 2021 12:46 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Aras Worthington <Aras.Worthington@hilcorp.com>; Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Bo York <byork@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com> Subject: OPERABLE: Injector 09-16 (PTD # 177-037) Tubing x IA communication repaired Mr. Wallace, Produced water injector 09-16 (PTD# 177-037) was made UNDER EVALUATION on 01/30/2021 to monitor for TxIA communication post tubing hanger green stick sealant treatment on 01/28/2021 executed under sundry #320-531. Follow up monitoring of the IA pressure with the well on injection has shown that the TxIA repair was successful. This well operates under AIO 4E.015 for slow IAxOA communication, per the AA requirements AOGCC permission was granted to resume injection on 2/24/2021. This well is now classified as OPERABLE. Please respond with any questions. Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, June 8, 2020 4:01 PM To: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector 09-16 (PTD # 1770370) Tubing x IA x OA communication All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015 for IAxOA communication. It was placed Under Evaluation on 04/27/20 to evaluate Tubing x IA communication. It was reclassified Operable after passing an MIT-T, CMIT-TxIA, and MIT-OA. However, since brought back online, the IA has required frequent bleeds to maintain pressure below the AA-specified IA NOL of 1000 psi. Pressure trends indicate Tubing x IA x OA communication. The well is now classified NOT OPERABLE, and must be shut in as soon as operationally feasible. Please reply with any questions, Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, May 16, 2020 10:40 AM To: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE: Injector 09-16 (PTD # 1770370) MIT-T & CMIT-TxIA Passed All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015. On 04/29/20 an MIT-OA Passed to 1094 psi and on 05/15/20 an MIT-T and CMIT-TxIA Passed to 2500 psi which verifies integrity of both primary and secondary well barriers. The well is now classified as OPERABLE. The well will requires 24 month AOGCC MIT-IA in the month of June 2020. Please reply if in conflict. Ryan Holt BP Alaska Well Integrity (Alternate Adrienne McVey) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, April 27, 2020 11:37 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector 09-16 (PTD # 1770370) IA exceeded Normal Operating Limit All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015. On 04/26/20, the inner annulus (IA) pressure exceeded 1000 psi, the limit specified by AIO 4E.015. Maximum recorded IA pressure was 1083 psi. The well was shut in. Pressure trends indicate a failure of one or more well barriers. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan Forward: 1. Operations: leave well shut in. Per AIO 4E.015, the well must remain shut in until AOGCC grants approval to restart injection. 2. Downhole Diagnostics: MIT-IA, MIT-OA 3. Well Integrity: additional diagnostics as required. Please reply if in conflict. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 09-16 PRUDHOE BAY UNIT 09-16 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 09-16 50-029-20257-00-00 177-037-0 W SPT 8118 1770370 2030 1421 1420 1422 1421 388 572 571 582 REQVAR P Adam Earl 5/8/2022 MIT IA tested as per AIO 4E.015 to max inj. PSI 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 09-16 Inspection Date: Tubing OA Packer Depth 28 2506 2472 2455IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509075852 BBL Pumped:4.6 BBL Returned:4.6 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 AIO 4E.015 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:33:02 -08'00' Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Wednesday, February 24, 2021 12:46 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Aras Worthington; Alaska NS - PB - Field Well Integrity; Oliver Sternicki; Bo York; John Condio - (C) Subject: OPERABLE: Injector 09-16 (PTD # 177-037) Tubing x IA communication repaired Mr. Wallace, Produced water injector 09-16 (PTD# 177-037) was made UNDER EVALUATION on 01/30/2021 to monitor for TxIA communication post tubing hanger green stick sealant treatment on 01/28/2021 executed under sundry #320- 531. Follow up monitoring of the IA pressure with the well on injection has shown that the TxIA repair was successful. This well operates under AIO 4E.015 for slow IAxOA communication, per the AA requirements AOGCC permission was granted to resume injection on 2/24/2021. This well is now classified as OPERABLE. Please respond with any questions. Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, lune 8, 2020 4:01 PM To: AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2FieldPTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>; 'chris.waIlace @alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIG EWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen @bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector 09-16 (PTD # 1770370) Tubing x IA x OA communication All, Wallace, Chris D (CED) From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, February 18, 2021 11:57 AM To: Wallace, Chris D (CED) Cc: Alaska NS - PB - Field Well Integrity Subject:09-16 (PTD# 177-037) request for restart under AIO 4E.015 Attachments: 09-1 _ ECEMBER2020_70-403.pdf Mr. Wallace, Injection well 09-16 (PTD# 177-037) had hanger sealant repair work completed under Sundry # 320-531 on 1/26/21- 1/28/21 to repair TxIA communication. The well was then placed on injection under evaluation per the sundry on 1/31/21 for up to 28 days to evaluate the effectiveness of the repair. Based on the TIO plots and injection rates the TxIA communication has been repaired. Hilcorp requests permission to continue injection into 09-16 under the requirements of AIO 4E.015 and return the well to Operable status. The most recent AOGCC witnessed MIT -IA was conducted on 5/24/2020 and passed to 2469 psi. A 10-404 for the wellhead repair work is currently in the process of being submitted. Regards, Oliver Sternicki Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com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RBDMS HEW 1/26/2021 tĞůůŚĞĂĚ^ĞĂůĂŶƚZĞƉĂŝƌ tĞůů͗ϬϵͲϭϲ Wd͗ϭϳϳϬϯϳ W/͗ϱϬͲϬϮϵͲϮϬϮϱϳͲϬϬ :HOOKHDG6HDODQW5HSDLU :HOO,QWHJULW\(QJLQHHU2OLYHU6WHUQLFNL 2SHUDWLRQV(QJLQHHU7RULQ5RVFKLQJHU ([SHFWHG6WDUW'DWH +LVWRU\ 3URGXFHGZDWHULQMHFWRU37'RSHUDWHVXQGHU$GPLQLVWUDWLYH$SSURYDO$,2( IRUVORZ,$[2$FRPPXQLFDWLRQ2QWKH,$SUHVVXUHH[FHHGHGWKHSVLSUHVVXUHOLPLW VSHFLILHGE\$,2(2QDQ0,72$SDVVHGWRSVLDQGRQDQ0,77DQG &0,77[,$3DVVHGWRSVLZKLFKYHULILHGLQWHJULW\RIERWKSULPDU\DQGVHFRQGDU\ZHOOEDUULHUV $IWHUWKHZHOOZDVSODFHGRQLQMHFWLRQRQWKH,$UHTXLUHGIUHTXHQWEOHHGVWRPDLQWDLQ SUHVVXUHEHORZWKH$$VSHFLILHG,$SUHVVXUHOLPLWRISVL7KHZHOOZDVVKXWLQDQGUHFODVVLILHG DVQRWRSHUDEOHRQ:HOOKHDGGLDJQRVWLFVRQLQGLFDWHWKDWWKH7[,$ FRPPXQLFDWLRQPD\EHPRYLQJDFURVVWKHZHOOKHDGVHDOVEXWQRUHSDLUZDVDWWHPSWHGDWWKHWLPH GXHWRWKHSDVVLQJ0,77RQ &XUUHQW6WDWXV LVFXUUHQWO\VKXWLQDQGFODVVLILHGDVQRWRSHUDEOH 2EMHFWLYH 5HSDLUOHDNLQJWXELQJSDFNRIIVE\LQMHFWLQJVHDODQWZHOOORFNJUHHQVWLFNSDFNLQJLQWRWKHSDFNLQJSRUW DQGRUWXELQJKDQJHUYRLGWKURXJKDSRUWHGORFNGRZQVFUHZDQGRUWKHWHVWSRUW 3URFHGXUH ,QMHFWVHDODQWZHOOORFNJUHHQVWLFNSDFNLQJLQWRWKHSDFNLQJSRUWDQGRUWXELQJKDQJHUYRLG$WWHPSWWR VTXHH]HWRSVL 32,8QGHU(YDOXDWLRQDQGPRQLWRUIRU7[,$UHSUHVVXUL]DWLRQIRUGD\V +LOFRUS1RUWK6ORSH//& +LOFRUS1RUWK6ORSH//& MEMORANDUM TO: Jim Regg P.I.Supervisor FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Friday, June 5, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. 09-16 PRUDHOE BAY UNIT 09-16 Ste: Inspector Reviewed By: P.I. Supry c.— Comm Well Name PRUDHOE BAY UNIT 09-16 API Well Number 50-029-20257-00-00 Inspector Name: Bob Noble Permit Number: 177-037-0 Inspection Date: 5/2412020 Insp Num: mitRCN200524140456 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-16 Type Inj W. TVD sns . Tubing 910 . 911- 910 -1 910 - PTD 1770370 , Type Test SPT Test psi 2030 IA 304 2495. z476 . 2469 - BBL Pumped: 4 -8B Returned: 4.3 OA 76 _ 303. 335. 358 - Interval REQVAR WIT P ✓ Notes: 2 Year MIT -IA per A104E.015 Friday, June 5, 2020 Page I of I Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Saturday, May 16, 2020 10:40 AM To: AK, GWO SUPT Well Integrity; AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan; Richards, Meredyth; Wallace, Chris D (CED) Cc: AK, GWO DHD Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J; Lau, Jack; Mcmullen, John C; Regg, James B (CED) Subject: OPERABLE: Injector 09-16 (PTD # 1770370) MIT -T & CMIT-TxIA Passed All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015. On 04/29/20 an MIT -OA Passed to 1094 psi and on 05/15/20 an MIT -T and CMIT-TxIA Passed to 2500 psi which verifies integrity of both primary and secondary well barriers. The well is now classified as OPERABLE. The well will requires 24 month AOGCC MIT -IA in the month of June 2020. Please reply if in conflict. Ryan Holt BP Alaska Well Integrity (Alternate Adrienne McVey) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com> Sent: Monday, April 27, 2020 11:37 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Ak, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2 Field PTL@bp.com>; AK, OPS FS2 OSM <AKOPSFS2OSM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth.Richards@bp.com>;'ch ris.waI lace @alaska.gov' <chris.waIlace @alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau @bp.com>; Mcmullen, John C <John.McMullen@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector 09-16 (PTD # 1770370) IA exceeded Normal Operating Limit All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015. On 04/26/20, the inner annulus (IA) pressure exceeded 1000 psi, the limit specified by AIO 4E.015. Maximum recorded IA pressure was 1083 psi. The well was shut in. Pressure trends indicate a failure of one or more well barriers. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan Forward: 1. Operations: leave well shut in. Per AIO 4E.015, the well must remain shut in until AOGCC grants approval to restart injection. 2. Downhole Diagnostics: MIT -IA, MIT -OA 3. Well Integrity: additional diagnostics as required. Please reply if in conflict. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 Wallace, Chris D (CED) From: Wallace, Chris D (CED) Sent: Friday, May 15, 2020 5:46 PM To: AK, GWO SUPT Well Integrity Cc: AK, GWO Well Integrity Engineer; Regg, James B (CED) Subject: RE: UPDATE UNDER EVALUATION: Injector 09-16 (PTD # 1770370) IA exceeded Normal Operating Limit Ryan, Request to resume injection under the administration approval conditions is granted. Regards, Chris -------- Original message -------- From: "AK, GWO SUPT Well Integrity" <AKDCWellintegrityCoordinator@bp.com> Date: 05/15/2020 4:14 PM (GMT -09:00) To: "Wallace, Chris D (CED)" <chris.waIlace @alaska.gov> Cc: "AK, GWO Well Integrity Engineer" <AKGWOWellSiteEnginee@bp.com>, "Regg, James B (CED)" <jim.regg@alaska.gov> Subject: UPDATE UNDER EVALUATION: Injector 09-16 (PTD # 1770370) IA exceeded Normal Operating Limit Mr. Wallace, Injector 09-16 (PTD# 1770370) passed both MIT -T & CMIT-TxIA to 2500 psi on 05/15/20 which verifies integrity of both primary and secondary well barriers. An MIT -OA passed to 1100 psi on 04/29/20. At this time we seek AOGCC approval as required in Administrative Approval AIO 4E.015 to resume PWI injection. If approval is granted, once the well thermally stable, we will execute required 24 month AOGCC witnessed MIT -IA that is due June 2020. Please respond at your earliest convenience. Thank you, Ryan Holt BP Alaska Well Integrity (Alternate: Adrienne McVey) Office: (907) 659-5102 Harmony Radio: 2376 From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, April 27, 2020 11:37 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS FS2 DS Ops Lead <AKOPSFS2DSOpsLead@bp.com>; Alk, OPS FS2 Facility PTL <AKOPSFS2FacilityPTL@bp.com>; Ak, OPS FS2 Field PTL <AKOPSFS2 Field PTL@ bp.com>; AK, OPS FS2 OSM <AKOPSFS20SM1@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Alatalo, Travis <Travis.Alatalo@bp.com>; G GPB FS2 Drillsites <ggpbfs2drillsites@BP.com>; Rupert, C. Ryan <Ryan.Rupert@BP.com>; Richards, Meredyth <Meredyth. Richards@ bp.com>; 'chris.wallace@alaska.gov' <chris.waIlace @alaska.gov> Cc: AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dem pseyl@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis. Montgomery@ bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smithl@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; Lau, Jack <Jack.Lau@bp.com>; Mcmullen, John C <John.McMullen@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: UNDER EVALUATION: Injector 09-16 (PTD # 1770370) IA exceeded Normal Operating Limit All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015. On 04/26/20, the inner annulus (IA) pressure exceeded 1000 psi, the limit specified by AIO 4E.015. Maximum recorded IA pressure was 1083 psi. The well was shut in. Pressure trends indicate a failure of one or more well barriers. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan Forward: 1. Operations: leave well shut in. Per AIO 4E.015, the well must remain shut in until AOGCC grants approval to restart injection. 2. Downhole Diagnostics: MIT -IA, MIT -OA 3. Well Integrity: additional diagnostics as required. Please reply if in conflict. Adrienne McVey BP Alaska Well Integrity Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday, April 27, 2020 11:37 AM To: AK, OPS EOC Specialists; AK, OPS FS2 DS Ops Lead; Ak, OPS FS2 Facility PTL; Ak, OPS FS2 Field PTL; AK, OPS FS2 OSM; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Alatalo, Travis; G GPB FS2 Drillsites; Rupert, C. Ryan; Richards, Meredyth; Wallace, Chris D (CED) Cc: AK, GWO DHD Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Worthington, Aras J; Lau, Jack; Mcmullen, John C; Regg, James B (CED) Subject: UNDER EVALUATION: Injector 09-16 (PTD # 1770370) IA exceeded Normal Operating Limit All, Produced water injector 09-16 (PTD # 1770370) operates under Administrative Approval AIO 4E.015. On 04/26/20, the inner annulus (IA) pressure exceeded 1000 psi, the limit specified by AIO 4E.015. Maximum recorded IA pressure was 1083 psi. The well was shut in. Pressure trends indicate a failure of one or more well barriers. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan Forward: 1. Operations: leave well shut in. Per AIO 4E.015, the well must remain shut in until AOGCC grants approval to restart injection. 2. Downhole Diagnostics: MIT -IA, MIT -OA 3. Well Integrity: additional diagnostics as required. Please reply if in conflict. Adrienne McVey BP Alaska Well Integrity (Alternate: Ryan Holt) Office: (907) 659-5102 Harmony Radio: 2376 Well Name PRUDHOE BAY UNIT 09-16 API Well Number 50-029-20257-00-00 Inspector Name: Bob Noble • MEMORANDUM State of Alaska Rel Insp Num: Alaska Oil and Gas Conservation Commission Packer Depth Pretest Initial DATE: Wednesday, June 27, 2018 TO: Jim Regg j 1 P.I. Supervisor 1 6 ef�l/7 SUBJECT: Mechanical Integrity Tests 11(1 BP EXPLORATION (ALASKA) INC. 1045 - 09-16 FROM: Bob Noble PRUDHOE BAY UNIT 09-16 Petroleum Inspector PTD 1770370 Type TCst SPT Test psi 2030 Sre: Inspector 46 Reviewed By: 2475 P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-16 API Well Number 50-029-20257-00-00 Inspector Name: Bob Noble Permit Number: 177-037-0 Inspection Date: 6/26/2018 Insp Num: mitRCN180626153823 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-16 Type It W `TVD 8118 Tubing 1040 1045 - 1044 1042 PTD 1770370 Type TCst SPT Test psi 2030 IA 46 2500 - 2475 2466 , BBL Pumped: 5.2 BBL Returned: 5 OA 217 330, 344, 366 Interval REQVAR P/F P Notes: AIO 4E.015, MIT -IA every 2 years to max anticipated injection pressure, Max injection presssure is 1200 x 1.2 = 1440 psi. 2500 psi was used to tesf well— SMAN"M JUL 16 n18 Wednesday, June 27, 2018 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission olds,/ DATE: Thursday,May 19,2016 TO: Jim Regg P.I.Supervisor 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 09-16 FROM: Jeff Jones PRUDHOE BAY UNIT 09-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-16 API Well Number 50-029-20257-00-00 Inspector Name: Jeff Jones Permit Number: 177-037-0 Inspection Date: 5/12/2016 Insp Num: mitJJ160515154409 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-16 a,Type Inj W TVD 8118 - Tubing 1059 . 1063 - ' 1063 - 1060 1770370 SPT 2030 - 592 2502 - 2483 - 2478 PTD� Type Test Test psi� IA Interval REQVAR Phi P '✓ OA 612 L 728 - 758 775 - �;— - — _.--- -- --- --. i.. --- ---- Notes: 2 year MIT;A1O 4E.015 for IA x OA communication. scams) SEP 2 7 2416 Thursday,May 19,2016 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWeIlIntegrityCoordinator@bp.com> Sent: Tuesday, April 05, 2016 6:47 AM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Sternicki, Oliver R Subject: Injector 09-16 (PTD #1770370) Anomaly - Outer Annulus Repressurization Attachments: 09-16 AA 01-30-07 .pdf; 09-16 AA Change Anniversary Date 07-23-10.pdf;Injector 09-16 (PTD # 1770370) TIO and Injection Plot.docx Chris, Per our conversation yesterday, produced water injector 09-16 (PTD#1770370) operating under Administrative Approval Area Injection Order(AIO)4E.015 for slow inner by outer annulus communication, has begun to exhibit signs of outer annulus repressurization. The original AA dated January 30, 2007 specified that the well exhibited surface casing repressurization that was manageable by bleeds. The updated AA issued September 02, 2010, stipulates that BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity indicated by increased inner or outer annulus pressure (OA), increased repressure rate, or increased bleed frequency. The last time OA repressurization was noted in this well was in 2008. The well passed a non-witnessed MIT-IA to 2500 psi on March 30, 2016 indicating two competent barriers to formation. At this time, BP will pursue an OA bleed to ensure arctic pack is not the cause of surface casing repressurization, monitor the well for 3 to 5 days, and then reclassify the well Under Evaluation if the OA continues to repressure. Please advise if a different course of action should be taken. Plan Forward: 1. Downhole Diagnostics: Bleed OA 2. Downhole Diagnostics: Monitor OA build up rate for 3 to 5 days 3. Well Integrity Coordinator: Reclassify Under Evaluation if OA continues to repressure A copy of the TIO plot, original 2007 issued AA,and revised 2010 issued AA have been included for reference. MIT data can be provided upon request. 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: AKDCWeIlIntegrityCoordinator(cr�BP.com 1 • • Injector 09-16(PTD# 1770370) Current TIO Plot April 05, 2016 -.41— On Y Current Injection Rates am a ti toe are • xe 40. 'MR. 001. MON1 GnYK 01.1 @]YK mo'e e,"+i6 January 01, 2008—January 01, 2009 TIO Plot !m !-M • OY ?qt 0..x.91 N..iq (pQ191 OY�!n uzsq pqq u,q 06Gtq M.Tq ROYOt OG:p ],O1M 0.':e}q C�.9 H. ...f Yvx Nma x pvq ,a.v t.�]t0t ]342q �YKO il.Y2f by RECEIVED 0 AUG 21 2014 CC BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA LOG DATA) Date 21 -Aug -2014 Transmittal Number: 93373 If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents SWNEO 1 CD-ROM Containing OPEN HOLE Digital Log Data: 01-141, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-081 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-031 B-11, B-241 B-25, C-10, L2 -07A, 0-02, M-041 M-05, U-14 The information on this CD �. is to be used for BP Exploration (Alaska) Inc. business only. If you are not the owner or licensed user of this CD, any disclosure, copying or use of the information on this CD is prohibited. If you obtain this Angela K. CD by error, please return the CD to the address shown below. BP will pay the postage. Thank you. Please Sign and gancpdc@bp.com Doug Dortch Petrotechnical Attn: State of Alaska Attn: Makana Bender 333 W. 7th Ave, Suite 1 Anchorage, Alaska 99501 If found please return CD to: BP Exploration PO Box 196612 Anchorage, AK 99519-6612 CD1of1 by For External Distribution BPXA OH Log Data 01-14, 03-20, 04-03, 04-09, 04-10, 04-24, 06-03, 06-04, 06-04A, 09-01, 09-02, 09-03, 09-04, 09-05, 09-08, 09-09, 09-10, 09-11, 09-12, 09-13, 09-14, 09-15, 09-16, 09-17, 09-18, 09-19, 09-20, 14-26, 16-07, A-03, B-11, B-24, B-25, C-10, 1-2-07A, 1-3-02, M-04, M-05, U-14 18 -AUG -2014 i Petrotechnical Data end 1�R2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 177-077 183-101 171-005 176-030 176-042 185-301 175-073 175-062 200-102 175-076 176-016 176-035 176-040 176-047 176-070 176-076 176-082 176-084 177-007 177-008 177-025 177-036 177-037 177-038 177-039 177-040 177-041 181-110 185-204 171-038 178-069 182-140 182-151 179-035 204-053 186-154 171-023 176-110 193-100 STATE OF ALASKA AL N OIL AND GAS CONSERVATION COMMI iN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon 1 11 Repair Well Plug Perforations Perforate L Other Ld Brightwater 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 Developmert❑ Stratigraphic❑ Exploratory ❑ Service ❑✓ 177-037-0 3. Address: P.O. Box 196612 6. API Number: Anchorage, AK 99519-6612 50-029-20257-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028328 PBU 09-16 9 Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary Total Depth measured 12589 feet Plugs measured 12023 feet true vertical 9195.29 feet Junk measured None feet JUL 3 1 20". Effective Depth measured 12023 feet Packer measured See Attachment feet AOGCr true vertical 8799.15 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 20" 94# H-40 26-110 26-110 1530 520 Surface 2702 13-3/8" 72# MN -80 25-2727 25-2726.89 5380 2670 Intermediate None None None None None None Production 11346 9-5/8" 47# L-80 24-11370 24-8345.24 6870 4760 Liner 1518 7" 29# L-80 11070 - 12588 8148,49 - 9194.6 8160 7020 Perforation depth Measured depth See Attachment feet 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): 11810'-11986', 12005' Treatment descriptions including volumes used and final pressure: 1741 GALS EC9660A (SURFACTANT), 8396GALS EC9398A (POLYMER) 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 20818 0 1216 Subsequent to operation: 0 0 13624 0 890 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Explorato"Ll Development ❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil L Gas Li WDSP GSTOR ❑ WINJ ❑✓ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 17. 1 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 Nita Summerhays Email Nita.SummerhaVsP_bp.com Printed Name N' ha Title Petrotechnical Data Engineer ignatu 00 Phone 564-4035 Date 7/31/2014 `d. Form 10-404 Revised 10/2012 RBDMS AUG - 1 2G�� Submit Original Only Daily Report of Well Operations ADL0028328 rig a er rea men umpe po ymer an su ac an down TBG while well was on water injection 15,200 BWP 'Establishing rates with proving pots*** Pumped a total of xxxx gallons of EC9660A (Surfactant) Average of xxx gph for xx hrs. Pumped a total of xxxx gal, since start of project. Pumped a total of xxxx gallons of EC9398A (Polymer) Average of xxx gph for xx hrs. Pumped a total of xxxx gal, since start of project. 6/15/2014 **Continue on 6-16-14** Brightwater Treatment (RESERVOIR bWEEP MOD) Pumpedpolymer and surfactanF down TBG while well was on water injection 15,200 BWP ***Establishing rates with proving pots*** Pumped a total of xxxx gallons of EC9660A (Surfactant) Average of xxx gph for xx hrs. Pumped a total of xxxx gal, since start of project. Pumped a total of xxxx gallons of EC9398A (Polymer) Average of xxx gph for xx hrs. Pumped a total of xxxx gal, since start of project. 6/16/2014 **Continue on 6-17-14** Brightwater Treatment (RESERVOIR SWEEP MOD) Pumpedpolymer and surfactanT down TBG while well was on water injection 15,200 BWP ***Establishing rates with proving pots*** Pumped a total of 882 gallons of EC9660A (Surfactant) Average of 98 gph for 9 hrs. Pumped a total of 882 gal, since start of project. Pumped a total of 4392 gallons of EC9398A (Polymer) Average of 488 gph for 9 hrs. Pumped a total of 4392 gal, since start of project. 6/17/2014 **Continue on 6-18-14** Brightwater Treatment (REbERVOIR SWEEP MOD) Pumpedpolymer and surfactant down TBG while well was on water injection 15,200 BWP ***Establishing rates with proving pots*** Pumped a total of 2352 gallons of EC9660A (Surfactant) Average of 98 gph for 24 hrs. Pumped a total of 3234 gal, since start of project. Pumped a total of 11712 gallons of EC9398A (Polymer) Average of 488 gph for 24 hrs. Pumped a total of 16104 gal, since start of project. 6/18/2014 **Continue on 6-19-14** Brightwater Treatment (RESERVOIR SWEEP MOD) Pumpedpolymer and surtactanF down TBG while well was on water injection 15,200 BWP ***Establishing rates with proving pots*** Pumped a total of 1741 gallons of EC9660A (Surfactant) Average of 98 gph for 17.72 hrs. Pumped a total of 4975 gallons for project. Pumped a total of 8396 gallons of EC9398A (Polymer) Average of 488 gph for 17.12 6/19/2014 hrs. Pumped a total of 24500 gallons since start of project. FLUIDS PUMPED 3DIESEL 3 METH 6 TOTAL FLUIDS PUMPED GALS Daily Report of Well Operations ADL0028328 1741 EC9660A (SURFACTANT) 8396 EC9398A (POLYMER) 10137 TOTAL AB ABANDONED MIR Perforation Attachment APF ADD PERF MIS MECHANICAL ISOLATED BPP ADL0028328 MILK MECHANICAL LEAK BPS SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base 09-16 9/4/1989 RPF 11810 11860 8649.33 8684.62 09-16 6/20/1995 RPF 11860 11870 8684.62 8691.67 09-16 6/20/1995 RPF 11870 11880 8691.67 8698.72 09-16 6/20/1995 RPF 11880 11910 8698.72 8719.84 09-16 4/15/1989 STC 11942 11946 8742.33 8745.14 09-16 4/15/1989 STC 11946 11962 8745.14 8756.37 09-16 4/15/1989 STC 11962 11986 8756.37 8773.2 09-16 4/15/1989 STC 11986 11990 8773.2 8776 09-16 4/15/1989 STC 11990 12005 8776 8786.52 09-16 4/15/1989 STC 12005 12010 8786.52 8790.03 09-16 1/12/1995 BPS 12028 12040 8802.67 8811.1 09-16 1/12/1995 BPS 12040 12076 8811.1 8836.41 09-16 1/12/1995 BPS 12076 12080 8836.41 8839.23 09-16 1/12/1995 BPS 12080 12090 8839.23 8846.27 09-16 1/12/1995 BPS 12090 12094 8846.27 8849.08 09-16 1/12/1995 BPS 12094 12100 8849.08 8853.31 09-16 1/12/1995 BPS 12100 12105 8853.31 8856.83 09-16 1/12/1995 BPS 12140 12186 8881.47 8913.85 09-16 1/12/1995 BPS 12220 12248 8937.76 8957.42 09-16 1/12/1995 BPS 12298 12333 8992.44 9016.86 09-16 1/12/1995 BPS 12350 12370 9028.69 9042.59 09-16 1/12/1995 BPS 12375 12395 9046.07 9059.98 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MILK 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 Casing / Tubing Attachment ADL0028328 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 20" 94# H-40 26 - 110 26 - 110 1530 520 LINER 1518 7" 29# L-80 11070 - 12588 8148.49 - 9194.6 8160 7020 NIPPLE 6 5-1/2" XN Nipple 11017 - 11023 8114.97 - 8118.75 NIPPLE 5 4-1/2" Camco DB Nipple 11135 - 11140 8190.11 - 8193.33 NIPPLE 4 3-1/2" D Nipple 12023 - 12027 8799.15 - 8801.96 NIPPLE 4 3-1/2" D Nipple 12270 - 12274 8972.84 - 8975.64 PRODUCTION 11346 9-5/8" 47# L-80 24 - 11370 24 - 8345.24 6870 4760 SURFACE 2702 13-3/8" 72# MN -80 25 - 2727 25 - 2726.89 5380 2670 TUBING 10980 7" 26# L-80 26 - 11006 26 - 8108.07 7240 5410 TUBING 14 5-1/2" 17# L-80 11007 - 11021 8108.69 1 - 18117.49 7740 6280 TUBING 99 4-1/2" 12.6# N-80 11048 - r 11147 8134.53 1 - 1 8197.85 8430 7500 Packers and SSV's Attachment ADL0028328 SW Name Type MD TVD Depscription 09-16 PACKER 11010 8056.58 2-7/8" HES RCP Packer 09-16 PACKER 11022 8064.12 4-1/2" Baker DB Packer 09-16 PACKER 11027 8067.27 2-7/8" HES RCP Packer 09-16 PACKER 11917 8670.76 3-1/2" Baker FB -1 Packer 09-16 PACKER 12016 8740.24 3-1/2" Baker FB -1 Packer 09-16 PACKER 12111 8807.05 3-1/2" Baker FB -1 Packer 09-16 PACKER 12261 8912.53 3-1/2" Baker FB -1 Packer TREE= 6" McEVOY WELLHEAD = ACTUATOR = FMC AXELSON KS REV= 54 0' BF REV= NA KOP = 3140' Max Angle = 61 ° @ 6633" Datum NO = 12101' Datum TVD = 8800' SS 113-3/8" CSG, 72# L-80, ID = 12 347' ft_V27" 7' TBG -PC 26# L-80. 0383 bpf ID = 6 276 11006' 2-7/8" TBG, 6 5# N•80. 0058 bpf ID = 2.441" —t ? 5-1/2" TBG, 17#, L-80; 0232 bpf ID = 4 892" 11020' 41/2" BKR LOC SEAL ASSY 1102V (BTM OF HES RCP TBG PATCH (05/08100) 11032' Minimum ID = 2.260" @ 11031' 2-7/8" HES XN NIPPLE IN TBG PATCH 9 -SIS' X T' BOT LNR HGR 11070- 4-1 t2" 1070' 4-112" TBG, 12 6#, N-80, 0152 bpf ID = 3 958" 11147' 9-5/8" CSG, 47# L-80. ID = 8681" 11370' 7" X 3-1/2" BKR FB -1 PKR, ID = 4 000" 11917' 3-12" BKR MILLOUT EXT , ID = 4 500 11921' 5" X 3-12" XO. ID = 2.992" 11927' 312" BKR LOC. SEAL ASSY, ID E-4 000" —12015- 17" X 3-12" BKR FB -1 PKR, ID = 4 000" — 12016' 312" BKR SEAL BORE EXT, ID = 4 000" 12019' 312" CAMCO DS NIP. ID = 2 875" (-1 12023' 3-12" WLEG ID = 2 992" 12026' ELMD TT LOGGED 08115/94 12026' OSA-. NOTES: 1-12S READINGS AVERAGE 125 -16 ppm WHEN ON MI. 4-1/2" DB NIPPLE@ 11135' NOT USABLE 9 D255173' —j7" CAMCO SSSVN, ID = 5-937" 412' 9-5/8" FOC 28 9-518" FOC 11007' -7' X 5-1/2" XO, ID = 4 892" 11010' 5-1/2" X 2-718" HES RCP PKR. 10 = 2390" 11017' S-1 /2" OTIS XN NIP, ID = 4 455" (BHIND PATCH) 110 5-1/2" X 4-112" XO. ID = 3 875" 11022' 9-5/8" X 4-112" BKR DB PKR, 11031' 2-7/8" HES XN NIP. ID = 2 25" (IN PATCH) 11041' 7" MILLOUT EXT , ID = 6 00T 11048' 7" X 4-1/2- XO, ID = 3 992" 11� 135' J-4112" CAMCO DB NIP, ID = 3 812" 11148' 4-112" WLEG, ID = 4.000" 11149' ELIVO TT LOGGED 09/05/99 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 11935 8737 45 CA-MMG-2 DMY TG 0 01/12/95 2 11975 8765 46 CA-MMG-2 DMY TG 0 02/07/93 3 12150 8889 45 CA-MMG DMY RK 0 12/29/91 4 12220 8938 45 CA-MMG DMY RKP 0 12/29/91 12023' ISA -2 BLANKING PLUG 01/12/95 12111' -7" X 3-1/2" BKR FB -1 PKR, ID = 4 000" 3-1/2" BKR MILLOUT EXT. ID = 4 500" REF LOG BHCS ON 0928/17 REV BY COMMENTS 12260' 312" BKR LOC SEAL ASSY, ]D= 3.OW' ANGLE AT TOP PERF 45'@11810' 10/07177 ORIGINAL COMPLETION Note Refer to Production DB for historical perf data BHC/TP PERF CORRECTIONS 12261' 7" X 3-1/2" BKR FB -1 PKR, ID = 4.000'" 12264' 3-1/2" BKR MILLOUT EXT, ID = 4 500" 31ZE SPF I INTERVAL I Opn/Sqz I DATE 05/11/08 PJP/TLH PERF & GLV CORRECTIONS 04/22/89 12270' 3-1/2" CA MCO DS NIP ID = 2.812" See Page 2 for Perforations RLM/PJC SSSV CORRECTION (07/13/09) 0923/01 RN/KAK CORRECTIONS 01/11112 12272' 3-1 /2" WL EG, ID = 2 992" 12276' ELMD TT LOGGED 10/21/94 04/07/02 1 PBTD 12546' 7" LNR, 29#, L-80, 0371 bpf. ID = 6 184" 12588' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/07177 ORIGINAL COMPLETION 09/02/02 BHC/TP PERF CORRECTIONS 05/10/85 RWO 05/11/08 PJP/TLH PERF & GLV CORRECTIONS 04/22/89 LAST RWO 0726/09 RLM/PJC SSSV CORRECTION (07/13/09) 0923/01 RN/KAK CORRECTIONS 01/11112 TMWJMD ADDED H2S SAFETY NOTE 04/07/02 1 CH TP ICORRECTIONS 0427102 I JKB/TLH 1CORRECTIONS PER APE PRUDHOE BAY UNIT WELL 09-16 PERMIT No '1770370 API No 50-029-20257-00 SEC 11 T10N. R15E877' FSL & 175'-W!- BP 75'FWL BP Exploration (Alaska) I TREE= 6" McEVOY 09-16 WELLHEAD = FMC ACTUATOR = AXELSON KB ELEV = 54.0' BF. ELEV = NA K6 -P- = 3140' ._ Max Angle = 61' -@6633- 6633"Datum Datum MD = 12101' Mum TVD = 8800' SS PERFORATION SUMMARY REF LOG BHCS ON 09/28177 ANGLE AT TOP PERF 45'@11810' Note Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz RATE 3-1/8" 4 11810- 11860 O 09/04/89 3-3/8" 4 11860 - 11880 0 0620/95 3-3/8" 4 11880 - 11910 O 06/20/95 3-1/8" 4 11942 - 11946 0 04/15/89 3-1/8" 4 11946 - 11986 0 04/15/89 3-118" 4 11986. 11990 S 04/08/89 3-1/8" 4 11990 - 12010 S 04/08/89 3.1/8" 1 12005 O 04/15/89 4 12028 - 12040 S 04/08/89 4 12040- 12076 C 04/19/91 4 12076 - 12100 C 04/19/91 3-1/8" 4 12100- 12105 S 04/08/89 3-1/8" 4 12140 - 12186 S 04/08/89 3-1/8" 4 12220- 12248 S 04/08/89 3-1/8" 4 12298 - 12333 C 04/15/89 3-1/8" 4 12350 - 12370 C 04/15/89 3-1/8" 4 12375 - 12395 C 04/15/89 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/07177 ORIGINAL COMPLETION 09/02/02 BHC/TP PERF CORRECTIONS 05/10185 RWO 05/11/08 PJPITLH PERF 8 GLV CORRECTIONS 04122/89 LAST RWO 07/26/09 RLWPJC SSSV CORRECTION (07/13109) 0923/01 RN/KAK CORRECTIONS 01/11/12 TMN/JMD ADDED H2S SAFETY NOTE 04/07/02I CH/TP CORRECTIONS 0427/02 JKB/TLH I CORRECTIONS PER APE PRUDHOE BAY UNIT WELL 09-16 PERMIT No '1770370 API No 50-029-20257-00 SEC 1 T10N, R15E 877' FSL 8 175' FWL BP Exploration (Alaska) MEMORANDUM State of Alaska Permit Number: 177-037-0 Alaska Oil and Gas Conservation Commission O: Jim Regg DATE: Tuesday, June 24, 2014 P.I. Supervisor K�1' 6117/1 IN SUBJECT: Mechanical Integrity Tests !( BP EXPLORATION (ALASKA) INC Well -F- 09-16 Type Inj W TVD 8118 IA 320 2517 09-16 FROM: Chuck Scheve PRUDHOE BAY UNIT 09-16 Petroleum Inspector SPT Test psi Src: Inspector OA Reviewed By: 395 P.1. Suprv, - NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-I6 API Well Number 50-029-20257-00-00 Inspector Name: Chuck Scheve Permit Number: 177-037-0 Inspection Date: 4/27/2014 Ittsp Num: mitCS140428061733 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well -F- 09-16 Type Inj W TVD 8118 IA 320 2517 2500 ' 2498 TD 1770370 Type Test SPT Test psi 2030 OA 253 395 398 442 IntervalTREQvAR PAF P Tubing 962 • 962 963 964 ' Notes: Two year test required by variance for slow IA x OA comunication Tuesday, June 24, 2014 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,June 11,2012 Jim Regg , P.I. 7 �" Supervisor r (Ii( v SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 09-16 FROM: Bob Noble PRUDHOE BAY UNIT 09-16 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 09-16 API Well Number 50-029-20257-00-00 Inspector Name: Bob Noble Permit Number: 177-037-0 Inspection Date: 5/20/2012 Insp Num: mitRCNI20521183616 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 09-16 - Type Inj W TVD 8118 IA 300 - 2500 , 2481 2479 • PTD 1770370 Type Test SPT Test psi 2273 OA 74 . 101 105 112 Interval lIQ"AR P/F j P ' Tubing 850 - 850 849 834 Notes: IA x OA Ayo 21t,-Os5 SCANNED MAR 1 3 2014 Monday,June 11,2012 Page 1 of 1 • • ~~GJ~C~ 0~ Q~Q~~{Q /~.M.~..w~~ ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 4E.015 (Revised-Corrected) Steve Rossberg Wells Manager - BP Exploration (Alaska) Inc. `'~ P.O. Box 196612 , ``~~- _ -` Anchorage, AK 99519-6612 RE: Prudhoe Bay Unit DS 09-16 (PTO 17.70370) Request for Administrative Approval Prudhoe Bay Oil Pool Dear Mr. Rossberg: This document corrects Administrative Approval 4E.015 Revised that was issued July 23, 2010. Several changes were made to the operating rules when all that was requested was a revision of the MIT anniversary date. This document restates the rules as contained in the Administrative Approval issued November 28, 2007 and revises the MIT anniversary date as requested. BP Exploration (Alaska) Inc. (BPXA) requests a permanent revision to the anniversary date for mechanical integrity tests (MIT) for Prudhoe Bay Unit (PBU) 09-16. Area Injection Order 4E.015 granted BPXA's request for administrative approval to continue water injection in the subject well. The Alaska Oil and Gas Conservation Commission (AOGCC or Commission) now approves BPXA's request to change the anniversary date for MIT's. PBU 09-16 exhibits surface casing repressurization. When AIO 4E.015 was originally issued, the MIT anniversary date was established as January 13, 2007 with a test interval not to exceed 2 years. Performing MITs during the summer realizes efficiencies for both BPXA and the Commission. AOGCC finds that BPXA has successfully performed MITs on June 2, 2008 and June 1, 2010 demonstrating that the well's condition has not changed since AIO 4E.015 was issued. The Commission further finds that neither the well's condition nor changing the MIT due date will compromise overall well integrity so as to threaten the environment or human safety, if the well's operation is subject to the constraints previously established and enumerated below. AOGCC's administrative approval to continue water injection in PBU 09-16 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates, and shall flag the well's periodic pressure bleeds on the report; AIO 4E.015 (Revised-Corrected • September 2, 2010 Page 2 of 2 BPXA shall perform an MIT-IA every 2 years to 1.2 times the maximum anticipated injection pressure; 4. BPXA shall limit the IA pressures to 1,000 psi; 5. BPXA shall immediately notify the AOGCC and shut in the well if there is any continued deterioration in well integrity, indicated by increased inner or outer annulus pressure, increased repressure rate, or increased bleed frequency; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is revised to June 1; the next MIT is due on or before June 1, 2012. DONE at Anchorage, Alaska and dated September 2, 201 C Daniel T. Seamount, Jr. Chair, Commissioner cc: Torin Roschinger/GeI•ald Murphy BPXA Well Integrity Coordinator, PRB-20 P.O. Box 196612 Anchorage, AK 99519-6612 RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. [f the Commission denies reconsideration, upon denial, this order or decision and the denial of re- consideration aze FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Com- mission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by in- action, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on re- consideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on re- consideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the pe- riod; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. rage i of i Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, September 01, 2010 2:30 PM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: DS 09-16 (177-037) AA 4E.015 (revised) ~~ Gerry, Thanks for the call. I will have a corrected revision issued for this well removing the 2500 psi limit and the pilot requirement. I think the original action in 2007 was prior to setting up the pilots, however I think we've required them on the OA not the IA. They all run together after a while. Tom Maunder, PE AOGCC From: AK, D&C Well Integrity Coordinator [mailto:AKDCWeIIIntegrityCoordinator@bp.com] Sent: Tuesday, August 31, 2010 9:44 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 09-16 (177-037) AA 4E.015 (revised) Tom, I'm at a loss also, as I do not see any requests other than Torin's MIT anniversary date change request since the denial in 2007. I will give you a call in the morning so we can discuss. Jerry Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, August 31, 2010 4:24 PM To: AK, D&C Well Integrity Coordinator Subject: DS 09-16 (177-037) AA 4E.015 (revised) Torin or Gerry, In the course of working on some AAs, I examined the revision for 09-16 which was issued on July 23. Torin sent in an email request to modify the MIT anniversary date which was accomplished, however it appears an additional rules increasing the IA pressure limit to 2500 psi and including a IA pilot were also included. There was an earlier request to increase the IA pressure that was denied. Will you guys look at your information on this well and we can discuss? I am at a loss as to how the rules got changed. Thanks in advance, Tom Maunder, PE AOGCC 9/1/2010 AOGCC MITIA Forms for 03-3660600), 03-12 (1790580), 03-37 (20990), 04-10 (... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, July 01, 2010 5:06 PM To: AK, D&C Well Integrity Coordinator Cc: Regg, James B (DOA); Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); AK, D&C Well Integrity Coordinator Subject: AOGCC MITIA Forms for 03-36 (1760600), 03-12 (1790580), 03-37 (2091390), 04-10 (1760420), 04-43 (1940130),04-44 (1940100),09-16 (1770370),09-19 (1770400), 09-31C (1960640), 09-36C (1951140), 09-37 (1940280) Attachments: June 2010 MIT Forms GPB part 1.zip Jim, Tom and Phoebe, Please find the attached AOGCC MITIA forms for the following wells: 03-06 (PTD #1760600) 03-12 (PTD #1790580) -enclosed are 2 tests; original test from 6/12 /2010 and retest on 6/29/2010. 03-37 (PTD #2091390) 04-10 (PTD #1760420) 04-43 (PTD #1940130) 04-44 PTD #1940100 09-16 PTD #1770370) 09-19 (PTD #1770400) 09-31 C (PTD #1960640) 09-36C (PTD #1951140) 09-37 (PTD #1940280) «June 2010 MIT Forms GPB part 1.zip» Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 ~ r, '~ (~ ;~. '~+ 7/2/2010 • OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay /PBU / DS 9 06/01 /10 Jerry Murphy Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Well 09-16 Type Inj. W TVD 8,118' Tubing 690 690 690 690 Interval V P.T.D. 1770370 Type test P Test psi 2029.5 Casing 270 2,500 2,490 2,490 P/F P Notes: MIT-IA to 2500 psi for AA compliance OA 270 380 380 380 Pumped 3.8 bbls MEOH Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P~F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test ~~~ INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU 09-16 06-01-10.x1s MEMORANDUM To: Jim Regg E4 Z ia~~lo P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, June 03, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-16 PRUDHOE BAY UNIT 09-16 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv--~ Comm Well Name: PRUDHOE BAY UNIT 09-16 API Well Number: 50-029-20257-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS100602072810 Permit Number: 177-037-0 Inspection Date: 6/]/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P.T.D _ 09-16 / yp ~ ~ e In . ~' _1~7o37o~TypeTest~sPT ~L- 8118 '~ TVD Tes p ---zoz9 -- IA ~ 270 i 2 OA ~ z7o ~ 500 / 3so 2490 sso 2490 ~ 3so ~ Interval REQvAR p/F P ~ Tubing 690 690 690 690 Notes: r~ Thursday, June 03, 2010 Page 1 of I To: ACC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastuflca LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey f ~b - U~S~ L ~9 °~~ 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-6952 1) Leak Detection -WLD 02-May-09 M-08 Color Log / EDE 50-029-20499-00 2) ~ Leak Detection -WLD 30-Apr09 09-16 Signed Print Name: Color Log / EDE '° _ 54 ------.- Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 EMAIL _ _ ._...:. - - .. wEBSITE: ~ C:\Docmnents and Settings\Oamer\Desktop\Transmit_BP.docx ~~~~~~ "~ STATE OF ALASKA JD~a-Op ALA OIL AND GAS CONSERVATION COM~I~I~dT ~ ~ ZOOS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ ~ ~$f~i -ITWATER Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ ~'Ti S~te;~Xferion ~ TREATMENT Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 177-0370 - 3. Address: P.O. Box 196612 Stratigraphic 6', Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20257-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 54 KB ~ PBU 09-16 ' 8. Property Designation: 10. Field/Pool(s): ADLO-028328 ~ PRUDHOE BAY Field/ PRUDHOE BAY OIL Pool 11. Present Well Condition Summary: Total Depth measured 12589 - feet Plugs (measured) 12023' 1/12/95 Junk (measured) None true vertical 9195.29 ~ feet ~-, p~~g~44 ~~°}} hh'~ Effective Depth measured 12023 feet ~~>811l~1~s ivQ,~ k L~ 2~~8 true vertical 8580 feet Casing Length Size MD TVD Burst Collapse Conductor 100' 20" Surface - 128' Surface - 128' 1530 470 Surface 2699' 13-3/8" 72# L-80 Surface - 2727' Surface - 2727' 4930 2670 Intermediate 11342' 9-5/8" 47# L-80 Surface - 11370' Surface - 8345' 6870 4760 Liner 1518' 7" 29# L-80 11070' - 12588' 8151' - 9195' 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: Tubing: (size, grade, and measured depth) 7" 26# L-80 SURFACE - 11006 5-1/2" 17# L-80 11007 - 11021 4-1/2" 12.6# N-80 11048 - 11147 Packers and SSSV (type and measured depth) (4) 3-1/2" BKR FB-1 PKR 11917 12016 12111 12261 4-1/2" BKR DB PKR 11022' 12. Stimulation or cement squeeze summary: po~C. r Intervals treated (measured): ~~ Q\~¢cP ~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 12878 180 1032 Subsequent to operation: 10121 100 960 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development C"~ Service ' - Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas l WAG ~' GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature ,~~'~ Phone 564-4944 Date 10/14/2008 Form 10-404 Revised 04/2006 " "~~ Submit Original Only /:a "~ -~, 09-16 177-0370 PERF ATTACHMENT O eration Date Perf Operation Code Meas Depth To Meas De th Base Tvd De th Top Tvd Depth Base 11/19/77 PER 12,140. 12,186. 8,881.47 8,913.85 11/19/77 PER 12,220. 12,248. 8,937.76 8,957.42 11!19/77 PER 12,298. 12,333. 8,992.44 9,016.86 2/20/84 APF 12,350. 12,370. 9,028.69 9,042.59 2/20/84 APF 12,375. 12,395. 9,046.07 9,059.98 _ 9/9/84 APF 11,810. 11,860. 8,649.33 8,684.62 9/9/84 APF 11,880. ~ 11,910. 8,698.72 8,719.84 9/9/84 APF 11,942. 11,962. 8,742.33 8,756.37 9/9/84 APF 11,990. 12,010. 8,776. 8,790.03 4/29/85 APF 11,860. 11,880. 8,684.62 8,698.72 4/29/85 APF 11,962. 11,990. 8,756.37 8,776. 4/29/85 RPF 11,810. 11,860. 8,649.33 8,684.62 4/29/85 RPF 11,880. 11,910. 8,698.72 8,719.84 4/29/85 RPF 11,946. 11,962. 8,745.14 8,756.37 4/29/85 RPF 11,990. 12,010. 8,776. 8,790.03 10/15/86 APF 12,028. 12,076. 8,802.67 8,836.41 10/15/86 APF 12,094. 12,105. 8,849.08 8,856.83 4/8/89 SOZ 11,810. 12,395. 8,649.33 9,059.98 4/8/89 STC 11,942. 11,946. 8,742.33 8,745.14 4/8/89 STC 11,946. 11,962. 8,745.14 8,756.37 4/8/89 STC 11,962. 11,986. 8,756.37 8,773.2 4/8/89 STC 11,986. 11,990. 8,773.2 8,776. 4/8/89 STC 11,990. 12,010. 8,776. 8,790.03 4/15/89 RPF 11,942. 11,986. 8,742.33 8,773.2 4/15/89 RPF 12,005. 12,010. 8,786.52 8,790.03 4/15/89 RPF 12,298. 12,333. 8,992.44 9,016.86 4/15/89 RPF 12,350. 12,370. 9,028.69 9,042.59 4/15/89 RPF 12,375. 12,395. 9,046.07 9,059.98 4/15/89 STC 11,917. 12,016. 8,724.76 8,794.24 9/4/89 RPF 11,810. 11,880. 8,649.33 8,698.72 9/4/89 RPF 11,880. 11,910. 8,698.72 8,719.84 6/23/90 APF 12,076. 12,080. 8,836.41 8,839.23 6/23/90' APF 12,090. 12,094. 8,846.27 8,849.08 6/23/90 RPF 12,094. 12,100. 8,849.08 8,853.31 4/19/91 APF 12,080. 12,090. 8,839.23 8,846.27 4/19/91 RPF 12,040. 12,080. 8,811.1 8,839.23 4/19/91 RPF 12,090. 12,100. 8,846.27 8,853.31 1/12/95 BPS 12,023. 12,025. 8,799.15 8,800.56 6/20/95 RPF 11,870. 11,910. 8,691.67 8,719.84 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 SOF SQUEEZE FAILED MIR MECHANICAL ISOLAT ED REMOVED SOZ SQUEEZE MIS MECHANICAL ISOLAT ED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 09-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 9/16/2008 We started pumping Bright Water chemical into well at 8 PM at a rate of ', (EC9360A) Surfactant at 131 GPH with a daily total of 1370 gallon and a job !total of 1370 gallons and the (EC9378A) polymer at a rate of 263 GPH with a daily total of 3064 gallons and a job total of 3064 gallons. Well pressure is :around 1000 psi and a water rate of 9800 BPD. 9/17/2008 Continue to pump Bright Water (EC9360A) Surfactant at a rate of 131 GPH with a daily total of 2886 Gallons and a job total of 4256 Gallons and (EC9378A) Polymer at a rate of 263 GPH with a daily rate of 5833 Gallons and a job total of 8897 Gallons. Well pressure fluctuated some through the night while we tried to ramp down the EC9360A, and water rate dropped down from 10000 BPD to 7200 BPD and we had to shut down pumping the EC9378A until the water rate recovered back to the 10000 BPD area and bring the Polymer back on line. 9/18/2008: Continue to pump Bright Water (EC9360A) Surfactant at a rate 131 GPH :ramping down to 74 GPH with a daily total of 1755 Gallons and a job total of :6011 gallons and (EC9378A) Polymer at a rate of 263 GPH with a daily total of :6704 Gallons and a job total of 15601 gallons. The well pressure is around 1050 :psi and the water rate is between 9700 to 10000 BPD. 9/19/2008continue to pump Bright watr (EC9360A) Surfactant at a rate of 66 GPH with a :daily total of 271 Gallons and a job total of 7829 Gallons, ans (EC9378A) ;polymer at a rate of 263 G PH with a daily rate of 439 Gallons and a job total of 22558 Gallons. well pressure is at 1000 psi and the water rate at 9500 BPD. :Job Completed at 9 am 9-19-08 ~__z _ _. ~ _. .._ ~ _ .... ..~~... ~ __ 9/19/2008Continue to pump Bright Water (E~C9360A) Surfactant at a rate of 66 GPH with a 'daily total of 1547 Gallons and a job total of 7558 gallons. (EC9378A) Polymer at a rate of 263 GPH with a daily total of 6518 gallons and a job total of 22119 ';gallons. the well pressure is 1000 psi and the water rate is between 9350 and 10050 BPD as of Gam on 9-19-08. FLUIDS PUMPED GALS 7558 SURFACANT 22119 POLYMER 29677 Total r MEliR®RANDUM To: Jim Regg '~ // P.I. Supervisor ) ~ ~~'~ bC l ~ 1t9~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Monday, June 02, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 09- 16 PRUDHOE BAY UNIT 09-16 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv __r~ Comm Well Name: PRUDHOE BAY UNIT 09-16 API Well Number: 50-029-20257-00-0o Inspector Name: Jeff Jones Insp Num: mitJJ080531 101421 Permit Number: 177-037-0 - Inspection Date: 5/30/2008 Rel Insp Num: Packers Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 0916 Typ J• ~/ TVD 8118 i IA 360 4000 i 3980 3960 3960 ~ - --- _ -- ---- a In _ Test si I zoz9 _ p~ a7o ~ no szo s4o -- s7o P.T. ype est I----- --- rnooTi-rER _ . __P/FsPT'__ - P -p JL--- Tubing __ I vo ~ I no - ~ -~ no~ - n ~o _ -i 1.70 Interval __~__-_ __ -_ BPXA re resentative J. Morales states the purpose of this MIT is to seek AOGCC permission to return this well to MI injectioi. Although the Notes: P IA passes the AOGCC criteria for a successful MIT, test data indicates the previously known IA x OA communication still ex s s Mr. Morales indicated that no well work has been done to repair the leaking IA (AIO 4E.015 1!30/07). 7.2 BBLS methanol pumped. t well house inspected; no exceptions noted. ~~~ ~uL ~ za~~ Monday, June 02, 2008 Page I of 1 ~LASBiA O1t14 .~-11TD GAs co~sExv~~oK cor~ssio~ .~~ SARAH FAUN, GOI/ERNOR r ~ 333 W. 7th AVENUE. SUITE 100 ~~ ANCHORAGE. ALASKA 9950-3539 PHONE {907) 279-1433 ~~ FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 4E.015 Mr. Steve Rossberg ~ Wells Manager BP Exploration (Alaska) Inc. _ P.O. Box 196612 ` Anchorage, AK 99519-6612 q _~ , ~, k ~, RE: PBU 09-16 (PTD 1770370) , Request for Revision of Administrative Approval Dear Mr. Rossberg: Administrative approval AIO 4E.015 was granted to BP Exploration (Alaska) Inc. ("BPXA"}'s for the continued injection of water in Prudhoe Bay Unit {"PBU") 09-16 subject to certain conditions. By letter dated October 30, 2007 (received November 20, 2007) BPXA requested a revision to the maximum allowable surface pressure on the inner annulus. The Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") DENIES BPXA's request for revision. PBU 09-16 exhibits outer annulus re-pressurization following pressure bleeds. The pressure source is unknown. BPXA provides no new information in support of reconsidering the maximum allowable inner annulus pressure except the statement that 2000 psi is "the standard for operable wells". The Commission has not established standard pressure limits for annuli pressures in injection wells. It appears BPXA is incorrectly seeking similar regulatory triggers as defined in Conservation Order 492 which covers allowable annuli pressures in development {production) wells only. Further, the information provided with the original application for administrative approval and the current request for reconsideration indicate BPXA has no problem maintaining annuli pressures under the maximum allowable surface pressure "with infrequent bleeds." AOGCC's administrative approval to inject water only in PBU 09-16 remains as issued on January 30, 2007 with the following conditions: i. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform aMIT - IA every 2 years to I.2 times the maximum anticipated well AIO 4E.015 Revision Denied November 28, 2007 Page 2 of 2 pressure; 4. BPXA shall limit the well's IA pressure to 1000 psi; 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. after well shut in due to a change in the well's mechanical condition, AQGCC approval shall be required to restart injection; and 7. The MIT anniversary date is January 13, 2007. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless reconsideration has been requested. Alaska and dated November 28, 2007. Biel T. Seamount, Jr Commissioner ,• ,- r Cathy . Foerster Com issioner MEMORANDUM To: Jim Regg /~ P.I. Supervisor ~ ~~~' ~L~`"I ~,,? ~ FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Wednesday, October 03, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 09-16 PRUDHOE BAY UNIT 09-16 Src: Inspector Nl11\ _!` (1NFTilF.NTT A T , Reviewed By: P.I. Suprv:y= Comm Well Name: PRUDHOE BAY UNIT 09-16 API Well Number: 50-029-2o2s7-oo-0o Inspector Name: chuck scheve Insp Num: mitC5071003063414 Permit Number: 177-037-o Inspection Date: toiz,2oo7 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 09-I6 Type Inj. ~, W ~ TVD g>>8 -~ IA sso 2soo -~ 24so ~ 2a~o P T ~ 177037 Y eTest ~ SPT ~ TeSt pSl 2029 5 ~ ~A~ 260 400 ~ 440 ~ 470 ~ Interval oT~R P/F P ~ Tubing ~ Iaoo ~aoo ~, , taoo Iaoo NOtes• Test performed for AA revision. ~~3'n~® IYU Y g. ~ ~~U~ Wednesday, October 03, 2007 Page 1 of 1 • r °~ COIITSER`Q DSO O1~IIIIS5IG0~11T • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL AIO 4E.015 Mr. Steve Rossberg, Wells Manager BP Exploration (Alaska) Inc. ~~~~ JINN ~ ~ 20~~ 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99519-6612 RE: PBU 09-16 (PTD 1770370) Request for Administrative Approval Deaz Mr. Rossberg: In accordance with Rule 9 of Area Injection Order 04E.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to inject water in the subject well. The Commission hereby denies BPXA's request for administrative approval to inject gas in the subject well. PBU 09-16 exhibits surface casing repressurization. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 09-16 and is able to manage the surface casing pressure with pressure bleeds. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures, PBU 09-16 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that well operation in water injection service will not threaten the environment or human safety. However, the Commission believes that PBU 09-16's condition does not conform to the relatively more stringent standards of well integrity necessary to ensure safe gas injection. AOGCC's administrative approval to inject water only in PBU 09-16 is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injection rates; 3. BPXA shall perform aMIT-IA every 2 years to 1.2 times the maximum anticipated well pressure; • AIO 4E.015 January 30, 2007 Page 2 of 2 4. BPXA shall limit the well's IA pressure to 1000 psi; • 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. after well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 7. The MIT anniversary date is January 13, 2007. Please note that PBU 09-16's status is changed from WAGIN to 1 WINJ. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day fallsy~ a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. sated January 30, 2007. Cathy P. Foerster Co ssioner ( t STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / Drill Site 09 12/21/03 Anna Dube Witnessing declined by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well 09-16 Typelni. F TVD 8,118' Tubing 1,700 1,700 1,700 1,700 Interval 4 P.T.D. 1770370 Type test P Test psi 2,030 Casing 400 2,500 2,480 2,470 P/F P Notes: Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover a = Other (describe in notes) ~.'.". (('C (,~ ri\\filli\,gU;:\i.'\,.: 0: !r: r. ~ 1 2. OO'~~ c.')~:::JIð"ïln~n~~~""" . L~ Ilv t,¡)) .., MIT Report Form Revised: 06/19/02 2003-1221_MIT _PBU_09-16.xls STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonJ--J SuspendJ--J Operation ShutdownJ~J PerforateJ-'J VarianceJ--J Annuar DisposalJ'-J After Casin~J'-J Repair WellJ"'J Plu.cl Pefforationsr'-J Stimulate[] Time ExtensionJ'-J OtherJ--J Change Approved ProgramJ--J Pull TubingJ--J Perforate New PoolJ--J Re-enter Suspended WellJ--J SBG TREATMENT 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development J~J Exploratoryr--J 177-037 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic r-1 Service [] 50-029-20257-00-00 7. KB Elevation (ft): 9. Well Name and Number: 54.00 09-16 8. Property Designation: 10. Field/Pool(s): ADL 028328 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12588 feet true vertical 9195 feet Plugs (measured) TT Plug Installed @ 12023' (01/12/1995). Effective Depth measured 12023 feet Junk (measured) true vertical 8580 feet Casing Length Size MD TVD Burst Collapse Conductor 100' 20" 128' 128' 40K 520 Surface 2699' 13-3/8" 2727' 2727' 80K 2670 Intermediate 11342' 9-5/8" 11370' 8345' 80K 4760 Liner 1518' 7" 11070'-12588' 8151 '-9195' 80K 7020 ' 12 '121 ' ' ' Perforation depth: Measured depth: Open Perfs 11810'-11910', 11942'-11986', 12005, 040- 00'.~,~ ~- ,~ ~,--12298"12383' Open Perfs 12350'-12370', 12375'-12395'. Sqzd Perfs 11986'-~'U .~ Sqzd Perfs 12028'-12040', 12100'-12105', 12140'-12186' 12220'-12248'. True vertical depth: Open Perfs 8649'-8720', 8742'-8773', 8787', 8811'-8853', 8992'-901J'~L Open Perfs 9029'-9043', 9046'-9060'. Sqzd Perfs 8773'-8790', 8803';8811', Sqzd Perfs 8853'-8857', 8881'-8914,8938'-8957'. ~1~$~(.3 Tubing: ( size, grade, and measured depth) 7" 26# L-80 TBG @ 11006'. 7" x 5-1/2" XO @ 11006'. 5-1/2" 17# L-80 @ 11020'. 5-1/2" x 4-1/2" XO @ 11021'. 4-1/2" 12.6# N-80 TBG @ 11147'. (2) 3-1/2" TBG ASSLY @ 11917' & 12111' 5-1/2" x 2-7/8" TBG Patch from 11010' - 11032'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" Baker DB Packer @ 11022'. (4) 7" x 3-1/2" BKR FB-1 FB-1 PKR's @ 11917', 12016', 12111' & 12261'. 7" Camco WRDP-2 SSSV Nipple @ 2173'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 5444 2852 Subsequent to operation: 15233 1614 14. Attachments: 15. Well Class after proposed work: Exploratoryr-J Development J--J Service~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: OilE~] Gasr-] WAGI~I GINJ[~ WINJ[~ WDSPLr"~ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct te.4h~ best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr I NIA Printed Name DeWayne R. Schnorr -. n Title Techical Assistant "- ' rz~~'~'~~ ~j~--'~-~,v.~ Phone 907/564-5174 Date June 24, 2003 Signature Form 10-404 Revised 2J~~~,, ~J~L (]) ~00~ 0 N IGIN A L RBDiI S BFL JUL 0,3 20113' 09-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 05/31/2003 SWAPPED FROM MI GAS TO PW WATER. 06/19/2003 SCMOO-B-GONE--SBG: SCMOO-B-GONE 06/20/2003 sCrvlOO-B-GONE--SBG: SCMOO-B-GONE 06/23/2003 TESTEVENT---INJECTION PRESSURE, PSI: 1614; TYPE: PW VOLUME: 5233 BWPD. EVENT SUMMARY 05/31/03 SWAPPED FROM MI GAS TO PW WATER. 06/19/O3 SCHMOO-B-GONE, SHUT-IN WELL T/I/O = 1250/0/0. PUMPED 457 BBLS SCHMOO-B-GONE MIX. 06/20/03 SCHMOO-B-GONE, PUMPED 13 BBLS TO MAKE A TOTAL OF 470 BBLS SCHMOO-B-GONE, LET SOAK 3 HOURS. DSO WILL BRING WELL ON FOR 353 BBLS AND LET SOAK 3 MORE HOURS AND BRING WELL BACK ON FINAL WHP - 650/40/0. O6/23/O3 TESTEVENT---INJECTION PRESSURE, PSI' 1614; TYPE: PW VOLUME: 5233 BWPD. FLUIDS PUMPED BBLS 470 SCHMOO-B-GONE MIX 47O TOTAL Page I TREE = 6" Mc Et/OY WELLHEAD= FMC 09 16 SAFETY NOTES: 4-1/2" DB NIP PLE @ 11135' ACTUATOR = AXELSON " NOT USABLE. KB. ELEV = 54.0' ,,,,-- .... BFI ELEV = NA J"' KOP = 3140' Max Angle = 61 @ 6633" DatumDatum IVD =.ivD = 8800'12101SS ,-~--]-----J 2173' H 7"CAMCOWRDP-2 SSSVI~ ID= 5.937"I ..... -I ~2, H ~_~,~,,~c~ I IT"TBG'"C, 26#,L'80,.0383bpf,'D:6.27e"I--J 11oos' I---i, ---I 11007' j-j ?'xs-1/2"xo, iD:4.892"J ~ t----J 11010' H 5-1/Z'X2-7/8"FESRCPPKR, ID:2.390" J J5-1/2"TBG, 17#,L-80, .0232bpf,ID=4.892" H 11020' ~ i ~ ~ ---~ 1102z H 9'~18"X4'1/2"BKRD~PK~"D=4'7~0" I I..~o...~.c~.^~c.-s~o~o H ~o3~' t----I ~----I ~o~' H ----I 11041' H 7"~LLOU~"'D=6'000" I Minimum ID = 2.250" @ 11031' -- --J 11048' H 7"X4-1/2"XO, ID=3.992" J 2-7/8" HES XN NIPPLE IN TBG PATCH L I~"x~".o~....~.l-I ~o7o' I--s II----I ~3s' H ~"~c°~"'",'~=~'~'l I~-~,~"c~,~#,~-~o,,~=~.-~"H ~7o' I-~ [] · J 11149' H ELMD'I-rLOGGED09/05/99 J I~"x~'~'"~F~'~""""~="'°°°" Iff ~ I J3-1/2"BKR~,L,OUTEXT..D=4.~00" H ,~,~02~' I---/ ____ __ .__.GAS LIFT MANDRELS -- , ST MD TVD DEV TYPE VLV LATCH PORT DATE JS"X3-1/2"XO,~D=2.992" J--j 11927' ~ T 119'--'~' 873'"'-T' 4'"T' CA-MMG-2------ TG J 3-1/2" BKR LOC. SEALASSY, ID= 4.000"H 1201~' ~.~ i 21197587C:x53 121§0 8889 4546 C~-Mhl3-2CA_Mi~ TG~ . 17''xa-112''~Rm'l~R'lD=4'°°°'' I-I 12°1~' I 412220003845 c^-u...~__~ I~-~" ~ ~ ~°~, ~--4.°°°" H ~2o~,. I [ 13.l,2.'cAMc°DsNIP'D=2.875,' Iq 12023' J ~IE~J7 12023'H A-2 BLANKING PLUG 01/12/95 J J3-1/2" WLEG, ID = 2.992" H 12026' J t I"'~'°~°~'~ I-I ~o~s' I ' ~2~' H ~"x~-~'~"~""~-~""",'~=~'°°°" I ~ 12114' 3-1/2" BKRMILLOUTEXT., ID= 4.500" J REFLOG: BHC,S ON 09/28/77 ~ 12260' 3-1/2" BKRLOO SEALASSY, ID= 3.000" J Note: Refer to,reduction DBfor histod¢alpeff data ~ 12284' 3-1/2" BKRMILLOUTEXT., ID=4.500" I S,~EI s~I ,NTE~VAL IOpn/Sq~l ~ ' ~?0' Iq ~'~"~mO~'~"~=~'O~" I Seo~§e2forl~rforations ~I~ 12272' H 3'U2"WL~'ID=2'992" I ' J 12276' H ELMD Tr LOGGED10/21/94 J II J7"LNR, 29#, L-80, 0.0371 bpf, ID =6.184" H 12588' I J DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/07/77 ORIGINAL COIVPLETION ~04/07/02 CH/TP CORRECTIONS WB.L: 09-16 05/10/85 RWO 04/27/02 JKB/IIh CORRECTIONS PER APE PERMIT No: 1770370 04/22/89 LAST RWO 09/02/02 BHC/TP PEFF CORRECTIONS APl No: 50-029-20257-00 11/07/00 SIS-JH CONVERTEDTOCANVAS SEC1,T10N, R15E877' FSL& 175'FWL 03/01/01 RNAL 09/23/01 RN/KA K CORRECTIONS BP Exploration (Alas k a) DATE REV BY COMMENTS DATE REV BY COMMENTS 10/07/77 ORIGINAL COIVPLETION '04/07/02 CH/'rP CORRECTIONS 05/10/85 RWO 04/27/02 JKB/I~h CORRECTIONS PER APE 04/22/89 LAST RWO 09/02/02 BHC/TP PEFF CORRECTIONS 11/07/00 SIS-JH CONVERTEDTOCANVAS 03/01/01 RNAL 09/23/01 RN/KAK CORRECTIONS TREE= 6" Mc EV OY WEL LHEA D = FM( ACTUATOR = AXELSON KB. ELEV = 54.0' BF. ELEV = NA KOP= 3140' Max. Angle = 61 (~ 6633" Datum IVD = 12101' Datum TVD = 8800' SS PERFORATION SUMMARY RI~ LOG: BHCS ON 09/28/77 ANGLEATTOPPERF: 45 @ 11810' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL O pn/Sq z DA'rE 3-1/8" 4 11810 - 11860 O 09/04/89 3-3/8" 4 11860 - 11880 O 06~20~95 3-3/8" 4 11880 - 11910 O 06/20/95 3-1/8" 4 11942 - 11946 O 04/15/89 3-1/8" 4 11946 - 11986 O 04/15/89 3-1/8" 4 11986 - 11990 S 04/08/89 3-1/8" 4 11990 - 12010 S 04/08/89 3-1/8" 1 12005 O 04/15~89 4 12028 - 12040 S 04/08/89 4 12040 - 12076 O 04/19/91 4 12076 - 12100 O 04/19/91 3-1/8" 4 12100 - 12105 S 04/08/89 3-1/8" 4 12140 - 12186 S 04~08~89 3-1/8" 4 12220 - 12248 S 04/08/89 3-1/8" 4 12298 - 12333 O 04/15~89 3-1/8" 4 12350 - 12370 O 04/15/89 3-1/8" 4 12375 - 12395 O 04/15/89 09-16 DATE REV BY COMMENTS DATE REV BY COMMENTS 10/07/77 ORIGINAL COIVPLErlON 04/07/02 CH/TP CORRECTIONS 05/10/85 RVVO 04/27/02 JKB/IIh CORRECTIONS PER APE 04/22/89 LAST RWO 09/02/02 BHC/TP PERF CORRECTIONS 11/07/00 SIS-JH CO NV ERT ED TO CANVAS 03/01/01 FINAL 09/23/01 RN/KAK CORRECTIONS PRUDHOE BAY UNIT WELL: 09-16 PERMIT No: 1770370 APl No: 50-029-20257-00 SEC 1, T1 ON, R15E 877' FSL & 175' FWL BP Exploration (Alas k a) J~.e: ARca Wel1 9-16 Patch (PTD 77-37) ) ) Subject: Re: ARCO Well 9-16 Patch (PTD 77-37) Date: Sun, 28 May 2000 16:28:20 -0900 From: "PRB Problem Wells" To: blair _ wondzell@admin.state.ak.us CC: tom_maunder@admin.state.ak.us Blair / Tom: You should have received in your office the 10-404 for the patch repair on 9-16. The well passed a post-patch MITIA @ 3000 psi (not witnessed). Currently the well is still under Sundry approval #91-233 for water injection only. The well is scheduled for MI gas injection service about August of this year. Do you require an additional submittal to cancel the Sundry or to approve MI injection? Also, we could schedule a Field Inspector MITIA for this summer with the other wells due. ultimately we won't know how good our fix is until the well is placed on MI service. If preferable, we can wait until after it's been on MI to change and/or cancel the Sundry. Thanks in advance to sorting this out. Jerry Dethlefs Phillips Problem Wells ---------------------- Forwarded by PRB Problem Wells/AAI/ARCO on OS/28/2000 04:10 PM --------------------------- Tom Maunder <tom~maunder@admin.state.ak.us> on 12/15/99 03:25:45 PM To: PRB Problem Wells/AAI/ARCO cc: Blair Wondzell <blair_wondzell@admin.state.ak.us>, John_Spaulding <john_spaulding@admin.state.ak.us> Subject: Re: ARCO Well 9-16 Patch SCANNED .L~N 11 20D6 Jerry, Thanks for the information regarding 9-16. I have forwarded the sundry request on recommending approval of the plan you proposed. with regard to 9-46. ..yes, we would very much like to see the FMC proposal and the subsequent work plan. There are at least 2 items regarding the potential repair we are concerned about. They are 1. If you cut off the presently installed ring, what plan is there a plan to provide a replacement?? will any leak "get bigger" when the compression force of the ring is removed?? 2. We presume pre- and post- heating of some sort will still be required. Has the temperature distribution in the wellhead assembly and any effect on elastomer seals been determined? Please keep us informed as this issue continues to progress. Thanks. Tom Maunder PRB Problem Wells wrote: > Blair/Tom: In response to your request for information on the troubleshooting of > 9-16, I have attached a document from our database with the individual events > that led us to the patch decision. Essentially we pressure-tested the tubing lof3 5/30/00 8:32 AM .,Re: ARC'O Well 9-16 Patch (PTD 77-37) ) and > casing from above (plug in nipple) the packer and below (IBP) the packer. The > pressure test above the packer resulted in a passing MIT-T, but failing MITIA. > The pressure test below the packer resulted in passing MITT and passing MITIA. > We knew the leak had to be near the packer, which was the target for the video > log. The tubing was displaced with gas for logging, and we pressured-up on the > IA with a pump. The leak was very obvious approximately 2-feet into the locator > assembly. The leak appears to be a small crack or possibly a thread leak. The > patch design is such it will straddle the leak area; the top RCP packer sealing > in the 5-1/2" tubing, the bottom RCP packer sealing in the 4-1/2" locator sub. > There are not any moving assemblies to be straddled. > In regards to the corrosion question, typically we do not have corrosion > problems on our injection wells. Although that is a general statement and may > not always be the case, we saw no evidence of corrosion in the tubing on the > video log. Usually we see pits or lines of corrosion on a video before corrosion > is a concern; in those cases we may run a caliper log to determine how extensive > it may be. In this case we are confident it is not a problem. > Let me know if you have any further questions or comments about this well. > I have an update on the 9-46 casing repair. FMC was able to provide us what we > think is a very good plan to weld the casing. Essentially the lock ring would be > cut off (leaving the internal threads), and only one fillet weld to be made. The > ARCO facility engineers are working on a procedure to "qualify" the welding of > 4130 to 4130 metal; this testing should take a couple weeks. After that the > repair can be made. We would be happy to share the weld procedure with you when > the facility engineers have it all prepared. Would you like for us to meet you > in town to go over this process? Or would you rather we invite your Field > Inspector to a meeting? Either way is fine. We hope to make the weld repair by > the end of January. > > Jerry Dethlefs > ARCO Problem Wells(See attached file: 09-16 History.doc) > > ------------------------------------------------------------------------ > Name: 09-16 History.doc > 09-16 History.doc Type: Microsoft Word Document (application/msword) > Encoding: base64 > Description: Mac Word 3.0 T0111 Maunder <t0111 maunder@admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of3 5/30/00 8:32 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X (Patch) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 54 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 8. Well number 4403' FNL, 5104' FEL, Sec. 1, T10N, R15E, UM (asp's 718570, 5942349) 09-16i At top of productive interval 9. Permit number / approval number 3865' FNL, 868' FEL, Sec.3, T1 ON, R15E, UM (asp's 712233, 5942707) 177-037 At effective depth 10. APl number 50-029-20257 At total depth 11. Field / Pool 3716' FNL, 1425' FEL, Sec. 3, T1 ON, R15E, UM (asp's 711672, 5942839) Prudhoe Bay Oil Pool , 12. Present well condition summary Total depth: measured 12589 feet Plugs (measured) TT Plug installed 1/12/1995 @ 12023' MD. true vertical 9195 feet Effective depth: measured 12023 feet Junk(measured)ORIGINAL true vertical 8580 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 100' 20" 258 Sx AS ~ 100' 100' Surface 2673' 1 3-3/8" 3100 Sx C~ass G 2727' 2727' Production 1 1316' 9-5/8" 1000 Sx Class G & 300 Sx AS I 1 1370' $345' Liner 1518' 7" s20 Sx C~ass G 12588' 9195' Perforation depth: measured 11810' - 11910'; 11942' - 11986'; (12005' & 12010' one shots); (isolated below TTplugare 12040' - 12100'; 12140' - 12186'; 12220'- 12248'; 12298'- 12333'; 12350'- 12370'; 12375'- 12395'). true vertical 8649' - 8720'; 8742' - 8773'; (8787' & 8790' one shots); (isolated below TTplug are 8811' - 8853'; 8881' - 8914'; 8938' - 8957'; 8992' - 9016'; 9028' - 9042'; 9046' - 9060'). Tubing (size, grade, and measured depth) 7", L-80, 26# PCT @ 11006' MD; 4-1/2", 12.6#, L-80 PCT Tail @ 11147' MD; 3-1/2", 9.2#, L-80 PCT Tail @ 12025' MD; 3-1/2", 9.2#, N-80 PCT Tail @ 12272' MD Packers & SSSV (type & measured depth) Baker DB PKR @ 11022' MD; Baker FB-1 Packers @ 11917', 12016', 12111', & 12261' MD. 7" CAMCO BAL-O SSSV @ 2173' MD. ' 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (Shut in) Subsequent to operation 6406 1434 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service __(WAG).__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed -'-~/~ ' _.~,,~ '~_.,,'b~.., ~1:~"~ Title PAl Wellwork Design&Optimization Supervisor Date ,~- //- 42 ¢.~ Erin Oba ' Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09-16i DESCRIPTION OF WORK COMPLETED SET TUBING/CASING PATCH Date Event Summary 4/15/2000: 5/08/2000: 5/09/2000: RIH & drifted to 11006' SLM. RIH & set patch f/11010' to 11032' MD. MITIA to 3000 psi - passed. Placed well on water injection. Obtained representative injection data. Page I ARCO Well 9-16 Patch Subject: ARCO Well 9-16 Patch Date: Wed, 15 Dec 1999 13:55:54 -1000 From: "PRB Problem Wells" <P1041@mail.aai.arco.com> To: Blair_Wondzell@admin.state.ak. us, tom_maunder@admin.state.ak, us CC: "PRB Problem Wells" <P1041@mail.aai.arco.com> Blair/Tom: In response to your request for information on the troubleshooting of 9-16, I have attached a document from our database with the individual events that led us to the patch decision. Essentially we pressure-tested the tubing and casing from above (plug in nipple) the packer and below (IBP) the packer. The pressure test above the packer resulted in a passing MIT-T, but failing MITIA. The pressure test below the packer resulted in passing MITT and passing MITIA. We knew the leak had to be near the packer, which was the target for the video log. The tubing was displaced with gas for logging, and we pressured-up on the IA with a pump. The leak was very obvious approximately 2-feet into the Iocator assembly. The leak appears to be a small crack or possibly a thread leak. The patch design is such it will straddle the leak area; the top RCP packer sealing in the 5-1/2" tubing, the bottom RCP pad(er sealing in the 4-1/2" Iocator sub. There are not any moving assemblies to be straddled. In regards to the corrosion question, typically we do not have corrosion problems on our injection wells. Although that is a general statement and may not always be the case, we saw no evidence of corrosion in the tubing on the video log. Usually we see pits or lines of corrosion on a video before corrosion is a concern; in those cases we may run a caliper log to determine how extensive it may be. In this case we are confident it is not a problem. Let me know if you have any further questions or comments about this well. I-ha.v~n update on the 9-46 casing repair. FMC was able to provide us wha?~ think is a--"W~sb~d plan to weld the casing. Essentially the lock ring_.~3ald~e cut _off~ (leaving the ~rrtem I~reads), and only one fillet weld t~-be'~ade. The g of r h you when I air by th of January. Jerry Dethlefs ARCO Problem Wells(See attached file: 09-16 History. doc) ~09-16 History. doc Name: 09-16 History. doc Type: Microsoft Word Document (application/msword) Encoding: base64 Description: Mac Word 3.0 Problem Well History For Well 09-16 12/4/1999 9/28/1999 9/24/1999 9/11/1999 9/10/1999 8/27/1999 Sundry to AOGCC for patch approval. T/IlO =1950NAC/0 TBG FL at 7390'. IA FL at 400' (10 bbls). WL ran video log, located leak 2' below 4-1/2" x 5-1/2" XO at 11,022' in Iocator sub. Displaced tubing with A/L gas to 7000', pushed fluid level past packer with N2. Pressured up on IA with triplex pump. IBP pulled post MIT; drift through obstruction in packer assembly. Largest drift that passed 3.675"; 3.705" would not drift. Rig records show 3.70" would not drift. Prep for patch options. MITT passed with plug in nipple above packer; MITIA failed. CMIT passed with IBP below packer; leak appears to be in 4' interval between nipple and packer. T/I/O - 820/890~0 CMIT Tbg x IA to 2480 psi PASSED state witnessed: Tbg and IA FL's @ surface. Started pumping down Tbg and IA at the same time. CMIT to 2480 psi: Tbg pressure gained from 2460 psi to 2470 psi in 15 mins, 2480 psi in second 15 mins, 20 psi total. IA pressure: 2460 psi to 2470 psi in 15 mins, 2480 psi in second 15 mins, 20 psi total. Pumped 3 bbls of methanol total down the Tbg and IA. Final WHP's - 600/600/0. DSM CMIT T x IA Passed @ 2500 psi against IBP set @ 11120. T/IlO - VAC/10/0 MITT to 2500 psi PASSED; TBG FL at 400' (15 BBLs). Pumped 17 bbls of methanol to pressure TBG to 2500 psi. TBG lost 10 psi in 15 mins and a total of 15 psi in 30 mins and IA pressure remained unchanged during MITT. CMIT TBG & IA to 2500 psi FAILED; IA FL at 200' (5 bbls). Left TBG at 2485 psi. Had to keep bleeding TBG to keep pressure below 2500 psi while pumping IA. CMIT to 2500 psi lost 20 psi on the TBG and 110 psi on the IA in 15 mins. Re-pressured IA to 2500 psi and TBG pressure increased to 2500 psi. Repeated with similar results. Pumped a test volume of 32 gallons in 72 mins down the IA, establishing an average leak rate of 0.44 GPM @ 2500 psi. MITIA FAILED; Bled TBG to 35 psi and pressured IA to 2500 psi. IA lost 380 psi in 15 mins on first attempt, 340 psi on second attempt and 390 psi on the third attempt. TBG pressure increased from 35 psi to 70 psi during MITIA. Pumped 91 gallons in 61 mins for a leak rate of 1.5 GPM @ 2500 psi. Pumped a total of 11 bbls of methanol down the IA. Final WHP's = 0/1300/0 8/24/1999 TTP set @ 10994' for CMIT T x IA. 6/27/1999 T/IlO = VAC/320/0 STATE WITNESSED MITIA to 2450 psi FAILED; IA FL at surface. Pumped 3 bbls of methanol down IA to pressure IA to 2450 psi. IA lost 40 psi in 15 mins and a total of 80 psi in 30 mins. Did not exhibit pressure stabilization during test. FINAL WHPs=VAC/0/0 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 _X Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate_ Other_ 2. Name of Operator ARCO Alaska, Inc. ,). Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 4403' FNL, 5104' FEL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, SEC. 03, T10N, RI5E, UM At effective depth At total depth 3716' FNL, 1425' FEL, Sec. 3, T10N, R15E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X -- 6. Datum elevation (DF or KB feet) RKB 54 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 09-16 9. Permit numb/er / approval number 77-37 10. APt number v' 50-029-20257 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12589 true vertical 9195 Effective depth: measured 11012 true vertical 8112 Casing Length Size Conductor 80' 20" Surface 2673' 13-3/8" Production 11316' 9-5/8" Liner 1518' 7" Perforation depth: measured true vertical I Fubing (size, grade, and measured depth !Packers & SSSV (type & measured depth) feet / Plugs (measured) feet PBTD tagged @ 11012' MD (9/24/1999) feet Junk (measured) feet Cemented Measured Depth True vertical Depth 258 Sx AS II 80' 80' 3100 Sx Class G 2727' 2727' 1000 Sx Class G & 3OO Sx AS I 1 1370' 8345' 520 Sx Class G 12588' ~'".: ~'"' ~ .... !" ~ ~ ~ '~;"" !g4 95' (see enclosed li~) RiG IN A L 7", L-80, 26#, PCT @ 11006' MD; 4-1/2", L-80, 26fl, PCT Tail ~ 11147' MD; 3-1/2",L-80, 9.2¢, PCT Tail ~ 12025' MD; 3-1/2", N-80,9.2¢, Tail ~ 12272' MD. BAKER FB-1 PACKER (TOP STRADDLE) ~ 11918' & 12016 MD; BAKER DB PACKER ~ 11023' MD; 7" CAMCO BAL-O SSSV ~ 2174' MD; BAKER FB-1 PACKER (Bottom STRADDLE) ~ 12111' & 12261' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 15. Status of well classification as: '14. Estimated date for commencing operation December 15, 1999 i6. If proposal was verbally approved Name of approver Date approved Oil Gas -- Service __WAG Injector Suspended __ 17. I tqereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~__~"~ ~' (~1~~"~'~/"~ Title: Problem Well Specialist .,/ Jerry Dethlefs FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test __ Location clearance __ Mechanical integrity Test'~ Subsequent form required 10,~ ~) ~ /ti)proved by order of the Commission ~,~ ~, ~,~ ~, . .~.. *,~. ¢.~,~r~e~g~missioner Robe~ N. Chdstenson I~_~~ Form 10-403 Rev 06/15/88 · Return to: Anders/Dethlefs, PRB-24 SUBMIT IN TRIPLICATE DS 09-16 Sundry Request SUNDRY DISCUSSION AND PROPOSED ACTION PLAN 12/04/99 DISCUSSION Well 09-16 is a WAG injector that exhibits minor tubing x 9-5/8" (IA) annular communication. The well is currently operating under a Sundry variance (91-233) allowing water injection only due to the communication problem. During an MIT conducted 6/27/99, the IA lost pressure at a steady rate of 40 psi/15 minutes and did not exhibit then-hal stabilization. A video log run on 9/28/99 identified a small leak at 11,022', 2' below the locator sub. ARCO Reservoir Engineering has identified the 9-16 injection pattern as having substantial production benefit if MI injection resumes. ARCO proposes to run a patch assembly to isolate the leak point, and resume MI injection. The patch assembly will not need to compensate for tubing movement. The following information supports the Sundry request: · An AOGCC witnessed combination MIT (T & IA) PASSED on 9/11/99 to 3000 psi against an inflatable bridge plug, set in the tubing below the packer. This indicates the 9-5/8" casing and packer have integrity. · The reservoir engineer identifies this as a favorable pattern for MI injection. · The proposed patch is retrievable, providing future repair or workover options. · The patch will consist of(l) HES 5-1/2" RCP packer, 2-7/8" space]-tube, and (1) 4-1/2" RCP packer to seal the leak near the locator sub. The upper packer sets in the 5-1/2" tubing; the lower packer sets in the locator sub assembly (see sketch). Vendor information suggests the patch is capable of a 5000 psi differential pressure. , PROPOSED ACTION PLAN o 2. 3. 4. 5. Cancel Sundry #91-233; Conduct an MITIA post patch set to 0.25 X TVD to the packer; Allow MI injection to resume; Monitor wellhead pressures daily. Shut-in and secure the well should MIT's or wellhead pressures indicate problems, and notify the AOGCC. RECEIVED [)EC 10 1999 ARCO ALASKA, INC. FO ~b~ 2412' Tubing-PC Casing FO (~ 2528' Casing Tubing NOGO Tubing-PC PKR Tubing MOE Tubing ]~.t35' Tubing MIN ID = :; $1Z" Liner Peri Peri Peri SQZ PKR Tubing MOE XO SEALASY PKR SBE !Z ,.;23' MIN ID =: 2875" ! TP w/Straddle NiP Tubing MOE LS PKR MOE NIP TTL Peri Peri' Perf Peri 09d 6 APl: 500292025700 SSSV Type: Annular Fluid: Diesel/9.4 NaCI Reference Log: BHCS Last Tag: 119163LM Last Tag Date: 8/8/99 Well Type: tNJ DePth Annotations Depth Comment 2412 FO@2412' 2528 FO @ 2528' Prudhoe Bay Orig Compltn: 10/7/77 Last W/O: 4/23/89 Ref Log Date' 9~28~77 RKB 54 ft TD: 12589 ftKB Max Hole 61 deg @ 7005 Angle: Angle@TS: 45deg@11779 09-16 Angle ~ TD: 46 deg @ 12589 Rev Reason: Comments corrected Last Update: 9/2/99 RECEIVED TVD Zone Status Feet.~PF Date Type 8685 ZONE 4 © 50 0 9/9184 APERF 8685 ZONE 4 O 50 0 4/29/85 RPERF 8699 ZONE4 (3 70 1/2 9/4/89 RPERF 8699 ZONE 4 O 20 0 4129185 APERF 8720 ZONE 4 O 40 4 G/20/95 RPERF 8720 ZONE4 O 30 0 9/9/84 APERF 8720 ZONE 4 O 30 0 4/29/85 RPERF 8720 ZONE4 O 30 1/4 9/4/89 RPERF 8756 ZONE 4 O 20 0 9/9/84 APERF 8773 ZONE 4 O 44 4 4/15/89 RPERF 8756 ZONE 4 O 16 0 4/29/85 RPERF 8776 ZONE O 28 0 4/29/85 APERF 4.ZONE 3 ZONE 3 O 20 0 9/9/84 APERF ZC)NE 3 O 20 0 4/29/85 RPERF 11990-12010 8776-8790 11990-12010 8776-8790 Mfr 1 11935 8737 CA 2 11975 8765 CA 3 12150 8889 CA 4 12220 8938 CA Perforations Interval 11810-11860 8649 11810-11860 8649 11810-1i880 8649 11860-11880 8685 11870-11910 8692 11880-11910 8699 11880-11910 8699 11880-11910 8699 11942-11962 8742 11942-11986 8742 11946-11962 8745 11962-11990 8756 Man V Mfr V Type V OD Latch Port TRO Date Vlv Type Run Commen1 CA RD 1 5 TG 0000 0 1/12/95 No Check [E ED-15R 1 5 TG 0.000 0 217193 CA RD 15 RK 0.000 0 12/29/91 %'A ~4KED 1'5 RKP 0.000 0 12129/91 Crossover 7"x 5-1/2" 0.000 5-112" Otis XN No-Go Nipple 4.455 Crossover 5-1/2" x 4-1/2" 0.000 9-5~8" x 4-1/2" Baker DB Packer . 0.000 7" Baker Sealbore Extension 0.000 7" Milloul Extension 0.000 Crossover 7"x 4-1/2" 0.000 4-1/2" Camco DB Nipple--not usable obstruction @ packer 3.812 4-1/2" Tubing Tail 0.000 7" x 3-1/2" Baker FB-1 Packel (Top Straddle) 0.000 3-1/2" Baker Mil~out Extension (Top Slraddle) 0.000 Crossover 5" × 3-1/2" ('fop Straddle) 0.000 3-1;2" Baker L{}catol Seal Assembly (Top Straddle) 0.000 9-5/8" x 3-1/2" Baker FB-1 Packer (l'op Straddle) 0.000 3-1/2" Baker Seal Bore Extension (Top Straddle) 0.000 3-1/2" Cam(:() S Landing Nipple ID=2.875" w/A-2 Blanking Plug (Set 0.001 0i/12/95) (Top Straddle) 3-1/2" ']'ubm9 '[ ail (Top Straddle) 0.000 7"X 3-1/2" Baker FB-1 Packer (Bottom Skaddle) 0.000 3-1/2" Baker Milioul Extension fBotlom Straddle) 0.000 3-1/2" Bake~ Locator Sub (Boltom Straddle) 0.000 7" x 3-1/2" Baker FB-1 Packer (Bottom Straddle) 0.000 3-1/2" Baker Millout Extension (Boltom Straddle) 0.000 3-1/2" Camco DS Landing Nipple (Bottom Straddle) 2.813 3-1/2" TubirLq Tail (Bottom Straddle) 0.000 Feet Description 2727 Casing 11370 Casing 1518 Liner Feet Description 1006 Tubing-PC 14 I ubing 6 Tubing-PC 21 Tubing ~00 Tubing 108 Tubing 161 Tubing Comment 12025 8801 TTL 12111 8861 PKR 12114 8863 MOE 12260 8966 LS 12261 8967 PKR 12264 8969 MOE 12270 8973 NIP 12272 8974 TTL CaSing:Strings - All Size Weight Grade Top Btm 13.375 72.00 L-80 0 2727 9.625 47.00 L-80 0 11370 7.000 29.00 L 80 11070 12588 TubingStrings - All Size Weight Grade Top Btm 7.000 26.00 L-80 O 11006 5.500 0.00 11006 11020 4.500 12.60 L-80 11020 11026 7.000 0.00 1102~ 11047 4.500 9.20 N-80 11047 11147 3.500 0.00 11917 12025 3.500 0.00 1211~ 12272 Gas LiffMandrelslValves Stn MD TVD Man 7" Camco BAL-O SSSV Nipple 2173 2173 SSSVNIP 11006 8110 XO 11017 8117 NOGO 11020 8119 XO 11022 8120 PKR 11026 8123 SBE 11041 8133 MOE 11O47 8136 XO 11135 8194 NIP 11147 8202 TTL 11917 8725 PKR 11921 8728 MOE 11927 8732 XO 12015 8794 SEALASY 12016 8794 PKR 12019 8796 SBE 12023 8799 NIP 11135 11,135' Tubing MIN ID = 3.812' 12023 12,023' MIN ID = 2875" TTP wiS~raddle Genera[N°tes Date Note i.'~{C 1(~ 1999 912/99 DB Nipple @ 11135' riot usable since W/O Waivered Well: Water Injection only. No Mi allowed. Other(plugs, equip., etc.) - JEWELRY Depth TVD Type Description 5.937 ARCO ALASKA~ INC. Tubing-PC Casing FO ~C~ 2412' FO ((~ 2528' ................ Casing Tubing NOGO Tubing-PC PKR Tubing MOE Tubing 11,135' Tubing MiN iD ~ ' 3,812" Liner Perf Perf Perf SQZ PKR Tubing MOE XO SEALASY PKR SBE 12,023' MIN ID = 2,875" TTP w/Straddle : · NIP Tubing MOE LS PKR MOE NIP TTL Perf Perf Perf Perf Prudhoe Bay Interval TVD Zone 12005 - 12010 8787 - 8790 ZONE 3 12028 - 12076 8803 - 8836 ZONE 3,ZONE 2 12040 - 12080 8811 - 8839 ZONE 3,ZONE 2 12076 - 12080 8836 - 8839 ZONE 2 12080 - 12090 8839 - 8846 ZONE 2 12090 - 12094 8846 - 8849 ZONE 2 12090 ~ 12100 8846 - 8853 ZONE 2 12094 - 12105 8849 - 8857 ZONE 2 12094 - 12100 8849 - 8853 ZONE 2 12140 - 12186 8881 - 8914 ZONE 2 12220 - 12248 8938 - 8957 ZONE 2 12298 - 12333 8992 - 9017 ZONE 2 12298 - 12333 8992 - 9017 ZONE 2 12350- 12370 9029 - 9043 ZONE lB 12350- 12370 9029 - 9043 ZONE lB 12375 - 12395 9046 - 9060 ZONE 1B,HOT 12375 - 12395 9046 - 9060 ZONE 1B.HOT Stimu!~tibnsATr~eatments Interval Date Type 11810-12395 4/8/89 SQZ 11942- 11946 4/8/89 STR 11946~ 11962 4/8/89 STR 11962- 11986 4/8/89 STR 11986-11990 4/8/89 STR 11990- 12010 4/8/89 STR 11946-11962 4/15/89 STR 11962-11986 4/15/89 STR Status Feet SPF Date TyPe O 5 4 4/15/89 RPERF O 48 0 10/15/86 APERF O 40 4 4/19/91 RPERF O 4 1/4 6/23/90 APERF O 10 4 4/19/91 APERF O 4 1/2 6123190 APERF O 10 4 4~19191 RPERF O 11 1/4 10/15/86APERF O 6 1/2 6/23/90 RPERF O 46 4 11/19/77 IPERF O 28 4 11/19/77 IPERF O 35 4 11/19/77 IPERF O 35 4 4/15/89 RPERF O 20 4 2/20/84 APERF O 20 4 4/15/89 RPERF O 20 4 2/20/84 APERF O 20 4 4/15/89 RPERF Comment 09-16 Comment RECEIVED L,'~C. 1 0 1999 Alaska Oil & Gas C(ms. ComPri Anchorage ARCO Calculations Chat Subject File JBy ,.,. ~ Sheet number J 1999 1~03q / _ ~: I~1 lTV I ITi-I~ PI:IINTIkli~ ANC~HORAGE. AK (gO7) 563-4743 159-5881 ARCO Alaska In{;, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 December 4, 1999 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Subject: DS 09-16 Sundry Notice Request Dear Mr. Wondzell: ARCO requests approval to install a tubing patch and resume MI injection in well 09-16. The well has a small tubing leak at 11,022', 2' below the locator sub. The patch will eliminate the slight Tubing x 9-5/8" communication and allow the well to be returned to MI injection service. Attached is a Sundry application, Sundry discussion, wellbore schematic and proposed patch design. If you have any questions please contact Joe Anders or me at 659-5102. Sincerely, Jerry Dethlefs Problem Well Specialist Attachments: Sundry Form 10-403 Sundry Discussion and Action Plan Wellbore Schematic PATCH SIZE / TYPE: Company: Well Number: Charge Code: HALLIBURTON I ;ALL~BUFITON ENERGY SERVICES PRDDHOE BAY, ALASKA 99734 Phone (9(/7)659-2528 EAX (907)659 2341 Date: HES Rep: DESCRIPTION LENGTH OD ID. 1) HES'RCP' Packer *Upper Section "GS Fishing Neck, Fishing Neck P~ofile ID = *Center of Element Package (. _...~) 2) Cressover 3) "- tb/ft N80 pup joint Locator/Seal Assembly * EFFECTIVE SEAL LENGTH: .... Locator .... Extension -- Molded Seal Assembly * P/N Extension ..... lb/it pL Extension, __ lb/It p~ .... Extension, lb/ft p( ..... Molded Seal Assembly * P/N ...... Molded Seal Assembly ~ P/N ...... Bullet Nose Seal Guide --Bottom oFGuide 5) Polished Bore Receptacle 'Lower Section 6) Crossove~ Fishing Neck "GS Fishing Neck, Fishing Neck Prefile ID = " 7) "lb/ft N 80 spacer pups __ Ib/ft N 80 pup jointr (Pin x Pin) .......... Ib/ft NSO pupioint, (__ (With Centralizel Coupling) 8) Crossovel Box X Pin ) ( (__._) ( DEPTH 0 O0 000 000 000 ( 000 10) Boltom of Assembly ......... 000 Top of the assembly to the cente~ of the: uppel element package is lower element package is DIS'1ANCE BETWEEN ELEMENTS uppel slip package is lower slip package is NOTES: RE1RIEVING TOOL IS A .... "GS FOR 'lite UPPER ASSEMBL' AND A ..... "GS FOR FHE LOWER ASSEMBLY THE FISHING NECK PROFILE(ID = _") IS AT THE TOP OF I-HE PACKER ON THE UPPER ASSEMBLY AND AT I'HE BOTTOM OF THE 'PB ON THE LOWER ASSEMBLY iT IS RECOMMENDED '/'FIE TQOLSfRING LENGTH EX1 lEND ABOVE THE TOI:: OF fidE PBR THE tIPPER PACKER IS PINNED WI~II LBS OF RE[ i ASI PINS, AND 'IFtE LOWER PACKER IS PINNED WI rH ......... l B~ RELEASING PINS AN 'ELEMEN1- RELAXING lIME' OF 45 MINLITES(MINIMHM) IS RECOMMENDED PRIOR I 0 STARTI 9) IqES 'RCP' Packer 000 *Center of Element Package ( ) (__~) Re: 9-16 Video Results Subject: Re: 9-16 Video Results Date: Mon, 04 Oct 1999 16:24:14 -0800 From: Blair Wondzell <blair_wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells CC: j ohn_spaulding~admin.state.ak.us '77 Joe, Thanks for the information. Blair We hope it works. PRB Problem Wells wrote: Dear Mr. Wondzell : A video log was run in well 9-16 on 9/28/99 to identify the tubing x 9-5/8" leak point. The tubing fluid level was depressed below the packer using nitrogen. A very clear picture was obtained of fluid streaming into the tubing at the locator sub, 11,022' We are evaluating installation of a patch across the leaking locator sub. This should restore bubble tight integrity to the tubing and allow safe MI injection to commence. A sundry request will be filed if we decide to pursue this option. Please call if you have any questions. Joe Anders Problem Well Specialist ARCO Alaska, Inc. (907) 659-5102 1 of 1 10/5/99 8:35 AM Re: DS 9-16 MIT ~ - Subject: Re: DS 9-16 MIT Date: Mon, 13 Sep 1999 08:05:21 -0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: PRB Problem Wells '7 7"0 BT Jerry, Thanks for the information. If they your engineering dept. proposes MI, we will evaluate for that and will probably approve with some additional monitoring. Regards, Blair Wondzell PRB Problem Wells wrote: > Blair: Larry Wade witnessed a passing combination MIT on the tubing and IA of > 9-16 on Saturday, 9/11/99. This test was against an IBP located in the tailpipe > below the upper packer. The prior MIT we attempted was with a plug in the nipple > above the packer (the nipple below the packer is not usable). The MIT on the > tubing passed, but the MITIA leaked off. Since this recent test passed, the T X > IA leak point must be in the 5-feet or so of tubing immediately above the top > packer. If ARCO Engineering still wants to put MI into this well we may be able > to patch this leak. I will let you know if we propose patching the leak. Until > then, we will return the well to PWI injection. Let me know if you need any > further information. > Jerry De thl efs > ARCO Problem Wells 1 ,~1 0Il'l/C;0 R.lC} AM Re; 9-'16 Sundry Action Plan Revision Subject: Re: 9-16 Sundry Action Plan Revision Date: Thu, 01 Jul 1999 06:58:49 -0800 From: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> Organization: SOA-AOGCC To: PRB Problem Wells Jerry, Thanks for the info. I knew that you were checking the injection rates and pressures daily, but what you are actually doing is more than I envisioned. Thanks for the information. Your plan forward sounds appropriate. Thanks, Blair PRB Problem Wells wrote: Blair: I will add a TTP and CMIT to our wellwork schedule. We do have some options for logging depending on the leak rate. We can do more diagnostics from the surface before we attempt logging to see if there is a reasonable chance of success. If it is located in the tubing string it should be patchable. The computer system records injection rates and tubing pressures constantly; casing pressures are read manually and input in the computer. Ail wells are visually monitored daily; most annulus pressures are recorded on the computer weekly. Wells with communication problems are specifically required to be recorded daily. We will contact the Field Inspector when we get the TTP run for the CMIT. Let me know if you need anything else. Jerry De thl efs ARCO Problem Well Specialist Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 06/29/99 12:20:33 PM To: PRB Problem Wells/AAI/ARCO cc: Jennifer D Watson/AAI/ARCO, William L Mathews/AAI/ARCO, PRB FIELD ENG/AAI/ARCO , chuck scheve@admin, state.ak, us Subject: Re: 9-16 Sundry Action Plan Revision Joe, AOGCC Sundry #91-233 approved: 1. Return well to water injection service only. 2. Perform quarterly 9-5/8" MIT to verify continuing casing integrity. 3. When magnitude of leak becomes large enough to detect, perform leak detection log to identify source of suspected Tubing by 9-5/8" communication. Joe, is the leak now large enough to find? Let's do this: 1. Set plug and run 'CMIT (notify AOGCC PI to witness). 2, Attempt to locate leak. 3. If located, can it reasonably be fixed? We can get together at this point. On injection wells, are the Tbg press., Csg press., and rate read and recorded each day? If you have questions, call or E-mail. Blair PRB Problem Wells wrote: > > Hi Blair. Well 9-16 is a water injector with AOGCC Sundry #91-233. On 6/27/99, > we conducted the required annual MIT on the tubing x 9-5/8" casing annulus. Over > a 1 hour period, the tubing x 9-5/8" pressure was observed to decrease from 2450 > psi at a steady rate of 40 psi~15 minutes. Based on this test, the Sundry > "Action Plan" is being revised as follows: 1 ^,'~> 7/I/C}Q 6.~0 AM Re: 9-26 Sundry Action Plan Revision Action Plan 1. Return well to w~ter injection service only. 2. Perform a combination tubing x 9-5/8" Mechanical Integrity Test at a 2 year frequency. Please call if you have any questions. Joe Anders Problem Well Specialist ARCO Alaska, Inc. (907) 345-3917 2 of 2 7/1/99 6:59 AM Re: 9-16 Sundry Action Plan Revision Subject: Re: 9-16 Sundry Action Plan Revision Date: Tue, 29 Jun 1999 13:20:33 -0800 From: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> Organization: SOA-AOGCC To: PRB Problem Wells CC: Jennifer D Watson <JWATSON~mail.aai.arco.com>, William L Mathews <WMATHEWS~mail.aai.arco.com>, PRB FIELD ENG , chuck_scheve~admin.state.ak.us "77-'07;7 Joe, AOGCC Sundry #91-233 approved: 1. Return well to water injection service only. 2. Perform quarterly 9-5/8" MIT to verify continuing casing integrity. 3. When magnitude of leak becomes large enough to detect, perform leak detection log to identify source of suspected Tubing by 9-5/8" communication. Joe, is the leak now large enough to find? Let's do this: 1. Set plug and run CMIT (notify AOGCC PI to witness). 2, Attempt to locate leak. 3. If located, can it reasonably be fixed? We can get together at this point. On injection wells, are the Tbg press., Csg press., and rate read and recorded each day? If you have questions, call or E-mail. Blair PRB Problem Wells wrote: Hi Blair. Well 9-16 is a water injector with AOGCC Sundry #91-233. On 6/27/99, we conducted the required annual MIT on the tubing x 9-5/8" casing annulus. Over a 1 hour period, the tubing x 9-5/8" pressure was observed to decrease from 2450 psi at a steady rate of 40 psi~15 minutes. Based on this test, the Sundry "Action Plan" is being revised as follows: Action Plan 1. Return well to water injection service only. 2. Perform a combination tubing x 9-5/8" Mechanical Integrity Test at a 2 year frequency. Please call if you have any questions. Joe Anders Problem Well Specialist ARCO Alaska, Inc. (907) 345-3917 1 nfl 6/29/99 1:20 PM 9-16 Sundry Action Plan Revision Subject: 9-16 Sundry Action Plan Revision Date: Mon, 28 Jun 1999 16:11:36 -0900 From: "PRB Problem Wells" T o: B lair_Wondzell~admin, state, ak.us CC: "Jennifer D Watson" <JWATSON@mail.aai.arco.com>, "William L Mathews" <WMATHEWS~mail.aai.arco.com>, "PRB FIELD ENG" , chuck_scheve~admin.state.ak.us Hi Blair. Well 9-16 is a water injector with AOGCC Sundry ff91-233. On 6/27/99, we conducted the required annual MIT on the tubing x 9-5/8" casing annulus. Over a 1 hour period, the tubing x 9-5/8" pressure was observed to decrease from 2450 psi at a steady rate of 40 psi/15 minutes. Based on this test, the Sundry "Action Plan" is being revised as follows: Action Plan 1. Return well to water injection service only. 2. Perform a combination tubing x 9-5/8" Mechanical Integrity Test at a 2 year frequency. Please call if you have any questions. Joe Anders Problem Well Specialist ARCO Alaska, Inc. (907) 345-3917 I ,-,f' I fi/90/OO 19.¢Q Dh,/[ GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9566 Company: 7/1 1/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 3-22 PERFRECORD 950618 1 1 D.S. 3-24 ~'~ ~ ~c~ IBP SEITING RECORD 950621 I 1 D.S. 4-48 ~' C I I (5 ~ PROD PROFILE 950622 I 1 D.S. 6-14A ~ ~-~- ~,"7 PRODLOG 950623 I 1 D..S. 7-06 '7 ?~[.~- P~,,RFRECORD ........ 950619 I 1 D.S. 9-16 "~ '~ PERFRECORD 950620 I 1 D.S~ 12-34 ¢~! [ , ,,~ ..~ JEWELRY LOG COLLAR LOCATOR 9.50619 I I ... ' ....... D.S. 12-34 I "'1 | ~ I PERFRECORD 950619. I 1 D.S. 13-1 '7 ~ G O BA.KERINFLATBRIDGEPLUG 950623 I I .. D.S. 17-05 '~"(~ ~j ~ IBP SETTIN .G RECORD 950618 I I .... , , ,,, ......... , , ............. ,,, SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 AT'I'N: Sherrie R£CF..i'VED 0 8 Alask~ 0ii & ~,as Cons. c0mmissi0rt NO. 9236 Company: 2/7/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Mylar Disk D.S. 1-22A CBT SONIC IN OPENHOLE 01 1 2 95 I 1 D.S. 3-24 CNT-D 011 295 I 1 D.S. 4-38 USIT 01 3095 I 1 D.S. 4-43 DUAL BURST TDT-P 0119 95 I 1 D.S. 4-40 DUAL BURST TDT-P 011 795 I 1 D.S. 9-2 PROD PROFILE 011 695 I 1 D.S. 9-16 INJEC PROFILE 01 1 595 I 1 D.S. 13-30 LEAK DETECTION 01 1 795 I 1 D.S. 15-41 STATIC PRESS SURVEY 01 1 395 I 1 D.S. 15-35 SHUT-IN BHP SURVEY/JEWELRY 01 1 495 I 1 D.S. 16-21 INFLATBRIDGE PLUG SETRECORD 01 1 595 I 1 D.S. 15-30 9501 7 iDUAL BURST TDT-P 1 23094 1 , , ,, SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 600 W. International Airport Road Anchorage, AK 99618-1199 AI'I'N: Sherfle NO. 9070 Company: I I Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 11/2/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 4-29 ~i~ ~" ' ~"~'t.,,-"'"PROD pROFILE (10-25-94) I 1 I D.S. 5-35 /') i ! c,) 'TUBG PATCH RECORD (10-23-94) 1 1 I D.S. 5-35 -! !" (._O ~ PERF RECORD (10-20-94) 1 1 D.S. 6-13 ~(~' ~ "-_~O PROD PROFILE (~ 10-24-94) 1 1 D.S. 09-161 -7 ?- INJEC SURVEY (10-21-94) 1 1 SIGNED: Please sign and retum one copy of this transmittal to Sherrle at the above address. Thank you. Naska Oil & Gas Cons. cemmisslon Anchorage P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-6-93 REFERENCE: ARCO CASED HOI_~E FINALS ., Completion l~___m 1, 5" Sch Perf Record l~_m 1, 5" Sch Jewelry/GR/CCL Tie-In Ih~n 1, 5" 'Sch Leak Detect Run 1, 1"&5~ Sch Leak Detect Run 1, l"&l~' Sch Dual Burst TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch TDTP (Borax) Run 1, 5" Sch CET Run 1, 5" Sch PITS Run 1, 5" Sch Static Pressure Survey Run 1, 5" Sch Compensated CBT Color Run 1, 5" Sch USIT Color Run 1, 5" Sch Completion Run 1, 5" Sch Completion Run 1, 5" Sch PITS Run 1, 5" Sch PITS Run 1, 5" Sch PITS Run 1, 5" Sch Please sign and rettm ~ attac~/~py as receipt of data. RECEIVED BY~/~_~ Have A Nice Day! Sonya Wallace APPROVED_~~j ATO-1529 Trans# 93058 CHEVRON 4/~ FILES D&M ~?~ 0 ~^ 'R&D CLINT CHAPMAN ~ Cz, ~ '~J~ BPX E~ON ~o~l C~ ~ STATE OF ~~ MOB~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-93 REFERENCE: ARCO CASED HOLE FINALS 1-7--~--i~ 2-20-93 Leak Detect Run 1. 5~ 3-18-93 ~ ~flle R~ 1, ~ 1-1~~ 3-5-93 ~ ~flle R~ 1, ~ }~?~1-24A 2-8-93 PITS R~ 1, ~ ' 2-11-- ~-~ 2-23-93 ~ ~flle R~ 1, ~ --2-13 2-13-93 ~d Reco~ R~ 1, ~ 3-1-U~ 1-8-93 ~ ~ffie R~ 1, ~ ~-9 11-12-92 ~d Reco~ R~ 1, ~ 3-34A--~ 1-28-93 ~ ~flle R~ 1, ~ ~12 9-19-92 Coll~ ~g R~ 1, ~ 4-24~~ 3-6-93 ~ Detection R~ 1, ~'~ ~5-6 2-13-93 ~ ~flle R~ 1, ~ 5-11-7~ 8-13-92 ~ R~ 1, ~ ~ 5-22 2-9-93 Ped Reco~ R~ 1, ~ 6-3--~-7~ 1-22-93 ~d Reco~ R~ 1, ~ 2-22-93 ~ ~flle R~ 1, ~ 7-3 2-15-93 ~ ~flle R~ 1, ~' ~9-2 2-8-93 ~ ~o~le R~ 1, ~ 9-7-~~ 3-9-93 ~ ~flle R~ 1, ~ ~4~-~ 2-20-93 Tempe~t~ ~g R~ 1, ~ 11-1~-~2-14-93 GR/ColI~ R~ 1, ~ 11-1~ 3-19-93 GR/ColI~ R~ 1, ~ --13~0 2-19-93 ~ ~ofile R~ 1, ~ 13~~_[}~2-14-92 Trace~csn R~ 1, ~ 13-33/'- ~12-14-92 Trace~c~ ~g R~ 1, ~ ~14-5A 3-19-93 PITS R~ 1, ~ ff14-28 3-2-93 B~er ~P/Coll~ R~ 1, ~ ~4-28 3-8-92 Baker ~P/Coll~ R~ 1, ~ 14-3~~{~12-10-91 ~ R~ 1, ~ ~16-25 2-26-93 ~ ~oflle R~ 1, ~ -- 16-28 2-28-93 ~ ~flle R~ 1, ~ 16-29A-~-~-1-93 ~ ~oflle R~ 1, ~ ~17-15 11-16-92 ~ Reco~ R~ 1, ~ /17-16 1-12-93 ~ Reco~ R~ 1, ~' Please sign and returnee a~tached c_0py~c_e~.t of data. RECEIVED B ¥_~_._(..~,~.~ Have A Nice Day! Sonya Wallace ATO-1529 C~Anco Camco Camco Camco Camco HL~ Camco HLS Camco HL~ Camco Camco HLS HLS HI~ Camco HLS Camco Camco HL~ Camco Camco Camco Camco Camco Camco Camco Camco Camco HLS HLS Camco Camco Camco HIS Camco Camco Camco Camco HLS HIS APPROVED_ff~__) Trans# 93049 CENTRAL FILES CHEVRON # LUCILLE JOHNSTON EXXON MOBIL PHILLIPS #BPX STATE OF ALASKA The correct API# for 14-34 is 50-029-21010-00. The coorect well name for this lo~/ is 16-29A. STATE OF ALASKA AND GAS CONSERVATION C REPORT OF SUNDRY WELL OP. RATIONS 1. Operations performed: Operation shutdown . Stimulate X Plugging ...-.-- Perforate .--. - ,,,~ Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well 6. Datum of elevation(DF or KB) Development 54' RKB fe ARCO Alaska, Inc. Exploratory 3. Address Strafigraphic 7. Uniter Property P.O. Box 100360, Anchorage, AK 99510-0360 service x Prudhoe Bay Unit 4. Location of well at surface 8. Well number 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM 9-16i At top of productive interval k E C ~ ~V ~ ~ 9. Permit number/approval number 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM 77-37 At effective depth ~ ~ ~ ~99~ 10. APl number 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM 50 - 029-20257 At total depth ~a,~_~ ~i~..& GaS C011S, (~0 ~,il(~ol'ag~ 11. Field/Pool 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM ...... Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 12589 feet Plugs(measured) TT Plugs @ 12248' & 12004' MD true vertical 9195 feet Effective depth: measured 12004 feet true vertical 8559 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 258 sx AS II 100' 100' Surface 2673' 13-3/8" 3100 sx Cl G 2727' 2727' Production 11316' 9-5/8" 1000 sx Cl G & 300 sx AS I 11370' 8345' Liner 1518' 7" 520 sx Cl G 11070-12588' 7542-9195' Perforation depth: measured See attached. true vertical See attached. Tubing (size, grade, and measured depth) 7", L-80, 26~, PCT @ 11006' MD; 4-1/2", L-80, 12.6~, PCT Tail @ 11147' MD; 3-1/2", L-80, 9.2#, PCT Tail @ 12025' MD; 3-1/2", N-80, 9.2#, Tail @ 12272' MD Packers and SSSV (type and measured depth) Camco Bal-O SSSV @ 2173' MD; Baker DB pkr @ 11022' MD; FB-1 pkrs @ 11917' & 12016' & 12111' & 12261' MD (5 packers total). 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation .... 0 -- 1800 Subsequent to operation .... 25000 -- 1700 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. / ~'-"~-- Title Engineering Supervisor Date Signed Form 10-4C~C{evj 06/15/88 c~ II~I~IIT I1~1 1'31 1131 I~./~,TI: ~-//.~ I,,'C)C ,.-,,,.,. (3%AI I%AID 9-16i Sundry Attachment: Perforation Data Open Perforations above Tubing Tail Plug set at 12004' MD: 11810 - 11910° MD (Z4) 8649 - 8719' TVD Ref Log: BHCS 9/28/77. Open Perforations isolated below Tubino Tail Pluoi's): 11942 - 11986' MD (Z4/3) 12005 MD: 1 shot (Z3) 12010 MD: 1 shot (Z3) 12040 - 12105' MD (Z3/2) 12140 - 12186' MD (Z2) 12220 - 12248' MD (Z2) 12298 - 12333' MD (Z2) 12350 - 12370' MD (ZIB) 12375 - 12395' MD (ZIB) 8742 - 8773' TVD 8786' TVD 8790' TVD 8811 - 8857' TVD 8881 - 8914' TVD 8938 - 8958' TVD 8993 - 9017' TVD 9029 - 9043' TVD 9047 - 9061' TVD Ref Log: BHCS 9/28/77. RECEIVED A!aska Oil & Gas Cons. Anchorage 9-16i DESCRIPTION OF WORK COMPLETED CTU MUD ACID WASH / STIMULATION TREATMENT 12/3/92: RIH & tagged PBTD at 12121' MD. 2/7/93: RIH & set a blanking plug in the 3.5" tubing tail at 12004' MD. 2/21/93: Removed asphaltene & particulate solid damage from the perforations, as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/CT while displacing the wellbore w/1% NH4Cl Water, then reciprocated a stimulation across the open perforations located above the tubing tail plug, at: 11810 - 11910' MD (Z4) Ref. Log: BHCS 9/28/77. Pumped: a) 182 bbls of 66% Diesel/33% Xylene, followed by b) 120 bbls 15% HCl w/additives @ 2.2 bpm, followed by c) 240 bbls 12% HCl- 3% HF, followed by d) 1% NH4Cl Water Flush, while POOH w/CT. Maintained injection down CTU x 7" annulus during the treatment, w/900 bbls of 1% NH4CI, & returned the well to produced water injection immediately after pumping acid. Rigged down. Obtained a valid injection test. RE E VE ^Iaska Oil & Gas Cons. Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-15-92 REFERENCE: 2-9 2-16 2-26 2.31 '3-11 3-13 4-3 4-40 4-42 6-18~ 7-3 9-3 ~ 3-25-92 Prod Profile Run 1, 5" Camco 4-28-92 Prod Profile R-n 1, 5" Camco 3-25-92 Prod Proffie R-n 1, 5" Camco 4-28-92 Prod Pr0tile Run 1, 5" Camco 4-4-92 InJ Profile R-n '1, 5" Camco 4-4-92 InJ Profile R.n 1, 5" Camco 4-6-92 Prod Profile R~_m 1, 5" Camco 4-7-92 GR/CCL/Jewelry R-n 1, 5" Camco 4-27-92 Static Temperature R-n 1, 5" Camco 3-31-92 PITS ~ R-n 1, 5" Camco 4-7-92 Prod Profile RI~n 1, 5" Camco 3-25-92 Prod Profile RI!n 1, 5" 'Camco 4-25-92 [nj Profile Ru_n 1, 5" Camco 4-11-92 Collar R-- 1, 5" Camco 4-16-92 [nj Profile R.n 1, 5" Camco 3-27-92 Prod Profile Run 1, 5" 'Camco 3-26-92 Leak Detect R~_m 1, 5" ,Camco 3-31-92 Prod Prof/Leak Detect Run 1, 5" Camco 4-12-92 Jewelry Run 1, 5" Camco Please sign and return the attached copy as receipt of data. RECEIVED _ . ECEIVED Have A Nice Dayi Sonya Wallace APPROVED Alas~,"G-~s Cons. Commission ATO-1529 Trans# 92099' F~'-A'Tmh°rage # CENTRAL FILES # CHE~ON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBm # ~LIPS PB WELL FILES R&D # BPX # STATE OF ~KA TEXACO ALASKA' AND GAS CONSERVATION C£ -'IlSSIOI~T REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-16i 9. Permit number/approval number 77-37 10. APl number 50 - 029-20257 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12589 feet 9195 feet Plugs(measured) T. Tail Plug @ 12248' MD Effective depth: measured 12546 feet true vertical 9165 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 258 sx AS II 100' 100' Sudace 2673' 13-3/8" 3100 sx CIG 2727' 2727' Production 11316' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' 8345' Liner 1518' 7" 520 sx CIG 11070-12588' 7542-9195' Perforation depth: measured See attached. true vertical See attached. Tubing (size, grade, and measured depth) 7", L-80, 26#, PCT @ 11006' MD; 4-1/2", L-80, 12.6#, PCT Tail @ 11147' MD; 3-1/2", L-80, 9.2#, PCT Tail @ 12025' MD; 3-1/2", N-80, 9.2#, Tail @ 12272' MD Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2173' MD; Baker DB pkr @ 11022' MD; FB-1 pkrs @ 11917' & 12016' MD 13, Stimulation or cement squeeze summary RECEIVED 14. Intervals treated(measured) See attached. Treatment description including volumes used and final pressure ~A¥ 1 ~_ 1992 Reoresentative Daily Average Production or Irlie~l~{[' "",A,,,,hnl.agt~' OiI-Bbl Gas-Md Water-Bbl Casing Prer~'~¥~' Tubing Pressure Prior to well operation .... 25000 -- 1575 Subsequent to operation 20000 -- 1650 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. ~grr~e~0_4~15~/8~ ~ Title Sr. Area Operations Engineer Date z~/~/~ ~ SUBMIT IN DUPLICATE 0,'34 IO I%AIO ,-,r,. OTAI ITAIR 9-16i DESCRIPTION OF WORK COMPLETED SELECTIVE STIMULATION w/INFLATABLE PACKER 1 2/29/91: RIH & set DGLV's in stations 3 & 4, and set a plug at 12248' MD, in the lower 3-1/2" tubing tail, to isolate lower perforation intervals in the well in preparation for stimulation. Rigged down. I 2/31/91: A Selective Mud Acid Stimulation, was performed as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/CT mounted Inflatable Bridge Plug, & set plug at 12000' MD, in the upper 3-1/2" tubing tail. PT packer, then selectively treated the perforations at: 12028 - 12040' MD (Z3: squeezed) Ref. Log: BHCS 9/28/77. 12040 - 12080' MD (Z3: open) 12080 - 12090' MD (Z3: open) 12090 - 12100' MD (Z3: open) 12100 - 12105' MD (Z2: open) Pumped Stage 1: a) 35 bbls of 12% HCI w/10% Xylene, followed by b) 71 bbls 12% HCI- 3% HF, followed by c) 103 bbls 2% NH4Cl Overflush, followed by d) 15 bbls 2% NH4CI w/1% surfactant & 3900 scf/bbl Nitrogen, followed by e) 5000 scf injected Nitrogen, followed by f) 15 bbls 2% NH4Cl w/1% surfactant. Continued pumping Stage 2 by repeating Steps A thru F (listed above). Continued pumping Stage 3 by repeating Steps A thru C (listed above), followed by 15 bbls 2% NH4Cl Overflush. Displaced CT w/33 bbls of Meth-Water. Released inflatable packer & POOH w/packer. Rigged down. Returned well to produced water injection. 4/25/92: Ran Injection Profile indicating greater injection capacity was achieved into the stimulated intervals. Returned well to produced water injection & obtained a valid injection test. Note: The Tubing Tail Plug located at 12248' MD will be left in place to maintain isolation of lower perforation intervals (see attachment). DGLV's located in stations 3 & 4 will also be left in place to maintain isolation of straddled perforation intervals (see attachment). Perforation Depth Data: Well 9-16i MD' 11810-11910' (open) 11942-11986' (open) 11986-12005' (sqzd 12005': I shot (open) 12005-12010' (sqzd) 12010': i shot (open 12028-12040' (sqzd) 12040-12105' (open) The following intervals are isolated below the 12248' MD, or straddled off behind DGLV's: 12140-12186' (open) 12220-12248' (open) 12298-12333' (open) 12350-12370' (open) 12375-12395' (open) ,,TVD' 8649-8719' 8742-8773' 8773-8786' 8786' 8786-8790' 8790' 8803-8811' 8811-8857' Tubing Tail Plug set at 8881-8914' 8938-8958' 8993-9017' 9029-9043' 9047-9061' 822/8 ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 24, 1991 L. C. Smith Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage AK 99501-3192 Re: Application for Sundry Approvals. Dear Mr. Smith: Please find enclosed the Sundry Approval Application for Drill Site Well 9-16. Sincerely, · Gillespie Operations Superintendent ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Atv~f~ (3t)D3 C STATE OF ALASKA ALASKA ( AND GAS CONSERVATION CO! 'SSION APPLICA' ,ON FOR SUNDRY APl-rIOVALS 1. Type of Request: Abandon Suspend ,, ,, Alter casing Repair well 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 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM operation shutdown . Plugging Pull tubing Vadance 5. Type of Well Development Exploratory Stratigraphic Service Re-enter suspended well -- Time extension Stimulate Perforate Other X 6. Datum of elevation(DF or KB) 54° RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 9-16 9. Permit number 77-37 10. APl number 50 - 029-20257 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) None REC~~V~D 12. Present well condition summary feet Total depth: measured 12589 feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical 9195 feet measured 12546 feet true vertical 9165 feet Junk(measured) Length Size Cemented Gas Cons. Me~~Qpth True vertical depth 80' 20" 258 sx AS II 100' 100' 2727' 13-3/8" 3100 sx CIG 2727' 2727' 11370' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' 8345' 1518' 7" 520 sx Cl G 11070-12588' 7542-9195' measured 11810 - 11880', 11880 - 11910', 11942- 11986', 12005 - 12010', 12094 - 12105', 12140 - 12186', 12220 - 12248', 12298 - 12333', 12350- 12370', 12375 - 12395'. true vertical 8595 - 8631', 8631 - 8645', 8742 - 8773', 8787 - 8789', 8848 - 8856', 8881 - 8913', 8937 - 8956', 8991 - 9016', 9028 - 9042', 9045 - 9056'. Tubing (size, grade, and measured depth) 7", 4-1/2", 3-1/2", L-80, tbg w/tail @ 12026' Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2174'; Baker DB pkr @ 111022'; FB-1 pkrs @ 11918' & 12016'. 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation Continue on H20 injection only Oil 16. If proposal was verbally approved Lonnie Smith 7/22/91 Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signedf~.,~. Z~~ Title Operations Superintendent FOR COMMISSION H~E ONLY Cond~Zje~s of approval: Notify Commission so representative may witness '" Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- 15. Status of well classification as: Gas Suspended . Water Injector Original Signed By David W. Johnston Approved by order of the Commissioner Form 10-403 Rev 06/15/88 J.M. Heusser, PRB 24, 659-5102 Approved Copy Commissioner Date ~,,,//Z..~,//~' / I Approva, No. SU 'RIPLICATE DS 9-16i SUNDRY NOTICE APPLICATION ACTION PLAN DISCUSSION Small, Tubing X 9-5/8" communication is suspected. The 9-5/8" casing pressure tracks the tubing pressure. The 9-5/8" casing continues to remain competent. ACTION PLAN 1. Return well to water injection service only. 2. Perform quarterly 9-5/8" Mechanical Integrity Test to verify continuing casing integrity. 3. When magnitude of leak becomes large enough to detect, perform leak detection log to identify source of suspected Tubing X 9-5/8" communication. INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA INJECTION ORDER #4 DATE: '-~/2~ /~/ TIME: ::~- NOTIFIED BY: REASON: ~ ~ ~,7..-.-~,..~ AOGCC CONTACT: ~_-. ~".,.,. 7 -,' Injection Well ~-- /(,'/ Annular Communication per Rule 7 Requirements of Area Injection Order No. 4 DISCUSSION: Sundry Notice Req'd at this time? YES / NO SIGNED~D-'~-~Di~- - SUPPORT SUPT. cc: DS Supv. '- Sr. Well Supv, ',... FS Supt. '\ / Field Area Ops. Engr. '~,~nular Comm. Spec~ Verbal Not.-AOGCC --.. STATE OF ALASKA - ALASKA AND GAS CONSERVATION C¢ 'ISSION REPORT UF SUNDRY WELL OPP_r ATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X , 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 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) RKB 54 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-16 ,- 9. Permit number/approval number 77-37/90-351 10. APl number 50 - 029-20257 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12589 feet Plugs(measured) 9195 feet Effective depth: measured 12546 feet true vertical 9165 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 80' 20" 258 sx AS II 100' 100' Conductor 2727 13-3/8" 3100 sx AS cmt 2727' 2727' Intermediate 11370' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' 8345' Liner 1518' 7" 520 sx CIG 11070-12588' 7542-9195' Perforation depth: measured 11810-11880', 11880-11910', 11942-11986', 12005-12010', 12040-12100', 12094-12105', 12140-12186', 12220-12248', 12298-12333', 12350-12370', 12375-12395' true vertical 8595-8631', 8631-8645', 8742-8773', 8787-8789', 8812-8854', 8848-8856', 8881-8913', 8937-8956', 8991-9016', 9028-9042', 9045-9056 Tubing (size, grade, and measured depth) 7"; 4-1/2"; 3-1/2", L-80, tbg w/tail @ 12026' Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2174'; Baker DB pkr @ 11022'; FB-1 pkrs @ 11918' & 12016' & 12111' & 12261' 13. Stimulation or cement squeeze summary ~ 14. Intervals treated(measured) JUN ] Treatment description including volumes used and final pressure ~.0JJ.~ Gas Col~s, Representative Daily Average ~ or In!ection Data~tl3Cll0raglB OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 22000 1800 Subsequent to operation 220O0 1800 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~6t]'yvt/~ A ..~, .~/~:~{~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 El I K I I~1,.. SUBMIT IN DUPLICATE DS 9-16i PERFORATING SUMMARY OF OPERATIONS ARCO Alaska, Inc. perforated DS 9-16i in the Ivishak Sand of the Prudhoe Bay Unit on 4/19/91 (12040-12100' MD, ref. log BHCS 9/28/77). Produced water was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/lubricator tested to 1.2 times the maximum expected surface pressure. A summary of the work is below: Rig up perforating unit on 4/19/91 and pressure tested equipment to 3000 psi. Backflow gas onto wellbore to depress liquid level (WHP 1700 psi) Bleed off WHP to drain system for drawdown. SI well. shot 12080-12100' MD, 4 spf. POOH, 2 shots not fired shot 12060-12080 MD, 4 spf. shot 12040-12060' MD, 4 spf. Secured well. RD. Returned well back to injection. .... ~-- STATE OF ALASKA ..... ALASKA AND GAS CONSERVATION C( 'ISSION REPORT UF SUNDRY WELL OPI-r ATIONS 1. Operations performed: Operation shutdown __ Stimulate Pull tubing Alter casing 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM Plugging Perforate X Repair well Other 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) RKB 54 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-16 9. Permit number/approval number 77-37/91-117 10. APl number 50 - 029-20257 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12589 feet Plugs(measured) 9195 feet Effective depth: measured 12546 feet true vertical 9165 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 80' 20" 258 sx AS II 100' 100' Conductor 2727 13-3/8" 3100 sx AS cmt 2727' 2727' Intermediate 11370' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' 8345' Liner 1518' 7" 520 sx CIG 11070-12588' 7542-9195' Perforation depth: measured 11810-11880', 11880-11910', 11942-11986', 12005-12010', 12040-12100', 12094-12105', 12140-12186', 12220-12248', 12298-12333', 12350-12370', 12375-12395' true vertical 8595-8631 ', 8631-8645', 8742-8773', 8787-8789', 8812-8854', 8848-8856', 8881-8913', 8937-8956', 8991-9016', 9028-9042', 9045-9056 Tubing (size, grade, and measured depth) 7"; 4-1/2"; 3-1/2", L-80, tbg w/tail @ 12026' 13. Stimulation or cement squeeze summary 14. Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2174'; Baker DB pkr @ 11022'; FB-1 pkrs @ 11918' & 12016' & 12111' & 12261' ~ Intervals treated(measured) Treatment description including volumes used and final pressure Prior to well operation JUN 1 ? ]991 Alasle 0il & C0aaa . Representative Daily Average ~or Injection Dat?.~ll~)l,tl[~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 19000 1900 Subsequent to operation 30000 1950 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed i~:/~Q,A.~k~ '~, _/.~~~- Title Operations Engineering Manager Form 10-404 Rev 06/15/88 ~1 IIMInh Date ~/jZ/~[ , SUBMIT IN DUPLICATE DS 9-16i PERFORATING SUMMARY OF OPERATIONS ARCO Alaska, Inc. perforated DS 9-16i in the Ivishak Sand of the Prudhoe Bay Unit on 6/23/90 (12076-12080), 12090-12100' MD, ref. log BHCS 9/28/77). Produced water was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/lubricator tested to 1.2 times the maximum expected surface pressure. A summary of the work is below: Rig up perforating unit on 6/23/90 and pressure tested equipment to 3000 psi. Backflow gas onto wellbore to depress liquid level (WHP 1750 psi) Bleed off WHP to drain system for drawdown. SI well. shot 12090-12100' MD, 1/2 spf. shot 12076-12080' MD, 1/4 spf. Secured well. RD. Returned well back to injection. DATE: 5-24-9t REFEI:(ENCF: ARCO CASED HOLE FINALS ,:.t6 2-24 6-~3 9-4 9-8 9-.16 " 9-t7 t2-t6 13-? t 3-28 4-28-9t PROD. F'ROF. RUN 4-28-9t" ': PROD. F'ROF.- ....... RUN 5-5-9t PROD. F'ROF. RUN 5-5-9t ...... LEAK DETECT, RUN 4-30-9t GR RUN t 5-6-91 ................... -IN J: PROF, ...................................................... .- RUN-t 4--25-?t INJ. F'ROF. RUN t 4-25-9t IN J. PROF. RUN 4-1 8-9t PROD. F'F;:OF:'. RUN 4-t7-9t ":-' LFAK DETECT, RUN 5-2."-9~ F'ROD. F'F;:OF',-'C;AS LIFT RUN 1 5'"4"'91 ....... LEAK DE'FEC. T. RUN 4-1 7-9t GAS ENTRY RUN COPY AS RECEIF"r OF' DATA PLEASE SIGN AND RETURN THE ATTACHED 5' 5m 2'& 5' 5" -' 65' 9 ' & 5" CAMCO C~MCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO RECEIVED BY ........................................ '-- ' ................ HAVE A NICE DAY! ..................... _It' ~ONYA WALLACE .... ' ..... ' ........ -~::"'-'- AF:'F'ROVE:I) ATO-t 529 'FRAN,S':~ 9t ...... /...i ;: "' ,', .,. . ', . . ......... DISTRIBUTION .... :.':CENTRAL FILES · "'.,,- CHEVRON · .-'"' EXTENTION" EXF'LORATION ~ EXXON MARATHON ..................... ¢: MOBIL . ¢ F'HILL. I F:'S "F'B 'WELL FILES ........... R & D -.." BF'X ......... STATE: OF ALASKA TEXACO I::.'. E F i.:.: R':'"i"': c · . I:~ ........ ARCri CASED HOLE F:iNAL;~; L..E ~:~ K £) F !' F: C '!" .[ 0 N C 0 l.. t... A F,.'. / P Iii: F: F' I N J E C T i 0 N C 0 l.. t... A R /t::' E R I= (] A ;~"., L..[ F:' '~" i"~ A F.,. D R E.',... .1:',.. ,...,:' ...,c',,,., ,,~. ,.. F' E: R I::' F.'. E C: 0 R D CIJI'...~ "'" '"'J" "" .... I..~l",.,' I" ,:: r,..l.' I N J I.':. C T ]i O :.:';OL.~ ,..., ,. ..... .... :--it"..., !" I::.h.J" i:" R O I..~ U L: '~." 1 0 F:' R O D Li ii:: T I O N CC:L P R O D LJ C '71" I O N' CCL. F' F..' 0 D LJ C T ! O N C 0 l.. l.. A F;..' / F:' liil I::.: F:' !.. I: k I.' R E C 0 R D F:' E R F' R Iii: ti:: O R D I NJEC'i" I ON ........ I N J E C T I O N fl.:UN I-,.: U I"..I. ~:~.'.t.JN F< U t-..! i:( t..~ r..~ J:,: I..J !:,: U i".l I.;.'. U N t:( U R LIN R tJ N i:(U N l'( U N R LJ N R U N R U N I.;t U N R U N F'L. EA;S'Ii:.: ;SIGN AND RETURN 'i'HE AT i'r;:~L;I-4,1:"D COF:'Y AS F;.'IEClii:.[F:"r OF:' DA'l" RIECIEIVEI) BY ,~._.b~ · 'i A V t":: A i"..! ! C IT !:; A Y ! D I ,S' '¥ R I B lJ '/" I 0 N · ir "'~ :,": C E N 'r R A L. F I !_ E,.'~ "' P I..! .[ I.. L. I I.. ,., " .......' F' B W E: I..I.. F I t.. E $ -,,-"" ,., H I=. '9 R 0 N D & M R & D .,,."" E X T E N 5' I O N E X F L 0 R ~:l T I 0 N .,.'"' B t::' X. · "' ,S 'i" A'l" E O F' A L A;S' K A · ..E X X 0 N .~,J: · .,, j.... MAF;.'.ATHON 'f' E;~.A ~.0 :~: M 0 B I L. A ~ _. .... STATE OF ALASKA --- [,.i i~ ~, :- ALASK,~ AND GAS CONSERVATION CL. 'ISSION APPLICA 'ION FOR SUNDRY AP -ROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Pe~fo~/lte X Othe~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED APR 1 2 1991 .0il & Gas Cons. uummissi~ Anchorage 6. Datum of elevation(DF or KB) 54 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-16 9. Permit number 77-37 10. APl number ~r~ 50-029-20257 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12589 feet Plugs(measured) 9195 feet Effective depth: measured 12546 feet true vertical 9165 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 80' 20" 258 sx AS II 100' 100' Conductor 2727' 13-3/8" 3100 sx AS cmt 2727' 2727' Intermediate 11370' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' 8345' Liner 1518' 7" 520 sx CIG 11070-12588' 7542-9195' Perforation depth: measured 11810-11880', 11880-11910', 11942-11986', 12005-12010', 12094-12105', 12140-12186', 12220-12248°, 12298-12333', 12350-12370', 12375-12395' true vertical 8595-8631', 8631-8645', 8742-8773', 8787-8789', 8848-8856', 8881-8913', 8937-8956', 8991-9016', 9028-9042', 9045-9056' Tubing (size, grade, and measured depth) 7"; 4-1/2"; 3-1/2", L-80, tbg w/tail @ 12026' Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2174'; Baker DB pkr @ 11022'; FB-1 pkrs @ 11918' & 12016' 13. Attachments Description summary of proposal 14. Estimated date for commencing operation April 1991 16. If proposal was verbally approved Name of approver Date approved x Detailed operations program I 15. Status of well classification as: Oil Gas Suspended Service x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed..~i'¥¥t&~./~-t"~, ,~/¥~ Title Senior Area Engineer FOR COMMISSION U~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- BOP sketch x Date ~--~/(~/~/ Approval No?./ --//7 Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LON~IF ~,, ,qMITI-I ApproVe~n~-Op¥ Retu . e.~ Co~/Date II P~/P~.q.q/nh SUBMIT IN TRIPLICATE..~_~ DS 9-16i PROPOSED PERFORATIONS APl # 50-029-20257-00 PERMIT # 77-37 ARCO Alaska, Inc. proposes to add perforations in DS 9-16 within the Sadlerochit Sand from the Prudhoe Bay Unit. The proposed perforation intervals are as follows: BHCS (Ref.) CNL Footage Flow (9/28/77) (10/3/801 ('MD) SPF Unit Zone 12040-12100 12040-12100 60 4 Victor 2 Well 9-16 is a produced water injector. The wellbore fluid present when the pedorations will be shot is water. The expected bottom hole pressure is 3650 psi. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure (diagram attached). RECEIVED APR 1 2 t991 Alaska Oil & Gas Cons, CommissiO~ Anchorage 3 i [ ~' / 1. '5000 PS1 7" WELLHEAD CONNECTOR F'LANOE 2. 5000 PS1 WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF RECEIVED APR 1 2 t99t Alaska Oil & Gas Cons. C;omm~sS~On Anchorage HIRELINE BOP EQUIPMENT I i llll! ARCO ALAS'KA, INC. P,.O~ BOX ~00~60 ANCHORAGE, ALASKA 995~ DATE ' 7-7-90 RE]F'EF:.:EiNCE' ARCO CASED I-.IOI_IZ r-:INA/..2 i - i 2 ": "':' '''~ - ':;' ;:" C 0 L_ L A R R I I N ~..,.* "" :.;. '"Y : ;..- ... 'i-.28 6-'i~-"?0 DSN (2 't/8') RIJN ~., i ---":' '=.': 6 .... i i - '>,':'; D 2 N ,' '.~, .3 / 8" '~ R t.I N i , oco~._ : :.. .. ,... . ., · 2.-28 6 .... 9 .... ;:'0 DSN ,":'~ '1 .."f->," ", RUN 'i 2 .... 26 6-9-90 D,S:N (.¥ :3/8') RUN 'i , ,'.--.-.,~ .a ·7---2-90 Cf'ti LAR F;:JN 'i , 9 .... ~ 6 .ii-2¥-90 F'FF.:F' RECOF,'D Rt. N 'i , 'i 2-'i 7- 'i --9".'3, COI_L_AF;.: RUM i: i 4-6 6-S0-'90 CC:L,"PE;F::F' RECORD F.:UN i , i 4--'i 6 6-29-90 CCL/PIFF.:f'-" RECUF;.:D RUN 'i . · i 6-6 ,.6---2':.5-90 COLLAR RUN i , F'I_EA;5..?E SIGN AND RE'FURN 'I'HE A r'f'A~~OF'Y A3': RECFiF'I' OF' DATA. ED c: Ii:' ]: v e-,' ¥ ........... P.. t V blAVF-£ A NICE DAY! dui,... ] 0 1990 :_? A L.. L Y H O F'F E C K E R Alaska 0ii & Gas Cons. uum¢~ssiOr~A F' P t:;: O V E I) ~.. -- A "I- 0 -.- i '5 "..-' 9 AlqC,hOfaO~ 't' R A iq ;!;' :~- 9 ,:~. "? S A 'F L F-ti...::'.: H i... ;!? 1.4, L. ::..7 I.'i i... ;'.:.' A f'I_A;? ,5:01.~, A f'l_ A£' A 'f' L A Z-': ~ 'f'l._ A 2: DISTRIBU] ION ">- CENTRAL F r LE.";' "~ PHII_L IF'£' -.-~ CHEVRON PB t/ELL F']:I_ES D & M F,' * D ~: EXTENSION EXF'LORATZON ql: BPX :~ EXXON '~-'"':!;'TA"FE OF ALA::?KA MARATHON 'f'IEXACO ~- MOBIL STATE OF ALASKA ALASF'-' i AND GAS CONSERVATION -* "~' 'ISSIQI~I p ~ G ~ J~ j~ j.(~~.% APPLIC,. TION FOR SUNDRY_ 1. Type of Request: Abandon Suspend Operation shutdown Alter casing Repair well Plugging Change approved program Pull tubing Variance 2. Name of Operator 5. Type of Well Development ~ ARCO Alaska, Inc. Exploratory ~ 3. Address Stratigraphic P.O. Box 100360, Anchorage, AK 99510-0360 service X 4. Location of well at surface 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 12589 feet Plugs(measured) 9195 feet Re-enter suspended well Time extension Stimulate Perforate X Other ,, 6. Datum of elevation(DF or KB) 54 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-16 9. Permit number 77-37 10. APl number 50 - 029-20257 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured true vertical Casing Length Structural 80' Conductor 2727' Intermediate 11370' 12546 feet 9165 feet Junk(measured) !;~<.~ Gii & Gas Cons. Com.~aissiuu , ~,[i.c. hora(~ size Cemented Measured depth True vertical depth 20" 258 Sx AS II 100' 100' 13-3/8" 3100 sx AS cmt 2727' 2727' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' 8345' Liner 1518' 7" 520 sx CIG 11070-12588' 7542-9195' Perforation depth: measured 11810-11880', 11880-11910', 11942-11986', 12005-12010', 12094-12105', 12140-12186', 12220-12248', 12298-12333', 12350-12370', 12375-12395' true vertical 8595-8631', 8631-8645', 8742-8773', 8787-8789', 8848-8856', 8881-8913', 8937-8956', 8991-9016', 9028-9042', 9045-9056' Tubing (size, grade, and measured depth) 7"; 4-1/2"; 3-1/2", L-80, tbg w/tail @ 12026' Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2174'; Baker DB pkr @ 11022'; FB-1 pkrs @ 11918' & 12016' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation May 1990 16. If proposal was verbally approved Oil Gas Name of apl)rover Date al)proved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~~ ~. ~_r~~" Title Senior Area Engineer FOR COMMIS~c;ION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- /'J¢'~/ ORIGINAL ,.SIGNED BY LONNIE C. SMITH Approved by order of the Commissioner Form 10-403 Rev 06/15/88 I I /~_//'~_~'1~.~1~ 15. Status of well classification as: Suspended __ App[uvud Cupy Returned -Izz_lqO Date .'~"/~//q(¢) lApprOval N°F(~--~ Commissioner Date ~'"- ~'-~:~O SUBMIT IN TRIPLICATE DS 9-16i PROPOSED PERFORATIONS AP1 # 50-029-20257-00 PERMIT # 77-37 ARCO Alaska, Inc. proposes to add perforations in DS 9-16 within the Sadlerochit Sand from the Pruclhoe Bay Unit. The proposed perforation intervals are as follows: BHCS CNL Footage (9/28/77) (10/3/80) ('MD/SS) 12076-12080 12076-12080 4/3 12090-12100 12090-12100 10/7 Reference Log: BHCS (9/28/77) Well 9-16 is a produced water injector. The wellbore fluid present when the perforations will be shot is water. The expected bottom hole pressure is 3650 psi. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure (diagram attached). 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) .3.5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF 2 HIRELINE BOP EOUIPHENT i ARCO Alaska, In~' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 10, 1990 Mr. John Boyle Alaska Oil and Gas Consepvation Commission 3001 Porcupine Ddve Anchorage, Alaska 99501 Dear John: Please cancel the following 14 Forms 403 for which no Forms 404 were written. Per the drill-site engineers, this work has not been done and is no longer planned. D,S. Apor. Vt Date Signed 1987 1988 3-4 7-51 1/26/87 4-6 7-263 4/20/87 4-10 7-188 3/20/87 4-10 7-238 4/8/87 4-14 7-264 4/20/87 5-8 7-624 9/23/87 9-16 7-291 4/27/87 14-13 7~399 6/18/87 14-30 7-100 2/13/87 16-24 7-117 2/26/87 3-9 8-826 11/2/88 3-13 8-854 11/17/88 6-13 8-316 4/28/88 9-34 8-864 11/21/88 Please call me at 263-4310 if you have any questions concerning these Sundr,es. S, T. H/Cfecke~p7 Reco4'ds Pro~ssor STH/ab/034 J. L. Glaeser - ATO 1528 ¢ CC: RECE!VED' . ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany APR 1 It 1990 ARCO ALA~'KA, INC~ F'.O· BOX i06,360 0 r.- .% ANCHORAGE, ALASKA .9:-i~ DATE' t~-8-87 ° REFERENCE' ARCO CASED HOLE FINALS -3 8-i3-89 F'ERF RECORD RUN t , 5' -3 8-t 6-89 PERF RECORD RUN i , 5' i-:~'~..,, i(-)-:~".'-8~;'~.. , DZN (2 i/8") RUN i, '~ - RUN t , 5' ~5 t~ 2'~-89 D~N rS 3/8') -26 t0-2t-89 DSN (3 3/8 ") RUN ~r 8 t'~ 89 F'ERF RECORD RUN:~ i&2 5 ~"i r ~. t4-89 PERF RECORD RUN 9-t6 9-4-89 F'tERF RECORD RUN 6-24 8-7-89 F'ERF RECORD RUN t , 5" F'LEA:~E &"I(.;N AND RETIJRN 'THE ATTACHED COPY A,*.; RECEIPT OF DA'FA, ' RE,..,E ]: VE:D BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i~29 DISTRIBUTION CENTRAL F I LE.~ CHEVRON · D & M EXTEN~'ION EXPLORATION EXXON "ir MARATHON ~ MOBIL '" PHILLIPS' PB WELL FILES R & D '"' BPX ' STATE OF ALAS'KA -ir '- TEXACO ARCO ALASKA, INC. P.O. BOX i0~36~ ANCHORAGE, ALASKA 995t0 DATE' i¢-~0-89 REFERENCE · ARCO CAS'ED HOLE FIN,~I_~ i-4 t,~-t3-89 F'RODUCTION PROFILE I:;:UN t, ~ -6 t ~-'2'2-89 CNL-GR RUN t , i -6. i 6,-''~ i -89 F'DK- i ~,~/GR/CCL RUN ~-~6 ~-~6-89 PRODUCTION PROFILE RUN ~, ~--~7 ~--~9-89 PERF RECORD RUN ~, ~-2S t(D-2~-89 CNL-GR RUN ~ , ~ ,_q-.,. ~ (~-~ 5-89 F'RODUCTION F'ROFILE RUN ~ , I- KUDUUTION PROFILE RUN i -°6 t ~3-t 5-89 "" .... i-29 i~-'i4-89 F'RODUCI'ION F'ROF'ILE RLJN i , 2-S i ~-i 8-89 CNL RUN 2, 2-'i2 i~-i6-89 I'EMF' SURVEY RUN i , 2-2S i ~-'2S-89 CNL-GR RUN t , 4'-'c. 1~ i ~-'25-89 CNL'-GR ' RUN i , 4-52 - l ~-'2~-89 F'DK-i ~6,/GR/CCL RUN t , ~7-i3 i~-i6-89 PRODUCTION F'ROFILE RUN i , ~9-'5 i(D i i-89 PRODUCTION PROFILE RUN 9-i6 i~-'ii-89 INJECTION F'ROFILE RLJN i, - - - ~u gl'ION PROFILE RUN i, ti i2 i~ 7-89 F'R~ .... U! i i -i S t (3-i 5-89 TEMF' RUN i t4-25 1~-i4-89 COMPLETION RECORD RUN i i6-ii i~-i~-89 LEAK DETECTION RUN i, -~t 6-2() i ~-4-89 TEMF' RUN i, i7-4 i¢'-i4-89 PRODUCTION F'ROFILE RUN i, i 8-i 6 9-i 8-89 PITS RUN t , Pt_EASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT [.IF' DATA, RECEIVED BY HAVE: A NICE DAY! SALLY HOFFECKER ATO- ~ 529 ~' · CAMCFi ~ · A ['LA~. .5" ATI...A,S' 5" C A M C 0 ~'" SCH ~" Al'LAS ::" C A M C 0 5 · C A M C ti 5" C A M C 0 5' SCH 5" CAMCO 5 ' ATLAS 5 ' ATLAS 5 ' ATLAS 5" CAMCO 5" CAMCO 5" CAMCO 5" CAMCO 2"&5" CAMCO 5" SCH '2 ' C A M C 0 5" CAM(](] 5" C A M C 0 5 ' CAMCO * THE CO]RE ** THE CORRE *** THE CORRr--" DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION ~ BF'X EXXON ~'~ STATE OF ALASKA C IV CTED AF'I:~ FOR i4-2S IS 50'-(:)29-2~757 CTEI) AF'I$ FOR i6-i t ].$ 5('~-¢329-2'~5i6. Anchorage STATE OF ALASKA ALASK,~ .... .. AND GAS CONSERVATION CC fiSSION /'~ REPOR'I SUNDRY WELL OF. ,tATIONS0 R I G I Operation shutdown , Stimulate ~ Plugging Perforate X Pull tubing Alter casing ~ Repair well ~ Other 1. Operations performed: 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-16 9. Permit number/approval number 9-769 10. APl number 50 - 029-20257 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 12589 feet Plugs(measured) 9195 feet Effective depth: measured 12546 feet true vertical 9165 feet Junk(measured) Casing Length Size Cemented Measured depth Structural 80' 20" 258 sx AS II 100' Conductor 2727' 13-3/8" 3100 sx AS cmt 2727' Intermediate 11370' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' Liner 1518' 7" 520 sx CIG 11070-12588' True vertical depth 100' 2727' 8345' 7542-9195' Perforation depth: measured 11942-11986', 12005-12010',12094-12105', 12140-12186', 12220-12248', 12298-12333', 12350-12370', 12375-12395', 11810-11910' true vertical 8742-8773', 8787-8789', 8848-8856', 8881-8913', 8937-8956', 8991-9016', 9028-9042', 9045-9056', 8595-8666' Tubing (size, grade, and measured depth) 7"; 4-1/2"; 3-1/2", L-80, tbg w/tail @ 12026' Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2174'; Baker DB pkr @ 11022'; FB-1 pkrs @ 11918' & 12016' 13. Stimulation or cement squeeze summary ~ ~ V ~ Intervals treated(measured) Treatment description including volumes used and final pressure SEP 2 1989 AJaska 0il & Gas Cons. Commission 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure /~/CO 0 //,~ 0oo Anchorage Tubing Pressure 7.5"'0 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. l Signed 2~~.,~~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 SUBMIT fN D/UPLICATE DS 9-16 PERFORATING SUMMARY OF OPERATIONS Began perforating operation on 9/4/89. SI well, RU perforating unit, pressure tested equipment. Back pressured with AL gas. RIH with gun #1, open up well and perforated interval 11890- 11910' MI) (1/4 spf), flowed well to cleanup. SI well, POOH, all shots fired. Back pressured with AL gas. RIH with gun #2, open up well and perforated interval 11880-11890 MD (1/4 spf) and 11870-11880' MD (1/2 s@f), flowed well to cleanup. SI well, POOH, all shots fired. Back pressured with AL gas. RIH with gun #3, open up well and perforated interval 11850-11870' MD (1/2 spf), flowed well to cleanup. SI well, POOH, all shots fired. Back pressured with AL gas. RIH with gun #4, open up well and perforated interval 11830- 11850' MD (1/2 spf), flowed well to cleanup. SI well, POOH, all shots fired. Back pressured with AL gas. RIH with gun #5, open up well and perforated interval 11810-11830' MD (1/2 spf), flowed well to cleanup. SI well, POOH, all shots fired. Secured well, RD, retumed well to injection. RECEIVED SEP 2 9 t989 Alaska Oil & Gas Cons. Commission Anchorage _ ~ .... STATE OF ALASKA ~" " ALAS~ '~-. _ AND GAS CONSERVATION ¢ - ' 'ISSION REPOR , OF SUNDRY WELL OP I-t:ATIO 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 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395' FEL, Sec. 3, T10N, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 54' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-16 9. Permit number/approval number 9-769 10. APl number 50 - 029-20257 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 12589 feet Plugs(measured) 9195 feet Effective depth: measured 12546 feet true vertical 9165 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 80' 20" 258 sx AS II 100' 100' Conductor 2727' 13-3/8" 3100 sx AS cmt 2727' 2727' Intermediate 11370' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' 8345' Liner 1518' 7" 520 sx CIG 11070-12588' 7542-9195' Perforation depth: measured 11942-11986', 12005-12010',12094-12105', 12140-12186', 12220-12248', 12298-12333', 12350-12370', 12375-12395', 11810-11910' true vertical 8742-8773', 8787-8789', 8848-8856', 8881-8913', 8937-8956', 8991-9016', 9028-9042', 9045-9056', 8595-8666' Tubing (size, grade, and measured depth) 7"; 4-1/2"; 3-1/2", L-80, tbg w/tail @ 12026' Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2174'; Baker DB pkr @ 11022'; FB-1 pkrs @ 11918' & 12016' 13. Stimulation or cement squeeze summary Intervals treated(measured) S~P Treatment description including volumes used and final pressure 0i~ & 14. Representative Daily Average Production or mi~ction Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation /&~ Ooo '7~'O Subsequent to operation / ~,j Oo 0 7,~" 0 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas Suspended Service X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /i¢~~J~ Title Operations Engineering Manager Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE DS 9-16 PERFORATING SUMMARY OF OPERATIONS Began perforating operation on 9/4/89. SI well, RU perforating unit, pressure tested equipment. Back pressured with AL gas. RIH with gun #1, open up well and perforated interval 11890- 11910' MD (1/4 spf), flowed well to cleanup. SI well, POOH, all shots fired. Back pressured with AL gas. RIH with gun #2, open up well and perforated interval 11880-11890 MD (1/4 spf) and 11870-11880' MD (1/2 spf), flowed well to cleanup. SI well, POOH, all shots fired. Back pressured with AL gas. RIH with gun #3, open up well and perforated interval 11850-11870' MD (1/2 spf), flowed well to cleanup. SI well, POOH, all shots fired. Back pressured with AL gas. RIH with gun #4, open up well and perforated interval 11830- 11850' MD (1/2 spf), flowed well to cleanup. SI well, POOH, all shots fired. Back pressured with AL gas. RIH with gun #5, open up well and perforated interval 11810-11830' MD (1/2 spf), flowed well to cleanup. SI well, POOH, all shots fired. Secured well, RD, returned well to injection. RECEIVED SF.? 1 1989 Alaska 0il & Gas Cons, G0ram'tssi0[~ Anchorage ARCO Alaska, In Prudhoe B~., ,-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager Au~st 28, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 9-16 Permit No. 77-37 Dear Mr. Chatterton: Attached, in triplicate, is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/GSS/ljm Attachment cc: J.S. Dietz, BP Exploration J. Gruber- ATO 1478 PI(DS9-16)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B 6132 C STATE OF ALASKA · ALASK --~. AND GAS CONSERVATION C ..... SSION APPLIC/. rlON FOR SUNDRY Ai--PHOVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well Plugging Time extension Stimulate Change approved program Pull tubing Variance Perforate X "'1 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 877'FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UM At effective depth 1553' FSL, 1395'FEL, Sec. 3, T10N, R15E, UM At total depth 1561'FSL, 1425'FEL, Sec. 3, T10N, R15E, UM 12. Present well condition summary Total depth: measured true vertical 12589 feet 9195 feet Plugs(measured) Effective depth: measured 12546 feet true vertical 9165 feet Junk(measured) Othe'r 6. Datum of elevation(DF or KB) 54 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-16 9. Permit number 77-37 10. APl number 50 - 029-20257 11. Field/Pool Prudhoe Bay Oil Pool Casing Length Size Cemented Structural 80' 20" 258 sx AS II feet Measu red de~prlt~?0[~rqu~e vert ica I depth 100' 100' Conductor 2727' 13-3/8" 3100 sx AS cmt 2727' 2727' Intermediate 11370' 9-5/8" 1000 sx CIG & 300 sx AS I 11370' 8345' Liner 1518' 7" 520 sx CIG 11070-12588' 7542-9195' Perforation depth: measured 11942-11986', 12005-12010', 12094-12105', 12140-12186', 12220-12248', 12298-12333', 12350-12370', 12375-12395' true vertical 8742-8773', 8787-8789', 8848-8856', 8881-8913', 8937-8956', 8991-9016', 9028-9042', 9045-9056' Tubing (size, grade, and measured depth) 7"; 4-1/2"; 3-1/2", L-80, tbg w/tail @ 12026' Packers and SSSV (type and measured depth) Camco BaI-O SSSV @ 2174'; Baker DB pkr @ 11022'; FB-1 pkrs @ 11918' & 12016' 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation September, 1989 16. If proposal was verbally approved 15. Status of well classification as: Oil Gas Suspended __ Name of approver Date approved Service 17. I hereby, certify that the foregoing is true and correct to the best of my knowledge. Signed 2Z~~2~ Title Operations Engineering Manager Date ~"/,~ Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNJE C. SMITH FOR COMMISSION H~E ONLY " IApproval No. ~,pproved CoPY Returne(~ C~oner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 9-16 PROPOSED REPERFORATIONS API # 50-029-20257-00 PERMIT # 77-37 ARCO Alaska, Inc. proposes to reperforate previously perforated intervals in DS 9-16 within the Sadlerochit Sand from the Prudhoe Bay Unit. The proposed perforation intervals are as follows: Interval, MD Footage. ft. SPF Zone 11810-11880 70 1/2 4 11880-11910 30 1/4 4 Reference Log: BHCS (9/28/77) Well 9-16 is a source water injector. The wellbore fluid present when the perforations will be shot is water. The expected bottom hole pressure is 3750 psi. All wireline work will be done through a 5000 psi WP BOP/lubricator, tested to 1.2 times the maximum expected surface pressure (diagram attached). 4 3 1. '5000 PSi 7" WELLHEAD CONNECTOR FLANO£ 2. 5000 PSi WlR£LIN£ RAMS (VARIABLE SIZE) ,,3. 5000 PS1 4 1/6" LUBRICATOR 4. 5000 PS1 4 1/6" FLOW TUBE PACK-OFF H l REL ] NE BOP EOU ] PHENT ADDENDUM WELL: 3/27/89 9-16 Cut 5½" tbg f/9-5/8" pkr. RU DA, tst BOPE to 3500 psi; OK. MU cutting tl, RIH to 10,850', cut 4½" tbg pup @ 10,780'. POOH. RD DA. Secure wellhead. Drilling Supervisor ANCHORAGE, ALASKA 995i (~ DATE' 7-i 6~-89 REFERENCE' 3-"':'6 3-34 3-34 4-t9 4-3 i 9-i6 ii-i i i-24 t3-6 t 4-27 i4-37 t 4-38 i6-9 PLEASE SIG ARCO CASED HOLE FINALS 6/23-24/89 6- i 4-89 .-i -89 6-i S-89 6-i 9-89 6- i 5-89 6-1 4-89 6- t 8-89 6- i 6-89 6-i 7-89 6-23-89 6-25-89 6-26-89 6-23-89 6-22-89 LEAK I)ETEC'Y'I ON PRODUCTION F'R'OF:' I t_E F'R. ODLJCTI ON PROFILE PRODUCTION F'i';,'O F .[ LE F'ITS INJEC'FION F'F(OF I LE I'EMP INJECTION F'ROF II_E PRODUCTION PROFILE PRODUCTION PR'OFILE INJECTION PROFILE F'RODUCTiON F'ROFILE PRODUCTION PROFILE PRODUCTION PROFILE F'RODLJCTI ON F'ROFILE 14.' L; N i, RU,W. i, 5" R l.J i'.,l, i , ~_," I:;:IJNi, 5" RUN i, 5" RUN i, 5" RtJN i , 5" RUN i , 5" RUN i, 5" RUN t, S' RUN i , S' RUN t , S' RUN i , 5' RUN I, S' RUN i , S" N AND RE I'~JRN THE ATTACHED COPY AS NECEIPT OF DATA C A ri C: O L; A f'i I.j LJ C A M C C A ~'"i C r) C rq il C O C ¢4 f"i C 0 C A iq C 0 C A m C O ....... tJ A ¢1 L: U CAMCO CA~CO [;AMC(] CAMCO CAHCO RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO- ~ 529 ~ --'~'"rRANS~- 89~§Z- CENTRAL FILES CHEVRON D &~M ":~'-:~"::" ·" EXTEN£ION EXPLORATION EXXON - .:' '-- MARATHON' - MOBIL :': F'.H ILL IF'S PB WELL FILES R & D BF'X Si'ATE OF ALASKA 'i"EX¢~CO .. STATE OF ALASKA ~ ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well Water Injector OIL :-~ GAS [] SUSPENDED ~J ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 77-37 3. Address 8. APl Number P,0. Box 100360, Anchorage, AK 99510-0360 50- 029-20257 4. Location of well at surface 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UN At Top Producing Interval 1414' FSL, 868' FEL, Sec. 3, T10N, R15E, UN At Total Depth 1561' FSL, 1425' FEL, Sec. 3, T10N, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 54' I ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 09/08/77 09/28/77 10/07/77* 17. Total Depth (MD+TVD) 12589' MD/9195 'TVD 18.Plug Back Depth (MD+TVD) 12546'MD, 9165'TVD 19. Directional Survey YES [] NO [] 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-16 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool 15. Water Depth, if offshore 116. No. of Completions N/A feet MSL/ 1 20. Depth whereSSSV set I 21. Thickness of Permafrost 2174' feet MDI 1900' (approx.) 22. Type Electric or Other Logs Run D I L/SP/BHCS/GR, GR/CNL/FDC/Cal , GR/CNL/CCL/FDC, GR/CBL/CET/CCL, Nu] ti shot 23. CASING, LINER AND CEMENTING RECORD CASINGSlZE WT. PER FT. GRADE HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 32" 13-3/8" 72.0# MN-80 17-1/2" 9-5/8" 47.0# S00-95 12-1/4" 7" 27.0# L-80 -- SETTING DEPTH MD TOP BOTTOM Surf 100' Surf 2727' Surf 11370' 10070 ' 12588 ' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. 258 sx Arctic Set I1 3100 sx Arctic $¢1; 1000 sx Class G & 300 sx 520 ~x Class G Liner 1 ap squeezed (See TUBING RECORD AS I I rem 2~) interval, size and number) 11942' -11986'MD/8742 ' -8773 ' TVD 12005 ' -1 2010 'MD/8787' -8789' TVD 12094 ' -1 2105 'MD/8848 ' -8856 'TVD 12140 ' -1 2186'MD/8881 ' -8913 'TVD 12220 ' -12248 'MD/8937 ' -8956 'TVD 12298 ' -1 2333 'MD/8991 '-9016 'TVD 12350 ' -12370 ' MD/9028 ' -904 2 'TVD 12375 ' -1 2395 'MD/CjBb,~ ' -c~fl56 'TVr). 27. N/A DEPTH SET (MD) ! PACKER SET (MD) SIZE l"/q-1/2"/3-1/2"' 12026' 11022,,' 11918' & i201'~~ / 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED Liner lap & perfs f/ 1820'-12080' sqzd w/617 sx Class G PRODUCTION TEST Date First Production Date of Test Hours Tested Method of Operation (Flowing, gas lift, etc.) OIL-BBL IPRODUCTION FOR TEST PERIOD CALCULATED 24-HOUR RATE GAS-MCF WATER-BBL Flow Tubing Casing Pressure OIL-BBL GAS-MCF WATER-BBL Press. 28. CDR E DATA CHOKE SIZE I GAS-OILRATIO 0IL GRAVITY-APl (cor-~ Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED MAY 1 o 1989 *Note: Workover performed, sqzd perfs & reperf 4/22/89. The well was recompleted & reperf 5/10/85. Al~kB0il E Gas Cons. C0mmissi0r~ Anchorag~ Form 10~407 038/WC6 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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 117797 8628 ~ N/A OWC 12 z~:37 ~ 9089 Base Sadl er'ochit 124787 91187 31. LIST OF ATTACHMENTS None , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed- (, Title Regional Drilling EngrE)ate_ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: if this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (D.F, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 STATE OF ALASKA AL/kSKj~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown ~ Stimulate __ Plugging __ Pull tubing ~ Alter casing ~ Repair well __ Perforate __ Other Workover 2. NameofOperator ARCO Alaska, Inc. 3. A~d.~.SSBox 100360 Anchorage, AK 99510-0360 4. Location of well at surface 877' FSL, 175' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 1414' FSL, 868' FEL, Sec. 3, TION, R15E, UM Atle5¥~tiV~sCL~?tlh395' FEL, Sec. 3, T10,, R15E, UM At total depth 1561' FSL, 1425' FEL, Sec. 3, TION, R15E, UM 5. Type of Well: Development __ Exploratory ~ Stratigraphic ._~ Service ~ 6. Datum elevation (DF or KB) RKB 54 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 9-16 9. Permitnumbeflapprovalnumber 77-37/9-178 10. APInumber 50-- 029-20257 11. Field/Pool Prudhoe Bay 0il Pool 12. Present well condition sUmmary Total depth: measured true vertical Effective depth: measured true vertical 1 2589' MD feet 9195 'TVD feet 12546'MD 9165 ' TVD feet feet Plugs (measured) No ne Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 2727' 11370' 2518' measured true vertical Size Cemented Measured depth 20" 258 sx AS II IO0'MD 13-3/8" 3100 sx AS cmt 2727 'MD 9-5/8" 1000 sx Class G & 11370'MD 300 sx AS I 7" 520 sx Class G 10070'-12588'MD Liner lap squeezed (see Item 13.) 11942'-11986', 12005'-12010', 12094'-12105', 12140'-12186' 12220 ' -1 2248' , 12298 ' -12333', 12350 ' -12370 ' , 1 2375 ' -12395' 8742'-8773', 8787'-8789', 8848'-8856', 8881 '-8913' 8937'-8956', 8991 '-9016', 9028'-9042', 9045'-9056' True vertical depth 1 O0 ' TVD 2727 'TVD 8345 ' TVD 7542 ' -91 95 'TVD Tubing (size, grade, and measured depth) 7"/4-1/2"/3-1/2,,, L-80, tbg w/tail @ 12026' R cker~ n S (~as e deB , , , , ~Jmco "a~l-'~ ~geC~cil~, ~aekd~r ~'~ pkr ~11022 , 'FB-1 pkrs ~11918 &,,0,~ECEIVED 13. Stimulation or cement squeeze summary I 0terv, al.s.treate.d (me.asured.) ~qzo ~ner ~ap ~ perrs f/11820'-12080' Treatment description including volumes used and final pressure 617 sx Class G MAY l 0 1989 Alaska 0il & Gas Con~. C0mmissi0~ Anchorage 14. N/A Representative Daily Average 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 classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ,/ * Oil __ Gas__ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. [. Title Regional Drilling Engineer Signed rk°verForm 10-404 Rev 06/1~/81!~ [ Well History (DAM) SW04/033 Water Injector Date/~/~? SUBMIT IN I~UI~LIOATE feet ARCO Oil and Gas Company,~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive d~ee only, District ~D, CO ALASKA INC. Field PRUDHOE BAY Auth, or W.O. noAs2963 l County, parish or borough Leese or Un~ORTH SLOPE ADZ,: 28328 Title WORKOVER IState St/'( DS 9-16 lWell no. API: 50-029-20257 Operator zlt.~CO Spudded or W.OA~'~pT Date and depth as of 8:~ a.m. 04/01/89 ( TD:12589 PB:12546 SUPV:RWO 04/02/89 ( TD:12589 PB:12546 SUPV:RWO 04/03/89 ( TD:12589 PB:~2546 SUPV:RWO 04/04/89 ( TD:12589 PB:12546 SUPV:RWO 04/05/89 ( TD:12589 PB:12546 SUPV:RWO 04/06/89 ( TD:12589 PB:12546 SUPV:RWO 04/07/89 ( TD:12589 PB:12546 SUPV:GTG/LP The above is correct ~ ::r fo~rU r,~ p ~eparatlon ~ b~ see Procedures Manual, Section 10. Drilling. Pages 86 and 87. IDate 03/31/89 )Hour 'Cornpiet ..... r~ac~ day reported 0330 HRS IARCO WI. 21.0000 Prior status if a W.O. LD 5-1/2" TUBING MW: 8.5 FSW ACCEPT RIG 0330 HRS 3-31-89. BULLHEAD 8.5 PPG SEAWATER - TUBING VOLUME DOWN TUBING - ANNULAR VOLUME DOWN ANNULUS, MONITOR WELL - ON VACUUM. BULLHEAD 100 BBL HEC PILL TO PERES. SET BPV, ND TREE, NU AND TEST BOP'S. POOH LAYING DOWN 5-1/2" TUBING. DAILY:S66,552 CUM=$66,552 ETD:S66,552 EFC:$1,235,000 RIH W/ OVERSHOT MW: 8.5 FSW FINISH LAYING DOWN 5-1/2" TUBING. MU OVERSHOT AND RIH W/ 3-1/2" DP. DAILY:S33,443 CUM: $99,995 ETD: $99,995 EFC:$1,235,000 RIH W/ INFLATABLE BP MW: 8.5 FSW FINISH RIH W/ OVERSHOT. MILL/DRESS AND LATCH TUBING STUB. JAR PACKER FREE AND POOH. LD PACKER AND TAILPiPE ASSEMBLY. MU BAKER INFLATABLE PACKER ON 2-1/16" CS HYDRIL TBG AND RIH. DAILY:S29,740 CUM: $129,735 ETD: $129,735 EFC: $1,235,000 MILLING PACKER MW: 8.5 FSW RIH AND ATTEMPT TO SET INFLATABLE BRIDGE PLUG AT 12111', NO INDICATION OF BP SETTING, POOH. LEFT BP IN HOLE, SETTING TOOL HAD SHEARED. MU PRT AND MILL, RIH AND TAGGED PACKER AT 11923'. MILL ON PACKER. DAILY:S24,613 CUM: $154,348 ETD: $154,348 EFC: $1,235,000 POOH W/ FISH MW: 8.5 Few MILL ON PKR AT 11925'. CIRC BTMS UP. POOH W/ FISH. RECOVER 10" PIECE PKR BODY. COLLAR THAT CONNECTS PKR TO MILL OUT EXT PARTED, LEAVING MILL OUT EXT IN HOLE. MU STOP ON TRI STATE SPEAR. MU TRI STATE SPEAR W/ 4" GRAPPLE AND RIH. TAG FISH AT 12,100'. SPEAR INTO FISH. POOH W/ FISH. DAILY: $25,753 CUM: $180,101 ETD:SiS0, 101 EFC: $1,235,000 ON BTM W/ E-PLUG MW: 8.5 FSW SERVICE RIG. CONT TOH W/ FISH ASSY # 3. NO FISH. MU TSA SPEAR ASSY #4. TIH W/ ASSY AND ENGAGE FISH AND TOH. LD PACKER TAIL ASSY. MU BAKER 7" RETRIEVE-O-MATIC AND E-PLUG ASSY AND TIH W/ 3-1/2" DP. DAILY:S96,089 CUM: $276,190 ETD: $276,190 EFC: $1,235,000 SQUEEZE CEMENTING MW: 8.5 FSW RIH AND SET 'E' PACKER PLUG IN PACKER AT 12117'. PU AND SET 7" RETRIEVOMATIC PACKER AT 11711', PRESSURE TESTED 7" LINER, LAP AND 9-5/8" CASING TO 3000 PSI, NO LEAK-OFF. TOH, LD RETRIEVOMATIC. PU 49 JTS OF 2-7/8" TUBING AND RIH W/ 3-1/2" DP. RU BJ TITAN, SPOTTED 6 SX OF SAND AR3B-459-1-D INurnber all daily well history forms consecutively aa they are Prepared for each well. iPage no. ARCO Oil and Gas Company ~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1} Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field IIC°unty or Parish JStatL ARCO ALASKA INC. I NORTH SLOPE JLease or Unit PRUDHOE BAY I DS 9-16 Complete record for each day while drilling or workover in progress AUDI 4 ~LUG, LEi SAND SETTLE A~D -'G--D~ ~ S,,~u .... WITH TUBING AT 12089'. CIRCULATED 500 BBLS OF 8.5 PPG SEAWATER TO COOL WELLBORE, BATCH MIXED 301 SX(60 BBLS) OF CLASS 'G' CEMENT. SPOTTED CEMENT ON TOP OF SAND, TOH ABOVE THE CEMENT AND BRADEN-HEAD SQUEEZED 47 BBLS CEMENT, FINAL SQUEEZE PRESSURE 900 PSI AT 2 BPM, SHUT-IN PRESSURE 650 PSI DAILY:S29,934 CUM:$306,124 ETD:S306,124 EFC:$1,235,000 Date and depth as of 8:00 a.m. 04/08/89 ( TD:12589 PB:12546 SUPV:GTG/LP 04/09/89 ( TD:12589 PB:12546 SUPV:GTG/LP 04/10/89 ( TD:12589 PB:12546 SUPV:GTG/LP 04/11/89 ( TD:12589 PB:12546 SUPV:GTG/LP 04/12/89 ( TD:12589 PB:12546 SUPV:GTG/LP JWell no. DRLG CEMENT MW: 8.5 FSW FINISH CEMENT SQUEEZE. SET RTTS W/ STORM VALVE AT 25'. ND BOP'S AND C/O TUBING SPOOL, NU BOP'S AND TEST TO 5000 PSI. POOH W/ DP, LD TUBING. RIH W/ 8-1/2" BIT AND SCRAPER. DRILLED CEMENT STRINGERS FROM 10872-11072(TOL). PUMPED 50 BBL HEC SWEEP. DAILY:S68,072 CUM:$374,196 ETD:S374,196 EFC:$1,235,000 DRLG CEMENT MW: 8.5 FSW FINISH CIRCULATING HEC SWEEP. POOH, LD 8-1/2" BIT AND SCRAPER. RIH W/ 6" BIT AND SCRAPER TO TOL(11072). DRILLED CEMENT STRINGERS FROM 11133-11825(SOFT). DRILLED CEMENT FROM 11825-11951(MEDIUM-FIRM). DAILY:S23,920 CUM:$398,116 ETD:S398,116 EFC:$1,235,000 TIH FOR 2ND SQUEEZE MW: 8.5 FSW DRILLED CEMENT FROM 11951-12080. CIRCULATED 50 BBL HEC SWEEP. TESTED SQUEEZE TO 1000 PSI, LEAKING OFF AT I BPM. POOH AND LD 6" BIT AND SCRAPER. RIH W/ 2-7/8" TUBING AND 3-1/2" DP. RU BJ TITAN FOR SECOND SQUEEZE. DAILY:S25,851 CUM:$423,967 ETD:S423,967 EFC:$1,235,000 DRILLING CEMENT MW: 8.5 FSW FINISH TIH W/ 2-7/8" TBG AND 3-1/2" DP. MIXED 316 SX(62 BBLS) OF CLASS 'G' CMT AND SPOTTED BALANCED PLUG OVER PERFS. BRADEN-HEAD SQUEEZED 5 BBLS AND ZONE SQUEEZED OFF AT 1500 PSI, HELD SQUEEZE PRESSURE I HOUR AND POOH. PU 8-1/2" BIT AND RIH, TAGGED CEMENT AT 10766', DRILLED SOFT CEMENT TO 10820', DRILLED FIRM CEMENT TO 10885'. CONTINUE DRILLING CEMENT. DAILY:S55,127 CUM:$479,094 ETD:S479,094 EFC:$1,235,000 DRILLING CMT MW: 8.5 FSW DRLD CMT F/ 10885' TO 11072', TOL. REVERSE CIRC AND DISP TO CLEAN 8.5 PPG SEAWATER. TOH AND LD 10 JTS DP. MU BI'L% W/ 6" BIT AND TIH W/ 3-1/2" DP. DRLD CMT F/ 11072' TO 11400'. FIRM TO HARD CMT. DAILY:$66,510 CUM:$545,604 ETD:S545,604 EFC:$1,235,000 The above is correct For fo~,m preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 Drilling Sul~t. AR3B-459-2-B RECEIVE[ MAY N~sk~ Oi~ & G~s Con~. Number all d~n~8~torms conseculively as they are ~a~Tor e~h well. IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed, Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlarim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish JState ARCO ALASKA INC. I NORTH SLOPE I AK Field Jtease or Unit PRUDHOE BAY I DS 9-16 IWell no. Date and depth as of 8:00 a.m. 04/13/89 ( TD:12589 PB:12546 SUPV:GTG/LP 04/14/89 ( TD:12589 PB:12546 SUPV:GTG/LP 04/15/89 ( TD:12589 PB:12546 SUPV:RWO 04/16/89 ( TD:12589 PB:12546 SUPV:RWO 04/17/89 ( TD:12589 PB:12546 SUPV:RWO 04/18/89 ( TD:12589 PB:12546 SUPV:RWO Tho above is correct For form preparation and distribution 'Complete record for each day while drilling or workover in progress AUDI 4 PRESSURE TEST SQZ MW: 8.5 FSW DRILLED CEMENT FROM 11400-12080. CIRCULATED HEC SWEEP. TESTED SQUEEZE TO 1000 PSI, BLED 250 PSI IN 30 MINUTES. DAILY:S25,664 CUM:$571,268 ETD:S571,268 EFC:$1,235,000 POOH W/ E-PLUG MW: 8.5 FSW TEST SQUEEZE TO 1000 PSI. BLED OFF 250 PSI IN 30 MIN. CIRC. WASH AND ROTATE ON SAND PLUG TO 12,104'. REVERSE CIRC W/ CLEAN SEAWATER. POOH W/ 3-1/2" DP. LDDP. MU BAKER E-PLUG AND TIH W/ 3-1/2" DP. PU KELLY AND WASH OVER PLUG. CBU. SPOT 100 BBL HEC PILL. POOH W/ DP AND E-PLUG. DAILY:S25,887 CUM:$597,155 ETD:S597,155 EFC:$1,235,000 POOH W/ 2.5" GR MW: 8.5 FSW POOH W/ PACKER PLUG. RU DA E-LINE. PERF 4" 34 GM CHARGES AT 90 DEGREE PHASE lSPF AT 12005' AND 12010', 4SPF AT 11942'-86'. MADE 4 RUNS TO TOL AT 11070' WITH 8.5" OD GR, RECOVERED PIECES OF METAL ON EACH RUN. RAN 6" OD GR, COULD NOT GET INTO LINER. MADE 2 RUNS TO PACKER AT 12111' WITH 5.9" OD GR, REC'VD METAL AND CEMENT. TAGGED PBTD WITH A 2.5" OD GR. POOH WITH 2.5" OD GR. DAILY:S23,590 CUM:$620,745 ETD:S620,745 EFC:$1,235,000 TIH W/ 7-1/16" MILL MW: 8.5 FSW ATTEMPT TO RUN 7" FB-1 PACKER, COULD NOT GET INTO LINER, POOH AND RD E-LINE. RIH WITH 7-1/16" MILL, DRESSED/POLISHED TOL, POH. RU E-LINE AND RAN 6" GR, TAGGED AT 11833', RECOVERED CEMENT, RAN 5.9" OD GR TO PACKER AT 12011, REC'VD CEMENT, RAN 6" OD GR TO 11850' AND STUCK GR, PULLED GR FREE AND POOH. RD E-LINE. RIH WITH 6" MILL. DAILY:S25,363 CUM:$646,108 ETD:S646,108 EFC:$1,235,000 TIH WITH 2-1/16" TBG AND MW: 8.5 FSW CLEAN OUT LINER WITH 6" MILL TO PACKER AT 12111', CIRCULATE HOLE, POOH. RU DA E-LINE AND RAN 6" OD GR TO PACKER AT 12111', NO RECOVERY. RAN 2.5" OD GR TO 12111', COULD NOT GET THROUGH PACKER, POOH AND RD E-LINE. MU 2.5" OD MILL AND 16 JTS OF 2-1/16" CS HYDRIL TUBING AND RIH WITH DP. DAILY:S30,081 CUM:$676,189 ETD:S676,189 EFC:$1,235,000 TIH W/ FB1 PKR MW: 8.5 FSW TIH W/ 2 1/2 MILL ON HYDRIL TBG. CLEAN OUT LOWER STRADDLE. POOH. L/D HYDRIL TGB & MILL. R/U E-LINE & RIH W/ 6." GR/JB TO 12111. POOH. RIH W/ 2.5" GR. TAG PBTD @ 12484'. POOH. M/U FB-1 PKR & CMPLTN ASSY. RIH & SET PKR @ 12016'. R/D E-LINE. M/U STRADDLE ASSY & FB-1PKR. RIH ON 3 1/2" DP. DAILY:~.~,~vv ..... ~ ...... ,.v. ETDI$Sll,c°n -~-.~'e~.,~~.,~= OOO see Procedures Manual Section 10, Drilling, Pages 86 and 87 RECEIVE AR38-459-2-B MAY 1 o i989 Alaska Oil & fi~S COP,:J, [;.3m[~]J~jOj} Anchnran~. Number ~11 d~ily well hislory lorm~ ~ns~c~ti~e~- ~Page no. las lhey ~re prepared ~or erich w~ll. ARCO Oil and Gas Company Daily Well History--Interim Instractiol~s: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until linal completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion, District ICounty or Parish IState NORTH SLOPE J AK Lease or Unit DS 9-16 Field ARCO ALASKA INC. PRUDHOE BAY Date and depth as of 8:00 a.m, 04/19/89 ( TD:12589 PB:12546 SUPV:RWO 04/20/89 ( TD:12589 PB:12546 SUPV:RJB 04/21/89 ( TD:12589 PB:12546 SUPV:RJB 04/22/89 ( TD:12589 PB:12546 SUPV:RJB Complete record for each day while drilling or workover in progress AUDI 4 no. SET DB PKR @ 11020' MW: 8.5 FSW RIH W/ BAKER 7" FB-1 PKR & TAIL ASSY. STING INTO PKR @ 12016' & VERIFY W/ 700 PSI. DROP BALL & SET FB-1 @ 11920'. TEST ANN TO 1000 PSI. LOST 500 PSI IN 5 MIN. UPPER PERFS LEAKING. POOH W/ 3 1/2 DP. L/D PKR RUNNING TOOL. REPAIR DRAWORKS. M/U BAKER 9 5/8" X 4 1/2" DB PKR, 2 JTS 4 1/2" 12.69 TBG, CAMCO DB NIPPLE W/ BLANKING PLUG & PRONG IN PLACE, 10' PUP & BAKER 4 1/2" REENTRY GUIDE SPOT PKR @ 11020. DROP BALL & PUMP TO PKR. DAILY:S25,777 CUM:$837,366 ETD:S837,366 EFC:$1,235,000 RUNNING 7" TBG MW: 8.5 FSW SET BAKER 9 5/8" DB PKR @11020'. SHEAR SETTING TOOL. TEST 9 5/8 CSG @ 3000 PSI. TOH. L/D 3 1/2" DP. CUT & SLIP DRILL LINE. PULL WEAR RING. C/O 3 1/2 RAMS TO 7". R/U TO RUN TBG. TEST 7" RAMS. N/D BELL NIPPLE. N/U LUB FLANGE. R/U OTIS SL. RIH & RET EQUAL PRONG & PLUG F/ DB NIPPLE @ 11132 WLM. N/D LUB FLANGE. N/U BELL NIPPLE. M/U TBG BHA. RUN BHA & 7" CSG. DAILY:S48,935 CUM:$886,301 ETD:S886,301 EFC:$1,235,000 FILL 7" TBG W/ 8.5 MW: 8.5 FSW SERV RIG. CONT. RIH W/ 7" TBG FILLED W/ SEA WATER. P/U WT = 147K9. LOAD PIPE SHED. CONT RIH W/ 7" LEAVE EMPTY FROM JT ~ 150 TO REDUCE WT. M/U CAMCO 7" SSSV. R/U & TEST CNTL LINES @ 5000PSI. CONT RIH W/ 7". STING INTO BAKER 9 5/8" DB PKR @ 11020' P/U WT:200K; S/O WT: 100K. PRESS ANN TO VERIFY STING IN. SPACE OUT & R/U LANDING JT & HNGR. FILL TBG VOID W/ SEA WATER. DAILY:S412,609 CUM:$1,298,910 ETD:S1,298,910 EFC:$1,235,000 SPACE OUT 7" TBG MW: 8.5 FSW R/U S-LINE. PULL SSSV DMY, XN PLUG. UNABLE TO SET DB PLUG. R/D S-LINE. PUMP DN TBG. NOTE RTNS UP ANN., STING INTO 9 5/8 PKR. R/U S-LINE. RIH. UNABLE TO GET DEEPER THAN 11926' TO SET DB PLUG. SET DUMMY PACK-OFF IN SSSV. R/D S-LINE. SPACE OUT TBG. DAILY:S30,700 CUM:$1,329,610 ETD:S1,329,610 EFC:$1,235,000 The above is correct · Signat~'~ ~ For form prc~paration and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B MAY i 0 Alaslm Oil & ~;' ~lchomgo Number all daily well hislory lorms consecutively as they are prepared for each well. JPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Ptugged. Abandoned. or Sold. "Final Report" should be submitted.also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" Iorm may be used ~or reporting the entire operation if space is available. District JCounty or Parish I Field ~'~'"=O ~'~'~ ~"~ :~'~ ' JL ...... ~t'T'~ ~ Auth. or W.O.~g~:[O: ~' Title ~L; JAccounting cost center code State B,9 9-1G Iwo, no. Operator Spudded or ~.~gun Date and depth' ..... as of 8:00 a.m. 04/23/89 ( 2 TD:12589 PB:12546 SUPV:RJB I A.R.Co. fN~'.l.II 50--029-2021H tal number of wells (active or inactive) on this, Icost center prior to plugging and ,,,, labandonment of this well Date 21 . Ow0 our JPrlor status if a w.o. I ~/~, /o~ t 0330 HRC Complete record for each day reported v~, ~, v~ .~.tJD I 4 RIG RELEASED @ 2300 MW: 8.5 FSW POLL SEALS OUT OF PKR. SPACE OUT & M/U HNGR. STING IN & PRESS. TO 500 PSI. STING OUT & DISPL HOLE W/ 8.5 INHIB SW. FREEZE PROT. W/ 128 BBLS DIESEL. LAND TBG & RILDS. TEST ANN @ 3000. AOGCC WITNESS B. FOSTER. L/D LND. JT. N/D BOP. N/U TREE. M/U CNTL LINES. TEST LINES & TREE @ 5000 PSI. R/D CELLAR RELEASE RIG @ 2300 HRS, APRIL 22, 1989. (NOTE: CAMCO 'BAL-O' SSSV @ 2174', BAKER 'DB' PKR @ 11022', BAKER 'FB-I' PKR @ 11918' & 12016', & TT @ 12026'.) DAILY:S54,700 CUM:$1,384,310 ETD:S1,384,310 EFC:$1,235,000 Old TD JNewTD I PB Depth Classifications (oil. gas. etc.) Type completion (single, dual. etc,) Producing method J Officia reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day P,.mp size. SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effeciive date corrected For form preparation and distribution, Drilling, Pages 86 and 87. KtLt v . AR3B-459-3-C jPage no. Olvl~Jon of AtlantlcRk::hfleldCompany ARCO ALASKA, INC, F',O, BOX i~0360 ANCHORAGE, ALASKA 995J ,.3 DATE- 4-24-89 REFERENCE' .ARCO CASED HOLE FINALS i-tA 4-6-89 PRODUCTION PROFILE RUN 2- t 6 3-23-89 TEMP RUN 9-t4 3-23-89 CCL/X-Y CALIPER RUN 9-i 6 4-t 4-89 COLLAR/F'ERF RUN 9-.38 4-t 3-89 CBT RUN 9-58 4- t $-89 CET RUN it-6 3-~5-89 PRODUCTION PROFILE RUN ~ J -~ 7 4-J 5-89 COLLAR/PERF RUN J J -J 8 4-t 6-89 COLLAR/F'ERF' RUN ~2-4 3-2~-87 PRODUCTION PROFILE RUN t2-t2 3-t 9-89 PRODUCTION FR]f-ILE RUN ~2--i3 3-~6-89 PRODUCTION PROFILE RUN i"2-i7 3-i8-89 F'RODUCTION PROFILE RtJN t2 28 3-t7-89 FRODUCIION PROFILE RUN ~ 8-~ 6 3-26-89 TEMP RUN ~ 8-23 3-29-89 CCL RUN F'LEA.?E SIGN AND RETURN THE ATTACHED COPY AS' RECEIPT OF' DATA, RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-t529 CAMCO C A M C 0 CAMCO ATI..AZ 5'CH ~' C H C A M C 0 A i'I_A~' ATLAS' CAMCO CAHCO CAMCO CAMCO CAMCO CAMCO CAMCO DIS'TRIBUTION CENTRAL FILES ~ PHILLIP£ CHEVRON PB WELL FILES D&M R&D EXTENSION EXPLORATION ~ BPX EXXON ~ STATE OF ALASKA MARATHON ~ TEXACO MOBIL M. EMORAN D~M~ ' State (o~, Alaska ALASKA OIL Ah~D GAS CONSERVATION COMMISSION /__ To: Loppie' C. Smit~d~/ O^TE: April 13, 1989 C~is sioner / F~L~ ~O: D. BDF. 050 THRU: Michael T. Minder Sr. Petroleum Engineer TELEPHONE NO: SUBJECT: BOP Test AAI PBU DS 9-16 Permit. No. 77-37 Prudhoe Oil Pool FROM: Petroleum Inspector Friday, March 31, 1989. The test beEan at 7:00 'pa and was concluded at '12:30' am. AS the attached BOP test report sho~s there were. no failures. In summary, I witnessed the BOP test on Areo's DS 9-16. STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date .o Representative Permit ~ ,~ '~- ~ 7 .' Location; Sec / T,/~JR./~ H Y ~f~_ _ Casing Set @ //~-'/ ft. Drilling Contractor~U~_~ Ri~ ~ ~/" "Representative ~, ~q/~:.~>/: Location, General_ ~ Well Stg~ ACC~LATOR SYST~ General Housekeeping~/~ Rig Pw~ Reserve Pit ~///9 Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure" Full Charge Pressure &~oO pstg,. Pressure After Closure. / ~"~ psig Pump incr. clos. pres. 200 psig -- min/~,see. Full Charge Pressure Attained: . / ~in~'sec. Controls: Master Remote Blinds switch cover _Kelly and Floor Safety Valves Upper Kelly / Lower Kelly Ball Type /' Inside BOP~ / Test Results: Failures '~ Repair or Replacement of failed equipment to be made within Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifold~~__Test Pressure.j~,~ No. Valves .. ~ No. flanges Adjustable Chokes ...... Hydrauically operated choke / Test Time ~ hrs. day~ and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC ce - Operator cc - Supervisor ARCO ALASKA, F'.O. BOX ANCHORAGE, ALASKA DATE- REFERENCE: 4-4-89 ARCO CASED HOLE FINALS t-9 3-tt-89 LEAK DETECTION 2-t? 3-22-89 TEMP & GAMMA TIE-IN 5-t3 3-t2-89 LEAK DETECTION &-t2 3-25-89 COLLAR/PERF 6-t4 3-t8-89 COLLAR/PERF 7-14 3-f2-89 LEAK DETECTION 9-t6 3-27-89 TUBING CUTTER tt-24 3-~5-89 TEMP i~-24 3-~9-89 COLLAR/PERF ~2-32 3-~6-89 CBT .~2-32 3-t6-89 CET t5-8 S-~3-89 PIT/PRODUCTION ~5-25 3-~-89 PRODUCTION F'ROFILE ~8-t4 3-~7-89 PERF RECORD i 8-i 5 3-i 7-89 PRODUCTION t8-i5 3-i8-89 DUAL BURST 'rDT-P t 8-20 3-26-89 COLLAR/PERF RUN t, 5' RUNS t82, 2"&5" RUN t, RUN t, 5" RUN t, 5" RUN t, RUN i, 5" RUN t, 5" RUN t, 5" RUN t, 5" R~N t, 5" RUN t, i/2"&5' RUN i, 5" RUN t, RUN i, 5" RUN t, RUN t, 5" PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT RECEIVED BY HAVE A NICE DAY! SALLY HOF'FECKER ATO-i 529 TRANS $89i~7 APF'ROVED .~ .9. DISTRIBUTION OF DATA. CENTRAL FILE£' CHEVRON D & M EXTEN£ION EXPLORATION EXXON MARATHON 5~ MOBIL PHILLIPS PB WELL FILES R & D BF'X STATE OF' ALASKA TEXACO CAMCO OTIS CAMCO Al'LAS Al'LAS CAMCO ATLAS CAMCO ATLAS SCH $CH SCI-t CAMCO ,,.S.'C H SCH SCH ATLAS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown __ Re-enter suspended well __ Alter casing __ Repair well ,'" Plugging __ Time extension ~ Stimulate __ Change approved program __ -- Pulltubing ¢' Variance ~ Perforate ,,-' Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 877' N & 175'E of SW cr,. Sec. 1, T10N, R15E, UM At top of productive interval 1414'N, & 868'W of SE cr, Sec. 3, TION, R15E, UM At effective depth 1553'N, & 1395'W of SE cr, Sec. 3, TION, R15E, UM At total depth 1561'N & 1425'W of SE cr, Sec. 3, TION, R15E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 54 ' 7. Unit or Property name Prudhoe Bay Unit 8. Well number BS 9-16 9. Permit number 77-37 10. APl number 50-- 029-20257 11. Field/Pool Prudhoe Bay 0il Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2727 ' Intermediate Production 11370 ' Liner 1516' Perforation depth: 12589'MD 9195'TVD 12546'MD 9165'TVD Size feet " Plugs(measured) feet None feet Junk (measured) feet None Cemented Measured depth 13-3/8", 72# 3100 sx 2727' 9-5/8", 47# 1000 sx 11370' 7" 29# 520 sx 12588' , 'Tr L~ e ~l~l~la~l'~ ~t h 2727' 8345' 9195' Date ,~- 7'- ~" SUBMITIN TRIPLICATE measured 11810'-11860~, 11880'~11910', 11942'-12010'~ 12028'-12076'~ 12094'-12105' 12140'-12186', 12220'-12248', 12298'-12333', 12350'-12370', 12375'-12395' true vertical 8649'-8684', 8698'-8719', 8742'-8789', 8802'-8836', 8848'-8856', 8881 '-8913', 8937'-8956', 8991 '-9016', 9028'-9042', 9045'-9056', Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 5-1/2", 17#, L-80, 10770'MD & 4-1/2", 12.6#, N-80, 11085'MD Baker FB-1, 12261', Baker FB-1, 12111'; Baker FB-1, 11925; Baker FHL, 10786'; CAMCO 'BAL-O' SSSV, 2201' 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch ~._ 14. Estimated date for commencing operation March 15, 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Service Gas ~ Suspended Seawater injector 17. I hereby certify thCht~ing is true and correct to the best of my knowledge. Signed ..~.~. ~~/./_../-¢-"'"'~ Title Regional Drilling Engineer FOR COMMISSION USE ONLY BES Conditions of approval: Notify Uommission so representative may witness Plug integrity __ B~P~ Test ~ Location clearance Subsequent form -- Mechanical Integrity Test/~ required 10- Approved Copy ORIGINAL SIGNED BY Returned Approved by order of the Commission 0 6 0 ~.~IE 6. SIVllT~ :~ - ~-'<¢2~'~' ' -i ..... , - oner Date ..~/¢~ ¢ J Approval No. p ~. / -~ Form 10-403 Rev 06/15/88 PBU DS 9-16 WORKOVER PRELIMINARY PROCEDURE OBJECTIVE: Pull the 5-1/2" completion and 9-5/8" packer. Mill and recover the 7" FB-1 packer at 11925'. Squeeze the perforated intervals from 11810' - 12010', re- perforate and install a 3-1/2" straddle over same interval. Set a permanent packer above the TOL and run a 7" completion. PROCEDURE: 1. Have Production freeze protect the well from the manifold building to 2000' with methanol/water. 2. RU E-line and jet cut the 4-1/2" tubing pup between the 9-5/8" FHL packer and the PBR. RD E-line. 3. MIRU AUDI Rig #4. Kill and displace the well with 8.5 ppg seawater. Pump HEC pills if fluid loss is unmanageable. 4. ND tree, NU and test BOPE. 5. Pull and LD the 5-1/2" tubing and PBR. 6. PU 3-1/2" DP and retrieve the 9-5/8" FHL packer at 10786'. 7. Mill and retrieve the 7" FB-1 packer at 11925'. · MU Baker E type packer plug and 7" retrievamatic packer. Set and release the E plug in the FB-1 packer at 12111' PU above the top perf at 11810' and set the retrievamatic. Pressure test the 7" liner, lap and 9-5/8" casing. POOH with the retrievamatic packer. PU 1500' of 2-7/8" tubing and RIH with 3-1/2" DP to the E plug. Spot 90' of sand on top of the E plug (top of the sand plug at +_12,020'). PU above the sand plug and circulate 500 BBLS of 60° F seawater to cool down the wellbore above the perf interval. 10. Batch mix 60 BBLS of class G cement. Spot a balanced cement plug and braden-head squeeze 50 BBLS of cement behind pipe. POOH. RIH with an 8.5" bit and 9-5/8" casing scraper and clean-out to the TOL. RIH with a 6" bit and 7" casing scraper. Clean out the 7" liner to 12015'. Pressure test the squeeze. Re-squeeze if required. Clean out the 7" liner to 12100' and POOH. Retrieve the E plug from the FB-1 packer at 12111' RU E-line unit. Re-perforate the squeezed interval with 4" hollow carrier guns. , . 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. Make an 8.5" OD GR/JB run to the TOL. Make a 6" OD GR/JB run to the FB-1 packer at 12111'. Make a 2.5" OD GR run through the existing 3-1/2" straddle and tag fill. If required: PU 550' of 2-1/16" CS HYDRIL tubing and RIH on 3-1/2" DP (space out a 7" casing scraper if the 6" OD GR/JB did not go). Run the 2-1/16" tubing through the 3-1/2" straddle from 12111' - 12272' and tag fill. Clean out fill if required. POOH. Set a 7" FB-1 packer with a 3-1/2" tailpipe assembly at 12016' (with a blanking plug in the 3-1/2" tailpipe). RD E-line. MU 3-1/2" straddle equipment and a FB-1 packer on a B-2 setting tool. RIH on 3-1/2" DP and land the straddle in the FB-1 packer at 12016' (verify position by pressuring up against the blanking plug in the 3-1/2" tailpipe). Set the top FB-1 packer at _+11925' MD. RIH and set a 9-5/8" DB packer with a 4-1/2" tailpipe assembly at _+11020' on 3-1/2" DP with a J type setting tool (run a blanking plug in the 4-1/2" tailpipe). POOH and LDDP. Run 7" completion equipment and space out the tubing. Displace the well with inhibited seawater and freeze protect the permafrost interval. Land the tubing. ND BOPE, NU and test the tree. Release the Rig. RU slickline and pull the plug from the 4-1/2" tailpipe and the plug from the 3-1/2" tailpipe. Replace the dummy valves in the upper 3-1/2" straddle with 3/4" orifice valves. RD slickline. Turn the well over to Production. I , I ANNULAR PREVENTER 6 PIPE RAHS 5 TUBIN6 HEAD ~5 1. 13-;5/8" CASING HEAD 2. 9-5/8" CASING HEAD ;5. 5000 PSI TUBING HEAD 4. 1;5-5/8" - 5000 PSI BLIND RAMS 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 1;5-5/8" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. ;5. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 2500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI, 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINE5 ARE FULL OF ARCTIC DIESEL AND ALL VALVE5 ARE SET IN TME DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12, TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. JG NOVEMBER 21, 1986 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510.0360 Telephone 907 263 4248 Donald E Scheve Operations Engineering Manager December 15, 1988 C. V "Chat" Chatterton Alaska Oil & Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS# 9-16 Permit No. 77-37 Dear Mr. Chatterton' Attached is the Application for Sundry Approval to continue water injection into Well 9-16 as required per Rule 7 of Area Injection Order No. 4. Very truly yours, D. F. Scheve Attachment cc: Standard Alaska Production Co. L. L. Gantt, ATO 1520 J. W. Groth, ATO 1570 T. A. Billingsley/M. A. Lucich, PRB 24 T. G. Zibell/L. J. Sennett, PRB 24 PRB Files (9-16) Oper. Eng. Files (9-16) DFS/TAB/prm STATE OF ALASKA ALAS~,A OIL AND GAS CONSERVATION COMM~oSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown ~: Re-enter suspended well '- Alter casing !_~. Time extension Change approved program Plugging '~ Stimulate .~ Pull tubing Amend order r Perforate [' Other 2 Name of Operator 5. Datum elevation(DF or KB) ARCO Alaska, Inc. 54' RKB feet 3 Address 6~Un~,orP~pert~n~me P. O. Box 100360, Anchorage, Alaska 99510 ~ruanoe ~ay unz~ 4. Location of wellatsurface 877'N & 175'E of SW cr, Sec 1, T10N, R15E, UM Attop ofproductive~nterval 1414'N & 868'W of SE cr, Sec. 3, T10N, R15E, UM Ateffective depth 1553'N & 1395'W of SE cr, Sec. 3, T10N, R15E, UM At total ,w . , 156 1425 of SE cr, Sec 3, T10N R15E, UM 7. Well number DS 9-16 8. Permitnumber 77-37 9. APInumber 50-- 029-20257 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 12589 feet Plugs (measured) 919 5 feet Effective depth: measured 12546 feet Junk (measured) true vertical 9165 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 2727' 13-3/8", 72# 3100 SX 2727' 2727' Intermediate 11370' 9-5/8", 47# 1000 SX 11370' 8345' Production 1516' 7" 29# 520 SX 12588' 9195' , Liner Perforation depth: measured 11810'--11860', 11880'-11910', 11942'-12010', 12028'-12076', 12094'-12105' 12140'-12186' 12220'=12248' 12298'-12333' 12350'-12370' 12375' 12395'. true vertical 8649'-8684' 8698'-8719' 8742'-8789' 8802'-8836' 8848'-8856' 8881'-8913' 8937'-8956' 8991'-9016' 9028'-9042' 9045'-9056' Tubing (size, grade and measured depth) 5-1/2",17#, L-80, 10770'MD & 4-1/2", 12.6#, N-80, l1085'MD Packers and SSSV (type and measured depth) 2 1' ak ~ 1 ' / Baker FB-1, 11925; Baker FHL, 107~?rc~'B~{-8 S~S~, ~0{ 7 ' 12111 ; , 12.Attachments Description summary of proposal 13. Estimated date for commencing operation Continue Water In~ection 14. If proposal was verbally approved Name of approver Mike Minder Date approved 12/12/88 15. I hereby/~ertify that the foregoing is true and correct to the best of my knowledge Signed Title Operations Engineering Manager Date12/12/88 Commission Use Only approval Notify commission so representative may witness I Approval Conditions of No. F2 Plug integrity I-i, BOP Test ~ Location clearance 7 ' -"/ /[' \-- ~ ' by order of Approved by i ~/-'5~ / ,:,c-~..~,~.~.'~:J- Commissioner the commission Date 72 Form 10-403 Rev 12-1-85 Submit in triplicate//_;: INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA INJECTION ORDER #4 DATE: 12-12-88 TIME: 1:15 p.m. NOTIFIED BY: Ellen Fitzpatrick AOGCC CONTACT: Mike Minder 279-1433 REASON: Injection Well 9-16 Annular Communication Per Rule 7 Requirements of Area Injection Order No. 4 DISCUSSION: Water Injection Well 9-16 tubing x 9-5/8" annular pressure .started tracking ~ pres_sur_.~e of 1700 psi. When 9-5/8" annulus pressure is bled to zero,-lt~'e builds up to 170~ psi in approximately 24 hours. _W_ell was shut In and passed MIT run on .12-12-88. 9-5/8" annulus test pressure of 2100 psi decreased to 2060 psi in 1 hour. Arco plans to continue monitoring pressures with no additional work planned unless leak condition worsens. 9-16 is not a WAG well. AoGcc RESPONSE: Permission given to operate for 1 week. Send documentation on form 403 to operate beyond I week. Sundry Notice Req'd at this time? YES X NO SIGNED: Productio~!~upport Superintendent Orig' cc: Ann Comm Eng, PRB 24 Prod Sup Supt, PRB 20 Sr Wireline Supv, PRB 20 DS Supv, PRB 14 FS Supt, PRB 14 DS Eng-ATO 1580 (8/28/88) '"'.,. f?, ......... F' N 'T' F,' ~ I.. F' '[ I Fr .$' · ,..'"' f': 14 I-.- V !:;.' !1.. N :~ F'y, 'T'E N,% T (.1. N .F. XF I... {. R ~T T lIN · ~.': H E} B .T t.. ARCO Alaska, Inc. Prudhoe Bay ~,,gineering Post Office Box '100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager April 24, 1987 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton- Re- DS 9-16 Permit Number' 77-37 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned well. Very truly yours, D. F. Scheve DFS/FEB'sd Enclosure CC' Standard Alaska Production Co. File P1(DS9-16)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK.. OIL AND GAS CONSERVATION COMN. _..,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well 12_3 Alter casing Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [3 Perforate J,~ Other 2. Name of Operator ARCO Alaska; Tnt. 3. Address Post Office Box 100360, Anchoraqe, AK 99510 4. Location of well at surface 877'N & 175'E of SW cr, Sec 1, TION, R15E, UM At top of productive interval 1414'N & 868'W of SE cr, Sec. 3, TION, R15E, UM At effective depth 1553'N & 1395'W of SE cr, Sec. 3, TION, R15E, UM At total depth 1561'N & 1425'W of SE cr~ Sec. 3, TION, R15E, UM 11. Present well condition summary 12589 Total depth: measured feet true vertical 9195 feet Effective depth: measured 12546 feet true vertical 9165 feet Plugs (measured) Junk(measured) Casing Length Size Cemented Structural 5. Datum elevation (DF or KB) 54' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 9-16 feet 8, Permit number 77-37 9. APl number 50-- 029-20257 10. Pool Prudhoe Bay Oil Poo Measured depth ~:'~:':'~'"~':i~rue Vertical depth Conductor Surface 2727' 13-3/8" ,72# 3100 SX 2727' 2727' Intermediate 11370' 9-5/8" ,47# 1000 SX 11370' 8345' Production 1516' 7" ,29# 520 SX 12588' 9195' Liner Perforation depth: measured 11810'-11860', 11880'-11910', 11942'-12010' ,12028'-12076', 12094'-12105', 12140'-12186', 12220'-12248', 12298'-12333', 12350'-12370', 12375'-12395i true vertical 8649'-8684', 8698' -8719', 8742' -8789', 8802' -8836', 8848'-8856' , 8881'-8913' , 8937' -8956' , 8991' -9016' , 9028' -9042' , 9045' -9059' Tubing (size, grade and measured depth) 5½" 17# L-80 10770'MD & 4½" 12 6# N-80 11085'MD Packers and SSSV (type and measured depth) Baker FB-1, 12261 '; Baker FB-1, 12111 '; Baker FB-1; 11925; Baker FHL. 10786'; CAMCO BAI-O SggV; 2201' 12.Attachments Description summary of proposal )i~ Detailed operations program _F..] BOP sketch 13. Estimated date for commencing operation May 1, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,qertify that the foregoing is true and correct to the best of my knowledge Signed ~/~¢~g' ~~~ Title Operations Enqineerinq Manaqer Date Commission Use Only Conditions of approval Notify commission so representative may witness[] Plug integrity [] BOP Test [] Location clearancelApprovalN°' by order of Approved by Commissioner the commission Date Form 10-403 Rev 12-1-85 Submit ~ triplicate Attachment to Application For Sundry Approvals ARCO Alaska, Inc. proposes to reperforate previously perforated intervals in DS 9-16 within the Sadlerochit Sand of Prudhoe Bay Unit. All wireline work will b--~ done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating operation. Proposed Reperforation Intervals' 12028'-12076'MD (48') 12094'-12108'MD (14') REF' BHCS 9/28/77 A n c h o r a g e, A L a .'...;' I,, a 995 ~ () DATlii:' December S ~, ~986 "l ........ t .... "'" I-,,1::. F [:. K [:. N C, I:= :' A R C (3 C a s' e d I..i o I. e F:' i n,':~ L i -'8 i 2-' i 2.--86 3-"i 7 i 2 .... i ()-86 S- '~ :; i 2-.i S-86 4'-... '2 i i '2 -.- 4 - 8 6 9 .... 4 i 2-.-t S.--86 9-'t6 t2 .... tt-'68 ">'-' 9-86 t3 .... t9 t,-.. t ,., i 6-2 t 2-' t 4-'86 I::'l. eas'e .,~ign a'nd re'l:ur'r; ! att. ,,,~ecl c i:~Y as' - c:eipi' of dar I',.(:: (.. E I:" "'" '~' ' red' · ]E.Iz' ,, / J~ ~,t r t" r'- * ~' ~ .~T/' ';~.,') Ros'anne PEek ~ / ...... ~ r,~ns b~,,,,,~slo~ . .. ~ 'f'RAN,S' ~:86859 DI$1'RIBUTION ~: F'hi LLip~' PB WeLL F'i Les R & D '"'-,. Sob i o ~,. ate of A La.'..~I<a · .-'"' Texaco ARCO Alaska, Inc. i Prudhoe Bay ~.,,gineering Post Office Box '~00360 Anchorage, Alaska ~)9510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 10, 1986 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Re' DS 9-16 Permit No. 77-37 Enclosed is the "Subsequent" Sundry Notice detailing work completed on the above-mentioned well. Very truly yours, a. F. Scheve DFS/FEB'sd Enclosures cc: Standard Alaska Production Company File: PI(DS 9-16)W4-3 ARCO Alaska, Inc. is a Subsidiary of AtlanHcRichfieldCompany STATE OF ALASKA ALASK,. ,oIL AND GAS CONSERVATION COMb,.. _,~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator ARCO Alaska; Inc. 3. Address Post Office Box 100360, Anchorages AK 99510 4. Location of well at surface 877'N & 175'E of SW cr, Sec 1, TION, R15E, UM At top of productive interval 1414'N & 868'W of SE cr, Sec. 3, TION, R15E, UM At effective depth 1553'N & 1395'W of SE cr, Sec. 3, TION, R15E, UN At total depth 1561'N & 1425'W of SE cry Sec. 3, TION, R15E, UN 11. Present well condition summary 12589 Total depth: measured Plugs (measured) true vertical 9195 feet feet 5. Datum elevation (DF or KB) 54' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 9-16 8. Approval number 77-37 9. APl number 50-- 10. Pool 029-20257 Prudhoe Bay Oil Pool Effective depth: measured 12546 feet Junk (measured) true vertical 9165 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 2727' Z3-3/8" ,72# 3100 SX 2727' 2727' Intermediate 11370' 9-5/8" 47# 1000 SX 11370' , 8345' Production 1516' 7",29# 520 SX 12588' 9195' Liner Perforation depth: measured 11810'-11860', 11880'-11910', 11942'-120~0' ,12028' 12076' 12094'-12105', 12140'-12186', 12220'-12248', 12298'-12333', 12350-12370', ~2375'-~239~ true vertical 8649' -8684' 8698' -8719' 8742' -8789' 8802' -8836' 8848' -8856' 8881' -8913' 8937' -8956' 8991'-9016' 9028' -9042' 9045' -9059' Tubing (size, grade and measured depth) a_~,, 12.6# N-80 11085 'MD 5½", 17#, L-80, 10770'MD & -2 , , , Packers and SSSV (type and measured depth) Baker FB-1, 12261 '; Baker FB-1, 12111' Baker FB-1. 11925: Baker FHL; 10786'-_. CAMCO RA!-0 SSSV, 2201_' 12. Stimulation or cement squeeze summary ~ E (, E ~ V 13. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average OiI-Bbl Gas-Mcf Water-Bbl ! 3 1986 Alaska 0i1 & O::~; Con. s. (,,¢:~.~,;som Injection Data A~:~;ii~,~u,, Casing Pressure Tubing Pressure Prior to well operation 35500 1000 1500 Subsequent to operation .... 38000 1000 1630 14. Attachments Daily Report of Well Operations ~ Copies of Logs and Surveys Run I ] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 2~~,~~~_~- Title Operations Enqineering Manager Form 10-404 Rev. 12-1-85 FEB (263-4261) Date Submit in Duplicate SUMMARY OF OPERATIONS Began perforating operations on 10/15/86. S/I well, RU perforating unit, pressure tested equipment. RIH w/gun #1, perforated one shot each at 12078', 12096' 12100', 12104' and 12107' POOH, all shots fired. RIH w/gun #2, perfor ted one shot each at 12054' 2062' and 12070' POOH, all shots fired RIH w/gun #3, perforated one shot each at 12030', 1203~', and 12046', POOH, all shots fired. Secured well, RD. Returned well to injection. ARCO Alaska, In~ Prudhoe Bu~ ~,,~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Doneld F. Scheve Operations Engineering Manager September 8, 1986 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-16 Permit No. 77-37 Enclosed is the "Intention" Sundry Notice detailing work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/FEB:sd Enclosures cc: Standard Alaska Petroleum Co. File PI(DS 9-16)Wl-3 RECEIVED SEP 0 9 1986 Alaska 0il & Gas Cons. commission Anchorage ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA -' ALA,_ A OIL AND GAS CONSERVATION CON .... ~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing I] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing Gl Amend order [--] Perforate X] Other ll 2. Name of Operator ARCO Alaska, Inc, 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 877'N & 175'E of SW cr, Sec 1, TION, R15E, UM At top of productive interval 1414'N & 868'W of SE cr, Sec. 3, TION, R15E, UM At effective depth 1553'N & 1395'W of SE cr, Sec. 3, TION, R15E, UM At total depth 1561'N & 1425'W of SE cr, Sec. 3, TION, R15E, UM 5. Datum elevation (DF or KB) 54' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 9-16 8. Permit number 77-37 9. APl number 50-- 029-20257 feet 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 12589 9195 feet feet Plugs (measured) Effective depth: measured 12546 feet Junk (measured) true vertical 9165 feet S E P 0 9 1986 :&las~a un ~ GaS Cons. Measured depth Anch0rCl~Vertical depth Casing Length Size Cemented Structural Conductor Surface 2727' 13-3/8" ,72# 3100 SX Intermediate 11370' 9-5/8" ,47# 1000 SX Production 1516' 7",29# 520 SX Liner Perforation depth: measured 11810' -11860', 11880'-11910', 11942' -12010' 12220'-12248', 12298'-12333', 12350'-12370' true vertical 2727' 2727' 11370' 8345' 12588' 9195' , 12140'-12186' , 12375'-12395' 8649'-8684' 8698'-8719' 8742'-8789' 8881'-8913' 8937'-8956' 8991'-9016' 9028'-9042' 9045'-9059' Tubing (size, grade and measured depth) 5½", 17#, L-80, 10770'MD & 4½", 12.6#, N-80, 11085'MD Packers and SSSV (type and measured depth) Baker FB-1, 12261'; Baker FB-1, 12111'; Baker FB-I~ 11925; Baker FHL, 10786'; CAMCO BAL-O SSSV, 2201' 12.Attachments Description summary of proposal ~ Detailed operations program Eli BOP sketch 13. Estimated date for commencing operation September 11, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereb,~rtify th~,~he ~/'eg~g is true and correct to the best of my knowledge Signed ,~k,'~'~/~'~_~/ ,¢~ ~ Title Operations Engineering Manager Date Commission Use Only Conditions of approval Notify commission so representative may witness Approved by [] Plug integrity [] BOP Test [] Location clearance Commissioner IApproval NO..¢~ ;:~cD .... by order of the commission Date ~ "-/(.? '-~'~"L~.- Form 10-403 Rev 12-1-85 Submit in triplicate Attachment to Application For Sundry Approvals ARCO Alaska, Inc. proposes to add perforations to DS 9-16 at selected intervals within the Sadlerochit Sand of Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating operation. Proposed Perforation Intervals' 12028'-12076'MD (48') 12094'-12108 'MD (14') REF' BHCS 9/28/77 ARCO Alaska, lnc F'.O. Box Anchorage, ALaska 995i0 DATE' Hatch 27, t986 REFERENCE' ARCO Cased Hole Final. DS-.6-5 2-t 2-86 DS 6-_'5 1 -t 2-85 DS 6-5 t-9-85 DS 6-5 t-! t-85 DS 6-t t - 2-7-85 DS 6-t t 2-7-85 DS 7-8 t~-~8-85_ ~ DS 9-t 2-t_,~-86 DS o_"z, ,_, 3-i-86 DS 9-t6 2-i-86 DS ii-8 ~-=-86 DS i2-!O it-30-84 D~ t2-i6 2-i7-86 _r:'$ i ~'-¢ 'i o,. t -~2-86.- DS t 3-24, 1 -22-°~, c,' DY t 3-2~^c:~ ~-i6-86 PLease sign and reCurn Che Caliper Inspection Run t _.~' CCL/F'erf. Record Run t 5" CET Cement Eval Run t 5' CET Run..° _s' CCL/Perf. Record Run 2 5' CET Run 2 5 ' F'L$ Run t_~=' Gamma Ray Run i 5' Gamma Ray Run t 5' Inj. 2',p inner Run t 5" Collar Run 1 5' TDT Run 7, 5 ' ~..-Y Cal;per Log Run t 5' Sp inner Run i 5' ~,, inner Run t ._.,' :?pJnner Run I _,=' attached copy as receipt of data. C8 ;~iE 0 ,Sch $ch Zch ~'ch $ch DA C8 f~lC 0 CS~EO Go ~0 $ch Ca mc o ._.8 ~';i C 0 Received By HAVE A NICE DAY! Irma Car I i n ATO-t 4--- yF TRAN$ $862t4 DIYTRIBUTION Central Fi le~ - ~ F'hi lli Chevror, F'B Well F'ilex D & M R & I) Extenxion P-xploration_ ~ ;.ohio Exxon ~ Xtate of A la~-ka Marathon ~ ~exaco ARCO Alaska, inc. Post Office I' 100360 Anchorage. A,.~ka 99510 Telephone 907 276 1215 Date: October 21, 1985 Reference: ARCO CH Finals 2-10~' CET Log 3-2 J CET ~6-10 *CET 7-2-- CET 9-16 ~ Ga~a Ray 1 i_12~CBL 13-4 ~CCL/Perf 13-25~EPL 13_98~CNL 14-2~ CET 14-4~ CET ~14-7~ CCL 14-34~ET 15-12~ET ~! 7-1 i~CET 17-13~ET 17-14~ET 6-30-85 3-11-85 3-6-85 3-8-85 4-27-85 12-13-$4 5-8-85 4-13-85 8-14 -85 8-14-85 6-29-85 6-29-85 4-5 -85 3-~0-85 ' 3-9-85 3-23-85 3-4-85 3-3-85 Run 1 5" Sch 1 5" Sch 1 5" Sch · 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1~ 5" Sch 15 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch 1: 5" Sch 1 5" Sch 1 5" Sch 1 5" Sch (Recomputed) (Epithermal-Recomputed) (Thermal-Recomputed). Trans 365 Chevron : Phillips -~ D & M PB Well Files Expl. Services' R & D Ext. Exploration~ Sohio Marathon Texaco · ~ob i l ARCO Alaska, Inc. ,, .... · Post Office E~ ;00360 Anchorage. Alaska 99510 Telephone 907 :)76 1215 Date: October 17, 1985 Reference: ARCO CH Finals %~i:::~:9-16 SPinner Run 1 5?' 'Camco 9-28-85 11-9 Temp 1 5" Camco 10-8/9-85 16-1 Spinner 1 5" Camco 9-29-85 16-14 Spinner 1 5" Camco 9-29-85 Please sign as receipt of data. Received by . U~~'~ Pam Lambert ~/MaS~a ATo 1429C Trans 359 ~evron D & M PB Well Files Expl. Services R & D Ext. Exploration Exxon Sta=e of Alaska Marathon Mobil ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Ataska 99510 Telephone 907 276 1215 Date: September 9, 1985 Reference: ARCO CH Finals "~2~ 15 Collar/Perf Log 5-7 Collar/Perf Log 9-16 Completion ~ ~Jll-13 CEL 4-19-85 Run 1 5" Sch 4-24-85 1 5" Sch 4-19-85 1 5" Sch 7-3-85 1 5" Sch Please sign as receipt o~ Recieved by Pam Lambert ATO 1429C Trans 307 Chevron D&M Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R&D Sohio State of Alaska Texa co ARCO Alaska, Inc. Post Office Bc, x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 September 12, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 9-16 Dear Mr. Chatterton: Enclosed is a copy of the Workover Well History to include with the Well Completion Report dated 7/1/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU11/L58 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Oiland Gas Company Well History - Initial Report- Dally Inatructio,a: Prepare and submit *the "IMIIM II,poE' on the first Wednesday after a well Is spudded or workover operations are started. Dally work prior to apud~llng Ihould be summarized on the form giving inclusive dates only. District I County. parish or borough Alaska I North Slope Borough Field Lease or Unit Prudhoe Bay ADL 28328 Auth. or W.O. no. ]Title AFE 903051 I Recompletion State Alaska Well no. DS 9-16 Nabors 1-ES Operator IARCO W.I. ARCO Alaska, Inc. ~ 21.66% Spudded or W.O. begUnworkover iD.re 4/17/85 IH°ur' 1530 hrs. ]PrlorstatuslfaW.O. Date and depth as of 8:00 a.m. 4/17/85 Complete record for each day reported 4/18/85 4/19/85 4/20185 thru 4/22/85 4/23/85 4124185 The above is correct 7" @ 12,588' 12,543' PBTD MIRU. 7" @ 12,588' - _,o =Lo~ PBTD, Monitor well 9.1 ppg Brine Accept ri~ @ 1530 hfs, 4/17/85. Pull BPV. Kill'well by bullhead'g 300 bbls sea wtr, 20 bbls 10.0 ppg NaC1 spacer & 100 bbls 10.8 kill pill, followed w/20 bbls, 10.0 ppg spacer. Spot w/9.1 ppg NaC1 Brine. Monitor well. Signature ,~ For form preparation and' dlg/l~butlon, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. 7" @ 12,588' 12,546' PBTD, Pmp BridgeSal pill 9.1 ppg Brine Set BPV. ND tree, NU &tst BOPE to 5000 psi. RU & pull hgr. RIH w/spear; unable to spear tbg. TIH w/OS, latch onto tbg, pull to surf. Pmp 9.1 ppg brine dn tbg. Pmp 100 bbls BridgeSal pill to kill well. 7" @ 12,588' 12,546' PBTD, Mill up pkr 9.1'ppg Brine Spot BridgeSal pill; hole taking fluid. Pmp 150 bbls kill pill, monitor well; stable. RU & pull 5~" tbg. Chg rams to -"'_3½" &tst to 5000 psi. MU OS & BHA, RIH w/3½" DP, tag fsh @ 10,798', sting over fish w/OS, unlatch K-Anchor, POOH. PU mill'g assy, RIH to 10,831', mill up pkr. 7" @ 12,588' 12,546' PBTD, POH w/pkr 9.6 ppg Brine Mill on pkr. SI well & record pressure. SIDPP = 200 psi, SICP = 500 psi. Wt up brine to 9.6 & monitor well. Mill on pkr, POH w/pkr & tail pipe assy. 7" @ 12,588' 12,546' PBTD, Circ 9.6 ppg Brine POH w/pkr & tailpipe assy. MU Bkr BP, RIH, set @ 2640', POH. Pull pack-off & chg out same. Tst to 5000 psi. MU Bkr retrv tl, RIH, latch onto BP, POOH. RIH w/scrpr & boot bskt, circ @ 11,070' TOL. Date I Title ARCO Oil and Gas Company,~,'~' Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores., Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ]County or Parish I State Alaska North Slope Borough Field ~Lease or Unit Prudhoe Bay I ADL 28328 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 4/25/85 4/26/85 4/27/85 thru 4/29/85 4/30/85 5/01/85 Alaska Well no. DS 9-16 7" @ 12,588' 12,546' PBTD, LD RTTS 9.5+ ppg Brine Fin circ hole, POH w/bit & JB. RIH w/RTTS, set @ 2562', tst 3½" x 9-5/8" ann to 2000 psi. RIH w/RTTS, press 9-5/8" x 13-3/8" @ selected intervals; appears 9-5/8" pack-off failure, POOH. 7" @ 12,588' 12,546' PBTD, Spot BridgeSal pill 9.4 NaC1 Att to tst 9-5/8" pack-off; would not tst. Retorque lockdn screws & retst pack-off; OK. RIH w/6" bit/JB/csg scrprs, tag junk @ 11,220', wrk & push to 12,170', rotate to 1,2,544' DPM, circ, hole started taking fluid. Wtr back wt to 9.4 ppg, circ & prep to pull to TeL & spot BridgeSal pill. 7" @ 12,588' 12,546' PBTD, RIH w/Bkr pkr 9.1NaC1 Pmp kl00 bbls 10.8 ppg pill, bullhead to perfs, POOH. RU Schl, log GR/CBL/CET/CCL f/12,465'-10,960', POH, RD Schl. RU GeoVann 5" perf gun, RIH, fire guns, POH. RIH w/6" bit/JB/csg scrprs, tag fill @ 12,484' DPM, POH to TOL, circ hole. RIH to fill @ 12,484', wsh & rm fill to PBTD, POH. RU Schl, RIH w/JB & gage ring, stopped @ 12,272', POH, RD Schl. RU Schl, RIH w/JB & 5.937" gage ring, stopped @ 12,272'. RIH w/CCL/wt bar, 3.375" OD, stopped @ 12,507'. MU Bkr FB-1 pkr w/2.813 nipple on setting tl, RIH. 7" @ 12,588' 12,507' Fill, POH w/setting tl '9..1NaC1 Set Bkr FB-1 pkr w/top @ 12,261', tail @ 12,272', POH, RD Schl. RIH w/pkr tailpipe assy on DP, drop setting ball, press up to 2500 psi, set pkr, POH, LD DP. RU Schl, RIH w/Bkr FB-1 pkr w/3.500" nipple, set pkr w/top @ 11,925', tail @ 11,936', POH. 7" @ 12,588' 12,507' Fill, Filter brine & displ well 9.1 NaC1 RD Schl, chg pipe rams to 5½". Rn 263 [ts, 5½", 17#, L-80 8RD LTC ABM non-coated tbg + 2 [ts, 4½", 12.6#, N-80 BTC tbg, lnd tbg hgr w/BP vlv in place. SSSV @ 2210', PBR @ 10,990', FHL Pkr @ 11,001', 3.813" Nipple @ 11,093', TT @ 11,106' FB-1Pkr @ 12,111', FB-1Pkr @ 12,261' w/pkr tail @ 12,272'. ND BOPE, NU & tst tree to 5000 psi. Displ well w/filtered brine. The above is correct Signature For form preparation and di.~ibution see Procedures Manual SectiOn Drilling, Pages 86 and 87 IDate ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Attach descript en of al cores. Work performed by Producing Section will be reported on "Interim" sheets until final Number all drill stem tests sequentially. . ......... ,--~ 1~ Sub'nit "Interim" sheets when filled out but not ess frequently than every 30 days, or (2) completion. Report official or representative Test on ~',-~=, ,u,,,,. -. on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District IState Alaska Field Alaska Prudhoe Bay CountyNorth Slope Borough or Parish Lease or Unit ADL 28328 Well no. DS 9-16 W/O Date and deptl~ as of 8:00 a.m. 5/02/85 5/03/85 5/04/85 thru 5/06/85 5/07/85 Complete record for each day while drilling or workover in progress 7" @ 12,588' 12,507' Fill, RIH w/temp log 8.6 Sea wtr in tbg & ann w/±2000' diesel on top in tbg & ann Cln filter unit. Pmp 440 bbls sea wtr dn tbg, followed by diesel. RU lubr & tst. RIH, pull dummy SSSV. PU tst plug, RIH, set in DB nipple, POOH. Att to set pkr & tst tbg. Press tbg to 2500 psi, drop in press on tbg w/inc of press on ann. Bled press off tbg, 900 psi on ann. RIH w/std'g vlv retrv tl, retrv DB std'g vlv. Redress std'g vlv. RIH & set DB vlv in nipple. Press up tbg to 1500 psi, ann coming up to 800 psi. Bled press & monitor. Press on ann dropped f/700 psi to 0 psi in 24 min. RD Otis. RU Camco E-In & RIH w/temp logging tl. 7" @ 12,588' 12,507' Fill, POOH w/blanking plug 8.6 Sea wtr in tbg & ann w/±2000' diesel on top in tbg & ann RIH, rn temp tl; shows PBR to be sheared out & pkr moved dnhole 8', RD E-line. Open tbg & ck f/flow; tbg flowing ±1BPM. SI w/lO0 psi on tbg. RU S/L unit, tst lubr to 1000 psi. RIH to retrv equalizing prong, latch equalizing prong, POOH. RIH to pull std'g vlv, POOH w/same. PU DB blanking plug, RIH & set same. Equalize tbg & ann; tbg flowing 3 bbl/min & ann dead. RU Otis, RIH to retrv blanking plug, POOH w/same. 7" @ 12,588' 12,507' Fill, LD 5½" tbg 8.6 Sea wtr RD Ot£s S/L unit. Kill well w/9.0 sea wtr, observe well; losing -fluid. Pmp kill pill into perfs, well stabilized. ND tree, NU BOPE. Pmp kill pill into perfs while bldg vol w/9.3# brine. A~t to pmp dn ann, taking rtns f/tbg. Circ dn tbg, pmp kill pill & chase w/9.3# brine. Tst BOPE. RU & unsting f/PBR, monitor well. RU & pull 3 jts, 5½" tbg & LD, observe well. Ann dead, tbg showing slight inc, well stable. POH w/5½" tbg & LD same. 7" @ 12,588' 12,507' PB, POH w/pkr & tailpipe 9.3+ POH w/5½" tbg & LD same. Chg rams to 3½". @ 11,032', unset & POH w/pkr & tailpipe. MU BHA, RIH, tag pkr The above is correct IDate ITitle 6/25/85 For form preparation and dJstributi~'n see Procedures Manual Section 10? Drilling, Pages 86 and 87 Drilli~g~per~iD~D~ent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations, if testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach descrit~tion of all cores., Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska North Slope Borough Field ~Lease or Unit Prudhoe Bay I ADL 28328 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 6/08/85 6/09/85 6/10/85 7" @ 12,588' 12,507' PB, POH, LD 3½" DP 9.3+ Sea wtr/NaCl Circ gas cut mud thru choke untol 9.3+ rtns to surf; well stable. POH w/pkr assy. MU BHA, RIH w/3½" DP, tag TOL, CBU, POH & LD 3½" DP. 7" @ 12,588' 12,507' PB, PU tbg hgr 9.4 Sea wtr/NaC1 Chg pipe rams to 5½", RIH w/5½" compl string. 7" @ 12,588' 12,507' PB, Jarring on plug to set & shear off 8.6 ppg sea wtr in tbg w/±3 bbls diesel cap - 9.4 ppg NaC1 in ann Lnd tbg. ND BOPE, NU & tst tree & pack-off to 5000 psi. Displ tbg w/8.6 ppg sea wtr, followed by diesel cap. Fill ann w/9.4 ppg NaC1. RU Otis, RIH, pull dummy SSSV. RIH w/3.813" DB plug to nipple @ 11,072', att to set in nipple, att to jar in place w/press on tbg. Alaska IWell no. DS 9-16 W/O The above is correct Signature For form preparation and distrli~3ution see Procedures Manual Sectiol'~ 10, Drilling, Pages 86 and 87 IDate ]Title 6/25/85 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first W. ednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District I State Alaska North Slope Borough Alaska Field Prudhoe Bay Auth. or W.O. no, AFE 903051 Nabors i-ES Operator ARCO Alaska, Inc. Spudded or W.O. begun Workover Date and depth as of 8:00 a.m. Old TD Released rig ICounty or Parish Lease or Unit Title J Well no. ADL 28328 DS 9-16 Reconmletion A.R.Co. W.,.21' 66% Date 4/17/85 5/11/85 1100 hrs. Complete record for each day reported Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well I our [Prior status if a W,O. 1530 hrs. I 7" @ 12,588' 12,507' PB, RR : 8.6 ppg sea wtr in tbg, 9.4 NaC1 in ann w/diesel cap Bled off tbg press, move plug uphole 10', hit tight spot. Wrk tls, appeared plug sheared off rn'g tl, POOH. While POH, press ann to 750 psi, bled off 25 psi/1 hr. Indicates pkr is set. POH w/WL, In parted, dropped tl string dn tbg. RD Otis. Set BPV. RR @ 1100 hrs, 5/10/85. Classifications (oil, gas, etc.) 011 New TD Kin~epth PB 12,546' PBTD lDate of rig · 5/10/85 Rotary Producing method Flowing ~i~ ¢ ~:' !~'? Potential test data IType completion (single, dual, etc.) Single Official reservoir name(s) Prudhoe Bay Well no. Date Reservoir Producing Interval Oil or gas Test time Production OiJ ~n ]pst : ~.,~T_:, ~,,, IGas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Al~y~a~l.e . . Effective date corrected . ,; t~,~ ,}~ , ~ The above is correct Signature~-~1¢ ~'d~~ J Date 6/25/85 I Title For form preparation and distribu~n, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, inc Post Office ~ox 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date' August /, 1985 Reference: ARCO CH Finals 3-7'~' Temp./Spinner 7-24/25-85 Run 1 5" Camco 3-16' CET 4-3-85 1 5" Sch 3-16" CET 4-7-85 2 5" Sch 5-13~ CNL 11-26-84 3 5" Sch 5-13~CET 4-29-85 1 5" Sch 6-19- Perf Record 6-9-85 1 5" Sch 7-22~ CNL 5-16-85 1 5" GO 9-4~' EPL 6-13-85 1 5" Sch 9-16~ CET 4-26-85 .1 5" Sch 9-16/ CBL ' 4-26-85 1 5" Sch 9-35' PDK 100 7-8-85 1 5" DA 11-8~CBL 7-/3/4-85 1 5" DA ll-13ZCBL 7-3-85 1 5" DA 12-21' CCL/Perf 11-29-84 1 5" Sch 16-13-'Spinner 7-25/26-85 1 5" Camco 17-14ZCBL 4-14-85 1 5" Sch Please sign as receipt of data. Received by Pam Lambert ATO 1429C Trans 252 Chewron Expl. Serwices Ext. Exploration Exxon Marathon Mobil .,,,a ~j~; ~ ~s Coos. Commission t!.~c ., borage Phillips PB Well Files R&D Sohio State of Alaska Tmxaco ARCO AlasKa. Inc. ~s ,3 Subs~cliary of AllanticRichfielclCornDanv ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telepho.ne 907 276 1215 Date: Reference: ARCO · l~J~ ~. ~ 9-,-16 Spinner 9-17 Spinner 13-22 Spinner c~f3- 23A Spinner ~i3-23~ spinner July 24, 1985 CH Finals 5-12-85 7-10-85 7-10-85 b-26-85 7-11-85 6-2b-85 Run 1 5" 1 5" 1 5" 1 5" 1 5" 1 5" DA Otis Otis Otis Otis Otis Please sign as receipt of data. Received by Pam Lambert Cons. Commission J'-,nchorage ATO 1429C Trans 223 Chevron D&M · Expl. Services Ext. Exploration Exxon Marathon Mobil Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Post Office BOA ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 3, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 9-16 Dear Mr. Chatterton: Enclosed is the Well Completion Report for the subject well. I have not yet received a copy of the Workover Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L46 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany -- STATE OF ALASKA ALASKA:.:_ _ AND GAS CONSERVATION 0¢- 41SSlON ! WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well RECOHPLET I ON OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICEX~ WATFR IN.IF£TAR ,. '~. Name of Operator 7. Permit Number ARCO Alaska, Inc, 77-37 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20257 4. Location of well at surface 9. Unit or Lease Name 877' FSL, 175' FWL, Sec.1, T10N, R15E, UN Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1414' FSL, 868' FEL, Sec.3, T10N, R15E, UM 9-16 At Total Depth 1 1. Field and Pool 1561' FSL, 1425' FEL, Sec.3, T10N, R15E, UM Prudhoe Bay Field , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Oi 1 Pool 54' RKB ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~ 15. Water Depth, if offshore 116. No. of Completions 09/08/77 09/28/77 10/07/77**I N/A feet MS LI 1 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set ] 21. Thickness of Permafrost 12589'ND,9195'TVD 12546'MD,9165'TVD YES [~X NO [] 2201 feet MD 1900' (Approx) '22. Type Electric or Other Logs Run D IL/SP, BHCS/GR, GR/CNL/FDC/Cal, GR/CNL/CCL/FDC, GR/CBL/CET/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 Surf 100' 32" 258 sx Arctic Set II 13-3/8" 72.0# MN-80 Surf 2727' 17-1/2" 3100 sx Arctic Set 9-5/8" 47.0# S00-95 Surf 11370' 12-1/4" 1000 sx Class G & 300 ,.x AS I 7" 29.0# L-80 10,070' 12588' -- 520 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD ,, interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 12,375'-12,395'MD (20') *11,810'-11,830'MD 3-1/2" 12,272' 12,261' & 12,111' 12,350'-12,370'MD (20') '11,830'-11,850'MD 4½" & 5½" 11~936' 11,925' & 11,001' 12,313'-12,333'MD (20') *11,850'-11,860'MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12,298'-12,313'MD (15') *11,880'-11,890'MD DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED ,. 12,220'-12,248'MD (28') '11,890'-11,910'MD N/A 12,140'-12,186'MD (46') '11,942'-11,962'MD 8649' -8914' TVD *11,990'-12,010' MD *Added 9/10/84 - 4 spf (cont'd on attached sheet) 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I "Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I ,.. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAvITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ,iU L 0,'., 1985 i,,~ ,.~ ,. · ' ...,;:.,:, ,~ ,~,i ,:,., u,'-:s (3()ns. Commissior.. Anchorage ! Form 10-407 ** The well was recompleted and reperforated on 5/10/85. GRU10/WC04 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOI'OGIC 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 11 ~779~ 8628~ N/A 0WC 1 2 ~ z~:37 ~ 9089~ Base Sadlerochit , ' ..12,478' 9118' · · . 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Well Completion or Reeompletion Report and Log 9-16 (¢ont'd) ITEM #24: The intervals from 11,810' - 11,910' and from 11,945' - 12,020' were reperforated with 4 spf on 04/28/85. GRUIO/WCO4b:tw RECEIVED J U L 0 ~, .Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office B¢~ ]00360 Anchorage, Alaska 99510-0360 Telephone 907 ;276 1215 July 1, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports Dear Mr. Chatterton' Enclosed are Subsequent Sundry Reports for the following wells' 1A-3 1A-4 DS 4-9 DS 9-16 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU10/L37 Encl osures ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA - ALASKA t _AND GAS CONSERVATION CC ¢IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE L I_X~ WATER INJECTOR 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-37 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20257 OTHER [] 4. Location of Well Surface: 877' FSL, 175' FWL, $ec.1, T10N, R15E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 54' 12. I 6. Lease Designation and Serial No. ADL 28328 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-16 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (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.) SUBSEQUENT REPORT OF: (Submit in Duplicate) "~L. 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). Accepted rig ~ 1530 hfs, 04/17/85. Killed well. ND tree. NU BOPE. Pulled 5-1/2" tubing. Milled & pulled pkr. Ran GR/CBL/CET/CCL f/12,465' - 10,960'. Perf'd well. Set FB-1 pkr ~ 12,261' & pkr tail ~ 12,272'. Stabbed 3-1/2" tbg into pkr @ 12,261' and set 2nd pkr @ 12,111'. RIH w/FB-1 pkr ~ set ~ 11,925' w/pkr tail ~ 11,936'. Ran 5-1/2"/4-1/2" completion assy w/pkr @ 11,001' & SSSV ~ 2210'. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/brine. Ran temperature log. (Log showed that the PBR was sheared out and the pkr moved 8' downhole.) Pumped kill pill into perfs. ND tree. NU BOPE. Pulled 5-1/2" tubing, pkr, & tailpipe. Reran 5-1/2" completion assy w/SSSV ~ 2201' & FHL pkr @ 10,786'. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp tubing w/300 bbls seawater and 3 bbls diesel. Filled annulus w/37 bbls diesel. Secured well and released rig ~ 1100 hrs, 05/10/85. ECEiVED 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~ ~~ ,~~~/ Title, ASSOCi_=te E,g'." neet The space bel~b for Commission use Conditions of APproval, if any: By Order of Approved by COMMISSIONER the Commission Date__ _ . Form 10-403 GRU9/SN11 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. -'~ Post Office B(~ 0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 13, 1985 Mr. C. V. Chatterton Commi ss ioner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the May monthly reports for the following wells' 3B-4 1Q-13 1R-6 2V-16 4-9 (workover) 3B-5 1Q-14 1R-7 L1-1 4-13 (workover) 3B-6 1Q-15 2V-13 L1-10 4-30 3B-7 1Q-16 2V-14 L2-24 4-31 3B-8 1R-5 2V-15 L2-28 9-34 9-35 9-16 (workover) 11-13 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRUg/L56 Enclosures RECEIVED JUN 4 1 185 Ataska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA --' ~ ALASKAO AND GAS CONSERVATION COl, ,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [] Workover operation [] XX 2. Name of operator 7. Permit No. ARCO Alaska, Inc, 77-37 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20257 4. Location of Well atsurface 877' FSL, 175' FWL, See.l, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54' RKB ADL 28328 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 9-16 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of Ma), , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig 1530 hfs, 4/17/85, Killed well, ND tree, NU BOPE, Pulled 5-1/2" tubing, Milled & pulled pkr, Ran GR/CBL/CET/CCL. Perf'd well, WL set #1 pkr ~ 12,261', tail ~ 12,272'. DP set #2 pkr @ 12,111'. Stabbed 3-1/2" tbg into #1 pkr. WL set #3 pkr ~ 11,925', pkr tail ~ 11,936'. Ran 5-1/2"/4-1/2" completion string w/pkr @ 11,001', SSSV ~ 2210'. ND BOP. NU tree. Displaced to brine. Ran temp. log (showed that PBR was sheared out and pkr moved 8' downhole). Pumped kill pill (see attached sheet) 13. Casing or liner rgn and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run GR/CBL/CET/CCL f/12,465' Temp. Log - 10,960' 6. DSTdata, perforatingdata, showsofH2S, miscellaneousdata Perforating data is not available at this time. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OTE -Report ~/n 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 Con§ervation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 ..... , ..... Submit in duplicate Monthly RePort of Drilling and Workover oPerations 9-16 (cont'd) Item 12: into perfs. NU BOPE. NU tree. Pulled 5-1/2" completion assy w/SSSV ~ 2201' & FHL pkr @ 10,786'. ND BOPE. NU tree & tstd. Set BPV. Secured well & released rig @ 1100 hfs, 05/10/85. ARCO Alaska, Inc Post Office b,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 15, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton' Enclosed are the April monthly reports for the following wells' 1Q-1 2U-10 2V-12 3B-16 9-28 1Q-2 2U-11 2V-13 3-16 (workover) 17-14 1Q-16 2U-12 3B-1 4-32 L1-1 1R-5 2V-10 3B-2 9-16 (workover) L~-9 2U-9 2V-11 3B-3 9-27 L2-28 If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU6/LI06 Enclosures ~ask~t ~',l & O;-~ Cons. Com~nJssion ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA '- ALASKA O,.- AND GAS CONSERVATION COk..ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling well [] Workover operation X[~( 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 77-37 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20257 4. Location of Well at surface 877' FSL, 175' FWL, Sec.1, TION, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 21 ' PAD 6. Lease Designation and Serial No. ADL 28328 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 9-16 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool For the Month of Apri 1 , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Accepted rig 1530 hrs, 4/17/85. Killed well. ND tree. NU BOPE. Pulled 5-1/2" tubing. Milled & pulled pkr. Ran GR/CBL/CET/CCL. Perf'd well. WL set #1 pkr ~ 12,261', tail 12,272'. DP set #2 pkr @ 12,111 '. Stabbed 3-1/2" tbg into #1 pkr. WL set #3 pkr 11,925', pkr tail @ 11,936'. Ran 5-1/2"/4-1/2" completion string w/pkr @ 11,001', SSSV 2210'. ND BOP. NU tree. Displaced to brine as of 05/01/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests NONE 14. Coring resume and brief description NONE 15. Logs run and depth where run GR/CBL/CET/CCL f/12,465' - 10,960' 6. DST data, perforating data, shows of H2S, miscellaneous data Perforating data is not available at this time. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Repo,t~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 C'~nservation Commission by the 15th of the succeeding month, unless otherwise directed. Submit in duplicate ARCO Alaska, Inc. Post Office b,~.~, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 20, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' DS 9-16 Dear Mr. Chatterton' Enclosed is the Sundry Notice for the subject well. We propose to workover the above well for use as a Sadlerochit water injector in the Prudhoe Water Flood. This work is scheduled beginning April, 1985. If you have any questions, please call me at 263-4610. "~/-~Since~ T. L. Fithian Area Drilling Engineer TLF/GLA/tw SN/L019 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA UIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, inc. 3. Ad~r. es~). Box 100360, Anchorage, AK 99510 4. Locatio~ of Well Surface: 877' FSL, 175' FWL, Sec.1, T10N, ELSE, UH 7. Permit No. 77-37 8. APl Number 50-- 029-20257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-16 11. Field and Pool Prudhoe Bay Fi eld 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool PAD 21' I ADL 28328 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEOUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [~' Alter Casing [] Perforations [] Altering Casing [] Stim u late [] Abandon [] St im ulation [] Aba ndonment [] 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 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 perform a workover on 9-16 in April, 1985. the following manner: The workover will be performed in 1, 2. 3. 4. 5. 6. 7. 8. Kill well prior to rig acceptance. MIRU workover rig. ~ ::' ,"., ~.,! {~ r~ ~:::/u ..~ ND tree. NU BOP stack. Pull 5-1/2" completion assembly. Alaska 0il & U[is C0iis. '~ ~,;.~.' r~ Cleanout to BPTD. Anch0r~o Perforate addition Sadlerochit intervals for increased water injectivity. Recomplete well with 5-1/2", 17~ IPC tubing. Additional packers will be installed in the 7" liner with profiles f~r downhole flow control. Secure well and release rig. A subsequent sundry will be submitted following the completion of this workover detailing the additional perforations and completion details. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The subsurface safety valve will be installed and tested upon the conclusion of the job. 14. I hereby certify that the for,~going is true Signed ~"?/'. /,~t_-~~/~' The space below for Commission use and correct to the best of my knowledge. Title Area Drilling Engineer Conditions of Approval, if any: · Approved by COMMISSIONER .Approved Co~y R®turnm;l By Order of the Commission Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate ARCo Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 275 1215 Date: February 18, 1985 Reference: ARCO CH Final zzg-16 Injection Profile Survey 1-12-85 Run 1 5" GO j13-21 Injection Profile Survey 1-14-85 Run 1 5" GO /15-7 Gamma Ray Log ,/15-8 Gamma Ray Log /15-9 Gamma Ray Log ~/~15-16 Collar Log 15-20 Gamma Ray Log >~14-29 Spinner /J14-30 Spinner 1-27-85 Run 1 5" Camco 1-28-85 Run 1 5" Camco 2-4-85 Run 1 5" Camco 1-10-85 Run 1 5" GO 1-25-85 Run 2 5" Camco 2-2-85 Run 1 5" Camco 1-30-85 Run 2 5" Camco ~Please sign and return the attached copy as receipt of data, Received by Pam Lambert ATO 1429C Trans #~)~ FEB20 1985 Alaska Oil & Bas Cons. Commission Anch0ra[~e Chevron D & M Expl. Services Ext. Exploration Exxon Marathon Mobil Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Alaska, Inc. Prudhoe Bay [ ;eering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 22, 1985 Mr. C. V. "Chat" Chatterton Alaska Oil 'and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 3-6 DS 3-7 DS 3-10 DS 3-18 DS 4-6 DS 4-8 DS 4-11 DS 4-14 DS 4-I5 DS 9-8 DS 9-10 DS 9-12 DS 9-14 DS 9-15 DS 9-16 Permit # 76-60 Permit # 76-53 Permit # 79-21 Permit # 79-103 Permit # 76-42 Permit # 76-10 Permit # 78-6 Permit # 78-36 Permit # 78-37 Permit # 76-70 Permit # 76-82 Permit # 77-7 Permit # 77-25 Permit # 77-36 Permit # 77-37 DS 9-18 DS 9-17 DS 9-19 DS 9-20 DS 11-2 DS 16-I DS 16-2 DS 16-3 DS 16-5 Permit # 77-39 Permit # 77-38 Permit # 77-40 Permit # 77-41 Permit # 81-128 Permit # 80-136 Permit # 80-150 Permit # 76-83 Permit # 81-37 DS 16-10 Permit # 80-04 DS 16-11 Permit # 80-118 DS 16-I6 Permit # 80-I27 DS 17-6 Permit # 80-132 DS 17-8 Permit # 81-74 DS i7-10 Permit # 81-97 Dear Hr. Chatterton: Attached are Subsequent Sundry Notices for work completed on the above-mentioned wells. Very truly yours, D. F. S cheve R E C E i V E O At t achment s JAN 2 5 1085 cc: Sohio Alaska Petroleum Company Alaska 0il & Gas Cons. Commlsslor~ Anchorage ARCO Alaska, Inc, Is a Subsidiary ot AtlanflcRIchfleldCompan¥ STATE OF ALASKA ALASKA uIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WE LL]I[3 OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, klaska 99510 4. Location of Well 877'N & 175'E of SW cr Sec. 1, T10N, R15E, UM 1414'N & 868'W of SE cr Sec. 3, T10N, R15E, UM 1561'N & 1425'W of SE cr Sec. 3, T10N, R15E, UM 7. Permit No. 77-37 8. APl Number 50- 029-20257 9. Unit or Lease Name Prudhoe Bay []nit 10. Well Number DS 9-16 11. Field and Pool Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 54' RKB I ADL 28328 12. 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 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). kRCO Alaska, Inc. has converted DS 9-16 to water injection se~Tice. part of the Flow Station 2 waterflood project. The well began receiving water on Jtune 14, 1984. .The well is 14. I hereby cg~iifY that the foregoing is true and correct to the best of my knowledge. Signed~ . .... Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate D~,, '7 I A F;; C'. 0 A 1. a _'-.': k a, I n c. "" ..... i ;3 r-', S 60 r' (3 I':':r', × .. F':'~ 'n ,.':: h ,:::,'r' .:':~ '.::j (-.?, ft [ a ..s- k 99 f.~ i 0 E:, t ';." i;; I| .'- ..... i) r-.'i .. j... ARCO Alaska, IF '. ~ii~ Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer October 12, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-14 DS 9-16~ DS 9-18 Permit No. 77-25 Permit No. 77-37 Permit No. 77-39 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/la Enclosures cc: SOHIO Alaska Petroleum Co. File PI(DS 9-14)W4-3 Pi(DS 9-16)W4-3' Pi(DS 9-18)W4-3 RECEIVED OCT 1 Alaska 0il & I~as Cons. commission Anchorage ~-- STATE OF ALASKA . ~- ~ ALASK, ,-;,. AND GAS CONSERVATION £ ilSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~ Water Injector . / 2. Name of Operator 7. Permit Number / ARCO Alaska, Inc. 77-37 ,, 3. Address 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50-029-20257 4. Location of well at surface 9'i Unit or Lease Name 877'N & 175'E of SW cr, Sec. 1, TiON, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1414'N & 868'W of SE cr, Sec. 3, T10N, R15E, UM DS 9-16 (33-3-10-15) At Total Depth 11. Field and Pool 1561'N & 1425'W of SE cr, Sec. 3, T10N, R15E, UM Prudhoe Bay Field , 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 54' RKBI ADL 28328 ,, , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 9/08/77 9/28/77 10/7/77 (per£ed 11/23/77)J feet MSL Sin§le , 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 12589'MD 9195'TVD 12546' MD 9165'TVD YES~ NO []I 2213 feet MD 1900' (approx.) , 22. Type Electric or Other Logs Run DIL/SP, BHCS/GR, GR/CNL/FOC/CAL, GR/CNL/CCL/FDL 23. CASING, LINER AND CEMENTING RECORD ,, , SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , , 20" 94# H-40' Surf. 100' 32" 258SX Articset II I 13-3/8" 72# MN-80 Surf. 2727 ' 17~" 3100SX Articset 9-5/8" 47# S0095 Surf. 11370' 12~4" 10000SX Class G 7" 29~A L-80 10070 ' 12588 ' -- 520SX , 2~. 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) 12375 - 12395' MD (20') *11810 - 11830' MD 5½ 10~963 10~837 12350 - 12370' MD (20') *11830 - 11850' MD ,. 12313 - 12333' MD (20') *11850 - 11860' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12298 - 12313' MD (15') *11880 - 11890' MD DEPTH INTERVAL (MD) AMOUNT& KIND OF MAT"ERIAL USED 12220 - 12248' MD (28') *11890 - 11910' MI) 12140- 12186' MD (46') *11942 - 11962' MD N/A 8649 - 8914' TVD *11990 - 12010' MD *Added 9-10-84 - 4 spf 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) N/AI Future Injector " Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-el L RATIO TEST PERIOD ~ I~'i'ow Tubing Casing PresSure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) ' Press. 24-HOUR RATE J~ 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - - GEOLOGIC~MARKERS: . , ' '" . ": i ' ' ' ::F~oRMATiON"~i~;~'izs:' ': ' :" '" ' . , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~~~,~~--~__~~ Title Regional 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 elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, I Prudhoe I=ay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer October 11, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 9-14 - Permit No. 77-25 DS 9-16 - Permit No. 77-37 DS 9-18 - Permit No. 77-39 Dear Mr. Chatterton: Enclosed are "Subsequent" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JB/mjb Attachments cc: SOHIO Alaska Petroleum Co. File Pi(DS 9-14)W1-3 File Pi(DS 9-16)W1-3 File Pi(DS 9-18)W1-3 RECEIVED OCT 1 l l lt Alaska Oil & Gas Cons. commission Anchorage A~I'~ Al.,.k~. Inr i~ m'R,ihel~llarv nf AllantlcRIchfleldComl:)any -~ --' STATE OF ALASKA - - ALAS[ O,,_AND GAS CONSERVATION 3 IISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 877'N & 175'E of SW cr Sec 1, T10N, R15E,UM (Producing Interval) 1414'N & 868'W of SE cr Sec 3, T10N, R15E,UM (Total Depth) 1561'N & 1425'W of SE cr Sec 3, T10N, R15E,UM 5. Elevation in feet (indicate KB, DF, etc.) 54' RKB 6. Lease Designation and Serial No. ADL 28328 7. Permit No. 77-37 8. APl Number 50- 029-20257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 9-16 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: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations E~. 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 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 9/10/84. RU perforating unit, pressure tested equipment. RIH with gun #1, shot interval 11990 - 12010' MD (4 spf). Shut-in well, POOH, all shots fired. RIH with gun %2, shot interval 11942 - 11962' MD (4 spf). Shut-in well, POOH, all shots fired. RIH with gun %3, shot interval 11890 - 11910' MD (4 spf). Shut-in well, POOH, all shots fired. RIH with gun %4 shot select fire interval 11880' - 11890' MD, pulled up, shot select fire interval 11850' - 11860' MD (4 spf). Shut-in well, POOH, all shots fired. RIH with gun #5, shot interval 11830 - 11850' MD (4 spf), shut-in well, POOH, all shots fired. RIH with gun %6, shot interval 11810 - 11830' MD (4 spf). Shut-in well. POOH, all shots fired. Ran SSSV, secured well, RD. _ Ref: BHCS 9/28/77 Alaska 0il & Gas Cous, Commission .Anchorage, 14. I hereb~rtify that th~oregoing is true and correct to the best of my knowledge. Signed.~/~~/f~~~/_ ......../~// Title ~ Regional Engineer The spa'ce below for Commission use Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Y Form 10-403 Rev. 7-1,80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, (: .i.i-.'!'i:.: .i~ Prudhoe Bay ~-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer August 28, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mro Chatterton: Re: DS 9-14 - Permit No. 77-25 · D~,,p'9-16 Permit No. 77-37 DS 9-18 - Permit No. 77-38 Enclosed are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/mjb Attachments cc: SOHIO Alaska Petroleum Co. File PI(DS 9-14)W1-3 File P1 (DS 9-16)W1-3 File Pi(DS 9-18)Wl-3 Alaska 0il & Gas ARCO Alaska. Inc. I$ a Sub-ldlarv of AtlantlcRIchfleldComDan¥ ~- ..... STATE OF ALASKA ...... ALASI~ .. ·AND GAS CONSERVATION IlSSION SUNDRY NOTICES AND 'REPORTS ON WELLS DRILLING WELL[] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 877'N & 175'E of SW cr Sec 1, T10N, R15E,UM (Producing Interval) 1414'N & 868'W of SE cr Sec 3, T10N, R15E,UM (Total Depth) 1561'N & 1425'W of SE cr Sec 3, T10N, R15E,UM 5. Elevation in feet (indicate KB, DF, etc.) t 6. Lease Designation and Serial No. 54' RKB I ADL 28328 12. 7. Permit No. 77-37 8. APl Number 50- 029-20257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number D.S. 9-16 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 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 :1~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Welt [] 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 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 add perforations to DS 9-16 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 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 11810 - 11860' MD (50') 11880 - 11910' MD (30') 11942 - 11962' MD (20') 11990 - 12010' MD (40') REF: BHCS 9/28/77 RECEIVED AUG 5 01~ Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby/~ertify that_the foregoing is true and correct to the beSt of my knowledge. Signed ..... Title Regional Engi n~r . The space below for Commission use Date Conditions of APproval, if any: Approved by. COMM ISS ION ER Approved Cop), Returned By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, h Post Office Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 August 1, 1984 Reference: ARCO Cased Hole Finals D.S. 2-17~/ 5-23-84 D.S. 7-19-~ 6-15-84 D.S. 9-14 ~/ 7-20-84 D.S. 9-15/~ 7-20-84 D.S. 9-16 7-21-84 D.S. 9-17-' 7-21-84 D.S. 9-20/ 7-19-84 D.S. 11-7~"~' 6-15-84 D.S. 13-27 6-2-84 Basket Flowmeter Spinner Spinner Spinner Spinner Spinner Spinner CN/MSN/GR Diff Temp Run 1 5" Camco Run 1 5" Otis Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" Camco Run 1 5" DA Run 1 5" GO L/Please~ sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. #302 Chevron D&M Drilling Mob i 1 Phillips Exp. Services Prudhoe Bay Well Files Ext. Exploration R& D Exx0t~ Carolyn Smith Getty Sohio Marathon State of Alaska ARCO Alaska, Im Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer June 13, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9 Water Injectors Permit Nos: 76-70, 76-82, 77-7, 77-25, 77-36, 77-37, 77-38, 77-39, 77-40, 77-41 Enclosed are the Sundry Notices for Change of Well Status for the proposed Drill Site 9 Water Injectors. Very truly yours, D. F. Scheve DFS:SDC:kg Enclosures cc: SOHIO Alaska Petroleum Co. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ~---- STATE OF ALASKA ALASKA . AND GAS CONSERVATION Cf. IlSSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WEL, [] COMPLETED WELL ?. Permit No. 77-37 50- 029-20257 ll. Fieldand Pool 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 877'N & 175'E of SW cr Sec. 1, T10N, R15E, UM 1414'N & 868'W of SE cr Sec. 3, T10N, R15E, UM 1561'N & 1425'W of SE cr Sec,, 3: T10N: R15E: TTM 5. Elevation in feet (indicate KB, DF, etc.)[ 6. Lease Designation and Serial No. __ 54' RKB ADT. 28328 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stim u late [] Abandon [] St im u lation 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. proposes to change Well 9-16 status from oil producer to water injector. It will be operated as part of the Prudhoe Bay Waterflood Project. RECEIVED JUN ! 4 ~984 Alaska Oil & Gas Cons, Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~ ~.~,/r.~~.,~ Title Regiorzal E~qineer The space belo~ f~r Com~ssion use Date Conditions of Approval, if any: ORIGIN,II SIGNED t~Y !.O,?..!E C. SMITH" Approved by COMMISSIONER Approved Copy _._ ,q./& ...... By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In, Prudhoe Bay ,'r. ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 16, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-16 DS 9-20 Permit No. 77-37 Permit No. 77-41 Enclosed are Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. Scheve Regional Engineer DFS/WT/la Enclosures cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany .... STATE OF ALASKA -- ~'~ ALASK,. _;,- AND GAS CONSERVATION L .dlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 77-37 31 Address 8. APl Number P.O. Box 100360, Anchorage; Alaska 99510 50-~9~-_90257 4. Location of well at surface 9. Unit or Lease Name 877' N & 175' E of SW cr, Sec. 1, TiON, R15E, UM (Surface) Prudhm~ Ray At Top Producing Interval 10. Well Number 1414' N & 868' W of SE cr, Sec. 3, T10N, R15E, UM (Top Prod) DS 9-16 (33-3-!0-!5) At Total Depth 1 1. Field and Pool 1561' N & 1&25' W nC SF. ¢_r; ,q~,r,_ ~_ T]0N~ PlSW.~ T_TI~ (TD) Prudhoe Bay Field 5. Elevation in feet {indicate KB, DF, etc.) 13. Lease Designation and Serial No. Prudhoe Bay Oil Pool 54' RKB AEL ?8328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. [ 15. Water Depth, if offshore 16. No. of Completions 9/8/77 9/28/77 10/7/77 (per£ed 11/23/771' -- feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 12589'MD 9195'TVD 12546'MD 9165'TVD YES [] NO [][ 2213 feet MD Approx. 1900' 22. Type Electric or Other Logs Run DIL/SP, BHCS/GR, GR/CNL/FOC/CAL, GR/CNL/CCL, FDL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H40 Surf. 100' 32" 258SX ARCTICSET II 13-3/8" 72~ MN80 Surf. 2727 ' 17½" 3100SX ARCTICSET 9-5/8" 475A S0095 Surf. 11370' ' 12~" iO00SX Class G 7" 29~ L-80 11070' ' 12588 ' -- 520SX 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) *12,375-12,395' MD (20') 9046-9060' TVD 5½" 10,963 10~837 '12,350-12,370' MD (20') 9028-9042' TVD 12,313-12,333' MD (20') 9002-9017' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12,298-12,313' MD (15') 8993-9002' T~CD DEPTH INTERVAL(MD) AMOUNT & KIND OF MATERIAL USED 12,220-12,248' MD (28') 8938-8958' TVD N/A 12,140-12,186' MD (46') 8909-8914' TVD *New Perf Shot 2/20/84 - 4 spf -, 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 2/4 / 78[ F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 2/29/84 6.1 hrs. TEST PERIOD ~ 1,524 4,701 0 24°I 3084 Flow Tubing Casing Pressure CALCULATED.1~ OIL-BBL GAS~MCF WATER-BBL OIL GRAVITY-APl (cor'r'i'" Press. 1905 450 24-HOUR RATE ~ 5,996 18~495 0 29.6° 28. CQR E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED MAR 2 3 984 r.r, : f :" r Alaska 0ii & O~s Cons. 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. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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, §team injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". ARCO Alaska, Inc, Prudhoe Bay IP_,,gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer March 16, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 9-16 Permit No. DS 9-20 Permit No. DS 12-12 Permit No. 77-37 77-41 81-83 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned wells. Very truly yours, D. . Scheve DFS/$gf/la Attachments cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc. is a Subsidiary of AtlanflcRIchfleldCompany ,~_.----- STATE OF ALASKA · ALASK .... AND GAS CONSERVATION C IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:~ 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 77-37 OTHER [] 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 877' N and 175' E of SW cr, Sec. 1, T10N,R15E,UM(Surface) 1414' N and 868' W of SE cr, Sec. 3, T10N,R15E,UM(Top Prod) 1561' N and 1425' W of SE cr, Sec. 3, T10N,R15E,UM(TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 54' RKB ADL 28328 8. APl Number 50- 029-20257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-16 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: 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 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 2/20/84. RU perf unit, pressure tested equipment. RIH with gun #1, flowed well, shot 12375-12395' MD 4 spf (Ref: BHCS 9/28/77), shut in well, POH, all shots fired. RIH with gun #2, flowed well, shot 12350-12370' MD 4 spf, shut in well, POH, all shots fired. RD. Secured well. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. e ,ona .n ,neer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc, Prudhoe Bay' ~-~gineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F, Scheve Regional Operations Engineer March 19, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 9-1 Permit No. 75-76 DS 9-12 DS 9-2 Permit No. 76-16 DS 9-13 DS 9-3 Permit No. 76-35 DS 9-14 DS 9-4 Permit No. 76-40 DS 9-15 DS 9-5 Permit No. 76-47 DS 9-16 DS 9-6 Permit No. 76-48 DS 9-17 DS 9-7 Permit No. 76-58 DS 9-18 DS 9-8 Permit No~ 76-70 DS 9-19 DS 9-11 Permit No. 76-84 DS 9-20 Permit No. 77-7 Permit No. 77-8 Permit No. 77-25 Permit No. 77-36 Permit No. 77-37 Permit No. 77-38 Permit No. 77-39 Permit No. 77-40 Permit No. 77-41 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JCD/lmh Attachments cc: Sohio Petroleum File PI(DS as above)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRtchfletdCompany ..__-.-- STATE OF ALASKA .__ ALASK, . AND GAS CONSERVATION C IISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 877'N & 175'E of SW cr Sec. 1, T10N, R15E, UN 1414'N & 868'W of SE cr Sec. 3, T10N, R15E, UM 7. Permit No. 77-37 8. APl Number 50- 029-20257 9. Unit or Lease Name Prudhoe Bay 10. Well Number 1561'N & 1425'W of SE cr Sec. 3~ T10N~ R15E~ UH 5. Elevationinfeet(indicateKB, DF, etc.) I 6. LeaseDesignationandSerialNo. __ R4' R~R ADL 28328 12. Check Ap0ropriateBoxTolndicate Natureo?Notice, Repo~to~Othe~Da~a NOTICE OF INTENTION TO: (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.) DR 9-16 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 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 add perforations on DS 9-16 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 11810-11860' MD 11880-11910' MD Ref: BHCS 9/28/77 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Date Conditions of Approval, if any: BY Approved by Form 10-403 COMMISSIONER Approved Copy Returned By Order of the Commission Date Submit "Intentions" in Triplicate 7,.. Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, inc. Post Offi¢--?~-'~ 360 Anchora~= ska 99510 Telephone 907 277 5637 March 19, 1984 Reference: ARCO Cased Hole Finals D.S. 4-1 / 12-5-83 D.S. 4-10 ~'~' 12-9-83 D.S. 4-11~ 12-5-83 D.S. 4-13~" 12-9-83 D.S. 5-2'~ 1-13-84 · D.S. 6-8~ 12-9-83 D.S. 6-11'" 12-21-83 D,S. 7-15/z 12-18-83 D. S. 9-7"'~/- 12-4-83 D.S. 9-16j 2-20-84 D.S. 9-17/, 12-4-83 D.S. 14-5~/ 3-4-84 D.S. 16-1j' 3-9 -84 D.S. 16-11~ 3-10-84 D.S. 16-16j'3-10-84 MS/CNL/OR EPL MS/CNL/OR CET Log Collar Log CH CNL CH CNL Perforating Record MS/CNL/OR Collar and Perforating Log MS/CNL/GR Collar & Perforating Log Collar & Perforating Log Collar & Perforating Log Collar & Perforating Log Run 1 5" DA Run 1 5" Sch Run 3 5" DA Run 1 5" Sch Run 1 5" Camco Run 2 5" Sch Run 3 5" Sch Run 1 5" Sch Run 1 5" DA Run l&2 5" GO Run 1 5" DA Run 1 5" GO 5" GO Ru-n 1 5" GO Run 1 5" GO Please sign/ and return the attached copy as receipt of data. HAVE A NICE DAY Kelly McFar land ATO-1429F Trans. # 101 DISTRIBUTION Chevron D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files R&D Carolyn Smith ~,~ Sohio State of ~aska ARCO Alaska, Inc. Prudhoe Bay =ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer December 14, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 9-16 DS 9-20 Permit No. 77-37 Permit No. 77-41 Dear Mr. Chatterton: Attached are Intention Sundry Notices for work to be performed on the above-mentioned drill sites. Sincerely, Donald F. Scheve Regional Engineer DFS: la cc: J. C. Dethlefs J. R. Schuyler D. Smiley Sohio Alaska Petroleum Co. Well File, DS 12-19 & 20 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRtchfleldCompany STATE OF ALASKA ALASK, ..... ~. AND GAS CONSERVATION £ VllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 __54 12. 4. Location of Well 877' N and 175' E of SW cr, Sec. 1, T10N, R15E, UM(Surface) 1414' N and 868' W of SE cr, Sec. 3, T10N, R15E, UM(Top Prod) 1561' N and 1425' W of SE cr, Sec. 3: T10N: R15E: UM(TD) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. AnT, 2RR2R 7. Permit No. 77-37 8. APl Number 5O-029-2025? 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 9-16 11. Field and Pool Prudhoe Bay Field Pru~ho~ Bay Oil Pool Check Appropriate Box To !ndicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate k~ 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.) (Submit in Duplicate) [] Altering Casing ~ [] Abandonment I--~ [] Other E~] 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 add perforations on DS 9-16 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion, of the perforating and clean-up operation. Proposed Perforation Intervals: Zone lB 12350-12370' MD 12375-12395' MD Ref: BHCS/GR 9-28-77 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed The space below for Commission use Regional Engineer Title Date Conditions of Approval, if any: Approved by Form 10-403 COMMISSIONER By Order of the Commission Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Oil and Gas_Company North Alas ~istrict Post Office oox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 10, 1980 Reference: ARCO Magnetic Tapes D.S. 17-5 ~' 10/29/80 D.S. 16-10~10/27/80 Tape #61122 Run 1 Tape #61061 Run 2 Tape #6]120 Run 1 /4~' '/ t'~ ' T 'T~"C'- I. STA'T T'E~ ,~Please sign and return the attached copy as receipt of data. · Mary F,. Kelli~ North Engineering Transmittal #786 . .DISTRIBUTION T' ~::'" NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and Gasf_.Company North Alas', istrict Post Office ,..,)x 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 21, 1980 Reference: ARCO Cased Hole Finals D.S. 1-10 12/9/79 DSTNDT D.S. 4-6 10/1/80 CNL D.S. 4-7 10/1/80 CNL D.S. 6-3 10/5/80 CNL D.S. 9-7 10/2/80 CNL /~D. S. 9-16 ~ 10/3/80 CNL Run 2 ~iign and return the attached copy as receipt of data. Run 3 2" & 5" (same log) Run 5 5" Run 4 5" Run 3 Run 2 5" "~] 2 ENG CONFER: FILF: Mary Kellis North Engineering TRANSMITTAL #737 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AtlantlcR~chfieldComp,~ny ARCO Oil and Gas_C~ompany North Alasl istrict Post Office oox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 15,,1980 Reference: ARCO MAGNETIC TAPES 8/17/80 Tape #60755 Run 3 9/22/80 i. Tape #61024 Run 1 ~~Please sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering TRANSMITTAL #705 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and Ga,_~s Company North A! Disiiict Post Off;.._ Box Anchorage, Alaska 'J:g510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer September 29, 1980 · ~nce AnCO Cased Hole Finals D.S. 2-16 8/5/80 CNL D.S. 11-4 8/4/80 Depth Co.~:troZ p.S. 3-4 8/18/80 DST;;L)C Run 1 9" -' -c*' of . ' lease sign and return the attached cop~ as rece~2~ data Mary F. Ke!!is North Engineering TR~{~M!TTAL #638 DISTRIBUTtOH ,North Geot ogy Exxon IR & D Hob11 · Drilling Getty i!i:~ .. ".: ' ' · ' 1{',, .' Eng Manager Phil 1 ips,...'"' .... . ..',.,,,x.,/>.,. ' , r .. ,'.._} .., ' D & I'I Sohio .,:... Gao I o g.y Ma Fa t h o n State of Alaska Chev:on AP, CO O,I and Oas Comp.iny Feb:uary 1, 19S0 Reference' Fmc!ozed are ~Iagnetic ]'apes for the following Al{CO welis' D.S. 12-2 8/4/79 Tape 11/6/79 Tape ,~60000 ~/P!ea~sign and return the attached copy as rece:i.pt of data. COMM J ..... R:-.S ENO i1 ENG 2,., 4 ENG-~ 1 GEOL J STAT ~[:~ CONFER,:---- K. J. Sahlstrom North Enginee:ing TfbkNSix[I TidAL /J 059 !~cember 27, 1979 Re£erence' Fmclosed are imgnatic Tapes :lot' the £ollowin2~ A!~CO wells' D.S. 1-12 10/27/79 D.S. 2-i 10/27/79 D,S. 4-15 11/5/79 P.S. S-t 2/27/79 D.S. S-S 10/29/79 D.S, 5-7 10/26/79 10/29/79 ~1,/22/79 Tape ~'60006 Tape It60007 Tape f60002 Tape !155475 Tape !t60005 Tape /t 60010 Tape ~',' 57072 Tape #57076 Tape d57034 ,,"';/ t-lease sigm and return the attached copy ~s receipt of' . data. ' K, J Sahlstrom North Engineering TRANS:X!ITFAf, f 533 ])] ~,,, ~.. o I i, l ]~UT i().X ~loh:i 1 Get-f)' Pi~ i ]. 1 i_ps North C, eo] ogy R & ]) ]-h' J_ 11 i n q Eng. ),!:mager State oF Alasl<a November 30, 1979 Reference, Fmclosed are Cased }Io. le Logs for the following AR(iO we].ls' D,S,. 3-4 11/2/79 TDT Run 2 D.S. 4~15 11/5/79 CNL Run 3 P,S. 7-I~ 10/24/79 CN/GR/~L$ Rkm :2 '! 10/23/79 CN/CR/}.IS P, un 2 ~ ~. 11/6/79 ~' Run 2 D.S, 14-8 9/27/79 EPL Rm~ 1 b'GI ~ 4 10/22/79 Acoustic O~L/~,~I IfGI ~ 4 10/27/79 CN/GR Run ]. 2 & 5" (same log) 5" 2 & 5" (same log) 5~ 5" 5:' ~/Please sign and retu]m the attached copy as re.cieJl)t of data. K. J. SM~lstrom North Engineering T}L&NSMITTAL # 503 D~S] I,INU 1 ].ON Not'th Ceo]og)' Dri]_l_ing ling. Hanager Ceol. ogy ~ta~.e of Alaska Exxon ?,lobil Cett:y Sohio Chevron ,.Jtlno Jg, 1!)7!) ] )~ (.'.'[ '0 r'(_;j lC 0 ' z~::(-'~ 'tNe ::ol]_o~,:i_:ng cased Nole 3-6 C/O 2/20/79 3 6 1;1. I)ens.2/19/79 3-s (2/0 3/14/79 ']~.,, -- 6 CNI, 3/25/79 3 7 '.['DT 10 /1.} / / 8 5-2 TDT 11/1L0/78 15-3 CNL 3/17/79 3--6 TDT 10/17/78 ~NI)W il-] Temp. 1/13/79 7--] 1. CNL 3/27/79 ].'1(-'.~ se s]?,n m~d 'returtt the cof)y as recel~. L. of da. ia. V.(;. l/e]~no, rs 'J'I{ANS?,I.I"t'~ 'Al, //i[8 7 North Alaska Distri6t Post O[fice [?"----q$0 ' Anchora~-'a,, ,,. .a 99510 Telephone 907 277 5S37 ~'~rch 16, 1979 Reference' , Enclosed are the following cased hole logs'. DS 4-2~i Diff. Temp. 9/25/78 DS 4-12v/× CCL 12/01/78 DS 9-20 - Spinner 12/ 3/78 DS 9~13-- Cont. Flow - 6/ 3/78 DS 14-5''-'-'~ CNL 11/28/78 DS 7-6 ""~ CBL/VDL 11/20/78 .~p~.. Diff. Temp. 9/18/78 .~~-j~ Cont. Flow 6/ 2/78 DS 9-19~' Cont. Flow 10/24/78 DS 3-7~~' Cont. Flow 8/29/78 Please sign and return the copy as receipt of data. ~- Sincerely, V.G. Reimers North Engineering TRZ~SMITTAL #99 DISTRIBUTION North Geology Drilling.~ F~g. Manager .. Geology State, o£~!i'Alaskai ~CD'['M ..... '~" ~ """, Sohio Mobil }.'Iarathon Phillips Chevron Getty Alaska Oil & Gas Conservation Commission Hoyle H. Hamilton Commissioner Chairman/v'~'' Lonnie C Smith Commissioner Bobby Foster~?'' 'Petroleum Inspector February 1, 1979 Retest SSSV on ARCO's Drill Site 9-16 _J~a~apry 26, .19.~79 -After completing BOPE test on Sohio's West Sak #4, I was picked up at Sohio's BOC and driven to ARCO's DS 9-16 by Gary McGuire, production foreman for ARCO. The results of the retest are attached. I was then driven to the Deadhorse Airport where I boarded Sohio flt #4 departing at 6:00 PM and arriving at Anchorage at 7:30 PM. I arrived at my home at 8:45 PM. In summary I witnessed the satisfactory retest of ARCO's DS 9-16. BF/LCS:emi ALASKA OIL & GAS CONSERVATION OOM~tISSION Field Test RelxDrt Surface (SSV) and Downhole (SSSV) Safeb: ~!a!~'~-~ DATE Operator ; Veil Pilot P1 t/Loc No. High Lew TBG, TSC, CSG i P- F~) Te st I P FP Te st ~ .... , .......... .... - '"' ' ' ~ .................... .... ~ ....... '", ,, .. ... ,- ............... ] ................. ..... ........ .... 1 ............. . .... .... [ ......... , .................. .... i ....... ,,. . ............... ............................... ....................... I ..... i - ~ ~ , , , ................ , , [ ............ I ~/.. AtianticRichfieidCompany t, North American Producing Division North Alaska:~'"'rict Post Office .50 Anchorage, Alaska 99510 Telephone 907 277 5637 August 14, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 9-13 Permit No. 77-8 DS 9-14 Permit No. 77-25 DS 9-15 Permit No. 77-36 Permit No. 77-37 - Permit No 77-38 DS 9-18 Permit No. 77-39 DS 9-19 Permit No. 77-40 DS 9-20 Permit No. 77-41 -Dear Sir: Enclosed please find a Completion Report for the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer FMB: lr Attachments SUBMIT IN L STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE ii ii i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: Oll,w~Lnt,.~m~V~ UASw~LL ~ Dn¥ [] Other __ b. TYPE OF COMPLETION: W~:Lr. OVF, R L__2 mx m~cx R~.SVg. Other ,, Perforated ..... 2. NAME OF OPERATOR Atlantic Richfield Company 3, ADDRESS OF OPERATOR P.O. Box 360 Anchorage, Ala..ska 99510 4. LOCATION OF wELL ~(Report location clearly and in accordance with any State requirements)* At surface 877N' & 175'E of SW cr Sec. 1, T10N, R15E, UM At top prod. interval reported below At total d&gl4'N &868'W of SE cr Sec.3, T1ON, R15E, [TM 5. API NUM. E1LICAL CODE 50-029-20257 6. LEASE DESIGNATION A~ND SEi%L~L 1NO. ADL 28328 7, IF 1NDIA2N, ALLOTTEE O11{ TRIBE NA_N~E 8. UNIT,F~I OH, LEASE NAME Prudhoe Bay Unit 9. W~:I,L NO. DS 9-16 (33-3-10-15) 10. FIELD A2qD POOL, ()It W~LDpqqldhoe Prudhoe Bay. Fi eld-0il Pool 11. SEC., T., R., M., (BOTTOM tIOLE O1MECTIVE) Sec.3, T10N, R15E, UN 12. PEP,~IIT NO. 1561'N &1425'W of SE cr Sec,3, T1ON, R15E, UM 77-37 13. D.~WE SPUDDED 14. DATE T.D. RE/kCH~,D 15. DATE COW~~ {)~ ABAN-D. 16.' 9-8-77 9-28-77 [ 10-7-77 11-23-77) 54' RKB l'IOW lVlA-NY* ROTARY TO01,8 CABI,E T(JO! N 12,589'MD. 9195'TVD ]12~546'MD, 9165'TV~ Single All 22. PRODUCING INTERVAL(S), OF THIS CO.IVIPLETIO~TOP, BOTTOM, NAME (MD AND TVI>)* ,23. %VAS DIRECTIONAL ? SUHVEY MADE Top Sadlerochit 11,781'MD 8629' TVD I Base Sadlerochit 12~ 480'MD~ 9119'TVD I Yes 24. TYPE ELECTRIC AND OTHIffi:t LOGS RUN ... DIL,ISP~BHCS/GR~ ...OR/_CNL/FDC/CAL, GR/CNL/CCL, FDL ~5. CASING RECORD (Report all strings set i:x well) ?0" .. I 94# 1I-I-40 [ 100' :..~.'"_J: 3'~" [ 13,3/8"[ 72#-Butt I~m-8°!2727' ~ I 17-1/2[' q-5/8"{ 47#-B~tt / U-S0al :~,370~ , , , ~oo-9s I ' [ 26. LINE~ ~CO~ 7" [ 11,070',,, (2,,sas' [ s20~, 28. PERFORATIONS' OP~ TO PRODUC~O~ (interval, size and number) / (12,313'-12,333' / ~' 12,298'-12,313' ,' 12,220'-12,248' 12,140'-12,186' w/4 shots per ft. I I I [ II 30, Pr~ODUCTION DAT'E FIRST PfiODUCTION ~--4.78 ', BATE Or T~ST, [HOURS TESTE, D 'ICIiOXE SiZE IPROD'N POl~, 2rB-J8 . ~ .... 6 ~ 1..74/64 ~ ~' FLO;V, TU PING- [CASUqG PRESSURE [CXLC~T~ OILBBL. : ~:? I -- I ; [ 10407 21. DISPOSITION OF GAS (80l'~', used ]~r ]uel, vented, etc.) Roiniacte~ . 82. LIST ~ ATTACHMENTS CISMLNTING REC:OILD ] AMOUNT PULLED 258 sx Arcticse_t I I ~mt.:__ 3100 sx Arcticset Cmt 1000 sx Class G ii i ! ii ...... 5-f/2" '10,963" 10 ,--g~'-- , 29. ACID, Si:OT, I;;17kC:'l GfiE, ~Vi~N? sQU~I!:~, ETC. D~-~IXi INTEAIVAL (MD) AM .~ U N 'F )kND Iii N I) (9 F: :,M/Ut E;q.{AL USED V,,1.iLL iJ'I'A'IUS Producing or Producing N/A PP~ODUCTION MEIfiOD (Flowii~g, ~j:as life. pumping--size and type of pump* Flowing oIL---BBL. GAS--RiCF. V~'//I'EII--Bt;L. I GAS-OIL II.k·TIO [ 2601 [ 1755.5 I 0 ] 675 GAS--R%CF. WATEIZ--BBL. I OIL GRAViTY-A.PI (COi:~R. [ 7022 .. I 0 J 27.0 ITEST \VITN'ESSI"D BY Production Operations hereby certify that the foregoing Bnd attached information is complete and correct as determined fr(,m all-available rt~c(ird.q /" *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well comPletion report end log on ~11 types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments given in cther spaces on this form and in any attachments. Items :20, and :22:: If this well is completed for separatc, production from more than one interval zone ~ . (multiple completion), so state in item 20, and in item 22 show the prcJucir~g interval, or intervals, top(s), bottom(s) and name (s) (if any) for only the interv~l reported in item 30. Submit a separate report (page) on this form, adequately identified, for each additior~l interval to be seperately produce.J, show- ing the additional data pertinent to such interval. It~m:2~: "S~cks Cement": Attached supplemental records for this well should show the details of any mul- .tiple stage cementing anti the location of the cementing tool. Item :28: Submit ~ separate completion report on this form for e~ch interval to be separately produced. (See instruction for items 20 ~nd 22 above). 34. SUMMAI[Y Of' PORNIATION T,~S'~"S INCLUI)IN(; INTEf[VAL TE. STED. PHE~URE DATA ~ '~COVERI~ OF OIL. GAS. 35. G~GIC MARK~ WAT~ AND MUD NAM~ I. C~~ B~.~. ~a~c~t ~i--~ ..... "'~' D~~NS O~ L{T[[OLOGY, PORO~. AN-D DE[~'EI) SIIOWS OP OIL., G~' OR _ ... Drl g. ~Permi Opera{or A~-'". il and Gas Conservatioi~ Corem ~.':::. } Field Inspection Report Wel 1/Platfm Sec T R , Represented by/~-~ 1~(2_~ Name & Number'~g~/ Satisfactory Yes No Item () () () () () () () () () () (~]. () () () (.) () ().'() () () () () Ty. pe Inspection ( ) Location,General 1. Well Sign 2. General Housekeeping 3. Reserve Pit-( )open( )filled 4. Rig (~)-"Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells / ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls.. , , , ( ) Final Abandonment llo P&A Marker SatisFactory Type Inspection Yes No Item ( ) BOPE Tests . ( ) ( ) 15. "Casing set Ia ( ) ( ) 16. Test fluid-( )wtr.-~ )mud ()oil ( ) ( ) 17. Master Hyd. Control Sys.- psi.Q. ( ) ( ) 18. N? btls. , , , psig ( ) ( ) 19. R~mote Controls ( ) ( ) 20. Drilling spool- "outlets ( ) ( ) 21. Kill Line-( ) Check valve ( ) ( ) 22. Choke Flowline ( )HCR valve ( ) ( ) 23. Choke Manifold~No. valvs fles__ ( ) ( ) 24. Chokes-( )Remote( )Pos.(-)-A-dj. ( ) ( )~!~' 25. Test Plug-( )Wellhd(')cs.o( )none ( ) ( ) 26. Annular Preventer,___ psig ( ) ( ) 27. Blind Rams, psi.Q -- ( ) ( ) 28. Pipe Rams psig ( ) ( ) 12. Water well-( )capped( )plugged ( ) ( ) 29. Kelly & Kelly-cock psig ( ) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve psig ( ) ( ) 14. Pad' leveled ( ) ( ) 31. Safety Floor valves-~-~-BV ( )Dart Total inspection observat~ior~ time.~~hrs/days ':Fota]. number, leaks, and/or equip, failures cc- Notify in days or when ready Inspected by' Date /-~.~f Receipt Acknowledged For- Please return receipt to- R. A. Logue Atlantic Richfield Co. North Engineering P.O. Box 360 Anchorage, Alaska 99510 MILE 4, NORTH RD. BOX 3453 KENAI. ALASKA 99611 PH. 1907) 283'4403 ComPany Well LocatiOn, ATLANTIC ,R__ICHFIEI,D COMPANY #16 NORTH SLOPE 1000 200~ress'ure ,, ·Field' Location P RUDHOE BAY Formation 3000 SADLEROCHIT 4000 DRILL SITE #9 State, ALAS K~_._ Date_. 21 NOVEMBER. 1977 _J~D_. S.S. _.PRESS. GRADIENT -0- -54 1223 100 -100 1284 .396 2054 -2000 1824 .283 4102 -4000 2442 .309 7286 -6000 3139 .348 10919 -8000 3830 .344 12101 -8800 4098 .335 -0- -54 1240 Dev. -54 Well Information Datum -8800 .Zero Pt K. B. Csg. ~ to .... to Tbg.~ to ........ to Perfs, Pkr. I ~ PBTD __~ Csg Press 0il Level H20 Level Well status Prod rate Date last test Status of well last test Prod. rate, last test Press. last test Press. this test Press. change Element Nos. 40585 Calib. No. Remarks BI~'£ = 192° A,,~ a nti,CF~ich fi eld Corn pany North American Producing Division Alaska Reg; Post Office ~ .... 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13,1978 Reference: Dear Gentleman: The ~llowing material is being submitted he~wit]l. Please acknowledge receipt by signing a copy of this letter and returning it to this office. D.S. 9-1 D.S. 9-2 D.S. 9-3 D.S. 9 5 D.S. 9-6 D.S. 9-7 D.S. 9-8 D.S. 9-9 D.S. 9-11 D.S. 9-12 Initial Transient Pressure Survey Nov.14/77 Nov.27/77 Nov. 24/77 Nov. Z1/77 Nov.18/77 Dec.18/77 Dec.6/77 Dsc. 10/77 Dec.17/77 Dec.21/77 Initial Static Gradient Pressure Survey D.S. 9-13 Nov.20/77 D.S. 9-14 Nov.18/77 D.S. 9-16 J Nov 21/77 ~lTruly y°ur~ ~ ~ Donovan Jackson...~./ .'~ ' North Alaska Dist~'~ Engineering To' North Alaska District Engineering TRANSMITTAL .. Front' J. A. Roch°n/ R. A. I,gav_e_ Date. _ FI~-~ Well Name' Transmitted herewith are the following for the subject well' Run No.. Scale BHC Sonic/Caliper Log . BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL' Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core' No. COre Description (SWC) - Interval Core Description (Cony.) - COre No. Directional Survey - Gyro Single Shot' ~ltishot Drill Stem Test - Test No. Ik~al Induction Laterolog Formati6n Density Log Formation Density Log/Gam~a Ray Gama Ray/CCL Laterolog ' Location Plat Microlaterolog. Microlog ~dlog- Interval Sample Log (A.R. c0.) - Interval Synergetic Log TVD-DIL ' .' TVD-Porosity Log.' Xerox Sepia BL Line Receipt Ackno~31edged For: Date: Please retm~ receipt to' . /-/4, 7~ Attn: Mr. Donovan Jackson Atlantic Richfield Company North Alaska Engineering P. O. Box 360 Anchorage, Alaska 99510 AtlanticRichfieldCompany North Ame~'~n Producing Division North Ala; istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 28, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK' 99501 SUBJECT: DS 5-8 (22-6-10-15) Permit No. 77-24 DS 5-11 (12-31-11-15)Permit No. 77-30 DS 5-16 (31-30-11-15)Permit No. 77-43 DS 9-14 (11-2-10-15) Permit No. 77-25 ~ DS 9r1~11-1-10-15) Permit No. 77-36 -3-10-15) Permit No. 77-37 Dear Sir: Enclosed please find a Sundry Notice outlining our changes for the above-mentioned wells. Very truly yours, Frank M. Brown D%strict Drilling Engineer FMB/mln Enclosures RECEIV!'!!D Subml t 'il ntentions" in Triplicate & "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~/~LLL[~WELLGAS D OTHER 2. NAME OF OPERATOR ATLANTIC RICHFIELD COMPANY 3. ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 877' N & 175' E of SW cr Sec 1, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20257 6. LEASE DESIGNATION AND SERIAL NO. ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 9-16 (33-3-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 3, T10N, R15E, UM 12. PERMIT NO. 77-37 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF L----J PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Correct Perforated Intervals SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertinent ~letalls, and give pertinent dates, including estimated date of starting any proposed work. Began perf operations 11/19/77. Tstd tree, csg & wireline BOP's. Pulled dummy valve. Perf'd intervals 12,313' - 12,333', 12,298' - 12,313', 12,228' - 12,248', 12,220' - 12,228', 12,180' - 12,186', 12,160' - 12,180', 12,140' - 12,160' w/4 shots per ft. All perf'd depths references to BHCS/GR open hole log of 9/28/77. Ran Amerada press bombs & FDL. Flowed well. Ran & set ball valve. Tstd balance & control lines to 5000 psi, ok. Bled press above ball valve to 0 psi, held ok. Installed & tstd tree cap to 5000 psi, ok. Released well to Production Dept. 11/23/77. This report replaces the one previously sent on 12/13/77. 16. I hereby certify that the foregoing is true and correct TITLE District Drillin$ En$ineer DATE-/~/~/~ ~ (This space for State office use) APPROVED BM CONDITIONS OF APPROVAL, IF ANY: T IT LE DATE See Instructions On Reverse Side To' North Alaska District Engineering TRANSMITTAL From' J. A. Rochon/D. R. Jackson. Date' December 19 ,,!.97[ Well Name' D.S. 9-16 Transmitted herewith are the following, fOr the subject well' Run No. Scale BHC Sonic/Caliper Log . I BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL 1 Compensated Formation Density Log 5" 1 .... Compensated Neutron-Formation Density 5" .... 1 .. Compensated Neutron Log 9-'28-77 5" Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro - Single Shot b~ltishot Drill Stem Test - Test No. . 1 Dual Induction Laterolog 5" Formation Density Log Formation Density Log/GammaRay Gamma Ray/CCL Laterolog Location Plat , . Microlaterolog Microlog · Mudlog - Interval ..... Sample Log (A.R. Co.) ' Interval Synergetic Log TVD-DIL TVD-Porosity Log 1 Compensated Neutron Log 511 casing Collar Log Receipt Acknowledged For: Attn: ~,~. DOnovan Jac!~on Please.return receipt to: Atlantic Richfield Company North Alaska Engineering P. O. Box 360 Anchorage, Alaska 99510 Xerox Sepia BL Line I. ea. ~ ea~ .... I ea. 1. ~.a lea. I ea. -I ea] I ea. I ea. ! ea. AtlanticRichfieldCompany North Amr"-~-q Producing Division North Alas: ,istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 13, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS' 9-13 (13-7-10-16) Permit No. 77-8 DS 9-14 (11-2-10-15) Permit No. 77-25 DS 9'15 (11-1-10-15) Permit No. 77-36 .: ~ DS 9-16i(33-3-10-15) · "-'~'e'r~i~"'x0. 77-37 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned wells. Very truly yours, ~ ; . ... ~. ., ..'" · .-,,./,;/:I ,':.-:," i c~ ' ( ~" , ~'. Frank M. Brown District Drilling Engineer /am Enclosures Forn~ 1,,3-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELL i i OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 877'N & 175'E of SW er Sec. 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB 1, T10N, R15E, UM 14. Check Appropriate Box To Indicate Nature of Notice, Re: 5. APl NUMERICAL CODE 50-029-20257 6. LEASE DESIGNATION AND SERIAL NO. ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 9-16 (33-3-10-15) 10. FIELD ANDPOOL. OR WILDCAT Prudhoe Bay Field-Prudhoe Oil Pool 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T10N, R15E, UM 12. PERMIT NO. 77-37 3ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASING MULTIPLE COMPLETE ABANDON* CHANGE PLANS SUBSEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) Perforate (NOTE= Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all 13ertlnent {:letall$, and give pertinent dates, including estimated date of starting any proposed work. Began perf operations-11/19/77. Tstd tree, csg and wireline BOP's. Pulled dummy valve. Perf'd intervals 12,313'-12,333' 12 298'-12 313' 12 230'-12 250' 12 220'-12 228' 12,180'-12,186', 12,160'-12,180', 12,140'-12,160' w/4 shots per ft. Ran Amerada press bombs and FDL. Flowed well. Ran and set ball valve. Tstd balance and control lines to 5000 psi OK. Bled press above ball valve to 0 psi, held OK. Installed and tested. tree cap to 5000 psi OK. Released well to ProdUction Dept 11/23/77. 16. I hereby certify that the foregoing is true and correct SIGNED TITLE Dist. Drlg. Engineer · DATE 12/13/77 (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE See Instructions On Reverse Side DEPARD~T CF NAq~IRAL R~3~~ Division of Oil ar~t Cas Conservation O. K. Gilbreth, Jr.~~0~ ~ ~. I,~ ~, Hoyle H. Hamilton /~ Chief Petroleum Engineer/~ '- . Petroleum Inspector Dec~uber 6, 1977 Surface Safety Valve (SSV) and Subsurface Safety Valve (SSSV) . Tests on Arco' s DS 9-13, 9-14, 9-15, 9-16 '- Well __ 9-13 9-14 9-15. 9L16 ~ ~lay, }k~b~r 21, 1977 - I departed my h~Te at 7:30 ~4 for an 8:00 AM shcwup and 9:00 am departure via BP charter for Deadhorse. Ileavy fog at Anchorage International delayed our departure until 9: 45 AR and we arrived in Deadhorse at 11:15 .AM. I checked into BP operatic~s and initiated testing of BP SSSV's in early aftemnocn. Kirk White, Arco drilling f~, called that night and advised SSV's and SSSV's in four %~lls would be ready for test/ng t/~ following evening. ~ts w~re made for me to witness those tests. ~__sday, ~ 22, 1977 - During the day SSSV's in seven BP wells w~re successfully tested, the subject of a separate report. At 7:00 PM I was pi~ up at BP operations by Ben Davis, Arco drilling for~nn, and we proceeded to drill site #9 wPm~e testing began at 8:00 PM and was ocmpleted at 12:15 AM the following momn/ng. Results are indicated belch;: Test Test Test 9 5/8" Tubing SSV SSSV Tim~ Annulas @ @ ?su ts (ar.D 1375 0 OK 800 f~{ 1/2 0 11-22-77 1500 0 ', C~ 1000 OK 1 0 11-22-77 1350 0 OK 825 (X~ 1/2 0 11-22-77 1350 0 ' OK 800 OK 1/2 0 11-22-77 ~e. sday,.l~°ve~ber 23, 1977 - I retumned to BP. operations at 1:00 ~{ and ~g on "F" pad resumed at '8:00 AM, the sub3ect of a separate report. I departed Deadhorse at 6:25 l~.t via BP charter, arriv/ng in And~rage at 7:45 ~.4 and at ray hc~e at 8:15 PM. In ~: I witnessed successful SSV and SSSV tests c~ Arco's DS 9-13, 9-14, 9-15, and 9-16. Drlg. ,Permit No,~_ Operator ,,,,.,, .':, Satisfactory Type Inspection Yes No Item ( ) Location,General () () () () () () () () (,,,) .... ( ) (,,,,) () 1. Well Sign 2. General Housekeeping t, Reserve Pit-( )open( )filled 4. Rig ( ~.).'~Safety Valve Tests 5. ~Fy~'ce:~~ 6. Subsurface-No. Wells~,~_ ( ) Well Test Data ( ) ( ) 7, Well ( ) ( ) 8, Hrs. obser ,__,__,__ () () 9. BS~W ( ) ( ) 10. Gr. Bbls. ( ) F i na~-T,6-a~donment Alas~' 'l and Gas Conservation Committ~ Field Inspection Report ~,,~ .:.,.,: ,,,,,, Wel 1 / P,,1 a'.tfm Sec T . R , M , ., - ~ ~,,~ ~'.:'-, ,.'~ Represented by '["~,,~.,..; ~.x ,,< Name & mumD~r., ~ .... ;' ~': ';?, ~';;",,~, ',,~i~:.~ x,.', ~,,::~ Satisfactory Type Inspection Yes No. Item ( ) BOPE Tests ( ) . ( ) 15. "Casing set ~ ( ) ( ) 16. %e~"L fluid-( )wt~ )mud ( ) oil ( ) ( ) "17. Master Hyd. Control Sys.- ..... psig · ( ) ( ) 18. N2 btls. ' __,~, _psig () () () () () () () () () () () () () () () () () 19. Remote Controls 20. DrillinQ spool- "outlets 21, Kill L~ne-( ) Che--e-~-~-valve 22. Choke Flowline ( ) HCR valve 23, Choke Manifold No. valvs flgs~ 24. Chokes-( )Remote( )Pos.(-~A-dj. 25. Test Plug-( )Wellhd( )cs.q( )none 26. Annular Preventer,~gsi.~ 27. Blind Rams, psi~ ( ) (), 11. P&A Marker ( ) (.) 28. Pipe Rams ~psiq ( ) ( ) lZ. Water well-( )cappe(~( )plugged ( ) ( ) 29. Kelly & Kelly-cock ~psig (.) ( ) 13. Clean-up ( ) ( ) 30. Lower Kelly valve _~Bsi? (.) ( ) 14. Pad leveled ( ) ( ) 31 Safety Floor valves-~- V / )Dart Total inspection observation time~,~hrs/daYs~ ,,~, Total number leaks and/or ~ouip. failures~<,;~ ' ~ ~ L~,,. '~ ' Rema r k S_~ ~"' ' ,' ~.: ' '~ ~?'~ -%::'.'~' '."~"/:" ~ ~'~ - ~ ..... · . ;~?,.~ ,. ,., /. ~-. Notify ]n days or when ready Inspected C c ~ ~;~ .:~L., t;,~~ ,~_-:, -~_- -. ':*- w '? SUBMIT IN DUi~.~., ;.:~ ~,~ STATE OF ALASKA Sl ructions on 5. API N~CAL CODE reverse side o~t ~ o~s co~s~var~o~ co~m[~ 50-029-20257 WELL cOMPLEIION OR RE~OMPLEIION REPORI AND LOG* la. TYP~ OF WELL: 'OII.,vELi. ~GAS,,.ELL ~ DRY ~ Other b. TYPE OF COMPLE~ON: NEW ~ WORK ~ DEEP- ~ PLUG ~ DIFF. ~ 8. UNIT ~ O, L~.K~E NA~iE w EI.I. OVER ~ EN ~ BACK gESVR. Other , 2. ~,~ o~ o~o~ Prudhoe Bay Unit Atlantic Richfield Company ~. ~ o~ o~o, ~S 9-1~ (33-3-10-15) P.0. Box 360; Anchorage, Alaska 99510 vruonoe ~a.Y hle/d Pool ~t ~u~ce C~[-~ H. S~C., ~., R., ~., (~o~ro~ HO~ O~ ~C-I'IV~) 8~1~ ~nt~r~lr~po~~C~ S~C. 1 ml0~ R15E At top prod. ~ ~ : 1414' ' ~tto~,~p& 868 ~ of SE cr Sec. 3, T10~, R15E, U~ 1561'N & 1425'~ of SE cr Sec. 3, T10~, R15E, UN =,~,~o. 77-37 12,589'ND 9195'WB [12,S46'a0 a°w ~n~l e 22,PRODUCING L~rTERVAL(S.~,OF THIS COMPLETION--TC~P, BOTTOM, NAME (MD AND TX, rD)- TOpSadlerochit ll,781'MD, 8629'IUD Base Sad]erochit 12,480'MD, 9119'TVD 6. LE. ASE DESIGNATION AND SERLKL NO. ADL 28328 7. IF INDIA-N, A-L, LOTTEE O1t THIBE NA_I~L~ Sec. 3, ~ION, R15E, UM ¢,.~' r:A I~I.E TOOl 2:1. XVAS D!I~ECTIONAL SUilVEY MADE Yes 241 TYPE ELECTRIC AND OTHE~ LOGS RUN DIL/SP/BHCS/GR, GR/CNL/FDC/C^L, 6R/CNL/CCL C~.SI~4 C~ SIZE 20" 13:3/8" 26. SIZE 7" [ 28.'"PE~tFORAT[ONS OPF--LN TO PRODUCTION N/A CASING RECORD (Repor~t all,strings set i,n well) 94# ! H-40 ] 100' (Approlx) 32" Circ to _q~rf anpwnv gna 72# Butt lMM-80 12727' ~-- |17-1/2" [3100 sx grcti~e{-~m~-- '4/~BUtt IN-e0&l z,ST0' ooo ii ii ii i il 30. P R.OD UCT! ON DA'I'I/; FIRST PI:LtDDUCTION [ PP~ODUCT1ON hlEI[4OD !Flo\vii~g. ~.'~,~ !?ft. pumping--size and type of pump, N/A ,1 . D~T~ OF TgST. ACURS _EST~ lcI-!OXE SiZE [PROD'N FOR Oi~BDL. ~61V] TUBING ,CA~.iNG pRESSURE ICAi,CL~ OI~BBL. GAS--r,ICF. z,r~ss. [~4-HOU~ ~1 31. ~sPOS~X'mx oF °,s ~Sold, u,ed Jor Juel, vented, etc.) LINE,X REC O I-LD TOP (},'ID) EOTTO!VI (.MD) SACKS CEMENT* SCi~EEN (B'ID~ SIZE i)EPTIt S~71' (MID* PACI[EI{ SET .11,070' 12.588'_ 520 ~×_ 5-1/2" 10.963' . 10,837' , 1 _ (interval, size and p_urnber) 2.3 ACID. Si:CT, FilA27'i GEE. C~". ,IKNT SQULi2'Z'.:. ETC DEPI~Ii I;42iffRV.~L (.MD~ / :'C.I.DUNi' AND 1.~!Ni) (.)!.' %!A'IE/IiAL USED N/A lAST OF ATTACHMENTS ~rill~n§ History, Multishot Directional Survey I hereby certify that the foregoing and attached information is comple{e and correct as determined frum (all-available r~,c.rds SIGNED ,~,~ District Drilling_ En.g_ineer ,,~.r~.: ........... *(See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well compJetion report end log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used es reference (where not otherwise showr~) for depth measure- ments given in ether spaces on this form end in any attachments. Items 20, and 22:: If this well is completed for separate, prcctuction from more th~n one ~nterval zone (multiple completion), so state in item 20, end in item 22 show the p~cJuci~,g interval, or intervals, top(s), bottom(s) end name (s) (if any) for only the interv,~l reported in item 30. Submit a separate report (page) on this form, ~dequately identified, for each addit'ionel interval to be separately produce, J, show- ing the additional date pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records 'for this well shoulJ show the details of any mul- tiple stage cementing anti the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). WATER AND MUD II I1 I I Illll II ....... I Ill NAME · ,,, ,, , ,, 26. COHE DATA. Aq'rAcI[ BRIEF '~O~tPI~ONS OF 'LITI[0LOGY. POROSITY. ...................... Drilling Hi story DS 9-16 (33-3-10-15) API 50-029-20257, ADL 28328, Permit No. 77-37 Spudded well @ 1300 hrs 9/8/77. drld 17½" hole to 2750'. RU & ran 13-3/8" csg w/shoe @ 2727'. Cmtd w/3100 sx Arctic Set cmt. Slurry wt 15.0 ppg when lost returns, max press 1000 psi. Pumped additional 1700 sx w/no returns. Down squeezed w/250 sx Arctic Set cmt. Top of cmt @ 2610'. Drld to top of FC. Drld cmt in 13-3/8" csg. Drld 10' new hole. Tstd form. Drld 12¼ hole to 11,400'. RU & ran 9-5/8" csg w/shoe @ 11,370', FC @ 11,291' lower FO @ 2528', upper FO @ 2412'. Cmtd w/lO00 sx Class G cmt, 0.75% D-65, slurry wt 15.8 ppg. Opened lower FO. Cmtd w/300 sx, 15.1 ppg Arctic Set cmt w/0.2% D13R & 0.2% D59. Closed lower FO. Opened upper FO. Arctic Packed 9-5/8" x 13-3/8" annul w/260 bbls Arctic Pack. Tstd 9-5/8" csg w/3000 psi OK. Drld cmt, float collar, float-shoe & 10' new form. Tstd form to 11.3 ppg equiv. Drld 8½" hole to 12,589'. Ran DIL/SP/BHCS/GR, GR/CNL/FDC/CAL. RU & ran 7" lnr w/shoe @ 12,588', top @ 11,070'. Cmtd w/520 sx Class G cmt w/0.75% D65, 0.2% D46, 18% D44. Drld cmt to 12,546'. Ran WSO tst on lnr lap, OK. Circ mud out w/wtr, displ wtr w/10.7 CaCl2. Ran GR/CNL/CCL. Ran junk bskt gauge ring to 11,070'.,, RU & ran 5½" tbg compl asbly w/shear sub @ 10,963', SAB pkr @ 10,837', 4½ XN nipple @ 10,904', 5½" XN Nipple @ 10,789', XA sliding sleeve @ 10,721', RQY nipple @ 2213'. Displ CaC1 w/diesel. Dropped ball, set pkr. Ran CCL/dummy gun. NU & tstd tree to 5000 ~si OK. Ran & set dummy valve. RU for long term tbg tst. Released rig @ 1800 hrs 10/7/77. Eastman ~ ',i Whipstock l)~ A PETROLANE COMPANY REPORT of SUB-SURFACE D IREC TI ONA L SURVEY ATLANTIC RIC~IFIELD COMPANY COMPANY WELL NAME PRUDHOE BAY LOCATION JOB NUMBER A977 S0112 TYPE OF SURVEY MULTI-SHOT DATE 10-10-77 SURVEY BY KEVIN DURLING OFFICE ALASKA COMPLETION REPORT OCTOBER 07,1977 ATLANTIC RICHFIELD COMPANY DRILL SITE 9-16 _~_A.G~4..E_T._I_C _ 1~ U.L_T._I_$~O T SUR VE Y __ D E ~_L. I.~i~l.[ .0~_i_QEG_,_E ASA __q. AD.I.U S_.. O.F. ~U_B_V~LU_B~ M E T ~Q.P__.O_E_~.OM.B U_T_A T..I .O~L5 .......... ~._ B_ EL.Er_, .... RECORD OF sUi~'VI~Y ...... ALL CALCULATIONS PERFORMED BY I B ~ ELECTRONIC COMPUTER TRUE A_s_.._ _iC7' i. 77_ic ......... _ .ifFT- ............. :c T s _DEPTH ..ANGLE DEPTH__SEA D.IREC D M DEG. ................................................... DOG_. LEG ........................... C .... L..O._S_U_.R ...... E .... $ ........SEM. ERI..T.Y_ .............. SL;.CT !ON D._LS T ~J.C.E__ A!~_6_L.E.. iD-E.GY_i_0..0JE_T_ .... __~.I_S_TA~C t D M S o 0 o _o_:_q0. -54.oo__s25_,_O.'_Q3,, ......... .0._.._~.O $ o.oo w 5 so 0 !5___5_2_?._,_?.% .... ~2._5__._93)..s_2..6_,.9.9La_ ............. !.,_03 s __0. ~0 w ~055 0 L.5. ........ 1_0_%~_,?~__~_0_.0_0_,..~_ ..... _S.~:~_..,._O_O_E ............. 2._,_98 S 0,16 g o_..Q.O .... $ ..... c___O__. O_jo' ..... Q,.O__O_O.. .0.,.0.o. 1.,!.5 ...... 5__....25 0 0 W 0_.,_Q~&7 _0.....~..0 2.99 5 ......3 ........ 8__~ 7 E 0.08.! ................. r_O .~ ,5 PRECEEDING SURVEYS ARE FROM DON BAKER ........................ , a6 2812 'I 0 2811,86 2757,86 539,00E 6,54 5 19,69 E 2905 I 15 2906.8~ 2850,8~ S 7.OOE 8.20 S 20.39 E 2998 4 , 0 2997.73 2943.73 $81.00W il.2St S 18.07 3092 B 0 '. 3091,20 3037,20 573,00W 13,48 5 8,51 E 3185 11 45 3182,80 3128,80 S69.00W'' 18,68 S 6.56 W 3278 15 0 3273,27 32i9~27 5~7_!..:0__0)',' , 26.03 S 26,77 W 3371 15__0 3363,10 3309, !_Q___S.~._8., 00 W 30,4.0 33 9 &,~3___$.SA, 0 ow J_k,._0_3 $ 7 a. ,AI_3Y ._ 3488,32 S 8_9_,_0_Q w 3 1 · 48 5 1.0D_,_0~_2',:~' 3578,2_2.__.~.(9..01_00w__ 31,7.2. S 3666,91 N89,00W 31,48 S 155,49 17 ,Sj~ ...... S__.Tj!_~ 2._:LS_E _0..,_0/~2 -.1Z,..~2. 2 0 ....7_~__5 71 36 39 g ' ' .0_,_57...1 .... _~.2.0..,_2q 2 1.._9.8__..~_~_8__.k__~_E__: _0_.Z69. ._r.2..l..10 2 1 · 30 S .5.8 1 50 g ?._.j_93 ...... -1_.}.-- 1 O_ __1_~_-9.._L$ !i_I_5 4 [ .A,_2~.5_9.. 'fk... 1_~..,...7.9__S_1_9__2_!_2_9_!g _4_tO..3_&__. 4 ,.68 3557 17 .Q 3542 3651 17 0 3632,22 370~ 18 0 3720.911 3837 2,0 0 ~808.84' 3754.84 N~~,W_ 3930 21 .0 3895.95 3841.95 N8R.OOW 402~ 23 30 4116 2'7 0 __ ._~_LO__Z.&,3_O .. 4303 3:_0_ o 439 6 32 0 3_0_,_3_._ .~ .23.&_,_3_2 W 2 k,..14.: $_ .... 43_0_,_05 W 4 :~.)_, 57 'S ' S 7 11 7 W P=, 17 ~ ~2..5.,.85. RECORD OF $tJRVEY ALL CALCULATIONS PERFORMED BY I B t_~LLQT_iOJ~C C_OFLPU_IEB TRUE MEA.S_, DRIFT VERTI(AL__ $U8 .DRI_ET DEPTH ANGLE DEPTH SEA D M ...... D.E_G_, ,T_O iA] c_o_cam_ N A T c s 4489 ~2 45~2 34 ~676 36 30 4543.32 4489,32 N87,OOW 13.09 S 58_4_,_6.8_ ~ W ,. 4769 38 15 4..6__!_7_,22 4563,2.2 .... ~_~.8.5700W 9._16 4862 40 15 ........ ~_~_8_9..t~..3, ~A.~__Sj.'~_3 ...... ~_5_~..QOW ...........a_ ,..O ~__S 699,60 W 4955 42 0 4759,29 4705,29 N8%¢OW 1.,._2..f~_.~q .... 7~J. W .... 5~41 48 o 48so.7~ ~836.7~ a~._h_0P~L ...... !...'Z_~_~_7 .... ~'.J 8~o.98. w 5235 52 0 ~951.16 4897.16 N79,OOW 29,~:~7 ~q 961,88 W .__p?__~,,,__..._,,"'~o~, .5~ .... 1 .... 5 ....................................................................................................................... .5007.51 4953,51 N76,00W 45.86 ~.! 1034.02 W ___~.'!2_!_.5~___0___~.P_6~__,~_?. 5p_._09__.__~_2_.__!_N_S!,__0_:0__W ............. 5.8..._,_7.7 __~xl 1107,2 ~ W '5515 ~0 0 5i21,9.3 ~057,93 N89,001~v 6_!,..2..6 fq ...... 1_!..8_Q,62 W _~7 o l 5'2 ~__0 ....... o_Z2:b__~:5 .~_! 8__<._¢_6_ .... .,,s..8_8_,_o_0vN ............. ~S.._._ s.2 ...... ~, .... i_3_~_~__._~_2_ w _4_.7_9_,.5.3 S_.. 87__55 ......... _3.._W ...... 1-.-.14-0 .............. 47.5 · i 1.- 5_3..0._,.:!7.._.5 .._ 8_ 8 1_9 ~.8.___W 2, ,_7_10 .................. ,5-2 (>-. 02. .5_8_.4_,_8.Z._5_~_8 ~.2 tg, W .. 2.-,~&l .~.S6~. ~- 6_.4_1._,..0.5 .... S_...8.9___lD_5_Z_W~,2.._0_54 ...... 6_9.__9__° .~_1._. K..89._...~+.0 .... 7.6_0..,5_,3 .... M 8..9_5...Z+ 8]'~ _l ._8.8_Z.~__7.~.&.._9~ 8 2_...!,..2..3 ...... N___._8 ~ ..... 26.____~.l__:! ... __I,_~..0_~. 8:2.0,9...4. 89 1 · ! 5__. N_. ¢. 8 ..... 5.2 .._5 1_0..:.5...,.04 N 87 2.7. .... :..K_W_ ....... Z._~6_9 ........... 103 ~. 49 10~.._?_8 N...8.6 .... :.7 .... 1..g..~_:....!9. .... ?~......87 9 5 z+ W .2~_81.1__ ......... 125_Z... ~ 5_. 1.3..2..6... 6.2 ....... ~L8_.7_2.7 ..~_O_,~J l_._14_9__ __i~2.~+. 6_5 579 z, 5 5887 55 0 53~6.99 5292,99 ~_.9_0_,_0_0.~'_, ....... 5..7.,..52 N L~,48_:~'. 1~_7..7...5.0 ~8_7 ._K___8_~~_,_O_O~ 1~.7~.. 4 ......................................... O_....~..3.b ......... 1 88.7.:. ~2 ~0 ~ ~0 55z~S ·: g 5>..~_b_:_2 .... ~_~_.~_,~_~_~5~' .... ~.{~.,.5.0_._!~.~._~_116 ..... L!?.L._.6_O~_._S_~__._i_4_O.~ .... =' ' 7 ' 54~5 50 0 ~63~ · 67 5585,67 ]~..~__~_?_~_(~.76 .... _6_!~.~_~_5~_52'. ~6 W 19_~_.i,_!5. .... !_.8._8 ..... ~0. ..... 8___~,:~ .......... ;0_...0. C_0_ ............... 1_9~ ,0.7 6726 61 0 ~776.,84 5722,86 NS~.., 00W .... 68~g 60 l~ 5822,~6 5768.46 N89,00W 68,08 ~N 2;~_J~.....W. Z~L&.5_~ .~_~_7~.5~'] ': 0,,_8_O5 ............ ~ZZ.]_..i3_ 7099 ?~EAS. DR~FT V~!_C.A_,L SuB ~_~.IFT T_OTAL _D._E P TJd A./,LGL. g. D~_P_._TId ........... .S. 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LQ_7,SZ 7_9_5_4_, : _7_9_O_0__2.&03_ .................. 6i_ .;L~_L9 .¢..~_~, _~ 8..k0_0 ,,2.9_2_5 6_0 1_k53_0 11817 8_2_5_%_, _ 8_2_0..0 ..... 29_7_9. 5..4__ 8 3 5 &, 8_3_0..0 3 02_9 .....................k0. , ~u~_5_~_. ..... g.§_Q_O. 3_02~ .... 4.7 ~3.3__q_, 8..5._0.0 ..... :1.2 0_ ~ ~, 8 ~ 5 ~. 8 6.0.._o_ 3._1A2 ............ _<+_g 875~, 82_o_o 3_Z25 ~ ~ 8~5~+, 8800 32.47 42 4._7_Q_,_i_8_LN ........... 60A3_,.7.0._:¢ ... 4_9 O_.._%l._.:,l : _51.~..&.2LT_~ 5_l.5_.._LS__L~ .... 6Z_49 ._7 8 ~: 5_9~_,_9.5__i~_____63./4.7_,..Z0 .... W ,5 9 9 ~_L.5_._Lt: .... 65.A 1,_.._80___A__ ........ 625_,2_7__~%J ...... 6539_,_38 ...... ,~ 9 0_5_4_, 9 0_0_0__ 3J_3_3 . z,,__~. 65:L.~.P_L_.L,L___6_7:Lg_..0.9_.I,; 1_..,:__4_, 9 I_Q.0 · 32__7_6 .......... ~_~ .6 7 4_,_~0__~_ 6_8 3_9. ,.. 0. ,~___W_ .("~ 9 _ ; NT ERP_D. LA.IF[') _VALUES TRUE AS.U..~ED DEPTH T I ~_&L_ _SUB___ ..... E P ~ S_EA______%O_ZAL ,,COORDiN~T E $ lOOn 2_0_0_0 4000 5_Q0_0 1_9_9_9_, ..... :L9_.45~,_ 29 _9_9_, ... 3_~6_Q.,. ___4 7__9. Z* ..... ~.7_3_8_* 5.4_,1_0.., __5.3_5 6., ........ 5 9_lD_, ..... _5 8..5.&, _~ 2 ,.B.6 ,, $ 0 :.i.'.q-6 W 5_,_O_~__S 7__,_6~ E 2 9._,fL5 S, 2 4 4 ,_4~___W ~_..gl__N_ ....... ,5_7_,_5. 2 t~ l_5.2_.,..L~.___N 3_2._8_2_,_6_0__!W HORIZONTAL VIEW SCALE I" : I000' ATLANTIC RICHFIELD CO. DRILL SITE 9-16 RADIUS OF CURVATURE MAGNETIC MULTI-SHOT ALE ARE TvDDEPTHS SHOWN 400- 800- 1200 1600 - VERTICAL SECTION' SCALE I" = I000' ATLANTIC RICHFIELD CO. DRILL SITE 9-16 RADIUS OF CURVATURE MAGNETIC MULTI-SHOT · 2_000 2400 2800 3 200 , ARE T VD · 4 _ ~%800 5?-00 - 5600 .................... - .................... ~ -' 6000 _ -- ; - 6400 _ . ~ooo~ ...... TVD: 9195' TMO: 12_,589' 7600 . ' _ · .......... AtlanficRichfieldCornpany North AmerP'"~-Oroducing Division North Alask~. ~rict Post Office Box 360 Anchorage, Alaska 995I~ Telephone 907 277 5637 October 13, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Ak 99501 Subject' DS 9-13 (13-7-10-16) Permit No. 77-8 DS 9-14 (11-2-10-15) Permit No. 77-25 ~p~s~I-I-IO-15) Permit No. 77-36 ~~-3-10-15) Permit No 77 37 Dear Si r- Enclosed please find Sundry Notices outlining our plans for the above-mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /kb Enclosures ,Form 10-403 REV. 1-10-73 Submtt "1 ntentions" In Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES'AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) 1. OIL r~ GAS D WELLL--J WELL OTHER 2. NAME OF OPERATOR At]antic Richfield ¢0mpany 5. APl NUMERICAL CODE 50-029-20257 6. LEASE DESIGNATION AND SERIAL NO. ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudhoe Bay Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P. O. Box 360, Anchorage, AK 99510 DS 9-16 (xx-3-lO-15) 4. LOCATION OF WELL At surface 877'N & 175'E of SW cr, Sec. l, TION, RI5E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 54' RKB 14. Check Appropriate Box To Indicate Nature of Notice, Re 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oil PoOl 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 3, T1ON, R15E, UM 12. PERMIT NO. 77-37 }ort, or Other Data NOTICE OF INTENTION TO: TEST WATER 5HUT~Z)FF ~ PULL OR ALTER CASING FRACTURE TREAT ~ MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) Perforate SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAI RING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS {Clearly state all pertinent details, and give pertinent dates, Including estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate seleci~ed intervals within the Sadlerochit interval. All perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere duri.ng perforati.ng operations. The downhole safety valve will be installed'and tested upon conclusion of job. Estimated Start Date' 11/7/77 16. I hereby certify that t~ true and correct SIGNED . , _ Dist. Drilling Engineer T IT LE DATE {This space for State office use) CONDITIoNso~(~pROvAL. IFANY: ' __ TITLE See Instructions On Reverse Side Post Office Box 3~0 Anchorage, A~sk~ 995~ Telephone 907 277 5637 October 4, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- D.S. 5-11 (xx-31-11-15) Permit No. 77-30 x-3-10-15) 77-37 Dear Sir- Enclosed please find Monthly Report of Drilling and Workover Operations for the above mentioned wells. Very truly yours, Frank M. Brown District Drilling Engineer /am Enclosures Form ~o, P--4 1R3L"V'. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION CONW~I'i-I'EE SUBMIT II~ DUPLICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WeLL WZLL 2.NAME OF OPEI~ATOR Atlantic Richfield Company 2.ADDRESS OF' OPERATOR P.O. Box 360; Anchora.qe, A1 aska 9951(1 4.LOCATION OF W~!.L 877'N & 175'E of SW cr Sec. 1, TION, R15E, UM AP1 NU~IERICAL CODE 50-029-20257 6 LEASE DESIGNATION AND SERIAL NO ADL 28328 IF INDIAI~', ALOTTEE OR TRIBE NAME 8. L,~IT F.~%M OR LEASE NAME Prudhoe Bay Unit 9 W~..t ,l, NO DS 9-16 (xx-3-10-15) 10. Fl~..l.r) A_ND POOL. OR V,'ILDCAT Prudhoe Ba7_ _Field-Prudh°e Oil Pool Ii SEC., T,, R., M. (BO'r'I'oM HOL.E O B.rF_.C'T ~_3 Sec. 3, TION, R15E, UM 12. PER.MIT NO 77-37 13. REPORT TOTAL DIEP'I'H AT END OF MONTH. CHA. NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTI-I SET A.N-D VOLI. rNIES USED, PERFORATIONS, TESTS A_ND RESULTS FISHING JOBS JUNK Lhl HOLE AND SIDE-TRACKED HOLE AND ANY OT}EER SIGNIFICANT CH. A3~GES IN HOLE CONDITIONS. Report of Operations for the month of September Spudded well @ 1300 hrs 9/8/77. Drld 17½" hole to 2750'. RU & ran 13-3/8" csg w/shoe @ 2727'. Cmtd w/3100 sx Arctic Set cmt. Slurry wt 15.0 ppg when lost returns, max press 1000 psi. Pumped additional 1700 sx w/no returns. Down squeezed w/250 sx Arcticset Cmt. Top of cmt @ 2610'. Drld to top of FC. Drld cmt in 13-3/8" csg. Drld 10' new hole. Tstd form. Drld 12¼" hole to 11,400'. RU & ran 9-5/8" csg w/shoe @ 11,370', FC @ 11,291' lower FO @ 2528', upper FO @ 2412'. Cmtd w/lO00 sx Class Gcmt, 0.75% D-65, slurry wt 15.8 ppg. Opened lower FO. Cmtd w/300 sx, 15.1 ppg Arcticset cmt w.0.2% D13R & 0.2% D59. Closed lower FO. Opened upper FO. Arctic Packed 9-5/8"x13-3/8" anul w/260 bbls Arctic Pack. Tstd 9-5/8" csg w/3000 psi OK. Drld cmt, float collar, float shoe & 10' new form. Tstd form to 11.3 ppg equiv. Drld 8½" hole to 12,589'. Ran DIL/SP/ BHCS/GR, GR/CNL/FDC/CAL. As of September 30 RU & ran 7" lnr w/shoe @ 12,588', top @ 11,070'. Cmtd w/520 sx Class G cmt w/0.75% D65, 0.2% D46, 18% D44. 14, I hereby is true and correct District Drilling Enginee~A~~ SIGNED TITLE NOTE--Report on this form is required for each colendur month1 regardless of the status of operations, and must be tiled in duplicate with the oil and eps conservation committee bythe 15th of the succeeding month, unle~8 otherwise directed. THRU: DEPARTMENT OF NATURAL RESOURCES Division of Oii and Gas Conservation O, K. Gtlbreth, Jr Dt rector Hoyle H. Hamilton Chief Petrotetan Engineer Petroleum Inspector . September 30, 1977 To Witness BOP Tests for Arco Drill Site 9-16, Sec. 3, T.iON, RISE, U. M. 9-9-77. t went to Prudhoe Bay by Wien Airlines to witness BOP testing for Arco on drill site 9-16. ~/hen I arrived at Prudhoe I was informed the BOP test would be delayed. In the meantime I witnessed two surface control subsurface safety valves and two surface safety valves at drl I1 site 1-7 on 9-9-77 and drttl site 2-6 on 9-II-77 which are separate reports. 9-11-77, 7:15 PM. BOP tests started on dri 11 si te 9-16. Kirk White was the supervisor for Arco. Tests were done with mud and diesel oi 1, and the test plug was a wellhead type. Pressuring up was done with a triplex pump. The annular preventer was tested to 3000 psi OK. The upper pipe ram, the lower kelly, the check valve on the kill line, five valves away from the stack on the choke line and superchoke, and three valves on the manifold were al1 tested to 5000 psi at ~e time and held OK. The inside and outside kill valves and inside and outside choke valve were tested to 5000 psi OK. Next three more valves on the manifold were tested and upper kelly was tested to 5000 psi OK. Two more valves away from the stack in the cellar was tested to 5000 psi OK. The lower pipe rams were tested to 5000 psi OK. There was a ball valve and dart valve on the floor in good shape. The test stem was pulled and the blind rams were tested to 5000 psi OK. The nitr~n backup system had four bottles with 2100, 2100, 2200, 2200 psi each. The master gauge on the accumulator had 2800 psi. The fuel tank is steel. The mud pit ts Men but well harmed. The well sign was not on location. Tile pad is well kept and free of debris. When tests were first started, we spent about two hours trying to run down a leak but it turned out to be leaking back th rough the test pump. Th!s was fixed and BOP tests we re completed. in su~ry: I witnessed the testing of BOP's on drill site 9-16 with no leakage for Arco. Tests were satisfactory. Oil and Gas Conservation Commit~ .~. ~,~ ..... Field Inspection Report '7t ! .... .") .,~' Drlg. Permit NO. ~z - Well/Platfm :'~ '"~. Represented ~ ~'/.,~' ~'~/,~'~r~:Name & Number Opera tor~ ]7 ~ ~. 9 ..... SatisfactorY Yes No (~) () ~,~: , 09 ( ) () () - () () () () () () () () () () () ( () () ~, ......... () .() ~,,~ () (,) Type Inspecti on ,General ll Sign .2. General. Housekeeping t, Reserve~ Pit'(,~)open( )filled 4, Rig S 5. Wells 6, s ( ).Well Test Data 7. Well Nos. , , , 8. Hrs.' obser , , , 9. BS&W , , , 10. Gr'. Bbls. () Fi.naPalming-- (X) ( ) lZ. Wa '-( )caPPed( )Plugged ''!') ()) 1.3. ~:Clean?up 14. Pad' level ed Satisfactory Yes No I (~-) ( ) (~)() ~) () ") () ~) () (~)() ~,)'( ) ~) () , >)() ) () Total inspection observati.on time Rema r k s · ~ ~. .~- ~ ~ · · , . ' ,, o, ,.-. ~ , ~ .... ,~ , cc.~d~ ,AW/~/,~..'5 Not~fy ~~.-clay. s .or when re~cLy_~. Inspected b T~pe Inspection ~. BOPE T6Sts , ,~! o 1 . ]~_~Cas]nfl set 16. Te~L fluid-( oil 17. Master Hyd. Control 18,' N2 btls;~tm~__ ~, 1.9. Remote Controls 20. Drilli.nq s ets 21~ Kill Li'.~e- valve 22. Choke Flowl,ine ( ) HCR.valve 23. Choke f,anlfold No. valvs[~ flds~ 24. Chokes-~)Remote( )Pos.. 25, Test Plug.( )Wellhd( )csg(.).none 26. Annular PreVenter,:O~mpsi 27. B 1 i nd Rams [~"~Ps 28. 29', ~ & y-cock~m~ psig SafetY 'F1 oor' vi eaks and/or equiP, fail Date 1977 pm~ ~ DS 9-16(~x-3-1~15) Atlantic ~&chfie!d Pen~t No. 77-37 Atlantic Richfield ~ Andre=age, ~ 99510 Dear Enclosed is ~ approved applicatic~ for permit to drill the abov~ referenced w~ll at a loca~ ~ Secti~ 3, Township 10N, Range 15E, UFL Well samp]ms, ~ ~ and a mud log are not reqldred. A directic~al ~ rivers in ~ ~ their drainage ~ have been classified as important for ~ spmwn/l~g or m~igrat/on of azlaftrfmx)us fish. Operations in ~ ~ .are subj~ to ~ 16.50.870 ~ the regula~ p~gated ~ (Title 5, Alaska ~strative Code). Prior to contraries operatio~ you ~ be o0~:act~d by t~ Habitat ~tor's office, Depart- ment of Fish ~ C~. Pollution of any waters of ~e State is prohibited by AS 46, Chaptmr 03, Article 7 and ~ regula~ ~gated ~etmder (Title 18, Alaska Administrative ~, (~er 70) and try the Federal Water Polluticm Cc~trol Act, ~ ~. Prior to cc~mm~Lng operations you may be contacted by a represen~ve of ~ Department of Env~ta! Pursuant to ~S 38. ~, ~ ~ ~ State Leases, the Alaska De~t of ~ is being ~ied of tt~ issuance of this permit to drill. notified .so that a ~tative of the Division may be present to witness test~ of blowout preven~ eq~t before surfaoe casing shoe is drilled. F. M. Brown -2- P. B. ~ 9-16 June 15, 1977 In ~ e~nt of su~~i~ or abandonment please give this office adequate advanoe notificatic~ so that we may have a witness present. O. K. ~lhreth, Jr. Enclosure De~ of Fish and Gam~, Habitat Section w/o encl. Depar~-=~mt of Enviro~ental C~merva~ w/o encl. ~t of ~, Su~, Lab= Law Divisi~ w/o encl. Form 10-401 R~V. 1-1-71 STATE OF ALASKA SUBMIT IN TRI (Other instruct], i / ...j OIL AND GAS CONSERVATION COMMItTiEE c~ '~ la. TYPE OF WORK DR! LL '~ b. TYPE OF WELL OIL t'7--1 GAS SINGLE '"ELL ~ WELL F-1 OTHER ZONE [~] . . NAME OF OPERATOR · Atl anti c Ri chfi el d Compa.n.y 3.ADDRESS OF OPERATOR P. O. Box 360 Anchoraqe, .Alaska 99510 4.LOCATION OF WELL At surface 877'N & 175'E of SW cr Sec. 1, TION, .R15E, UM. PERMIT TO DRILL OR DEEPEN DEEPEN ~ .TE Atpr°p°~dpr°d''°nq385'N & 1320'W of SE cr Sec. 3, T!ON, R15E, UM 13. DISTANCE IN blILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* Approximately 6½ miles northeast of Deadhorse, Alaska ... API No. 50-029-20257 6. LEASE DESIGNATION AND SERIAL NO. ADI 2832.8 i 7.' IF INDIAN, ALLOTTEE OR TRIBE NAblE 8. UNIT FARM OR LEASE NAME Prudhoe Bay 9. WELL NO. Drill Site 9-16 (xx-3-10-15) 12. bIULTIPLE F--1 .ZONE k_J Sec. 3, TION, R15E 14. BOND INFORMATION: ~pEStatewide Suretyand/orNo. Federal Insurance Co. #8011-38-40 Arno.n, $1 00,000. O0 15. .DfS'/'ANCE FROM PROPOSED * . 'LOCAT,O~ TO NEAREST- 320 PROPERTY OR LEASE LINE, FT, . l (Also to. n~est drig, urfit, it' any) ~8. t, IS~rANCE VROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR .,aPLIE~ FO~, Fr, 26 O0 2'1. ELEVATIONS (Show whether DF, RT~ CR, etc.) 21' Pad Elevation (Gravel) 23. 16. No. OF ACRES IN LEASE ~560 19. PROPOSED DEPTH 12,932'MD 9,162'TVD 17. .NO,ACRES ASSIGNED TO Tills WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START 12 Oct. 19.77 PROPOSED CASING AND CEMENTING PROGRAbl SIZE OF HOLE - ' sIZE oF'CAsINO' '' WEIGHT PER FOoT GRADk kETTING DiPTH ' ' Quantity of cement ..... ........... 20" ' .'.'94#. .H,40 lO0'+ Circ to surf approx 500 sx q7-1/2 13-3')8''i' 72# N-80 27.00'; Circ to surf aoDrox 5560 : '' 'I · ' ' ..... 12-1/4 g-.5/a ..... 47~ N-an ll4fifi'~ ?Rna,+ cmt column on. lst.stage !0 .... m .... & qoo-qa ~flfl'+ Imfan endqfnn:,,,125+cv 'a-l/~ ...... 7" 79~ N-aN ]~aaq.'+ ~.' th~ ~an 3aa ~ + ...... , .... )0 sx AtlantiC Richfield Company proposes to directionally drill this well to 12932'+MD, 9162'+TVD · to prOduce the Sadlerochit zone. Logs will be run across selected intervals. - - A 13-5/8" 5000 psi Hydrill and 13-5/8" 5000 psi pipe and blind rams will be used on the 13-3/8" casing. The BOP equip- ment will be pressure tested each week and operationally tested each trip. A string of 5½" 17# N-80 tubing, packer and necessary provisions for subsurface safety equipment will be run. The packer will be set above the SadleroChit. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer pro.am. ('ibis space f,>r S:ate office use) CONDITIONS OF APPROVAL. IF ANY: OTHER REQUIREMf£NTS: TITLE District Drilling Engr.' SA.~,PLES AN'~ CORE caiPS ~QUIRED ~ ~o DIRECTIONAL SURVEY REQUIRED ~ Y~:S ~ ~'o MUD LOG [] YES A.P.I. NUMERICAL CODE 50-029-20257 PERMIT NO. 77-37 APPOVED BY. · ..... ~ ' APPROVAL DATE wrrL~ Chairman *'see Instruction On Reverse Side June 15, 1977 DATE .......June 15, 1977 2.00' ~) Well 17 Well 18 250' OWeil 19 2.74' Well 20 SEC. I SEC. 11 SEC. 12 EXISTING WELL OR COND'UCTOF{ PIF~. CERTIFICATE OF SURVEYOR I HERE:BY CERTIFY THAT I AM PROPERLY REGISTERED AND LJCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION AND ALL DIMENSIONS ANQOTHER DETAILS ARE CORRECT. / ~.~S BULL{ Wi::::LL LULAI IUFI::) '/ELL No. 12 ..AT. 70° 14! LONG. 148° 14' 46.838"Y 5 942 815.87 06.527"X 7 i 8 456.54- WELL No. I~ LAT. 70°14' 45.68~"Y 5 9~2 699.30 LONG. 148°14' 0.5.80zC'X 718 484.81 WELL No. 14- LAT. 70°1 4' 44.53Z"Y 5 94-2 582.98 LONG. 148°14' 05.073"X 718 51~.32 WELL No. 15 4' 43.577;:Y 5 94Z 466.30 LAT. 70© 14, LONG. 148° I 04.:552. X ?i8 5~1.52 WELL No. 18 LAT. 70° 14' 4;3.221~Y 5 942:349.60 LONG. 148° 14' 0~.615 X 71~ 570.~2. WELL No. 17 LAT 70° 14' 41.065" Y 5 942 2.32.79 LONG. 148° 14'02..893" X 718 598.50 WELL No18 LAT. 70° 14,' 39.9t0" Y 5 94,2- I 1 6.14 LONG. 148° 14'02.176" X 718 626.56 WELL NC). 19 LAT. 70° 14', 38.7601~,Y 5 942 000.01 LONG. 148°14 01.442 X 7'i8 655.18 WELL No. 2.0 LAT. 70° 14' $7.606" Y 5 941 88:5.42 LONG. 148 14'00.721" X 718 68;5.57 ARCO No. HVLNo 39-DS9-77 ATLANTIC RICHFIELD CO. AS BUILT DRILL SITE No. 9 WELLS No. 12,13 ~ 14 LOCATED IN PROTRACTED SECTION ] ,T. 10 N., R.I 5 E,U./~. PREPARED BY HEWlT'r V. LOUNS~URY & ASSOC. 72:3 W. 6fh AVENUE ANCHORAGE ~ALAS~A DATE FEB. 1977 SCALE I" = 200' CHKD BY PC FIELD .. CHECK LIST FOR NEW W'ELL PERMITS Company /~¥00 Yes No Remarks 1. Is the permit fee attached ..................... x/~ Lease & 'Well No. ~" _~-/,~ _ m 2. Is well to be located in a defined pool .... . .......... /z,r~_/f_ 3. Is a registered survey plat attached ._Wz~,~__ 4. Is well located proper distance from property line ......... ~v~.~ 5. Is well located proper dist~ance from other wells .......... 6. Is sufficient undedicated acreage availabl'e in this pool ...... ~ 7. Is well to be deviated ....................... X/~r-- 8. Is operator the only affected party ................ /~-- 9. Can permit be approved before ten-day wait ............. )(/~ 10. Does operator have a bond in force ................ '.. ll. Is a conservation order' needed ..... . .............. 12. Is administrative approval needed .................. ~/~4/y, 13. Is conductor string provided ..................... 14. Is enough cemen.t used to circulate on conductor and 'surface .... ~=t5- Will c,emen-t tie' ~.n-s.u~f'a'~e' and intermediate or prOduCtiOn strings 1'6. Will cement cover all known productive horizons .......... 17. Will surface casin~ protect fresh water zones ........... 18. Will all casing give adequate safety in colla'pse,'tension & burst' 19. Does BOPE have sufficient pressure rating - Test to ~..om_O_psig "20, Has DMEM approved Plan of Operation .......... - ...... Additional Requirements: Approval Recommended' -Geo 1 og~' Engi n.e. er i ng: ll~l~ JTtt,,~ FIH H '~-~O CM ~ - ' 'LCS~RAD~ HWK Revised 11/17/76 . Weld History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No special'effort has been made to chronologically organize this category of information. SIj.~.NIA~i 01¢' D/~TA RLCUt~DS NLtt~BE;I-', {.JF IqECURDS: 155 I,,ENGTH O~,' I~,ECURDiS: 1014 I,,,E;NG~I'Id LtF I~A.S'r RE;CU~D: fILE NAME: EDIT .003 MAXINUN PHYSICAL RECU~,D TAPE 'I:RA 1 l~gR I,ENGIIi: 1 .:t2 I'APE N.AMk: (~0000 SI;;RV 1Ck .NAME: EDIT TAPE CONTINUATI(]N NUi~%BER: 01 NLX. I' TAPE NAN,: 1024 g~"l'l~;S DAi'E: 801 I, t22 11 000000 ?'77 t77 ~777 000000 7 l?.'! ? 11't77 11 000000 1177777777 000000 77777 1 / 777 I 111 OO OO 77 OO O0 77 1 i 11 O0 O0 77 O0 OO 77 11 O0 O000 77 O0 0000 77 11 O0 0000 77 O0 0000 77 1 1 O0 O0 O0 1'7 O0 O0 O0 7 7 1 i O0 O0 O0 17 O0 O0 O0 11 0000 O0 77 00OO O0 Il 11 0000 O0 77 0000 00 ?'7 11 00 O0 77 O0 OO 17 11 O0 O0 77 O0 O0 77 } 1 I 11 i 000000 77 OOOO00 ll 1 i 1111 00OO00 77 O00000 11 bbbV~6 000000 000000 000000 000000 ~bO6~b 000000 000000 000000 000000 b~ O0 O0 O0 OO OO OO 00 O0 66 O0 O0 O0 O0 O0 O0 O0 O0 66 O0 0000 O0 0000 OO 0000 O0 0000 66 O0 000() O0 00()0 O0 0000 O0 0000 b6bbbbfl6 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 6666Ob66 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 6~ 6~ 0000 O0 O000 O0 OOOO OO 0000 OO 66 66 0000 O0 OOO0 OO 0000 O0 0000 OO 06 66 OO O0 OO O0 O0 OO O0 O0 66 b~ O0 OO O0 OO O0 O0 O0 O0 60666b 000000 OOOO00 gOO000 000000 bb66~6 000000 000000 000000 000000 *STARt* LJSL~ PCAL [10707~60000] dub SH]LP 5E[4. 138,30Al.'m 22-dAN-80 15:03:40 H(JI'.~iI'(_~R $w$ KLIOE./t4 JUL-19. ,S2'Ak'r, *5'rAk'I* USLI~ PCAb [I0707~60000] dUB ~HIP SEu, 13~3 t)A'I'L 22-JAN-80 15:03:4~) ~-~()t~ill'ttR $m$ i~L10~34 JUL-79. ,$TAt4T, iIiII1 PP iiiii1 PP 11 PP 1I PP I1 PP 1I PP Ii PP 11 PP 1I PP i1 PP l.i PP II PP 1Iiili PP Illlli PP PPPPPP PPPPPP Pp PP PP PP PPPPPP PPPPPP ,S'I~ARI', LJ,.,%ER PCA6 [10'707~o0000J dub SHIP bI[JN]'Ft~R 5w5 b. blOE34 Jill 79. *START* ~'ll,h: [)S~H:fNIP TU<057>[1.0707.600001 C~a, ATEO: P?INTE~: 22-dAN-B0 15:04:01 OULUL S~ITCHES: /~I6k:~oRT tC[.)PIES:I /SPACING:I /61MI1'1123 /~URMS:NO~I,,~AL ,SLL~. 1,38,) Oal~k, 22-dAN-B0 i 5-JAN-80 1515.3:17 S H I P T 13 · ~HIPPI NG INSTRUC'I~iON5 ISSUED J 5-JAN-80 15:49 B~ GHB PCCC VENTURA~ CAblF{JRNIA 93003 P¢CC 11Iiii 11IIIi 1i 1I 11 11 11 1i 11 ii IlIllI IllIII f'~ 000000 000000 3333133 000000 000000 333:33,3 O0 O0 O0 O0 33 33 O0 O0 O0 00 .33 33 O0 0000 O0 0000 33 00 O000 OO 0000 33 O0 O0 O0 O0 O0 O0 33 O0 O0 O0 O0 O0 O0 /t 3 0000 O0 0000 O0 0000 O0 0000 O0 33 O0 O0 O0 O0 ~ 3 33 O0 O0 O0 O0 33 33 000000 000000 33.33-~3 000000 000000 333_3 ~3 *$:rARI'* LiSE, t~ PCA[,, [10707~b0000J dub SHIP N{JNi'ru~ SwS KLlOL34 JUL-/9. *START* flbg: DSKH:VLRI~.O03<051>[IO707,~0000] CRLA'IED: PRINTED: 22-JAN-80 15:04110 OUEtJE SwiTChES: /~ILEI~UHT /CUPiE8:i /SPACiNG:I /LiP~iT:123 1,~8.t I)A'I'~. 22-OAN-80 22-JAN-~O 15:02:56 15:03:4b SCHLUMBERGE~ COMPUTI. NG CLNTtuiq 10707,60000 REEl, HEADER REEL NAMe;: P.C.A.L. SERVICE NAME: REEL CONTiNUA'Ii'ION NUMBL;R: O1 PREVIOUS REEL NAME TAPE DEADER LENGI'D: 132 B~TLS TAPE NAME: 00000 SERVICE NAME;: EDiT TAPE CONTINUATION NUMBER: O1 PREVIUU$ TAPE NAME: C()MMENTS: DALE: 80/ 1t22 OATE: 80/ 1/22 FILE hEADEg I, ENGIH: 62 FILE NAML: EDIT .001 MAXI, MUM PH~81CAL RECURD LENG'i'H: PP,~'~,VIUUM ~'ILL NAME: ~'lbg CtJMM~NI'~ PASS ONE AND PASS 'fWD 1024 iSY'l'k, 8 SiTE iN~URMATitJ~'q RECORD LENGTH: w E L L: [; IELD: RANGE: TOWN: SEC7 1 UN: C[)UN I ~: STATE: 181 ~Y'fk$ Ai'LAN'IlC R1CH[IEi,D CO. D.8. 9-1~ PRU£)H[Jk 6A~ 1UN 3 N. SbC}Pk ALASKA DATA PO~i~IAT SPgCiP'ICAI'IUN ~.~NTR~' BLOCKS: 0 1 66 DATU~ SP~CI.["ICA'TIUN BbUC~,6: ~NTRY JC TUUb OEPT GR 'iDT T A O T D T THA'I TDT SIGH 'I'DT N 1TD TOT IN2TD TOT N 3 T D TDT ~ 1 TD TDT f 2 T D T O T f'3 TD TDT GR TDT T ~ U T D't TRAI' TOT 8IGf~ TDT N1 I'0 TOT N2TD TDT N ~'rD T DT F1TD TDT f2TD TDT ~ lTD TDT S V OR.D ~t UN 1 TS ~T GAPI US C/C CU CPS CPS CPS CPS GAPi US C/C CCI CPS CPS CPS CPS CPS AFl 0 51 51 51 51 51. 51 51 51 51 51 51 51 51. 51 51 51. 51 51 51 51 AP I 0 31 41 42 ~0 39 39 39 39 39 39 31 41 42 $0 39 39 39 39 39 39 AP 1 APt 0 0 2 0 1 O 1 0 1 0 1 0 2 0 3 0 1 0 2 0 3 0 2 0 1 0 1 0 I 0 I 0 2 0 3 0 1 0 2 0 3 O 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1. 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1 o ~ o 0 1 0 4 0 0 1 0 4 0 o I 0 4 0 0 I 0 4 0 0 I 0 4~ 0 0 1 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1 0 4 0 0 1 RLP DgP'£ 68 0 0 68 0 0 08 0 0 08 0 0 08 0 0 08 0 0 68 0 0 b8 0 0 68 0 0 68 0 0 68 0 o 08 0 0 08 0 0 08 0 0 68 0 0 08 0 0 68 0 0 08 0 0 68 0 0 b8 0 0 e~8 0 0 DI~PTH 12520,000 12500,000 12400,000 121300,000 1,2200,000 12100,00O 1.2000.000 11900,00O 118.00o000 ~;MUN ic N1TD ~2TD TRAT N3TD GR NITD ['2TD TRAT N3TD GR NI TD F2TD TRAT NBTD N1TD P2TD TRAT N3TD GR N1TD TRAT N3TD N1TD T R A T N 3 T D GR N 1 T D [~2TD I'RA'I' N3TD ITL, 2TD I'RAT N3TL) GR N1TD k2TD I~AT VALUE 67.100 101'7.017 105.105 -999.000 -999,000 31.900 1381,381 141,1.41 4,400 456,456 37,500 1347,347 223,22J 3,445 472,472 16,500 1549.550 22~,22~ 2,705 50t,504 50,900 2418,418 226,226 4.060 606.607 17,400 1765,76b 242,242 3.020 500,561 18,500 1825.826 242.242 2.945 b32,633 22,200 1823,824 235,235 3.005 b54.655 55, 'l O 0 2728.729 268.268 4.b20 ~ 14.o75 t, qt)N iC TAU N2TD SiGM PITD TAU N2TD l~ 3TO 81GM [;lTD TAU N2TD S1GM ~'iTD N2TD ~'3TD SiGM [;:lTD 'IAU N2TD F3TD SiG~ [;lTD TAU ~2TD ~'3TD SiGM ~ITD T A 0 N 2'I'0 [; .lTD ~ lTD 'tAU N2'ro [;3'rD IAU N2TD ~3TD V AbUE 102.013 748.'749 66.066 -999.000 -999.000 87.925 894.895 62.062 49.425 190.190 180.503 928. 929 64.064 26 100 278:278 291.195 1025.025 60.060 15.600 3:77.377 140,000 1475.475 84,084 ,33,425 386,.~86 242.390 1207.207 64.064 18.500 379. t79 249.937 1221.221 72.072 18.625 385.385 238,868 1261.261 78.078 19.725 390.396 122.893 1~43.644 8o.08b 35.625 ~92.392 TRAT NSTD GR Ni, TD N3TD N1TO ~2TO TRAT N3TD GR N1TD TRAI' N3TD alTO P2TD TRAT N3TO NITD TRAI~ N3TO GR G~ I~A I' Gg. l~ 1I'O f 2'l;O VAL, UE 5.040 484. 484 -999.000 -999.000 -999.000 4.305 418,418 43.000 1313.313 127.1.27 3. 645 456.456 43. 800 1 389. ,389 230.230 2.925 492.492 20.400 1629.030 249.249 5.895 540.541 4'1,900 2706.707 23~,236 2.975 574.574 16.200 1799.800 257.25'1 2.~20 578.578 1~,900 1.953,954 273,~73 3.070 614.o15 23.400 2040.040 274.274 4.785 O60.o61 b8.000 2632.032 243.243 SIG~ ~:ITD TAU N2TD F3TD N2TO 'l>g U N 2'i'0 TAU m 2TD .F 3 'i~ O SIGM F1 TO TAU N 2 TO ~"' 3'I'O TAU N 2'to ~ 3TD SiGM 'tAU N 2 'tO [;'ITt3 tAU N2TD ~3TD ~IGM ~lTO 'tAU i~2'FO F31'~ VAbU~ 43.025 142.i42 -999.000 -999.000 -999.000 50.325 20~.208 89.93i 898.899 b2.062 25,525 291.291 1'76.22~ 948.949 O8.0~8 15.625 343,34.3 290.1U9 iObl.O01 69.009 32.225 360.366 134.214 1633,~34 1~.850 353.353 244.900 1157.151 '14.07~ 18.1Z5 3/1.371 2~3.899 131~.317 19.125 332.332 230.5bb 13o9.369 ]4.0t4 30.325 390.390 125,151 160i.o01 ~O.O~o i1700.000 1 I 600. 000 1159q.500 ~MiJN lC GR NITD T~AT N3TD G~ N1TD E'2TD TRAT N3TD ,~* 1 T D f'2TD 'rRAT m 3 TD VAL '? a 2424 204 5 688 151 2496 214 5 7OO 151 2496 214 5 7:10 UE .9O0 .424 .2O4 .365 .689 .700 .496 .214 .385 .701 .700 .496 .214 .140 .731 1/A U m 2TD 8IGM ~ITD TAU N2TD ~3TO SIGM PI'rD ~AU N2TD ~'3TD 8IGN ~ITO V A L U 116. 1.511. 92. 39. 33 a. i17. 158'7. 114. .:18. 332. 1 17. 1587. 114. 1:t9. 350. 004 511 092 600 107 587 114 6O0 ::t32 10 '7 587 114 ~25 350 T ~ A i: h I T D t' 2TD '1' R A f .N 3TD GR ~ 1 T D P2TD TRA'I' a3TD GR ~2TD VAbU~ 4.900 680.081 87.100 2536.536 21,0.210 5.220 69~.097 130.000 2504.504 204.204 5.405 690.691 113.'100 2628.028 218.218 MNkMUN LC 81G~ P'ITO TAU N2TD ~'3TO t~ 1 T t3 TAU N 2 T U t"'3 T t) TAU N2TD [~ 3TO 330.33~ 112.830 1.031.632 92.092 38.025 330.330 115.849 l, O03.~Oq 111.111 38.025 33U.330 112.0'75 110.110 DATA RKCU~D$ NUMBLR UF RECORDS: 1.55 I.,ENG~Ih O~, RLCOIqDS: 1014 O'~TES LENGTH tJ~ LAST ~ECOI4D: 342 B~!tLS FlEE TRAJbE~ 1024 B~'I'ES [' ILE }*lEADER I,ENGTit: 62 BYTES I'ILE NANE: EDiT .002 MAX.][MUM PHI~SICAL RECuRD LENGTH: PREVIUU8 ~ILE NAME: FILE CUMNENT8 PASS THNEE 1024 WEI.,i~ ,.S.ITE iNFUlqMATIt]N HECUi-<D LLNGI'H C~IPAN ~ t' I ELD: RANGE,: T{IWN: SEC '1'1 UN C 0 U N 1'~ STALL: 181 BYTES ATLANTIC I~ICHblLLD CU. D.S. 9-1 6 P P, IJ D H U t"., t3 A :~' 1.5E iON N. SLt)Pe~ ALASKA 0 1 66 0 DATUt4 ~PE, CIF ICAI'ION ~.bJ, JCK~: [,NTR~ lC TOOL, SVURD~ UNITS APl AP1 AP1 APl. FIbL,~ &IZ~ EXP PROC SAM REP DEPT SHill':1' 1~'~I~ 0 0 0 0 0 ,4 0 0 1 b 8 0 0 GAPi 51 ,~1 i~2 0 0 4 0 0 1 b8 0 0 U S 51 4 ! I 0 0 q 0 0 I b 8 0 0 C/C 51 42 1 0 0 ti 0 0 I 68 0 0 CO 51 40 1 0 0 q 0 0 i b8 0 0 CPS 51 ~9 1 0 0 q 0 0 1 b8 0 0 CPS 51 ~]9 2 0 0 4 0 0 I 68 0 0 CPS 51 39 3 0 0 4 0 0 1 b8 0 0 C P $ 51 39 I 0 0 4 0 0 1 68 0 0 CPS 51 ii9 2 0 0 4 0 0 I 68 0 0 CPS 5! .~9 3, 0 0 4 0 0 1, 68 0 0 1) E P T H 12520. 000 12500.000 12400.000 12.300,000 12200,000 12100.000 120O0.000 11900.000 11800.000 11700.000 11600.000 ,11594.500 E M [J 1'41 C GR N 1 T [,) [. 2TD GR N 1 T D N 1 'r D F2 T,t) N I TO F2 T D G~ N 1 NITD F 2TD N1TO ['2 TO N1TD F2 T D GR N1TD ['2TD (314 N 1 TD F GR N1 TD I'2TD GR N1TD V A b U E '-'999.000 -999.000 -999. 000 18.100 1431,431 150,150 41.600 127'?.277 215.21,5 20.600 1929.930 296.296 46.900 2542.542 232.232 20.20(') 2006.006 300. 300 19.400 185].854 250.250 23.300 1089.690 247.24'7 59.400 2694.694 244.244 85.700 2572.572 228.228 114.900 2664.665 237.237 114.900 2664.605 237.237 ~ N i~ l'<i U N i C T A U ~'~ 2 T D t~' 3 T' D fAO .N2TD ~3TO N 2 TD T A U N2TD F 3'i'D IAU N 2 T [) [. 3TO TAU N2TD 'tAU N 2 T D [' 3TO T A U N 2'tO ~ 3TD 1' A O [' .3 'I'D iA ti N 2TD l' 3TD 'lAd N2TD ~3'I'0 'IAU N2TD 1' 3 TD V.AbUg - 999. 000 -999.000 -999. 000 88.176 1017.01'1 86.086 i92.075 962.9b 3 74. ()74 272.0'15 1261.261. 82.O82 135.975 1~03.b04 90.090 230.818 1375.375 94.094 252.704 1273.2'13 79.079 240.415 1207.207 79.079 123.145 1717.718 90.090 113.836 1655.656 9~.093 11'1.358 1~87.688 120.120 117.358 1~87.eB8 120.120 i:* ,,~ 'ID I'RA I N 3 T D A 1' 'I'D T Pt A 17' N3TD TH A T N 3 T D T Ii A i' N 3 T O N 3 T O 1' H A 1' N 3TO :1; RA 1' l'leA'l' N ]TD '1HAl N31'u VALU~ '999,000 '999.000 4.500 604.604 3.300 61~.~17 2.045 678.679 4.020 ~88.b89 3.075 70 b. 70 '7 3.065 608.069 3.085 4.835 744.745 5.285 '7 82.783 4.805 788.789 4.805 788.789 MNLNLIN lC f I i' O 5i GM S iGM fl TD S 1 G M ["lTD $ IGM $ I G M F1 TL) S 1 GM [.' 1,1 SIGM lTD ['lTD S 1 G M 51GM [~'1 I'L) 61GM F'I i'L) VAbU~ -999.000 -999.0(i)0 50.125 220.220 24.025 284.284 ib.525 404.404 32.900 380.380 19.625 39b.39b 1't.925 357.357 1~.5'/5 340.34~ 30.300 39.125 338.33~ 393.393 38.000 393.393 SUMMAR]t 0[" DA~A R~CU.RD,S I~ENGil'lq O~ RECi3t~DS: 1018 BY~It;S I..,I~CNGI'H 0["" LAS'I' I~fi;CLtRD: 53-4 B~'I'ES LENGTH: 62 BYTES FILE NAME: EDIT .002 MAXIMUM PMXS1CAL RE;CURD LENGTH: NEXT ~lbg NANE: i024 LENGTH: 62 BYTES ~'ILE NAi'4E: EDiT ,003 M.AAI~qLiM PH¥SICAb RECURD bENGTH: PRE~IUUS ~ILE NA~IE: ~lbE COMNENTS ~:'A~a ~UUR AND PAS& ~IVE 1024 BITES 181 bY'lES ATLAN:I:IC MIC~f'iLbD CU. D.S. 9-I~ PRUDMOE BAY iON 3 N, ALASKA 0 DATI,JiVl SPECIFICATION BbOCKS: ENTRY. 1C I'OUL SVtlfRD~ UNI[[~S AP1 API APl APl FIL~ ~l, Zb ~XP PHUC SAivl H~P DEP:I' SMi~I' [~" T 0 0 0 0 0 4 0 0 1 68 0 0 GAP I 51 31 32 0 0 4 0 0 I 08 0 0 US 51. 41 1 0 0 4 0 0 I 68 0 0 C/C 51 42 1 0 0 4 0 0 I e~8 0 0 C U 51 40 1 0 0 4 0 0 1 O 8 0 0 CPS 51 39 1 0 0 4 0 0 I 68 0 0 CPS 51 39 2 0 0 4 0 0 1 68 0 0 CPS 51 39 3 0 0 4 0 0 1 68 0 0 CPS 51 139 1 0 0 4 0 0 1 ~8 0 0 CPS 51 39 2 0 0 4 0 0 1 08 0 0 CPS 51 39 3 0 0 4 0 0 1 68 0 0 GAP1 51 31 32 0 0 4 0 0 1 O8 0 0 US 51 41 1 0 0 4 0 0 I 68 0 0 C / C b 1 42 i 0 0 4 0 0 1 68 0 0 CO 51 40 1 0 0 zi 0 0 1 68 0 0 CPS 51 39 i 0 0 4 0 0 I 08 0 0 CPS 51 39 2 0 0 ~ 0 0 1 OB 0 0 CPS 51 39 3 0 0 ,4 0 0 I 08 0 0 CPS 51 39 1, 0 0 4 0 0 1 ~8 0 0 CPS 51 .{9 2 0 0 4 0 0 I e~B 0 0 CPS 51 39 3 0 0 4 0 0 1 68 0 0 DEPTH 12520.000 12500.000 12400.000 12300.000 12200.000 12100.000 2000.0O0 11900.000 11800.000 M N k; M O N I C N1TD F2T[) TRAT N3TD N1TD ~2TD TRAT GR NiTD ~2TD 'I'RAT N3TD 614 N 1 TD ~" 2TD T ia, A T N 3TD GR N1TD .~ 2TD TRA T N 3 T D N1TD N3TD N1TD ~2TD ~RAT N3ffD GR Nll'D !' 2 T D 'I'H A 'I N 3 TD N 1 'rD ? 2TD TRAT N lTD V'ALUB 80.700 1507.507 lb9.!59 4.005 032,533 10.500 1.:373.373 140.i40 4.605 598.599 42.000 1253,253 2110,210 3.385 0,30,637 20.200 1623.624 238.238 2.735 520,621 50.500 2608.608 252.252 3.860 750.757 21.300 1917.918 280.280 2.940 712.713 19.100 1809.810 241.241 2.945 716.717 23.500 1855.856 2o9.269 2.880 730.731 Se.100 2024.~25 24~.240 4.615 772.773 MNkMUNIC TAU N 2 T D [' 3TD SiGM ~'ITD TAU N2TD ~ 3TD SI, GM 17 lTD TAU' ~3TD ~'ITD 'tAU N2TD ~3TD S1G~ P1TD ':t A U N2TD ~ 3TD ~ITD ~AU N2TD ~3TD SIGM ~ITD '1' A U N2TD ~ 3TD 5IGM ~ITD 1AIj N2TD F3TD ~iGM ~iTD IAU N2TD ~3TD SiGM ~lTD V Ab Ijl~; 87.673 1059.059 84,084 47.725 210.210 90.692 958.959 78.078 46.525 1,82.182 185.535 956.957 '79.079 23,4'25 286.286 296.226 1119.119 75.075 15.525 358.358 134.465 1 e '75.67'6 84. 084 .]4.500 414.414 239.8'74 1327.327 82.082 19.1.00 366.305 256.226 1257.2~7 79.079 18.150 377.377 240.415 1293.293 89.089 18.875 370.370 124.403 1701.702 98.098 ]0.200 382.382 N3TD 1'~ 1 Tu ~, 2TV TRA'I' N3TD N1TD ~2TO N lid ~2TD N3TD ~ 2TD NITD ~2ID ~HAI NI~D I'RAi N.]TD G~ N1TU ~2TD I'RAI N1TD i' k A 1 VALUm 4.325 672.073 87.500 1249.249 146.146 4.420 596.597 76.100 1183.183 138.138 3,490 616,bl, 7 44.900 1353,353 198.198 2.020 6.38.539 23.700 i65,3.654 237.237 3.900 708.709 50.~00 2784.785 250.200 2.965 084.085 19.000 i933.934 271.271 2.960 708.109 25.000 1.893.89~ 238.238 3.015 740.741 20.000 1807.868 25~.256 4,815 700.701 59.900 2078.078 239.239 MNt~MUN LC 51GM fflTD TAU N2TD ~3TD SI, GM ~ 1 T D T AU S iGM F1 'rD :tAU N2TO ~'3TO &IGM F1TD TAU N2TD 61GM ~ITD TAU N 2 T D 8IGM 1. N 2TD 1~' 3Tm FI'FO 1AU N2TU F3TO 5IGM ~ITD N2TU 15 f'l TO "t A U N21, O f 3'1'O vAbUE 50.325 220.220 92.453 910.911 48 .t~15 201.2O 1 95 75 '17.077 24.8!5 258,208 196.604 1023.023 14.0;4 15,115 347.347 292.201 1139.139 81.0~7 33,325 385.38O 130.189 i811,812 230.855 1317.317 ~'i.081 11.100 249.937 1310.315 1~.325 35b,35o 12U7.287 35.900 398.39~ 12.3.648 1725.720 luO.lOO D L P :1' }t I1700.000 11~00,000 11594.500 G~ N1TD ~2TD IRAT N1TD ~2TD N3TD NiTD P2TO TRAT N3TD VALU 86. 2706. 202, 5, 7'14. 147, 2e8o. 24!. 4. 818. 147. 2080. 241. 4. 818. 100 7 O7 202 315 775 700 681 241 940 819 700 681 241 940 819 MN ~?~Oa lC TAti a2TD ~3TD S!Gig P1TD I'AU a2TD P3TD SI, Ga ~'ITD TAU N2TD SIGM P1TD VAbUE 110.063 1755.756 106.106 38.225 307.307 11. 4.088 1763.704 127.127 38.575 369,309 114,088 176,3.704 1,27,127 38,575 369,369 IR A'I m 3 T O GR l" 2TD i~ 3TO G~. a 1 TO ~' 2T'D I~RAT GR m 1. TO ~2TD VALU~ 5.045 840.841 83.900 2452.452 185.185 4.955 796.797 I42,500 272b.'127 249.249 4.955 79~.'797 142.500 272~.127 249,249 S ,1 GM ~'1 TO S,IG~ iAU m2TD F3TO SI, GM ~'ITD 'tAU N2TD F3TO VAbU~S 40.225 323.323 110,352 1~01.601 I09.10~ 39.200 340.34~ 115,591 1739.'740 130,130 39,200 34~,340 1,15.59'1 1739.740 130,130 :tt . 11 11:11 1111 11 It 11 11 I 1 11 11 11 !,1i111 !11111 -, 000000 000000 00 O0 00 00 00 0000 O0 0000 00 0 o 00 O0 O0 O0 0000 O0 0000 O0 00 00 00 O0 000000 0 00 000 :77777'77777 7777771777 77 77 '77 77 77 77 "77 77 '77 '? 7 000000 000000 O0 O0 00 00 00 0000 O0 0000 00 00 00 00 00 00 0000 O0 0000 O0 O0 O0 00 017) 00000 Il) 000000 " '77;77777777 7777777777 77 77 77 77 77 77 77 ? ? 77 77 77 '7 ? 000000 000000 0 U 00 OO O0 00 0000 O0 0000 0 O 00 00 00 0 000 0000 O0 0000 O0 O0 O0 0 0 O0 000()00 000000 7777'777777 5555555555 7777'777777 5555555555 '77 55 77 55 77 555555 77 555555 77 55 7'1 55 ?7 55 77 55 77 55 55 77 55 55 77 555555 77 555555 5555555555 5555555555 55 55 555555 555555 55 55 55 55 55 55 55 55 555555 555555 P h P [ 1 (} 7 07, ~ ,3 '755 ] J LJ I~ [10'707.b07551 jU¢ SHIP SHiP O EEEE 0 ~ q90 DA'fi:. 2q-'aEP-80 14:5t:19 14:53:19 I: I I I II I t I1 !i 1I II i ! I I i :[ I. 1 1 I ii ti :l I: PP PP PP PP 14:5]:19 1.4:14 t? C C C II1ill iI1]iI ii ii II II lI 11 iI i1 iIilIi iIIIII Y ¥ 996 i),AIL 2g-SEP-80 2q-StP-80 14:51:$3 14:5]:19 ,.SCHLOM~ERGED CO?4PUTINIG CENTER 10707,60755 TAPE DATE: 80/ 9/29 'JAPE ~EPVICE NANk: ~.;PtT TAPE CON'I'Ii'JlJA'[1OI'~ NUMBER: O1 DATE: 80/ 9/29 k f) l 0 2 t 'I~ Y?E 0 i 66 0 ,I C T ~,l U b P' T 0 0 0 0 0 ~ 0 0 I o 8 0 0 G ~ P l 51 31 32 0 0 4 0 0 1 68 0 0 G A P I 5 1 3 1 ,3 2 0 0 4 0 0 I 6 8 0 0 C t,.i 5 1 4 0 1 0 0 4 0 0 I o ~ 0 0 C 0 5 1 4 0 2 0 0 4 0 0 1 6 8 0 0 CPS bl ,]9 99 0 0 4 0 0 1, 68 0 0 CPS 51 39 99 0 0 4 0 0 I 68 0 0 C P S 5 1 ] 9 9 9 0 0 ,ti 0 0 1 o 8 0 0 C P $ 5 1 3 9 9 9 0 0 4 0 0 1 t~ 8 0 0 C/C 51 42 0 0 0 4 0 0 I, 68 0 0 51. 4 ~ 0 0 0 4 0 0 I ~8 0 0 11255P. 000 I. 2 500.00 c) 1..2 300. 000 200. 12 1()o. oo0 12 0 o 0.000 1, 1 9(30. 1! 8':iO.O00 I 1 l 1 6VO.O()O 550.000 GR 'i~ f~/% G~ TNb~ 'I'k A 1' G2 T ~ B h Ti~AT 'i' h t:~ i<, 'l k A '!' G~ I' t-: A 'I V ~L - 999.000 -999. 000 - g 99.000 ~ 4. 050 80.355 3.798 35. 700 1. 49.46 ] 2.97~5 1 ~. 25O 131.217 2. ::'t ~ 7 49.900 170.082 2. 897 I 8. 450 190. 702 2,. ] 86 18.050 210.44 '7 1.927 :25..4 0 0 2:23.069 2.925 52.95o 253.002 it.b74 85.050 :2 b 8.30 a 4.495 166. 250 277.9~0 4.949 -999.25U -999.250 -999.250 bi it M O N T M 0 D G R B U TFBK 1 'I'q U D 'I M (~ D GP, BU T l'a 0 [,) 'I"t~ 'I M (J 0 I'F bK T M O [) G R .6 U 'l ?'4 0 D G R tJ [1 't lq (J i) GRBIJ 7' ~4 (J D G~BU TF [~K Gkb~J 1 F'itJ D lC -999. 000 -999. 000 -999. 000 0. ] 75 180.250 (). 366 0 . ] 75 174.000 0.591 0. 174.450 O. ]20 O..~ '75 It:,2. 550 0.474 O. 3'15 74.550 0.432 [).~'75 1,~b.850 0.499 0. ~ 75 107.600 (). 504 o. 375 17(3. 250 0.547 0. ~, 75 '?0. 150 0,771 o. ]75 167. 650 O.ql2 -g99.250 -99q.250 -9~9.250 M,N b M I:] N 1 C 51 G t~ :'t N G SIGF! 8 [ G M 1: N G 'I N G T NG 51 G ~ 'I'N G 81 G 8 iGM TNG 1 i'd G TNG v ALUE -999.000 -999.000 q9. '762 87 7.1,53 19.994 86'7,915 14.901 885.144 30.901 786.207 16.998 878.901 15.140 886.1. t2 18.0'1'1 832,959 30.b4b 807.2~I 37. 79b.255 792.260 -999.750 -999.250 F'8IG T F G F$IG TFG F$I,G TFG F8 t G Fa iG TFG F$1G TF'G [,SIG I'FG [':':8 IG TFG FSIG TFG F,S I.G rFg t.'S 1G VALU~ -999.00() -999.000 43.9'70 280.,160 !b.862 .~12.765 11.408 358.35~ 29.180 312.705 14.240 :t58.481 12.067 358.481 14.764 358.48:1 21.591 312.765 39.759 312.765 37.01'! 312.765 -1000.250 -999.250 1024 : ¥: gTL/~;q51C I, ICHi;'ILLD Ct.~. g-It> DA.'I/~ FOHMAI 5PLCiFiCA'TiO~k.' 0 [)~TU!V~ SPEC.I.F I. CAi~.Ii;i.' ~'d bLLiC!58. ,1 UN[T,S APl API A['I APL fILE F ]; 0 O 0 0 G A P 1 5 1 .3 1 3 2 0 GAP t 5 1 3 1 ;:~ 2 O C U 51 40 1 0 CU 51 40 2 0 CPS 51 7t9 99 0 C PS 51 39 99 0 CPS 51 39 99 0 CtC 51 42 0 0 51, 4 ,], 0 0 G A P .[ 5 1 31 3 2 0 GAP1 51 31 32 0 CU 5 1 40 I 0 Ca 51 40 2 0 CPS 51 39 9 :~ 0 CPl5 51 39 99 0 CPS 51 ~9 99 0 CPS 51 39 99 0 C/C 51 42 0 0 5 1 4 3 0 0 # ~ 1Z5 EX 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 q 0 4 0 0 1 e>8 0 0 0 1 68 0 0 0 I 08 0 0 0 1 68 0 0 0 1 b8 0 0 0 1 t~8 0 0 0 1 e, 8 0 0 0 I 68 0 0 0 I ~8 0 0 0 I b 8 0 0 0 i e~ 8 0 0 0 1 1~ 8 0 0 0 I 68 0 0 0 1 6 8 0 0 0 i t>8 0 0 0 I 68 0 0 0 1 68 0 0 0 1 ~8 0 0 0 I t>8 0 0 0 I ~8 0 0 0 1 68 0 f) L [" 'I H 12555 , 000 12 ,:500 o () 00 l 2 400.000 1.2 ]00. 000 12200. ()00 12100.000 l 2oeo. 0o0 1 I l 1830. OOt; 'iRA T &IGM T N G G~ T }~ A 'Ii T,NG T h G GR 1' 14A T T N "' Gl-: T N B K Tl-:AT ~I N G G R '1 ,}~ A T ,S i G M G~ 'Ik A 1 S 'IN (; Si G~ 1 R A 1 5I Gi,i I N G 0. 000 -0.125 e. 000 -999. 000 99.000 70.9o0 199.0"7 ~ 3.604 48 88i, .1.49 37.050 237.316 2.591 19. 290 877.15 ] 22 .bS0 2 ,] 0. O 07 2.2'77 14.931 874.157 5O. 150 259.5b0 2.83o J t. ~ 20 802.247 le.900 2el.OhO 2.407 17.118 8e2.172 22.950 287.553 1.975 15.200 ~2.10~ 291.552 2.9e5 19.845 ~2e.714 bU. 70O 310.291 3.3~4 31 .515 1 ~ 7.01 b T M [3 D F$I.G GBBU TI-'BK T M I J i.) fSIG '[ H {] D IbibD ~S1G [, ;SiG i MIJ D i'SIG 'tFG G}~btJ PSIG If G GFbtJ :I b'! b I} TFG V A L !j g 0.375 -O.t00 0.0O2 -999.000 -999,000 70.412 179.450 0.482 45.394 286.285 38.202 178.050 0.661 17.O57 344.617 23.471 1'71.250 0.490 12.382 35u.481 50.4]7 154.850 0.591 28.191 ]12.705 16.979 I 73. @50 0.538 13.925 358.481 23.221 166.600 0.580 12.bOb 35~.~5~ 22.4'72 106.250 n.594 15.753 60. 050 i e~. 850 0.710 28. ,'~91 312.765 ~ t'~ g M t:J !"41 C TNG GR, TNBK I RA'I' I'NG G~ TNBK blGM TNG 'i'RAT 81G~ 'IRA'I' TN~t~ lb.A'I TNG G~ 1NB~ IRAI TNG iRA'I 'i' N G GR T R A 1 '1 NG '1 NHK V A L U k, 59.~55 0.749 -999.000 -999.000 -999.000 49.68 '1 87,t.157 67.300 273. 932 3.15,3 :1.9,904 879,151 45,200 31.1.547 2,931 1~.490 885.893 21.200 297.551 2.220 32.219 702.297 56.050 .327.293 2,902 lo.893 858.677 23,050 5]24.294 2.235 874.407 25.400 323.0~}4 2.047 18.916 837.953 30.bO0 333.542 2.200 31.515 792.010 o~.20u 344.414 3,450 gNLMOmlC FSiG TFG GRBU FSIG TFG GRBU T M [) D TFG GRb U T M 0 D F$ [G TFG GRBU 'i MUD FSIG TFG GR6U TFBK fMOD FSIG I'FG GRBU T~BK TMUD FSIG TFG GNBU rMUD ~SIG IM. UO fFG GRBO 58.955 0.375 -999.000 -999.000 -999.000 46.308 2~0.285 181,350 18.~15 31b.263 49.189 174.b00 0.793 11.701 358.48 1 23.970 172.550 0.631 30.064 :312.765 56.b79 163.050 0.701 13.580 358.481 23.221 17~.450 0.052 12 358.481 25.968 I 14.v50 0.714 1~.083 368.481 30.9bl 151. 250 0.091 z7.54o 312.7~5 67.b~5 1.68.450 0.779 f} k t~~ T ~:! 700.000 1 I 600.000 ! 1 81 G a 81 (; H 'I N G GR I' ~ G 93 323 4 3'/ '77 3 U L .544 .684 .711 !59.250 J29.043 '~. 689 38.152 776.03O -99 -99 -99 -99 -99 9.250 9.250 q. 250 9.750 9.25O G.R B ~ [ I:FG G R B U TFBK TFBK T~G VALIJE 91.885 170. 150 0.7 77 3 ?. 676 51 '2. 765 158. ~02 172.050 3 7. g 31 711, 2.765 -999. 250 -999.250 -999.250 -1000.250 -999.250 61 G N T .a G T iq B ~ 'r R A T 'ING I' N .B K SIGN ;lNG V A b O i~2 798.252 9i.550 307.283 4.748 37.073 797.253 161.250 3 e, 3.534 2.1,75 -999.150 -999.250 -999.250 -999.250 -999.250 al~gaO.a lC FSIG Tf'G GRBU ~SIG GRBO TM(ID TFG GRBO TFBK T P.iiJD V A L U ,g 39.100 312.'?e5 93.508 100.050 0.929 37.272 312.890 159.675 157.050 1.354 -1000.250 -999.250 -999.250 -999.250 -999.250 L E h.i G'I: H U ~' L A $ '1 '.iq. kC (JiS:< i.>: ,594. 1024 :, I 024 6 6 F T o 0 0 0 0 q 0 0 1 68 0 0 G ~ P l 51 .~ 1 32 0 0 4 0 0 1 ~ 8 0 0 g A ~;~ I 51 31 :~ 2 0 0 ~ 0 0 i 68 0 0 C U 51 40 1 0 0 4 0 0 I ~ 8 0 0 C t'.i 51 40 2 0 0 ,~ 0 0 1 68 0 0 CPS 51 39 99 0 0 4 0 0 I 68 0 0 CP~i 51 39 9q 0 0 4 0 0 1 b~ 0 0 C P S 51, 39 99 0 0 4 0 0 I ~ 8 0 0 C P f5 51 39 9 9 0 0 4 0 0 I ~ a 0 0 C/C 51 42 0 0 0 4 0 0 I b8 0 0 51 4 ] 0 0 0 q 0 0 1 b 8 0 0 G A P I 51 ~ 1. 32 0 0 ~ 0 0 1 68 0 0 GAPI 51 ~1 ~2 0 0 4 0 0 I 68 0 0 C U 51 ,~ 0 l 0 0 ~ 0 0 1 68 0 0 C Li 51 40 2 0 0 4 0 0 1 68 0 0 CPS 51 39 99 0 0 4 0 0 1 68 0 0 CPS 51 ~9 99 0 0 4 0 0 I O~ 0 0 CPS 51 ~9 99 0 0 4 0 0 1 68 0 0 CPS 51 39 99 0 0 ~ 0 0 I 68 0 0 C / C 51 42 0 0 0 4 0 0 1 ~ 8 0 0 51 43 0 0 0 4 0 0 1 b8 0 0 1 12 400,000 12 ~00.0()0 12 200. 000 12 I 00.000 20O0. 000 1 1900. 000 I 1 8U(). r>O(J S I G t4 TNG S I G 1'4 T t~tG GI~ TNBb, SIGH G I< 'T'jR A 81. (7; '_r aG Gl;' 'IleAl' £ P, A T V ~. L U b -0. 150 - 0.375 6,005 59,455 0,999 69. 750 281.555 3.6 ] 8 50.45t 877.1, 5 ti 44.050 312.922 2.041 21, .552 a67.915 25.000 295.551 2,277 15.021 890.637 e0.350 t 08.6 '7,3 2.937 30. 287 ,909.238 29. 500 314.921 2.395 16.77¢ 9O J. 87O 7OO .O 't3 900 I 07 33.600 if)fa . 42 i 2.731 19. 050 34.2 ()7 ~8.150 32~.29~ 3.1o4 32.114 34,7 o ? O R B U T Fi (J O FSI, G TF'G GRBU 1: H O D f,$IG I'FBK [,SIG 't F"BK [" ,51 G 1~? BK fSiG FS1G TPG t~SIG 1'FO [,'big 't?'G V ALtlE 0 . .~,75 - 0.30 0 O .002 58.955 {). 3'75 '70.412 180.450 0.658 55.838 286.285 40. 567 176.800 0.731. 19. ~50 312.765 20.966 l 73. 650 0.599 1. 1.. 797 358.q81 60.799 165.600 0.73,4 28.386 312.765 29.213 172.250 15.139 358.481 22.472 1'74.450 0.782 tt.l. 61 358.481 31.r~86 165.450 0.606 14.839 358.481 ~)7.41~ 174.100 1.057 27.966 1112.765 mlG~ TEA1 TNG G~ TNB~ S 1 G ~ TNG GR 'I~NBK TRA~i blGN TNG GR S,IGN :I'NG GH TRAT IRAI GR TNHK 6IG~q TNG T RA I IPA'I VALUE 59.455 0.7%9 -0.100 -0.250 e.004 .49.253 873.158 78.100 296.926 5.803 20.084 878.652 50.200 351.531 2.257 15.215 883.1,46 31.000 310.547 1.900 800.991 6'7.80() 320.045 2.880 17.193 803.171 29.550 313.047 2.236 15.o80 900.125 26.450 322.q19 2.080 20. 803 853.932 33.250 321.045 2.707 31.200 828.7i.~ bS.lO0 314.921 3.299 t~'~ N I:: H O N 1 C Tf'G GRBU TNOD F6IG TFB~ TFG GRBU TFBK fSlG TFG GRBU "FHOD F$1G Tf'G f'SlG I'~G TFBK THOD F'S I.G i'FG t' b, lUO F81G TFG GP, BU 'i't' i:SK FSIG 'rF G GkbU '¥ H () D VALUE. 58.940 0.3'75 0.375 -0.200 0.002 ~4.030 266.i60 '78.152 1,18.950 0.858 16.2'78 313.015 51.001 173.350 1.011. 12.397 358.481 30.961 1'12.550 0.678 29.779 312.7~5 61.915 162.150 0.834 13.o25 358.481 31.336 181.750 0.o10 11.797 358.481 20.407 118.450 0.773 15.558 .358.481 ~3.708 104.250 0.646 2'1.846 312.165 b4.6~9 174.150 0.718 1 t 700 . 000 600. OOO 11 550.000 T N L~, K 61, Gg T N G TNBt< SIGH TR. AT 5 TNG VAL 7 174 ]1.5 38 12 2 59 0 .000 .170 .304 .687 . .250 .546 .764 .092 .950 .150 .044 .745 .440 .999 T ?'.B F, i~$IG GR6U TI~BK GRBU I'~'G 91.0O4 167.600 I .742 ..~5. 698 ]12.765 17 ]. 9O8 175.750 1. 40.958 31 2.765 72.409 164.250 2.0bO 58.955 0.~75 MN i~ MIl N lC 'I~NG TRA~: 'lNG INBK i' R A VALU 38. 83 ,]. 98. 323. 4. 834. 166. 333. .~, 7. 8,~8 . O. O. 6. 481 2O8 450 544 ? 49 7 4 7 7 0 7 95O 72 ~ 028 202 000 000 000 MNEMONIC TFG GRBU TM{ID GRBU T M O D FS I.G T F G GRBO TFBK TMOD V AL UP_; 31.338 312.705 95.880 1'13.250 0.925 38.650 312.7'05 i65. 793 1 1/4.850 0.995 29.989 312.765 0.499 0.000 0.002 , SEi~'VtC~.: NAME: TAPE CONIiN~JAI'I. tSN NOM~Ek: O1 1024 B~TES 9/29 11 il 1111 11 11 11 II Ii 1! 111111 bb 66 b6 bb 6b bb b~ 000000 000000 00 ()0 O0 O0 O0 0000 00 0000 O0 O0 O0 O0 O0 O0 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 il 11 llrll 1111 11 11 11 1! 11 11 11 11 111111 111111 1'777777 117 7'? 77'177777 77 77 77 '77 I 7 '/7 7'1 77 77 17 77 000000 000000 00 00 00 00 O0 0000 00 0000 O0 O0 O0 00 00 00 0 000 ,00 0000 OO 00 O0 0 0 0 0 000000 O00nO0 000000 000000 O0 O0 O0 O0 O0 0000 O0 0000 00 00 00 00 00 00 0000 O0 0000 O0 O0 O0 O0 O0 000000 000000 obb~bb bbb~bb bb b~ bboOb~bb bbbbbbbb bo 6b ~b 66 Ob 6b bb bb ~66666 777717 1177 ?'177 177777 77 77 ? 7 77 '? 7 7 '7 77 71 7 '? 11 11 1111 1111 11 11 11 11 11 11 11 11 111111 111111 0 GGGG h ~ G H H G H H G GGG H H G G H H (;GG M H ~ B P R F, ~ P U U D I.) I') O U U D L) ti b I) D U Ij D D U U O D U U D tJ UL. ItJI. J U DI'ti)D '~ S I" A k :1' * MUNI'I:(JR * b 'r A R I', L!S ki~ f;CAL [1070?,blObl] 5v.;5 KLI. 0E.IO Sk[-'-80. *SIAK'Y* USKR FCAb [107UT,blOul.t 6wS ~Llo?40 ,SLP-,,,jO. *5'i'APF* 5HiP SEQ. 1778 i)/4'rP-, ,~O-UCT-,80 1 7: 09: I 1 DA'tr,, 17:09:11 1I I1 1i I1 i [ t I I il I t t I 11 1I II ii ii I i I I ii i1 I I I, [ llll PPPPPPPP PPPPPPPP PP PP PP PP PP PP P P P P PPPPPPPP P P P P P P P P PP PP PP PP PP $81'AR'/* USER PCAL [107o7,e, 10e~l] dot-5 SHIP t4ONITf)P ~S KLIO~.~O 8EP-80. FILL: DSF:HIfi~IP.i'Li<2~5>[IO7~)7 010613 CHEATED: PRIN1LD: '{0-t.)C~'-80 1~:09:~1 (~LJEUF, S~iq. CHE5: tflhk:ft.]~T /C(.iPIES:I ,SEW, !'778 [)ATt-. ]O-LiC'F-80 30-OCT-80 14;5J:24 17:09:11 ,5}~ 1PP [ i'qG INST}~0CT II)~S I S S tJ i~:; D 3 0 '- ~J C T - 8 0 1 4: 5 3 Si,tiP V Et~'I'[iR h, CALI? OIqi'~ i h PCCC 8 ~t GHB PCCC 11111I 1iiiii II II I 1 1 I 1I I1 I I 1I, I1 I;11II1 II, i11I ~Y :~Y YY 0000~)0 000000 222222 000000 000000 222222 O0 O0 O0 O0 :22 22 O0 O0 O0 O0 22 22 00 0000 O0 0000 22 O0 0000 O0 0000 22 O0 O0 O0 O0 O0 O0 22 0 O 00 00 00 00 00 22 0000 O0 0000 O0 22 0000 O 0 0000 00 2 '2 O0 O0 O0 uo 22 00 O0 ()0 00 22 000000 00000c~ 2222222222 O000oO 00000() 2222222222 *S?API* USE~ PCAL [.l. 070'?~blOblJ dub SHIP Shg. MONIqOt4 ,bv:S ~,L10~40 SL['-80. *START* ~ILE: DSh~:VE~I~Y.OO2<OS/>[IO/OT,oIOol] CREATED: PF1NIED: ~0-[.)C1'-80:17109155 C~ULU[, SWJq'CHES: /k-ll,L:F(.ikT /CDPI, E8:I /6PACING:I /I, INI[:109 /~(JgP, S:HOH?~AL 1778 DA'rE 30-uC't-80 ]o-UCT-80 17:u1:2:3 17:09:11 I, IS VEPSi[}N 15..HO1 19!03/26 10707,61061 REEl,, t~ANE: PREV10Ii~ Hgg[., NAME: CO~M~NTfi: LIS F'ORMA"[ CUSTOMg~ TAPE 80110/30 TAPE NA~E; 010~1 DATE: 80/10/30 SgRV 1CE ~AME: LDI~ TAPE CUN'i'INUATION NI.IN~k,R: t)l PREVIU[)S '['APE NAP~E; CQHHkN"L~: UNI(~tjE WELl,., IDgNT].PICAiI. ON NU~,IB~R iS 50-029-2025'7 ~ I.I.JF, HLAURH WkLI,, : D.S. 9-10 [~ I k__ .[, iJ : k:' I.~' f.J O H 19 i:, TUi~NSH I P : 10i'J SEc'ri(iN : 3 STAFF., : ALASKA DLHS[T¥ : ~00. 'I YP~: 0 SIZE 1 I~EP CUDE bi A M E l i.~ El IL~ UNif' APi AP1 APl API EILE. SIZE SA~ R~{F FkUCE~8 1, NDICAtURS F T 0 0 0 0 0 4 G A P I 4 2 3 1 3 2 0 0 4 P U q 2 b 8 3 0 0 4 C/C 42 42 1 O 0 4 CPS 42 ;~4 92 0 0 4 CPS 42 .~41 9,,~ 0 0 4 G A P 1 't 2 ;~t 1 32 0 0 4 P O 42 68 .~ 0 0 4 C/C 42 42 1 0 0 4 C P $ 42 3 ,~ 92 0 0 4 C P 8 42 ~ 4 93 0 0 4 GAPI 42 31 32 0 0 q P U 42 6 8 3 0 0 4 C/C 42 42 I 0 0 4 1 68 1 08 1, 08 1 b8 1. b8 USEtE DE;I~IN[~/D UU'IPUT AI:~RA¥ 12555.000 !~500.000 12400 . 000 I 2:~,O0. O00 12200 . 000 12100. O 00 120 O 0 o 000 I 1 .. O0 I I 800.000 1700.000 116UO. 000 t !'40 N I C FCNL NC N b N R A 'I' f'CNL NCNL NR^T GR F NC Nh NRAT G t"CNL N C N 1., NRAT NC Nb NI'~A T GR NCNb GR NCNb NPAI f'CNL N C iu L GR FCNi: N P A T G k ~CNb N C N L NP, Ar f C ~ b V A 1., U L 200.1 O0 999,141 -999. 000 2.1.95 9O0 897 700 740 38.400 b q. 35 o 166.q52 3. 051 21.000 152.724 ]07.224 3.012 49.900 111.111 293.007 15.800 109.824 298,584 3.08O 17.2O0 16].878 31'1.949 ] .080 21.OOU 1.08.392 294.72] 2.912 62.500 109. 824 290.0{)4 ,~.02! 89. e,O~) b~.495 23e,.379 g.410 128.at)0 53.196 199.914 4.102 ~NEN(]NiC NP~I fCNL N P ti ,[ 17 CNL NPH I i~'C NL NPH I ['CNL N P H I G~ l, CNL N P H 1 GR [~ CNL .NPH 1 G~ I. C N b N PHI F CNL i''~ P }i I G R r CNI~ m P H I [' CNL VAI.~IiE 20. O 20 -999.000 -999.000 31.1 '~ 0 72.40O :~ ~. 610 21.140 40.200 bi .776 16.640 18.800 '1.6!.~04 lg.2~{) 51.700 '96.95 q 20.8o0 lO.500 1 O2.1. O2 13.140 14. 10 ]°8?8 22.5b0 22.800 104.676 2 ,t. 020 61..] 00 124.410 ~2.540 87.000 60.918 45.1~0 13 '1. ¢) 00 51.051 N RAI {'4PHI NPH i NRAT NPHI NPH 1 N R A T NPHJL N 14 A 1 N P H 1 GA i~RAI r,~PH i /'iRA 1 NPH 1 GR ~,~ P H i VAbUE 2.]00 -999.000 51.1,88 ].228 31.940 07.50] 2.540 22.320 36.781 2.690 18.38O 23.594 2.528 2 ,]. 000 47. 594 2.574 22.e2o 15.594 2.090 13. 300 16,391 2.070 22.7~0 21.984 2.830 25.720 51.5'94 3.95,4 41.420 80.75o 4.0'18 41 .e, 8o 120. 750 NCNb NHAI' NPHI NCNb N RAT NPH 1 m C N L r~ R A ,r NPHi NCNb N 1~ A i' NC N b N iR. A 'I NPH 1 i'~ C tN b N R A 'I" NCNb NRAT NPN.I l,lC Nb NRAT NPHI ,NC Nb i~ R A '1.' NPHI NCNb NRAI NPHI NCNb i~ R A i NPHI 'VAbUE 999.141 -999°OOO 15.2J4 !30.41o 3.244 3b.512 17 ]. 145 2. 724, 25.732 366.795 2.524 24.756 279. '708 :2.176 21.191 29o.010 2.b62 2b.318 379.0~5 2.150 20.660 297.726 2.058 24.1 '?0 201.690 2,884 26,074 242..~5 3.892 4b.996 2il.92~ 3.860 42.432 S i,,I Pi H A .k :~ ~ E 1) A :i~ A :R E C t] ~:-~ b $ !024 BYTt~$ TAPE it4AILE.R I,ENGTH: 112. BYTE5 'rAPE ~N A~,L: 610t~l VALE: 80/I0/$0 T~F'E CL~N'II!'~dATiON NO~,i~L~: Ol C(]~MLN'I'~: 'UNIQtJL ?~g!,,b IDENriF1CATiOr,i NUMBLB IS 50-029-20257 DEPTH 115O0.0O0 1495.000 G N C' N L qALUE I g g. 000 51. 909 205. 062 -q99. 250 0.000 0.858 283.998 -999.25O G~ NPH1 [~C Nb VALUE ] 9.380 144. 500 5 ~ °625 -0. 020 148. 172.458 ~ P~ I NPHI VALUE ~.~20 40.5~0 -999.250 1.834 20.340 -999.250 NCNb 205.062 NRA<I' 3.~3~ NPHi -99925.000 NCNb 2.574 NRAT 3.8~4 NPHX -99925.000 COPPAaY CUUNT~ D~PTH FEET EFF POR % ¥OL 6H OH CH % % % PERM---- ....... INTEGRATIONS ......... PHI-E BVUH BVCH PERM. MD P-FT }t-FT H-~"T MD-~'T 11622.0 17. 49. 58. 11637.0 16. 49. 68. 53. 11638,0 16. 50. 69. 5]° 11729.0 i1730o0 11731-0 11732.0 1173]o0 11734.0 11735.0 i1736.0 11737.0 11738-0 11739.0 11740.0 11741.0 11742.0 11743.0 11744.0 11745!.0 11746.0 11747.0 11749'0 11750,0 11751.0 11752.0 11753.0 11754.0 11755,.0 11761.0 1'1764.0 11773.0 11774.0 11775.0 11785.0 11786°0 11787.0 I178~.0 1. O. O. O. O. O. ~I. 100. lO0. 39. 100. i00. ]8. 98. 97, 36. I00. lO0. 38. lO0. i00. 40. 100. 100. 42. 100. 100. 40. 100. I00. 41. 100. 100. 42. I00. 100. 3]. 100. 100. 28. lO0. lO0. 29. 100. 100. 24. 100. i00. 26, 100, 100. 32. 100. 100. 39. 100. 100. 38. 65, i00. 42. 19. 97. 40, 50. 3i. 100. 100. 30. i00. i00. 39. 100, 100. ~6. I00. I00. 44. 100. 100. 46, 100. 100. 48. 63. 100. 6. 42. 36. 100. 5, 43. 32. 100. 4. 49. 50. 100. 9. 47. 49. 5]. 12. 30. 54, '?~. 10. 26, 82, i00. 5. 35. 100. 100. 11'794.0 11. 44. 58. 99. 10. 124.3 92.0 92.0 2~00b. 122.8 91.7 91.7 2879~H. i22,7 91.7 91.7 2879~b. O, 120,1 91,2 91.2 287914, O, 120,1 91,2 91,2 28'?91i, O, 120,1 91,2 91,2 28~7914. O, 120,1 91,2 91,2 28791~. O, 120,I 91,2 91,2 287914, O, i20,1 91,2 91,2 287914. O, 120,1 91,2 91,2 287914, O. 120,1 91,2 91.2 287914, O, 120,1 91,2 91,2 28Y913. O, 120,1 91,2 91,2 287913. O. 120,1 91,2 91.2 287913. O, 120,1 91.2 91.2 2H7913, O, 120,1 91.2 91~2 287913, O, 120,1 91,2 91,2 2a7913. O, 120,1 91,2 91,2 287913. O. 120.1 91,2 91.2 287913. O, i20,1 91.2 91.2 28791.~. O, 120,0 91.2 91,2 2~791~. 0, 120.0 91,2 91.2 287912. O, 119,9 91.1 91,1 287912. O, 119.9 91,1 91,1 287912. O, 119,9 91,1 91,1 287912, O, 119,9 91,1 91,1 2~7911. O, 119.9 91.1 91,1 287911, O, 119,9 91,1 91,1 2a7911. O, 119,9 91,1 91,1 287911. O, 119.8 91.1 91.1 287911. O, 119,7 91.1 91.1 287910. O. 119.5 91.1 91.1 2B7909. O. 119.5 91.0 91.0 28'7909. O, 1t9,4 91,0 91,0 287909. 1. 119,1 90.9 90.9 2~7908. 2. 1!9.0 90,8 90,8 28790~. O, 118,9 90,8 90,8 287905, O. II~.B 90,8 90.8 287904. t. 118.7 90.8 90.8 2~7904. BEET EFF POR % VOL ;BH OH CH % % % PERM ......... -INTLGRATION$ ......... PHI-E BVOH BVCH PERM. HD P'FT H-FT H-FT MD-FT 11795.0 11796.0 11~01.0 11802.0 11803.0 11804.0 11807.0 11808,0 11809°O 11810,0 11811,0 11B12.O 11813,0 11814,0 11815,0 11816.0 11817,0 11818.0 11819.0 11820,0 1i821.0 11822.0 11823,0 11824.0 11825,.0 11826.0 11827.0 1i828.0 11829.0 118]0.0 11831,0 11832.0 11833.0 11834.0 11835,0 11836,0 11837.0 11838.0 11839,0 11840.0 11891.,0 11842.0 11843.0 11844,0 11845,0 11846.0 9. 35. 85. 100. 42. 100, 100, 0 g. 11. 10. 45. 55. 100. 4]. 48. 100. 42. 41. 99. 45. 40. 100. O. 118.6 90.7 90.7 28790j. O. 118.5 90.7 90.7 287903. 1. 118.3 90.7 90.7 287902. 1, 118.2 90.7 90.7 287901. 3. 118ol 90,0 90,b 287900. 2, I18.0 90.5 90.5 287897. 12. 40. 29. 68. 7. i3. 35. 26. 52. 14. I5. 27. 21. 34. 50. 19. i5. 18. 29. 172. 19. 11, 18. 33. 190, 16. 12. 23. 45. 45. I0. i4. 39. 92. 3. 7. 19, 63. 100. O. 9. 30. 44, 100. i, 9. 39, 39. 99, 1, 9. 26, 39, 91. I. 12. 14. 26. 61. 9. 15. g. 19, 50. 59. 18. O. 17. 43. 157. 20. 8. 15. ]2. 280. 22. 8. 13. 18. 651. 25. 8. 11, 12, 1428. 27. 7. 11. 14. 2207. 25. 7. 11. 16. 1719. 23. 8. 11. lb. 1174. 24. 9, I0. 1.6. 1828, 25. 8, 10. i6. 2035. 24. 7. 10. lb. 1568. 24. 7. 9. lU. 1987. 24. 7. 9. 15, 2114, 23, 7. 9. lb. 1902, 22. 7. 8. 19, 1879, 22. b. 8. 20. 1'146, 22. 6. 8. 20. 1733, 23. b. 8, 17. 2384. 24. 6. 8. 18. 2497. 23. 8. 9. 17. 2001. 23, 10. 9. 18. 1420, 21. 11. 10. 22. 1046, 20. I2. 10. 26. 871. 19, 15, 11, 31, 439. 15. 15. 14, 51, 96, 12, 14. 17. 73. 27. 14. 15. 16. 56, 64. i7. 16. 14. 45. 154. 117,7 90,4 90.4 287892. 117,6 90,t 90,] 287884, 117,5 90.2 90.2 287863. 117.3 90.1 90.1 287788. 117.1 89.9 89,9 2875~0. i17.0 89.7 89,7 2874J]. 116.8 89,b 89.6 287402. lib,7 89,6 89.6 28740t, t16.6 89.6 89,6 287400. 116.5 89,5 89,5 28]399. 116.5 89.5 89.5 287]98. 11~.4 89.4 89.4 28739U. 116,2 89,3 89,3 287380, llb.l 89.2 89.2 287297. 115,9 89,0 89.0 28712~. 115.7 88.8 88.8 286775. t15.5 88.6 88.6 285949. i15.2 88.4 88.4 28430q. 115.0 88.2 88.2 282051. 114.7 88.0 88.0 2~0531. 114,5 87.8 87.8 279279. 114.2 87.5 8'1.5 277252. 114.0 87.3 87.3 275318. 113.7 87.1 87.1 273bo~. '113,5 86,9 86.9 271670. 113,] 8b.7 80,7 269419. 113,0 86,4 86.4 25705b. 112.8 86,2 86.2 2657b7. i12,6 86.0 86.0 2~408~. 112.4 85.8 85.8 2~2358. 112,1 85,6 85.6 259942, 111,9 85.4 ~5.4 25'7580. 111,7 85.2 85.2 255b:77. 111.4 85.0 85.0 2544{)2. 111.2 84,8 84.8 253314. ii1,0 84,6 84,0 252671. 1i0,8 84.4 84.4 252236. 110.7 84.~ 84. t 2521~Y. 110.6 84.2 84.2 252134. 110.4 84,1 84,1 252047, DEPTH FEET % VOL --SATOR-- SH OH CH % % % PERM MD .......... INTEGHATI(JN$ ......... -PHZ-E BVOH BVCJt PERM, P-FT fi-FT tt-FT ND-FT 11847.0 18. 16. 13. t5. 11848.0 20. 12. 12. 27. 11849.0 21. 10. 12. 20. 11850,0 21. 10. 12, 21. 11851.0 21. 11. 13. I1852.0 19. 13. 13. 28. 1185].0 19. t0. 13. 11854.0 21. 8, 12. 22. 11855.0 22. 6. 12. 20. 11856.0 23. b. 12. 20. 11857.0 23. 6. 11. 20. 11858.0 23. 6. 11. 22. 11859,0 22, ?. 11, llSbO.O 21. 7. 11. 28. 11861.0 21. 8. 10, 11802.0 23. 7. 9. 20. llSb].O 22, 7. I0, 22. 11864.0 18. 8. 11. 33. 11865.0 1t. 10. 16. 66. 11806.0 7. 10. 24. i00. 1i867.0 13. 8. 16. 11868.0 1'7. 7. 14, 42. I1869.0 !6. 7. 16. 40. 11870.0 18. 8. 16. 11871.0 18. 13. 17. 34. I1872.0 17. 19, 18. 41. 11873.0 16. I7. 19. 52. 11874.9 15. 13. 21. 59. 11875.0 16. 8. 19. 49. 11876.0 18. 7. 17, 39. 11877.0 18. 9. 17. 40. 11878,0 17. 11. 18. 11879.0 14. 1]. 21. 53. 11880.0 16. 14. IX. 11881.0 19, i4. 16. 31. 118B2o0 19. 16. 14. 26. 11883.0 20. 9. 14. 29. 11884.0 20. 4. 14. 32. 11885,0 16. 5, 15. 44. 11886.0 1~. 5. 17. 45. 11887.0 19. 6. 12. 20. 11888.0 24. 6. 11. 15. 11889.0 24. 6. 11. 20. i1890.0 19. 4. 13. 40, 11891.0 15. 3. 16. 58. 11892.0 18. ~, i~. 45. 11893.0 16. 4. i3. 59. 11894.0 9. 7. 21. I00. 268. 450. 669, 572. 493. 334, 311, 627. 765, 862. 1209. t170. 876. 755. 973. 1404. 1132. 347, 20. 2. 35, 1Bb. 16~. 165. 108. 64. 40. 84. 159. 160. 9~. 85. 200, 290. ~18. 397. t22. 41. 425, 1281. 1285. 301. 79. 298. 164. 110,3 83.9 83.9 2518b0. 110,i 83.8 83.8 251549. 109o9 83,6 83,6 251034. 109,b 83,4 83,4 250350, 109.4 8~,~ 8~,2 24979~, 109,2 83,1 8],1 24932~, 109.0 82,9 82,9 249026, 108.9 82,7 82.7 248~38, 108,~ 82,5 8~,5 247979. 10~.4 82,3 82.3 247190, 108,2 82,1 82,1 2462~5. 108.0 81.9 81,9 24~0b0. 107.7 81,7 81,7 24]904. 107.5 81,5 81,5 243130. ~07.3 81,4 81,4 242340, 107.1 81.2 81~2 211200. 106,9 81,0 81,0 239847, 106,6 80,8 80,8 238887. 106.5 80,6 80,6 106,4 80,5 80,5 106,3 80,5 80,5 2~864b. 106,2 80,3 80,3 106.0 80,2 80,2 2.~8j99. 105,8 80,1 80,1 2~8277o ~05.~ 79,9 79°9 238110, 105.5 79,8 79,8 2{7955, I05,3 79,6 79,6 2]7865, 105.1 79,5 79,5 2{7808, 105,0 79,4 79,4 2Ji77UT, 104,8 79,3 79,-~ 104.6 79,1 79,1 23749]. 104,5 ?9,0 79.0 104.3 78,8 78,8 23727~, 10i.2 78,7 78.7 104,0 78,6 78,6 21712~. 10~,B 78,4 78,4 21b~99. 103.6 78,2 78,2 2~b601. 103.4 78.1 '?~,1 103.2 77,9 77,9 215919. 103.1 77,8 '1'7.8 2{5834, 102,9 77,7 77,7 235752, 102.7 77,5 77.5 I02,5 77,3 77,3 233682, 102.2 77.1 77,1 102,1 76,9 76,9 23244~. 101.9 76,8 76.8 101,7 7b,~ 76,6 212004. !Ol.b 76.5 76.5 2~1909. DEPTH FEET POR % % % % PERM MD .......... INTEGRATiUNS ......... -PHI-E H¥OH BVCH PERM, P-f'l H-FT H-FT f4D-f'T 11895,0 14. 8, 14, 11896,0 23, 7. 11. 28, 11897.,0 25, 7. 11, 19, 11898,0 20. 7, 11. 11899,0 25, 8. I1, 11900,0 24, 8, II, 11901,0 21, 8, i2, 27, 11902.0 i6. 10. 15. 42. 11903,0 18, I0, 15, 11904,0 23. 9. i2. 18, 11905,0 24, 9, I3, 18, 11906,0 24, 8, 12, 20, 11907,0 2], 8, 13, 27, 1i908,0 21. 8. 14, 11909,0 17, 10, 17, 39, 11910,0 15, ii. 21, 11911,0 19, 11, 18, 11912,0 23, II, 15, 1191],0 22, 18, 15, 24, 11914.0 19. 17. 19. 11915,0 15. 18, 29. 51, 11916,0 12. 24, 38, 97. 11917,0 8, 36. 50, 100, 11919,0 I1927,0 11928.0 . . 48. 54. lO0. 44, I00. 100, 4't, 100, I00, 79, 1029, 1657, 2083. 1793, 1302, 562, 115, 211. 888. 940. 1011. 828. 452. 120, 167. 603. 426. 5. 1. O. O. I1936,0 b. 41, 73, 100. O, 11937,0 b, 44, 69, 100, O, 11938,0 7. 48, 56. 100, 0, 11939,O 9, 47, 43. 100, 1, 11940.0 11. 42. 11941.0 14. 34. 26. 74. 23. 11942.0 15. 24. 24. 5b. 35. 11943,0 17. 16, 20, 45. 86. 11944.0 17. 14. 18. 45. 98. 11945,0 i8, 14, 18, 38. :137, 11946.0 20. 12. 18, 33, 202, 11947.0 19. 13. 20. 40. 158. 11948,0 lb. 19, 22. 58, 50. 11949.0 12. 20. 24. 68. 15. 11950.0 15. 22. Ig. 53. 50. 11951,0 I?, 11, 16, 55, 149. 11952,0 lb. 7. 16. 72. 87. 11953.0 I2. 6. 21. I00. 17. 1195,t.0 9. 6. 27. 100. 3. IO1,5 76,4 76,4 2.~1904, 101,3 70,3 76,3 231037. 101,1 76,1 76,1 230389, 100,8 75,8 75,8 22~t14. 100.6 75.6 75.6 226590. 100.3 75.4 75.4 224898. I00,1 75.2 75,2 223753. 99,9 75.0 75.0 223355. 99.7 74,9 74.9 22~240. 99.5 74,7 '14.7 222887. 99.3 74.5 74.5 221965. 99.1 74.3 74.~ 221024. 98.8 74.1 74.1 220027. 98.b 73,9 73.9 219279. 98.4 73,7 73,7 218930. 98.2 73.6 73.U 218838. 98.1 73.4 73.4 218777. 97.9 73.3 73°3 21~504. 97.7 73.1 73.1 217976. 97,4 72,9 72,9 217559. 97.3 72,8 72,8 217439. 97.1 72.7 72.7 217422. 97.0 72,6 72.6 217419. 96.9 72.5 72.5 217418, 96.5 72.5 72.5 217417. 96.5 72.5 72.5 217417, 90,1 72,4 72,4 217t10, 96.0 72,4 72,4 217416, 96,0 72,4 '72,4 211410, 95.9 72.3 72.3 217416. 95.8 72.3 72.3 2i741~. 95.7 72,2 72.2 217400. 95.5 72.1 72,1 21'/3~1. 95.4 72.0 72.0 217333. 95.2 71,8 71.8 2172~0. 95.1 71.7 71.7 217131. 94.9 71,5 71.5 21bq83. 96.7 71,4 71,4 210775. 94,5 7i,2 '11.2 210b47. 94.~ 71.I 71,1 21bb03. 94.2 11,0 71.0 210584. 94.1 70,9 70.9 216510. 93.9 70.7 70.7 210308, 93.7 70.6 70.b 210299. 93.b 70.5 70.5 2102~9. DEPTH f'EET EFF % VOL --$ATUR-- SH OH CH % % % PERM .......... INTEGRATIONS ......... PHI-E BVU}! BVCH PERM. MD P-~T H-FT }t-FT MD-f~T 11955.0 19. 6. 16. 42. 11956.0 26. 6. 12. 17. 11957.0 27. 6. 11. 14. 11958.0 27. b. 12. 14. 11959.0 25. 5. 12. 21. 11960.0 24. 7. 13o 19. 11902-.0 25. 9. 1]. 15. 11961.0 25. 9. 13. 14. 11~64.0 23. 9. 14. 17. 11965.0 21. 9. 13. 11966.0 20. I0o 15. 28. 1t967.0 19. 13. 16. 11968.0 17. 19. 16. 11969.0 19. 19. 14. 40. 11970,0 22. !3. 13. 33. I1971.0 2~. 15. 13. 11972.0 21. 17. 12. 26. 1197t~0 25. 10. 11. 16. 11974.0 28. 6. 10. 13. 11975.0 26. 7, 10. 15. 11976.0 23. 10. 12. 22. 11977.0 21. 13. 12. 30. 11978.0 20. I0. 12. 11979.0 19. 8. 12. 38. 11980°0 22. 8. 1!. 24. 1198t.0 25. 7. 9. 15. 11982.0 25. 9. 10o 11983.0 25. 8. It. 14. 11.984.0 26. 6. II. 17. 11985.0 25. 7. ii. 17. 11986.0 25. 8. 12. I~. 11987.0 24. I0. 12. 20. 11988.0 22. 8. 13. 11989.0 22. 7. 13. 25. 11990.0 21. 7. 14. 27. 11991.0 22. 7. 15. 26. 11992.0 22. 8. 16. 11993.0 23. 9. t7. 24. 11994.0 22. 1i. 18. 11995.0 19. 13o 19. ]9. 11996.0 18. 1t. 19. 44. I1997~0 21. 6. 16. 37. 11998.0 21. 6. 15. 31. 11999.0 22. 6. 14. 27. 12000.0 22. 5. 13. 26. 12001.0 22. 4. 12. 25. 12002.0 23. 5. 11. 24. 221. 93.5 70.5 70.5 216275. 1469. 93.3 70.3 70.3 215740. 2154. 93.0 70.0 70.0 214124. 1949. 92.8 69.8 ~9.8 212006. ~443. 92.5 69.6 69.6 210172. 1023. 92.3 69.4 69.4 208890. I108. 92.0 69.1 69.i 20'1870. 1357. 91.8 68.9 08.9 200691. 1158. 91.5 68.7 68.7 205299. 707. 91.3 68.5 t8.5 204284. 547. 91.0 68.3 68°3 20361]. 348. 90.8 68.1 68.1 20~1il. 207. 90.6 67.9 67.9 202803. I38. 90.4 67.8 67.8 202618. 293. 90.3 67.b 67.6 202461. 648. 90.1 67.5 67.5 647. 89.8 67.3 07.3 201381. 629. 89.b 67.1 67.1 20076~. 1566. 89.4 66.9 66.9 200005. 3119. 89.1 bb.7 bb.7 197991. 2364° 88°9 66.4 66.4 19~956. i009. 88.6 96.2 bO.2 192960. 621, 88.4 66.0 66.0 192076. 505° 8~.2 65.~ 65.8 191466. 444. 88.0 65.6 65.b 190985. 1023. 87.8 65.4 b5.4 190459. 2014. ~7.5 65.2 65.2 189101. 1821. 87.3 bS.0 65.0 18'1091. 1795. 87.0 64.8 64.8 185279. 1994. ~6.8 ~4.6 64.~ 18~92. 1708. 86.5 64.3 64.3 181417. 1330. 86.3 64.1 64.1 179840. 1085. 86.0 6~.9 63.9 1785bl. 735. 85.8 o3.7 6].7 177640. 578. 85.6 03.5 63.5 176874. 517. 85.4 63.3 b~.] 170299. 469. 85.1 b].l b].t 175806. 491. 84.9 ~2.9 6209 t75~25° 466. ~4.7 ~2.7 52.7 17482~. 316. 84.5 62.6 52.6 174388. 152. 84.3 62.4 62.4 174118. 134. ~4.1 62.2 62.2 1739~4. 327. ~3.9 62.1 ~2.1 173~11. 404. 83.'1 61.9 01,9 173454. 577. 83.5 bl.7 61.7 173030. 653. 83.3 61.5 bl.5 1'12410. 765. ~3.0 61.3 61.~ 171738. 1043. 82.8 ~1.2 61.2 17091~. DkPTH FEET POR -% VOL --.SA TUtq-- · SH OH CH % % % PERN ---- ...... INTEGRATION6 ......... ;PH1-E BVOH BVCH PERM, MD P-I~'~T H-FT it-FT MD-FT 12003.0 24, 6. 11. 12004.0 23. 4. II. 12005.0 22. {. 12. 12006.0 23. 4. i2. 12007.0 24, 4. 11. 12008.0 23. b. 11. 12009,0 19, 8, 13, 12010.0 17. 7. 12. 12011.0 17. 7. 12, 12012.0 16. 5. 15. 12013.0 18. 4. 14, 12014.0 21. 3. 10. 12015.0 lB. 4. i0. 12015,0 9. 4. 18, 12017.0 11. 6. 16. 12018.0 22. 4, 10. 12019.0 26. 4, 11. 12020.0 26. 4. 13. i2021.0 26. 5. 13, 12022.0 23. ?. 13. 12023.0 20. b. 14. 12024.0 15. 8, 17. 12025,0 16. 8, i7. 12026.0 lb. 7. 19. 12027.0 16. 6. 19, 12028.0 16. 6. 19. 12029.0 18. 4. 16. 12030,0 21. 2. 14. 12031.0 24. 3. 11. 12032.0 24. 5, 10. 12033.0 24. 5. IO. 12034.0 24. 6. 10. 12035.0 2]. 5. 9. 12036.0 23. 2. 9. 12037.0 23. 2. 10. t20.)8.0 22. 3. 10. 12039.0 21. 3. 10. 12040.0 21. 2. 8, 12041.0 20. 2. 9. 12042,0 20. 2. 12. 12043,0 20, 1, 17, 12044,0 20. O. 2t, 12045,0 23. 1, 20. 12046.0 25, 2, 18, 12047,0 25. 4, 13. 12048,0 23. 8. 11, 12049.0 22. 8. 11. 12050,0 23. 5. 11, 21. 1342. 25. i017. 26. 792. 23. 1054. 23. 1310. 25. 962. 39. 312. 53. 241, 55. 235. 65. 103. 55, 216. 42. 768, 58. 416. I00. 6. 100. 17. 33. 1254, 15. 1918, 15. 1421. lb. 1265. 18, 831. 34, 345. 57, 64, 50. 88. 45, 40, 72, 40. 86. t3. 182. 21. 499. 15. 1347. 14, i590. 15. 1629, 15. i780. 20. 1903. 20. 1357. 18. 1182. 21. 1107. 23, 950. 24. 1206. 26, i057. 2~. 454, 29, 240, 27. 170, 18. 293. 14. 534, 15, I096, 16. 1112, 17, 821, 19, 997, 82,6 60,9 b0,g 159727, 82,4 b0,7 60,7 168450, 82,1 60,5 60,5 16750], 81.9 bO,3 ~0.~ 16bOOb. 8t,7 60,1 60.1 16553~. 81,4 59.9 59,9 1b422~. 81,2 59.7 59,7 163450, 81.0 59,6 59,6 80.9 59,4 59,4 16290b. 80,7 59,3 59,3 162714, 80,5 59,1 59,1 162593. 80,4 59,0 59.0 162282. 80-1 58.8 58.8 161456. 80,0 58.7 58,7 lh122b. 79.9 58.6 58.b 161222. 79.8 58,5 58,5 Ibi094. 79,5 58,3 58,3 159451, 79,3 58,0 58,0 15772~. 79,0 57,8 57,8 155330, 78.8 57,6 57.6 15514~. 78,5 57,4 57,4 154442. 78.~ 57,2 57,2 1.54189. 78,2 57.1 57.1 15412~. 78,0 57,0 57,0 1540~5, 77-9 56,8 56,8 153975. 77.7 56,7 56.7 153901. 77,6 56,6 56,b 153798. 77,4 55,4 55,4 153550. 77,2 56,2 56,2 152995, 76,9 55.0 50,0 151559. 76,7 55.8 55,8 149902. 7~,4 55,6 55,6 1482ii. 76.2 55,4 55.4 14~2~6, 76,0 55.2 55,2 144740. 75,7 55,0 55,0 143469. 75,5 54.8 54,8 142257. 75,3 54,6 54,6 141242. 75,1 54.4 54,4 140265. 74,9 54,2 54,2 119002. 74,7 54,0 5.4,0 11818~, 74,5 53.8 5.3.8 1{7790. 74,3 53,7 53,7 1375~9, 74,1 53,5 53.5 137399. 73,8 53.3 53,_i I.$704B, 73.6 53.1 5].1 136416. 7~,4 52,9 52,9 1.~5230. 73,1 52,7 52,7 114178, 72,9 52,5 52,5 DEPTH FEET POR % VOL % % % PERM ...... ---- 1N TEGR AT I O N,'~ ......... PHI-E BVOH BVCH PERM, MD ,P-FT H-FT H-FT MD-FI~ 1205i.0 22. 4. 12. 22. 12052.0 22. 4. 11. 21. 12053.0 22. 5. 11. 21. 12054,0 22, 4, 12, 19. 12055.0 21. 6. 13. 21. 12056,0 20-, 6, 13. 23. 12057.0 19. 6. 15. 25. 12058.0 19. 8. 16. 21. 12059.0 20. 4, 16, 23. i2000,0 20. 4, 17. 23, 12061.0 20. 5. 16. 2]. 12062,0 2t, ], 16, 24, 12063,0 21, 4, 15. 25. 12064.0 21. 4. 15. 24. 12065,0 21, 5, 15- 12066,0 20, 4, 15, 24, 12067.0 22. 3, 15. 23. 12068.0 23. 3. 14. 19. 12069,0 22. 5. 14. 20. 12070.0 23. 5. 14. i9. 1207t.0 23. 6, 13. 16. I2072,0 23. 7, 14. lb. 12073.0 23. 6. 15. 20. 12074,0 22. 7, 15. 20. 12075,0 22. 6. 15, 26, 12076°0 22. 4, 15. 28. 12077.0 23. 4, 14, 25, 12078,0 25, 4, 12, 20, 12079,0 24. 5, 11, 18, 12080,0 23, 4, II. 12081.0 24. 4. 10. 20. 12082,0 26. 3, 10. 16. 12083.0 27. 3. 10. 16. 12084.0 27, 4. 11. lb. 12085.0 26. 6, 13. t4. 12086,0 26, 6, 13, 15. 12087.0 26. 7. 13. 14. 12088,0 26. b. 13. 14. 12089-0 27. 7. 12. 12. 12090.0 26., 9. 1]. 14. 12091-.0 26. 7. 13. 17. 12092,0 25. 4. 14. 21. 12093.0 25. 5. 14. 21. 12094.0 24. 5, 14. 24. 12095,0 22, 4, 15. 35, 12096.0 20. 3. 16. 40. 12097.0 21. 3. 14. 32. 12098.0 23. 3, 12, 26. 812, 72.7 52.3 52.3 132422. 894. 72.5 52.1 52.1 131596. 884. 72.2 51.9 51,9 110687. 874. 72.0 51.7 51,7 129839, 540, 71,8 51,5 51,5 129099, 408, 71.6 51.3 51,] 128598, 271, 71,4 51.2 51,2 128237, 243, 71,2 51,0 51,0 12Y972, 276, 71,0 50,8 50,8 127741, 246. 70.8 50,7 50,7 127477, 294, 70,6 50.5 50,5 127222, 333, 70.4 50,3 50,3 12691~, 343. 70,2 50,2 50,2 126580, 411. 70,0 50.0 50,0 126228, 420, 69,8 49,8 49,8 125774, 322, 69,6 49.6 49,6 125366. 462, 69,4 49,5 49,5 125057, 669, 69.2 49.3 49,3 124548. 570. 68.9 49,1 49,1 123895, 671. 68,7 48.9 48,9 123312. 777. 68,5 48,7 48,7 122594. 552. 68.2 48,5 48,5 121867, 615, 68.0 48.3 48.3 121217. 492. 67.8 48.1 48.1 120639. 463. 67.6 47.9 47,9' 120158, 445. 67,] 47.7 47,7 119699, 692, 67,1 47.5 47,5 119228, 1424, 66,9 47,3 47,3 118357. 1250. 66.6 47.1 47.1 116891. 1084. 66.4 46,9 46,9 115729. 1640, 66,2 46.7 46,7 114559, 2539, 65.9 46.5 46.5 112~70, 2613. 65.7 46.2 46,2 110079. 2184, 65,4 46.0 46,0 107532, t533. 65.1 45.8 45.8 105550. 1~02. 64.9 45.5 45,5 104073. 1289. 64.6 45,3 45,3 102814, 1582, 64.] 45.1 45,1 1.01456, 1877, 64,1 44,8 44,8 99795, 1459. 63,8 44,6 44,6 97949, 1254. 63,6 44.4 44,4 96597, 1006, 63,3 44,2 44,2 q5~99, 997. 63,0 43,9 43,9 g4405, 841. 62,8 43.7 43,7 93408, 483, 62.6 43,5 43,5 92046, 298, 62,4 43.4 43,4 92233, 470. 62.1 43.2 43.2 9191~. 882 bi 9 43 0 43,0 91350. DEPTH FEET 12099.0 12100.0 12101'0 12102°0 12103.0 12104~0 12105i. 0 12106.0 12107,0 12i08,0 12109,0 12110.0 12iii.O 12112,O 12113,0 12114.0 12115,O 12116,0 12117,0 12118.0 12ilg, O 12120,0 12121.,0 12122,0 12123°0 12124,0 12125!,0 12126,0 12127o0 12128,0 12129,0 12130,0 12131,0 12132,0 12133-0 121i4,0 12135,0 12136,0 12137,0 12138,0 12139,0 12140.0 12141,0 12142,0 12144,0 12145,0 t2Itb,O ;POR % 22. 2i, 22. 24, 24, 25, 24, 24, 24° 23. 24. 24, 23. 23, 25. 22, 22, 21, 20, 2O. 20. 20. 25. 25. 2~. VOL SH OH CH % % 3. 4. 5. 4. 3, 5, 6. 6. 5. 4. 6. 7. 9, 5. 5, 4. 6. 5, 5. 5. 8. 9. 9. 9. 7. 5. 4. 4. 2. 2. 4. 4. 2. 3, 2. 12. 26, !3o 30. 11'o 29. 10, 23. I0, 24. I0, 21. 9, 17. i0, 15, 12. 14. 18, I5. 18, 16. 22, i6, 15. 21' 15. 16. 15. 16, 16, 16, 17. 26, lb. ~1. 16, 19. 15, i8. 15. 14. 16, 14. 17, 18. 17. 18. 19, 19, 19, 20. 22. 20. 25. 21. 26, 20, 28, 20. 34, 19. 90. :17. 25, 17. 22, 16. 20. 15. 21, 15, 25. 17. ~0. 17, 34, 16, 27. 16, 20. 16, i6. 16. 18. 16, 18. 16. 16. 16, 15, PERM .......... IN TEGRAT i O i.i.5 ......... .PHI-E BVOH BVCH PERM, MD P-FT H.-FT H-FT MD-F'I 753, 61,7 42.8 42,a 904~4, 530. 61,5 42,5 42,6 89'189, 817, 61,3 42,4 42,4 89234, 1441, 51,1 42.2 42.2 88217. 1411, 60,8 42.0 42.0 86821. I912, 60,6 41,8 41.8 85281. 2162, 60.3 41.6 41.6 8332~. 1958. 60.1 41.4 41.4 81213. 1'150. 59,8 41.1 41.1 79471. 741. 59,6 40,9 40,9 78445. 643, 59,4 40,7 40,7 77713, 513. 59.1 40.5 40.5 77117. 643, 58,9 40,3 40.3 76584. 695, 58.7 40,1 40.1 76905. 607, 58,4 39,9 39.9 75233, 584, 58,2 39.7 39,7 74b12. 506, 58,0 39,5 ]9.5 7~049, 468, 57,7 39,3 39,~ 7354~, 464, 57,5 39,1 i~9.1 73099. 503, 57,3 39,0 ]9,0 72622. 526, 57,0 38,8 38,8 72105, 676. 56,8 38.b ~8.6 71548, 870. 56.6 38,4 38,4 70808. 768, 56,3 ]8,2 38,2 b9942. 591, 56,1 37,9 37.9 b9225. 539. 55.8 37,7 37.7 b~655. 326, 55.6 37,6 37.6 68132. 298, 55,4 37,4 ]7.4 b782~. 201, 55,2 37,2 37,2 675~0, i79. 55,0 37,0 3'7.0 671b8. 162, 54,8 36,9 3b,9 67193. 172, 54,6 36,7 ]6,7 ~7034. :156, 54.4 36,6 lb,0 6bBb4, 208. 54,2 36.4 36.4 60700. 296. 54.0 36.2 36.2 604'77. 434. 53.8 36.1 36.1 497, 53,5 35.9 35.9 65684, 532, 53,3 35,7 35.7 6517~. :480, 53,1 35.5 35.5 b4bb3. 280. 52,9 35,3 35.] b4223, 277, 52.7 35,1 35,1 63954, 563, 52,4 35,0 ]5,0 b]b21. 8i7, 52,2 34,8 34.8 ~2971, 883. 51.9 34.5 3.1,5 O2119. 813, 51.7 34.3 34.3 61232. 879, 51,4 34.1 34,1 00410. 908. 51.2 33.9 33,9 59514, 959, 50,9 33.7 33,7 5~589, DEPTH {FEET gFF POR % V aL SH OH CH % % % PERN .......... !NTEGRATiON~ ....... -- PHI-E BVOH BVCH pERlVt. MD P-I~'I' H-FT H-FT MD-F']~ 12147.0 27. 3. 17. 16. 12148.0 27. 3. i6. 15. 12149.0 26. 4. 16. 16. 12150.0 26. 5. lb. 16. 12151.0 25. 4. 16. 20. 12152.0 26. 4. 14. 20. 12153.0 26. 4. 13. 16. 12154°0 27. 7. 13. 10. 12155,0 27. 6. 14. 12, 12156.0 26. 4. 15. 19. 12157.0 2.5. 4. 17. 22. i2158.0 25. 4, 18. 25. 12159.0 25. 3. 18. 24. 12160,0 27. 3. 17. 18, 12161.0 27. 3. 16. lb. 12162,0 27, 4, 14, 17, 12163,0 26, ], 14, 19, 12164,0 25, ~. 15, 23, 12165,0 23, 5. t5, 26. 12166.0 23. 6. 15. 27. 12167.0 23. 8. 15. 12168,0 23, 6, 16, 24, 12169,0 23. 7. I8, 24, 12170°0 21. 6, 22, 36, 12171,0 20, 6, 25, 38. 12172,0 21, 5, 28, ~1, 12173.,0 20, 3. 30. 29, 12174,0 20, 2, 32, 31, 12175.0 21, 1, 28, 27. 12176,0 21, 2, 26, 25, 12177-0 22, 5, 23, 22, 12178,0 22, 9. 20, 1.2, 12179,0 21, 18, 20, 9, 12180,0 21, 18, 19, I0, 12181,0 20, 13. 22. 19, 12182.0 20. 8. 22. 12183,0 21, 7. 21, 36. 12184,0 21, 6, 21, 27, 1218.5.0 20. 6. 22. 24. 12186,0 20. 6, 21. 26, 12187,0 19, 11, 22, 29, 12188.0 18. 16. 23. 12189°0 14. 31, 29, 35, 12190,0 I0, 39, 37. 98. 12191,0 6. 43. 55, 100, 12192.0 5. 47. 52. I00. 12193,0 8, 49, 42, i00, 938. 50.7 33.5 33.5 57621. 1019. 50.4 33.2 33.2 50670. 935. 50.1 33.0 33.0 55658. 904. 49.9 32.8 32.8 54'Y03. 762. 49.6 32.6 32.6 53874. 1218. 49.4 32.4 32.4 1426. 49.1 32.1 32.1 51736. 1497. 48.8 31.9 31.9 50300. 1606. 48.6 31.7 31.7 48622. 1081. 48,3 31.4 ]1,4 4';1~0, 755. 48.0 31.2 31.2 46168. 570. 47.8 31.0 31.0 45409. 603. 47.5 30.8 30.8 44907. 914. 47.3 30.b ~O.b 4~22S. 1184. 47,0 30,4 30,4 43211. 1381. 46.7 30.1 ]0.1 41900. 1195, 46,5 29,9 29,9 40601, 880. 46.2 29.7 29.7 ]9473. 6i2. 46.0 29.5 29.5 38667. 600. 45.7 29.3 29.3 ~8070. 535. 45.5 29.1 29.1 ~7492. 547. 45.3 28.9 28.g {6959.. 444. 45.0 28.7 28,7 3641.i. I~5. 44.~ 28.5 28.5 160~4. 119. 44.6 28.4 28.4 35884. 107. 44.4 28.2 28.2 .~5704. 81. 44.2 28.1 28.1 _{5bbO. 63. 44.0 27.9 27,g 35588. 113. 43.8 27.8 27.8 35516. 133. 43.5 27.b ~7o6 35396. 191. 4~.4 27.5 27.5 35251. 2~6. 43.1 2~.3 27.3 215. 42.9 27.1 27.1 34729. 226. 42.7 26.9 2~.9 136, 42,5 26,8 26,8 342~1, 164. 42.3 26.6 2~.6 '~4145. 184. 42.1 26.5 26.5 33976. 197. 4i.9 26.3 26..~ 170. 41.? 26.1 26.1 {359B. 175. 41.5 2b.0 26.0 33433. 118, 41,3 25.8 25.8 75. tl.l 25.7 25.7 3~173. 16. 40,9 25,6 25,6 33115, 2. 40.8 25.5 25.5 ~3103. O. 40.7 25.4 25.4 33101. O, 40,b 25.4 25,4 1. 40.6 25.4 25,4 12195.0 7. 49, 56. 100, O. 40.4 25.3 25,3 35100, 12196.0 12197.0 12198.0 12199.0 12200.0 12201.0 122O2. O 12203°0 12204.0 EFF % . 7, 4, 4. 5, 5, 4, 6, 7. VOL --SATUR-- SH [tH CH % % % 4], 67, 100. 42, 67, I00, 45, 88, 100, 42, 97, 100. 44, 76, 67, 78, I00. 49, 90, 100, 49. 71, I00, 49, 65, 100, 12209.0 5. 46. 75. 100. 12210.0 4. 44. 91. I00. 12211.0 2. 49. 100. 100. 12212,0 4, 46, 88, 100, 12213.0 6. 4.]. 57. 100. 12214.0 6. 39. 56, I00, 12215,0 7. 35, 54, I00, 12216,0 8. ]4, 44, I00, 12217,0 11. 33, 30, 100. 12218.0 15. 24. 2], 61, 1221g,0 20, 10o 19. 12220.0 21. 6. iB. 33. 12221.0 20. 4. 19, 12222.0 20. 5. 19. 53. 12223,0 19, 7, 21. 32, 12224.0 lb. I1. 23. ~0. 12225.0 18. 12. 20. 30. 12226.0 22, 13. 17, 27, 12227°0 23, 8, 18, 22. 12228.0 24, 4, 18. 25, 12229,0 25, 5. 18. 25, 12230.0 23. 3. 20. .30. i2231,0 22, 3, 21, 29, 12232.0 23, 3. 21, 20, 12233.0 22, 2, 21. 29. 12234,0 23. 2. 2U. 32, 12235,0 26. 3, 17. i2236.0 26. 3. 16, 24, 12237,0 26. 5. 17, 16. 12238,0 2b. O, 17. 12, 12239,0 26. 6. I@, 12, 12240,0 25, 5, 20, 12241,0 24, 5, 21, 18. 12242,0 23. 4. 22, 21, 12243,0 22. 4, 23, 24, 12244,0 22. 5, 23, 12245,0 22, 6, 23, 24, 12246,0 22. 6, 23, 25. PERM ........ -- IN Tf. GRAT IUN~% ......... PHI-E BVOH BVCH PERM, MD P-Fl' }i-FT H-f'T MD-fi' O, 40,4 25,2 25,2 3]100, U, 40,3 25,2 25,2 ]3099, O. 40,2 25,2 25,2 ]3099, 0. 40,2 25,2 25,2 33099, O. 40,1 25,2 25,2 3]099, O. 40.1 25,2 25,2 13099, O. 40,1 25.2 25,2 ]3099. 0, 40,0 25,2 25,2 330~9, 0. 39,9 25,1 25,1 .~3099. O. O, O, O, O, O, O, 1, 7, 39, 199, 208. 189. 214, 126. 48, 124, 366. 443. 527. 600, ~i3, 227, 304, 273, 302. 849, 970. 775, 751. 673, 540, 350, 295. 208, 19~, ~1], 203. 39.7 25,1 25.1 13098. 39.5 25.1 25.1 33098. 39.6 25.1 25.1 ~3098. 39,6 25,1 25,1 33098, 39,5 25,1 25,1 ~3098, 39.5 25,0 25,0 33098, 39,4 25,0 25,0 .]3098, 39,3 25,0 25,0 39,2 24,9 24,9 ]3096, 39,1 2~,8 24,8 38.9 24,7 24,7 ]3019, ~8,7 24,5 24,5 38,5 24,4 24,4 ]2552. 38,3 24,2 24,2 32358, 38,1 24,1 24,1 32154, 38,0 23,9 2J,q 32056. 37,8 23,8 23,8 32000. ]7,6 23.6 2~.6 ]1821. 37.4 23.4 23.4 31427. 37,1 23,3 23.~ 36,9 23,0 23,0 .3U~94. 36,6 22,8 22,~ 36,4 22,7 22,7 29572, 3~,2 22,5 22,5 29.i22, 30.0 22,3 22,3 29015, J5.8 22,1 22,1 2~762, 35,5 22,0 22,0 28361, 35,3 21,7 2~.7 274'15, 35,0 21,5 21,5 2~581, 34,7 21,3 21,.~ 34,5 21,1 2!.,1 2509~. 34.2 20.9 20.9 2444o. 34.0 20.7 20.7 23940. 33.1 20.5 20,5 23011. 33,5 20,3 20.] 33,3 20,1 20.1 2313~. 33,1 20,0 20,0 22935, 32,8 19,~ 19,8 22'12j. EFF % VUL --SATON-- % % % PERM .......... INTEGJqATiON,5 ......... PHI-E BVOH BVCH PkRN. ND P-FT H-FT H-FT ~ [)- ~' T 12247.0 20. 7. 24. 33. 12248.0 18. 11. 24. ]9. 12249-.0 17. 18. 12250.0 16. 27. 27. 40. 12251.0 12. 44. 34. 66. 12252.0 8. 40. 53. 100. 1225].0 I0. 26. -55. I00. 12254.0 7. 21. 82. 100. 12255.0 7. 25. 78. I00. 12256.0 7. 29. 12257.0 7. 30. 58. 100. 12258.0 6. 34. ~6. I00. 12259.0 6. 49. 62, 100. 12279.0 9. 44. 46. 100. 12280.0 i0. 41. 43. 5b. 12281.0 12. 33. 42. 37. 12282.0 12. 31. 44. 73. 12283.0 9. 37. 55. 100. 12284.0 b. 49. 74. I00. 12293.0 14. 47. 30. 82. 12294.0 17. 39. 25. 33. 12295.0 18. 29. 25. 20. 12296.0 20. 22. 23. 14. 12297.0 22. 14. 22. 10. 12298°0 24. 10. 21. 11. i2299.0 24. 7, 21. 12300-0 25. 5. 20. 16. 12301.0 26. 3. i9. 12302.0 27. 3. t8. 12303.0 28. 5. 17, 12304.0 27. 6. 18, 12305.0 26. 10. 20. 15. 12306.0 25. 11. 22. 20. 12307.0 24. 13. 23. 24. 12]08.0 22. 18. 24. 12309.O 24. il. 21. 12310.0 27. 6. 17. 16. 12311.0 27. 4. 18. 19. 12312.0 27. 5. 18. 21. 12313.0 27. 4. 19. 28. 12314.0 25. 5. 20. 12315.0 24. 4. 20. 47. 12316.0 20. ]. 22. 64. 12317.0 17, 1. 26. 76. 12318°0 i7. 2. 25. 73. 12319.0 I~. 3. 23. 69. 114. 32.6 19.6 19.6 22545. 74. 32.4 19.5 19.5 2244Y. 58. 32.3 19.4 19.4 22373. 34. 32.1. 19.2 19.2 22315. 7. 31.9 19.1 19.1 2228b. O. 31.8 19.1 19.1 222~2. t. 31.8 19.0 19.0 ~2282. O. 31.7 i9.0 19.0 222~1. O. 31.5 19.0 19.0 22281. O. 31.5 19.0 19.0 222~1. O. 31.5 18.9 1~.9 22281. O. 31.4 18.9 IB.q 222~0. O. 31.3 I8.9 18.9 22280. 1. 31.0 18.8 18.8 22~. 2. 30.9 18.8 18.8 22277. 4. 30.8 18.7 18.7 2227bo 3. ]O.b 18.7 18.7 222'~0. I. 30.5 i8.6 18.b 22268. 0. ]0.4 18.6 18.6 22207. 14. 30.0 18.5 18.5 222U4. 56. 29.8 18.4 18.4 22240. 77. 29.7 1~.2 18.2 2217B. 134. 29.5 i8.1 18.1 22092. 253. 29.3 17.9 17.9 2192~. ]66. 29.0 17.8 17,8 21054. 370, 28.8 17.b 17.6 2128b. 532. 28.6 17.4 17.4 20892. b59. 28.3 17.2 17.2 20324. 881. 28.0 i7.0 17.0 19618. iObl. 27.8 lb.7 lb.7 18661. 864. 27.5 16.5 10.5 1'1623. 622. 27.2 lb.3 lb,3 lb837. 392. 27.0 ib.l 16.1 lb269. 287. 2b.7 15.9 15,9 15~. i80. 2~.5 15.7 15.7 15050. ~89. 20.3 15.5 15.5 lb441. 946. 26.0 15.] 15.3 14940. 914. 25.? 15,1 15.1 13961. 876. 25.5 14.9 14.9 1305b. 710. 25,2 1~.7 14.7 IZ21b. 522. 24.9 14.4 14.4 11557. ]78. 24,7 14.2 14.2 11019. 142. 24.5 14.1 14.1 107bl. 53. 24.3 13.9 13.9 lObbS. 59. 24.1 13.8 13.8 10599. ~8. 23.9 1].? 13.7 lO~Sb. DEPTH FEET POR % VUL --SATUR-- % % % PERM ....... --- INTEGI~AT lt, JN,% ......... :PHI-E BVOH BVCH PERbl. MD P-FT H-FT !t-FT ND-I~'T 12320.0 19. 2. 22. 60. 12321.0 19. 2. 24. 57. 12322.0 19. 2. 25. 51. 12323.0 22. 3. 22. 43. 12324.0 23. 4. 21. 38. 12325.0 21. 5. 23. 40. 12326.0 18. 5, 27. 37. 12327.0 22. 5. 21. 20. 12328-0 28, 4. 17, 14. 12329.0 27. 5. 18. 14. 12330.0 27. 5. 18. 16. 1233i.0 26. 7. 22. 17. 12332.0 25. 8. 2b. 23. 1233].0 25. 8. 31. 28. 12334,0 26, 10. 32, 23, 12335,0 24, 11. 34, 21. 12336.0 23. 13. 33. 19. 12337.0 22. 20. 30. 12. 12338°0 21. 16. 27. 9. 12J39.0 21. 11. 24. 9. 12340,0 20. lO, 23, 18, 12341.0 19. 19, 33. 50. 12342.0 7. 36. 57. 100. 12343.0 5. 46. bS. I00. 12344.0 7. 40. 62. 100. 12345.0 8. 35. 62. 100. 12346.0 9. 36. 56. I00. 12347.0 9. 39. 52. I00. 12348,0 11. 32. 47. 70. 12349.0 15. 23. 38. 43. 12350,0 17. 21. 35, lb. 12351.0 1'7. 2]. 34. 12352.0 17. 21. 33, 33. 12353.0 19. i8. 32. 28. 12354.0 19. 17. 32. 26. 12355.0 i9. 18. 31. 25. 12356.0 19. 2I. 29. 21. 12357.0 20. 22. 27. 15, 12358.0 20. 17. 27. 15. 12359,0 21. 15. 27. 18. 12360.0 t9. 14, 29. 26. 12361'.0 13. 13. 41. 48. 12362.0 17. 10. 33. ~3. 12303.0 23. 7. 25. 27. 12364.0 19. 7. 28. 43. 12365.0 i3, 7. 41. 94. t2366,0 6. 7. 86. I00. 123~7o0 i7. I0. 30. 34. 125. 23.7 13.5 13.5 10430. 98. 23.5 13.4 13.4 10312. 94. 23.3 13.2 13.2 10220. 203. 23.1 13.1 13.1 1010~. 27b. 22.9 12.9 12.9 9875. 151. 22.7 12.7 12.7 9018. 56. 22.5 12.b 12.b 9503. 273. 22.3 12.4 12.4 9~29. 1005, 22.1 12.3 12.3 8957. 946, 21.8 12,0 12.0 7937. 876, 21.5 11,8 11.8 1013. 479. 21.3 ll,b 11.6 b23~. ~03. 21.0 11,4 11,4 5811, 201. 20.~ 11.2 1i.2 55~3. 219. 20.5 11.0 11.0 5~41. 153. 20.3 10.9 10.9 51~4. 113, 20,0 I0.7 10.7 4991. 116. 19.8 10.5 10.5 4~79. 122. 19.6 10,4 10.4 4763. 151. 19.4 10.2 10.2 4040. 134. 19.2 10.1 10.1 4479. 13. 19.0 9.9 9.9 43~0. O. 18.9 9,9 9.9 4372. 0. 18.8 9.8 9.8 ~372. O. 18.7 9.8 9.8 4~72. O. 18,7 9.8 9.8 437~. 1. 18.b 9.8 9.8 4372. 1. 18,b 9.7 9.7 43'71. 2. 18.4 9.7 9.7 4370. 14. 18.3 9.6 9.6 4360. 27. 18.1 9.5 9.5 4348. 27. 18.0 9.4 9.4 4320. 34, 17,8 9.] 9.~ 4292. 51. 17.b 9,2 9.2 4254. 59. 17.4 9.0 9.0 4203. 65. 17,2 8,9 8.9 4i40. b4. 17.0 8.8 8.8 407'1. 99. 16.8 8.b 8,b 4003. 104, I6,b 8,5 8,5 3908, 112. 16.4 8.3 8.3 3799. bO. 16.2 8.2 8.2 3693. 7. 16.1 B.1 8.1 3653. 34, 15,9 8,0 8,0 364b. 196. 15,7 7.9 7.9 3507, 78. 15.5 7.7 7.7 3398. 5. i5,3 7.6 7,6 3345. O. i5.2 7.5 7.5 J342. 39. I5.1 7.5 7.5 33~1. O,. DLPTH POR % VOL --6ATOR-- % % % PER~I .......... iNTEGRATIONS ......... ND P-FT H-FT H-FT 12368.0 20. 11. 28. 30. 12309.0 14. 15. 37. 55. 12370.0 12. 18. 44. 71. 12371.0 14. 22. 39. ~7. 12372.0 20. 25. 28. 20. 12373,0 19. 20, 29. ,31. 12374,0 19, i2. 29. 12375.0 i5. 11. 33. 44. 12376,0 5. 12, 82, 100, 12377.0 3. 15. I00. 100. 12378.0 2. 14. 100. !00. 12379.0 13. 11. 44. ~3. 12380,0 19. 10. 33. 19. 12381,0 22. 12, 30, 15, 12382,0 20. 14. 33. 19, 12383,0 19, 18, 34, 20, 12384,0 19, 21, 33, 20. 12385,0 19, 20, 34, 17, 12386,0 22, 12, 31, 15, 12387,0 25. 9. 28, 11. 12388,0 25. g. 27. 12389,0 23, 10. 27, 20, 12390,0 20, i1, 28, 36, 12391,0 t3, 12, 38, 99, I2392.0 6. I0. 91, I00. 12393.0 3. i0. 100. 100. 12394.0 1t, 11, 57, I00, 12395.0 22, 13. 31. 18. 12396,0 25, I1. 29, 9, 12397,0 24, 11, 30, 12398.0 23. 11, 30, lb, 12399,0 23, 14. 29. 15. 12400.O I7. 36. 35. 12406.0 12. 33. 52. 97. 12407.0 lb. 24. 40. 39. 12408.O lg. 20. 36. 30. 12~09,0 19, 19. 3~, 26. 12410,0 19, 15, 38, 27. 12411,0 18, 13, 39, 27, 12412,0 20. i. 4, i2413,0 19, 14, 38. 22, 12414,0 17, lb, 44, 25, 12415.O 13. 16. 56. 38. 12416,0 13, 19, 52, 38, 12417.0 i2. 2~. 5b. 45. 12418.O 12. 24. 56. 60. 12q19.0 13. 19. 57. 84, 15.0 7,3 7~.{ 32bt, 12, 14,8 '7,2 7,2 3202, 4. 14.6 7.1 7,1 3193, 9. 14.5 '1.1 7.1 3189. 84. 14.4 7.0 7.0 ~163. b9. 14.2 6.8 b.8 3074. 62. 14.0 6.7 6.7 3008. 19, 1~,8 6,b 6.6 2947° O. 13.7 6.5 6.5 2937. O. 13.6 b.5 6.5 2937. 0. 13.6 6.5 6.5 2937. 5. 13.5 6.5 o.5 2937, 57. 13.4 6.4 ~.4 2922. 117. 13.2 0.2 0.2 284~. 63. 13.0 6.1 b.l 2751. 48. 12.8 O.O b.O doll. 49. 12.6 5.8 5.8 2648. 46. 12.4 5.7 5.7 2597. I08, 12.2 5,6 5,6 2543, 258. 12,0 5.4 5.4 Z397. 272. 11,7 5.2 5.2 2111. 204. 11,5 5,1 5,1 1851, 84. 11,3 4,9 4,9 1671. 7, 11,1 4,8 4,8 lolo, O, 11,0 4.7 4.7 1613. O. I0.9 4.7 q.7 1612. 2. 10.9 4.7 4.7 lb12. 128. 10.8 4.0 4.6 1590. 235. 10.5 4.5 4.5 1417, 184, 10,3 4,3 4,.] 11~0, 155. I0,0 4,1 4,1 101~, i64. 9.8 3.9 3.9 ~41. 28. 9.b 3.8 3.8 717. 2. 9.3 3.7 3.7 700. 15. 9.2 3.b .'3.6 bgb. 40. 9.1 3.5 3.5 674. 45. 8.9 3.4 3.4 35. 8.7 3.3 j.3 589. 32. 8.5 3.2 3.2 555. 47. 8.3 3,0 3,0 521. 44. 8.1 2.9 2.9 470. 17. 7.9 2.8 2.8 432. 3. 7.8 2.7 2.7 420. 4. 7.b 2.7 2.7 417. 3. 7.5 2.b 2.h 413. 2. 7.4 2.5 2.5 410. 4. 7.3 2.5 2.5 40~. DEPTH FEET EFF POR % VOL % % % PERM .......... iN'I'EG}{AT IONS ......... PHI-E BVUH BVCH P£RM, MD P-~'T ~t-FT H-FT MD-FT 12420,0 I6. 18. 50° 57, 12421,0 18, 19, 46. 46, 12422,0 18. I8, 49, 43° 1242],O 18, 19. 49, 40. 12424,0 18, i9° 49, 42, 12425,0 18, 19. 50, 44, 12426,0 20, 19. 49, 38, 12427o0 19, 20, 52, 40. 12428,0 17. 21, 59, 46, 12429,0 17, 21. 62. 48° 12410,0 17, 28. 60, 51, 12431,0 i7, 33, 50, 05, 12432,0 11. 28, 9], 100, 1243],0 5, 27, 100, 100, 12434.0 11. 23. I00. I00. 12435,0 19. 23, 62. 48. 12436,0 21, 24, 57, 32, 12437,0 20. 27° O1, 27. 12438,0 20. 23, 08, 35, 12439,0 20. 21. 71, 40, 12440.0 20, 20, 72. 41, 12441,0 19, 25, 74. 99, 12442,0 15, 35. 84. 34, 12443,0 il, 43. 100, 50, 12449,0 12450,0 12451,O 12452,0 12453,0 12454,0 12455.0 12456,0 12457,0 12458,0 12459,0 12460,0 12461°0 12462,0 12463.0 12464.0 124~5,0 12406o0 124~7,0 12468°0 12469.0 12470,0 12471°0 11. ]4, 82, 100. 17o 22, 60. 60. 18. 21, 57, 52. 16, 26. 57, 63. 14. 3t. 60. al. 13. 30. 65. 100. 10. ~. 79. I00. 7, 4]. 97, 100, 7. 48, 95, 100. 9. 47° 69, 100. I0. 42. ~3. 100. 10. 40. 00. I00. 9° 39° 75. I00. 8, .46, 85, I00. 4, ~8, I00, 100, 2. 35. I00. 100. 8. 36. 95. 100. 10. 32. 70. I00. I0. 32. 73. 100. 10. 28. 73. I00. 11. 28. ~7. 100. 13, 29, 57, 87, i5. 29. 51. 77. 12. 7.1 2.4 2.4 40.~. 21. 6.9 2.~ 2..~ 388. 17. 6.8 2.2 2.2 17. 6.6 2.2 2.2 561. 20. 6.4 2.1 2,1 333. 20, 6,2 2,0 2,0 314. 28. 6.0 1,9 1o9 293, 22. 5,8 1,8 1,8 11. 5,7 1,7 1,7 241, 9. 5,5 1.6 1,6 23~, 9, 5,3 1.6 1,6 22/, 12. 5.1 1.5 1.5 21~. O. 5.0 1.4 1.4 209. O. 4.9 1.4 1.4 208. O. 4.8 1.4 1.4 208. 1~. 4.7 1.4 1.~ 206. 29. 4.5 1.3 1.3 18~. 21. 4.3 1.2 1.2 21. 4.1 1.2 1.2 142. 22. 3.9 i.1 1.1 121. 22. 3.7 1.0 1.0 98. 1~. 3.5 1.0 1.0 78. 3. 3.3 0.9 0.9 08. O. 3.2 0.9 O.q bO. O. 3.0 0,9 0.9 8. 2.8 0.9 0.9 04. 13. 2.7 0.8 0.8 54. 9, 2.5 0,7 0,7 42, 4, 2,3 0,7 0,7 34. 2. 2,2 0,6 0,6 30, O. 2.1 O.b 0.6 29. O. 2.0 0.6 0.6 29. O. 1.9 O.b 0.6 29. 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