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Home My WebLink About199-125CAUTION: 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 X-24A (PTD #1991250) Secured with TTP Date:Monday, September 11, 2023 8:23:56 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Monday, September 11, 2023 5:59 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: NOT OPERABLE: Injector X-24A (PTD #1991250) Secured with TTP Mr. Wallace, Injector X-24A (PTD #199125) was secured with a tubing plug and subsequent CMIT-TxIA passed on 09/05/23. An LDL identified multiple tubing leaks on 09/10/23. The well is now classified as NOT OPERABLE and will remain shut in until tubing integrity is restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Thursday, August 17, 2023 11:31 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg@alaska.gov; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector X-24A (PTD #1991250) MIT-IA Failed Mr. Wallace, Injector X-24A (PTD #199125) failed biennial required AOGCC MIT-IA on 08/17. The well has been shut in and freeze protected and will not be put on injection without prior approval from AOGCC as per AA AIO 3B.003. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Please see attached 10-426. Plan Forward: 1. Operations Engineer: Evaluate tubing repair / secure. 2. Well Integrity: 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: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, August 6, 2019 7:28 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad AB <AKOPSWellPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWellPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com>; Igbokwe, Chidiebere <Chidiebere.Igbokwe@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@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>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE: Injector X-24A (PTD #1991250) Well barriers restored with tubing patch, MITs passed All, Injector X-24A (PTD #1991250) was made not operable on 4/22/2018 for having anomalous inner annulus repressurization and failing an MIT-IA. A leak detection log was performed on 6/10/2018 and found two tubing leaks at 5,411 and 5,611’ MD. On 7/9/2019 e-line completed setting two tubing patches covering 5,395’-5,425’MD and 5,595’-5,625’MD under AOGCC sundry #319-186. The well passed a subsequent MIT-T to 2,290psi and CMIT-TxIA to 2,390psi confirming well barriers have successfully been restored. At this time the well is reclassified as Operable. An AOGCC MIT-IA will be conducted once the well is on stable injection. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Sunday, April 22, 2018 1:33 PM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC1 Field O&M TL <AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad AB <AKOPSWellPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWellPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Boman, Wade <Wade.Boman@bp.com>; Von Tish, Douglas B <Douglas.VonTish@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@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>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector X-24A (PTD #1991250) failed MIT-IA All, Injector X-24A (PTD #1991250) was put Under Evaluation on 04/21/18 for exhibiting an increase in the inner annulus repressurization rate. On 04/22/18 DHD tried to perform a MIT-IA but observed direct communication with the production tubing while trying to build test pressure. The failed MIT-IA indicates the production tubing has failed. The well is now classified as NOT OPERABLE and must remain shut in, it will be secured with a down hole plug. Please respond with any questions. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 From: AK, GWO Well Integrity Engineer Sent: Saturday, April 21, 2018 10:52 AMTo: AK, OPS EOC Specialists; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Boman,Wade; Von Tish, Douglas B; 'chris.wallace@alaska.gov'Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert,Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; 'Regg, James B (DOA) (jim.regg@alaska.gov)'Subject: UNDER EVALUATION: Injector X-24A (PTD #1991250) change in IA build up rate, must be shut in All, Injector X-24A (PTD #1991250) operates under AIO.3B.003 for having slow TxIA communication when on PWI. The AA specifically references an IA build up rate of 90 psi/day. On 04/20/18 DHD bled the inner annulus from 940 psi to 530 psi. When the bleed was shut in, the pressure climbed from 530 psi to 950 psi in a matter of minutes. The drastic change in buildup rate indicates a change in the mechanical condition of the well and must be shut in accordance with the AA. The well is now classified as UNDER EVALUATION and is on the 28 day clock to further asses the mechanical condition. Please do not have the well online without Well Integrity approval. Plan forward: 1. Operations: Shut in well 2. DHD: Perform MIT-IA 3. Well Integrity Engineer: Additional diagnostics as needed. Please respond if in conflict. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 considersappropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, October 13, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC X-24A PRUDHOE BAY UNIT X-24A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/13/2023 X-24A 50-029-21098-01-00 199-125-0 W SPT 8432 1991250 2250 1119 1130 1128 299 383 341 REQVAR F Austin McLeod 8/17/2023 Two year to MAIP. AIO 3B.003. S/I. 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 X-24A Inspection Date: Tubing OA Packer Depth 1552 2430 1969IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230817185409 BBL Pumped:3.1 BBL Returned:1.9 Friday, October 13, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 AIO 3B.003. James B. Regg Digitally signed by James B. Regg Date: 2023.10.13 16:16:53 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector X-24A (PTD #1991250) MIT-IA Failed Date:Thursday, August 17, 2023 11:59:52 AM Attachments:image001.pngMIT PBU X-24A 08-17-23.xlsx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, August 17, 2023 11:31 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UNDER EVALUATION: Injector X-24A (PTD #1991250) MIT-IA Failed Mr. Wallace, Injector X-24A (PTD #199125) failed biennial required AOGCC MIT-IA on 08/17. The well has been shut in and freeze protected and will not be put on injection without prior approval from AOGCC as per AA AIO 3B.003. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Please see attached 10-426. Plan Forward: 1. Operations Engineer: Evaluate tubing repair / secure. 2. Well Integrity: 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: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, August 6, 2019 7:28 AM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad AB <AKOPSWellPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWellPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com>; Igbokwe, Chidiebere <Chidiebere.Igbokwe@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@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>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: OPERABLE: Injector X-24A (PTD #1991250) Well barriers restored with tubing patch, MITs passed All, Injector X-24A (PTD #1991250) was made not operable on 4/22/2018 for having anomalous inner annulus repressurization and failing an MIT-IA. A leak detection log was performed on 6/10/2018 and found two tubing leaks at 5,411 and 5,611’ MD. On 7/9/2019 e-line completed setting two tubing patches covering 5,395’-5,425’MD and 5,595’-5,625’MD under AOGCC sundry #319-186. The well passed a subsequent MIT-T to 2,290psi and CMIT-TxIA to 2,390psi confirming well barriers have successfully been restored. At this time the well is reclassified as Operable. An AOGCC MIT-IA will be conducted once the well is on stable injection. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Sunday, April 22, 2018 1:33 PM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC1 Field O&M TL <AKOPSGC1FieldOMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad AB <AKOPSWellPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWellPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Boman, Wade <Wade.Boman@bp.com>; Von Tish, Douglas B <Douglas.VonTish@bp.com>; 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@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>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine <Katherine.O'connor@bp.com>; Romo, Louis A <Louis.Romo@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com>; 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov> Subject: NOT OPERABLE: Injector X-24A (PTD #1991250) failed MIT-IA All, Injector X-24A (PTD #1991250) was put Under Evaluation on 04/21/18 for exhibiting an increase in the inner annulus repressurization rate. On 04/22/18 DHD tried to perform a MIT-IA but observed direct communication with the production tubing while trying to build test pressure. The failed MIT-IA indicates the production tubing has failed. The well is now classified as NOT OPERABLE and must remain shut in, it will be secured with a down hole plug. Please respond with any questions. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 From: AK, GWO Well Integrity Engineer Sent: Saturday, April 21, 2018 10:52 AMTo: AK, OPS EOC Specialists; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Boman,Wade; Von Tish, Douglas B; 'chris.wallace@alaska.gov'Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert,Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; 'Regg, James B (DOA) (jim.regg@alaska.gov)'Subject: UNDER EVALUATION: Injector X-24A (PTD #1991250) change in IA build up rate, must be shut in All, Injector X-24A (PTD #1991250) operates under AIO.3B.003 for having slow TxIA communication when on PWI. The AA specifically references an IA build up rate of 90 psi/day. On 04/20/18 DHD bled the inner annulus from 940 psi to 530 psi. When the bleed was shut in, the pressure climbed from 530 psi to 950 psi in a matter of minutes. The drastic change in buildup rate indicates a change in the mechanical condition of the well and must be shut in accordance with the AA. The well is now classified as UNDER EVALUATION and is on the 28 day clock to further asses the mechanical condition. Please do not have the well online without Well Integrity approval. Plan forward: 1. Operations: Shut in well 2. DHD: Perform MIT-IA 3. Well Integrity Engineer: Additional diagnostics as needed. Please respond if in conflict. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently 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 considersappropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1991250 Type Inj W Tubing 1169 1130 1128 Type Test P Packer TVD 8843 BBL Pump 3.1 IA 1552 2430 1969 Interval V Test psi 2211 BBL Return 1.9 OA 299 383 341 Result F Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp North Slope LLC Prudhoe Bay / PBU / X Pad Austin McLeod Ryan Holt 08/17/23 Notes:2 Year AOGCC MIT-IA Per AA AIO 3B.003. Max antipicated injection pressure 2250 psi Notes: Notes: Notes: X-24A Form 10-426 (Revised 01/2017)MIT PBU X-24A 08-17-23 (002) MEMORANDUM TO: Jim Rrk7 ��I P.I. Supervisor i FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 5, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC X -24A PRUDHOE BAY UNIT X -24A Src: Inspector Reviewed By: P.I. Supry jD-- Comm Well Name PRUDHOE BAY UNIT X -24A API Well Number 50-029-21098-01-00 Inspector Name: Brian Bixby Permit Number: 199-125-0 Inspection Date: 8/3/2021 Insp Num: mitBDB210803134120 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well — - x -24A Te In w' — V D T� - 8432 , --- Tubing 1287 1287 ' 1287- — 1287 PTD J 19912 50 —Type Test SPT"ITest psi 2108 -- IA -- ' ----- 523 2349 - 2298 - —'' 2278 -- - BBL Pumped: 5.3 BBL Returned: 5.2 OA 163 362 354 352 Interva� REQvAR 1P/F P Notes: 2 Year MITIA as per AID 3B.003 Thursday, August 5, 2021 Page 1 of 1 RE OOIL RT AND STATE OF ALASKA 7 operations Performed OAS CONSERVATION COMMISSION OF SUNDRY WELL OPERATIONS Abandon ❑ Plug Pe Suspend ❑ rtprations ❑ Plug for Retlnll ❑ Perforate New pgPerforate ❑❑ 2. Operator Name: BP Ex to 3_ Address: P O P ration (Alaska), Inc 4. 8ox 196612q �N'F �'yi temi' Fracture Stimulate ❑ ._ O 1 ^ n n Other Stimulate ❑ Pull Tubing ❑ Repair Well 0' r AlteCasing CIOPeratlons,Ch I shutdg .„� ❑ 7' P Pe D AK 99519-6612 nchorege, Development Props, rtY esignation (Lease Number 8tret192phic 9. Logs (List logs and aut....:. ) ADL 028313 11, PresentWell Condition Summary: Total DepN: 20" x 30" Intermediate2 36-9150 measuretl 10355 measured Effective Depth: true vertical8feet Plugs 309 measured -feet Liner 1458 1p true vertical feet Junk Packer Casing: 8-� - feet Packer Measured depth. Length: Structural Size: True vertical depth: MD: Conductor BB3= Tub 78 Surface 633 20" x 30" Intermediate2 36-9150 13-3/8" measured 9111414 � Liner 309 9-5/8" Liner 1458 71I Perforation Depth: -_ 2-7/8" TVD: Measured depth. 9800-10260 - feet True vertical depth: BB3= Tub feet Packers and SSSV grade, measured and true vertical depth) true vertical depth) (type, measured and Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Work Re-enter Su Well ❑ ange A"'rtl 'IlQarh 9� ❑ Other Set Tubing Patches 27 ❑ Exploratory ❑ 5. Permit to Drill Number ❑ 199-125 Service m 6. API Number: e. Well Name and 50-029-21098-01-00 Number 10 E PBU X -24q reld/Pppls: PZY, PRUDHOE OIL 39-117 38-2671 39-117 36-9150 re measured None � measured tt Net truevertical 88-� feet -_ feet TVD: Burst: 39-117 38-2671 39-117 36-9150 38-2671 8884-9793 36-8714 8894-10352 8470-8754 8479-90,54 12.6# L-80 4d/2"BOT 3- 3H P4-8949 em1 packer No SSSV 8843 SWllad - 5380 6870 7240 8430 Representative Dail Oil -Bbl YAverage Production Prior to well o Gas -Mg or injection Data Aeration: Subsequent to Water -bbl operation: Casing pressure 74. Attachments: (,Wuhan Perzo 0 r✓C 25.0)025. vii, a 25280) 0 Daily Report of Well O 75. Well Class5860 operations Nl after work: 350 Copies of Logs and Surve Ex to ys Run P retory ❑ Printed antl❑ De"IOPment ❑ Electronic Fracture Stimulation 18. Well Status after work: ). I hereby certify that the foregoing is true and Data to the TOR ❑ WINJ CIWAG p im....:_- . - best of my knowledge. Authorized Title: Well Authorized `onn 10.404 Revised 0412017 Date: 34-8530 8432 Collapse: 2670 4760 5410 7500 Tubing Pressure 1820 -_ 187070 Service Stratigraphic ❑ Oil ❑ Gas ❑ WOSPL ❑ NJ ❑ SUSP ❑ SPLUG ❑ Sundry Number or N1A if C.O. Exe 319-I6(p rnpt: Contact O�nfacl Email: Obngewitch- Beau BEAU.OBRIGEWITCHabp com Contact - Phone: .1 rind ***WELL S/I ON ARRIVAL***(Patch Tubing Liner) RIG UP SWCP 4522 6/16/2019 ***CONT ON 6-17-19 WSR*'* ***CONT FROM 6-16-19 WSR***(Patch Tubing Liner) DRIFTED WITH 45KB PKR DRIFT, 25' OF SPACER, LOWER PKR DRIFT (CAL 35.). ALL CLEAR TO 5700' SLM. PULLED 4-1/2" PX -PLUG FROM X -NIPPLE @ 8847' MD.(recovered ipc in plug body) SET 4-1/2" x 2-7/8" NIPPLE REDUCER IN X -NIPPLE @ 8847' MD.(ipc in tools) CONFIRMED GOOD SET W/ 4-1/2" CHECK SET.(sheared) SET 2-7/8" XX PLUG W/ FILL EXT IN NIPPLE REDUCER @ 8847' MD. CONFIRMED GOOD SET W/ 2-7/8" CHECK SET.(sheared) LRS ATTEMPTED FAILING CMIT-TxIA. WE ARE NEEDED ON ANOTHER JOB. 6/17/2019 '**WELL LEFT S/I AND IN LRS CONTROL, PAD -OP NOTIFIED OF STATUS*** **WSR continued from 06-17-2019*** CMIT-TxIA FAILED to 2342/2299 psi, Max Applied Pressure=2500 Target Pressure=2250 psi. Pressured TBG/IA to 2493/2443 psi with 4.09 bbls DSL. CMIT-TxIA lost 29/28 psi in 1st 15 minutes and 26/27 psi in 2nd 15 minutes for a total of 55/55 psi during 30 minute test. Bled TBG/IA to 300/300/40 psi. Hang tags on WV/IA. AFE sign on MV ***FLUID PACKED WELL*** Valve 6/18/2019 ositions=SV,WV,SSV closed MV open CV's OTG FWHP=300/300/40 TWO = 16/13/36. Temp = SI. CMIT-TxIA *** FAILED 4 attempts*** (Patch TBG LNR). T & IA FLs @ near surface. Pumped 9.1 bbls diesel down Tbg & IA to achieve test pressure. CMIT-TxIA failed 3 attempts. Bled TP & IAP from 2391/2389 psi to 5/9 psi in 1 hr 10 mins (gas fluid mix w/ 6.1 bbls returned). Pumped 6.8 bbls diesel down Tbg & IA to achieve test pressure. TP/IAP lost 69/69 psi in the 1 st 15 mins & 48/46 psi in the 2nd 15 mins fora total of 117/115 psi in 30 mins. Established a LLR of 0.2 gals/min @ 2500 psi. Bled TP/IAP from 2501/2502 psi to 10/20 psi (7.1 bbls returned) in 16 mins. Tags hung. Final WHPs = 10/20/40. 6/20/2019 SV, WV, SSV = C. MV=O. IA, OA = OTG. 1650 hrs. *'*WELL SHUT IN ON ARRIVAL**'(ior) PARTIAL RIG UP OF SCHLUMBERGER SLICKLINE UNIT 4521. LAID DOWN FOR NIGHT. 6/28/2019 ***JOB CONTINUED ON 6/29/19 WSR**' ***CONTINUED FROM 6/28/19 WSR***(patch tubing/ liner) EQUALIZE & PULL 2 7/8" XX -PLUG BODY FROM XX NIPPLE REDUCER @ 8847' MD (fill ext full fill) SET 2 7/8" XX PLUG W. 24" FILL EXT IN 4 1/2" x 2 7/8" NIPPLE REDUCER. ATTEMPT TO CMIT Tx IA TO psi WITH A TRIPLEX.**FAIL'*( losses were real similar to previous attempts) EQUALIZE & PULL 2 7/8" XX PLUG & 4 1/2" x 2 7/8" NIPPLE REDUCER FROM 8847' MD ( nipple reducer looks **PLUG AND NIPPLE REDUCER LEFT OUT OF HOLE.*' 6/29/2019 ***WELL LEFT SHUT IN. JOB POSTPONED.'** *'*CONTINUED FROM 6/29/19 WSR***(patch tubing/ liner) SET 4 1/2" x 2 7/8" XX -NIPPLE REDUCER IN X -NIPPLE @ 8847' MD. VERIFIED SET BY SHEARING 4 1/2" CHECKSET ON NIPPLE REDUCER. SET 2 7/8" XX -PLUG IN NIPPLE REDUCER @ 8826' SLM. ATTEMPTED 2 CMIT Tx IA, BOTH FAIL. SET 4 1/2" X-SELCTIVE TEST TOOL IN SLIDING SLEEVE @ 8767' SLM. ATTEMPTED FAILING CMIT Tx IA. LAID DOWN FOR NIGHT. 7/2/2019 ***CONTINUED ON 7/3/19 WSR*** ***CONTINUED FROM 7/2/19 WSR***(patch tubing/liner) SET 4 1/2" X-SLECTIVE TEST TOOL IN SLIDING SLEEVE @ 8773' SLM /8767' MD( the only +correction, 40' different) ATTEMPTED FAILING CMIT Tx IA, PULL 2 7/8" XX PLUG BODY FROM X -NIPPLE REDUCER @ 8826' SLM/ 8847' MD. PULL 4 1/2" x 2 7/8" X -NIPPLE REDUCER FROM 8847' MD. LAID DOWN FOR NIGHT. 7/3/2019 **'WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE'** Daily Report of Well Operations PBU X -24A ***CONTINUE FROM 07/03/2019 WSR*** (patch tubing/ liner) SET 4 1/2" PX PLUG & PRONG IN X NIP @ 8,847' MD MADE 2 ATTEMPTS FOR A CMIT Tx IA TO 2,250PSI (see log) 7/4/2019 ***CONTINUE ON 07/05/2019 WSR*** TWO = 2000/2000/20 TEMP = 60* PPPOT-IC Pack off Y -seal ATTEMPT: Slik-Line (CMIT) testing well with two failing test. Sting into IC test void 1,600 psi on void and 1,870 on T&A. Slick -Line Bleed down TWA to 0 psi, test void tracking T&IA pressures. Secondary seals no longer holding. Bleed T/IA/OA to 0 psi. Monitored for 15 min, no change in pressure. Torque (LDS) to 550 ft/lbs. R/U Packing gun, pump 1/4 J -Stick to 3,500 psi. Unable to pressure test IC void over 3,000 psi (FAIL). Slick -Line 7/5/2019 IPressure T&IA to 2,500 psi for 30 min. IC test void stayed at 0 psi. ***CONTINUE FROM 07/04/2019 WSR*** (patch tubing/ liner) ATTEMPT CMIT TO 1,800 PSI (unable to meet stabilization criteria) CAMERON REP TORQUED LOCKDOWNS & ENERGIZED Y SEALS ON CASING HANGER MULTIPLE ATTEMPTS AT A CMIT TO 2,250 PSI (same results as the 1,800 psi test, see log) PULLED PRONG & 41/2" PX PLUG BODY FROM X NIP @ 8,847' MD 7/5/2019 ***CONTINUE ON 07/06/2019 WSR*** ***CONTINUE FROM 07/05/2019 WSR*** (patch tubing/ liner) SET 4 1/2" x 2 7/8" NIPPLE REDUCER IN X NIP @ 8,847' MD RAN 4 1/2" CHECKSET TO NIPPLE REDUCER @ 8,847' MD (sheared) SET 2 7/8" XX PLUG IN NIPPLE REDUCER @ 8,847' MD PERFORMED PASSING CMIT T x IA TO 2,390 PSI(2,500 max applied pressure) 7/6/2019 ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** ***WELL SHUT IN ON ARRIVAL*** SET 45 KB FLOGUARD PATCH FROM 5595' - 5625' ME, CCL TO ME 8.9'. CCL STOP DEPTH 5486.1' SET 45 KB FLOGUARD PATCH FROM 5395'- 5425' ME, CCL TO ME 8.9'. CCL STOP DEPTH 5386.1' PERFORM PASSING 2290 PSI MIT -T (see data tab for details) LOGS RRELATED TO PDS LDL DATED 06-09-2018 7/9/2019 ***JOB COMPLETE, PAD OP NOTIFIED*** ***WELL S/I UPON ARRIVAL*** (patch tubing/liner) EQUALIZE AND PULL 2-7/8" XX PLUG FROM NIPPLE REDUCER @ 8,847' MD 7/16/2019 ***WELL 3/1 ON DEPARTURE*** T/1/0=500/vac/0 Temp=S/I (LRS Unit 76-HPBO:Op's Request) Pumped 4 bbls 60/40 down TBG, TBG pressured up to 2500 psi. TBG eventually fell off, pumped an additional 34 bbls 60/40 verify if TBG is clear. Pumped 290 bbls of 120* 1% KCL down TBG to load, freeze protected surface lines with 3 bbis 60/40. Notify 8/6/2019 pado to POI. Final WHP's=550/4/32 TWO = 1620/50/400. Temp = 140*. AOGCC MIT -IA PASSED to 2438 psi. Max Applied Pressure = 2500 psi, Target pressure = 2250 psi (Witnessed by Lou Laubenstein). IA FL @ near surface. Used 9.1 bbl of diesel to pressure IA to 2500 psi. IAP decreased 45 psi in 1st 15 min and 10 psi in 2nd 15 min for a total loss of 55 psi in 30 min. Bled IAP from 2438 psi to 50 psi in 20 min (7.6 bbls). Tags hung. Final WHPs = 1640/50/410. 8/13/2019 1 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 12:00. 13-3/8" CSG, 72#, L-80, ID = 12.347 2671' Minimum ID = 2.372" @ 8894' 2-7/8" LINER 4-1/2" TBG, 12.6#, L-80, D = 3.958' 8949' 9-5/8" CSG, 47#, L-80, D = 8.681" H 9150' PERFORATION SUMMARY REFLOG: PDS ND/GR ON 01/18/00 ANGLE AT TOP PERF: 76"Qa 9800' Note: Refer to Production DB for historical pert data SIZE SPF KrERVAL Opn/Sgz DATE 2" 6 9800- 9820 O 11/26/01 2" 4 10205-10260 C 01/19/00 TOPOFWHPSTOCK 9190' 7" LNR 26#, L-80, .0383 bpf, D = 6.276"9717' /� a SAFETY NOTES: H28 READINGS AVERAGE 125 ppm XWHEN ON MREUIRES 24A MI. WELL AINGLEELL > 70Q@ 9321 A SSSV WHEN ON rT m SSV NP, D = 3.813' PATCH, D = 2.45"(7-9-19) PATCH, D = 2.45" (7-9-19) r, RIFFVFi)=saw 881��PBR, TBG, SEAL ASSY 8843' 9-5/8" x 4-1/2" BOT -31-1, PKR D = 3.958- 8847' 4-12' OTIS'X' NIP, D = 3.813' 8847' 4-12" X 2-7/8' X NP REDUCER D= 2.313- (07106/19) 8883' H 4-12" OTIS'X' NP, D = 3-813- 8916' H4-1/2" OTIS MILLED XN NP, D = 3.800" 1 8949' H4-1/2- TBG TAL D=3.958' 8980' AMD TT LOGGED 07/29/90 MLLOUT WINE- TO 9200' 10087' 2-1/8'BKRBP(1125/01) 1 10226' 1 1 2-7/8" LMR, 6.16#, L-80-0055 bpf, D= 2.372" 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 04/21/94 ORIGINAL COMPLETION 06/13118 CJWJMD ADDED MISSNG NP PERTALLY 01M9100 CJS CTD SIDETRK COMPLETION 08/06/19 EPD/JMD SET NP RED, SET PATCHES 02/16/11 MB/JMD ADDED SSSV SAFETYNOTE 0120/12 TMN/JMD ADDED H2S SAFETYNOTE 02/19114 CW/PJC PERF CORRECTION 06/13/18 CJWJMD SET PX PLUG (06/10118) I PBTD I PRUDHOE BAY UNIT WELL: X -24A PERMIT No: rl991250 API No: 50-029-21098-01 BP Exploration (Alaska) MEMORANDUM TO: JimRegg 714Lrl ebb l 11 P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector Well Name PRUDHOE BAY UNIT X -24A Insp Num: mitLOL190814152857 Rel Insp Num: State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, August 19, 2019 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. X -24A PRUDHOE BAY UNIT X -24A Ste: Inspector Reviewed By: P.I. Supry J1 P— Comm API Well Number 50-029-21098-01-00 Inspector Name: Lou Laubenstein Permit Number: 199-125-0 Inspection Date: 8/13/2019 Packer Depth Well X -24A 'Type Inj w TVD 8432 PTD 1991250 Type Test SPT Test psi 2108 BBL Pumped: 9.1 '113111, Returned: 1 7.6 ' Inter OTHER p/F I P Notes: MIT -IA post patch per Sundry 9 319-_186 tti rr 6tt(e- (G'7'ZcIA6; S14,4-" 1/\ 3t tlice `f � ( ZC71 i3 Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing_ 1618 1640 - 1640 1640 IA 48 2493 - 2448 - }138 - QA 404 688 600' Monday, August 19, 2019 Page 1 of 1 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWeIISiteEnginee@bp.com> Sent: Tuesday, August 6, 2019 7:28 AM To: AK, OPS EOC Specialists; Ak, OPS GC1 Field PTL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Glasheen, Brian P; Igbokwe, Chidiebere; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED) Subject: OPERABLE: Injector X -24A (PTD #1991250) Well barriers restored with tubing patch, MITs passed All, Injector X -24A (PTD #1991250) was made not operable on 4/22/2018 for having anomalous inner annulus repressurization and failing an MIT -IA. A leak detection log was performed on 6/10/2018 and found two tubing leaks at 5,411 and 5,611' MD. On 7/9/2019 a -line completed setting two tubing patches covering 5,395'-5,425'MD and 5,595'-5,625'MD under AOGCC sundry #319-186. The well passed a subsequent MIT -T to 2,290psi and CMIT-TxIA to 2,390psi confirming well barriers have successfully been restored. At this time the well is reclassified as Operable. An AOGCC MIT -IA will be conducted once the well is on stable injection. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GW6,We111I Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Sunday, April 2Z-2018.1:33 PM To: AK, OPS EOC Specialists <A CSpecialists@bp.com>; AK, OPS GC1 Field O&M TL <AKOPSGC1Fie IdOMTL2@bp.com>; AK, O ellpad Lead <AKOPSGC1Wel[pad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Con s <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad AB <AKOPSWeliPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWeII bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESG tWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <A CCEOCTL@bp.com>; Boman, Wade <Wade.Boma n@bp.com>; Von Tish, Douglas B<Douglas.VonTish@bp.com>;'chris.w a@alaska.gov' <ch ris.wa (lace@a laska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletions5upt@bp.com>; AK, GWO DHD Well <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWelllntegrityEnl THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU X -24A Permit to Drill Number: 199-125 Sundry Number: 319-186 Dear Mr. Obrigewitch: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Www. o o g c c. a l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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. Sin erely, Daniel T. Seamount, Jr. Commissioner DATED this f � day April, 2019. RBDMSJ±A/APR I b 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS APR In 7010 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 • ra nsshutdown ❑ lil�l`�.."., e., Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Tubing Patch x 2 10, 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class Exploratory ❑ Development ❑ 5. Permit to Drill Number. 199-125 3, Address, P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic ❑ Service ®• 6. API Number: 50-029-21098-01-00. 7. If perforating: What Regulation or Conservation Order govems well spacing in this pool? e. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU X -24A 9. Property Designation (Lease Number): 10. Field/Pools: ADL 0028313 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(n): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10355 9056 8847 8435 8847.10087.10226 None Casing Length Size MD TVD Buret Collapse Structural Conductor 78 20" x 30" 39-117 39-117 Surface 2366 13-3/B" 38-2671 38-2671 5380 2670 Intermediate 1 9114 9-5/8" 36-9150 36-8714 6870 4760 Liner 309 7" 8884-9193 8470 - 8754 7240 5410 Liner 1458 2-7/8" 8894-10352 8479 - 9054 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9800- 10260 8839-8991 4-1/2" 12.6/1 L-80 34- - 8949 Packers and SSSV Type: 41/2' BOT 3H Perm Packer Packers and SSSV MD (ft) and TVD (ft): 8843/8431 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 ' 14. Estimated Date for Commencing Operations: April 17, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Otingewitch, Beau be deviated from without prior written approval. Contact Email: BEAU,OBRIGEWITCHflbp.com Authorized Name: Obngewitch, Beau Contact Phone: +1 907 564 4854 Authorized Title: All Integdty Engineer Authorized Signature: L 7) � Date: / COMMISSION USE ONLY' Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /✓`7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test LR" Location Clearance ❑ Other: ff APR 16 2019 Post Initial Injection MIT Req'd? Yes 11IBDMS No ❑ , I Spacing Exception Required? Yes ❑ No Subsequent Form Required: if)-r"i 0 i 1 APPROVED BYTHE r �, � Approved by: COMMISSIONER COMMISSION Date. I �— 6 / I ORIGINAL .�,�p 's1lt'RW �RI? Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval.chments in Di to 10-403 Sundry Application for Well PBU X -24A PTD#199-125 Expected Start Date: April 17, 2019 Current condition of well: Water Injection Well, Not Operable, Offline: Water Injection Rate: Injection Pressure: Shut-in Wellhead Pressure: 2400 psi Reservoirpressure: 3200 psi Well objective(s): Set patches over known tubing leaks at 5,411' and 5,611' to restore tubing integrity and return well to Operable status. Proposed program: 1. Drift for patch 2. Pull Plug from 8,847' 3. Set Nipple Reducer and Plug 4. Load Tubing 5. CMIT-TxIA to 2,500 psi: Testing Nipple Reducer and Plug 6. Set Patches: a. 5,595'— 5,625' b. 5,395'-5,425' 7. MIT -T to 2,500 psi: Verifying restoration of Tubing Integrity 8. AOGCC MIT -IA to 2,500 psi: While Injecting BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU X -24A PTD#199-125 Annotated Reference Log (LDL): rrram� m a v w = �amrm -yy o z n K'OVMMMMo j g a m m A company BP Exploration (Alaska), Inc. ; WfU ' q o M -T i,g 3 0 0 = Well X - 24A > rE m N _ a m Field Prudhoe Bay s ` S g $ F z g$ m 1 e A �- m - Borough North Slope G 0 " State Alaska ; D C W O T (7 1 W _ m. w q lA tai�- _ 3 n 4 Lmn m�qW czc 3 _ p9 3 = 3 m N Z -U x CO su�tl1?a 0mo :� B O O m O {� �4 Nr NA JR Dw1 my NNi x � D � m888: m�m� C/)r r m O m z o -U D D O U 'n to O Z 9 Z ti ewgsa -� r— r D y 3 "g o m D r N p y Cir) Cn C a 2a 3 >D .__. m o �.otim croac o �oPy Z m ZZ -1 -< imp b W j «<Fold Here >>> BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU X -24A PTDN199-125 -._. -1 r; - �rr� r.•. .."Wrr.re .. ... .bnntb }I/'n .er..an� Mr r) ' w,{- m_orer ernent- gx•'u0 { r. v.rryri t, Iwr4,v� /.. ...,r rn... r• .nr.- r.. n i� y4 Ic� � t r 1 1� NNlb1l�-M^ l<M �.,- Crl.�n'•nfX'4 _ _� � nrr > K1 iv S\ Ips IOyT• � T .rr.r.a Ir .riven n.. -... r.,. 4n.n-, .•�. -._. -1 r; - �rr� r) ' w,{- m_orer ernent- gx•'u0 { t, i 5} i� y4 Ic� � t r 1 1� > K1 iv S\ Ips IOyT• � T .rr.r.a Ir .riven n.. -... r.,. 4n.n-, .•�. ~� L -._. -1 r; - �rr� BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 i 5} C 1� > K1 Ips IOyT• � .rr.r.a Ir .riven n.. -... r.,. 4n.n-, .•�. BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 TT1ff = 4' CNV WHIFFAD= ACTUATOR= KB. ELFV = NCEVOY BAKER 7523' BF 9 -EV = KOP= _ 39.83' 47OU Nix Angle = 9T6 9570 - 570'Datum Do t ur ND= 9931 Datum ND= 8800 -SS, D= 12.347' 1--1 2671' Minimum ID = 2.372" @ 8894' 2-7/8" LINER TOP OF 7' LNR 8893' OF 2710-LNRI-F 8894- 1/2- TBG, 12.6#, L-80, ID = 3.958' I-� 8949' 9-5/8' CSG, 47# . L-80, D = 8.681' 9160' PERFORATION SUTA MRY RE= LOG. PDS NYGR ON 01/18/00 ANGLE AT TOP FERE: 76° Q 9800' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2' 6 9860 - 9820 O 11126101 2' 4 10205 - 10260 C 01/19)00 7- LNR, 26#, L-80, .0383 bpf, D = 6.276' 1-1 9717' X -24A SAFETY NOTE: H25 READINGS AVERAGE 126 ppm WHEN ON MI. WELL REQUIRES A SSSVWNEN ON ML WELL ANGLE> -70° 9321'. 11 _ 2148' 4-1/2' OTIS DBE SSSV NP, ID= 3-813' I 8762 I 8819' 1 PBR, TBG, SEAL ASSY DATE REV BY COMMENTS 8$43' 9-5/8' x 4-1/2' BOT -3H, PKR D = 8847' 8847 8883' 4-1/2' OTIS 'X' NP, ID = 3.813' 4-1/2' PX PLUG (06/10/18) 4-112' OTIS'X' NP, D = 3.813' 14-1/2" OTIS MILLED XN NP, D = 3.800' 1 8949' 1--14-1/2' TBG TAL D = 3.958' 8980' EL�® 07/29/90 MLLOUT V1TaDW- 9193' TO 9200' 10087' 2-1/8-BKRBP(11/25101) .0055 bp1, ID = 2.372' 10357 DATE REV BY CO&fA3NTS DATE REV BY COMMENTS 04121 M4 ORIGINALCOMPLETKIN 02/16/11 M3/JMD ALn®SSSV SAFETY NOTE 01119/00 CJS CTD SIDETRK COM PLETION 01/20/12 TMWJMD ADD®F12S SAFETY NOTE 06118/01 RN'iP CORE ECTIOFS 02/19/14 CW/ PJC PERF CORRECTION 11/28/01 ATD'KAK PEWS; BP, FILL 06/13/18 CJNJW SET PX PLUG (06/10/18) 11/20/03 JDWM-P CLOSE PERF 08113/18 CJNJMJ ADDED MISSING NP PER TALLY 03/05109 FMSV TREE ClO(02122/09) PBTD H 10321' PRUDHOE BAY UWT WELL' X -24A PERMT M: '1991250 ARM: 50-029-21098-01 SM 6, TION, R14E, 244' NSL 8 402 WTi BP Exploration (Alaska) 10-403 Sundry Application for Well PBU X -24A PTD#199-125 Post Work Wellbore Schematic: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, April 21, 2018 10:52 AM To: AK, OPS EOC Specialists;AK, OPS GC1 Field O&M TL;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad AB;AK, OPS Well Pad CX;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Boman,Wade;Von Tish, Douglas B;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J; Regg,James B (DOA) Subject: UNDER EVALUATION: Injector X-24A(PTD#1991250) change in IA build up rate, must be shut in Attachments: X-24A.pdf All, Injector X-24A(PTD#1991250) operates under A10.3B.003 for having slow TxIA communication when on PWI.The AA specifically references an IA build up rate of 90 psi/day.On 04/20/18 DHD bled the inner annulus from 940 psi to 530 psi.When the bleed was shut in,the pressure climbed from 530 psi to 950 psi in a matter of minutes.The drastic change in buildup rate indicates a change in the mechanical condition of the well and must be shut in accordance with the AA. The well is now classified as UNDER EVALUATION and is on the 28 day clock to further asses the mechanical condition. Please do not have the well online without Well Integrity approval. Plan forward: 1. Operations:Shut in well 2. DHD: Perform MIT-IA 3. Well Integrity Engineer:Additional diagnostics as needed. Please respond if in conflict. Andrew Ogg Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 WNW 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,August 07, 2016 6:38 PM To: AK, OPS GC3&PCC OSM;AK, OPS GC3 Facility OTL;AK, OPS GC3 Field OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX; Boman,Wade;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO SUPT Well Integrity; Regg,James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: OPERABLE:Injector X-24A(PTD#1991250)Administrative Approval 36.003 for Water Only Attachments: X-24A aio3B.003 08-02-16.pdf All, Injector X-24A(PTD#1991250)was placed Under Evaluation on 06/04/16, due to anomalous IA pressure trends while on water injection. During the evaluation period,the well was confirmed to have slow TxIA communication. On 08/02/16, the AOGCC granted Administrative Approval,AIO 3B.003,allowing water infection only,subject to conditions specified in the attached AA. The well is reclassified as Operable,and may be brought online in water only injection service. Please be aware of the fluid-packed annuli. Thanks, t„ NB JAN 32017, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWelllntegrityCoordinator@BP.com From: , WO SUPT Well Integrity Sent: Saturday, • 30, 2016 6:54 AM To: AK, OPS GC3&PCC • • K, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; •..'el, Ryan; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; AK, RES GPB West Wells Opt Engr; AK, RES GPB East ; Opt Engr; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Boman, Wade; 'chris.wallace@alaska.g. Cc: AK, GWO DHD Well Integrity; AK, GWO Projects ►- tegrity; AK, OPS FF Well Ops Comp Rep; Dickerman, Eric; 'Regg, James B(DOA) (jim.regg@alaska.gov)'; Sternicki, Olive Subject: UPDATE UNDER EVALUATION: Injector X-24A (PTD #19• 0 Administrative Approval for slow TxIA communication All, Injector X-24A(PTD#1991250)extended monitoring period indicates the well does have slow Tu•''; x Inner Annulus pressure communication. Cover letter and technical justification for administrative approval for contin -. operation 1 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday,July 30, 2016 6:54 AM To: AK, OPS GC3&PCC OSM;AK, OPS GC3 Facility OTL;AK, OPS GC3 Field OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX; Boman,Wade;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Dickerman, Eric; Regg,James B (DOA); Sternicki, Oliver R Subject: UPDATE UNDER EVALUATION: Injector X-24A (PTD#1991250)Administrative Approval for slow TxIA communication All, Injector X-24A(PTD#1991250) extended monitoring period indicates the well does have slow Tubing x Inner Annulus pressure communication. Cover letter and technical justification for administrative approval for continued operation was submitted to the AOGCC on July 29 2016.The AOGCC agreed with a proposal to leave the well on stable water injection while processing this application.The well remains classified as Under Evaluation and may remain on water injection for an additional 28 days until the application is processed. Please call with any questions or concerns. Ryan Holt fi.,'tE'ri7,z(' tee: BP as Well InGlIv Global Wells SCANNED CCS Organization Office: 907.659.5102 From. • GWO SUPT Well Integrity z Sent: Satur•. July 02, 2016 5:52 AM To: AK, OPS GC3: = OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, :c • A; Daniel, Ryan; AK, GWO SUPT Special Projects; AK, GWO SUPT Slickline; AK, RES GPB West Wells Opt Engr; AK, RES ' ast Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Boman, Wade; 'chris.wallace• . : a.gov' Cc: AK, GWO DHD Well Integrity; AK, GWO P •'- Well Integrity; AK, OPS FF Well Ops Comp Rep; Dickerman, Eric; 'Regg, James B (DOA) (iim.regg@alaska.gov)'; Stern Oliver R Subject: UPDATE UNDER EVALUATION: Injector X-24A(• & #1991250) - Evaluate Possible TxIA Communication All, Injector X-24A(PTD#1991250)was shut in June 6th 2016 as intervention and integri work followed.The well has remained shut in as part of field proration over the last week.The 28 day Under Evaluati• • clock will be reset to allow an additional period of monitoring while the well is on injection. Plan Forward: 1. Downhole Diagnostics: MIT-IA—Passed 06/07/16 2. Wellhead Tech: Perform Tubing Packoff Test—Completed 06/17/16 3. Downhole Diagnostics/Wellhead: Monitor re-pressurization and wellhead seals while on injection 1 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Wednesday,July 27, 2016 8:05 PM To: AK, GWO SUPT Well Integrity Subject: RE:X-24 (PTD 1991250) extended monitoring period Ryan, Additional 28 days injection is agreeable. Thanks Chris SC W EB 2.017 Original message From: "AK, GWO SUPT Well Integrity" <AKDCWellIntegrityCoordinator@bp.com> Date: 07/27/2016 4:29 PM (GMT-09:00) To: "Wallace, Chris D (DOA)" <chris.wallace@alaska.gov> Cc: "AK, GWO SUPT Well Integrity" <AKDCWe1lIntegrityCoordinator@bp.com> Subject: X-24 (PTD 1991250) extended monitoring period Chris, X-24 is approaching the end of the extended 28 day monitoring period approved late last month. We are satisfied that the well does in fact have very slow tubing x inner annulus pressure communication on water injection. As such, we are drafting a cover letter and technical justification for administrative approval which should be delivered to the AOGCC by Friday July 29`x'2016 . My preference is to keep the well on stable water injection throughout this process. This would eliminate cost/ risk associated with and inherent to well start up/shut down, such as freeze protection. Therefore, I propose an additional 28 days period of injection to allow for processing of the administrative approval application. Please let me know at your earliest convenience or feel free to call at any time. Thanks, Ryan Holt(Filling in for Jack Lau) Well Integrity Superintendent—GWO Alaska (Alternate:Adrienne McVey) 0: (907)659-5102 1 • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday,July 02, 2016 5:52 AM To: AK, OPS GC3&PCC OSM;AK, OPS GC3 Facility OTL;AK, OPS GC3 Field OIL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX; Boman,Wade;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Dickerman, Eric; Regg,James B (DOA); Sternicki, Oliver R Subject: UPDATE UNDER EVALUATION: Injector X-24A (PTD#1991250) - Evaluate Possible TxIA Communication All, Injector X-24A(PTD#1991250)was shut in June 6th 2016 as intervention and integrity work followed.The well has remained shut in as part of field proration over the last week.The 28 day Under Evaluation clock will be reset to allow an additional period of monitoring while the well is on injection. Plan Forward: 1. Downhole Diagnostics: MIT-IA—Passed 06/07/16 2. Wellhead Tech: Perform Tubing Packoff Test—Completed 06/17/16 3. Downhole Diagnostics/Wellhead: Monitor re-pressurization and wellhead seals while on injection Please call with any questions or concerns. Ryan Holt (AIttrnate- tee G/ey) BP Alaska-Well Integrity GVVGlobal Wells Organization Office: 907.659.5102 alt'WDEC092016 From: AK, D&C - ntegrity Coordinator Sent: Saturday, June 04,"' 6 8:15 AM To: AK, OPS GC3&PCC OSM; A .'S GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Danie, , an; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB Wes -IIs Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad C', 'man, Wade; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Wel -_rity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Dickerman, Eric; 'Regg, James B 0,4 (jim.recigOalaska.gov)'; Sternicki, Oliver R Subject: UNDER EVALUATION: Injector X-24A (PTD #1991250) - Evalua - 'ossible TxIA Communication All, Injector X-24A(PTD#1991250) is showing anomalous inner annulus pressure trends while on wat- section. The well has been reclassified as Under Evaluation for additional diagnostics. 1 • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Thursday,June 30, 2016 10:08 AM To: 'AK, GWO SUPT Well Int rit ' Subject: RE:X-06 (PTD 1800090 /X-24 (PTD 1991250lxtended monitoring period Ryan, Approved for up to additional 28 days monitoring and diagnostics. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission DEC 1 6 ZG1BEll , 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: AK, GWO SUPT Well Integrity [mailto:AKDCWelllntegrityCoordinator©bp.com] Sent: Wednesday, June 29, 2016 7:10 AM To: Wallace, Chris D (DOA) Cc: AK, GWO SUPT Well Integrity Subject: X-06/X-24 extended monitoring period Chris, I would like to propose an additional 28 day monitoring period for both X-06 and X-24. Both wells were shut in earlier in the month and have not been brought on due to proration.An extended monitoring period would be used to continue diagnostics and continue evaluation of any re-pressurization observed while on MI injection. Please let me know at your earliest convenience or feel free to call anytime. Thanks, Ryan Holt(Filling in for Jack Lau) Well Integrity Superintendent—GWO Alaska (Alternate:Adrienne McVey) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWellIntegritvCoordinator@BP.com 1 • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, June 04, 2016 8:15 AM To: AK, OPS GC3&PCC OSM;AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers; AK, OPS Well Pad CX; Boman, Wade;Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Dickerman, Eric; Regg, James B (DOA); Sternicki, Oliver R Subject: UNDER EVALUATION: Injector X-24A (PTD #1991250) - Evaluate Possible TxIA Communication Attachments: Injector X-24 (PID# 1991250) TIO and Injection Plots.docx All, Injector X-24A(PTD#1991250) is showing anomalous inner annulus pressure trends while on water injection. The well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: Evaluate TxIA Communication 1. Downhole Diagnostics: Perform MIT-IA 2. Downhole Diagnostics: Bleed inner annulus pressure and monitor build up rate 3. Wellhead Tech: Perform Tubing x Inner Casing Packoff Test 4. Well Integrity Engineer: Additional diagnostics as needed Please respond if in conflict with plan forward. Thanks! Jack Lau sCIMED JUN 1 3 2016 (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent W: 907.564.5102 C: 907.943.0296 H: x2376 1 • • i Injector X-24(PTD#1991250) TIO Plot June 4, 2016 Well x u 4 XE7 XL 4D-1bQ -.—a 00A Or r 1 C! V I 0306'16 0311'15 01•16 16 MS 16 60.At'1f 069616 011516 017116 G624'16 0906 16 061116 05261b 052716 O6%3':£ Injection Plot June 4, 2016 Hell X 24 ,IOC %A —, �1. - \ : 1 40C 13.104 11W I NeVOW ,160L 61ax e060 16 f _6 IA 1 o a 404 1 . MA, OL%:16 03"L'h OLOiIi 04.N OLWM 01.1414 .2..--� .k26:5 OStt,ib CSnL% CSNYN 05.27 16 060146 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,December 28,2015 P.I. upgg � SUBJECT: Mechanical Integrity Tests P.I.Supervisor ��C� ��' Zd'�!S g y BP EXPLORATION(ALASKA)INC. X-24A FROM: Guy Cook PRUDHOE BAY UNIT X-24A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X-24A API Well Number 50-029-21098-01-00 Inspector Name: Guy Cook Permit Number: 199-125-0 Inspection Date: 12/22/2015 Insp Num: mitGDC151222190659 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ------ ------- Well X 24A - Type Inj W TVD 8432 Tubing 1430 1430 - 1436 . 1431 PTD' 1991250 - Type Testf SPT Test psi 2108 IA 800 2502 2500 , 2498 - Interval 4YRTST --- P/F P OA 0 2 0 I_ Notes: 1.2 bbls pumped to test. MITIA. Kevin Parks not on site. Beau Obrigewitch,a well integrity engineer,on site as operator rep. SCANNED SEP 1 6 2016 Monday,December 28,2015 Page 1 of 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Friday, October 30, 2015 9:45 AM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; Regg,James B (DOA) Subject: Injector X-24A (PTD #1991250) Permission to Operate with Inner Annulus Anamoly Attachments: Injector X-24A (PTD#1991250) TIO and Injection Plot.docx;Injector X-24A (PTD # 1991250) Wellbore Schematic.pdf Chris, As per our discussion yesterday, Injector X-24(PTD#1991250) is a WAG well currently on water that displays an anomalous pressure trend on the inner annulus. When bled,the inner annulus will rapidly repressure before stabilizing between 600 to 700 psi. The well recently passed a MIT-IA to 2500 psi on October 16, 2015 indicating two competent barriers to formation. A PPPPOT-T performed on April 06, 2014 failed. A subsequently leak path evaluation performed on the wellhead on May 03, 2014 indicated a suspected slow leak through the primary wellhead seal. Recent bleed history: 09/26/15: Bled IA from 1020 psi to 300 psi, 25 mins, 1 bbl fluid 09/28/15: IA increased 350 psi in two days to 670 psi,wellhead temperature and injection pressure decreased 10/06/15: Bled IA from 1060 psi to 250 psi, 10 mins, %2 bbl fluid 10/07/15: IA increased 320 psi in 24 hours, wellhead temperature and injection rate were unchanged 10/13/15: Bled IA from 580 psi to 200 psi, 10 mins, 3/ bbl fluid 10/14/15: IA increased 400 psi in 24 hours, wellhead temperature and injection rate were unchanged 10/16/15: MIT-IA to 2500 psi passed BP would like permission to continue operation of this well as a passing MIT-IA was obtained and pressures are manageable well below MOASP. A copy of the wellbore schematic as well as 90 days of both injection and TIO plot. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNEV APR 2I206 (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinatorpBP.com 1 • Injector X-24A(1991250) TIO Plots October 30, 2015 Well)1 N l 1 —Mg ; —M OA OCA 55.5 00 1 iiiIhIrLi r 3095 16.96,5 061215 062011 022715 040215 0915,5 0421215 022415 16916 ,666'15 ,5156 162215 1029,5 Injection Plot MNI MN 1.690 -5. E t I(7n\V/^\V// 11f0. -6503 1 000.0---"-----...\______j i ! ''"--'\"--V :1 050 ' 1 A5 -5.6 65tl 0008 60 :5 —aa.' soo :150D soo .3900 3% :3500 200 3030 AO J \ T :,50D :,000 0200'15 069615 061115 056015 *2915 09/0165 02615 061715 0924'15 105,:15 606 12 1711 .22 le 102915 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, October 22, 2015 12:22 PM To: AK, OPS GC3&PCC OSM;AK, OPS GC3 Facility OTL;AK, OPS GC3 Field OTL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX; Boman, Wade; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg,James B (DOA) Subject: OPERABLE:Injector X-24A(PTD#1991250) MIT-IA Passed Attachments: Injector X-24A (PTD#1991250)TIO and Injection Plot.docx All, Injector X-24A(PTD#1991250)was showing anomalous inner annulus pressure trends while on water injection. An MIT- IA passed on October 16, 2015 confirming two competent barriers in the wellbore. This well has been reclassified as Operable. A copy of the TIO and Injection plots are included for reference. Please call with any questions or concerns. Thank you, Kevin Parks (Alternate: Whitney Pettus) SCANNED AUG 1 7 2016 BP Alaska Well Integrity Coordinator GINGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: A , ;; Well Integrity Coordinator Sent: Tuesday, I :.-r 06, 2015 9:15 PM To: AK, OPS GC3&PCC 0 :K, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; 0. "-I Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB '- r ells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Boman, Wade; 'c " . .(lace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well In • ". Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; -=a James B (DOA) (jim.regg©alaska.gov); Sayers, Jessica; Dickerman, Eric Subject: UNDER EVALUATION: Injector X-24A (PTD #1991250) Inner Annulus Repressu " "•n All, 1 s. - 0 • Injector X-24A(PTD#1991250) Injection Plot I. filh\ ,,• 1. aM ------\\-\11 •f CIX'i =:-M nX F -ro e CO OW 4 306 TM o.•x 0")x aw as a1s o6�b A a16n 4Mn aN'+ 0tat5 mw�. .cam I 701n5 It.u+!'� 1 Injector X-24A(PTD#1991250)TIO Plot I I ,m, +r ma -_.-. m. 111 -.-caw aro J m,mn VOWS umu OM. asxns un. .1213 MN; WW1! aw»a OM. wmu wwn ,m.iS • S Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, October 06, 2015 9:15 PM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; Boman, Wade; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA); Sayers, Jessica; Dickerman, Eric Subject: UNDER EVALUATION:Injector X-24A (PTD #1991250) Inner Annulus Repressuriztion All, Injector X-24A(PTD#1991250) is showing anomalous inner annulus pressure trends while on water injection. The well has been reclassified as Under Evaluation for additional diagnostics. Plan Forward: 1. Downhole Diagnostics: Perform MIT-IA 2. Well Integrity Engineer: Bleed inner annulus pressure and monitor build up rate for 3 to 5 days 3. Well Integrity Engineer: Additional diagnostics as needed Please call with any comments or concerns. Thank you, SCANNED AUG 0 4 2016: Whitney Pettus (Alternate: Kevin Parks) BP lAllaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, October 16, 2013 9:00 PM To: AK, OPS GC3 Facility& Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; Black, Brittany; Wallace, Chris D (DOA); AK, OPS Well Pad CX; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: OPERABLE: Injector X-24A(PTD#1991250) Passing MIT-IA and PPPOT-IC All, Injector X-24A(PTD#1991250) had a passing MIT-IA o 2,500 psi on September 23, 2013, as well as a passing PPPOT-IC on October 10, 2013.The well has been monitored has been monitored for over a month, and shows no signs of repressurization. At this time the well is reclassified as Operable, and may remain online as needed. Please call with any questions. Thank you, Laurie Climer NN i; �, BP Alaska - Well Integrity Coordinator Global Wells V Y Y Organizat+on WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D&C Well Integrity Coordinator Sent: Friday, September 20, 2013 4:50 PM To: AK, OPS GC3 Facility& Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; Black, Brittany; 'chris.wallace @alaska.gov'; AK, OPS Well Pad CX Cc: AK, D&C DHD Well Integrity Engineer; Walker, Greg (D&C); Holt, Ryan P; 'jim.regg @alaska.gov' Subject: UNDER EVALUATION: Injector X-24A (PTD #1991250) Possible Inner Annulus Repressurization All, Injector X-24A(PTD#1991250) exhibited possible inner annulus repressurization during routine monitoring on 09/19/2013. The well is online and injecting produced water. The well is reclassified as Under Evaluation and is placed on a 28 day clock to facilitate evaluation, and may remain on injection during the evaluation period. Plan forward: 1. DHD: MITIA to 2500 psi 1 A copy of the TIO plot and wellbore schematic are included. Please call with any questions. Thank you, Jack Disbrow BP Alaska -Well Integrity Coordinator G VVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator @bp.com 2 ,a L:t v . STATE OF ALASKA • AL A OIL AND GAS CONSERVATION COMM•N AUG 12 2G i3 REPORT OF SUNDRY WELL OPERATIONS :,P 1.Operations Abandon U Repair Weill Li Plug Perforations U Perforate ❑ Other Li Bright Water Performed: Alter Casing ❑ Pull TubingE Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdowin❑ Stimulate-Other ❑ Re-enter Suspended WeIII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 199-125-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service IR 6.API Number: Anchorage,AK 99519-6612 50-029-21098-01-00 ; 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028313 PBU X-24A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071). 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: Total Depth measured 10355 feet Plugs measured 10087 feet true vertical 9055.72 feet Junk measured None feet Effective Depth measured 10087 feet Packer measured 8843 feet true vertical 8917.5 feet true vertical 8431.57 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 30-110 30-110 0 0 Surface 2642 13-3/8"72#L-80 29-2671 29-2670.92 4930 2670 Intermediate None None None None None None Production 9122 9-5/8"47#L-80 28-9150 28-8714.32 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9800-9820 feet 10205-10260 feet SCANNED NOV�" 3 True Vertical depth 8838.62-8843.5 feet 8961.81-8991.24 feet 1 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 27-8949 27-8529.7 Packers and SSSV(type,measured and true vertical depth) 4-1/2"BOT 3H Perm Packer 8843 8431.57 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Developmenit❑ Service 5 ' Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG LJ • GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays(a,BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician �� /4iJ �� Date 8/8/2013 —40511- ,%// //�� _ '� /v//Ii!" _ Phone 564-4035 VLF BtAVI S AUG 2 0 20 A Form 10-404 Revised 10/2012 002-9 Submit Original Only • • Daily Report of Well Operations ADL0028313 ® r® 1 :01 emp= o -rig a er 'eservorr weep Mod) Pumping brightwater chemicals down TBG while on water injection @ xxxx bwpd. Pumped 595 gal. EC9360A (Surfactant) Average of 41 gph for 14.5 hrs. Pumped a total of 595 gal. since start of project. Pumped 2870 gal. EC9398A( Polymer) Average of 205 gph for 14 hrs. Pumped a total of 2870 gal. since start of project ***Job continued to 7-16-13 WSR*** 7/15/2013 ***Job continued from 7-15-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 8500 bwpd. Pumped 656 gal. EC9360A(Surfactant) Average of 41 gph for 16 hrs. Pumped a total of 1251 gal. since start of project. Pumped 3229 gal. EC9398A ( Polymer) Average of 205 gph for 15.75 hrs. Pumped a total of 6099 gal. since start of project 7/16/2013 ***Job continued to 7-17-13 WSR*** ***Job continued from 7-16-13 WSR***(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection 8500 bwpd. Pumped 821 gal. EC9360A(Surfactant) Average of 41 gph for 20 hrs. Pumped a total of 2071 gal since start of project. Pumped 3895 gal. EC9398A( Polymer) Average of 205 gph for 24 hrs. Pumped a total of 9994 gal. since start of project Job completed as per procedure. Upon LRS departure valve positions were as follows, SV=closed, WV, SSV, MV=open, IA,OA=OTG FW HP 1500/750/80 7/17/2013 FLUIDS PUMPED GALS 2072 EC-9360A SURFACTANT 9994 EC-9398A POLYMER 12066 TOTAL Casing / Tubing Attachment ADL0028313 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20"x 30" 30 - 110 30 - 110 LINER 309 7"26# L-80 8884 - 9193 8469.56 - 8753.59 7240 5410 LINER 1458 2-7/8"6.16# L-80 8894 - 10352 8478.83 - 9053.54 13450 13890 PRODUCTION 9122 9-5/8"47# L-80 28 - 9150 28 - 8714.32 6870 4760 SURFACE 2642 13-3/8" 72# L-80 29 - 2671 29 - 2670.92 4930 2670 TUBING 8922 4-1/2" 12.6# L-80 27 - 8949 27 - 8529.7 8430 7500 • • ENI■ TREE= 4"OW • WELLHEAD= MCEVOY ---s-AllikoTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= BAKER X-24A WHEN ON MI.WELL REQUIRES A SSSV WHEN ON KB EL MI. WELL ANGLE>—70°fa 9321% EV= 75 23' BF ELEV = 3983' , KOP= 4700' Max Angle= 97°@9570 Datum MD= 9931 Q 1 2148' _4-1/2"OTIS DBE SSSV NIP ID=3 813" Datum TVD= 8800 SS a 13-3/8"CSG,72#,L-80 ID 12 347" H 2671' '____A I, Minimum ID = 2.372" @ 8894' I 8767' 1-4-1/2"OTIS SLIDING SLEEVE ID 3 813" 2-7/8" LINER I I 1 8819' H FOR,TOG, SEAL ASSY . 1 8843' —19-5/8"x 4-1/2.BOT-3H,PKR,ID=3 958" I 8883' —4-1/2"OTIS'X'NIP, ID=3.813' TOP OF 7"LNR --I 8893' I TOP OF 2-7/8"LNR I— 8894' . I 8916' —4-1/2' OTIS MILLED XN NP, ID=3 800" .1 4-1/2"TOG, 12.6#,L-80,ID=3 958" H 8949' , 8949' 1— 4-1f2`TOG TAIL ID=3958" IL 8980'_I—_ELMRTT LOGGED 07%29/90 1 9-5/8'CSG,47#,L-80,ID=8681" H 9150' 1 PERFORATION SUMMARY REF LOG. RDS INCt/GR ON 01/18/00 ANGLE AT TOP PERF 76°@ 9800' . Note.Refer to Production D3 for historical pert data MILLOUT WINDOW-9193'TO 9200' SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9800-9820 0 11/26/01 2" 4 10205-10260 C 01/19/00 1 „....„..--1 10087' 1—2-1/8"BKR IBP(11/25/01) 1 - A4411440ip TOP OF WHIPSTOCK H 9190' \:,:,-, ', ,. 10226' —1—TOP OF FILL Vioil****4 •••••• / ibsi••••• O.0,641■........ PBTD — 10321' r LNR,26#,L-80, 0383 bpi,ID=6 276" H 9717' ■ .i.%. .%1L■111... '`WILILW ,w...." 2-7/8"LNR,6 16#, L-80, 0055 bpi,ID=2372" — 10352' 1 _ — DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/21/84 ORIGINAL COMPLETION 11/20/03 JDW/TLP CLOSE PERF WELL. X-24A 01119100 CJS CTOSIDETRK COMPLETION 03/05/09 RiVVSV TREE C/0(02/22J09) PERMT No '1991250 0224/01 SIS-QAA CONVERTED TO CANVAS 02/16/11 MB/JMD ADDED SSSV SAFETY' NOTE AR No 50-029-21098-01 03/02/01 SIS-MD FINAL 01/20/12 TMN/JMO ADDED H2S SAFETY NOTE SEC 6,T1ON,R14E,244'NSL&402'WEL 06/18/01 RNITP CORRECTIONS 11128/01 ATD/KAK PERFS,BP FILL BP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, February 01, 2012 TO: Jim Regg e 1/ c 7 1 (v P.I. Supervisor ` SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC X -24A FROM: Chuck Scheve PRUDHOE BAY UNIT X -24A Petroleum Inspector Src: Inspector Reviewed By P.I. Supry J6 4--- NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT X - 24A API Well Number: 50 029 - 21098 - 01 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS120129175950 Permit Number: 199 - 125 - Inspection Date: 1/28/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well X -24A • Type Inj. W ' TVD 8432 • IA 855 2803 ' 2796 2794 P.T.D 1991250' TypeTest SPT Test psi 2108 ' OA 7 21 18 21 Interval 4YRTST P/F P ' Tubing 1567 1567 1567 1567 Notes: Wednesday, February 01, 2012 Page 1 of 1 IC.1ZS Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, January 27, 2012 5:40 AM To: Regg, James B (DOA) Cc: AK, D &C Well Integrity Coordinator; Daniel, Ryan; Schwartz, Guy L (DOA); Maunder, Thomas E (DOA) 2q, Subject: L -105 (PTD #2020580) and X 2((PTD #1991250) UIC Compliance testing Jim, Injector L -105 (PTD #2020580) was due for its annual AOGCC state witnessed MIT -IA on 01/18/12 and Injector X -24 ,i (PTD #1991250) was due for its four year AOGCC MIT -IA on 01/22/12. Injector L -105 (PTD #2020580) passed an MIT -IA psi on 01/03/12 and Injector X -24 (PTD #1991250) passed an MIT -IA pre-test to 2750 pre-test to 4000 ps o Injector ( ) psi on 01/02/12. p p p The slope state inspector was contacted early last week and notified of the due dates for both injectors. However, we have been unable to perform the AOGCC state witnessed MIT-lAs for these injectors due to the limited availability of the state inspector and weather shut downs on the slope. As soon as weather conditions permit, the AOGCC state witnessed ` MIT4A - § wiil be schedule and performed. Please let me know if you have any questions. Thank you, Whitney King filling in for Mehreen Vazir 5 FEB t S ZU1' (Alternate. C;r'ruld Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP. 1 Monthly Injection Report for GPB,•MA, Northstar, Milne Point & Endicot for April 2... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, May 19, 2011 2:49 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D &C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Daniel, Ryan Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for April 2011 Attachments: AOGCC Inj Report 05- 11.zip Tom, Jim, Phoebe, and Guy, Attached is the April 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. <<AOGCC Inj Report 05- 11.zip >> �u 2l� I i Notes on wells: Added to Report: L -119: Added for being Under Evaluation for potential TxIA communication. L -210: Added for being Under Evaluation for potential TxIA communication. S -217: Added for evaluation of TxIA communication diagnostics. The Well Integrity Coordinator will apply for an administrative approval pending IA repressurization. W -44: Added for being Under Evaluation for potential TxIA communication. Taken off Report: X -24A: Removed after showing no signs of IA repressurization since December, 2010. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 5/31/2011 • MEMORANDUM To: .Jim Regg ~C ~ < (~' (~? Q ~ ~~ P.I. Supervisor t\~~~ 1 FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 23, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA} P.VC X-24A PRliDHOE BAY INIT X-24A Src: Inspector NON-CONFIDENTIAL Reviewed By• , P.I. Suprv ~~~ I Z4 (~ ~ Comm Well Name: PRUDHOE BAY UNIT X-24A Insp Num: mitCS08ot22152352 Rel Insp Num: API Well Number: ~0-029-21098-O1-00 Inspector Name: Chuck Scheve Permit Number: 199-125-0 Inspection Date: 1/22/2008 Packer Depth Pretest Initial CIS Min. 30 Min. 45 Min. 60 Min. Well ~~ X-24A ~I,Type Ind. ~,~ W TVD ~ 8432 ~~ IA 40 ~~ 4000 3960 ~~~ 3960 ~ P T ~ I99IZSO ITypeTest ~ sPr'~ Test psi 2108 j OA ~ o % o o j o ~~ ~ Interval nYRTST p~F _ P / Tubing ~ 900 'I~ 900 'i 900 _ 900 ~ Notes: ~cc>~,~~9E~ FEB ~ 4 _ ~ 2008 Wednesday,lanuary 23, 2008 Page 1 of 1 ~. (' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg \<c'4Vl \l1ð\C/r DATE: January 15, 2004 P.I. Supervisor l SUBJECT: Mechanical Integrity Tests From: John Spaulidng BPXA Petroleum Inspector X-pad 24 Prudhoe Bay Unit Prudhoe Bay Field NON- CONFIDENTIAL Well 4 P.T.D. P Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. M= Annulus Monitoring 1= Initial Test G = GAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer Survey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details M.I.T.'s performed: 1 Number of Failures: Q Total Time during tests: 1 hr Attachments: none cc: .!1Q!!g ~(Ç¿~~~ElÜ tJt~N ~~J ~ 2001~. MIT report form 5/12/00 L.G. 2004-0115_MIT _PBU_X-24.Jhs.xls 1/20/2004 ~, ( 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 / X Pad 12/22/03 Anna Dube Witnessing declined by John Crisp Packer Depth Pretest Initial 15 Min. 30 Min. Well X-24A Type Inj. F TVD 8,431' Tubing 1,850 1,850 1,850 1,850 Interval 4 P.T.D. 1991250 Type test P Test psi 2,108 Casing 420 2,500 2,470 2,470 P/F P Notes: 4-Year required test. AOGCC representative declined witnessing test. Well Typelnj. 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 Ini. 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) 8tÞ~~~E[) DEC ~ 1 2003 MIT Report Form Revised: 06/19/02 2003-1222_MIT _PBU _X-24A.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELl. OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ SBG - ACID Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 5035' FNL, 401' FEL, Sec. 06, T10N, R14E, UM At top of productive interval 3412' FNL, 4466' FEL, Sec. 05, T10N, R14E, UM At effective depth 3681' FNL, 3976' FEL, Sec. 05, T10N, R14E, UM At total depth 3843' FNL, 3829' FEL, Sec. 05, T10N, R14E, UM 5. Type of Well: Development _ Exploratow__ Stratigraphic__ Service__X (asp's 665475, 5940364) (asp's 666649, 5942013) (asp's 667146, 5941756) (asp's 667297, 5941597) 6. Datum elevation (DF or KB feet) RKB 75 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-24A 9. Permit number / approval number ~,/ 199-125 10. APl number 50-029-21098-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2635' Intermediate 9114' Liner 309' Sidetrack Liner 1458' 10355 ,feet Plugs (measured) 9056 feet TD Tagged @ 10226' (11/25/2001) Set IBP @ 10087' (11/25/2001) 10087 feet Junk (measured) 8918 feet Size Cemented Measured Depth True Vertical Depth 30" 72 c.f. Concrete 146' 146' 13-3/8" 3720 c.f. Permafrost II 2671' 2671' 9-5/8" 1856 c.f. 'G', 345 c.f. PF 9150' 8714' 7" 300 c.f. Class 'G' 8884' - 9193' 8469' - 8753' 2-7/8" 175 c.f. Class 'G' 8894'- 10352' 8479' - 9053' Perforation depth: measured Open Perfs 9800' - 9820', Open Perfs Below IBP 10205' - 10260' true vertical Open Perfs 8838' - 8843', Open Perfs Below IBP 8962' - 8991' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 TBG @ 8819' MD. PBR, TBG, Seal Assy @ 8819'. Tubing Tail @ 8980'. 4-1/2" Otis DBE SSSV NP @ 2148' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure ,AY 0 5 Ata~ka 0~I & Gas Co~s, 14. Prior to well operation 03/06/2003 Subsequent to operation 04/05/2003 OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 6278 2OO Casing Pressure Tubing Pressure ? 12 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil __ Gas _ Suspended _ Service WAG Injector 17. I hereby certify that the foregoing is~true and correct to the best of my knowledge. DeWayne R. Schnorr RBDtMS BFL CA NE ORIGINAL Date April 07, 2003 Prepared b~/DeWayne R. Schnorr 564-5174 SUBMIT IN DUPLICATE 03/21/2003 03/22/2003 03/23/2O03 03/24/2OO3 03/24/2O03 03/25/2003 O3/25/2OO3 03/26/2003 03/21/O3 O3/22/03 03/23/03 O3/24/O3 O3/24/O3 O3/25/O3 03/25/O3 03/26/O3 X-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SCMOO-B-GONE--SBG: DRIFT/TAG; SSSV C/O OR STROKE SCMOO-B-GONE--SBG: DRIFT/TAG SCMOO-B-GONE--SBG: DRIFT/TAG TESTEVENT---Inj Press, psi: 3,245 Type: MI Vol: 0 ACID: ACID TREATMENT; SCMOO-B-GONE TESTEVENT --- INJECTION PRESSURE, PSI: 0 TYPE: MI VOLUME: 6,448. ACID: ACID TREATMENT; SCMOO-B-GONE ACID: ACID TREATMENT; SCMOO-B-GONE EVENT SUMMARY <<< WELL SHUT IN UPON ARRIVAL >>> RAN EQ SUB BUT SAW NO CHANGE IN PRESSURE. ATT'D TO LATCH MCX. RUNNING PUMP BAILER TO MCX. BALLED IRON SULFIDE OFF OF TOP OF ISSSV. DRIFTED W/3.84 GAUGE RING TO 2149' SLM. PULLED 4 1/2" MCX ISSSV FROM 2147' SLM.(SERIAL # = BPX 99- 1). DRIFT & TAGGED @ 9236' SLM. SAMPLE BAILER PACKED OFF WITH IRON SULPHIDE. PAD OPERATOR WANTS WELL LEFT SHUT-IN FOR ACID WASH. TESTEVENT--- INJECTION PRESSURE, PSI: 3,245 TYPE: MI VOLUME: 0. MIRU. JOB IN PROGRESS. TESTEVENT --- INJECTION PRESSURE, PSI: 0 TYPE: MI VOLUME: 6,448. BOP TEST. DRIFT COIL. PU 2" DJN, RIH. DISPLACE COIL WITH SBG. JET LINER TO 9850'. JET TUBING WITH SBG AS POH TAKING RETURNS INITIALLY TO WELL X-36. AFTER OUT OF LINER SEND EVERYTHING DOWNHOLE. JOB IN PROGRESS. COMPLETE JETTING TUBING WITH SBG AS POH. DISPLACE SBG TO PERFS WITH 1% KCL INITIAL INJECTIVlTY IS 1.5 BPM AT 1800 PSI, FINAL INJECTIVITY IS 2.1 BPM @ 1040 PSI. RIH WITH 2" JS NOZZLE. TREAT INTERVAL 9790' CTMD TO 9830' CTMD WITH 25 BBLS - NH4CL, 50 BBLS ~ 7.5% HCL, 51 BBLS - 9%/1% HCL/HF FOLLOWED BY 113 BBLS NH4CL OVERFLUSH. INITIAL TREATING RATE AND WHP WAS 1.5 BPM @ 1560 PSI. FINAL TREATING RATE WAS 1.7 BPM @ 1170 PSI. POOH FILLING VOIDAGE WITH 1% KCL. PERFORMED INJECTIVITY-TEST DOWN WELL; 1BPM @ 640 PSI, 2 BPM @ 1220 PSI, 3 BPM @ 1510 PSI, 4 BPM @ 1730 PSI, AND 5 BPM @ 1830 PSI. WELL FREEZE PROTECTED TO 2500' WITH 60/40. WELL TO BE POI ON 03/27/2003 AS PER PAD OPERATOR. RDMO --- JOB COMPLETED. Page 1 X-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS Fluids Pumped 17 DIESEL FOR PRESSURE TEST AND SPEAR. 287 METHANOL 121 60/40 METHANOL WATER 291 SCHMOO B GONE 5O HCL ACID 51 HCL-HF ACID 138 NH4CL 335 1% KCL WATER 129O TOTAL Page 2 DATA SUBMITTAL COMPLIANCE REPORT 2/5/2002 Permit to Drill No. 1991250 Well Name/No. PRUDHOE BAY UNIT X-24A Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-21098-01-00 MD 10355 TVD 9050 Completion Date 1/19/2000 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log Nc> Samples N__9_o Directional Survey No -- .......................... ~.~ .~-~i~_~Z~-'_-~_- ~'_~.~'~._ ~ .~ '-d ............ '~_q~2-'~-__~_.~-7--'£ .......... ---?.--~-~Z '-V--__--V"2-_--_ ~?~_' '~'-'_' 2 .~ .- 2~7 ............... DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint) Well Log Information: Log/ Data Digital Digital Log Log Run Interval OH / Dataset Type Media Format Name Scale Media No Start Stop CH Received Number Comments ............................................. ~- N-~I~}rI~D .................... 2,~ ............ FiI~,~'L- ....... 8-6-6~, ....... -8980 OH 5~25~2000 D R SRVY LSTNG 9100 10355 OH 2/15/2000 BH . D t..,,L,,/' NGP-MD 25 FINAL 9182 10355 OH 5~25~2000 D aR/"SRVY RPT 9100 10355 OH 2/15/2000 SPERRY D ,..K-"~'l L 25 FINAL 9000 10345 OH 2/10/2000 .--T''~''' O 2110/2000 09504 ~"/9000-10345 ~ O 5~25~2000 09561,...-' 9182-10317 W-eii.(~-~i?~ ~i;i-~.~-. ih~f0i:~iii~;,~i ........................................................................................................................................................................................ Interval Dataset Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? ~ N Formation Tops Receuived? Comments: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X SBG/ACIDIIBPIPERF/ACID Pu~ tubing _ Alter casing _ Repair well_ Other _X IBP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 75 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 5035' FNL, 401' FEL, Sec. 06, T10N, R14E, UM (asp's 665475, 5940364) X-24A At top of productive interval 9. Permit number / approval number 3412' FNL, 4466' FEL, Sec. 05, T10N, R14E, UM (asp's 666649, 5942013) 199-125 At effective depth 10. APl number 3687' FNL, 3974' FEL, Sec. 05, T10N, R14E, UM (asp's 667148, 5941750) 50-029-21098-01 At total depth 11. Field / Pool 3843' FNL, 3829' FEL, Sec. 05, T10N, R14E, UM (asp's 667297, 5941597) Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10355 feet Plugs (measured) TD Tagged @ 10226' (11/25/2001) true vertical 9056 feet Set IBP @ 10093' (11/25/2001) Effective depth: measured 10093 feet Junk (measured) true vertical 8919 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 30" 72 c.f. Concrete 146' 146' Surface 2635' 13-3/8" 3720 c.f. Permafrost II 2671' 2671' Intermediate 9114' 9-5/8" 1856 c.f. 'G', 345 c.f. PF 9150' 8714' Liner 309' 7" 300 c.f. Class 'G' 8884' - 9193' 8469'- 8753' Sidetrack Liner 1458' 2-7/8" 175 c.f. Class 'G' 8894' - 10352' 8479' - 9053' Perforation depth: measured Open Perfs 9800'-9820', Open Perfs Below IBP 10205'- 10260' true vertical Open Perfs 8838' - 8843', Open Perfs Below IBP 8962' - 8991' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 TBG @ 8819' MD. PBR, TBG, Seal Assy @ 8819'. Tubi~n~g~ Tail @ .8~80'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BOT - 3H, PKR @ 8843'. 4-1/2" Otis DBE SSSV NP @ 2148' MD. 13. Stimulation or cement squeeze summary ~,r~.~ ~ t,~i; -"';'~, ";i ~UU'~' Intervals treated (measured) (see attached) . Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 12/13/2001 Shut-in Water injection started 12/15/2001 Subsequent to operation 12/18/2001 7324 1444 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas _ Suspended __ Service _WAG Injector 17. I hereby certify that the foregoing i.s true and correct to the best of my knowledge. ~'~~~~~ Title: TechnicalAssistant Date December20, 2001 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 10/30/2001 11/22/2001 11/23/2OO 1 11/23/2001 11/24/2001 11/25/2001 11/26/2001 1 2/07/2001 1 2/15/2001 10/30/01 11/22/01 11/23/01 X-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERF(ADD-PERF): DRIFT. PULL MCX. DRIFT/TAG. PERF(ADD-PERF): IBP, ADD PERF, STIM PERF(ADD-PERF): SBG, ACID, IBP, PERF, ACID PERF(ADD-PERF): PULL SSSV FOR CTU PERF(ADD-PERF): SCHMOO BG/AClD/IBP/PERF/AClD PERF(ADD-PERF): SBG/ ACID/ IBP/ PERF/ ACID PERF(ADD-PERF): SBG/ ACID/ IBP/ PERF/ ACID ANN-COMM: AC EVAL HIGH IA PRESSURE. SSSV C/O OR STROKE: SET MCX INJECTION SSSV EVENT SUMMARY 3.82" DRIFT TO 953' WLM. SAT DOWN. 1-3/4" SAMPLE BAILER TO 960' WLM. ICE PLUG. MIRU CTU #3, MU BHA #1 2.75" DJN, SIWHP = 3315 PSI, BLEED WHP TO 600 PSI & RIH, TAG HARD ICE PLUG @ 978' CTMD, INCREASE WHP TO 3600 PSI, PUMP 1.4 BPM 60/40 MW. SWAP TO KCL. JET DOWN TO 1150' CTD, BROKE THROUGH ICE. JET DOWN TO SSSV, TAG AT 2164' CTD. CLOSE CHOKE, POOH BULLHEADING KCL @ .7 BPM. AT SURFACE, FP COIL. ATTEMPT INJ TEST, PUMPED 6.5 BBLS 60/40 MW & LOCKED UP. MU BHA #2 SLIM 1.75" DJN, JET 0.5 BPM, SAW SLUSH BUT DID NOT TAG, RIH TO 2150' CTD. POOH. PRESSURED UP W/1 BBL 60/40 MW. MU BHA #3 2.75" DJN, RIH TO MAKE SURE FISHING NECK CLEAR OF SLUSH. POP OFF WELL, MU BHA#4 3.0 JSN NO CKS. STAB ON, BLOW DOWN COIL W/ N2. RIG DOWN. ***LEFT WELL SI W/2000 PSI WHP, 60/40 MW FLUID PACKED. TO ICE PLUG. WILL BE BACK AFTER REEL SWAP & SLICKLINE PULLS SSSV*** 11/23/01 PULLED 4 1/2 MCX. SERIAL # M-01. LEAKING FLANGE ON SPOOL PIECE ON TOP OF SWAB VALVE. NOTIFIED WELLS GROUP AND DSO. *** SSSV IS OUT OF THE HOLE, WELL IS NOT BE ON MI INJECTION UNTIL SSSV IS RAN *** 11/24/O 1 MIRU DS CTU #3 . RIH WITH 2.25 DOWNJET NOZZLE TO CLEAN OUT ICE PLUG. TAGGED 1ST RESTRICTION @ 2195'. CLEANED OUT TO 9237'. CIRC. 60/40 MEOH ENTIRE TIME AND HAD GAS RETURNS. UNABLE TO EST INJECTION. WELL LOCKED UP. POSSIBLE OBSTRUCTION IN LINER OR PLUGGED PERFS.BLEED GAS WHILE POOH ClRC 60/40 . POOH TO INSTALL 2" NOZZLE. RIH, TAG OBSTRUCTION AT 10,171' CTD, JET DOWN TO 10,191' CTD W/26 BBLS DIESEL/XYLENE, NOT MAKING HOLE. TEST INJECTIVlTY AT 1.1 BPM, 2300 PSI DOWN . JET 10 BBLS SBG, BULLHEAD 10 BBLS SBG, NO IMPROVEMENT, LAY IN SBG 1:1 TO SURFACE. Page 1 '~ .... X-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 11/25/01 FINISH LAYING SBG, DISPLACE W/55 BBLS 2 % KCL, 76 BBLS MW 60/40. POP OFF TO CHANGE TO 2.25" JSN. RIH. JET 2 7/8" LINER WITH 60 BBLS OF 7.5% HCL / 20% XYLENE AND DISPLACE TO PERFS WITH 45 BBLS OF NH4CL. POOH. RIH WITH MEMORY GR/CCL. LOG DOWN FROM 9600' TO 10200' CTMD. LOG UP FROM TD TO 9850' AND FLAG PIPE (RED & BLUE), CONT' LOG UP TO 9600'. POOH. LOG CORRECTS TD TO 10,226' CTMD. MU BAKER 2 1/8" IBP. RIH. SET IBP ELEMENT @ 10,093' CTD. POOH. 11/26/o 1 MU 20' 2" PJ 6 SPF, RIH, PERF 9800-9820', POOH. MU 2.13 JET SWIRL NOZZLE, MIRU ACID AND PUMPING EQUIPMENT. SAFETY MEETING. PUMP 25 BBLS NH4CL, 50 BBLS 7.5% HCL, 50 BBLS 9-1 MUD ACID, 150 BBLS NH4CL OVERFLUSH, DISPLACE W/60 MEOH. INITIAL INJ RATE WAS .5BPM AT 2650 WHP, FINAL INJECTIVITY- 0.5 BPM AT 360PSI, 1BPM AT 1040PSI, 1.5 BPM AT 1910 PSI, 2.0 BPM AT 2280 PSI, 3.0 BPM AT 3025 PSI. SHUT DOWN. RDMO WELL. SECURE WELL. NOTIFY PAD OPERATOR THAT JOB IS COMPLETE, AND X-24 IS FREEZE PROTECTED, AND READY TO PUT ON WATER INJECTION. ********JOB COMPLETE***** 12/07/01 BLED IA FROM 2000 PSI TO 560 PSI. 12/15/01 SET 4 1/2" HES MCX INJ SSSV, SER#BPX 99-1 (SSSV HAS X EQ DEVICE & .75" CHOKE). DID NOT FLOW TEST, WELL WAS ON VACCUM. NOTIFIED PCC, H.E.S. PUT WELL BACK ON INJECTION. Fluids Pumped 3 PUMPED 1 BBL OF DIESEL FOR PRESSURE TESTING LUBRICATOR (3 TESTS) 1129 60/40 METHANOL WATER 136 SCHMOO B GONE 47.5 7.5% HCL ACID 59 7.5% HCL / 20% XYLENE 49 9-1 MUD ACID 215 3% NH4CL WATER 2OO KCL WATER 108 2% KCL WATER 26 DIESEL/XYLENE 1972.5 TOTAL ADD PERFS 11/26/2001 THE FOLLOWING INTERVAL WAS PERFORATED USING 2" PJ 6 SPF, 60 DEG PHASING, RANDOM ORIENTATION. 9800'-9820' Page 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Schmoo Treatment Operation shutdown_ Stimulate _X Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 244' FSL, 401' FEL, Sec. 06, T10N, R14E, UM At top of productive interval 1866' FSL, 813' FWL, Sec. 05, T10N, R14E, UM At effective depth 1447' FSL, 1431' FWL, Sec. 05, T10N, R14E, UM At total depth 1435' FSL, 1450' FWL, Sec. 05, T10N, R14E, UM Perforate _ Other_ 5. Type of Well: Development __ Exploratow__ Stratigraphic__ Service~X (asp's 665475, 5940364) (asp's n/a) (asp's 667277, 5941609) (asp's 667297, 5941597) 6. Datum elevation (DF or KB feet) RKB 75 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number X-24A 9. Permit number / approval number 199-125 10. APl number 50-029-21098-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 2635' Intermediate 91 14' Liner 309' Sidetrack Liner 1458' Perforation depth: 10355 9056 10321 9031 Size 30" 13-3/8" 9-5/8" 7" 2-7/8" measured Open Perfs 10205' - 10260' true vertical Open Perfs 8962' - 8991' Tubing (size, grade, and measured depth) feet Plugs (measured) feet feet Junk (measured) feet Window milled @ 9193' - 9200' in 7" csg. Abandoned 7" csg from 9193' to 9717'. Cemented Measured Depth True Vertical Depth 72 c.f. Concrete 146' 146' 3720 c.f. Permafrost II 2671' 2671' 1856 c.f. 'G', 345 c.f. PF 9150' 8714' 300 c.f. Class 'G' 8884' - 9193' 8469' - 8753' ' - 3' 175 c.f. Class 'G' 8894' - 10352'REcE'~~?i~ JUL 2, 0 2001 Alaska Oii& Gas Cons. Commission Anchorage 4-1/2", 12.6#, L-80 TBG @ 8819' MD. PBR, TBG, Seal Assy @ 8819'. Tubing Tail @ 8980'. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BOT - 3H, PKR @ 8843'. 4-1/2" Otis DBE SSSV NP @ 2148' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Avera.qe Production or Injection Data Gas- Mcf Water- Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service _Water & Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~~,~~ ~~)~ Title: Technical Assistant DeWayne R. Schnorr Date July 10, 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE X-24A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/13/01 06/16/01 SCHMOO B GONE: SBG SCHMOO B GONE: MI BREAK-OVER EVENT SUMMARY 02/13/01 PUMP SBG DOWN TUBING FROM SKID 06/16/01 SBG PREP. ATTEMPTED TO LOAD WELL AND BREAKOVER. WELL LOCKED UP TO 4300 PSI W/ONLY 16 BBLS AWAY. LEAKOFF VERY SLOW. Fluids Pumped 286 WATER 31 SCHMOO B GONE 20 METHANOL 12 50 - 50 METHANOL 4 SEA WATER 353 TOTAL Page 1 WELL LOG TRANSMITTAL To: State of Alaska May 25, 2000 Alaska Oil and Gas Conservation Comm. Attr~: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs X-24A, AK-MW-90226 1 LDWG formatted Disc with verification listing. APl#: 50-029-21098-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jan Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED mtga¥ 25 000 Alaska 0il & 6as Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs' X-24A, May 25, 2000 AK-MW-90226 X-24A: 2" x 5" MD Gamma Ray Logs' 50-029-21098-01 2" x 5" TVD Gamma Ray Logs' 50-029-21098-01 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIFF BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Tun Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well I-~ Oil i~l Gas [] Suspended I~Abandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 199-125 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21098-01 4. Location of well at surface '~ :~ ~ ~ ' ~~'i' 9. Unit or Lease Name 244'NSL, 402'WEL, SEC. 06, T10N, R14E, UM ii'/~'~"/~'"=~'~.- .i ~! Prudhoe Bay Unit At top of productive interval i .~' 10. Well Number 1866' NSL, 813' EWL, SEC. 05, T10N, R14E, UM : ~ :-~' ,;i X-24A At total depth 11. Field and Pool 1436' NSL, 1447' EWL, SEC. 05, T10N, R14E, UM Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE - 75.23'I ADL 028313 12. Date Spudded01/14/00 113' Date T'D' Reached ! 14' Date C°mp" Susp" °r Aband'115' Water depth' if °ffsh°re 116' N°' °f C°mpleti°ns01/18/00 01/19/00 N/A MSLI One 17. Total Depth (MD+TVD)I18. Plug Back Depth (MD+TVD)I19. Directional Survey J20. Depth where SSSV set 121. Thickness of Permafrost 10355 9056 FTI 10321 9031 FT1 [~Yes E~]No (Nipple) 2148' MD 1900' (Approx.) 22. Type Electric or Other Logs Run GR, POP, Memory Induction 23. CASING~ LINER AND CEMENTING RECORD CASING S E'I-FING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" x 30" Insulated Conductor Surface 110' 36" !8 cu yds Concrete 13-3/8" 72# L-80 Surface 2671' 17-1/2" 3720 cuft Permafrost II 9-5/8" 47# L-80 Surface 9150' 12-1/4" 1856 cuft Class 'G', 345 cu ft Permafrost 7" 26# L-80 8884' 9193' 8-1/2" 300 cuft Class 'G' 2-7/8" 6.16# L-80 8894' 10352' 3-3/4" 175 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8949' 8843' MD TVD MD TVD 10205' - 10260' 8962' - 8991' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 25 Bbls MeOH 27. PRODUCTION TEST Date First Production tMethod of Operation' (Flowing, gas lift, etc.) January 24, 2000 Water & Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATE O~L-BBL GAS-MCF WATER-BBL O~L GRAViTY-APl (CORR) Press. D 24-HOUR 28. RATE CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered and Marker Name Depth Depth gravity, GOR, and time of each phase. Top of Shublik A 9212' 8770' !Top of Shublik B 9245' 8796' Top of Shublik C 9273' 8815' ,Top Sadlerochit / Zone 4B 9363' 8848' Base of Shublik C 9632' 8830' Top Sadlerochit / Zone 4B 9751' 8830' Zone 4A 10180' 8950' Zone 3 10320' 9030' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32.'lsignedh ereby certify that t~r, egoin, g is tr~;nd correct to the best of my knowledge Terrie Hubble (~vA~, __ Title Technical Assistant III Date ' [_ ~'__(~ X-24A 199-125 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. RECEIVED Form 10-407 Rev. 07-01-80 & ns. G4 mia n An ora To: Anchorage Production Engineering Location: X-24 From: Kirby Walker Date: January 8, 2000 Operation: Mill Window Cost Code: 4P1346 Job Id: 9335 - 0x0 - xxx Detail Code: CTSDTRK / Mill / etc Summary RU Dowell CTU. Have HB&R freeze protect FL from skid. MU BHA #1 and RIH. Tag cement stringer at 8,856' and mill through. Tag XN and mill. RIH to whipstock seeing no further signs of cement. Stall motor upon tag- flag pipe, adjust depth and begin milling window. Order 50 bbl of Biozan and pump 5- 10 bbl sweeps periodically. Tight spot noted at 9,185' on both up and down passes. With the window estimated to be at 9,200' - milled to 9,205'. POOH jetting. RDFN. Estimated Daily Cost: $22,700 01/08/00 Initial Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F SI 100 920 0 N/A 1200 40 I Time Operation 08:30 MIRU Dowell CTU #2, 14,975' (33.1 bbl) - BOP TEST WAS PERFORMED YESTERDAY- WITNESSED BY JOHN CRISP 09:00 RU HB&R at skid to freeze protect flowline. 11:00 Begin FP flowline. 11:40 RIH. 13:49 Tag whipstock. 21:30 On surface with coil. RDFN. Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 11:40 0 0 0 75 0 Open well and RIH. 12:00 1380 0.75 1175 0 0 Start pumping to displace methanol. 12:31 5000 0.75 790 0 23 Pickup weight - 9,700# RF_CEIVE 12:57 8100 0.5 248 0 44 Drop rate. _ _ 13:03 8740 0 40 0 47 S/D pump. 13:04 8800 0 45 0 Pickup weight-18,400# . .!.~ 'J 5 2000 13:07 8856 2.6 2730 90 47 Tag cement stringers- begin milling. 13:14 8872 0 139 0 64 S/D and continue RIH. Alaskai~&GasC4xlS,~ 13:15 8905 2.6 2740 100 64 Tag cement stringers - begin milling. N1~10~ 13:23 8947 2.8 2745 91 88 Tag XN nipple- stall. Adjust depth (-10') 13:30 8947 2.6 2743 91 88 Begin millingXN nipple. 13:33 8947.5 1.5 1350 27 110 Through XN- slow rate. Continue RIH 13:49 9191.1 0 450 0 133 Tag whipstock. PU- note overpull 13:52 9193 0 531 0 138 Stall motor- adjust depth (+3') FLAG PIPE at 9191.3' 14:00 9193 2,7 2745 110 145 Begin milling. Refer to attached mill report. 14:35 9185 2,7 4100 15 243 PU to swap to circulating, Note overpull. Cannot keep prime- switch back to not taking returns. 15,33 9110 1,7 2405 323 243 Resume milling- returns to flowline. Operation: X-24 Page: 2 15:39 Losing air on tractor- PUH 16:00 305 RIH 17:11 9199.3 2.4 2941 327 483w Biozan sweep. 17:16 9199.3 2.0 3861 324 493 Back to slick water. 17:30 9199 2.5 3146 340 523 Biozan outnozzle. 19:04 9202.8 2,4 2871 342 745w Biozansweep. 19:06 9203.1 2,4 3550 346 750 Back to slick water. 19:12 9204.2 2.5 3173 353 765 Biozan sweep. 19:15 9196 2.5 3637 349 772 Back to water. 19:21 9204.5 2.5 3647 351 790 Biozan sweep. 19:23 9204.6 2.5 3875 349 800 Back to water. 21:51 9206.6 2.0 3396 334 849 At depth- pump remainin~l Biozan. 21:57 9205 1.8 3522 337 859 Finish Biozan- backto water. 20:14 9205.0 0 352 270 891 Biozan around nozzle- dry tag. (window at 9,200') 20:17 9205 3.0 3577 373 903 POOH jetting. 21:07 3320 1.8 2490 330 1024 Start methanol. 21:30 0 0 65 15 39 On surface - RDFN. Final Well Status Slwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F SI 15 900 0 N/A 50 10 Fluid Summary 974 Seawater w/friction reducer. 50 Biozan. 45 Meoh. 1069 Total Jet Swirl Nozzle Bottom Hole Assembly # 1 Tool String Descriptions O.D. I.D. Length Comments Baker CTC 3.125 1.0 0,94 BPV 3.125 - 1.58 Hydraulic Disc. 3.375 - 1.52 7/8" ball Circ Sub 3.125 - 1.14 aA" ball Inteq motor 2.875 - 11.15 Hughes Diamond Mill 3.80 - 0.51 Total Length 16.84 RECEIVED To: From: Anchorage ProdUction Engineering Kirby Walker Location: Date: Operation: 2n'~ Mill Run Cost Code: Job Id: 9335 - 040 - 420 Detail Code: X-24 January 9, 2000 4P1346 CTSDTRK / Prep / Mill Summary MU BHA #1 and RIH. Adjust depth at flag and begin milling taking returns to X-25 flowline. Mill catching at 9,181' - unable to make positive progress. Able to slide to 9,187.5'. Attempt back-reaming with little success. Start motor and make good milling progress down from 9,186.5' to what appears to be bottom at 9,197'. (Depths are uncorrected and about 8' shallow from yesterday's.) Attempt to ream-up through top of window at 9,186' and stall 5 consecutive times. Start Biozan sweeps (2 x 10 bbl) separated by 15 bbls of water. Shut down pump and dry tag TD at 9,200.5'. Bring on pump and continue circulating Biozan sweeps- POOH jetting. Freeze protect top 2,000' with methanol. RDMO Dowell CTU. There is an obstruction at 9,185' (corrected depth). The window was dressed from 9,195'- 9,201' (corr). Open hole was drilled putting TD at 9,208' (corr). Both the diamond mill and the string mill were in gauge with little sign of wear - no unusual marks. Estimated Daily Cost: $45,500 01/07/2000 Initial Well Status Fwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F SI 30 820 0 N/A 2010 10 Time Operation 07:20 MIRU Dowell CTU #2 14,960' of 1-3/4" (ctv 33.1 bbls). 07:30 Hold pre-job safety meeting. *** yesterday's mill was in gauge with the diamond cutting surface still intact and a worn ring groove at the crown. 09:15 Open well and RIH. 21:25 On surface with coil. RDMO CTU. Time Depth Rate Ctp Whp Total Remarks ft bpm psi psi bbls 09:15 0 0 0 30 0 RIH. 09:40 2100 0.75 1414 300 Come on with pump. 10:51 8800 0 210 275 53 Weight check- 16,200# 11:00 9000 1.5 2200 326 53 Resume pumping. 11:05 9153 1.6 2210 323 62 Stop at flag- adjust depth. Refer to attached Mill Report. r'3r'L'-I''~.~ 13:46 9187.5 0 427 312 422 Drytag r%l-,~J'~,-I ~' "'"""'" 13:48 9185 1.6 3180 340 424 PUH milling._.. 14:29 9183 0 390 287 475 Pump went down. 14:40 9145 0.3 510 290 477w Swap to methanol. .... 16:00 9145 1.0 1242 331 17m Pump fixed - back to water. 16:27 9145 0 335 274 34 Methanol out of coil- S/D RIH. Operation: X-24 Page: 2 17:55 9200.5 2.5 2953 381 253 On bottom. PUH back reaming. 18:16 9175 0 360 239 298 Run to bottom and pull through restriction- see nothing. 18:45 9183 2.4 2434 356 309 Attempt to back ream- hang up 5 times at same depth. 18:47 9197 2.0 3147 355 334w Start Biozan sweep. 18:58 9190 2.0 3189 365 10b Swap back to water. 19:04 9193 1.9 3254 367 15w Pump remaining Biozan. 19:10 9197 2.1 3369 353 9b Swap back to water. 19:17 9174 0 550 271 10 S/D RIH for dry tag. 19:20 9200.5 0 500 300 Tag TD. 19:21 9200.5 2.1 2813 346 12 Resume pumping and POOH. 20:10 5892 2.1 2271 340 105 Drop ballto open circ sub. 20:28 3811 3.1 3445 400 141w Swap to methanol. 21:20 0 0 268 0 66m Onsurface. RDMO Dowell. Final Well Status Slwhp lap 0ap GIp FIp Fit psi psi psi psi psi °F SI 268 890 0 N/A 2400 55 Fluid Summary 967 Seawater w/friction reducer. 18 Biozan. 85 Mech. 1070 Total Milling Assembly Bottom Hole Assembly # 1 Tool String Descriptions O.D. I.D. Length Comments Baker CTC 3.125 1.0 0.94 BPV 3.125 - 1.58 Hydraulic Disc. 3.375 - 1.52 7/8" ball Circ Sub 3.125 - 1.14 3,~,, ball Inteq motor 2.875 - 11.15 Carbide String Mill 3.80 - 3.08 Hughes Parabolic Diamond Mill (used) 3.80 - 0.75 Total Length 20.16 RECEIVED AIa 0il & Gas Cons, Commiaioa Well: X-24A Accept: 01/14/00 Field: Prudhoe Bay Spud: 01/14/00 APl: 50-029-21098-01 Release: 01/19/00 Permit: 199-125 CTD Unit: Nordic #1 01/14/O0 1 Accepted rig on X-24Ai at 04:00 Hrs., 01-14-00. N/U BOPE. Spot rig trailers and tank. M/U hardline to cuttings tank. Prepare for initial BOPE test. 01/15/00 2 General rig up. Tested BOPE. PU injector. Pulled & installed coil in injector. Changed packoff & installed hardline. Pumped dart through coil. M/U DS CTC. M/U MWD BHA #1 with 2.7 deg. short radius motor. RIH with BHA #1. Oriented TF to highside and ran through window OK. Drilled build section from 9208 - 9321 ft at 15-25 FPH, using seawater with FIoPro sweeps. POOH to reduce bend in motor to 1.7 deg. At surface. Adjust motor and RIH with BHA #2 [1.7 deg. motor and same bit]. 01/16/O0 3 Drilled to 9375'. MWD signal quit. POH to c/o MWD tool. C/O MWD tool. RIH. Tied-in with BHCS/GR [+9' to CTD]. Drilled from 9375 - 9410 ft. First mud losses seen at 9410 ft. Drilled to 9420 ft and had 2 BPM losses. Drilled to 9452 ft with 2 BPM losses. Pulled into liner and mixed a 30 BBL Form-A-Set pill to reduce losses. RIH. Pumped 10 BBL FIoPro, 30 BBL Form-A-Set and 12 BBL FIoPro. Displaced with seawater. Closed choke with 2 bbls Formaset out. WHP = 0 during entire job. Opened choke and laid in last 7 bbls of plug. Pulled into liner and waited on Form-A-Set pill to get firm for 4 hours. RIH and started pumping. Pumped 20 bbls before seeing returns. RIH to TD with losses of 1.1 BPM. Drilled from 9452 - 9500 ft with losses of 1.0 - 1.2 BPM. Pulled into liner and mixed second 30 pill of Form-A- Set pill to further reduce losses. RIH. Pumped 10 BBLS FIoPro, 30 BBLS Form-A-Set and 10 BBLS FIoPro. Displace with seawater. 01/17/O0 4 Spotted 2® 30 bbl forma-Set pill across fault @ 9410'. Squeezed away 20 bbls. Spotted 10 bbls above fault. POH. To 9020'. WO Forma-Set for 4 hrs. Held safety meeting & tested rig ESD system. Drilled to 9692 ft using SW and FIo-Pro sweeps. Drilled into Shublik formation at 9630 ft. Short trip to liner. Orient TF down to get below Shublik. Drilled out of Shublik at 9732 ft. Drilled to 9801 ft. Pulled to window and Tied-in with BHCS/GR at 9192 ft. Added 8.5 ft to CTD. RIH and drilled to 9930 ft. Lost MWD signal. POOH to liner and determined Sperry manifold had frozen. Thawed manifold and got MWD signal back. RIH to TD. Orient TF. 01/18/00 5 Drilled to 10080' w/SW and FIo-Pro sweeps. Unsuccessfully attempted to orient @ 10080'. Had to pull to window to orient. RIH. Drilled to 10200'. Wiper trip to window. Drilled to 10325 ft. Made a short trip to the window and tied-in with the BHCS/GR. Added 5 ft to CTD. Drilled to a final TD of 10,355 ft. Made a short trip to the window. RIH to TD and laid new FIoPro in the open hole while POOH. Lay out drilling BHA. Held Safety Meeting. M/U PDS Memory Induction / GR logging BHA and RIH to 9000 ft. Log down at 30 FPM. RECEIVED X-24A, Coil Tubing Drilling Page 2 01/19/O0 6 RIH. Logged down with PDS Memory Ind/GR f/9000-10355' @ 30 fpm. Logged up f/10355-9000'. POH. LD logging tools. Held Safety Meeting. PU & RIH 48 its, 2-7/8", 6.16ppf, L80, STL, liner. M/U Baker CTLRT. RIH with 2 7/8" liner on CT. Landed liner at TD of 10,352 ft BKB [per PDS IND/GR log]. Pump 80 bbls clean seawater. Drop 5/8" ball and release from liner. Held Safety Meeting. DS pump 31 bbls Class G cement with latex. Displace wiper dart with seawater to latch collar with ~ returns through out. Jet TOL clean, POOH. LD CTLRT. MU 2.25" jet nozzle on 26 stands CSH workstring. RIH with CT to PBD. Jet liner clean with 2% KCl water losing 0.5 bpm. POOH. Stand back CSH workstring. MU Baker 4-1/2" KB liner top packer. RIH with packer assembly. 01/20/00 7 RIH with Baker 4 ~" KB retrievable production packer. Sting seal assembly into PBR. Pressure test seals - OK. Sting out of PBR and displace 5/8" ball onto seat. Sting into PBR, land and pick up 1 ft. Set packer with top at 8894'. Pick up and pressure test liner lap to 2200 PSI. Good test. POOH. Lay out Baker tools. Safety Meeting. RIH with SWS perforating guns on CSH workstring. Tag and correct CTD to PBTD of 10,321 ft BKB. Position bottom shot at 10,260 ft and shear firing head. Perforated interval: 10,205' - 10,260' (55' Total). POOH with perforating guns. Lay out CSH workstring in singles. Safety meeting. LD perf guns-all shots fired. RIH with nozzle and freeze protect wellbore to 2000' with MeOH. Blow down CT with N2. ND BOPE. Install tree cap and pressure test. Release rig at 0000 hrs 1/20/00. RECEIVED North Slope Alaska Alaska State Plane 4 PBU WOA X Pad X-24A Surveyed: 18 January, 2000 ORIG!NAi,_ S UR VEY REPORT 3 February, 2000 RECEIVED FEB 1 5 2000 Gas Cons. Commission Anchorage Your Ref: API-500292109801 Surface Coordinates: 5940363.37 N, 665476.09 E (70° 14' 35.9961" N, 148° 39' 48.3361" W) Kelly Bushing: 75.23ft above Mean Sea Level DRILLING SERVICES Survey Ref: svy9620 North Slope Alaska Sperry-Sun Drilling Services Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (~) (~) (~) 9100.00 23.500 52.100 8593.30 8668.53 9193.00 24.210 56.558 8678.36 8753.59 9225.53 36.120 56.498 8706.44 8781.67 9255.55 46.580 56.448 8728.94 8804.17 9290.33 58.890 56.388 8749.96 8825.19 9321.43 71.100 56.328 8763.08 8838.31 9352.23 78.570 56.278 8771.13 8846.36 9390.78 87.540 56.208 8775.79 8851.02 9412.93 91.760 58.498 8775.92 8851.15 9442.73 95.100 61.838 8774.14 8849.37 9476.68 96.420 68.338 8770.73 8845.96 9505.85 96.060 74.138 8767.56 8842.79 9540.25 95.540 80.818 8764.08 8839.31 9570.80 97.030 90.838 8760.72 8835.95 9621.46 94.310 102.788 8755.70 8830.93 9653.48 94.660 109.118 8753.19 8828.42 9692.38 89.740 116.858 8751.70 8826.93 9720.63 87.710 121.248 8752.33 8827.56 9751.38 83.060 126.698 8754.80 8830.03 9790.03 77.870 131.268 8761.21 8836.44 9828.10 74.090 138.478 8770.44 8845.67 9858.68 73.480 145.158 8778.99 8854.22 9876.18 72.770 150.428 8784.07 8859.30 9904.68 73.040 156.578 8792.46 8867.69 9931.08 73.740 162.908 8800.01 8875.24 Survey Report for X-24A Your Ref: API.500292109801 Surveyed: 18 January, 2000 Local Coordinates Global Coordinates Nothings Eastings Nothings Eastings (ft) (ft) (ft) (fi) 1526.87 N 1074.20 E 5941913.45 N 666516.51 1548.77 N 1104.74 E 5941936.02 N 666546.57 1557.77 N 1118.35 E 5941945.31N 666559.98 1568.71N 1134.86 E 5941956.61N 666576.24 1583.99 N 1157.88 E 5941972.40 N 666598.92 1599.57 N 1181.29 E 5941988.49 N 666621.99 1616.06 N 1206.01E 5942005.51N 666646.34 1637.30 N 1237.79 E 5942027.45 N 666677.64 1649.24 N 1256.44 E 5942039.80 N 666696.02 1664.04 N 1282.23 E 5942055.16 N 666721.49 1678.26 N 1312.85 E 5942070.05 N 666751.79 1687.58 N 1340.30 E 5942079.97 N 666779.02 1695.00 N 1373.69 E 5942088.12 N 666812.24 1697.21N 1403.93 E 5942090.99 N 666842.43 1691.23 N 1453.89 E 5942086.11N 666892.51 1682.46 N 1484.57 E 5942078.01N 666923.37 1667.29 N 1520.31E 5942063.63 N 666959.44 1653.58 N 1544.99 E 5942050.47 N 666984.41 1636.47 N 1570.40 E 5942033.92 N 667010.19 1612.51 N 1600.01 E 5942010.62 N 667040.32 1586.49 N 1626.18 E 5941985.18 N 667067.05 1563.43 N 1644.32 E 5941962.52 N 667085.70 1549.26 N 1653.24 E 5941948.55 N 667094.93 1524.90 N 1665.39 E 5941924.46 N 667107.61 1501.18 N 1674.14 E 5941900.94 N 667116.88 Alaska State Plane 4 PBU_WOA X Pad Dogleg Vertical Rate Section (°/lOOff) (~) E 447.45 E 2.083 467.97 E 36.612 477.39 E 34.844 488.81 E 35.394 504.72 E 39.261 520.89 E 24.254 537.95 E 23.269 559.87 E 21.675 572.91 E 15.835 591.59 E 19.441 614.97 E 19.804 637.16 E 19.378 665.59 E 32.963 692.98 E 24.077 741.70 E 19.739 773.47 E 23.559 812.28 E 17.117 840.26 E 23.251 870.14 E 17.782 906.43 E 20.882 940.25 E 21.069 965.52 E 29.101 978.97 E 20.646 999.12 E 23.128 1015.88 Comment Tie-in Survey Window Point Continued... 3 February, 2000 - 11:04 - 2 - DrillQuest 1.05o04e Sperry-Sun Drilling Services Survey Report for X-24A Your Ref: AP1.500292109801 Surveyed: 18 January, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 9963.08 73.560 169.588 8809.03 8884.26 1471.37 N 1681.44 E 9991.30 74.350 177.148 8816.84 8892.07 1444.45 N 1684.56 E 10022.33 74.270 175.038 8825.23 8900.46 1414.65 N 1686.60 E 10057.33 74.970 165.548 8834.53 8909.76 i381.43 N 1692.29 E 10089.05 74.790 160.448 8842.81 8918.04 i352.16 N 1701.24 E 10119.23 71.540 151.658 8851.57 8926.80 1325.78 N 1712.93 E 10153.80 66.620 147.788 8863.91 8939.14 i297.90 N 1729.18 E 10187.73 62.840 142.698 8878.40 8953.63 1272.70 N 1746.65 E 10217.05 59.060 138.478 8892.64 8967.87 1252.90 N 1762.90 E 10251.90 55.990 126.168 8911.40 8986.63 1233.12 N 1784.53 E 10285.90 50.190 121.598 8931.82 9007.05 1217.95 N 1807.06 E 10320.45 43.510 122.128 8955.43 9030.66 i204.65 N 1828.46 E 10355.00 43.510 122.128 8980.49 9055.72 1192.00 N 1848.60 E Global Coordinates Northings Eastings (ft) (ft) 5941871.30 N 667124.82 E 5941844.46 N 667128.54 E 5941814.71 N 667131.23 E 5941781.62 N 667137.65 E 5941752.55 N 667147.24 E 5941726.44 N 667159.50 E 5941698.92 N 667176.37 E 5941674.11 N 667194.38 E 5941654.67 N 667211.06 E 5941635.37 N 667233.13 E 5941620.69 N 667255.98 E 5941607.87 N 667277.67 E 5941595.67 N 667298.08 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 27.207° (14-Jan-00) The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 111.260° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10355.00ft., The Bottom Hole Displacement is 2199.59ft., in the Direction of 57.186° (True). Dogleg Rate (°llOOft) 20.038 25.896 6.552 26.217 15.532 29.878 17.658 17.550 18.011 31.051 20.155 19.367 0.000 Alaska State Plane 4 PBU WOA X Pad -- Vertical Section Comment (ft) 1033.49 1046.16 1058.86 1076.21 1095.16 1115.62 1140.88 1166.30 1188.62 1215.95 1242.45 1267.21 1290.57 Projected Survey Continued... 3 February, 2000 - 11:04 - 3 - DrillQuest 1.05.04e Sperry-Sun Drilling Services Survey Report for X-24A Your Ref: AP1-500292109801 Surveyed: ~8 January, 2000 North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9100.00 8668.53 1526.87 N 1074.20 E 9193.00 8753.59 1548.77 N 1104.74 E 10355.00 9055.72 1192.00 N 1848.60 E Comment Tie-in Survey Window Point Projected Survey Alaska State Plane 4 PBU_WOA X Pad 3 February, 2000 - 11:04 - 4 - DrillQuest ~.05.04e 8300 ,.-.. 8400 ~ 8500 (D 8600 8700 ~ o~ 8800 8900 I v 9000 9100 Tie-in Point B.P. Exploration (True) Structure : Pad X Field : Prudhoe Bay Well ' X-24AI, 50-029-21098-01 Location : North Slope, Alaska Ec]sf (fee~) -> Date plotted: 20-Jen-2OO0 Plot Refecence ;= X-24AL CeordJnetee ere in feet reference X-24. True Verttcel Depthe ere reference RKB - MSL = 75.2 Brij Potnis 267-661,3 --- Bet<er Hughel INTEO --- 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 I I I I I , I I I I I I I I ,, I I I I, I I I ,I I I I I I I I I ,I I Tie-in Point/ ~ Projected to TO RECEIVED Projected to TO ,ql Oit & Cons. Commil :m X-2¢AI Co~e113c Plon J · I I [ II I I I I I I I I I I I I 200 100 0 100 200 300 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 Verficc]l Section (feet) -> Azimut'h 110.00 with reference 1526.86 N, 1074.20 F from X-24 2OOO 1900 1800 1700 16oo A I 1500 1400 1300 1200 1100 1000 900 B.P. Exploration (True) Pad X X-24AI X-24 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : X-24AI Our ref : svy283 License : 50-029-21098-01 Date printed : 20-Jan-2000 Date created : 20-Jan-2000 Last revised : 20-Jan-2000 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 665883.554,5940129.199,999.00000,N Slot location is n70 14 36.012,w148 39 48.338 Slot Grid coordinates are N 5940365.000, E 665476.001 Slot local coordinates are 244.73 N 402.29 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED FEB 1 5 2.000 Alaska Oil & Gas Cons. Commission Anchorage B.P. Exploration (True) Pad X,X-24AI Prudhoe Bay, North Slope, Alaska SURVEY LISTING Page 1 Your ref : X-24AI Last revised : 20-Jan-2000 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C O O R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing' 9100.00 23.50 52.10 8593,33 1526.86N 1074.20E 1.21 0.00 666516.27 5941915.02 9193.00 24.21 56.56 8678,39 1548.76N 1104.75E 2.08 21.21 666546.33 5941937.59 9225.53 36.12 56.50 8706.47 1557.76N 1118.36E 36.61 30.92 666559.73 5941946.89 9255.55 46.58 56,45 8728.97 1568.70N 1134.87E 34.84 42.70 666576.00 5941958.19 9290.33 58.89 56.39 8749.99 1583.98N 1157.88E 35.39 59.10 666598.67 5941973.97 9321.43 71.10 56,33 8763.11 1599.57N 1181.31E 39.26 75.78 666621.74 5941990.06 9352.23 78.57 56.28 8771.16 1616.05N 1206.02E 24.25 93.36 666646.09 5942007.08 9390.78 87.54 56.21 8775.82 1637.29N 1237.80E 23,27 115.97 666677.39 5942029.02 9412.93 91.76 58.50 8775.95 1649.23N 1256.45E 21.68 129.40 666695.77 5942041.37 9442.73 95.10 61.84 8774.17 1664.03N 1282.25E 15.84 148.58 666721.23 5942056.72 9476.68 96.42 68.34 8770.76 1678.25N 1312.86E 19.44 172.49 666751.53 5942071.62 9505.85 96.06 74.14 8767.59 1687.57N 1340.31E 19.80 195.09 666778.76 5942081.54 9540.25 95.54 80.82 8764.11 1694.98N 1373.70E 19.38 223.93 666811.98 5942089.68 9570.80 97.03 90.84 8760.75 1697.19N 1403.95E 32.96 251.60 666842.16 5942092.56 9621.46 94.31 102.79 8755.73 1691.21N 1453.90E 24.08 300.59 666892.24 5942087.68 9653.48 94.66 109.12 8753.22 1682.44N 1484.58E 19.74 332.42 666923.10 5942079.58 9692.38 89.74 116.86 8751.73 1667.27N 1520.32E 23.56 371.19 666959.16 5942065.21 9720.63 87.71 121.25 8752.36 1653.56N 1545.00E 17.12 399.08 666984.14 5942052.04 9751.38 83.06 126.70 8754.83 1636.44N 1570.41E 23.25 428.80 667009.91 5942035.49 9790.03 77.87 131.27 8761.24 1612.49N 1600.03E 17.78 464.82 667040.05 5942012.20 9828.10 74.09 138.48 8770.47 1586,47N 1626.19E 20.88 498.31 667066.77 5941986.76 9858.68 73.48 145.16 8779.02 1563.40N 1644.33E 21.07 523.25 667085.42 5941964.10 9876.18 72.77 150.43 8784.10 1549.24N 1653.25E 29.10 536.48 667094.65 5941950.14 9904.68 73.04 156.58 8792.49 1524.87N 1665.40E 20.65 556.22 667107.33 5941926.04 9931.08 73.74 162.91 8800.04 1501.15N 1674.15E 23.13 572.56 667116.60 5941902.52 9963.08 73.56 169.59 8809.06 1471.34N 1681.44E 20,04 589.61 667124.54 5941872.89 9991.30 74.35 177.15 8816.87 1444.43N 1684.57E 25,90 601.75 667128.26 5941846.05 10022.33 74.27 175.04 8825.26 1414.62N 1686.60E 6,55 613.85 667130.95 5941816.30 10057.33 74.97 165.55 8834.56 1381.40N 1692.29E 26.22 630.56 667137.37 5941783.21 10089.05 74.79 160.45 8842.84 1352.13N 1701.24E 15.53 648.98 667146.96 5941754.15 10119.23 71.54 151.66 8851.60 1325.76N 1712.93E 29.88 668.99 667159.22 5941728.04 10153.80 66.62 147.79 8863.94 1297.88N 1729.18E 17.66 693.80 667176.09 5941700.52 10187,73 62.84 142.70 8878.43 1272.67N 1746.65E 17.55 718.83 667194.10 5941675.71 10217.05 59.06 138.48 8892.67 1252.87N 1762.90E 18.01 740.87 667210.78 5941656.27 10251.90 55.99 126.17 8911.43 1233.09N 1784.53E 31.05 767.96 667232.84 5941636.98 10285.90 50,19 121.60 8931.85 10320.45 43,51 122.13 8955.46 10355.00 43,51 122.13 8980.52 1217.92N 1807.06E 20.15 794.32 667255.69 5941622.30 1204.62N 1828.45E 19.37 818.98 667277.38 5941609.48 1191.97N 1848.60E 0.00 842.23 667297.79 5941597.28 ! 5 ~_~ Oil & · ~chorago All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from X-24 and SSTVD from RKB - MSL = 75.2 ft. Bottom hole distance is 2199.57 on azimuth 57.19 degrees from wellhead. vertical section is from tie aC N 1526.86 E 1074.20 on azimuth 110.00 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad X,X-24AI Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : X-24AI Last revised : 20-Jan-2000 Comments in wellpath MD SSTVD Rectangular Coords. Comment 9100.00 8593.33 1526.86N 1074.20E Tie-in Point 10355.00 8980.52 1191.97N 1848.60E Projected to TD NO Targets associated with this wellpath TRA' SM/TTAL . ~Active Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St, ^-?_-borage, Alaska 99501 RE' Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of · Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petrotechnical Data Center MB'3-3 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT{S) OR CD-ROM F~LM BLUEL~NE X-24ai 1-18-2000 Open Hole I I 1 . ' Res. Eval. CH I I 1 Mech. CH Caliper Survey R ~_ C El\[E, . D 1 1RptBL°r Signed · ~ Da~e · Print Name: ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 F~x:(907)659-23 ]4 E-mai|: pdspmdho¢~NAS00.net %Vcbske: www.mcmorvlo~.com TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit X-24A BP Exploration (Alaska) Inc. Permit No: 199-125 Sur Loc: 244'NSL, 402'WEL, Sec. 06, TI0N, RI4E, UM BtmholeLoc. 1441'NSL, 1521'EWL, Sec. 05, T10N, R14E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P.E. Chair BY ORDER OF THE ~OMMISSION DATED this ~_~¥e~ day of December, 1999 dlf/Enclosures cc: Department of Fish & G~'une. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .--- STATE OF ALASKA -- ALAS. , OIL AND GAS CONSERVATION CC MISSION PERMIT TO DRILL 20 AAC 25.005 !la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 75.23' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028313 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 244' NSL, 402' WEL, SEC. 06, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 1793' NSL, 703' EWL, SEC. 05, T10N, R14E, UM X-24A At total depth 9. Approximate spud date Amount $200,000.00 1441' NSL, 1521' EWL, SEC. 05, T10N, R14E, UM 01/01/2000 12'i'"Distance to neares;[' property line J 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028312, 3758' MDI No Close Approach 2560 10495' MD / 9050' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 9200' MD Maximum Hole Angle 104° Maximum surface 2344 psig, At total depth (TVD) 8800' / 3400 psig 18. Casing Program Setting Depth Size Specifications Top Bottom. Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 1595' 8900' 8409' 10495' 9050' 95 cuft Class 'G' ,, DEC ~on$. Gorrlmlssion Present well condition summary~,/ t~~~t AL Total depth: measured 9717 feet Plugs (measured) IBP at 9472' MD (11/97) true vertical 9223 feet Effective depth: measured 9676 feet Junk (measured) Fill at 9467' MD (11/97) true vertical 9187 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2636' 13-3/8" 3720 cuft Permafrost II 2671' 2671' Intermediate 9115' 9-5/8" 1856 cuft Class 'G', 345 cuft PF 9150' 8714' Production Liner 833' 7" 300 cu ft Class 'G' 8884'- 9717' 8470' - 9224' Perforation depth: measured 9192'- 9214' (Sag River); 9306'- 9356', 9366'- 9434' (Ivishak) Sqzd: 9446' - 9462', 9471' - 9513' true vertical 8753'-8773' (Sag River); 8856'-8902', 8911'-8972' (Ivishak) Sqzd: 8983'- 8997', 9005'- 9043' 20."Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Ted Stagg Title CT Drilling Engineer Date Commission Use Only Permit Number ,..,.., _.,~ APl Number [ Approval Date. I See cover letter /?'~Z~--/,?.,,'~ I 50-029-21098-01 /...,~,-" --~.-'~ -"~/~; for other requirements Conditions of Approval: Samples Required []Yes I~No Mud Log Required []Yes ~i~No Hydrogen Sulfide Measures [~Yes [] No Directional Survey Required J~Yes [-] No Required Working Pressure for'BOPE [-I2K; J~3K; I-]4K; 1'-ISK; []10K; I--I15K Other: ORIGINAL by order of SiGNED. BY' Commissioner the commission Date//~~,,~ Approved By Robert_ N_ C~hd,-_:" ....... Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX X-24ai Sidetrack Summary of Operations: X-24 is being sidetracked to improve injection conformance. Zone 4B is the targeted injection interval. This sidetrack will be conducted in two phases. Phase 1: Set Whipstock, squeeze perfs: Planned for Dec. 22-24, 1999. · A Mechanical Integrity Test was successfully performed, with AOGCC witness, on 4/28/99. · The whipstock drift and Kinley caliper were run on 5/10/99. · A Schmoo-B-Gone treatment was pumped on 5/8/99. · E-Line will be used to set the mechanical whipstock at 9,190' MD about 12/22/99. · Service coil will cement squeeze existing perfs & pressure test to 1500 psi on 12/23-24/99. Phase 2: Mill Window, Drill & Complete sidetrack: Planned for Jan. 1, 2000. Directional drilling coiled tubing equipment will be rigged up to mill the window then drill and complete the directional hole as per attached plan to planned TD of 10,495' MD (9,050' TVDss). Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.7 - 8.8 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 8,900' MD and cemented with approx. 17 bbls. cement to bring cement 200 fi above the window. The liner will be pressure tested to 2200 psi and perforated with coiled tubing conveyed guns. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 fi. No gyro will be run. Logging · A Gamma Ray Icg will be run over all of the open hole section. · Open hole will be logged with Memory Induction Icg. · No Cement Evaluation Log is planned on the 2 7/8" liner as isolation above the Sag R. is good and will not be compromised by the sidetrack. A copy of the original CBL is attached. Hazards One fault in the Shublik with lost circulation potential will be crossed with this well path. Reservoir Pressure Res. pressure is 3400 @ 8800ss. Max. surface pressure with gas (0.12 psi/fi) to surface is 2344 psi. o~1oo X-24 2,000 X-24ai Case 113c 12/7/99 1,000 I I I 5OO 00 1,200 1,700 X distance from Sfc Loc 2,200 IWell Name X-24 I CLOSURE I Distance 2,262 ft i Az 57 de~ NEW HOLE E/W(X) N/S (Y) KickOff 1,073 1,574 TD 1,892 1,239 State Plane 667,368 5,941,604 Surface Loc 665,476 5,940,365 DLS de~l/100 Tool Fac~ Length Curve 1 6 OI ~,0 Curve 2 33 0 235 Curve 3 22 90 285 Curve 4 22 120 110 Curve 5 14 140 180 Curve 6 14 - 140 455 1,295 Drawn: ######## 13:40 Plan Name: Case 113c :4 rtical Section 0 .... 9,050 ............................... Path Distance (Feet) 500 1,000 1,500 2,000 t I I Angle @ K,O,= 24 deg X-24ai case 113c 12/7/99 Tot Drld:1295 ft 10495 TD Marker Depths ~Ori~l Wellbore TSHU I 8,6981ft TVD TSAD I 8,7741ft TVD IKick Off I 8,6851ft TVD 9,2001ft MD IDeprtr @KO 1,920 ft I MD KO Pt 9,200I MD New Hole 1295I I Total MD lO,495I TVD TD 9,o5oI DLS de~/100 Tool Face Len~lth Curve 1 ' 6 0 ~0 Curve 2 33 0 235 Curve 3 22 90 285 Curve 4 22 120 110 Curve 5 14 140 180 Curve 6 14 - 140 455 1,295 Drawn: ######## 13:40 Plan Name: Case 113c TREE: 4" ClW WELLHEAD: MCEVOY ACTUATOR: AXELSON X-24ai Proposed Completion KB. ELEV = 75.23' BF. ELEV = 39.83' 13-3/8", 72 #Iff, L-80, BTRS CMT'd SSSV LANDING NIPPLE (OTIS DBE)(3.813" ID) 2148' KOP: 4600 MAX ANGLE: 29 4-1/2", 12.6#/ft, L-80, IPC BTRS TUBING TUBING ID: 3.958" CAPACITY: .01522 BBL/FT 7" LINER 8884' 9-5/8", 47#/ft,I9150' I~ L-80, BTRS ' 2 7/8" liner cemented to 200 ft above whipstock. PERFORATION SUMMARY REF LOG: GEARHART - BHCS 4-17-84 33SIZE SPF INTERVAL OPEN/SQZ'D 3-3/8 6 9192-9214 SQZD/6-30-90 3-1/8 4 9306-9355 .... 3-1/8 4 9368-9428 .... 2-3/4 4 9446-9462 .... 3-1/8 4 9471-9513 .... 3/8" 6 9192 - 9214' OPEN/7-29-90 -3/8 4 9306-9356 open 8-17-90 3-3/8 2 9966-9434 open 8-17-90 PBTD I 9676' I 7", 26 #/ft, L-80, IJ4S J 9717' [ L SLIDING SLEEVE OTIS XA I 8767' ( 3.813" MIN. ID) TUBING SEAL ASSY. J 881 9' I PBR 9-5/8" PACKER I (DOT 3H)(3.958"ID) 8843' 4-1/2", 12.6#/ft, L-80 TAILPIPE 4-1/2 .... X" NIPPLE I (OTIS) (3.813" ID) I 8883' 4-1/2 .... XN" NIPPLE I 891 6' ( OTIS ) ( 3.725" ID) 4-1/2" TBG TAILI 8949' (DOT SOS)(3.958"ID) (ELMD) I 8980' Abandonment cement downsqueezed past whipstock l~P;SETAT 9262! ON 7~26290 ,' & SCALE ~ ~ ~:~,~_ ~ ~.~:::i:~i~ ~;~.~ i~ ~..,. ~....,.-: LOG DEEP = .:, ]:' 23/8"CT~ J Pack-Off Lubricat°rt X-24ai CT Drilling & Completion BOP U.I 12" 36" 22.5"I 7 1/16" Annular Blind/Shear 71/16" Pipe/Slip 7 1/16' x 5,000 psi 2 3/8" 18" 38" Slips 71/16" Pipe 7/8" 3/8" SWAB OR MASTER VALVE VE.O0. AL ASKAO ][L,A O0 . DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT N'~T ~ , 120999 CK 120999A 100. O0 100. O0 HANDLING INST: S/H TERRI HUBBLE XJ&28 THE ATTACHED CHECK IS '" PAYMENT FOR rTE:MS DESCRIBED A~VE. ~ 100. O0 1,00,. O0 ~i"$T ~,TIOI~i~,:BANK:~iF ASHLAND No. H, :'.:,,::1. 5 9'9 4 8:. ':': " ::A:~!'~ '.~.IUATE,~ .:¥:,' ..... · ...... ' ;'.v. k'"'" ........ ': ' "A~I'ON~:"CI~,~NK ..... · ' CONS~i~ED ,coM~RClA'~i'AC~U~' - '~EV~XhD, dH'lO .... : .... .... .. .:,..::::::, :.. :",.','. . , .... . : · :.:, ,: .. .~ O0 ~ 5~4~::":::: PAY To:"The:,i::, :ALASKA OIL AND :::~AEl:i;.'k:,,. :'.':': :~RDER? ?:::: '~DNS~VAT Z ON :':::COHHiGS''I oN ANCHORAOE AK 99501 NO?VALID AFTER 120 D~¥$ ,,:. .... .~ .~ , WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ c/~'~.,/Z~"-_('~ INIT CLASS ADMINISTRATION DATE WELL NAME .~.--'~b~../ ,~'-~,'~/~ PROGRAM: exp . · ,r /~b/l'/~t~__~ GEOL AREA ENGINEERING A~P~R DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... GEOLOGY 14. Conductor string provided .............. . ..... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~ o c:~::~ .psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... ~, N .DATE 31. Data presented on potential overpressure zones ....... .,¥~d Y N 32. Seismic analysis of shallow gas zones ............. ,/t/,~ Y N 33. Seabed condition survey (if off-shore) ............. ,,Vk? ~ N 34. Contact name/phone for weekly progress reports [exploratory only]~_~ N ANNULAR DISPOSAL 35. APPR DATE With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N dev ~ redrll ¢/ serv v'/ wellbore seg ann. disposal para req ~ UNIT# C~'~//~. ~'~") ON/OFF SHORE ~-)',~- GEOLO~,~Z~ ENGINEERING: UlC/Annular COMMISSION: ~P-~~ BEW I "~ ~ WM "-'"-~' DWJ JDH RNC TEM ~ CO ~ ,~/~]~ Comments/Instructions: c:\msoffice\wordian\diana\checklist (rev. 09~27~99) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. T° 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 APPENDIXi ,. No special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed May 17 16:43:25 2000 Reel Header Service name ............. LISTPE Date ..................... 00/05/17 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date'. .................... 00/05/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE BIT SIZE 1ST STRING 3.750 2ND STRING 3.750 3RD STRING 3.750 PRODUCTION STRING MWD RUN 1 AK-MW- 90226 B. JAHN R. WHITLOW/J (IN) X-24A 500292109801 BP Exploration Sperry Sun 17-STAY-00 (Alaska), Inc. MWD RUN 2 MWD RUN 3 AK-MW-90226 AK-MW- 90226 B. JAHN B. JAHN R. WHITLOW/J R. WHITLOW/J 8 10N 14E 244 402 75.23 .00 38.43 RECEIVED P-5 P. O00 Al~sk~ Oil & G~s Cons. C, ommission An~ho[~ge CASING DRILLERS SIZE (IN) DEPTH (FT) 7.000 9193.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 - 3 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC LOG OF 01/18/00 (PDS Ga) WITH A KBE OF 75.23' AMSL. KICKOFF POINT FOR THIS WELLBORE IS AT 9193' MD, 8678' SSTVD (TOP OF WHIPSTOCK). 4. MWD RUNS 1 - 3 REPRESENT WELL X-24A WITH API # 50-029-21098-01. THIS WELL REACHED A TOTAL DEPTH OF 11355' MD, 8981' SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED RATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER:. 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 9182.5 10317.0 ROP 9213.5 10347.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 9182 5 9186 5 9192 5 9213 0 9223 0 9242 0 9249 0 9252 5 9255 5 9257.5 9267.5 9283.5 9288.0 9295 5 9298 5 9303 0 9307 0 9310 5 9316 0 GR 9182.0 9186 0 9191 0 9212 0 9221 0 9240 5 9248 0 9252 0 9255 0 9256 5 9266 0 9283 0 9288 0 9295 0 9298 5 9303 5 9307 0 9310 5 9316 5 EQUIVALENT UNSHIFTED DEPTH 9323 0 9329 0 9332 0 9337 0 9339 5 9355 0 9363 0 9369 5 9375 0 9379 5 9397 5 9401 5 9418 0 9420 5 9422 5 9433 5 9435 5 9436 5 9444 5 9476 0 9486 5 9498 0 9572.0 9582 0 9590 5 9595 0 9603 5 9609 5 9619 5 9633 0 9642 0 9656 5 9677 0 9711 5 9727 0 9738 0 9749 5 9757 0 9761 5 9769 5 9774 0 9785 5 9824 0 9839 0 9843 5 9863 5 9924 0 9939 5 9961 5 10005 5 10017 5 10044 5 10056 0 10121 5 10132 0 10153 5 10193 5 10198 0 10206 0 10218 0 10220 0 10241 0 10249 5 10262 0 10268 5 10287 5 10293 5 10302 0 9323 . 0 9329.0 9331.5 9336.5 9339.0 9354.5 9361.5 9367.5 9373.5 9378.5 9396.5 9400 5 9417 5 9420 0 9423 0 9433 0 9436 0 9437 5 9444 5 9475 0 9487 0 9497 5 9570 5 9581 0 9589 0 9593 5 9602 0 9609.0 9619 0 9634 0 9642 5 9654 5 9676 0 9707 5 9723 5 9735 0 9746 5 9755 0 9758 0 9766 5 9773 0 9790.5 9829.0 9845.0 9850.0 9867.5 9930.0 9945.0 9966.5 10011.0 10023.5 10050 0 10061 0 10127 5 10135 0 10158 0 10197 5 10202 0 10210 0 10222 5 10225 0 10243 5 10251 0 10265 0 10272 0 10290 5 10302 0 10310 0 10311.0 10318.5 10347 · 5 10355 · 0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 $ REMARKS: MERGED MAIN PASS. $ MERGE TOP MERGE BASE 9182.0 9321.0 9321.5 9375.0 9375.5 10355.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9182.5 10347.5 9765 2331 ROP MWD FT/H 0.79 2058.69 79.8973 2269 GR MWD API 20.77 1088.75 99.9345 2270 First Reading 9182.5 9213.5 9182.5 Last Reading 10347.5 10347.5 10317 First Reading For Entire File .......... 9182.5 Last Reading For Entire File ........... 10347.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/17 Maximum Physical Recordo.65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NI/MBER: 2 RAW MWD Curves and lo9 header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9182.0 ROP 9212.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9291.0 9321.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Lo99in9 Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacin9 ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 15-JAN-00 Insite 7.74 Memory 9321.0 23.5 61.0 TOOL NUMBER 007 3.750 Sea Water 8.30 .0 8.0 1800 .0 .000 .000 .000 · 000 .0 167.0 .0 .0 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 9182 9321 9251.5 279 ROP MWD010 FT/H 7.1 61.54 21.898 218 GR MWD010 API 64.53 729.42 174.583 219 First Reading 9182 9212.5 9182 Last Reading 9321 9321 9291 First Reading For Entire File .......... 9182 Last Reading For Entire File ........... 9321 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NIIMBER: 3 R3tW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9291.5 9344.5 ROP 9321 . 5 9375 . 0 $ LOG HEADER DATA DATE LOGGED: 15-JAN-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 9375.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/qGLE: MAXIMIIM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE A/qD CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MLrD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPER3kTURE: MUD FILTR3kTE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STA/qDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 71.0 78.6 TOOL NUMBER 007 3.750 Sea water 8.30 .0 8.0 0 .0 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 .0 154.5 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9291.5 9375 9333.25 168 ROP MWD020 FT/H 9.15 222.37 38.2898 108 GR MWD020 API 73.15 170.11 114.603 107 First Reading 9291.5 9321.5 9291.5 Last Reading 9375 9375 9344.5 First Reading For Entire File .......... 9291.5 Last Reading For Entire File ........... 9375 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/17 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEA/DER FILE NUMBER: 4 PJIW MWD Curves and log header data for each bit run in separate files. BIT RUN NI/MBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9345.0 ROP 9375.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10324.5 10355.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE A_ND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MI/D PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (0HMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 17-JAN-00 Insite 7.74 Memory 10355.0 43.5 97.0 TOOL NUMBER 002 3.750 Sea water 8.65 .0 9.0 23500 8.0 .000 .000 .000 .0 137.5 .0 MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STAArDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 Name Service Unit Min Max Mean Nsam DEPT FT 9345 10355 9850 2021 ROP MWD030 FT/H 0.79 2058.69 89.691 1960 GR MWD030 API 20.77 1088.75 90.3794 1960 First Last Reading Reading 9345 10355 9375.5 10355 9345 10324.5 First Reading For Entire File .......... 9345 Last Reading For Entire File ........... 10355 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/17 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/05/17 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/05/17 Scientific Technical Services Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File