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HomeMy WebLinkAbout209-099CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector L-223 (PTD #2090990) MIT-IA Passed Date:Tuesday, April 4, 2023 9:31:48 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 31, 2023 10:22 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector L-223 (PTD #2090990) MIT-IA Passed Mr. Wallace, My apologies. I classified this well as operable on 03/28/23 (see below) but failed to send you a separate note. Injector L-223 (PTD #2090990) DGLV was set in sta #7 on 03/07/23 and passed AOGCC MIT-IA on 03/10/23. Subsequent monitoring of casing pressure has shown no tubing by IA pressure communication. AOGCC has agreed that no AA is required for continued injection and well is now classified as OPERABLE. 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: Tuesday, March 28, 2023 3:14 PM To: Brodie Wages <David.Wages@hilcorp.com>; Claire Mayfield <Claire.Mayfield@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Ron Phillips - (C) <Ron.Phillips@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: OPERABLE: Injector L-223 (PTD #2090990) MIT-IA Passed All, Injector L-223 (PTD #2090990) DGLV was set in sta #7 on 03/07/23 and passed AOGCC MIT-IA on 03/10/23. Subsequent monitoring of casing pressure has shown no tubing by IA pressure communication. AOGCC has agreed that no AA is required for continued injection. 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 <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 10, 2023 1:05 PM To: Brodie Wages <David.Wages@hilcorp.com>; Claire Mayfield <Claire.Mayfield@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Ron Phillips - (C) <Ron.Phillips@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: Update: UNDER EVALUATION: Injector L-223 (PTD #2090990) UE clock extended All, An AOGCC witnessed MIT-IA passed to 3398 psi on 03/10/23. The IA re-pressurization appears to have stopped after a DWFR was set in Sta #7. The AOGCC has granted an extension of 28-days for continued monitoring and to progress the AA application. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Friday, February 17, 2023 2:21 PM To: Brodie Wages <David.Wages@hilcorp.com>; Claire Mayfield <Claire.Mayfield@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; akimsuser@hilcorp.com; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Ron Phillips - (C) <Ron.Phillips@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: Update: UNDER EVALUATION: Injector L-223 (PTD #2090990) anomalous IA re-pressurization All, Fullbore performed an offline, passing MIT-IA to 2882 psi on 02/15/23. The AOGCC has granted us approval to put the well back on produced water injection for continued diagnostic work. The well will remain UNDER EVALUATION and operations will place the well back on PWI when feasibly possible. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 12, 2023 3:28 PM To: Brodie Wages <David.Wages@hilcorp.com>; Claire Mayfield <Claire.Mayfield@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com>; PB EOC Specialists <PBEOCSpecialists@hilcorp.com>; PB Wells Optimization Engineers <PBWellsOptimizationEngineers@hilcorp.com>; PBW GC2 Field Lead Operator <PBWGC2FieldLeadOperator@hilcorp.com>; PBW GC2 Foreman <PBWGC2Foreman@hilcorp.com>; PBW GC2 Wellpad HUQ <PBWGC2WellpadHUQ@hilcorp.com>; PBW GC2 Wellpad LV <PBWGC2WellpadLV@hilcorp.com>; PBW GC2 Wellpad MN <PBWGC2WellpadMN@hilcorp.com>; PBW GC2 Wellpad RJ <PBWGC2WellpadRJ@hilcorp.com>; PBW GC2 Wellpad S <PBWGC2WellpadS@hilcorp.com>; PBW GC2 Wellpad W <PBWGC2WellpadW@hilcorp.com>; PBW GC2 Wellpad Z <PBWGC2WellpadZ@hilcorp.com>; PBW GC2 West Field Lead Operator <PBWGC2WestFieldLeadOperator@hilcorp.com>; PBW PCC Leads <GC3ProdContCenterLeads@hilcorp.com> Cc: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; John Menke <jmenke@hilcorp.com>; Kevin Brackett <Kevin.Brackett@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Ron Phillips - (C) <Ron.Phillips@hilcorp.com>; Stan Golis <sgolis@hilcorp.com> Subject: UNDER EVALUATION: Injector L-223 (PTD #2090990) anomalous IA re-pressurization All, Injector L-223 (PTD #2090990) had an IA bleed performed on 02/11/2023. The pressure was bled from 1620 psi to 500 psi. On 02/12/23 the IAP pressure climbed back to 1634 psi and cannot be contributed to any rate or thermal changes. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Operations will shut-in and freeze protect the well when feasibly possible. Well Integrity will report the anomaly to the AOGCC within 24 hours. Plan forward: 1. DHD: Offline MIT-IA 2. Fullbore (pending): AOGCC witnessed MIT-IA if offline MIT-IA passes 3. Well Integrity (pending): Apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE: Request to put Injector L-223 (PTD #2090990) online for continued diagnostics Date:Tuesday, March 14, 2023 1:30:12 PM Attachments:image001.pngimage002.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Friday, March 10, 2023 10:07 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Re: UPDATE: Request to put Injector L-223 (PTD #2090990) online for continued diagnostics Andy, Additional 28 days monitoring and diagnostics is approved. Regards, Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 10, 2023 9:34:45 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UPDATE: Request to put Injector L-223 (PTD #2090990) online for continued diagnostics Mr. Wallace, Further monitoring did prove the well has IA re-pressurization while online. An AOGCC witnessed MIT-IA was conducted on 03/10/23 and passed to 3398 psi. The passing MIT-IA confirms mechanical integrity; however, it is suspected that the intermittent communication is occurring when the feed thru packer @ 11022’ MD is exposed to injection pressure in the Nb interval. Slickline replaced station #7 injection valve with a dummy valve on 03/07/23 to cease injection into the Nb interval and the subsequent daily pressure reads indicate the IA re-pressurization has stopped. Hilcorp is requesting an additional 28-day online period to continue monitoring with the Nb interval dummied off and progress an AA application. Please respond with any questions or concerns. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Wednesday, February 15, 2023 5:12 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: [EXTERNAL] RE: Request to put Injector L-223 (PTD #2090990) online for continued diagnostics Andy, Evaluation under produced water injection is approved. Lets revisit this before - or at 28 days. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.govCONFIDENTIALITY 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 ofsuch 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: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, February 15, 2023 4:23 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Request to put Injector L-223 (PTD #2090990) online for continued diagnostics Mr. Wallace, Injector L-223 (PTD # 2090990) was shut-in and freeze protected on 02/12/23 after the anomalous IA pressure and bleed response noted in the previous email. Fullbore performed a non- AOGCC witnessed offline passing MIT-IA on 02/15/23 to 2,882 psi. Due to the initial event occurring with the well online, we would like to conduct further diagnostics with the well on injection under the assumption that the well temperature may play a role in the IA pressure responses previously seen. Hilcorp is requesting your approval to put the well back on Produced Water Injection to monitor for any intermittent IA re-pressurization. An online AOGCC witnessed MIT-IA will be conducted at the end of the evaluation period to verify operability and/or to support an AA request if necessary. Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 12, 2023 3:35 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-223 (PTD #2090990) anomalous IA re-pressurization Mr. Wallace, Injector L-223 (PTD #2090990) had an IA bleed performed on 02/11/2023. The pressure was bled from 1620 psi to 500 psi. On 02/12/23 the IAP pressure climbed back to 1634 psi and cannot be attributed to any rate or thermal changes. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Operations will shut-in and freeze protect the well. Plan forward: 1. DHD: Offline MIT-IA 2. Fullbore (pending): AOGCC witnessed MIT-IA if offline MIT-IA passes 3. Well Integrity (pending): Apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1-1/16" (7W WELLHEAD = FMC ANGLE AT TOP PE RF_ 47-@11094- 7°@11094'Note: ACTUATOR= LEO SPF KB. EL BI = 1T-1%112" Opn/Sgz DATE 4-1/2" X 312" XO, ELF. E LEV = 25.8 O 10/19/09 4-1/2" =2.992" KOP= 11275- 11328 O Max Angle = '8" @ 9965 COPDIJCTOR nnh Im LTL = 11 19e 11370-11418 L-223 !35/8'-C56L=80 BTC, ID=8.84" 6r 7" CSG, 26/J, L-80 TC11 XO TO L-80 BTC 7594' - 17" MARKE R JONT w / RA TAG 7" X 312" FES DOUBLE F® THRU PKR D = 2.965" Minimum ID = 2.75" @ 11727' 3-1/2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: SLB LJSET 10/21/09 ANGLE AT TOP PE RF_ 47-@11094- 7°@11094'Note: Note-Refer to Production DB for historical perf data SIZE SPF ZONE 14T9RVAL Opn/Sgz DATE 4-1/2" 5 Nb 11092-11120 O 10/19/09 4-1/2" 5 OA 11275- 11328 O 10/19/09 4-1/2" 5 Oba 11370-11418 O 10/19/09 4-1/2" 5 OBc 11516-115" O 10/19/09 4-1/2" 5 OBd 11588-11655 O 10/19/09 312" TBG, 92H, L-80 TCI, .0087 bpf, D = 2.992" 71750' PBTD11811' - 7" CSG, 26N, L-80 BTC -M, .0383 bpf, D = 6276" 11893' JAr l T M I O: ffC & RcwujmR A J V ffnf ON MI — HES Fi02 @ 11022' IS "FULL TO RELEASE BUT CAN ALSO BE REAS® BY PRESS. DO NOT EXCEED 2000 PSI ON THE A w /OUT PEWORMNG TBG Rn%/ M 7JrrAI r.cP nm r-q*Jr ., aaF-"- 1006' 9-58" TAM PORT COLLAR 4518' 31/2" FES X NP, ID=2.813" WATER INJECTION MANDRELS ET MD TVD DEV TYPE VLV LATCH PORT DATE 8 11065 4436 48 W.0 HW -H DMY RK 0 10/22/09 7 11133 4482 47 Wvr H N -G R15 XJR RK 16L 12/29/09 6 11329 4616 47 MMIG-FINN-F P-15 XJR RK 12L 12/29/09 5 11386 4655 47 MC HW -E DMY RK 0 10/22/09 4 11434 4687 47 MCHC -D P-15 XJR RK 10L 12/29/09 3 11500 4732 46 LrTr HW -C DMY RK 0 10/22/09 2 11547 4765 45 bWHW-B DMY RK 0 1229/09 1 11674 4856 45 Wvr HW -A DMY RK 0 1022/09 s-vc rvrxv JlNl�Lt selvxnc, Iu=�.aac 11225' -1 7" X 3112" FES SINGLE F® THRU RtR D = 2.965- 1123W 312" NDPG SNGLEGAUGE ID=2.992" 7" X 3112" FEES SINGLE F® THRU RCR, D = 2965- 11 3W 965" 11360' 312' NDPG SINGLE GAUGE, D = 2.992' 11466- 11480' 7" X 312" FES SINGLE F® THRU PKR D = 2.965" 1312" NDPG SINGLEGALJGE ID=2.992" I 11569' 1-17" X 312" FES SINGLE F® THRU PKR D = 2.965" 11727' 11�75� 13112" FES X NP, ID = 2.813" I 1312" FES XN NP, ID=2.75" 1 312" HACPA PLUG (1027/09 DATE REV BY COMMENTS DATE REV BY COMMENTS 1027/09 WES OEBGINAL COMPLETION 0327/11 MBM/PJC TUBING CORRECTIONS 11/04/09 SV DRLG HO CORRECTIONS 0125/18 EZ/JMD ADDED SPRING WEIGHT TO WF 12/15/09 TWIPJC DRLG DRAFT CORRECTION 02102/10 JAF/PJC WFR C/O(12J29/09) 02115/11 MB/JMD ADDED SSSV SAFETY NOTE 02/27/11 MW/PJC SFTY NOTE HES PKR'S 31/2" WLEG, D = 2.992" ORION UNIT WELL: L223 PERMIT No: 2090990 API No: 50-029-23415-00 SEC 34, T12N, R11 E, 2554' FSL & 1521' FWL Hilcorp North Slope, LLC MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, April 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-223 PRUDHOE BAY UN ORIN L-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/17/2023 L-223 50-029-23415-00-00 209-099-0 W SPT 4407 2090990 3200 1348 1357 1353 1348 0 0 0 0 OTHER P Kam StJohn 3/10/2023 MIT-IA to 1.0 times Anticipated surface pressure (Max MI header pressure = 3200psi) to inform AA Request. 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 UN ORIN L-223 Inspection Date: Tubing OA Packer Depth 123 3540 3425 3398IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230310110739 BBL Pumped:8.3 BBL Returned:7 Monday, April 17, 2023 Page 1 of 1 5(9,6(' 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 5HYLVHGPLQ7XELQJSUHVVXUH 1353 5HYLVHGPLQ7XELQJSUHVVXUH James B. Regg Digitally signed by James B. Regg Date: 2023.04.17 14:14:06 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, April 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-223 PRUDHOE BAY UN ORIN L-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/05/2023 L-223 50-029-23415-00-00 209-099-0 W SPT 4407 2090990 3200 1348 1348 1357 1348 0 0 0 0 OTHER P Kam StJohn 3/10/2023 MIT-IA to 1.0 times Anticipated surface pressure (Max MI header pressure = 3200psi) to inform AA Request. 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 UN ORIN L-223 Inspection Date: Tubing OA Packer Depth 123 3540 3425 3398IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230310110739 BBL Pumped:8.3 BBL Returned:7 Wednesday, April 5, 2023 Page 1 of 1 9 9 9 9 9 9 9999 9 9 AA Request. James B. Regg Digitally signed by James B. Regg Date: 2023.04.05 16:24:36 -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: Request to put Injector L-223 (PTD #2090990) online for continued diagnostics Date:Wednesday, February 15, 2023 5:13:27 PM Attachments:image001.png From: Wallace, Chris D (OGC) Sent: Wednesday, February 15, 2023 5:12 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: Request to put Injector L-223 (PTD #2090990) online for continued diagnostics Andy, Evaluation under produced water injection is approved. Lets revisit this before - or at 28 days. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.govCONFIDENTIALITY 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: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, February 15, 2023 4:23 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Request to put Injector L-223 (PTD #2090990) online for continued diagnostics Mr. Wallace, Injector L-223 (PTD # 2090990) was shut-in and freeze protected on 02/12/23 after the anomalous IA pressure and bleed response noted in the previous email. Fullbore performed a non- AOGCC witnessed offline passing MIT-IA on 02/15/23 to 2,882 psi. Due to the initial event occurring with the well online, we would like to conduct further diagnostics with the well on injection under the assumption that the well temperature may play a role in the IA pressure responses previously seen. Hilcorp is requesting your approval to put the well back on Produced Water Injection to monitor for any intermittent IA re-pressurization. An online AOGCC witnessed MIT-IA will be conducted at the end of the evaluation period to verify operability and/or to support an AA request if necessary. Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 12, 2023 3:35 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-223 (PTD #2090990) anomalous IA re-pressurization Mr. Wallace, Injector L-223 (PTD #2090990) had an IA bleed performed on 02/11/2023. The pressure was bled from 1620 psi to 500 psi. On 02/12/23 the IAP pressure climbed back to 1634 psi and cannot be attributed to any rate or thermal changes. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Operations will shut-in and freeze protect the well. Plan forward: 1. DHD: Offline MIT-IA 2. Fullbore (pending): AOGCC witnessed MIT-IA if offline MIT-IA passes 3. Well Integrity (pending): Apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector L-223 (PTD #2090990) anomalous IA re-pressurization Date:Wednesday, February 15, 2023 8:45:38 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, February 12, 2023 3:35 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-223 (PTD #2090990) anomalous IA re-pressurization Mr. Wallace, Injector L-223 (PTD #2090990) had an IA bleed performed on 02/11/2023. The pressure was bled from 1620 psi to 500 psi. On 02/12/23 the IAP pressure climbed back to 1634 psi and cannot be attributed to any rate or thermal changes. The well is now classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Operations will shut-in and freeze protect the well. Plan forward: 1. DHD: Offline MIT-IA 2. Fullbore (pending): AOGCC witnessed MIT-IA if offline MIT-IA passes 3. Well Integrity (pending): Apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector L-223 (PTD #2090990) Requires online AOGCC MIT-IA Date:Tuesday, January 10, 2023 11:51:41 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, December 31, 2022 6:49 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Injector L-223 (PTD #2090990) Requires online AOGCC MIT-IA Mr. Wallace, Injector L-223 (PTD #2090990) was made not operable due to being shut in and missing the required 4 year AOGCC MIT-IA. The well is operationally ready to be placed on injection. At this time, the well is classified as OPERABLE. AOGCC witnessed MIT-IA will be performed once the well is thermally stable for regulatory compliance. 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 <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, October 6, 2021 1:15 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector L-223 (PTD #2090990) for tracking purposes Mr. Wallace, Injector L-223 (PTD #2090990) is due for an AOGCC witnessed MIT-IA. The surface kit needed repairs and the well has not been placed on injection to date. The well will go back to NOT OPERABLE status until injection is ready to commence and an AOGCC witnessed MIT-IA can be performed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Thursday, May 27, 2021 6:21 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS-PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2-WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW- GC2-WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com> Subject: OPERABLE: Injector L-223 (PTD #2090990) MIT-IA Passed All, Injector L-223 (PTD #2090990) passed MIT-IA on 05/25/21 and 05/26/21. Previous reports of failing MIT-IA from 2011 have been found to be inaccurate. The passing MIT-IA demonstrates two competentwell barriers. The well is now classified OPERABLE. An AOGCC MIT-IA will be conducted once the well is thermally stable. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 ___________________________________________ From: AK, D&C Well Integrity Coordinator Sent: Sunday, May 22, 2011 6:32 AM To: 'Maunder, Thomas E (DOA)' <tom.maunder@alaska.gov>; 'Regg, James B (DOA)' <jim.regg@alaska.gov>; ''Schwartz, Guy (DOA' <guy.schwartz@alaska.gov>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPSGC2 Field O&M TL <AKOPSGC2FieldOMTL@BP.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Prod Controllers <AKOPSProdControllers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; AK, D&C Wireline OperationsTeam Lead <AKDCWirelineOperationsTeamLead@BP.com>; AK, D&C Well Services Operations Team Lead <AKDCWellServicesOperationsTeamLead@BP.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com> Cc: Greaves, Damien C <greadc@bp.com>; Walker, Greg (D&C) <Greg.Walker2@bp.com>; Clingingsmith, Mike J (Swift) <Mike.Clingingsmith@BP.com> Subject: NOT OPERABLE: Injector L-223 (PTD #2090990) Well Secured with Load and Kill All, Injector L-223 (PTD # 2090990) has been secured with kill weight fluid and re-classified as Not Operable. An LDL will be run to determine a plan forward for repair. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator@BP.com _____________________________________________ Well Integrity Coordinator ay 01, 2011 10:15 AM omas E (DOA)'; 'Regg, James B (DOA)'; ''Schwartz, Guy (DOA'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D&CWireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel,Ryan ; Greaves, Damien C EVALUATION: Injector L-223 (PTD #2090990) IA pressure tracking tubing pressure All, Injector L-223 (PTD #2090990) is a new well that has not yet been put on initial injection. Coil tubing was on the well 4/30/11 to set Water Flood Regulators and the IA was found to be trackingthe tubing pressure. The well has been reclassified as Under Evaluation while diagnostics are conducted. An LDL will be run to determine a plan forward. A wellbore schematic is attached for reference. Thank you, << File: L-223.pdf >> Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator@BP.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector L-223 (PTD #2090990) for tracking purposes Date:Wednesday, October 6, 2021 1:22:11 PM Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, October 6, 2021 1:15 PM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: Injector L-223 (PTD #2090990) for tracking purposes Mr. Wallace, Injector L-223 (PTD #2090990) is due for an AOGCC witnessed MIT-IA. The surface kit needed repairs and the well has not been placed on injection to date. The well will go back to NOT OPERABLE status until injection is ready to commence and an AOGCC witnessed MIT-IA can be performed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: Alaska NS - PB - Field Well Integrity <PBFieldWellIntegrity@hilcorp.com> Sent: Thursday, May 27, 2021 6:21 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS - PB - EOC Specialists <EOCSpecialists@hilcorp.com>; Alaska NS - PB - Wells Optimization Engineers <WellsOE@hilcorp.com>; Alaska NS - PB W - GC2 - Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS - PB W - GC2 - Foreman <GC2Foreman@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad HUQ <AlaskaNS-PBW-GC2-WellpadHUQ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad LV <AlaskaNS-PBW-GC2-WellpadLV@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad MN <AlaskaNS-PBW-GC2-WellpadMN@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad RJ <AlaskaNS-PBW-GC2-WellpadRJ@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad S <AlaskaNS-PBW- GC2-WellpadS@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad W <AlaskaNS-PBW-GC2- WellpadW@hilcorp.com>; Alaska NS - PB W - GC2 - Wellpad Z <AlaskaNS-PBW-GC2- WellpadZ@hilcorp.com>; Alaska NS - PB W - GC3 - ProdContCentLeads <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages <David.Wages@hilcorp.com> Cc: Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; John Condio - (C) <John.Condio@hilcorp.com> Subject: OPERABLE: Injector L-223 (PTD #2090990) MIT-IA Passed All, Injector L-223 (PTD #2090990) passed MIT-IA on 05/25/21 and 05/26/21. Previous reports of failing MIT-IA from 2011 have been found to be inaccurate. The passing MIT-IA demonstrates two competentwell barriers. The well is now classified OPERABLE. An AOGCC MIT-IA will be conducted once the well is thermally stable. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 ___________________________________________ From: AK, D&C Well Integrity Coordinator Sent: Sunday, May 22, 2011 6:32 AM To: 'Maunder, Thomas E (DOA)' <tom.maunder@alaska.gov>; 'Regg, James B (DOA)' <jim.regg@alaska.gov>; ''Schwartz, Guy (DOA' <guy.schwartz@alaska.gov>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPSGC2 Field O&M TL <AKOPSGC2FieldOMTL@BP.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Prod Controllers <AKOPSProdControllers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; AK, D&C Wireline OperationsTeam Lead <AKDCWirelineOperationsTeamLead@BP.com>; AK, D&C Well Services Operations Team Lead <AKDCWellServicesOperationsTeamLead@BP.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com> Cc: Greaves, Damien C <greadc@bp.com>; Walker, Greg (D&C) <Greg.Walker2@bp.com>; Clingingsmith, Mike J (Swift) <Mike.Clingingsmith@BP.com> Subject: NOT OPERABLE: Injector L-223 (PTD #2090990) Well Secured with Load and Kill All, Injector L-223 (PTD # 2090990) has been secured with kill weight fluid and re-classified as Not Operable. An LDL will be run to determine a plan forward for repair. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator@BP.com _____________________________________________ Well Integrity Coordinator May 01, 2011 10:15 AM Thomas E (DOA)'; 'Regg, James B (DOA)'; ''Schwartz, Guy (DOA'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan ney; Greaves, Damien C DER EVALUATION: Injector L-223 (PTD #2090990) IA pressure tracking tubing pressure All, Injector L-223 (PTD #2090990) is a new well that has not yet been put on initial injection. Coil tubing was on the well 4/30/11 to set Water Flood Regulators and the IA was found to be trackingthe tubing pressure. The well has been reclassified as Under Evaluation while diagnostics are conducted. An LDL will be run to determine a plan forward. A wellbore schematic is attached for reference. Thank you, << File: L-223.pdf >> Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator@BP.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, 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 considers appropriate. 1 Guhl, Meredith D (CED) From:Wallace, Chris D (CED) Sent:Tuesday, October 19, 2021 9:00 AM To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector L-223 (PTD #2090990) for tracking purposes     From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>   Sent: Wednesday, October 6, 2021 1:15 PM  To: Wallace, Chris D (CED) <chris.wallace@alaska.gov>  Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity  <PBWellsIntegrity@hilcorp.com>  Subject: NOT OPERABLE: Injector L‐223 (PTD #2090990) for tracking purposes    Mr. Wallace,    Injector L‐223 (PTD #2090990) is due for an AOGCC witnessed MIT‐IA. The surface kit needed repairs and the well has  not been placed on injection to date. The well will go back to NOT OPERABLE status until injection is ready to commence  and an AOGCC witnessed MIT‐IA can be performed.    Please respond with any questions.    Andy Ogg  Hilcorp Alaska LLC  Field Well Integrity / Compliance  andrew.ogg@hilcorp.com  P: (907) 659‐5102  M: (307)399‐3816     From: Alaska NS ‐ PB ‐ Field Well Integrity <PBFieldWellIntegrity@hilcorp.com>   Sent: Thursday, May 27, 2021 6:21 AM  To: Abbie Barker <Abbie.Barker@hilcorp.com>; Alaska IMS User <akimsuser@hilcorp.com>; Alaska NS ‐ PB ‐ EOC  Specialists <EOCSpecialists@hilcorp.com>; Alaska NS ‐ PB ‐ Wells Optimization Engineers <WellsOE@hilcorp.com>;  Alaska NS ‐ PB W ‐ GC2 ‐ Field Lead Operator <GC2FieldLO@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Foreman  <GC2Foreman@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad HUQ <AlaskaNS‐PBW‐GC2‐WellpadHUQ@hilcorp.com>;  Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad LV <AlaskaNS‐PBW‐GC2‐WellpadLV@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad  MN <AlaskaNS‐PBW‐GC2‐WellpadMN@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad RJ <AlaskaNS‐PBW‐GC2‐ WellpadRJ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad S <AlaskaNS‐PBW‐GC2‐WellpadS@hilcorp.com>; Alaska NS ‐  PB W ‐ GC2 ‐ Wellpad W <AlaskaNS‐PBW‐GC2‐WellpadW@hilcorp.com>; Alaska NS ‐ PB W ‐ GC2 ‐ Wellpad Z <AlaskaNS‐ PBW‐GC2‐WellpadZ@hilcorp.com>; Alaska NS ‐ PB W ‐ GC3 ‐ ProdContCentLeads  <GC3ProdContCenterLeads@hilcorp.com>; Brian Glasheen <Brian.Glasheen@hilcorp.com>; Brodie Wages  <David.Wages@hilcorp.com>  Cc: Stan Golis <sgolis@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com>; Oliver Sternicki  <Oliver.Sternicki@hilcorp.com>; John Condio ‐ (C) <John.Condio@hilcorp.com>  Subject: OPERABLE: Injector L‐223 (PTD #2090990) MIT‐IA Passed    All, 2   Injector L‐223 (PTD #2090990) passed MIT‐IA on 05/25/21 and 05/26/21. Previous reports of failing MIT‐IA from 2011  have been found to be inaccurate. The passing MIT‐IA demonstrates two competentwell barriers. The well is now  classified OPERABLE. An AOGCC MIT‐IA will be conducted once the well is thermally stable.   Please call with any questions or concerns.    Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659‐5102 M: (907) 232‐1005 ___________________________________________  From: AK, D&C Well Integrity Coordinator   Sent: Sunday, May 22, 2011 6:32 AM  To: 'Maunder, Thomas E (DOA)' <tom.maunder@alaska.gov>; 'Regg, James B (DOA)' <jim.regg@alaska.gov>; ''Schwartz,  Guy (DOA' <guy.schwartz@alaska.gov>; AK, OPS GC2 OSM <AKOPSGC2OSM@bp.com>; AK, OPS GC2 Facility OTL  <AKOPSGC2FacilityOTL@bp.com>; AK, OPSGC2 Field O&M TL <AKOPSGC2FieldOMTL@BP.com>; AK, OPS GC2 Wellpad  Lead <AKOPSGC2WellpadLead@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; AK, OPS Prod Controllers  <AKOPSProdControllers@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; AK, D&C Wireline OperationsTeam Lead  <AKDCWirelineOperationsTeamLead@BP.com>; AK, D&C Well Services Operations Team Lead  <AKDCWellServicesOperationsTeamLead@BP.com>; AK, RES GPB West Wells Opt Engr  <AKRESGPBWestWellsOpt@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>  Cc: Greaves, Damien C <greadc@bp.com>; Walker, Greg (D&C) <Greg.Walker2@bp.com>; Clingingsmith, Mike J (Swift)  <Mike.Clingingsmith@BP.com>  Subject: NOT OPERABLE: Injector L‐223 (PTD #2090990) Well Secured with Load and Kill     All, Injector L-223 (PTD # 2090990) has been secured with kill weight fluid and re-classified as Not Operable. An LDL will be run to determine a plan forward for repair. 3 Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator@BP.com     _____________________________________________ AK, D&C Well Integrity Coordinator unday, May 01, 2011 10:15 AM under, Thomas E (DOA)'; 'Regg, James B (DOA)'; ''Schwartz, Guy (DOA'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan g, Whitney; Greaves, Damien C UNDER EVALUATION: Injector L-223 (PTD #2090990) IA pressure tracking tubing pressure All, Injector L-223 (PTD #2090990) is a new well that has not yet been put on initial injection. Coil tubing was on the well 4/30/11 to set Water Flood Regulators and the IA was found to be trackingthe tubing pressure. The well has been reclassified as Under Evaluation while diagnostics are conducted. An LDL will be run to determine a plan forward. A wellbore schematic is attached for reference. Thank you, 4   << File: L-223.pdf >> Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellIntegrityCoordinator@BP.com         The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.     MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, March 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-223 PRUDHOE BAY UN ORIN L-223 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/06/2023 L-223 50-029-23415-00-00 209-099-0 W SPT 4407 2090990 1500 1346 1351 1354 1352 700 796 776 770 INITAL P Brian Bixby 1/7/2023 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 UN ORIN L-223 Inspection Date: Tubing OA Packer Depth 1260 2019 1967 1957IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230108032411 BBL Pumped:1 BBL Returned:1 Monday, March 6, 2023 Page 1 of 1            2Q2011 Not Operable Injector Re. • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, July 04, 2011 4:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) 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; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 2Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 2Q2011.zip Tom, Jim, Phoebe and Guy, Attached is the 2Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and. Endicott injectors classified as Not Operable. 1 «Not Operable Injector Report 202011.zip» � � JUL 1 2 11 Notes on wells: Removed from Quarterly Injection Report: 13 -09 (PTD #1811580): RWO repaired TxIA comm. On 04/30/11 END 3- 43/P -36 (PTD #1931700): Surface casing leak repaired with Brink platelets on 05/17/11 LGI -08 (PTD #1860570): Not Operable Producer that had been mismarked in BP system as a not operable injector thereby being generated to report MPF -92 (PTD #1981930): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 MPF -95 (PTD #1981790): SI waiting for AOGCC MIT -IA that passed an AOGCC MIT -IA on 04/17/11 P2 -16 (PTD #1931230): RWO repaired PC leak and TxIA comm. On 04/15/11 U -10 (PTD #1851970): TxIA comm. That was repaired with a tubing patch on 06/05/2011. Moved to Monthly Injector report pending AOGCC witnessed test WGI -06 (PTD #1900300): RWO repaired TxIA comm. Well moved to Monthly Injector report pending AA cancellation Z -12 (PTD #1891020): TxIA communication repaired with cement packer on 05/24/11. Ad ta_Q,uaL'I,erly Injection Report: L -223 (PTD #2090990): MIT -1A failed on 05/01 . MPS -07 (PTD #2020720): - ailed on 04/09/11 MPS -13 (PTD #2021140): Passed MIT -IA on 04/11/11. LTSI that requires AOGCC MIT -IA when put on production. 1 1 V -227 (PTD #2091160): Exhibiting rapid IA repressurization. Classified as Not Operable on 06/20/11. 7/5/2011 Well L -223 Injection Plot TIO Plot Well: L -223 o Pressure vs. Rate O PTD: 2090990 0 0 rS co Tbg IA R - OA VI, o o ° __.__. -.. __— o n o - o m N N 0 O. 0 0 0 0 0 0 ) I r • Last 90 days • Last Month -- - o _ .__...._ - -_.__ _.. ....... o 0 0 0 1 1 1 2/19/11 5/12/11 8/2/11 Injection Rate, MCFPD • Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 07/01/11 0 693 07/01/11 600 340 0 06/30/11 0 576 06/30/11 600 340 0 06/29/11 0 584 06/29/11 600 340 0 06/28/11 0 729 06/28/11 750 340 0 06/27/11 0 825 06/27/11 750 340 0 06/26/11 0 719 06/26/11 750 340 0 06/25/11 0 628 06/25/11 750 340 0 06/24/11 0 605 06/24/11 750 340 0 06/23/11 0 662 06/23/11 750 340 0 06/22/11 0 687 06/22/11 750 340 0 06/21/11 0 642 06/21/11 750 340 0 06/20/11 0 765 06/20/11 750 340 0 06/19/11 0 820 06/19/11 950 340 0 06/18/11 0 816 06/18/11 950 340 0 06/17/11 0 1,059 06/17/11 950 340 0 06/16/11 0 1,087 06/16/11 1,250 340 0 06/15/11 0 792 06/15/11 680 340 0 06/14/11 0 626 06/14/11 680 340 0 06/13/11 0 570 06/13/11 600 340 0 06/12/11 0 551 06/12/11 560 340 0 06/11/11 0 538 06/11/11 550 320 0 06/10/11 0 540 06/10/11 550 320 0 06/09/11 0 529 06/09/11 550 320 0 06/08/11 0 545 06/08/11 -100 320 0 06/07/11 0 573 06/07/11 -100 320 0 06/06/11 0 579 06/06/11 -100 320 0 06/05/11 0 602 06/05/11 -100 320 0 06/04/11 0 561 06/04/11 -100 320 0 06/03/11 0 529 06/03/11 -100 320 0 06/02/11 0 520 06/02/11 -100 320 0 06/01/11 0 556 06/01/11 -100 320 0 NOT OPERABLE: Injector L -223 ,D #2090990) Well Secured with Loaded Kill Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator @bp.com] Sent: Sunday, May 22, 2011 6:32 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Greaves, Damien C; Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: NOT OPERABLE: Injector L -223 (PTD #2090990) Well Secured with Load and Kill All, Injector L -223 (PTD # 2090990) has been secured with kill weight fluid and re- classified as Not Operable. An LDL will be run to determine a plan forward for repair. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 50414itilitaj MAY 2; 3 2011 Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Sun.: May Ol, 2011 10:15 AM To: 'Maunder, Th. -.s E (DOA); 'Regg, James B (DOA); "Schwartz, Guy (DOA; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 We ... Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operation -am Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Greaves, Damien C Subject: UNDER EVALUATION: Injector L -223 (PTD 490990) IA pressure tracking tubing pressure All, Injector L -223 (PTD #2090990) is a new well that has not yet been p • n initial injection. Coil tubing was on the well 4/30/11 to set Water Flood Regulators and the IA was found to be tra • • the tubing pressure. The well has been reclassified as Under Evaluation while diagnostics are conducted. An LD ll be run to determine a plan forward. A wellbore schematic is attached for reference. Thank you, « File: L- 223.pdf » 5/23/2011 TREE 4- 1/16" C WELLHEAD = FMC C • SAFETY N WELL REQUIRES A SSSV WHEN ON MI * ** R @ 11022' IS "PULL TO RELEASE ACTUATOR = LEO -223 BUT CAN ALSO BE RELEASED BY PRESS. DO NOT KB. ELEV = 77.10' EXCEED 2000 PSI ON THE IA w /OUT PERFORMING TBG = 25.87' BF. ELEV 4 -1/2" X 3 -1/2" X0, 25 t J MOVEMENT CA LC'S & DISCUSSING w / APE * ** -1 I I I KOP = 500' ID = 2.992" Max Angle = 78° @ 9965' I 1006' H9-5/8" TAM PORT COLLAR I Datum MD = 11126' 'CONDUCTOR H 108' ' ' I 4518' H3-1/2" HES X NIP, ID = 2.813" I Datum TVD = 4400" SS I9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.84" H 6121' MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7594' CSG, 26 #, L -80 TC11 XO TO L -80 BTC 7" H 8 11065 4436 48 MMG -HW -H DMY RK 0 10/22/09 I I 1- -X 7 11133 4482 47 MMG -HW -G P -15 XJR RK 16 12/29/09 6 11329 4616 47 MMG -HW -F P -15 XJR RK 12 12/29/09 13-1/2" MARKERJOINTw/ RA TAG H 10979' I 1 5 11386 4655 47 MMG -HW -E DMY RK 0 10/22/09 I7" MARKER JOINT w! RA TAG H 11021' I---= 4 11434 4687 47 MMG -HW -D P -15 XJR RK 10 12/29/09 3 11500 4732 46 MMG -HW -C DMY RK 0 10/22/09 7" X 3 -1/2" HES DOUBLE FEED 11022' ■ 2 11547 4765 45 MMG -HW -B DMY RK 0 12/29/09 THRU PKR, ID = 2.965" 1 11674 4856 45 MMG -HW -A DMY RK 0 10/22/09 - No ' 11035' H3-1/2" NDPG SINGLE SENSOR, ID = 2.992" I Z 11225' H 7" X 3-1/2" HES SINGLE FFFf) THRU PKR, ID = 2.965" I Minimum ID = 2.75" @ 11727' 3-1/2" HES XN NIPPLE • I 11239' H3 -1/2" NDPG SINGLE GAUGE, ID= 2.992" I Mr I z ■■ 11352' H 7" X 3-1/2" HES SINGLE FEED THRU PKR, ID = 2.965" I . I 11360' 1-13-1/2" NDPG SINGLE GAUGE, ID = 2.992" I IIIP EP ' z EMI 11466' I -17" X 3 -1/2" HES SINGLE FEED THRU PKR, ID = 2.965" I PERFORATION SUMMARY • I 11480' 1-13-1/2" NDPG SINGLE GAUGE, ID = 2.992" I REF LOG: SLB USIT 10/21/09 IIIF ' ANGLE AT TOP PERF: 47 ° @ 11094' Note: Refer to Production DB for historical perf data p 11569' H7" X 3 -1 /2" HES SINGLE FEED THRU PKR, ID = 2.965" I Z SIZE SPF ZONE INTERVAL Opn /Sqz DATE ■ 4 -1/2" 5 Nb 11092 - 11120 0 10/19/09 • 1 11583' I -13 -1/2" NDPG SINGLE GAUGE, ID = 2.992" I 4 -1/2" 5 OA 11275 - 11328 0 10/19/09 4 -1/2" 5 Oba 11370 - 11418 0 10/19/09 4-1/2" 5 OBc 11516 - 11544 0 10/19/09 ' 11707' H3-1/2" HES X NIP, ID = 2.813" I 4 -1/2" 5 OBd 11588 - 11655 0 10/19/09 ' 1 11727' H3-1/2" HES XN NIP, ID = 2.75" I ------- 11727' H3 -1/2" HA CPA PLUG (10/27/09 1 I3 -1/2" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" I-1 11750' 1--/ \ -1 11750' I- 13 -1/2" WLEG, ID = 2.992" I PBTD 11811' • 17" CSG, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" I-1 11893' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 10/27/09 N7ES ORIGINAL COMPLETION 03/27/11 MBM/PJC TUBING CORRECTIONS WELL: L223 11/04/09 SV DRLG HO CORRECTIONS PERMIT No: 2090990 12/15/09 TW /PJC DRLG DRAFT CORRECTIONS API No: 50- 029 - 23415 -00 02/02/10 JAF /PJC WFR C/O (12/29/09) SEC 34, T12N, R11 E, 2554' FSL & 1521' FWL 02/15/11 MB /JMD ADDED SSSV SAFETY NOTE 02/27/11 MW /PJC SFTY NOTE (HES PKR'S) BP Exploration (Alaska) UNDER EVALUATION: Injector L -223 (PTD #2090990) IA pressure tracking tubing pr... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Sunday, May 01, 2011 10:15 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Greaves, Damien C Subject: UNDER EVALUATION: Injector L -223 (PTD #2090990) IA pressure tracking tubing pressure Attachments: L- 223.pdf All, Injector L -223 (PTD #2090990) is a new well that has not yet been put on initial injection. Coil tubing was on the well 4/30/11 to set Water Flood Regulators and the IA was found to be tracking the tubing pressure. The well has been reclassified as Under Evaluation while diagnostics are conducted. An LDL will be run to determine a plan forward. A wellbore schematic is attached for reference. Thank you, «L- 223.pdf» ) `I 5 , Th L \ Mehreen Vazir (Alternate: Gerald Murphy] Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 5/2/2011 DATA SUBMITTAL COMPLIANCE REPORT 2/9/2011 Permit to Drill 2090990 Well Name /No. PRUDHOE BAY UN ORIN L -223 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23415 -00 -00 MD 11927 TVD 5035 Completion Date 10/27/2009 Completion Status WAGIN Current Status WAGIN 7U IC Y j' REQUIRED INFORMATION \ Mud Log No Samples No Directional Survey Yes) t, - i DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, DIR, RES, NEU, AZI, DEN, PWD, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med /Frmt Number flame Scale Media No Start Stop CH Received Comments r '---- D C Lis 19083 Cement Evaluation 138 11720 Case 12/3/2009 LIS Veri, USIT, CCL C Lis 19087 e- induction /Resistivity 43 11926 Open 12/3/2009 LIS Veri, GR, ROP, FET, RPM, RAM, DRHO, NPHI, TRPM og Induction /Resistivity 25 Blu 47 11892 Open 12/3/2009 MD Vision Service og Induction /Resistivity 25 Blu 47 11892 Open 12/3/2009 TVD Vision Service 1 og Cement Evaluation 5 Col 200 11775 Case 12/3/2009 USIT w /inclinometer, GR, CCL, GPIT 21- Oct -2009 C Pds 19092" Cement Evaluation 200 11775 Case 12/3/2009 USIT w /inclinometer, GR, CCL, GPIT 21- Oct -2009 - a C Asc Directional Survey 0 11927 Open pt Directional Survey 0 11927 Open • Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments . 1 DATA SUBMITTAL COMPLIANCE REPORT 2/9/2011 Permit to Drill 2090990 Well Name /No. PRUDHOE BAY UN ORIN L -223 Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 23415 -00 -00 MD 11927 TVD 5035 Completion Date 10/27/2009 Completion Status WAGIN Current Status WAGIN UIC Y ADDITIONAL INFORMATION Well Cored? Y /� Daily History Received? N Chips Received? Y--/-N- - Formation Tops / N Analysis '" Received? Comments: Compliance Reviewed By: '' Date: l 7 1 4 • • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 March 31, 2010 C943—on RECEIVE Mr. Tom Maunder Alaska Oil and Gas Conservation Commission APR 0 7 2010 333 West 7 Avenue Co Anchorage, Alaska 99501 GasCrnt+s''"1°n Ancitonxte Subject: Corrosion Inhibitor Treatments of GPB L -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator 4 • • • J BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) L pad Date 3/31/2010 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ sealant Well Name PTD # API # Initial top of cement pumped cement date inhibitor date ft bbls ft na gal L -01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L -02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L -03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L -04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L -100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L -101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L -102 2020360 50029230710000 37' NA Need Top Job? NA L -103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L -104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L -105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L -106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L -107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L -108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L -109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L -110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L -111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L -112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L -114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L -115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L -116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L -117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L -118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L -119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L -120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L -121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L -122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L -123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L -124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L -200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L -201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L -202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L -204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L -205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L -210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L -211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L -212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L -213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L -214A 2060270 50029232580100 NA 0.25 NA 10.2 5/6/2009 L -215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L -216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L -217 2060750 50029233120000 plate blocking conductor NA NA L -218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L -219 2071480 50029233760000 surface NA NA L -220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L -221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L -222 2091190 50029234200000 NA 1.7 NA 13.6 12/6/2009 L -223 2090990 50029234150000 NA 0.7 NA 3.4 12/6/2009 L -250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L -50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L -51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 Ill STATE OF ALASKA 0 R ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ❑ Development ❑ Exploratory ❑ GINJ ❑ WINJ ® WAG ❑ WDSPL ❑ Other __No. of Completions One ® Service ❑ Stratigraphic 2. Operator Name: Date Com Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 10/27/2009 209 - 099 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 10/1/2009 50 - 029 - 23415 - - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 10/10/2009 PBU L -223 2554' FSL, 3758' FEL, SEC. 34, T12N, R11 E, UM 8. KB (ft above MSL): 77,1' 15. Field / Pool(s): Top of Productive Horizon: 34' FSL, 951' FWL, SEC. 23, T12N, R11 E, UM GL (ft above MSL): 48.3' Prudhoe Bay Field / Orion Total Depth: 9. Plug Back Depth (MD +TVD): Schrader Bluff 559' FSL, 1235' FWL, SEC. 23, T12N, R11 E, UM 11811' 4953' 4b. Locationl of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 583156 y - 5978275 Zone- ASP4 11927' 5035' ADL 028239 & 375134 TPI: x- 587760 y- 5986367 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 588038 y 5986895 Zone- ASP4 None 18. Directional Survey: IN Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1754' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill /Lateral Top Window MD/TVD: MWD, 1GR, DIR, RES, NEU, AZI DEN, PWD, USIT N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# A -53 Surface 108' Surface 108' 42" -260 sx Arctic Set 9 - 5/8" 40# L - 80 Surface 6121' Surface 2898' 12 -1/4" 832 sx Arcticset Lite. 412 sx Class 'G' 7" 26# L -80 Surface 11893' Surface 5011' 8 -3/4" 182 sx LiteCrete. 343 sx Class 'G' • 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) ` PR SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 3 -1 /2 ", 9.2 #, L -80 11750' 4407, 11225 i 4545' 4-1/2" Gun Diameter 11 352'/4631'.11466' /4709' MD TVD MD TVD 11569' / 4781' • 11094'- 11122' 4455'-4474' 110 ./4497', 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. • 11277' - 11330' 4580' - 4616' 1122 ' / 545' 11372' - 11420' 4645' - 4678' 1135 ' 31', rot DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 11518' - 11546' 4745' - 4765' 11 '/47 . < ' e< '1" ' S 11590' - 11657' 4796' - 4844' Freeze Protected w/ 119 Bbls Diesel down IA Y Zr a° Freeze Protected w/ 11.4 Bbls Diesel down Tubing 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet _ N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and_s.ummarize Iithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photograp f iQM8 fl& iry analytical results eertbC 250.071. None ��" NOV 2 4 2009 Alaska Oil & Gas Cons. Commission Form 10-407 Revised 07/2009 � ; � ' � / t I ON ERSE 7.2 •/� Pax - ! , . ; it Ori g inal O n l y r ' • ` b 1 �� /o ff la 29. GEOLOGIC MARKERS (List all formations and m rs encountered): 30. •ORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top 28.5' 28.5' If yes, list intervals and formations tested, briefly summarizing test Permafrost Base 2051' 1782' results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 6084' 2888' Ugnu MA 10643' 4167' None Ugnu MB1 10710' 4208' Ugnu MB2 10829' 4282' Ugnu MC 10931' 4348' Schrader Bluff NA 11054' 4428' Schrader Bluff NB 11095' 4456' Schrader Bluff NC 11136' 4484' Schrader Bluff NE 11154' 4496' Schrader Bluff NF 11225' 4545' Schrader Bluff OA 11276' 4579' Schrader Bluff OBa 11374' 4646' Schrader Bluff OBb 11447' 4696' Schrader Bluff OBc 11518' 4745' Schrader Bluff OBd 11590' 4796' Schrader Bluff OBe 11676' 4857' Schrader Bluff OBf 11732' 4897' Base Schrader Bluff OBf / Top Colville Mudstone 11792' 4940' Formation at Total Depth (Name): Colville Mudstone 11927' 5035' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and a Leak - Off Test Summary. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. /2 Signed: Sondra Stewman � Nt.XvL Title: Drilling Technologist Date: PBU L - 223 209 Prepared By Name/Number Sondra Stewman, 564 -4750 Well Number Permit No. / Approval No. Drilling Engineer: Ryan Ciolkosz, 564-5977 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only BP EXPLORATION Page 1 of 1 Leak -Off Test Summary Legal Name: L -223 Common Name: L -223 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 10/8/2009 LOT 6,121.0 (ft) 2,897.0 (ft) 8.80 (ppg) 614 (psi) 1,938 (psi) 12.88 (ppg) Printed: 11/12/2009 9:24:15 AM • BP EXPLORATION Page 1 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 9/25/2009 00:00 - 04:00 4.00 RIGD P PRE RIG DOWN FLOOR, BRIDLE UP AND PREP DERRICK TO LAY DOWN. BLOW DOWN STEAM AND WATER LINES IN PITS. DISCONNECT SERVICE LINES TO PIT MODULE. BUILD RAMP AND PREPARE TO INSTALL 3412 MOVING GENERATOR IN PIT MODULE. INSTALL GENERATOR IN PIT MODULE, POSITION GENERATOR AND BOLT DOWN, HOOK UP COOLING SYSTEM AND ELECTRICAL. 04:00 - 04:30 0.50 RIGD P PRE PJSM, LAY DOWN DERRICK 04:30 - 12:00 7.50 RIGD P PRE CONTINUE INSTALATION OF 3412 CATERPILLAR MOVING GENERATOR IN PIT MODULE, TEST RUN GENERATOR. 12:00 - 13:00 1.00 RIGD P PRE DISCONNECT ELECTRICAL LINES BETWEEN RIG AND PIT MODULE, SLIDE BACK INTERCONNECT. 13:00 - 15:00 2.00 RIGD P PRE LOAD CAMP AND SHOP AND PREP FOR MOVE. INSTALL MOVING JEEP ON PIT MODULE, PULL PITS AWAY FROM RIG. 15:00 - 00:00 9.00 RIGD P PRE BEGIN MOVING PIT MODULE CAMP AND SHOP FROM DS -04 TO L -PAD. (ROAD CONDITIONS SLICK) CAMP, SHOP AND PITS AT K -PAD ROAD INTERSECTION @ 19:00 HRS, SCARIFY AND SAND HILL GOING ONTO K -PAD ROAD. CONTINUE MOVING @ 20:00 HRS. PULL SUB OF WELL AND POSITION AT ENTRANCE TO PAD. REMOVE TREE FROM CELLAR PICKUP MATS AND CLEAN CELLAR AREA. LAY MATS ON ACCESS ROAD. CAMP MOVE AT INTERSECTION OF SPINE ROAD AND K -PAD ROAD @ 21:30 ALLOW SAND CREW TO SAND HILL AND SCARIFY ROAD AT TWIN TOWERS. CONTINUE MOVING AT 22:30 HRS. STOPPED AT J -PAD AT 23:30 HRS TO ALLOW TRAFFIC TO GO AROUND AND SAND APPROACH TO KAPARUK RIVER BRIDGES. 9/26/2009 00:00 - 01:30 1.50 MOB P PRE SAND APPROACHES TO KAPARUK RIVER BRIDGES. 01:30 - 05:00 3.50 MOB P PRE MOVE FROM J -PAD TO L -PAD CAMP SHOP AND PIT MODULE ON LOCATION @ 05:00 HRS 05:00 - 08:00 3.00 MOB P PRE PREPARE TO SPOT CAMP SHOP AND POSITION PIT MODULE NEAR L -223 08:00 - 00:00 16.00 MOB P PRE MOVE SUB FROM DS -04 TO L -PAD, RIG AT ENTRANCE TO E -PAD AND K -PAD ROAD AT 00:00 HRS. HAD TO MOVE THE CAMP AND SHOP ON L -PAD FROM THE NORTH WEST CORNER OF THE PAD TO THE SOUTHEAST CORNER DUE TO COMMUNICATION PROBLEMS. 9/27/2009 00:00 - 06:00 6.00 MOB P PRE RIG TURNED ONTO SPINE ROAD FROM K -PAD ROAD CO 0100 HRS, AND PAST FRONTIER CORNER CO 0230 HRS. STOPPED AT J -PAD TO ALLOW TRAFFIC TO GO AROUND @ 04:00 HRS, STOP AT KAPARUK EAST CHANNEL BRIDGE @ 05:00 HRS TO ALLOW TRAFFIC TO PASS AND CREW CHANGE. 06:00 - 12:00 6.00 MOB P PRE AFTER ROUTINE INSPECTION OF MOVING SYSTEM A PROBLEM WAS DISCOVERED WITH ONE OF THE MOVING SYSTEM HYDRAULIC DRIVE MOTORS ON THE DRILLER SIDE FRONT. THE SEAL ON THE MOTOR FAILED WHICHED CAUSED HYDRAULIC FLUID TO LEAK INTO THE BRAKING SYSTEM. A SMALL AMOUNT OF HYDRAULIC OIL (LESS THAN ONE QUART) WAS DISCOVERED IN THE Printed: 11/12/2009 9:24:21 AM • BP EXPLORATION Page 2 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 9/27/2009 06:00 - 12:00 6.00 MOB P PRE CONTAINMENT UNDER THE DRIVE AXLE. THE DRIVE MOTOR WAS CHANGED AND OIL WAS CLEANED FROM BRAKE SYSTEM AND AIR WAS BLED FROM SYSTEM. 12:00 - 17:00 5.00 MOB P PRE CONTINUE MOVING ACROSS KAPARUK RIVER BRIDGES TO Z -PAD ACCESS ROAD. 17:00 - 21:30 4.50 MOB P PRE WAIT AT Z -PAD ACCESS ROAD TO ALLOW TRAFFIC TO PASS AND FINISH LAYING MATS FROM SPINE ROAD TO V -PAD. 21:30 - 00:00 2.50 MOB P PRE MOVE FROM Z -PAD TURNED ONTO V -PAD ROAD @ 23:00 HRS. STOPPED ON V -PAD AT MIDNIGHT. 9/28/2009 00:00 - 12:00 12.00 MOB P PRE MOVE RIG FROM V -PAD TO L -PAD, LAY MATS ON ROAD FROM V -PAD TO -LPAD, MOVE RIG TO END OF MATS AND BEGIN MAT SHUFFLE. 12:00 - 00:00 12.00 MOB P PRE MOVE RIG FROM V -PAD TO L -PAD, LAY & SHUFFLE MATS. MOVE KUSKOKWIM CAMP FROM TARMAC PAD TO MOBIL PAD BEGIN MOVING @ 13:00 HRS. CAMP ON LOCATION @ 19:00 HRS. 9/29/2009 00:00 - 12:00 12.00 MOB P PRE MOVE SUB FROM V -PAD DOWN TO L -PAD, WELL L -2231. LAY AND SUFFLE RIG MATS. 12:00 - 00:00 12.00 MOB P PRE CONTINUE TO MOVE NABORS 7ES ALONG V -PAD AND L -PAD ACCESS ROAD. SHUFFLE AND LEAP -FROG RIG MATS TO AID IN RIG MOVE. 9/30/2009 00:00 - 05:00 5.00 RIGU P PRE PJSM. MOVE RIG ONTO L -PAD. RIG ON LOCATION @ 04:30HRS. CLEAR RIG MATS FROM ACCESS ROAD. 05:00 - 11:00 6.00 RIGU P PRE HANG 20' RISER IN CELLAR, SPOT SUB OVER L -2231. PULL BACK AND SECURE BOPS. RAISE DERRICK, PIN CATTLE CHUTE AND BRIDLE DOWN. 11:00 - 14:30 3.50 RIGU P PRE SPOT CUTTINGS BOX AND PITS; CONNECT PITS. RU RIG FLOOR. TAKE ON FRESH WATER CO 14:30HRS. 14:30 - 21:00 6.50 RIGU P PRE RU RISER AND DIVERTER, C/O AIR BOOTS. TAKE ON DRILLPLEX MUD @ 16:30HRS. START TO LOAD AND DRIFT 5" DP IN PIPE SHED. RIG ACCEPT @18:00HRS. 21:00 - 00:00 3.00 RIGU P PRE CONTINUE TO RU RIG FLOOR; RU CEMENT LINE, TONGS AND RACK SUBS. CONTINUE TO LOAD PIPE SHED W/ 5" DP AND DRIFT. 10/1/2009 00:00 - 02:30 2.50 RIGU P PRE PJSM. CONTINUE TO STRAP AND DRIFT 5" DP IN PIPE SHED. FINISH PREPPING RIG FLOOR. 02:30 - 03:00 0.50 RIGU P PRE FUNCTION TEST DIVERTER, TIME KNIFE VALVE. TEST WITNESSED BY WSLS BRIAN BUZBY AND AMANDA REBOL, AND NAD TP LENWARD TOUSSANT. AOGCC REP BOB NOBLE WAIVED WITNESS OF DIVERTER TEST. TEST ACCUMULATOR. 03:00 - 11:00 8.00 RIGU P PRE MU STANDS OF 5" DP IN MOUSEHOLE; PU AND STAND BACK 58 STANDS OF 5" DP AND 5 STANDS OF 5" HWDP. 11:00 - 11:30 0.50 RIGU P PRE PRE -SPUD MEETING. DIVERTING SHALLOW GAS DRILL. 11:30 - 13:30 2.00 RIGU P PRE RU WIRELINE FOR GYRO SINGLE -SHOT SURVEYS; RU TEST TOOL. 13:30 - 15:30 2.00 RIGU P PRE MU 12 -1/4" SPUD BHA. RIH AND TAG UP @ 45'. PRESSURE TEST SURFACE EQUIPMENT TO 3000PSI; GOOD. Printed: 11/12/2009 9:24:21 AM BP EXPLORATION Page 3 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/1/2009 15:30 - 16:00 0.50 RIGU P PRE DRILL CEMENT IN BOTTOM OF CONDUCTOR PIPE FROM 45' TO 98' MD. 30K UP, 30K DOWN, 30K ROTATING. 5K WOB, 220PSI @ 400GPM. 1K TORQUE. 16:00 - 20:00 4.00 RIGU P PRE POH FROM 98' AND LD BHA. PU DRILLING BHA: MXL -1K HUGHES BIT, 1.83DEG MOTOR, DRILL COLLARS, MWD TOOLS, DRILL COLLARS, FLOAT SUB, JARS AND HWDP. 20:00 - 23:30 3.50 DRILL P SURF DRILL AHEAD; DRILL CONDUCTOR FROM 98' TO 108', AND P DRILL PERMAFROST FROM 108' TO 263' MD. 40K UP, 40K DOWN, 40K ROTATING. 583PSI @ 552GPM; 1K TORQUE. 0.45HRS SLIDING TIME, 0.25HRS ROTATING TIME, 0.71 TOTAL DRILLING TIME. GYRO @ 113', 229' AND 263'. LOSSES EXPERIENCED STARTING CO 259' UNTIL TD SECTION; 120BBLS LOSSES TOTAL. WHILE DOING GYRO SURVEY, DISCOVERED FLUID IN NEIGHBORING WELL CELLARS. 23:30 - 00:00 0.50 DRILL N FLUD SURF POH TO ASSESS CELLAR FLUID SITUATION. 10/2/2009 00:00 - 02:30 2.50 DRILL N FLUD SURF PJSM. SUCK OUT NEIGHBORING WELLS AND MONITOR; CELLARS FILLING AGAIN WITH THAW WATER; SUCK BACK DOWN; NO ADDITIONAL FILLING. PU BHA AND RIH TO 263'. STAGE PUMPS UP; MONITOR NEARBY WELLS; NO FLUID RISING IN NEIGHBORING WELLBORES WHILE CIRCULATING @ 530GPM. TOTAL 7 BBLS RECOVERED FROM L -115 AND L -118 CELLARS. 02:30 - 12:00 9.50 DRILL P SURF DRILL AHEAD FROM 263' TO 1007' MD. 75K UP, 65K DOWN, 67K ROTATING. 915PSI ON, 815PSI OFF @ 550 GPM AND WOB = 25K. TORQUE: 4K ON, 2K OFF @ 40 RPM. 2.77HRS SLIDING, 1.48HRS ROTATING, 4.25HRS TOTAL DRILLING TIME. SLIGHT LOSSES WHILE DRILLING. GYRO SURVEY DOWN TO 727' MD. 12:00 - 00:00 12.00 DRILL P SURF CONTINUE TO DRILL 12 -1/4" SURFACE HOLE THROUGH PERMAFROST, FROM 1007' TO 1902' MD. 83K UP, 70K DOWN, 77K ROTATING. 1210PSI ON, 1140PSI OFF @ 600GPM AND WOB = 20 -25K. TORQUE: 6.5K ON, 3.5K OFF @ 4ORPM. 6.28HRS SLIDING, 3.30HRS ROTATING, 9.58HRS TOTAL DRILLING TIME. 156BBLS OF DRILPLEX LOST WHILE DRILLING TODAY. 10/3/2009 00:00 - 00:30 0.50 DRILL P SURF PJSM. DRILL AHEAD TO 1953' MD. 83K UP, 70K DOWN, 75K ROTATING. 1210PSI ON, 1140PSI OFF @ 600GPM AND WOB = 25K. TORQUE: 6.5K ON, 4K OFF @ 4ORPM. 0.55 HRS SLIDING, 0 HRS ROTATING, 0.55 HRS TOTAL DRILLING TIME. 00:30 - 02:00 1.50 DRILL P SURF CIRCULATE BU X3 TO CLEAN HOLE AND STABILIZE DRILPLEX PROPERTIES. CIRCULATE @ 600GPM, 1200PSI, ROTATE @ 4ORPM. 02:00 - 03:00 1.00 DRILL P SURF MONITOR WELL; STATIC. POH FROM 1953' TO SURFACE TO ADJUST MUD MOTOR BEND AND CHANGE TO NEW BIT. 03:00 - 05:30 2.50 DRILL P SURF CHANGE TO NEW 12 -1/4" BIT, AND ADJUST MOTOR BEND FROM 1.83 DEG TO 1.5 DEG. BIT GRADE: 1- 2- WT- A- E -1 -NO -BHA. 05:30 - 06:30 1.00 DRILL P SURF RIH FROM SURFACE TO BOTTOM @ 1953' MD; WASH PIPE DOWN; NO FILL ON BOTTOM. Printed: 11/12/2009 9:24:21 AM • BP EXPLORATION Page 4 of 18 operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/3/2009 06:30 - 12:00 5.50 DRILL P SURF DRILL AHEAD FROM 1953' TO 2545' MD. 87K UP, 63K DOWN, 75K ROTATING. 1350PSI ON, 1295PSI OFF @ 600 GPM AND WOB = 25K. TORQUE: 7K ON, 5K OFF 6ORPM. 2.65 HRS SLIDING, 0.92 HRS ROTATING, 3.56 HRS TOTAL DRILLING TIME. HYDRATES ENCOUNTERED 2385'; MONITOR MUD WEIGHT AND ADJUST MUD PROPERTIES AS NECESSARY. STILL EXPERIENCING SLIGHT LOSSES TO WELLBORE. 12:00 - 00:00 12.00 DRILL P SURF DRILL 12 -1/4" SURFACE HOLE AHEAD FROM 2545' TO 3745' MD. 90K UP, 55K DOW, 75K ROTATING. 1510PSI ON, 1380PSI OFF @ 600GPM AND WOB = 25 -30K. TORQUE: 9K ON, 6K OFF @ 6ORPM. 5.37 HRS SLIDING, 4.02 HRS ROTATING, 9.39 HRS TOTAL DRILLING TIME. LOSING SOME FLUID; 177BBL LOST TODAY. 10/4/2009 00:00 - 12:00 12.00 DRILL P SURF PJSM. DRILL AHEAD IN 12 -1/4" SURFACE HOLE FROM 3745' TO 5035' MD. 112K UP, 50 K DOWN, 78K ROTATING. 1630PS1 ON, 1525PSI OFF @ 600GPM AND WOB = 30K. TORQUE: 11.5K ON, 9K OFF a 6ORPM. 4.42 HRS SLIDING, 4.52 HRS ROTATING, 8.94 HRS TOTAL DRILLING TIME FOR TOUR. SLIGHT LOSSES TO FORMATION WHILE DRILLING AHEAD; HYDRATES BREAKING OUT AT SURFACE. 12:00 - 00:00 12.00 DRILL P SURF CONTINUE TO DRILL SURFACE HOLE FROM 5035' TO 6008' MD. 122K UP, 55K DOWN, 83K ROTATING. 1890PSI ON, 1680PSI OFF @ 600GPM AND WOB = 30K. TORQUE: 13.5K ON, 10K OFF @ 6ORPM. 3.72 HRS SLIDING, 5.1 HRS ROTATING, 8.82 HRS TOTAL DRILLING TIME FOR TOUR. HYDRATES STILL BREAKING OUT OF MUD SYSTEM; EXPERIENCING SLIGHT LOSSES; 123 BBLS LOST FOR THE DAY. 10/5/2009 00:00 - 01:30 1.50 DRILL P SURF PJSM. DRILL AHEAD TO SURFACE INTERVAL TD; GEOLOGIST CALLS TD CO 6134' MD, 2900' TVD. 120K UP, 501( DOWN, 83K ROTATING. 1754PSI ON, 1675PSI OFF 600GPM AND WOB = 30K. TORQUE: 12.5K ON, 11K OFF CO 60 RPM. 1.45 HRS ROTATING, 0 HRS SLIDING; 1.45 HRS TOTAL DRILLING TIME. HYDRATES BREAKING OUT AT SURFACE. 01:30 - 02:30 1.00 DRILL P SURF CIRCULATE AND CONDITION MUD BEFORE SHORT TRIP; CBU X2 AT 600 GP, 1630PSI. 02:30 - 09:30 7.00 DRILL P SURF MAKE SHORT TRIP TO 1952' MD. HOLE SWABBING ON FIRST 5 STANDS; MU TOP DRIVE AND PUMP OUT TO 5225' MD. ATTEMPT TO PU W/O PUMPS ON; OVERPULL. BACK REAM TO 5030' AT 80 RPM, TORQUE © 9 -12K. PUMP OUT TO 4225' MD; ADDITIONAL OVERPULL; BACKREAM REMAINDER OF THE WAY TO 1952' MD. 09:30 - 12:30 3.00 DRILL P SURF CIRCULATE TO CLEAN UP MUD BEFORE RUNNING BACK TO BOTTOM; CIRCULATE © 660GPM, ROTATE AT 8ORPM. MUD CLEANING UP SUBSTANTIALLY; 1430 PSI INITIAL, 1250 PSI FINAL; 9K INITIAL TORQUE, 4.5K FINAL TORQUE. EXTREME INCREASE IN CUTTINGS AT SURFACE AT BOTTOMS -UP. 12:30 - 16:00 3.50 DRILL P SURF RUN BACK TO TD © 6134' MD. BHA OCCASIONALLY TAKING -25K WEIGHT; WORK PIPE AND WIPE AREAS Printed: 11/12/2009 9:24:21 AM 410 BP EXPLORATION Page 5 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/5/2009 12:30 - 16:00 3.50 DRILL P SURF WHERE TAKING WEIGHT. WASH PIPE TO BOTTOM, -4 FT OF FILL ON BOTTOM. 16:00 - 18:30 2.50 DRILL P SURF CIRCULATE AND CONDITION MUD BEFORE FINAL POOH; CIRCULATE @ 650 GPM AND ROTATE @ 80 RPM TO CLEAN HOLE. 60% INCREAS IN CUTTINGS AT BOTTOMS UP. 18:30 - 23:30 5.00 DRILL P SURF MONITOR WELL; STATIC. POOH TO BHA; NO SWABBING OR OVERPULL FOR MOST OF TRIP. OVERPULL -30K 724' MD, TURN PUMPS ON CP 550GPM, 840 PSI AND PUMP THROUGH SECTION. NO FURTHER ISSUES WHILE POOH. 23:30 - 00:00 0.50 DRILL P SURF BREAK OUT AND LD BHA; RACK BACK DRILL COLLARS; PJSM W/ SLB DD AND MWD BEFORE LAYING DOWN TOOLS. 10/6/2009 00:00 - 00:30 0.50 DRILL P SURF PJSM, LAY DOWN BHA. 00:30 - 01:00 0.50 DRILL N RREP SURF REPAIR ELECTRICAL SWITCH ON IRON ROUGHNECK. 01:00 - 02:30 1.50 DRILL P SURF CONTINUE TO LD BHA; BREAKOUT MWD TOOLS, LD MUD MOTOR AND BREAK OUT BIT. BIT GRADE: 1- 1- WT- A- E- 1- NO -TD. 02:30 - 05:00 2.50 CASE P SURF PJSM TO RIG UP TO RUN 9 -5/8" SURFACE CASING. MAKE DUMMY RUN WITH CASING HANGER, RIG UP CASING HANDLING TOOLS, 350 TON ELEVATORS AND SPIDERS, STABBING BOARD, FRANKS FILL -UP TOOL. 05:00 - 09:30 4.50 CASE P SURF PJSM 9 -5/8 ", 40 #, BTC CASING BAKERLOCK SHOE TRACT, FILL CASING WITH FRANKS TOOL AND CHECK FLOATS. CENTRALIZERS ON FIRST 25 JOINTS PLACE ONE CENTRALIZER ON EITHER SIDE OF TAM PORT COLLAR (POSITIONED TO BE AT 1000' MD WHEN CASING IS LANDED). FILL EACH JOINT AND BREAK CIRCULATION EVERY 10 JOINTS. 09:30 - 12:30 3.00 CASE P SURF RUN CASING TO 2250'. CIRCULATE ONE BOTTOMS UP AT AT 290 PSI AND 5 BPM. WORK PIPE THROUGH TIGHT SPOTS AT 2530' MD AND 2573' MD. CIRCULATE AND WASH CASING TO 3503' AT 4.6 BPM. PUW =162K, SOW =37K 12:30 - 13:30 1.00 CASE P SURF CIRCULATE ONE BOTTOMS UP AT 3503' MD. 300 PSI AND 5 BPM 13:30 - 19:00 5.50 CASE P SURF CONTINUE TO RUN CASING TO 6103'. FILL EVERY JOINT AND BREAKING CIRCULATION EVERY 10 JOINTS AND WASH JOINT DOWN SLOWLY. PICK UP LANDING JOINT WITH FMC FLUTED MANDREL HANGER. WITH SHOE AT 6121' PUW =210K, SOW =75K 19:00 - 20:30 1.50 CASE P SURF CIRCULATE ONE BOTTOMS UP AT 5BPM 350 PSI. RECIPROCATE CASING 12' STROKES. PUW =210K SOW =75K. SHAKERS CLEANED UP ON BOTTOMS UP. 20:30 - 21:00 0.50 CASE P SURF RIG DOWN FRANKS FILL UP TOOL. RIG UP SCHLUMBERGER CEMENTING HEAD AND LINES. 21:00 - 22:00 1.00 CEMT P SURF CIRCULATE AND CONDITION MUD AT 5 BPM 350 PSI. WAIT ON TRUCK DRIVERS, LATE SHIFT CHANGE DUE TO RIG MOVE TO Z PAD. PJSM WITH SCHLUMBERGER AND RIG CREWS FOR CEMENT JOB. RECIPROCATE CASING Printed: 11/12/2009 9:24:21 AM BP EXPLORATION Page 6 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/6/2009 21:00 - 22:00 1.00 CEMT P SURF WHILE CIRCULATING PUW =170K SOW =75K 22:00 - 00:00 2.00 CEMT P SURF MIX AND PUMP 75 BBL MUD PUSH it 10.0 PPG AT 5 BPM. TEST LINES TO 3000 PSI. DROP BOTTOM PLUG. MIX AND PUMP 668 BBL 10.7 PPG ARCTIC SET LITE, 808 SX. 4.51 CUFT /SX LEAD CEMENT AT 5.5 BPM 412 PSI. FULL RETURNS STOP MOVING CASING AT 23:57 HRS. BECOMING STICKY AND HAVING DIFFICULTY GOING DOWN. SHOE AT 6121' TAM PORT COLLAR AT 1006' 10/7/2009 00:00 - 01:00 1.00 CEMT P SURF MIX AND PUMP 85 BBL 15.8 PPG CLASS 'G' 412 SX, 1.17 CUFT /SX TAIL CEMENT AT 5 BPM, 240 PSI. FULL RETURNS. DROP TOP PLUG 01:00 - 03:00 2.00 CEMT P SURF PUMP OUT PLUG WITH 10 BBL WATER WITH CEMENT UNIT. SWITCH TO RIG PUMPS. DISPLACE WITH 448 BBL 9.2 PPG DRILLING MUD AT 5 BPM. AFTER PUMPING 295 BBL MUD RETURNS VISCOSITY INCREASED TO VERY HIGH. SLOW DISPLACEMENT TO 3 BPM FOR LAST 150 BBL. GOOD CEMENT RETURNS, 45 BBL FULL RETURNS THROUGHOUT JOB. BUMP PLUG WITH 1500 PSI. CEMENT IN PLACE AT 02:40 HRS. FLOATS HELD. PRESSURE UP CASING TO 3000 PSI AND HELD FOR 5 MINUTES. 03 :00 - 05:00 2.00 CEMT P SURF RIG DOWN CEMENTING HEAD AND LINES. REMOVE LANDING JOINT AND LAY DOWN. FLUSH RISER, FLOW LINE AND 20" DIVERTER OF CEMENT. CLEAN AND CLEAR RIG FLOOR. 05:00 - 08:00 3.00 CEMT P SURF REMOVE FLOOR MATS AMD ROTARY TABLE COVER. RIG UP SUPER SUCKER TO CLEAN MUD AND CUTINGS FROM UNDER TABLE, FLOOR AND DRAWWORKS. 08:00 - 09:30 1.50 BOPSUF P SURF NIPPLE DOWN 20" DIVERTER AND 16" HYDRAULIC KNIFE VALVE. SET DIVERTER ON STAND AND SECURE IN CELLAR. 09:30 - 11:00 1.50 WHSUR P SURF INSTALL FMC 11" GEN 5 CASING HEAD AND 11" TUBING SPOOL THROUGH BORE SYSTEM. TEST SEALS TO 1000 PSI FOR 10 MINUTES. 11:00 - 15:00 4.00 BOPSUF P SURF NIPPLE UP 13 5/8" 5000K BOP. REMOVE FROM STUMP IN CELLAR AND INSTALL ON NEW FMC 11" TUBING SPOOL 15:00 - 20:30 5.50 BOPSUF P SURF TEST BOP. RIG UP TESTING EQUIPMENT. TEST BOP TO 250 PSI AND 4000 PSI WITH 5" AND 3 1/2" TEST JOINTS. ANNULAR TESTED TO 2500 PSI. TEST CHOKE MANIFOLD AND SURFACE EQUIPMENT. TEST ACCUMULATOR. TEST WITNESSED BY N.A.D. TOOLPUSHERS JOHN CASTLE AND LENWARD TOUSSANT. BP WSL MIKE DINGER AND DUNCAN FERGUSON. AOGCC INSPECTOR JONES WAIVED WITNESSING THE TEST. 20:30 - 21:30 1.00 BOPSUF P SURF RIG DOWN BOP TESTING LINES AND TOOLS. BLOW DOWN TOP DRIVE. INSTALL WEAR BUSHING AND Printed: 11/12/2009 9:24:21 AM • BP EXPLORATION Page 7 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/7/2009 20:30 - 21:30 1.00 BOPSUF P SURF SECURE WITH LOCK DOWN SCREWS. 21:30 - 00:00 2.50 DRILL P PROD1 LOAD PIPE SHED WITH 4" AND 5" DRILL PIPE AND STRAP ALL JOINTS. CHANGE VALVES AND SEATS AND LINERS ON BOTH MUD PUMPS FROM 5 1/2" TO 5 ". SERVICE TOP DRIVE. PREPARE TOOLS TO HANDLE BHA. CHANGE BALES ON TOP DRIVE. 10/8/2009 00:00 - 01:30 1.50 DRILL P PROD1 PICK UP 24 JOINTS 5" DRILL PIPE AND RIH. POH DRILL PIPE AND STAND BACK 01:30 - 04:30 3.00 DRILL P PROD1 PICK UP 8 3/4" DRILLING BHA. HELD PJSM WITH CREW ON HANDLING NUCLEAR SOURCE. MAKE UP NEW 8 3/4" PDC HYCALOG BIT, DTX619M -D2, XP MOTOR WITH 1.5 DEG BEND, MWD, LOAD NECLEAR SOURCE INTO ADN, NON MAG DRILL COLLARS, FLOAT SUB, PUMP OUT CIRC SUB, JARS AND 5" HWDP. CROSS OVER TO 4" DRILL PIPE. SHALLOW TEST MWD. ATTEMPT TO CIRCULATE TO TEST MWD. MUD COMMING OUT OF THE WELL VERY THICK AND GELATINOUS. NOT FLOWING DOWN THE FLOW LINE FREELY. JET THE FLOW LINE AND WATER BACK MUD TO LOWER VISCOSITY. PERFORM A SUCCESSFUL SHALLOW TEST 04:30 - 06:00 1.50 DRILL P PROD1 RIH WITH DRILLING BHA. PICK UP 4" DRILL PIPE IN SINGLES TO 2160'. 06:00 - 07:00 1.00 DRILL P PROD1 CIRCULATE AND FILL PIPE. MUD RETURNS VERY THICK. CIRCULATE AND CUT MUD WITH WATER TO LOWER VISCOSITY. 07:00 - 08:00 1.00 DRILL P PROD1 RIH WITH DRILLING BHA. PICK UP 4" DRILL PIPE IN SINGLES TO 3595'. 08:00 - 09:00 1.00 DRILL P PROD1 CIRCULATE AND FILL PIPE. MUD RETURNS VERY THICK. CIRCULATE AND CUT MUD WITH WATER TO LOWER VISCOSITY 09:00 - 10:30 1.50 DRILL P PROD1 RIH WITH DRILLING BHA. PICK UP 4" DRILL PIPE IN SINGLES TO 5015'. PIPE FLOATING WHILE RIH. PUW =130K 10:30 - 11:30 1.00 DRILL P PROD1 CIRCULATE AND FILL PIPE. MUD RETURNS VERY THICK. CIRCULATE AND CUT MUD WITH WATER TO LOWER VISCOSITY 11:30 - 13:00 1.50 DRILL P PROD1 RIH WITH DRILLING BHA. PICK UP 4" DRILL PIPE IN SINGLES TO 5967'. PUW =140K SOW =25K 13:00 - 14:00 1.00 DRILL P PROD1 SLIP AND CUT DRILLING LINE 118'. SERVICE TOP DRIVE AND INSPECT DRAWWORKS. 14:00 - 15:00 1.00 CASE P PROD1 TEST CASING. RIG UP EQUIPMENT AND LINES. .PRESSURE TEST 9 5/8" CASING TO 3500 PSI FOR 30 MINUTES. LOST 30 PSI IN FIRST 15 MINUTES. LOST 10 PSI IN SECOND 15 MINUTES. RIG DOWN TEST EQUIPMENT AND BLOW DOWN LINES. 15:00 - 16:00 1.00 DRILL P PROD1 DRILL CEMENT. WASH DOWN AND TAG FLOAT COLLAR AT 6034'. DRILL FLOAT COLLAR, CEMENT AND SHOE TRACT TO 6116'. PUW =140K SOW =25K ROT =72K. 450 GPM, 2170 PSI, 45 RPM, 11K TO 16:00 - 18:00 2.00 DRILL P PROD1 CIRCULATE AND DISPLACE SPUD MUD. PUMP 75 Printed: 11/12/2009 9:24:21 AM • BP EXPLORATION Page 8 of 18 Operat Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/8/2009 16:00 - 18:00 2.00 DRILL P PROD1 BBLWATER, 50 BBL HIGH VIS FLOWZAN SPACER FOLLOWED WITH 870 BBL 8.8 PPG LSND MUD. 18:00 - 18:30 0.50 DRILL P PROD1 DRILL9 5/8" CASING SHOE AND NEW HOLE TO 6157' PUW =100K SOW =55K ROT =173K 450 GPM 1260 PSI 50 RPM 6K TQ PULL BHA INTO 9 5/8" CASING SHOE 18:30 - 19:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP AND CONDITION MUD. 450 GPM 1353 PSI ROTATE PIPE AT 50 RPM OBTAIN SLOW PUMP RATES 19:30 - 20:30 1.00 DRILL P PROD1 PERFORM LOT AT 9 5/8" CASING SHOE AT 6121' MD 2897' TVD. 614 PSI EMW 12.9 PPG 20:30 - 00:00 3.50 DRILL P PROD1 DRILL AHEAD 8 3/4" PRODUCTION HOLE FROM 6157' TO 6655' WOB =15K PUW =113K SOW =50K ROT =75K RPM =120 SPM =238 GPM =580 PSI ON =2072 PSI OFF =2000 TQ ON =10K TQ OFF =8K CAL ECD =9.69 PPG ACT ECD =10.2 PPG MUD WT =8.8 PPG ROTATE =1.43 SLIDE =.65 ACC DRILL 2.08 10/9/2009 00:00 - 12:00 12.00 DRILL P PROD1 DRILL AHEAD 8 3/4" PRODUCTION HOLE FROM 6655' TO 8893' BACK REAM EACH STAND BERORE ALL CONNECTIONS TO CONTROL ECD WOB =12K PUW =160K SOW =60K ROT =90K RPM =120 SPM =234 GPM =580 PSI ON =2685 PSI OFF =2570 TQ ON =13.5K TQ OFF =12.5K CAL ECD =9.78 PPG ACT ECD =10.79 PPG MUD WT =8.9 PPG ROTATE =4.99 SLIDE =1.77 ACC DRILL 6.76 SLOW PUMP RATES OBTAINED AT 7190' 12:00 - 13:00 1.00 DRILL P PROD1 DRILL AHEAD 8 3/4" PRODUCTION HOLE FROM 8893' TO 8987' BACK REAM EACH STAND BERORE ALL CONNECTIONS TO CONTROL ECD WOB =12K TO 15K PUW =175K SOW =55K ROT =90K RPM =120 SPM =234 GPM =580 PSI ON =2750 PSI OFF =2590 TQ ON =14K TQ OFF =12K CAL ECD =9.78 PPG ACT ECD =10.79 PPG MUD WT =8.9 PPG ROTATE =4.99 SLIDE =1.77 ACC DRILL 6.76 13:00 - 13:30 0.50 DRILL P PROD1 CIRCULATE AROUND A 50 BBL 11 PPG HIGH VIS SWEEP TO REDUCE ECD THAT HAD INCREASED TO 11 PPG AND LOWER TORQUE. INCREASE OF 25% IN CUTTINGS ON BOTTOMS UP 13:30 - 00:00 10.50 DRILL P PROD1 DRILL AHEAD 8 3/4" PRODUCTION HOLE FROM 8987' TO 10214' BACK REAM EACH STAND BERORE ALL CONNECTIONS Printed: 11/12/2009 9:24:21 AM • • BP EXPLORATION Page 9 of 18 Operat Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/9/2009 13:30 - 00:00 10.50 DRILL P PROD1 TO CONTROL ECD WOB =10 - 15K PUW =160K SOW =60K ROT =90K RPM =120 SPM =234 GPM =580 PSI ON =2685 PSI OFF =2570 TQ ON =13.5K TQ OFF =12.5K CAL ECD =9.78 PPG ACT ECD =10.79 PPG MUD WT =8.9 PPG ROTATE =4.99 SLIDE =1.77 ACC DRILL 6.76 OBTAIN SLOW PUMP RATES AT 9269' 10/10/2009 00:00 - 12:00 12.00 DRILL P PROD1 DRILL AHEAD 8 3/4" PRODUCTION HOLE FROM 10214' TO 11438' BACK REAM EACH STAND BERORE ALL CONNECTIONS TO CONTROL ECD ADD DRILZONE AND LOTORQ TO 1 1/2 % TO REDUCE TORQUE WHILE DRILLING AND DRAG WHILE SLIDING. INCREASE MUD WEIGHT TO 9.4 PPG WOB =10 - 15K PUW =220K SOW =75K ROT =105K RPM =120 SPM =234 GPM =570 PSI ON =3219 PSI OFF =3105 TQ ON =20K TQ OFF =20K CAL ECD =10.44 PPG ACT ECD =10.91 PPG MUD WT =9.4 PPG SLIDE =3.62 ROTATE =3.18 ACC DRILL 7.8 12:00 - 16:00 4.00 DRILL P PROD1 DRILL AHEAD 8 3/4" PRODUCTION HOLE FROM 11438' TO 11927 TD. BACK REAM EACH STAND BERORE ALL CONNECTIONS TO CONTROL ECD WOB =10 - 15K PUW =260K SOW =80K ROT =120K RPM =120 SPM =234 GPM =580 PSI ON =3500 PSI OFF =3345 TQ ON =20.5K TQ OFF =20.8K CAL ECD =10.44 PPG ACT ECD =10.91 PPG MUD WT =9.4 PPG SLIDE =.28 ROTATE =2.32 ACC DRILL =2.6 CAL ECD =10.4 PPG ACT ECD =11.16 PPG 16:00 - 19:00 3.00 DRILL P PROD1 CIRCULATE AND CONDITION MUD. CLEANING HOLE TO ECD OF 10.48 PPG. MONITOR WELL, STATIC 19:00 - 20:30 1.50 DRILL P PROD1 POH FOR WIPER TRIP TO THE 9 5/8" CASING SHOE. OVER PULL OF 25K AT 11703'. WORK PIPE THROUGH TIGHT SPOT. POH TO 11655' MAD PASS FROM 11655' TO 11500'. 225'/HR 120 RPM 20:30 - 23:30 3.00 DRILL P PROD1 POH. OVER PULL OF 25K AT 11452' BACK REAM TO 10336' 23:30 - 00:00 0.50 PROD1 TRIP OUT OF HOLE TO 9584' WIPING TIGHT SPOTS AT 10117', 9875', AND 9824'. 10/11/2009 00:00 - 01:30 1.50 DRILL P PROD1 POH TO 8850'. PULLING TIGHT, 35K OVERPULL. WORK Printed: 11/12/2009 9:24:21 AM BP EXPLORATION Page 10 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/11/2009 00:00 - 01:30 1.50 DRILL P PROD1 PIPE SEVERAL TIMES. MUD WEIGHT 9.4 PPG 01:30 - 07:30 6.00 DRILL P PROD1 BACK REAM FROM 8850' TO 9 5/8" CASING SHOE AT 6121' ADJUSTING RPM AND PUMP RATE TO AVOID PACKING OFF AND ECD SPIKES GPM =550 PSI =2990 07:30 - 08:30 1.00 DRILL P PROD1 CIRCULATE AND CONDITION MUD. GPM =575 PSI =2825 RPM 120 08:30 - 09:00 0.50 DRILL P PROD1 SERVICE TOP DRIVE 09:00 - 12:00 3.00 DRILL P PROD1 RIH TO TD AT 11927'. NO PROBLEMS OR OBSTRUCTIONS. MUD WEIGHT 9.4 PPG 12:00 - 14:30 2.50 DRILL P PROD1 CIRCULATE AND CONDITION MUD. PUMP AROUND 50 BBL 11.4 PPG HIGH VIS SWEEP. CLAY AND COAL ON BOTTOMS UP. GPM =580 PSI =3450 RPM =120 14:30 - 21:30 7.00 DRILL P PROD1 POH. LAY DOWN 198 JOINTS OF 5" DRILL PIPE. PULL INTO 9 5/8" CASING SHOE. MUD WEIGHT 9.4 PPG 21:30 - 23:00 1.50 DRILL P PROD1 CIRCULATE AT 9 5/8" CASING SHOE. PUMP AROUND 40 BBL SWEEP WITH 6% STEEL LUBE EP. MONITOR WELL. PUMP DRY JOB. BLOW DOWN LINES 23:00 - 00:00 1.00 DRILL P PROD1 POH. STAND BACK 4" DRILL PIPE. MUD WEIGHT 9.4 PPG 10/12/2009 00:00 - 02:00 2.00 DRILL P PROD1 POH. STAND BACK 4" DRILL PIPE 02:00 - 03:30 1.50 DRILL P PROD1 LAY DOWN 8 3/4" DRILLING BHA. DISCOVERED A 2" LONG VERTICAL CRACK IN THE BOX OF THE JARS. NO WASH OUT. BIT GRADE 1- 1- CT- A- X- I -NO -TD 03:30 - 07:00 3.50 BOPSUF P PROD1 CLEAN AND CLEAR RIG FLOOR. PULL WEAR BUSHING. INSTALL TEST PLUG. CHANGE TOP RAMS TO 7" AND TEST WITH 7" TEST JOINT TO 250 LOW AND 3500 PSI HIGH. 07:00 - 09:30 2.50 CASE P RUNPRD RIG UP TO RUN 7" CASING. MAKE DUMMY RUN WITH CASING HANGER. RIG UP HYDRAULIC CASING TONGS WITH COMPENSATOR AND TORQUE TURN COMPUTER. 09:30 - 19:30 10.00 CASE P RUNPRD MAKE UP 7" SHOE TRACT AND CHECK FLOATS. THREAD LOCK FIRST THREE JOINTS. RUN 104 JOINTS 7" 26# L -80 BTC -M CASING WITH RADIOACTIVE (RA) TAG ON PUP JOINT ON TOP OF JOINT 21. PICK UP BTC -M TO TC -II CROSS OVER JOINT. RUN 7" 26# L -80 TC -II CASING TO 9 5/8" CASING SHOE AT 6121'. MAKE UP TORQUE ON TC -II 10,100 FT /LBS. FILL PIPE EVERY JOINT, TOPPING OFF EVERY 10 JOINTS. INSTALL CENTRALIZERS PER PROGRAM. 19:30 - 20:30 1.00 CASE P RUNPRD CIRCULATE 1 1/2" CASING VOLUMES AT 9 5/8" CASING SHOE. 20:30 - 00:00 3.50 CASE P RUNPRD RUN 7" 26# L -80 TC -II CASING TO 8099'. MAKE UP TORQUE 10,100 FT /LBS. FILL PIPE EVERY JOINT. CIRCULATE DOWN EVERY 10 JOINTS TO BREAK CIRCULATION. CHECK UP AND DOWN WEIGHTS TO CONFIRM FRICTION Printed: 11/12/2009 9:24:21 AM • BP EXPLORATION, Page 11 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/12/2009 20:30 - 00:00 3.50 CASE P RUNPRD FACTOR OF 0.25 ON DRAG PLOT. 10/13/2009 00:00 - 05:30 5.50 CASE P RUNPRD RUN 7" 26# L -80 TC -II CASING TO 11922'. TORQUE TURN CONNECTIONS 10,100 FT /LBS. FILL PIPE EVERY JOINT. CIRCULATE DOWN EVERY 10 JOINTS TO BREAK CIRCULATION. CHECK UP AND DOWN WEIGHTS TO CONFIRM RICTION FACTOR ON DRAG PLOT. CIRCULATE LAST JOINT DOWN. PICK UP LANDING JOINT AND CASING HANGER RUN DOWN TO LANDING RING AND LAND CASING. 05:30 - 06:30 1.00 CASE P RUNPRD RIG DOWN FRANKS FILL UP TOOL. INSTALL CEMENTING HEAD AND LINES. 06:30 - 09:30 3.00 CASE P RUNPRD CIRCULATE AND CONDITION MUD PRIOR TO CEMENT JOB. STAGE PUMPS UP TO BPM =5 GPM =210 PSI =650. RECIPROCATE CASING CONTINOUSLY 20' STROKES. 09:30 - 11:00 1.50 CEMT P RUNPRD MIX AND PUMP 30 BBL MUD PUSH II 10.0 PPG AT 5 BPM. TEST LINES TO 4000 PSI. DROP BOTTOM PLUG. MIX AND PUMP 106 BBL 11 PPG LITE CRETE, 182 SX, 1.83 CUFT /SX LEAD CEMENT AT 5 BPM 670 PSI. MIX AND PUMP 71 BBL 15.8 PPG GAS BLOC "G" TAIL 308 SX, 1.16 CUFT /SX AT 5 BPM. PUMP OUT LINES FROM CEMENTING UNIT TO RIG FLOOR WITH 10 BBL WATER, DUMP CEMENT DOWN FLOW LINE NOT DOWN THE 7" CASING. SWITCH TO RIG PUMPS. DROP TOP PLUG. FULL RETURNS. 11:00 - 13:00 2.00 CEMT P RUNPRD DISPLACE CEMENT WITH 451 BBL 9.8 PPG BRINE AT 5 BPM. SLOW DISPLACEMENT TO 3 BPM FOR LAST 60 BBL. FULL RETURNS THROUGHOUT JOB. BUMP PLUG WITH 2448 PSI. CEMENT IN PLACE AT 12:41 HRS. FLOATS HELD. RECIPROCATE CASING 20' STROKES. BECOMING STICKY AND HAVING DIFFICULTY GOING DOWN. PIPE FREE TO COME UP. CONTINUE WORKING PIPE TO BUMP PLUG. CASING HANGER NOT SEATED ON LANDING RING 28.62' ABOVE. SHOE AT 11893' FLOAT COLLAR AT 11811' "RA" TAG AT 11020' 6X) TOP JOINT OF BTC -M AT 7675' 13:00 - 14:30 1.50 CASE P RUNPRD PRESSURE TEST CASING TO 4000 P I F• R • u ► S. FIRST TEST PRESSURE DROPPED 150 PSI IN FIRST 15 MINUTES AND 70 PSI IN SECOND 15 MINUTES. REPEAT TEST. LOST 50 PSI IN THE FIRST 15 MINUTES AND 50 PSI IN THE SECOND 15 MINUTES OF TEST. Printed: 11/12/2009 9:24:21 AM • • BP EXPLORATION Page 12 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 l Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/13/2009 14:30 - 15:00 0.50 CASE P RUNPRD PJSM WITH CREW TO SET EMERGENCY SLIP ON 7" CASING AND REMOVE CEMENTING HEAD AND LANDING JOINT HIGH IN THE DERRICK. 15:00 - 15:30 0.50 CASE P RUNPRD RIG DOWN 7" CEMENTING HEAD. JOB STOPPED DUE TO DROPPED OBJECT. 15:30 - 18:30 3.00 CASE N HMAN RUNPRD SAFETY STAND DOWN TO INVESTIGATE A DROPPED HAMMER WHILE REMOVING THE HOSE FROM THE CEMENTING HEAD. THE INCIDENT WAS DECLARED A "DROPPED OBJECT" AS THE FLOOR WAS CLEAR OF WORKERS WHILE OVERHEAD WORK WAS IN PROGRESS. A TETHERED HAMMER WAS ACCIDENTALLY DROPPED WHEN THE CARABINER ON THE TETHER STRAP WAS INADVERTENTLY RELEASED. NO INJURY TO PERSONNEL, IMPACT TO THE ENVIRONMENT OR EQIPMENT DAMAGE. 18:30 - 19:00 0.50 CASE P RUNPRD REMOVE CEMENTING HEAD FROM LANDING JOINT AND LOWER TO THE RIG FLOOR. BACK OUT LANDING JOINT FROM RUNNING TOOL AND DRAIN BRINE. SUCK BRINE FROM 7" CASING JOINT DOWN TO CUT POINT IN THE CELLAR. 19:00 - 19:30 0.50 CEMT P RUNPRD PUMP 10 BBL 9.5 PPG DRILLING MUD DOWN THE 9 5/8" X 7" ANNULUS PRIOR TO FREEZE PROTECTING. BREAK DOWN AT 330 PSI. 19:30 - 22:00 2.50 WHSUR P RUNPRD MONITOR 9 5/8" X 7" ANNULUS FOR RETURN PRIOR TO PICKING UP THE BOP TO INSTALL EMERGRNCY SLIPS. PJSM WITH RIG CREW AND FMC ON PICKING UP BOP, INSTALLING EMERGENCY SLIPS, CUTTING 7" CASING AND INSTALING PACK OFF. 22:00 - 00:00 2.00 WHSUR P RUNPRD NIPPLE DOWN BOP WITH BREAK BETWEEN TUBING SPOOL AND CASING HEAD. INSTALL FMC GEN 5 WELLHEAD SYSTEM EMERGENCY SLIPS WITH 85K WEIGHT ON SLIPS. 10/14/2009 00:00 - 01:30 1.50 WHSUR P RUNPRD RIG UP FMC PNEUMATIC CASING CUTTING TOOL. CUT 7" CASING. PULL AND LAY DOWN CUT JOINT. RIG DOWN CASING CUTTER. 01:30 - 02:00 0.50 WHSUR P RUNPRD INSTALL FMC 7" GEN 5 PACK -OFF IN CASING HEAD. RUN IN LOCK DOWN SCREWS. 02:00 - 03:30 1.50 WHSUR P RUNPRD NIPPLE UP BOP. TEST CASING SPOOL TO TUBING SPOOL FLANGE TO 5000 PSI AND FMC PACK -OFF TO 4200 PSI WITH HAND TEST PUMP 03:30 - 06:30 3.00 BOPSUF P RUNPRD CHANGE TOP RAMS FROM 7" TO 3 1/2" X 6" VARIABLE. CHANGE TOP DRIVE QUILL FROM 4 1/2" IF TO 4" HT40. TEST TOP RAMS WITH 4" TEST JOINT. TEST LOWER I- BOP AND QUILL ON TOP DRIVE. 06:30 - 09:00 2.50 WHSUR P RUNPRD PUMP 173 BBL 11.7 PPG DRILLING MUD DOWN 9 5/8" X 7" ANNULUS. BREAK DOWN AT 1250 PSI. INJECT AT FINAL PRESSURE OF 775 PSI. FREEZE PROTECT OA WITH 58 BBL DIESEL AT 60 DEG F to 1800' TVD. FINAL PRESSURE 1350 PSI. 09:00 - 00:00 15.00 CASE N WAIT RUNPRD SLOPE WIDE SAFETY STAND DOWN. Printed: 11/12/2009 9:24:21 AM • BP EXPLORATION Page 13 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date. From - To Hours Task Code NPT Phase Description of Operations 10/14/2009 09:00 - 00:00 15.00 CASE N WAIT RUNPRD A RECENT INCREASE IN INCIDENTS AND ACCIDENTS PROMPTED UPPER MANAGEMENT TO CALL A STOP TO ALL ADW ACTIVITIES. THE RIG CREWS GATHERED TO DISCUSS WAYS AND COME UP WITH PLANS TO STOP ACCIDENTS WHERE PEOPLE GET HURT. GET A BETTER CONTROL OF WORK PLAN AND SIMOPS. MAKE BETTER RISK ASSESSMENTS. CHANGE THE CULTURE. GAIN ACCEPTANCE THAT ALL WORKERS ARE AT RISK OF INJURY. SHARE INFORMATION AND IDEAS WITH OTHER RIGS AND CREWS. 10/15/2009 00:00 - 00:00 24.00 CASE N WAIT RUNPRD SLOPE WIDE SAFETY STAND DOWN. A RECENT INCREASE IN INCIDENTS AND ACCIDENTS PROMPTED UPPER MANAGEMENT TO CALL A STOP TO ALL ADW ACTIVITIES. THE RIG CREWS GATHERED TO DISCUSS WAYS AND COME UP WITH PLANS TO STOP ACCIDENTS WHERE PEOPLE GET HURT. GET A BETTER CONTROL OF WORK PLAN AND SIMOPS. MAKE BETTER RISK ASSESSMENTS. CHANGE THE CULTURE. GAIN ACCEPTANCE THAT ALL WORKERS ARE AT RISK OF INJURY. SHARE INFORMATION AND IDEAS WITH OTHER RIGS AND CREWS. 10/16/2009 00:00 - 00:00 24.00 CASE N WAIT RUNPRD SLOPE WIDE SAFETY STAND DOWN. A RECENT INCREASE IN INCIDENTS AND ACCIDENTS PROMPTED UPPER MANAGEMENT TO CALL A STOP TO ALL ADW ACTIVITIES. THE RIG CREWS GATHERED TO DISCUSS WAYS AND COME UP WITH PLANS TO STOP ACCIDENTS WHERE PEOPLE GET HURT. GET A BETTER CONTROL OF WORK PLAN AND SIMOPS. MAKE BETTER RISK ASSESSMENTS. CHANGE THE CULTURE. GAIN ACCEPTANCE THAT ALL WORKERS ARE AT RISK OF INJURY. SHARE INFORMATION AND IDEAS WITH OTHER RIGS AND CREWS. 10/17/2009 00:00 - 00:00 24.00 CASE N WAIT RUNPRD SLOPE WIDE SAFETY STAND DOWN. A RECENT INCREASE IN INCIDENTS AND ACCIDENTS PROMPTED UPPER MANAGEMENT TO CALL A STOP TO ALL ADW ACTIVITIES. THE RIG CREWS GATHERED TO DISCUSS WAYS AND COME UP WITH PLANS TO STOP ACCIDENTS WHERE PEOPLE GET HURT. GET A BETTER CONTROL OF WORK PLAN AND SIMOPS. MAKE BETTER RISK ASSESSMENTS. CHANGE THE CULTURE. GAIN ACCEPTANCE THAT ALL WORKERS ARE AT RISK OF INJURY. SHARE INFORMATION AND IDEAS WITH OTHER RIGS AND CREWS. 10/18/2009 00:00 - 13:00 13.00 CASE N WAIT RUNPRD SLOPE WIDE SAFETY STAND DOWN. A RECENT INCREASE IN INCIDENTS AND ACCIDENTS Printed: 11/12/2009 9:24:21 AM • BP EXPLORATION Page 14 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From To Hours Task Code NPT Phase Description of Operations 10/18/2009 00:00 - 13:00 13.00 CASE N WAIT RUNPRD PROMPTED UPPER MANAGEMENT TO CALL A STOP TO ALL ADW ACTIVITIES. THE RIG CREWS GATHERED TO DISCUSS WAYS AND COME UP WITH PLANS TO STOP ACCIDENTS WHERE PEOP GET HURT. GET A BE CONTROL OF WORK PLAN AND SIMOPS. MAKE BETTER RISK ASSESSMENTS. CHANGE THE CULTURE. GAIN ACCEPTANCE THAT ALL WORKERS ARE AT RISK OF INJURY. SHARE INFORMATION AND IDEAS WITH OTHER RIGS AND CREWS. 13:00 - 15:00 2.00 EVAL P OTHCMP CREWS RETURN TO WORK. INSPECT DERRICK AND CLEAR OF ICE ACCUMULATED DURING THAW AND FREEZE AND SNOW FALL OVER THE PAST SEVERAL DAYS. INSPECT TOP DRIVE AND DRAWWORKS. PREPARE FLOOR TO START WORK. 15:00 - 18:00 3.00 BOPSUF P OTHCMP RIG UP TO TEST BOP. PULL WEAR BUSHING. INSTALL TEST PLUG. FILL STACK AND LINES WITH WATER. 18:00 - 23:30 5.50 BOPSUF P OTHCMP TEST BOP TO 250 PSI AND 4000 PSI WITH 4" AND 3 1/2" TEST JOINTS. TEST ANNULAR TO 2500 PSI. TEST CHOKE MANIFOLD AND AUXILIARY EQUIPMENT TO 250 PSI AND 4000 PSI. TEST ACCUMULATOR. AOGCC REP LOU GRIMALDI WAIVED WITNESSING THE TEST TEST WITNESSED BY DRILLER DAVE GUESS, TOOLPUSHER BIFF PERRY AND WSL DUNCAN FERGUSON. 23:30 - 00:00 0.50 BOPSUF P OTHCMP RIG DOWN BOP TESTING EQUIPMENT AND LINES. INSTALL WEAR BUSHING. BLOW DOWN LINES. 10/19/2009 00:00 - 01:30 1.50 PERFOB P OTHCMP RIG UP TO RUN TCP GUNS. PJSM WITH RIG CREW AND SLB TCP GUN TECH. 01:30 - 03:30 2.00 PERFOB P OTHCMP PICK UP SCHLUMBERGER 4 1/2" HSD POWER JET 4505, 5SPF TCP GUNS WITH eFIRE HEAD. PICK UP LWD IMPULSE TOOL ON TOP OF GUNS. 03:30 - 09:00 5.50 PERFOB P OTHCMP RIH 4 1/2" TCP GUNS. PICK UP 219 JOINTS 4" DRILL PIPE. SHALLOW TEST LWD IMPULSE TOOL AT 1603' CONTINUE RIH WITH GUNS PICKING TO 7601' UP 4" DRILL PIPE FROM PIPE SHED 09:00 - 14:00 5.00 PERFOB P OTHCMP RIH WITH 4 1/2" TCP GUNS ON 4" DRILL PIPE FROM THE DERRICK. TAG UP ON 7" FLOAT COLLAR AT 11,810' PUW =180K SOW =55K 14:00 - 18:00 4.00 PERFOB P OTHCMP ACTIVATE IMPULSE LWD LOGGING TOOL. PUMP AT 2 TO 3 BPM AT 350 TO 380 PSI. MAKE TWO PASSES. CORRELATION AND CONFIRMATION PASS TO TIE -IN FORMATION WITH DRILLING LOGS. PLACE GUNS ON DEPTH. 18:00 - 19:00 1.00 PERFOB P OTHCMP PERFORATE WELL WITH SCHLUMBERGER 4 1/2" HSD POWER JET 4505 5SPF TCP GUNS USING eFIRE -TCP Printed: 11/12/2009 9:24:21 AM • BP EXPLORATION Page 15 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/19/2009 18:00 - 19:00 1.00 PERFOB P OTHCMP FIRING SYSTEM. PULSE SEQUENCE: 500 PSI FOR 1 MINUTE, 700 PSI FOR 1 MINUTE, BLEED TO 0 PSI FOR 2 MINUTES, 1200 FOR 2 MINUTES, BLEED TO ZERO FOR 5 MINUTES. PERFORATE INTERVALS: OBd 11590' TO 11657' 67' OBc 11518' TO 11546 28' OBa 11372' TO 11420' 48' OA 11277' TO 11330' 53' Nb 11094' TO 111.22' 28' ALL DEPTHS REFERENCED TO MWD DRILLING LOGS. GUNS FIRED AT 18:14 HRS. INITIAL LOSS TO WELL OF 8 BBL 9.8 PPG BRINE. LOSSES SLOWED TO 3 BPH 19:00 - 19:30 0.50 PERFOB P OTHCMP POH TO 11025' TO POSITION GUNS ABOVE TOP PERF 19:30 - 20:30 1.00 PERFOB P OTHCMP CIRCULATE ONE BOTTOMS UP. NO GAS OR OIL. 228 GPM 1091 PSI 20:30 - 21:00 0.50 PERFOB P OTHCMP SLIP AND CUT DRILLING LINE 148' 21:00 - 00:00 3.00 PERFOB P OTHCMP POH WITH 4 1/2" TCP GUNS TO 5760' LOSING BRINE TO THE WELL AT 3 BPH. 10/20/2009 00:00 - 02:30 2.50 PERFOB P OTHCMP POH WITH 4 1/2" TCP GUNS TO 649' LOSING BRINE TO THE WELL AT 3 BPH. 02:30 - 04:30 2.00 PERFOB P OTHCMP POH. LAY DOWN IMPULSE LWD TOOL AND BUMPER SUB. PJSM WITH CREW AND SCHLUMBERGER TCP GUN TECHS ON LAYING DOWN GUNS. LAY DOWN 4 1/2" TCP GUNS. ALL GUNS FIRED. LOSING BRINE AT 3 BPH 04:30 - 05:30 1.00 PERFOB P OTHCMP RIG DOWN TCP GUN RUNNING TOOLS AND HYDRAULIC POWER TONGS. CLEAN AND CLEAR FLOOR 05:30 - 07:00 1.50 CLEAN P CLEAN LOAD SHED W/ CLEANOUT TOOLS; STRAP AND TALLY. CLEAN AND CLEAR RIG FLOOR TO PICKUP BHA. 07:00 - 09:30 2.50 CLEAN P CLEAN PICK UP BAKER VACS CLEAN OUT TOOL AND BHA. 09:30 - 14:00 4.50 CLEAN P CLEAN RIH W/ CLEANOUT ASSY ON 4" DP FROM SURFACE (BHA LENGTH -882' LONG) TO 8781'. 14:00 - 15:00 1.00 CLEAN P CLEAN SAFETY MOMENT: INVESTIGATE AND REPAIR STAINLESS SHRINK TUBE CLAMP; CLAMP FELL FROM SERVICE LOOP TO RIG FLOOR. 15:00 - 16:30 1.50 CLEAN P CLEAN CONTINUE TO RIH FROM 8781' TO 10872' MD. 16:30 - 21:00 4.50 CLEAN P CLEAN WASH CLEANOUT ASSEMBLY TO BOTTOM FROM 10,872' TO 11,785'. CIRCULATE THROUGH VACS CLEANOUT TOOL @ 247GPM, 1691 PSI. ROTATE @ 4ORPM, TORQUE = 10K. 195K UP, 50K DOWN AND 92K ROTATING. 21:00 - 00:00 3.00 CLEAN P CLEAN MONITOR WELL; STATIC; 9.8PPG IN AND OUT. POOH W/ 4" DP AND CLEANOUT ASSY FROM 11,785' TO 8306' MD. LD AND RACK BACK DP; MANAGE PIPE TO LEAVE 50 STANDS IN THE DERRICK AND LD PIPE FOR INSPECTION. 10/21/2009 00:00 - 02:00 2.00 CLEAN P CLEAN PJSM. CONTINUE TO POOH FROM 8306' MD TO CLEANOUT BHA. 02:00 - 02:30 0.50 CLEAN P CLEAN HOLDING PIN IN ELEVATORS SLIPPING OUT; C/0 ELEVATORS. 02:30 - 06:30 4.00 CLEAN P CLEAN CONTINUE POOH TO VACS CLEANOUT ASSY AND JUNK BASKET AT 882' MD. Printed: 11/12/2009 9:24:21 AM BP EXPLORATION Page 16 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date. From - To Hours Task Code NPT Phase Description of Operations 10/21/2009 06:30 - 09:00 2.50 CLEAN P CLEAN LD VACS TOOL AND CLEANOUT BHA; APPROX 0.5 CUPS OF DEBRIS IN COLLECTION BASKET. CLEAN AND CLEAR RIG FLOOR. 09:00 - 12:00 3.00 EVAL P OTHCMP PJSM W/ SLB E -LINE CREW. RU TO RUN USIT LOG. SPOT LOGGING TRUCK AND LOAD USIT AND WELLTEC TRACTOR IN PIPE SHED. MU TOOLS IN THE SHED TO MINIMIZE PICKS TO RIG FLOOR. 12:00 - 14:00 2.00 EVAL N WAIT OTHCMP WAIT ON WEATHER; PENDING PHASE 3 CONDITIONS. 14:00 - 16:30 2.50 EVAL P OTHCMP FINISH RU TO RIH W/ USIT AND TRACTOR. 16:30 - 20:00 3.50 EVAL P OTHCMP RIH W/ USIT AND TRACTOR. TAG UP @ 11,774' MD. 20:00 - 00:00 4.00 EVAL P OTHCMP LOG UP FROM 11,774' MD W/ USIT AND TRACTOR -5600 FT /HR. 10/22/2009 00:00 - 02:30 2.50 EVAL P OTHCMP PJSM. CONTINUE TO LOG TO TOP OF CEMENT; FINISH POOH TO SURFACE. 02:30 - 03:00 0.50 EVAL P OTHCMP LD WELLTEC TRACTOR, LD USIT LOGGING TOOL. 03:00 - 04:00 1.00 EVAL P OTHCMP MU TRACTOR ON E -LINE; MU GAUGE RING AND JUNK BASKET. 04:00 - 06:30 2.50 EVAL N WAIT OTHCMP WAIT ON CORRECT SIZE GAUGE RING TO BE DELIVERED FROM DEADHORSE. 06:30 - 09:30 3.00 EVAL P OTHCMP RIH W/ GR/JB ON E -LINE; TRACTOR GR/JB TO BOTTOM. GR SIZE = 6.125" 09:30 - 13:30 4.00 EVAL P OTHCMP TAG UP © 11,780' MD AND POOH W/ GR/JB AND TRACTOR. APPROX ONE QUART OF DEBRIS RECOVERED IN JUNK BASKET. 13:30 - 15:30 2.00 EVAL P OTHCMP CONSULT WITH TOWN TO DETERMINE IF SECOND GR/JB RUN IS NECESSARY; DETERMINE TO NOT COMPLETE SECOND RUN. 15:30 - 17:00 1.50 EVAL P OTHCMP RD E -LINE UNIT. 17:00 - 23:00 6.00 RUNCOMP RUNCMP RU TO RUN 3 -1/2" COMPLETION. PULL WEAR BUSHING, PERFORM DUMMY RUN W/ TBG' HANGER. BRING DOUBLE STACK AND TORQUE -TURN EQUIPMENT TO FLOOR, C/O ELEVATORS AND BALES. SET UP I -WIRE SPOOLS AND CLAMPS. 23:00 - 00:00 1.00 RUNCOIVP RUNCMP PJSM W/ SLB, HES AND NABORS CASING; RUN 3 -1/2" COMPLETION FROM SURFACE TO PLANNED WLEG DEPTH © 11,747' MD. 10/23/2009 00:00 - 12:00 12.00 RUNCOMP RUNCMP PJSM. RUN 3 -1/2 ", 9.2# L -80, TCII COMPLETION JEWELRY FROM SURFACE TO 771' MD; BAKER -LOCK ALL CONNECTIONS BELOW DEEPEST PACKER, AND UTILIZE TORQUE -TURN EQUIPMENT TO TORQUE ALL CONNECTIONS TO AN OPTIMUM 2350 FT -LBS. 12:00 - 21:00 9.00 RUNCOMP RUNCMP CONTINUE TO RIH FROM 771' TO 3563' MD W/ 3 -1/2 ", 9.2# L -80 TCII TUBING; ALL JEWELRY IN THE HOLE. RUNNING TWO ENCAPSULATED I- WIRES; SECURE CLAMPS OVER EVERY COLLAR AND TEST I -WIRE PERIODICALLY. 21:00 - 00:00 3.00 RUNCOMN WAIT RUNCMP SAFETY STAND -DOWN WITH INCOMING RIG CREW; REVIEW MATERIAL FROM PREVIOUS SHUTDOWN AND OPEN DISCUSSION FOR CREW FEEDBACK AND CONCLUSIONS. 10/24/2009 00:00 - 12:00 12.00 RUNCOMN WAIT RUNCMP CONTINUE SAFETY STAND -DOWN; REVIEW PREVIOUS STAND -DOWN MATERIAL AND OPEN RIG CREW DISCUSSION. 12:00 - 13:00 1.00 RUNCOMP RUNCMP CLEAN ICE AND FROST FROM DRILLING LINE TO Printed: 11/12/2009 9:24:21 AM • • BP EXPLORATION Page 17 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase ` Description of Operations 10/24/2009 12:00 - 13:00 1.00 RUNCOMP RUNCMP PREVENT FROM FALLING ONTO THE RIG FLOOR. 13:00 - 00:00 11.00 RUNCOMP RUNCMP CONTINUE TO RUN 3.5 ", 9.2 #, L -80, TCII COMPLETION FROM 3563' TO 6977 MD; TORQUE TURN ALL CONNECTIONS TO 2300FT -LBS; PERIODICALLY TEST I -WIRE. 65K UP, 40K DOWN. 10/25/2009 00:00 - 08:30 8.50 RUNCOMN WAIT RUNCMP SAFETY STAND -DOWN WITH RIG CREW TO DISCUSS SAFETY PLAN- FORWARD. COMPILE CONCLUSIONS AND CREW PLAN- FORWARD. DISCUSS W/ NAD TOOLPUSHERS AND BP WSLS BEFORE SENDING INPUT TO TOWN. 08:30 - 09:00 0.50 RUNCOMP RUNCMP CLEAR ICE AND SNOW FROM DERRICK AND LINES; INSPECT DERRICK. 09:00 - 12:00 3.00 RUNCOMP RUNCMP PJSM W/ NABORS CASING HAND AND SLB I -WIRE TECHNICIANS. CONTINUE TO RUN 3.5 ", 9.2 #, L -80 TCII COMPLETION FROM 6977' TO 8030' MD. 73K UP, 40K DOWN. TORQUE -TURN ALL CONNECTIONS AND MANAGE I -WIRE WHILE RIH. 12:00 - 22:30 10.50 RUNCOMP RUNCMP FINISH RIH W/ 3.5" COMPLETION, FROM 8030' TO 11,748' MD. 102K UP, 42K DOWN. ALL CONNECTIONS TORQUED TO 2300 FT -LBS. TEST I -WIRE PERIODICALLY, CLAMP WIRES OVER COLLARS. TOTAL OF 327 FULL CLAMPS, 24 HALF CLAMPS RUN. COUNT EXTRA COMPLETION JOINTS AND REMOVE FROM PIPE SHED. 22:30 - 00:00 1.50 RUNCOMP RUNCMP PU 2' PUP JOINT AND EXTRA JOINT TO SPACE OUT COMPLETION FOR GR/CCL CORRELATION. RIH 30' TO POSITION COMPLETION; SET IN SLIPS. REMOVE REMAINING I -WIRE FROM SPOOLS AND SECURE AT RIG FLOOR (I -WIRE NOT TERMINATED). PARTIALLY RD DOUBLE -STACK TO MAKE ADDITIONAL ROOM FOR E -LINE SHEAVES. 10/26/2009 00:00 - 02:00 2.00 RUNCOMP RUNCMP PJSM WITH SLB E -LINE CREW. RU WIRELINE UNIT; BRING WELLTEC TRACTOR AND GR/CCL TOOL INTO PIPE SHED. MU TOOLS IN PIPE SHED AND BRING TO RIG FLOOR USING WIRELINE HEAD. RU PACK -OFF FOR PRESSURE CONTROL; HANG SHEAVES. 02:00 - 07:30 5.50 RUNCOMP RUNCMP RIH W/ GR/CCL WIRELINE TOOL; TRACTOR TOOL TO 11,660' MD AT -3600 FT /HR. LOG UP TO DETERMINE ACTUAL COMPLETION DEPTH; GOOD TIE -IN WITH RA TAGS AND FORMATION TOPS. DETERMINE THAT COMPLETION NEEDS TO BE SHIFTED SLIGHTLY. FINISH POOH W/ WIRELINE. 07:30 - 08:00 0.50 RUNCOMP RUNCMP LD WELLTEC TRACTOR AND GR/CCL TOOL. RD SLB WIRELINE. 08:00 - 11:00 3.00 RUNCOMP RUNCMP PU DOUBLE - STACK, PREP TOOLS TO LAND COMPLETION. LD TOP TWO JOINTS, PLACE PUP JOINT IN COMPLETION AND MU FINAL JOINT. MU TUBING HANGER AND LANDING JOINT; TERMINATE I -WIRES AT HANGER AS PER SLB TECHNICIAN. LAND TUBING HANGER AND RILDS AS PER FMC HAND. 11:00 - 12:00 1.00 RUNCOMP RUNCMP RU TO CIRCULATE; CIRCULATE DOWN TUBING TO MAKE SURE COMPLETION IS CLEAR FOR HACPA. CIRCULATE 5BBLS TOTAL @ 1 BPM AND 950PSI. 12:00 - 13:00 1.00 RUNCOMP RUNCMP RU TO PUMP FREEZE PROTECT AND CORROSION Printed: 11/12/2009 9:24:21 AM • • BP EXPLORATION Page 18 of 18 Operations Summary Report Legal Well Name: L -223 Common Well Name: L -223 Spud Date: 9/27/2009 Event Name: DRILL +COMPLETE Start: 9/26/2009 End: 10/27/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/27/2009 Rig Name: NABORS 7ES Rig Number: 7ES Date From - To Hours Task Code NPT Phase Description of Operations 10/26/2009 12:00 - 13:00 1.00 RUNCO P RUNCMP INHIBITED BRINE DOWN 3.5" X 7" ANNULUS. 13:00 - 19:30 6.50 RUNCOMP RUNCMP BULLHEAD 9.8PPG CORROSION INHIBITED BRINE DOWN IA; TOTAL OF 172BBLS PUMPED CO 1BPM. WHILE PUMPING, ANNULUS PRESSURE = 800PSI, TUBING PRESSURE = 800PSI. PUMP FREEZE PROTECT VIA LRHOS; PUMP 119BBLS TOTAL © 1 BPM. WHILE PUMPING, ANNULUS PRESSURE = 1150PSI, TUBING PRESSURE = 780PSI. 19:30 - 22:00 2.50 RUNCOMP RUNCMP RU LRHOS TO FILTER POD; CONNECT LINES TO PUMP FREEZE PROTECT AND CORROSION IHIIBITED BRINE DOWN 3.5" TUBING. SIMOPS; MU HACPA ON RIG FLOOR AND INSERT INTO LANDING JOINT. 22:00 - 00:00 2.00 RUNCOMP RUNCMP FLUSH LINES TO ENSURE CLEAN FLUID IS PUMPED DOWN TUBING; PT LINES. START PUMPING HACPA; KICK PLUG OUT OF LANDING JOINT WITH 2BBLS FILTERED BRINE FROM LRHOS. LD LANDING JOINT AND CLOSE BLIND RAMS BEFORE CONTINUING PUMPING. PUMP HACPA DOWN WITH 11.4 BBLS FILTERED DIESEL (TREATED WITH LUBE 776) FOLLOWED BY 84.3 BBLS OF FILTERED 9.8PPG BRINE AT 3BPM. HACPA SEATED AT 97.7BBLS PUMPED; CONTINUE TO PRESSURE UP TO 4500PSI AS PER HES TECHNICIANS TO SET PACKERS. 10/27/2009 00:00 - 02:00 2.00 RUNCOMP RUNCMP PJSM. HAVE LITTLE RED BLEED OFF TUBING PRESSURE TO 4000PSI; HOLD PRESSURE FOR 30 MINUTES TO TEST TUBING, AND CHART TEST. BLEED TUBING TO 1500PSI, AND PRESSURE UP ON IA TO 4000PSI TO TEST PACKERS. CHART TEST; BOTH TESTS GOOD. TUBING O MIN 4100 PSI � 15 MIN 3970 PSI 30 MIN 3920 PSI ANNULUS 0 MIN 4300 PSI 15 MIN 4100 PSI 30 MIN 4060 PSI BLEED OFF ALL PRESSURE ON TBG AND IA. 02:00 - 02:30 0.50 RUNCOMP RUNCMP INSTALL TWC AS PER FMC HAND; TEST FROM ABOVE TO 1000PSI; GOOD. 02:30 - 07:30 5.00 BOPSUF P RUNCMP NIPPLE DOWN BOPS. 07:30 - 11:00 3.50 WHSUR P RUNCMP NIPPLE UP ADAPTOR AND DOUBLE MASTER; TEST TO 5000PSI FOR 30MIN WITH DIESEL; GOOD. TEST AND TERMINATE I -WIRE. 11:00 - 12:00 1.00 WHSUR P RUNCMP DSM INSTALL VR PLUGS IN ANNULAR VALVES. 12:00 - 20:00 8.00 WHSUR P RUNCMP LD REMAINING 48 STANDS OF DP FROM DERRICK BEFORE MOVING RIG. RIG RELEASE © 20:00 HRS FROM L -2231 TO L -2221. Printed: 11/12/2009 9:24:21 AM bp . 0 L -223 Survey Report $cblumberger Report Date: 11- Oct -09 Survey 1 DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 30.040° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: L -PAD / L -223 TVD Reference Datum: Rotary Table Well: L -223 drilling TVD Reference Elevation: 77.10 ft relative to MSL Borehole: L -223 Sea Bed/Ground Level Elevation: 48.30 ft relative to MSL UWIIAPI #: 500292341500 Magnetic Declination: 22.203° Survey Name 1 Date: L-223 1 October 11, 2009 Total Field Strength: 57655.848 nT Tort 1 AHD 1 DDI 1 ERD ratio: 223.727° /9969.90 ft / 6.723/1.980 Magnetic Dip: 80.896 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 01, 2009 Location Lat!Long: N 70.35061811, W 149.32485263 Magnetic Declination Model: BGGM 2009 Location Grid N1E YIX: N 5978275.380 ftUS, E 583156.190 ftUS North Reference: True North • Grid Convergence Angle: +0.63583551 Total Corr Mag North -> True North: +22.203 Grid Scale Factor: 0.99990786 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea TVD ND Closure DLS Northing Basting Latitude Longitude Depth True Section Departure True North True North (ft) (deg) I (deg) I (ft) l (ft) (ft) (ft) (ft ) (ft ) (ft ) (deg1100ft ) I (ftUS) I (ftUS) RTE 0.00 0.00 0.00 -77.10 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5978275.38 583156.19 N 70.35061811 W 149.32485263 GYD GC SS 84.00 0.55 230.36 6.90 84.00 -0.38 0.40 0.40 -0.26 -0.31 0.65 5978275.12 583155.88 N 70.35061740 W 149.32485515 141.00 0.57 296.49 63.90 141.00 -0.65 0.90 0.83 -0.31 -0.77 1.07 5978275.07 583155.42 N 70.35061727 W 149.32485892 171.00 0.86 317.70 93.89 170.99 -0.59 1.27 1.06 -0.07 -1.06 1.29 5978275.30 583155.13 N 70.35061791 W 149.32486124 215.00 1.19 338.11 137.89 214.99 -0.21 2.05 1.57 0.60 -1.45 1.11 5978275.96 583154.73 N 70.35061973 W 149.32486442 242.00 1.98 351.35 164.88 241.98 0.33 2.79 2.09 1.32 -1.63 3.21 5978276.68 583154.55 N 70.35062170 W 149.32486584 273.00 3.04 0.91 195.85 272.95 1.46 4.15 3.16 2.67 -1.69 3.66 5978278.03 583154.47 N 70.35062540 W 149.32486639 303.00 4.28 4.24 225.79 302.89 3.16 6.06 4.85 4.58 -1.60 4.19 5978279.94 583154.54 N 70.35063062 W 149.32486562 333.00 4.79 0.84 255.69 332.79 5.27 8.43 7.11 6.95 -1.50 1.92 5978282.31 583154.61 N 70.35063709 W 149.32486479 363.00 4.61 359.40 285.59 362.69 7.40 10.89 9.53 9.41 -1.49 0.72 5978284.77 583154.59 N 70.35064381 W 149.32486475 1.4 393.00 4.88 2.24 315.49 392.59 9.56 13.37 11.98 11.89 -1.46 1.19 5978287.25 583154.60 N 70.35065058 W 149.32486445 424.00 5.26 2.68 346.37 423.47 11.99 16.11 14.69 14.62 -1.34 1.23 5978289.99 583154.69 N 70.35065806 W 149.32486349 454.00 6.04 5.31 376.22 453.32 14.65 19.07 17.61 17.57 -1.13 2.74 5978292.93 583154.87 N 70.35066611 W 149.3248 178 486.00 6.13 5.99 408.04 485.14 17.74 22.46 20.96 20.95 -0.79 0.36 5978296.31 583155.16 N 70.35067533 W 149.32 7 516.00 6.21 8.26 437.87 514.97 20.70 25.68 24.15 24.14 -0.39 0.86 5978299.52 583155.53 N 70.35068407 W 149.32 2 546.00 7.14 13.67 467.66 544.76 24.00 29.17 27.56 27.56 0.28 3.74 5978302.94 583156.17 N 70.35069340 W 149.32485035 635.00 10.23 22.34 555.64 632.74 37.14 42.58 40.51 40.25 4.59 3.76 5978315.67 583160.34 N 70.35072807 W 149.32481534 MWD +IFR +MS 657.67 11.28 20.50 577.91 655.01 41.32 46.81 44.61 44.19 6.14 4.87 5978319.63 583161.83 N 70.35073883 W 149.32480282 752.66 14.36 17.44 670.52 747.62 61.99 67.88 65.42 64.13 12.92 3.32 5978339.65 583168.40 N 70.35079331 W 149.32474774 846.46 16.91 21.05 760.84 837.94 86.82 93.15 90.51 87.97 21.31 2.91 5978363.57 583176.52 N 70.35085842 W 149.32467965 941.57 19.18 20.14 851.27 928.37 115.88 122.61 119.81 115.55 31.66 2.40 5978391.26 583186.56 N 70.35093377 W 149.32459563 1034.24 21.63 16.71 938.12 1015.22 147.50 154.91 152.07 146.20 41.81 2.94 5978422.03 583196.37 N 70.35101752 W 149.32451319 1128.43 24.72 13.60 1024.70 1101.80 183.29 191.96 189.11 181.98 51.44 3.53 5978457.91 583205.60 N 70.35111527 W 149.32443505 1223.02 29.02 12.35 1109.06 1186.16 224.14 234.70 231.81 223.64 61.00 4.58 5978499.66 583214.70 N 70.35122907 W 149.32435742 1317.55 32.45 11.73 1190.30 1267.40 270.07 283.01 280.05 270.88 71.06 3.64 5978547.01 583224.24 N 70.35135813 W 149.32427572 1412.34 35.45 11.49 1268.92 1346.02 320.29 335.94 332.91 322.73 81.71 3.17 5978598.97 583234.31 N 70.35149978 W 149.32418927 SurveyEditor Ver SP 2.1 Bld( users) L- 223 \L -223 drilling \L - 223 \L -223 Generated 11/24/2009 9:48 AM Page 1 of 4 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub-Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft) I (deg) I (deg) (ft) (ft) (ft) (ft ) (ft ) (ft) (ft ) (deg /100ft ) (ftUS) (ftUS) 1505.76 39.08 14.69 1343.27 1420.37 374.39 392.49 389.45 377.79 94.58 4.40 5978654.16 583246.56 N 70.35165018 W 149.32408479 1600.75 43.41 15.60 1414.67 1491.77 434.90 455.10 452.05 438.22 110.96 4.60 5978714.76 583262.27 N 70.35181527 W 149.32395182 1695.24 46.79 14.92 1481.36 1558.46 499.60 522.02 518.96 502.78 128.56 3.61 5978779.51 583279.15 N 70.35199165 W 149.32380890 1789.76 47.81 13.90 1545.46 1622.56 566.49 591.48 588.42 570.06 145.84 1.34 5978846.97 583295.68 N 70.35217545 W 149.32366859 1885.75 52.47 15.15 1606.97 1684.07 637.48 665.14 662.08 641.36 164.34 4.96 5978918.46 583313.39 N 70.35237023 W 149.32351838 1979.81 53.32 15.66 1663.71 1740.81 710.06 740.16 737.08 713.68 184.27 1.00 5978990.99 583332.51 N 70.35256780 W 149.32335657 2073.61 55.84 14.89 1718.07 1795.17 783.97 816.59 813.51 787.41 204.40 2.77 5979064.94 583351.82 N 70.35276923 W 149.32319313 2167.84 60.01 13.65 1768.10 1845.20 860.78 896.42 893.33 864.78 224.06 4.56 5979142.51 583370.62 N 70.35298059 W 149.32303352 2263.58 63.87 13.74 1813.13 1890.23 941.84 980.89 977.79 946.85 244.06 4.03 5979224.79 583389.70 N 70.35320479 W 149.32287112 2356.00 67.14 13.10 1851.44 1928.54 1022.41 1064.98 1061.87 1028.64 263.57 3.59 5979306.79 583408.30 N 70.35342825 W 149.32271269 2450.51 67.97 14.11 1887.52 1964.62 1106.19 1152.33 1149.21 1113.54 284.12 1.32 5979391.90 583427.91 N 70.35366018 W 149.32254582 2544.68 70.21 17.81 1921.14 1998.24 1191.50 1240.28 1237.12 1198.09 308.32 4.37 5979476.70 583451.17 N 70.35389115 W 149.32234929 2639.05 73.54 21.15 1950.50 2027.60 1279.65 1329.96 1326.46 1282.61 338.24 4.87 5979561.54 583480.15 N 70.35412204 W 149.32 3 2734.16 75.29 25.51 1976.07 2053.17 1370.60 1421.56 1417.08 1366.70 374.52 4.78 5979646.02 583515.49 N 70.35435177 W 149.327 2828.02 75.89 29.61 1999.43 2076.53 1461.40 1512.47 1506.03 1447.27 416.58 4.28 5979727.04 583556.64 N 70.35457187 W 149.32147017 2922.27 73.30 30.48 2024.47 2101.57 1552.26 1603.32 1594.34 1525.92 462.06 2.89 5979806.18 583601.25 N 70.35478673 W 149.32110081 3016.39 72.76 31.94 2051.94 2129.04 1642.26 1693.34 1681.69 1602.91 508.71 1.59 5979883.68 583647.03 N 70.35499705 W 149.32072203 1 3112.03 74.64 32.13 2078.78 2155.88 1734.00 1785.14 1770.74 1680.72 557.40 1.97 5979962.02 583694.85 N 70.35520962 W 149.32032663 3203.86 77.26 32.64 2101.07 2178.17 1823.00 1874.21 1857.28 1755.94 605.11 2.90 5980037.76 583741.72 N 70.35541510 W 149.31993917 3299.22 78.31 33.21 2121.25 2198.35 1916.08 1967.41 1947.87 1834.17 655.77 1.25 5980116.54 583791.50 N 70.35562881 W 149.31952777 3392.76 76.85 32.96 2141.37 2218.47 2007.30 2058.76 2036.84 1910.71 705.63 1.58 5980193.62 583840.51 N 70.35583789 W 149.31912280 3487.66 75.20 32.76 2164.28 2241.38 2099.27 2150.85 2126.81 1988.06 755.60 1.75 5980271.51 583889.61 N 70.35604919 W 149.31871701 3581.81 77.38 33.14 2186.60 2263.70 2190.62 2242.31 2216.31 2064.81 805.35 2.35 5980348.80 583938.50 N 70.35625885 W 149.31831297 3676.88 75.61 33.27 2208.80 2285.90 2282.91 2334.75 2306.84 2142.15 855.97 1.87 5980426.70 583988.26 N 70.35647013 W 149.31790184 3771.17 75.35 33.92 2232.44 2309.54 2374.01 2426.03 2396.26 2218.18 906.47 0.72 5980503.28 584037.91 N 70.35667783 W 149.31749164 3867.43 75.85 34.50 2256.38 2333.48 2467.00 2519.26 2487.53 2295.29 958.89 0.78 5980580.95 584089.47 N 70.35688845 W 149.31706589 3959.37 74.31 34.54 2280.05 2357.15 2555.57 2608.10 2574.54 2368.48 1009.24 1.68 5980654.69 584138.99 N 70.35708840 W 149.31665699 4054.68 76.31 34.39 2304.22 2381.32 2647.48 2700.29 2664.98 2444.49 1061.41 2.10 5980731.27 584190.31 N 70.35729602 W 149.31623325 4149.60 74.46 34.07 2328.17 2405.27 2739.08 2792.13 2755.27 2520.43 1113.07 1.98 5980807.77 584241.12 N 70.35750345 W 149.31581360 4243.73 75.91 33.97 2352.24 2429.34 2829.86 2883.13 2844.87 2595.85 1163.98 1.54 5980883.74 584291.19 N 70.35770948 W 149.31540006 4338.44 77.20 33.77 2374.26 2451.36 2921.77 2975.24 2935.70 2672.33 1215.32 1.38 5980960.78 584341.67 N 70.35791840 W 149.3108 4432.72 75.94 33.64 2396.15 2473.25 3013.28 3066.94 3026.25 2748.62 1266.21 1.34 5981037.62 584391.70 N 70.35812678 W 149.31 3 4526.74 76.47 33.87 2418.57 2495.67 3104.40 3158.25 3116.46 2824.53 1316.94 0.61 5981114.09 584441.58 N 70.35833415 W 149.314 60 4621.04 76.53 33.86 2440.59 2517.69 3195.89 3249.95 3207.09 2900.67 1368.04 0.06 5981190.78 584491.83 N 70.35854213 W 149.31374254 4716.06 74.82 33.61 2464.09 2541.19 3287.76 3342.01 3298.17 2977.23 1419.16 1.82 5981267.90 584542.10 N 70.35875125 W 149.31332720 4806.71 74.79 34.36 2487.85 2564.95 3375.03 3429.49 3384.72 3049.77 1468.06 0.80 5981340.96 584590.18 N 70.35894939 W 149.31292996 4901.98 74.49 33.78 2513.09 2590.19 3466.67 3521.36 3475.63 3125.87 1519.53 0.67 5981417.62 584640.80 N 70.35915726 W 149.31251188 4997.46 73.12 34.39 2539.72 2616.82 3558.13 3613.04 3566.41 3201.80 1570.91 1.56 5981494.12 584691.33 N 70.35936468 W 149.31209444 5092.20 72.89 34.88 2567.41 2644.51 3648.44 3703.65 3656.05 3276.35 1622.40 0.55 5981569.22 584741.99 N 70.35956831 W 149.31167611 5186.33 74.76 34.95 2593.63 2670.73 3738.51 3794.05 3745.46 3350.48 1674.14 1.99 5981643.91 584792.90 N 70.35977079 W 149.31125575 5279.21 75.50 34.70 2617.47 2694.57 3827.97 3883.82 3834.32 3424.17 1725.41 0.84 5981718.16 584843.34 N 70.35997207 W 149.31083926 5373.35 75.82 34.28 2640.78 2717.88 3918.90 3975.02 3924.71 3499.35 1777.06 0.55 5981793.90 584894.14 N 70.36017741 W 149.31041965 5467.23 75.70 33.69 2663.88 2740.98 4009.68 4066.02 4015.03 3574.80 1827.92 0.62 5981869.90 584944.16 N 70.36038350 W 149.31000639 5561.75 74.91 33.53 2687.85 2764.95 4100.93 4157.45 4105.88 3650.94 1878.53 0.85 5981946.60 584993.91 N 70.36059148 W 149.30959520 SurveyEditor Ver SP 2.1 Bld( users) L- 223 \L -223 drilling \L - 223 \L -223 Generated 11/24/2009 9:48 AM Page 2 of 4 I I r II I Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub -Sea TVD TVD Closure DLS Northing Easting Latitude Longitude. Depth True Section Departure True North True North (ft ) (deg) (deg) (ft ) (ft ) (ft ) (ft) I (ft) I (ft) (ft ) (deg /100ft ) (ftUS) (ftUS) 5656.78 76.09 33.31 2711.65 2788.75 4192.77 4249.45 4197.35 3727.73 1929.20 1.26 5982023.94 585043.73 N 70.36080123 W 149.30918348 5749.99 78.05 33.51 2732.50 2809.60 4283.46 4340.29 4287.70 3803.56 1979.22 2.11 5982100.31 585092.90 N 70.36100836 W 149.30877705 5845.22 77.23 33.13 2752.89 2829.99 4376.33 4433.31 4380.25 3881.29 2030.32 0.95 5982178.59 585143.13 N 70.36122067 W 149.30836184 5940.39 76.08 32.77 2774.85 2851.95 4468.81 4525.91 4472.46 3958.99 2080.68 1.26 5982256.84 585192.62 N 70.36143291 W 149.30795259 6032.25 75.52 32.61 2797.39 2874.49 4557.76 4614.96 4561.18 4033.94 2128.78 0.63 5982332.31 585239.88 N 70.36163762 W 149.30756175 6066.80 74.96 33.07 2806.19 2883.29 4591.13 4648.37 4594.46 4062.01 2146.90 2.07 5982360.58 585257.68 N 70.36171429 W 149.30741453 6191.24 73.65 32.99 2839.85 2916.95 4710.77 4768.17 4713.79 4162.45 2212.20 1.05 5982461.73 585321.86 N 70.36198862 W 149.30688390 6285.18 72.79 34.06 2866.97 2944.07 4800.54 4858.11 4803.31 4237.42 2261.87 1.42 5982537.24 585370.69 N 70.36219341 W 149.30648025 6380.80 75.43 34.08 2893.15 2970.25 4892.27 4950.07 4894.78 4313.60 2313.39 2.76 5982613.98 585421.35 N 70.36240147 W 149.30606162 6473.84 78.08 33.34 2914.47 2991.57 4982.64 5040.62 4984.93 4388.93 2363.64 2.95 5982689.85 585470.76 N 70.36260723 W 149.30565322 6567.59 78.20 33.78 2933.73 3010.83 5074.22 5132.37 5076.30 4465.38 2414.36 0.48 5982766.86 585520.63 N 70.36281605 W 149.30524103 6661.41 76.61 32.96 2954.19 3031.29 5165.62 5223.93 5167.52 4541.85 2464.72 1.90 5982843.87 585570.13 N 70.36302489 W 149.30483174 6756.58 73.68 33.28 2978.59 3055.69 5257.47 5315.91 5259.20 4618.88 2514.98 3.10 5982921.45 585619.52 N 70.36323530 W 149.30430 6851.50 74.78 33.06 3004.38 3081.48 5348.68 5407.26 5350.26 4695.34 2564.96 1.18 5982998.45 585668.65 N 70.36344414 W 149.30 2 6944.46 74.00 33.48 3029.40 3106.50 5438.06 5496.79 5439.50 4770.20 2614.07 0.95 5983073.84 585716.92 N 70.36364859 W 149.30 95 7038.78 74.13 33.29 3055.29 3132.39 5528.60 5587.48 5529.90 4845.93 2663.98 0.24 5983150.12 585765.98 N 70.36385543 W 149.30321233 7132.42 74.59 32.49 3080.54 3157.64 5618.67 5677.66 5619.85 4921.65 2712.94 0.96 5983226.37 585814.10 N 70.36406224 W 149.30281434 7227.60 76.18 32.97 3104.55 3181.65 5710.66 5769.75 5711.74 4999.12 2762.74 1.74 5983304.38 585863.03 N 70.36427384 W 149.30240960 7322.07 75.98 32.76 3127.28 3204.38 5802.24 5861.45 5803.22 5076.14 2812.50 0.30 5983381.94 585911.92 N 70.36448420 W 149.30200514 7416.07 73.52 33.65 3152.00 3229.10 5892.79 5952.13 5893.66 5152.02 2862.15 2.77 5983458.36 585960.73 N 70.36469144 W 149.30160151 7510.29 73.74 32.34 3178.56 3255.66 5983.07 6042.53 5983.85 5227.84 2911.38 1.35 5983534.71 586009.11 N 70.36489852 W 149.30120137 7605.10 76.22 31.89 3203.13 3280.23 6074.57 6134.10 6075.29 5305.39 2960.06 2.66 5983612.79 586056.92 N 70.36511033 W 149.30080569 7700.44 77.13 32.18 3225.10 3302.20 6167.29 6226.87 6167.95 5384.04 3009.27 1.00 5983691.97 586105.25 N 70.36532513 W 149.30040566 7794.47 76.76 32.00 3246.34 3323.44 6258.83 6318.47 6259.43 5461.64 3057.93 0.44 5983770.10 586153.04 N 70.36553708 W 149.30001008 7890.08 74.44 30.76 3270.12 3347.22 6351.40 6411.07 6351.97 5540.69 3106.15 2.73 5983849.68 586200.38 N 70.36575299 W 149.29961806 7982.94 73.87 31.15 3295.47 3372.57 6440.72 6500.40 6441.26 5617.30 3152.10 0.73 5983926.78 586245.47 N 70.36596222 W 149.29924451 8076.90 74.69 31.46 3320.93 3398.03 6531.14 6590.84 6531.65 5694.58 3199.09 0.93 5984004.57 586291.60 N 70.36617328 W 149.29886245 8171.65 75.17 31.85 3345.56 3422.66 6622.60 6682.33 6623.07 5772.46 3247.11 0.64 5984082.97 586338.74 N 70.36638598 W 149.29847209 8265.96 75.83 31.70 3369.18 3446.28 6713.86 6773.64 6714.29 5850.08 3295.19 0.72 5984161.11 586385.95 N 70.36659798 W 149.29808119 8359.40 74.20 33.39 3393.34 3470.44 6804.03 6863.90 6804.41 5926.16 3343.74 2.47 5984237.72 586433.65 N 70.36680578 W 149.29768648 8453.53 73.92 33.59 3419.19 3496.29 6894.38 6954.41 6894.70 6001.65 3393.68 0.36 5984313.75 586482.75 N 70.36701193 W 149.294 8548.26 73.53 34.19 3445.74 3522.84 6985.10 7045.34 6985.37 6077.13 3444.39 0.73 5984389.79 586532.61 N 70.36721808 W 149.29 1 8643.24 72.83 33.65 3473.22 3550.32 7075.81 7136.26 7076.02 6152.58 3495.12 0.92 5984465.78 586582.50 N 70.36742412 W 149.29 2 8737.72 75.39 33.30 3499.09 3576.19 7166.51 7227.12 7166.68 6228.37 3545.24 2.73 5984542.12 586631.76 N 70.36763111 W 149.29604826 8831.60 74.86 33.04 3523.19 3600.29 7257.11 7317.85 7257.24 6304.32 3594.88 0.62 5984618.60 586680.56 N 70.36783853 W 149.29564462 8926.12 74.95 33.19 3547.80 3624.90 7348.24 7409.11 7348.34 6380.75 3644.74 0.18 5984695.58 586729.56 N 70.36804728 W 149.29523924 9020.28 73.99 32.71 3573.01 3650.11 7438.84 7499.83 7438.92 6456.88 3694.08 1.13 5984772.24 586778.05 N 70.36825519 W 149.29483801 9115.56 75.03 31.69 3598.46 3675.56 7530.59 7591.65 7530.65 6534.58 3743.01 1.50 5984850.47 586826.10 N 70.36846738 W 149.29444018 9208.04 73.27 32.42 3623.72 3700.82 7619.50 7680.61 7619.55 6609.97 3790.22 2.05 5984926.38 586872.47 N 70.36867329 W 149.29405626 9303.16 75.41 33.20 3649.39 3726.49 7710.97 7772.20 7711.01 6686.94 3839.84 2.38 5985003.89 586921.24 N 70.36888350 W 149.29365271 9396.83 75.48 33.34 3672.93 3750.03 7801.49 7862.86 7801.51 6762.75 3889.58 0.16 5985080.23 586970.13 N 70.36909052 W 149.29324826 9491.27 75.09 33.68 3696.92 3774.02 7892.67 7954.20 7892.68 6838.91 3940.01 0.54 5985156.94 587019.70 N 70.36929851 W 149.29283819 9586.26 74.16 33.70 3722.11 3799.21 7984.07 8045.79 7984.07 6915.12 3990.81 0.98 5985233.70 587069.65 N 70.36950662 W 149.29242504 9681.75 75.84 33.60 3746.82 3823.92 8076.12 8138.02 8076.12 6991.89 4041.92 1.76 5985311.04 587119.90 N 70.36971630 W 149.29200943 9775.23 76.15 33.94 3769.44 3846.54 8166.63 8228.73 8166.63 7067.29 4092.34 0.48 5985386.98 587169.47 N 70.36992220 W 149.29159942 SurveyEditor Ver SP 2.1 Bld( users) L- 223 \L -223 drilling \L-223\L-223 Generated 11/24/2009 9:48 AM Page 3 of 4 I Measured Azimuth Vertical Along Hole NS EW Comments Inclinat Sub-Sea TVD I TVD I Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North (ft ) (deg) (deg) (ft ) (ft ) (ft ) (ft) (ft) (ft ) (ft ) (dep1100ft ) (ftUS) (ftUS) 9870.09 76.66 33.76 3791.74 3868.84 8258.63 8320.93 8258.63 7143.87 4143.70 0.57 5985464.11 587219.97 N 70.37013132 W 149.29118176 9964.60 78.03 33.57 3812.44 3889.54 8350.65 8413.14 8350.67 7220.61 4194.81 1.46 5985541.41 587270.23 N 70.37034091 W 149.29076605 10058.84 75.56 33.01 3833.97 3911.07 8442.25 8504.88 8442.28 7297.30 4245.17 2.68 5985618.65 587319.73 N 70.37055032 W 149.29035650 10152.56 71.43 32.99 3860.59 3937.69 8531.97 8594.72 8532.01 7372.64 4294.10 4.41 5985694.52 587367.81 N 70.37075608 W 149.28995855 10247.49 67.96 32.34 3893.53 3970.63 8620.89 8683.74 8620.94 7447.58 4342.15 3.71 5985769.98 587415.02 N 70.37096072 W 149.28956774 10342.21 64.74 32.66 3931.52 4008.62 8707.56 8770.49 8707.63 7520.75 4388.76 3.41 5985843.65 587460.81 N 70.37116053 W 149.28918864 10436.11 60.48 32.91 3974.71 4051.81 8790.82 8853.84 8790.90 7590.82 4433.89 4.54 5985914.22 587505.16 N 70.37135191 W 149.28882154 10530.50 56.34 32.21 4024.14 4101.24 8871.13 8934.23 8871.23 7658.57 4477.16 4.43 5985982.44 587547.67 N 70.37153691 W 149.28846958 10624.84 52.68 30.22 4078.91 4156.01 8947.90 9011.03 8948.01 7724.23 4516.99 4.24 5986048.53 587586.76 N 70.37171622 W 149.28814563 10719.41 51.77 29.68 4136.84 4213.94 9022.65 9085.78 9022.76 7789.00 4554.31 1.06 5986113.70 587623.36 N 70.37189309 W 149.28784204 10812.05 51.49 28.92 4194.34 4271.44 9095.28 9158.41 9095.38 7852.33 4589.85 0.71 5986177.42 587658.20 N 70.37206607 W 149.28755286 10906.79 49.26 28.74 4254.76 4331.86 9168.23 9231.37 9168.32 7916.26 4625.04 2.36 5986241.72 587692.67 N 70.37224064 W 149.287 59 11001.09 49.23 29.09 4316.32 4393.42 9239.65 9302.81 9239.73 7978.78 4659.58 0.28 5986304.63 587726.51 N 70.37241140 W 149.289 11096.17 47.13 28.45 4379.72 4456.82 9310.48 9373.66 9310.56 8040.89 4693.68 2.26 5986367.10 587759.92 N 70.37258100 W 149.286 10 11190.01 46.98 28.14 4443.65 4520.75 9379.14 9442.35 9379.21 8101.37 4726.24 0.29 5986427.93 587791.80 N 70.37274618 W 149.28644317 11283.39 46.84 28.64 4507.44 4584.54 9447.31 9510.55 9447.37 8161.36 4758.67 0.42 5986488.28 587823.56 N 70.37291002 W 149.28617936 11377.83 46.98 27.92 4571.96 4649.06 9516.24 9579.51 9516.30 8222.10 4791.34 0.58 5986549.36 587855.55 N 70.37307588 W 149.28591350 11470.75 47.04 27.69 4635.32 4712.42 9584.16 9647.48 9584.20 8282.22 4823.05 0.19 5986609.83 587886.59 N 70.37324007 W 149.28565552 11565.60 44.49 29.23 4701.48 4778.58 9652.08 9715.43 9652.12 8341.97 4855.41 2.93 5986669.92 587918.28 N 70.37340324 W 149.28539219 11660.22 44.63 28.73 4768.90 4846.00 9718.46 9781.82 9718.50 8400.04 4887.58 0.40 5986728.35 587949.80 N 70.37356184 W 149.28513046 11753.76 44.85 28.43 4835.34 4912.44 9784.28 9847.67 9784.31 8457.86 4919.07 0.33 5986786.51 587980.65 N 70.37371974 W 149.28487417 11849.25 44.86 28.57 4903.04 4980.14 9851.61 9915.02 9851.63 8517.05 4951.21 0.10 5986846.05 588012.12 N 70.37388138 W 149.28461267 Last Survey 11866.33 44.91 28.08 4915.14 4992.24 9863.66 9927.07 9863.68 8527.66 4956.93 2.05 5986856.72 588017.72 N 70.37391036 W 149.28456613 TD (Projected) 11927.00 44.91 28.08 4958.11 5035.21 9906.46 9969.90 9906.48 8565.45 4977.09 0.00 5986894.73 588037.46 N 70.37401356 W 149.28440207 Survey Type: Definitive Survey NOTES: GYD GC SS - ( Gyrodata - gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - ( In -field referenced MWD with mult- station analysis and correction applied in post - processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Y) MUM Eastinq 1X) fftUS1 Surface : 2554 FSL 3758 FEL S34 T12N R11E UM 5978275.38 583156.19 • BHL : 557 FSL 4045 FEL S23 T12N R11 E UM 5986894.73 588037.46 SurveyEditor Ver SP 2.1 Bld( users) L- 223 \L -223 drilling \L - 223 \L -223 Generated 11/24/2009 9:48 AM Page 4 of 4 TREE = 4- 1/16" CIW • WELLHEAD FMC SAFET ES: ACTLATOR = CAM LEO L -223 KB. ELEV = 77.10' BF. ELEV = 25.87' DRLG DRAFT KOP = I l 1 24' 1-14.5" X 3.5" X0, ID = 2.992" I Max Angle = 78° @ 3299' (CONDUCTOR H 108' 4 518 1� 3.5" HES X NIP, ID = 2 I Datum MD = 11126' ' .813" Datum TVD = 4400'SS GAS LIFT MANDRELS 19 -5/8" CSG, 40 #, L -80, BTC ID = 8.84" H 6121' ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 11065 4436 48 MMG -HW DMY RK 0 10/22/09 7" CSG, 26 #, BTC, XO TO TCII ( J I 7593' I — X 7 11133 4482 47 MMG -HW DMY RK 0 10/22/09 6 11329 4616 47 MMG -I-IW DMY RK 0 10/22/09 5 11386 4655 47 MMG -HW DMY RK 0 10/22/09 MARKER JOING w / RA TAG I—I 10978' I 1 4 11434 4687 47 MMG -HW DMY RK 0 10/22/09 3 11500 4732 46 MMG -HW DMY RK 0 10/22/09 2 11547 4765 45 MMG -HW DMY RK 0 10/22/09 ( MARKER JOINT w / RA TAG H 11020' 1 - 1 1 11674 4856 45 MMG -HW DMY RK 0 10/22/09 S ► +/ Minimum ID = 2.75 " @ 11,727' 11022' 7" X 3 -1/2" HES DBL FEEDTHRU PKR, ID = 2.965" 3 -1/2" HES XN NIP 11035' HNDPG GAUGE 1 M S ►=, 11225' H 7" X 3-1/2" HES SINGLE FEEDTHRU PKR, ID = 2.965" I • I 11239' I I NDPG GAUGE 1 MP ' Z '+ 11352' H7" X 3 -1/2" HES SINGLE FEEDTHRU PKR, ID = 2.965" 1 • 1 11360' I GAUGE 1 MIP IIP S mo 11466' H7" X 3-1/2" HES SINGLE FEEDTHRU PKR, ID = 2.965" I PERFORATION SUMMARY • I 11480' I� NDPG GAUGE 1 REF LOG: ANGLE AT TOP PERF: 47° @ 11094' ' Note: Refer to Production DB for historical perf data IIM SIZE SPF ZONE INTERVAL Opn /Sqz DATE S ► =, 11569' 1 X 3 -1/2" HES SINGLE FEEDTHRU PKR, ID = 2.965" I 4.5" 5 Nb 11094 - 11122 0 10/19/09 4.5" 5 OA 11277 - 11330 0 10/19/09 I 11583' I-I NDPG GAUGE 1 4.5" 5 OBa 11372 - 11420 0 10/19/09 4.5" 5 OBc 11518 - 11546 0 10/19/09 WI 1 4.5" 5 OBd 11590 - 11657 0 10/19/09 ' , I 11707' H3.5" HES X NIP, ID = 2.813" I 1 1 1 11727' I- -13.5" HES XN NIP, ID = 2.75 I 13.5" TBG, 9.2 #, L -80 TCII, .0087 bpf, ID = 2.992" H 11750' / \ — 1 11750' I -13.5" WLEG, ID = 2.992" ( PBTD H 11811' .'f•∎ ■•1■ 1 1 7" CSG, 26 #, BTC ID = 6.276" H 11893' • 1. TD = 11927' DATE REV BY COMMENTS DATE REV BY COMMENTS ORION UNIT 10/27/09 N7ES ORIGINAL COMPLETION WELL: L -223 11/04/09 SV DRLG HO CORRECTIONS PERMIT No: 209 -099 AR No: 50- 029 - 23415 -00 SEC T R BP Exploration (Alaska) • - 0 c? ISCEANICAL INTEGRITY REPORT • 5 DA.__ : Z64 /0 OPER & FIELD e r " £ t.in X 5 RIG RELEASE: • l a /Z7/d9 ELL NUMBER L - 22 3 4 LL DATA TD: f //27.2D.. So3.rTVD :BTD : II"' ?•ID TVD Casing: 9 Shoe : '' (-' MD 2 8 98 TVD ; DV: O T4'D -.' Shoe: /CS'93.MD Sb11 TVD; TOP: 1)1 MD ':vp Viz Packs. MX TVD; Set at ( /02_Z 'op .;ale Size tY :' and ; Perfs /014 to /6E7 r.. * O r ECBAII�..g• -L INTEGRITY - PART 11 430o yioo Annulus Press Test: ZP 4 s 15 min 3 `�76 ; 30 min 5 6 : •� Comments : ,' ` e T ..‘ so-,_:.9 6L- S " I - Aso . • '4E CHANICAL INTEGRITY - PART #2 ��� " Sae Cement Volumes: Amt. %c /23 66/ tcsg DV CID vol to cover perfs ' 30t -e.xc Toc- _ - 7 Q- // O wt Theoretical TOC 72 w/ at £€CC Ccs-; /et.: -cLT Cement Bond Log 40.r No) as / r ; In AOGCC File CBL Evaluation, zone above perfs L 1 �4,2 I "ro -� 7 70 b n4 J/. Production Log: Type SUM- 7 Evaluation CONCLUSIONS: P ert # 1: 14/ css 2 Mt 7 /,4 ?art 2: /v i 2 3. 101“-k6 L - 22.3 Y l ll rage 1 of 1 • • Maunder, Thomas E (DOA) From: Ciolkosz, Ryan R [Ryan.Ciolkosz @bp.com] Sent: Wednesday, September 23, 2009 10:52 AM To: Maunder, Thomas E (DOA) Subject: L -223 PTD Tom, I wanted to let you know that L -223 have moved up on the schedule compared to what the permit states. 7ES will be moving to L pad on Friday 25, 2009. I wanted to see how the permit approval process is coming along with this well and if there are any issues with the permit? Thank you, Ryan Ciolkosz GPB Rotary Operations Drilling Engineer BP Exploration Alaska Office: (907)564 -5977 Cell: (907)306 -5626 9/23/2009 4 r t t `* l SchI ler NO. 5180 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambet Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date 81 Color CO OWDW -SW 83S0 -00032 RST/WFLy G l J`7 _ 'j'69 q 11/07/09 1 1 F L -223 8581-00014 USIT V 1 c # U '' { • 10/2/109 1 1 S -218 BUN-00018 USIT CY U "" 40 • ' 10/21/09 1 1 L -222 8350 -00031 USIT it • ' • "' • ` • 11/07/09 1 1 L2 -24 B148 -00079 i ' • ^ _ 10/31/09 1 1 0 L2 -32 814B-00078 RST 3 Q 1 � AWN !�/ 10/30/09 1 1 L1 -14 AVIH 00029 RST A �j;��T 10/27/08 1 1 L2 -18A 1314@ -00077 �` �l�"j/!� 10/30/09 1 1 D -28B AXED -00053 i a L 10/02/09 /09 _ALTO 10/27/09 1 1 S -22B 138K5 -00008 RST ;� rfA tra� �, 0-24 AWL8-00038 RST ` � 18-15B AYS4-00107 RST G .- - NC '' •' ' 09/27/09 0/31/09 1 1 04-21 L2-07A AY00 -00047 � a � as 1!)/2 1 1 _- OWDW -SW 13350 -00032 RST T (n( , _K 11/07/09 1 12- 05AP81 40015441 OH MWD/LWD EDIT ... • •,• _ 07/01/07 2 1 06 -218 08AKA0016 011 MWD/LWD EDIT () r- •Z Alf.. 07/28/08 2 1 D -16A 09AKA0175 OH MWD/LWD EDIT ' n ;` 09/07/09 2 1 1-223 09AKA0081 OH MWD/LWD EDIT V D" — OT Q 10/10/09 2 1 L -223 8581 -00014 CH EDIT PDC (USIT) ( arp, �_ 1 41 10/21/09 1 S -218 B5JN-00018 CH EDIT PDC (USIT _rA f / , _ 10/21/09 1 L -222 B3SQ -00031 CH EDIT PDC (USIT) (z aA— ( (01 fl 11/07/09 1 04 -33A 09AKA0075 OH MWD/LWD EDIT a —01t — /y AZ.5 09/19/09 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambol! Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 a $ChIumberger NO.5180 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD OWDW -SW 8390 -00032 RST/WF c- IOQ - 3 ' 7 � '} G/ 11/07/09 1 1 L -223 8581 -00014 USIT � -) - c ' ' 10/21/09 1 1 S -218 B5JN -00018 USIT (} 10/21/09 1 1 1-222 8350.00031 USIT 0-1.6_ QAg ...1 ( C3 + /) 0 11/07/09 1 1 L2 -24 _ 814B -00079 RST 07 G( )4 d 1 S 4 10/31/09 1 1 0 L2 -32 8148-00078 RST ) ( (/ 10 /30 /09 1 1 11-14 AVIH 00029 RST ,�j ail 10/27/09 1 1 12 -18A 8148 -00077 RST j / 10/30/09 1 1 D -28B AXBD -00053 MCNLB( '' I d/ 10/02/09 1 1 S -228 B8K5 -00008 RST t j')' C i .- C f / 9 (icy '- 10/27/09 1 1 D-24 AWL8-00038 RST 11- s — ,QQg g 09/27/09 1 1 18 -15B AYS4 -00107 RST q'. -- o ( • ' Qj 10/31/09 1 1 04 -21 - ANHY -00115 RST 1 — ' 0 10/27/09 1 1 L2 07A AY00 -00047 RST 1 — r `j air r 10/29/09 1 1 OWDW -SW B3S0 -00032 RST ) Ifr 10( " (5 , r 11/07/09 1 12- 05APB1 40015441 OH MWD/LWD EDIT al' —0 &C 07/01/07 2 1 06 -218 08AKA0016 OH MWD/LWD EDIT - • '" �" 07/28/08 2 1 r D ILA 09AKA0175 OH MWD/LWD EDIT ' C b ) -n _ ' • _ 09/07/09 2 1 1-223 09AKA0081 OH MWD/LWD EDIT _ _ 4" S' ' • Y 10/10/09 2 1 , L -2 8581 -00014 CH EDIT PDC (USIT) ( -rti c p c f j_ n e" .10 , 3 10/21/09 1 S -218 B5JN -00018 CH EDIT PDC (USIT) O a0 — ( 3g_ /59 10/21/09 1 L -222 B3SQ -00031 CH EDIT PDC (USIT) (Zy a� — ( (o AO ter 11/07/09 1 04 -33A 09AKA0075 0H MWD/LWD EDIT a A al -pior 19 h 09/19/09 2 J 1 1 lit PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, State 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 Alaska Drilling and Wells Saftand Down • Page 1 of 2 Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs @bp.com] Sent: Thursday, October 15, 2009 4:55 PM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel Subject: RE: Alaska Drilling and Wells Safety Stand Down Tom- Doyon 14 - Z -25 - Operations shut down at 21:00 hours on 10/12/09. Cement Plug in place at 11,032'. Clean -out BHA hung off from floor to 3350' with circulation through the cement line while the shut -down is ongoing. Doyon 16 - Q -04A Had just tested BOP's and were preparing to pull tubing when operations were shut down. Two way check installed in tubing and tested. Kill lines blown down. Begin stand down at 22:30 on 10/12/2009. Nordic 1 - 06 -18A Finish logging run of newly run and cemented liner. Clear floor, Jet Stack, begin Stand Down at midnight, 10/12/09. Nordic 2 - H -05B Drill to 13,795' MD. Trip for bit. Test BOP's. Begin safety stand -down at 15:45 hours 10/14/09. Fill hole every six hours with a loss rate of 1 barrel per hour. Nabors 4es - Move to MPL -29. Incident occurred at approximately 12:00 hours on 10/10/09. Begin Safety Stand -down at 12:30 p.m. Still rigging up at time of incident. Rig over well, pits full, no wellwork started. aoe oSci Nabors 7es - L -223 7" casing run and cemented. Emergency slips set with pack -off. NU BOP. Test casing spool to tubing spool flange to 5000 psi and FMC pack -off with hand test pump. Change rams from 7" to VBR's, test. Freeze protect OA. Begin Stand Down at 0900 Hours 10/14/09. Nabors 9es - S -218 Currently finishing up running and cementing 7" longstring. Freeze protect OA. Anticipated start of Safety Shut -down- 10:00 hours 10/15/09. Hope that will suffice. Sorry about the delay- the computer has been acting up today - Thanks and don't hesitate to get back with me if you need more information - Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, October 15, 2009 11:15 AM To: Hobbs, Greg S (ANC) Cc: Schultz, Mikel; DOA AOGCC Prudhoe Bay; Regg, James B (DOA); Aubert, Winton G (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Davies, Stephen F (DOA); Roby, David S (DOA) Subject: RE: Alaska Drilling and Wells Safety Stand Down Greg, Thanks for the information. Unfortunate that events have prompted this significant response. You indicate that the stand downs began with the wells at a "safe place" which is appropriate. With the wells secure and no 10/20/2009 Alaska Drilling and Wells Saftand Down Page 2 of 2 operations taking place, the need to accomplish BOP tests on the proscribed time interval is not necessary. You are correct that where the test time intervals have been exceeded that the BOP test will need to be accomplished as the first order of business when operations are resumed. For our records, would you please provide a summary of the wells associated with each rig and the wellbore conditions at the time of SD? Keep us informed as operations are resumed. Please call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs ©bp.com] Sent: Thursday, October 15, 2009 11:04 AM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel Subject: Alaska Drilling and Wells Safety Stand Down Tom - To follow up on our phone conversation yesterday, ADW is taking a safety stand down after a high potential incident over the weekend (Saturday) on Nabors 4es. Nabors 4es has been shut down since this event, Nabors 7es went down yesterday, and Nordic 1 and 2 and Doyon 14 and 16 started their stand -downs at a point in between. Nabors 9es is starting its stand -down today. This last incident, and our current safety statistics have created significant concern for ADW management that our current safety culture is not in the place it needs to be. The directive from Steve Robinson is that the stand down be used to address gaps in our safety culture that have allowed 50% of the incidents that have occurred to happen to employees with five years of experience or less. Of these incidents, 40% have occurred with employees working alone. By having every contractor and rig come up with a plan to address these issues, ADW management expects that occurrence of events at the top of the pyramid will be pushed out further into the future. Steve Robinson has asked that plans be presented to him, and they will require his approval. This stand down is unique in that each rig has shut down at a safe point, and there is no planned end time. Start-up on a rig by rig basis is dependent on contractors providing a plan that immediately adresses the above statistics which should defer more significant events. The plan also needs to address longer term changes to embed behaviors that will make a significant change in our current safety culture The reason for this mail is to make you aware that BOP tests could go beyond their timing requirements during the stand down. If this is the case, they will occur as the first operation following ADWE management's approval for a rig to re -start operations. We wanted to make you aware of this potential issue, and appreciate your support, and management wants everyone focuesd on their safety plans, not operations at this time. If you have any questions, feel free to get back with me. Thanks - Greg Hobbs 10/20/2009 7 !TA G Ems' ¢ fl P { u i g ii, , , ,., i i 4 S 6 ( t ) 4 r Ep , ��� R � 1 \ 1 k l I r ' SEAN PARNELL, GOVERNOR L L iL x t: , � , � a . u..? 1,1{ . 1 e I 4 J U) `i IA \...1 L (e. ALASKA OIL AND GAS / 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Mr. G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510 -0360 Re: Colville River Field, Alpine Oil Pool, CD4 -24 ConocoPhillips Alaska, Inc. Permit No: 209 -097 Surface Location: 2996' FNL, 515' FEL, Sec. 24, T11N, R4E, UM Bottomhole Location: 4486' FNL, 4416' FEL, Sec. 23, T11N, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, el / Daniel T. Seamount, Jr. / Chair DATED this ad of September, 2009 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA "' , ALAS•IL AND GAS CONSERVATION COMMI•N 9 -x,-09 ` PERMIT TO DRILL i r J 20 AAC 25.005 1 a. Type of work 1 b. Current Well Class ❑ Exploratory ❑ Development Gas 1 c. Specify if vell is proposed f or:' O Drill ❑ Redrill ® Service ❑ Multiple Zone ❑ Coalbed Methane ❑ Gas Hydrates ❑ Re -Entry ❑ Stratigraphic Test ❑ Development Oil ❑ Single Zone ❑ Shale Gas 2. Operator Name: 5. Bond: ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU L - 223 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 11905' TVD 5039' Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): 7. Property Designation: Schrader Bluff Surface: ADL 028239 & 375134 2554' FSL, 3758' FEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 330' FSL, 1090' FWL, SEC. 23, T12N, R11E, UM September 30, 2009 . Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 544' FSL, 1203' FWL, SEC. 23, T12N, R11E, UM 2560 4580' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Plan 15. Distance to Nearest Well Within Pool: Surface: x- 583156 y- 5978275 Zone -ASP4 (Height above GL): 77.5' feet 2920' 16. Deviated Wells: Kickoff Depth: 250 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 75 degrees Downhole: 2279 Surface: 1775 18. Casina Program: Specifications Too - Settina Depth - Bottom Quantity of Cement. c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 91.5# A -53 Weld 80' Surface Surface 80' 80' —260 sx Arctic Set 12 -1/4" 9 -5/8" 40# L -80 BTC 6008' Surface Surface 6037' 2887' 910 sx Arcticset Lite. 407 sx 'G' 8 -3/4" 7" 26# L -80 BTCM 11905' Surface Surface 11905' 5039' 186 sx LiteCrete. 305 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re - entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor / Structural _ Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ❑ Filing Fee, $100 ❑ BOP Sketch 0 Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Property Plat ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ryan Ciolkosz, 564 - 5977 Printed Name Ro rt Tirpac Title Engineering Team Leader Prepared By Name /Number Signature ,ri", :- r Phone 564 -4166 Date 770 Prepared Hubble, 564 -4628 Commission Use OnI Permit To Drill API Number: Permit val See cover letter for Number: 010 50,e�•?9,7 ,60000 Date: V Q / I requirements Approval: Conditions ofA a o f'lo,., i•% 4,c.c.r.( M /9 ied PP GC�� : v�► P Eardi% w ( !l � d ?� If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrate or gas contained shales: M 1 f .. . tew„e�.f tp,s.�C j Lot Sa Req'd: 2 Lr1 No Mud Log Req'd: ❑ Yes 0a No (/ H Measures: Yes ❑ No Directional Survey Req'd: Yes ❑ No Other: At 1 16°D rs:- 3OP /;s`t 2.94) e x_ ,Q. - 7 - co f� e n I e < moo z� 4A e z.s. v 33 cj, P r tw►as J. acc1 0• APPROVED BY THE COMMISSION Date „Aj ■■ , COMMISSIONER Form 10-401 Revised 1 -005 Submit In Duplicate ORIGINAL �2�a„ , • Well Name: L -223i Drill and Complete Plan Summary 1 Type of Well (service / producer / injector): 1 WAG Injector Surface Location: X= 583156 Y= 5978276 As -Built 2554' FSL, 3758' FEL, T12N, R11E, Sec. 34 Target Locations: Tgt 1 X= 587895 Y= 5986665 Z =4797 329' FSL, 4190' FEL, T12N, R11E, Sec. 23 Bottom Hole Location: X = 588006' Y = 5986880' Z =4797' 544' FSL, 4076' FEL, T12N, R11E, Sec. 23 Doug Von Tish Geophysicist 564 -5158 Taylor West Prod. Engineer 564 -4647 Ryan Ciolkosz Drilling Engineer 564 -5977 I API NUMBER: 1 TBD I I Rig: I Nabors 7ES I Estimated Start Date: 1 09/30/2009 1 'Operating Days to complete: 1 24 I MD: 111905' I I TVD: 1 5039' I I RT /GL: 1 28.5'/49.0' 1 I RTE: 1 77.5' I Well Design: Schrader Bluff Injector 3'/2" tbg, 9.2# L -80, TC -II, multi - packer I Objective: 1 WAG Injector into the OBd, OBc, Oba, OA, and Nb sands Directional Plan: Version: Schlumberger P3b KOP: 250' MD, build 1.5/100 Maximum Hole Angle: 75.15° Close Approach Wells: All wells pass major risk criteria. Reference anti - collision report Nearest well within Pool: L- 215PB2 (2920') Distance to Nearest Property 4580' Line: Wells Within 1 /4 mi. in pool/ None L -223i Permit Application Page 1 • • Logging Program: Surface Interval Drilling, MWD: GR/Directional Open Hole: None Cased Hole: None Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density, PWD (Realtime and Recorded Mode) Open Hole: None Cased Hole: USIT (Primary Depth Control Mode) Mud Program: 12'/4" Surface Hole: Drillplex Spud Mud Funnel Plastic API Fluid Interval D e n sity Viscosity Viscosity Y lb / ) t Loss pH (secon /qt) (cp) (mis /30min) Initial to Base Perm 8.8 - 9.2 400 - 300 55 - 30 70 - 55 NC - 8.0 9.0 - 9.5 Base PFto top SVi 9.0 - 9.5 250 -225 55 -30 60 -45 8.0 9.0 -9.5 (surface hole TD) 8 3 /4" Production Hole: LSND Mud Densit Plastic Yi y eld Point API Interval nsi Viscosit (Ib /100ft2) Fluid Loss pH MBT (PP (cp) (m1/30 min) Surface eto TID. 88 -9.2 12 -18 18 -24 <6.0 9 -10 <18 Shoe to TD Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Connection Length Top Btm Tbg O.D. MD/TVD MD/TVD RTE 42" Insulated 20" 91.5 A -53 WLD 80' GL 807 80' 12 9 ' /8 " 40 L -80 BTC 6008' GL 6037' / 2887' 8 3 /d' 7" 26 L -80 TC -II 11,876' GL 11905' / 5039' Tubing 3 9.2 L -80 TC -II 11694' GL 11723' / 4894' Comments: 1 Tbq crossover to 4 1 /2" just below tree Integrity Testing: Test Point Depth Test Type 9 5 /8" Surface Casing 20' — 50' from surface shoe LOT Cement Calculations: Casin Size 1 Surface Casing - 9 -%" 40 ppf L -80 BTC - Single Stage Basis Lead: Open hole volume + 250% excess in permafrost, 40% excess below permafrost. TOC at surface. Tail: Open hole volume + 40% excess + 80' shoe track. TOC is 1000' ft above Surface Casing Shoe. Fluid Sequence and TAM port collar potentially run at 1,000' MD as a contingency for cement to surface. Volume: Wash None Spacer 50 bbls of MudPush 11 weighted to 10.0 ppq Lead 635 bbls (910 sks) 10.7 ppq Arctic Set Lite cement — 3.92 ft' /sk Tail 84 bbls (407 sks) 15.8 ppq Class G —1.16 cuft/sk Temp BHST = 40° F from SOR L -223i Permit Application Page 2 • 0 In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin, Size 1 Production Casing — 7" 26 ppf L -80 BTC -M with TC -II crossover - Single Stage Basis Lead: Open hole volume + 30% excess. TOC is 1000' MD below surface casing shoe. Tail: Open hole volume + 30% excess + 80' shoe track. TOC 500' MD above MA sandstone. Wash None Spacer 30 bbls of MudPush 11 weighted to 10.0 ppg Lead 108 bbls (186 sks) 11 ppg LiteCRETE — 3.27 ft' /sk Tail 63.7 bbls (305 sks) 15.8 ppq Class G —1.17 ft' /sk w /latex Temp BHST =185° F from SOR Formation Tops(TVDss) and Estimated Pore Pressures Commercial Est. Formation Hydrocarbon Est. Pore Tops Uncertainty Bearing Est. Pore Press. Press. (PPg Formation (TVDss) (feet) (Yes /No) (Psi) EMW) G1 -260 +/- 50' no 117 8.7 SV6 -890 +/- 50' no 401 8.7 +/ 100' M.D. - Fault #1 (L see fault section Pad Fault) -1165 for details EOCU -1345 +/- 50' no 605 8.7 SV5 -1485 +/- 50' no 668 8.7 Gas hydrates SV4 -1610 +/- 50' below BPRF 725 8.7 BPRF - 1690 +/ 50' no 761 8.7 SV3 -1980 +/- 50' Gas hydrates 891 8.7 SV2 -2165 +/- 50' Gas hydrates 974 8.7 SV1 -2500 +/- 50' Gas hydrates 1125 8.7 UG4 - 2790 +/ 50' 1256 8.7 Heavy Oil - 2820' - 2880' UG4A -2820 +/- 50' SS 1269 8.7 UG3 -3220 +/- 50' Thin coals 1449 8.7 Heavy Oil - 3925' -4025' UG1 - 3775 +/ 50' SS 1699 8.7 Not known, may be wet or UG_Ma -4125 +/- 50' oil 1856 8.7 UG Mb1 -4160 +/- 50' No - wet 1872 8.7 UG_Mb2 -4240 +/- 50' No - wet 1908 8.7 UG_Mc -4315 +/- 50' No - wet 1942 8.7 SB_Na -4365 +/- 50' No - wet 1964 8.7 Not known, may be wet or SB_Nb -4385 +/- 50' oil 1962 -2050 8.6 - 9.0 L -223i Permit Application Page 3 • 0 SB_Nc -4415 +/- 50' No - wet 1987 8.7 SB_Ne -4425 +/- 50' No - wet 1991 8.7 SB_OA -4510 +/- 50' No - wet 2085 -2135 8.9 - 9.1 SB_OBa -4575 +/- 50' No - wet 2060 -2142 8.7 - 8.9 SB_OBb -4625 +/- 50' No - wet 2130 -2160 8.9 - 9.0 Not known, may be wet or SB_OBc -4680 +/- 50' oil 2066 -2095 8.5 - 8.6 SB_OBd -4720 +/- 50' Oil, high Sw. 2033 -2115 8.3 - 8.6 SB_OBe -4785 +/- 50' Poss. Oil 2153 8.7 SB_OBf -4830 +/- 50' Poss. Oil 2174 8.7 Base_SB_OBf -4875 +/- 50' No 2194 8.7 TD -4962 No 2233 8.7 Well Control: The 12 1 / 4 " hole will be drilled with diverter. The 8 3 /4" intermediate hole will use well control equipment consisting of 5000 psi working pressure pipe rams(2), blind /shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 4000 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- • Maximum anticipated BHP: 2279 psi @ 5039' TVD, 8.7 ppg EMW (at base of OBe, - 11,905' MD) • Maximum surface pressure: 1775 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi /ft) • Planned BOP test pressure: • Annular Preventer 250 / 2500 psi • Rams 250 / 4000 psi • Planned completion fluid: 9.2 ppg brine / 6.8 ppg diesel Kick Tolerance / Integrity Testing Summary Table I Casing and Casing Test Maximum Mud Weight Exp Pore LOT / Interval Pressure Influx Press FIT Volume 9 Surface 3500 psi 50.3 BBLS 9.2 9.0 LOT Casing (assuming 11.8 LOT) 7" Production 4000 psi NA NA NA NA Casing L -223i Permit Application Page 4 • Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. • Fluid Handling: Haul all drilling and completion fluids and other Class 11 wastes to DS -04 for disposal. Haul all Class !wastes to Pad 3 for disposal. Variance Request: To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. � /oo• et L -223i - Drill and Complete Procedure Summary Pre -Ri g Work: 1. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 7ES. 2. Nipple up and function test diverter. 3. Pick up - 5700ft of 5" drill pipe. 4. MU 12 1 / 4 " drilling assembly with MWD /GR and directionally drill surface hole to below Permafrost. POOH and RIH with new 12 V /4 bit and drill to TD. The surface hole TD will be approximately 5 -10' below the UG4 marker. 5. Run and cement 9 5 /8 ' 40# L -80 surface casing. A TAM port collar may be run at 1000' as a contingency. Pressure test casing to 3500 psi for 30 minutes at plug bump. 6. ND diverter and NU casing / tubing head. NU BOPE and test to 4000 psi. 7. Lay down 5" drill pipe and pick up enough 4" drill pipe to drill to TD. 8. Make up 8 3 /4" drilling BHA with MWD /GR /RES /Azi- Den /NEU /PWD and RIH to float collar. Drill out shoe track and displace well to 9.0 ppg LSND drilling fluid. Drill 20' - 50' of new formation and perform LOT. 9. Drill ahead to production hole target TD (approx. 11905' MD, 250' below OBe). Circulate one BU, back -ream out of hole until the ghost reamer is inside the surface shoe, then POOH to run casing. 10. Change out to 7" rams and test to 4000 psi. 11. Run and cement the 7" 26# L -80 BTC -M x TCII production casing. Displace with 8.6 ppg seawater. Pressure test casing to 4000 psi for 30 minutes at plug bump. 12. Install 7" packoff then perform injection test in the outer annulus. Confirm 500 psi cement compressive strength prior to freeze protecting the outer annulus. Freeze protect the 7" x 9-%" annulus. 13. Change out rams to variable rams and test 4" and 3.5" to 4000 psi 14. PU DPC guns and RIH w/ -221' of 4.5" perf guns. 15. Space out pert guns by tagging PBTD and utilizing GR. Once correlated correctly, circulate over to 9.2 ppg brine. Confirm cement compressive strength is at least 1000 psi before firing. Perforate Nb, OA, OBa, OBc, OBd. POOH. LD DP and guns. 16. RU Tubing conveyed cleanout assembly (flat -bottom mill, string mill and two junk baskets) to clean out perforated zone for running completion. 17. Run E -Line with gauge ring junk basket with tractor for casing cleanout ,/18. Run USIT log on tractor following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 19. Run the 3 - ", 9.2# completion with a 7" x 3 -'/2" straddle packer assembly, I -wire, gauges, and injection mandrels. Torque turn TC -II threaded tubing. Confirm that packers are on depth using strapped tubing lengths. 20. Freeze protect the well to 2500' TVD by first shutting in the tubing and bullheading corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oil truck. L -223i Permit Application Page 5 • 21. Drop tubing Dart and pump to bottom with diesel. Run in lockdown screws and set the packers. Give AOGCC 24 hours notice, then test the production casing /tubing annulus and tubing to 4000 psi each. 22. Install and test TWC. Nipple down the BOPE. Nipple up and test double master valves to 5000 psi. 23. Install TWC in tubing hanger. Install a VR plug in the 7 "x 3 - annulus valve and secure the well. Ensure that IA/OA are protected with two barriers. 24. Nipple down BOP stack. 25. Install adapter flange and Double master Valves 26. RDMO. Post -Rig Work: 1. Install tree with electric SSV actuator. 2. Pull dummy valves from injection mandrels and replace with injection valves. 3. Pull VR plug. 4. Install wellhouse and flowlines. Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Maximum reservoir pressures anticipated: Interval Psi (EMW) TVDss (ft) MD (ft) Schrader Bluff 2279 (8.7ppg) 5039 11905 Sands II. Hydrates and Shallow gas: A. Free gas and /or gas hydrates may be present in the SV5 through the SV1 surface hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. Set surface casing below deepest SV1 sand hydrate zone to isolate gas bearing intervals behind cemented pipe in surface hole from intermediate hole section. III. Running Gravels: A. Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. Hazards include cobbles /boulders, running gravels, wood, lost circulation and tight hole problems while drilling and running casing. See Pad data sheet for details. IV. Lost Circulation: A. Very few loss circulation incidents on L -pad, L -214i saw 400bph losses while drilling surface hole. Reference standard operating procedures, including running LCM and increasing mud viscosity. V. Kick Tolerance / Integrity Testing: A. The 9 5 /8" casing will be cemented to surface. A TAM port collar run at 1000' MD in the surface casing is contingency to get cement to surface. A LOT will be performed after drilling 20 -50' of new formation after drilling out the 9 5 /8" casing shoe. B. The 7" casing will be cemented to 1000' MD below the 9 5 /8" casing shoe. L -223i Permit Application Page 6 • • Kick Tolerance / Integrity Testing Summary Table ` I Casing and Casing Test Maximum Mud Weight Exp Pore LOT Interval Pressure Influx Press ` FIT Volume 9 Surface 3500 psi 50.3 BBLS 9.2 9.0 LOT Casing (assuming 11.8 LOT) 7" Production 4000 psi NA NA NA NA Casing VI. Heavy Oil A. Heavy oil is expected in the UG4A and UG1 sand intervals which could result in plugging of shaker screens. Follow established operating practices for drilling in heavy oil zones; depths of heavy oil intervals are outlines in the Marker Tops section. VII. Hydrogen Sulfide A. All L Pad gas lift wells are expected to have H levels in the 10 to 250 ppm range; result of PBU gas lift gas. While no H is anticipated on this site, standard H precautions should be followed at all times. HIS Summary Table Well Name H,S Level fapm o °° Date. of Rea lin #1 Closest SHL Well H2S Level L -118 40 ppm 11/26/2008 #2 Closest SHL Well H2S Level L -250 20 ppm 12/4/2007 #1 Closest BHL Well H2S Level L -250L1 20 ppm 12/4/2007 #2 Closest BHL Well H2S Level L -202 20 ppm 9/7/2007 Max. Recorded H2S on Pad /Facility L -120 250 ppm 10/20/2006 VIII. Faults A. Penetration of the L pad fault will occur during between drilling of the SV6 and the SV5 intervals. Fault depth is approx. 1165' ( +/. 100') TVDSS. Fault throw: west direction, approx. 40' — 60'. Fault has not previously been associated with fluid losses. Follow LCM tree if losses occur. B. No faults are predicted in the injection interval. CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION L -223i Permit Application Page 7 TREE = 41/8 "CW Minimum ID = 2.75" @ 11702' ACTUATOR= Ele � c L, -22li PROPOSED • 3-1/2" HES XN NIPPLE KB. ELEV = 81.8' BF. ELEV = ) 1 29' I--I41 /2" X0 3-1 /2", ID= 2.992" 1 KOP = 250' Max Angle = 75 deg ) l Datum MD = 11723 3-1/2" 9.2ppf L -80 TC-II ID = Datum TVD = 112.992" 4-1/2" TBG, 12.6#, L -80, --1 1 4756' H3 - 1/2" HES X MP, ID = 2.813' 1 TC-11, .0152 bpf, ID = 3.958" 19 -5/8" CSG, 40#, L -80, TC-11, ID = 8.835" 11 6037' / IX /0 7" TC -II to 7" BTC -M H 7186' I I 1097T — 7" HES AHR PKR w / DUAL 1/4" FEED THRU, ID= 2.965" NOTE DO NOT EXCEED 4300 PSI 7" Csg. MARKER JOM w/ I RA TAG 11,050' 1 11017' H MULTI DROP SGM FOR NDPG GAUGE I ' WI GAS LIFT MANDRELS ST MD I TVD DEV I TYPE VLV LATCH PORTI DATE 71 111205' I 1 7" HES AHR PKR w / 1/4" FEED THRU, ID = 2.965" 10 xxxx f MMG DCR RK I NI WATER INJECTION MANDRELS 11218' H MULTI DROP SGM FOR NDPG GAUGE I ST MD TVD DEV TYPE VLV LATCH PORT DATE I 8 xxxx MMG -W DMY RK 7 xxxx MMG -W DMY RK Er 6 xxxx MMG -W DMY RK 1 11324' I 17" HES A HR PKR w / 1/4" FEED THRU, ID = 2.965" I 5 xxxx MMG -W DMY RK ��j ,2I 4 xxxx MMG -W DMY RK 3 xxxx MMG -W DMY RK 2 xxxx MMG - DMY RK 11333' H MULTI DROP SGM FOR NDPG GAUGE I 1 xxxx MMG -W DMY RK ' W ® 1 11436' 1 17" HES A HR PKR w / 1/4" FEED THRU, ID = 2.965" I IL PERFORATION SUMMARY I 11449' I MULTI DROP SGM FOR NDPG GAUGE REF LOG: SLB Realtime LWD ANGLE AT TOP PERF: 1111 W Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE K 1 11541' 7" HES AHR PKR w/ 1/4" FEED THRU, ID = 2.965" II I 4 -1/2" 5 Nb 30' 0 4 - 1/2" 5 OBa 55' 0 11555' I MULTI DROP SGM FOR NDPG GAUGE I 4 - 1/2" 5 OBb 30' 0 4 -1/2" 5 OBd 85' 0 4 -1/2" 5 OBe 45' 0 1 11681' H3 -1/2 HES X NIP, ID = 2.813" I PBTD = 11825' � I 11702' H3- 1/2 " HES XN MP, ID =2.75" 1 17" CSG, 268, L -80, BTC -M, .0383 bpf, ID = 6.276 H 11905' TD I : .....•.... '§. ��4).4 I 11723' I - 13 -1/2" WLEG, ID = 2.992" I DATE I REV BY I COMMENTS DATE REV BY COMMENTS ORION UNff 12/09/081 RRC 1 Proposed WBD WELL: L -2231 PERMIT No: API No: Sec 34, T12N, R11E BP Exploration (Alaska) bp 0 L -223 (P3b) Proposal $cblumberger Report Date: April 21, 2009 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 30.050° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure / Slot: L -PAD / L -223 M Study TVD Reference Elevation: 77.50 ft relative to MSL Borehole: TVD Reference Datum: Rotary Table Well: Plan L -223 : Plan L -223 ea5;p Sea Bed Ground Level Elevation: 49.00 ft relative to MSL UWI/API #: 50029 Magnetic Declination: 22.309° Survey Name / Date: L -223 (P3b) / April 21, 2009 Total Field Strength: 57700.324 nT Tort / AHD / DDI 1 ERD ratio: 121.738° / 9933.70 ft / 6.456 / 1.971 Magnetic Dip: 80.883° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: August 15, 2009 Location Lat/Long: N 70.35061981, W 149.32485412 Magnetic Declination Model: BGGM 2008 • Location Grid N/E YIX: N 5978276.000 ftUS, E 583156.000 ftUS North Reference: True North Grid Convergence Angle: +0.63583412° Total Corr Mag North -> True North: +22.309° Grid Scale Factor: 0.99990786 Local Coordinates Referenced To: Well Head Measured Azimuth Vertical NS I EW Mag 1 Gray Directional Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft ) (deg) I (deg) I (ft) (ft) (ft) (ft) (ft) (deg) (deg /100ft) Index (ftUS) (ftUS) I RTE 0.00 0.00 15.00 -77.50 0.00 0.00 0.00 0.00 - -- 0.00 0.00 5978276.00 583156.00 N 70.35061981 W 149.32485412 KOP Bld 1.5/100 250.00 0.00 15.00 172.50 250.00 0.00 0.00 0.00 15.00M 0.00 0.00 5978276.00 583156.00 N 70.35061981 W 149.32485412 300.00 0.75 15.00 222.50 300.00 0.32 0.32 0.08 15.00M 1.50 0.00 5978276.32 583156.08 N 70.35062067 W 149.32485343 G1 337.51 1.31 15.00 260.00 337.50 0.97 0.97 0.26 15.00M 1.50 0.12 5978276.97 583156.25 N 70.35062245 W 149.32485201 Bld 3/100 350.00 1.50 15.00 272.49 349.99 1.26 1.26 0.34 15.00M 1.50 0.29 5978277.27 583156.32 N 70.35062326 W 149.32485137 400.00 3.00 15.00 322.45 399.95 3.16 3.16 0.85 15.00M 3.00 0.99 5978279.17 583156.81 N 70.35062844 W 149.32484724 500.00 6.00 15.00 422.13 499.63 10.74 10.74 2.88 HS 3.00 1.82 5978286.77 583158.76 N 70.35064914 W 149.32483076 600.00 9.00 15.00 521.26 598.76 23.34 23.34 6.26 HS 3.00 2.34 5978299.41 583162.00 N 70.35068358 W 149.32480334 700.00 12.00 15.00 619.58 697.08 40.94 40.95 10.97 HS 3.00 2.71 5978317.06 583166.52 N 70.35073166 W 149.32476505 800.00 15.00 15.00 716.80 794.30 63.48 63.49 17.01 HS 3.00 3.00 5978339.67 583172.31 N 70.35079326 W 149.32471601 900.00 18.00 15.00 812.67 890.17 90.90 90.92 24.36 HS 3.00 3.23 5978367.18 583179.35 N 70.35086820 W 149. 634 SV6 981.90 20.46 15.00 890.00 967.50 116.95 116.97 31.34 HS 3.00 3.40 5978393.30 583186.04 N 70.35093937 W 149. 967 1000.00 21.00 15.00 906.93 984.43 123.13 123.16 33.00 HS 3.00 3.43 5978399.51 583187.63 N 70.35095627 W 149.32458621 Cry 3.5/100 1046.36 22.39 15.00 950.00 1027.50 139.68 139.71 37.44 HS 3.00 3.52 5978416.11 583191.88 N 70.35100149 W 149.32455020 1100.00 24.27 15.00 999.25 1076.75 160.20 160.23 42.93 HS 3.50 3.61 5978436.68 583197.15 N 70.35105755 W 149.32450557 1200.00 27.77 15.00 1089.11 1166.61 202.55 202.60 54.29 HS 3.50 3.78 5978479.17 583208.03 N 70.35117328 W 149.32441341 1300.00 31.27 15.00 1176.11 1253.61 250.12 250.18 67.04 HS 3.50 3.92 5978526.89 583220.25 N 70.35130328 W 149.32430990 1400.00 34.77 15.00 1259.95 1337.45 302.74 302.81 81.14 HS 3.50 4.06 5978579.66 583233.76 N 70.35144705 W 149.32419542 1500.00 38.27 15.00 1340.30 1417.80 360.19 360.28 96.54 HS 3.50 4.18 5978637.29 583248.52 N 70.35160405 W 149.32407039 1600.00 41.77 15.00 1416.87 1494.37 422.28 422.38 113.18 HS 3.50 4.29 5978699.57 583264.47 N 70.35177371 W 149.32393529 SV5 1686.73 44.80 15.00 1480.00 1557.50 479.70 479.81 128.57 HS 3.50 4.38 5978757.16 583279.22 N 70.35193060 W 149.32381035 1700.00 45.27 15.00 1489.38 1566.88 488.77 488.88 131.00 HS 3.50 4.40 5978766.26 583281.55 N 70.35195538 W 149.32379062 WellDesign Ver SP 2.1 Bld( users) L- 223 \Plan L- 223 \Plan L- 223 \L -223 (P3b) Generated 4/21/2009 2:12 PM Page 1 of 3 Measured Azimuth Vertical NS EW Mag 1 Gray Directional Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ( ft) ( de de ) (ft) (ft) (ft ) (ft ) (ft ) (deg) (deg/100ft) Index (ftUS) (NUS) 1800.00 48.77 15.00 1557.55 1635.05 559.40 559.54 149.93 HS 3.50 4.49 5978837.11 583299.70 N 70.35214840 W 149.32363691 SV4 1881.96 51.64 15.00 1610.00 1687.50 620.21 620.35 166.22 HS 3.50 4.57 5978898.10 583315.31 N 70.35231455 W 149.32350460 1900.00 52.27 15.00 1621.12 1698.62 633.93 634.08 169.90 HS 3.50 4.58 5978911.86 583318.84 N 70.35235204 W 149.32347474 2000.00 55.77 15.00 1679.86 1757.36 712.06 712.23 190.84 HS 3.50 4.67 5978990.23 583338.91 N 70.35256554 W 149.32330471 Base Perm 2018.17 56.40 15.00 1690.00 1767.50 726.62 726.79 194.74 HS 3.50 4.69 5979004.84 583342.65 N 70.35260533 W 149.32327303 2100.00 59.27 15.00 1733.56 1811.06 793.51 793.70 212.67 HS 3.50 4.75 5979071.93 583359.83 N 70.35278810 W 149.32312746 2200.00 62.77 15.00 1782.00 1859.50 877.97 878.18 235.31 HS 3.50 4.83 5979156.65 583381.53 N 70.35301890 W 149.32294365 2300.00 66.27 15.00 1825.02 1902.52 965.14 965.36 258.67 HS 3.50 4.90 5979244.08 583403.92 N 70.35325708 W 149.32275396 2400.00 69.77 15.00 1862.44 1939.94 1054.67 1054.92 282.66 HS 3.50 4.97 5979333.89 583426.92 N 70.35350173 W 149.32255911 Cry 4/100 2485.83 72.77 15.00 1890.00 1967.50 1133.16 1133.42 303.70 84.84R 3.50 5.03 5979412.62 583447.08 N 70.35371619 W 149.32238829 2500.00 72.82 15.59 1894.19 1971.69 1146.25 1146.48 307.27 84.66R 4.00 5.04 5979425.71 583450.50 N 70.35375187 W 149929 2600.00 73.24 19.75 1923.39 2000.89 1239.65 1237.59 336.30 83.45R 4.00 5.11 5979517.13 583478.52 N 70.35400077 W 149. 356 2700.00 73.74 23.89 1951.82 2029.32 1334.51 1326.57 371.93 82.27R 4.00 5.17 5979606.49 583513.16 N 70.35424386 W 149.32183421 SV3 2783.94 74.22 27.35 1975.00 2052.50 1414.94 1399.31 406.81 81.31R 4.00 5.22 5979679.60 583547.22 N 70.35444255 W 149.32155096 2800.00 74.31 28.01 1979.35 2056.85 1430.38 1413.00 413.99 81.14R 4.00 5.23 5979693.37 583554.25 N 70.35447995 W 149.32149266 2900.00 74.97 32.10 2005.85 2083.35 1526.79 1496.44 462.28 80.05R 4.00 5.29 5979777.33 583601.60 N 70.35470789 W 149.32110056 End Cry 2925.90 75.15 33.16 2012.53 2090.03 1551.78 1517.51 475.77 - -- 4.00 5.31 5979798.55 583614.86 N 70.35476546 W 149.32099101 SV2 3442.74 75.15 33.16 2145.00 2222.50 2050.63 1935.75 749.00 - -- 0.00 5.47 5980219.76 583883.40 N 70.35590800 W 149.31877213 SV1 4749.78 75.15 33.16 2480.00 2557.50 3312.15 2993.44 1439.96 - -- 0.00 5.75 5981284.95 584562.52 N 70.35879722 W 149.31315978 UG4 5998.30 75.15 33.16 2800.00 2877.50 4517.19 4003.77 2099.98 - -- 0.00 5.93 5982302.45 585211.23 N 70.36155691 W 149.30779725 9 -5/8" Csg 6037.31 75.15 33.16 2810.00 2887.50 4554.85 4035.34 2120.60 - -- 0.00 5.94 5982334.24 585231.50 N 70.36164315 W 149.30762965 UG4A 6134.85 75.15 33.16 2835.00 2912.50 4648.99 4114.27 2172.17 - -- 0.00 5.95 5982413.73 585282.18 N 70.36185875 W 149.30721064 UG3 7422.39 75.15 33.16 3165.00 3242.50 5891.69 5156.17 2852.82 - -- 0.00 6.09 5983463.03 585951.16 N 70.36470449 W 149.30167885 UG1 9314.67 75.15 33.16 3650.00 3727.50 7718.07 6687.45 3853.16 - -- 0.00 6.24 5985005.16 586934.36 N 70.36888656 W 149.29354600 Cry 4/100 10033.45 75.15 33.16 3834.23 3911.73 8411.82 7269.10 4233.14 170.63L 0.00 6.29 5985590.94 587307.82 N 70.37047502 W 149.29045588 10100.00 72.52 32.70 3852.75 3930.25 8475.66 7322.75 4267.89 170.50L 4.00 6.31 5985644.97 587341.97 N 70.37062153 W 149.29017328 10200.00 68.58 31.99 3886.04 3963.54 8569.86 7402.39 4318.33 170.27L 4.00 6.33 5985725.16 587391.52 N 70.37083902 W 149.28976297 10300.00 64.64 31.25 3925.74 4003.24 8661.59 7480.53 4366.45 169.97L 4.00 6.36 5985803.82 587438.76 N 70.37105240 W 149.28937161 10400.00 60.70 30.45 3971.64 4049.14 8750.40 7556.78 4412.00 169.60L 4.00 6.38 5985880.56 587483.46 N 70.37126064 W 149. 110 10500.00 56.77 29.58 4023.53 4101.03 8835.86 7630.77 4454.76 169.16L 4.00 6.39 5985955.01 587525.40 N 70.37146271 W 149.2 5324 10600.00 52.85 28.64 4081.15 4158.65 8917.55 7702.15 4494.53 168.61L 4.00 6.41 5986026.82 587564.36 N 70.37165763 W 149.28832974 Drp 0.5/100 10662.57 50.39 28.00 4120.00 4197.50 8966.58 7745.32 4517.80 HS 4.00 6.42 5986070.24 587587.15 N 70.37177554 W 149.28814040 1 Ma 10662.59 50.39 28.00 4120.01 4197.51 8966.59 7745.33 4517.81 LS 0.50 6.42 5986070.26 587587.16 N 70.37177557 W 149.28814036 10700.00 50.21 28.00 4143.91 4221.41 8995.35 7770.75 4531.32 LS 0.50 6.42 5986095.82 587600.39 N 70.37184497 W 149.28803042 Mb1 10717.32 50.12 28.00 4155.00 4232.50 9008.64 7782.49 4537.56 LS 0.50 6.42 5986107.62 587606.50 N 70.37187704 W 149.28797963 10800.00 49.71 28.00 4208.24 4285.74 9071.86 7838.34 4567.26 LS 0.50 6.43 5986163.80 587635.57 N 70.37202957 W 149.28773801 Mb2 10818.16 49.62 28.00 4220.00 4297.50 9085.69 7850.56 4573.76 LS 0.50 6.43 5986176.09 587641.93 N 70.37206295 W 149.28768514 10900.00 49.21 28.00 4273.25 4350.75 9147.80 7905.43 4602.94 LS 0.50 6.43 5986231.28 587670.50 N 70.37221281 W 149.28744775 Mc 10948.48 48.96 28.00 4305.00 4382.50 9184.41 7937.78 4620.14 LS 0.50 6.43 5986263.81 587687.34 N 70.37230115 W 149.28730780 11000.00 48.71 28.00 4338.91 4416.41 9223.17 7972.02 4638.34 LS 0.50 6.43 5986298.25 587705.16 N 70.37239467 W 149.28715966 WellDesign Ver SP 2.1 Bld( users) L- 223 \Plan L- 223 \Plan L- 223 \L -223 (P3b) Generated 4/21/2009 2:12 PM Page 2 of 3 Measured Azimuth Vertical NS EW Mag I Gray Directional Comments Inclination Sub -Sea TVD TVD DLS Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty (ft) (deg) (deg) (ft) I (ft) I (ft) I (ft) (ft ) (deg) (deg/100ft) Index (ftUS) (ftUS) I Na 11031.91 48.55 28.00 4360.00 4437.50 9247.10 7993.16 4649.59 LS 0.50 6.43 5986319.51 587716.17 N 70.37245240 W 149.28706820 Nb 11069.60 48.36 28.00 4385.00 4462.50 9275.29 8018.07 4662.83 LS 0.50 6.43 5986344.56 587729.13 N 70.37252042 W 149.28696043 11100.00 48.21 28.00 4405.23 4482.73 9297.97 8038.11 4673.48 LS 0.50 6.44 5986364.71 587739.56 N 70.37257514 W 149.28687375 11200.00 47.71 28.00 4472.20 4549.70 9372.18 8103.68 4708.35 LS 0.50 6.44 5986430.66 587773.70 N 70.37275421 W 149.28659006 OA 11248.63 47.46 28.00 4505.00 4582.50 9408.06 8135.37 4725.21 LS 0.50 6.44 5986462.54 587790.20 N 70.37284077 W 149.28645291 11300.00 47.21 28.00 4539.82 4617.32 9445.81 8168.73 4742.94 LS 0.50 6.44 5986496.08 587807.56 N 70.37293186 W 149.28630860 OBa 11337.01 47.02 28.00 4565.00 4642.50 9472.91 8192.66 4755.67 LS 0.50 6.44 5986520.16 587820.03 N 70.37299723 W 149.28620502 11400.00 46.71 28.00 4608.07 4685.57 9518.85 8233.25 4777.26 LS 0.50 6.44 5986560.98 587841.16 N 70.37310807 W 149.28602940 OBb 11410.10 46.66 28.00 4615.00 4692.50 9526.19 8239.74 4780.71 LS 0.50 6.44 5986567.50 587844.53 N 70.37312579 W 149.28600133 OBc 11482.70 46.29 28.00 4665.00 4742.50 9578.80 8286.22 4805.42 LS 0.50 6.45 5986614.25 587868.73 N 70.37325272 W 149.28580021 11500.00 46.21 28.00 4676.96 4754.46 9591.29 8297.25 4811.29 LS 0.50 6.45 5986625.34 587874.47 N 70.37328285 W 149..47 11520.38 46.10 28.00 4691.08 4768.58 9605.98 8310.23 4818.19 - -- 0.50 6.45 5986638.40 587881.23 N 70.37331829 W 149. 31 11523.22 46.10 28.00 4693.05 4770.55 9608.02 8312.03 4819.15 179.05L 0.00 6.45 5986640.21 587882.17 N 70.37332323 W 149.28568849 L -223 Tgt OBd 11562.02 45.91 28.00 4720.00 4797.50 9635.92 8336.68 4832.26 LS 0.50 6.45 5986665.00 587895.00 N 70.37339053 W 149.28558185 OBd 11562.04 45.91 28.00 4720.01 4797.51 9635.93 8336.69 4832.26 LS 0.50 6.45 5986665.01 587895.01 N 70.37339056 W 149.28558181 11600.00 45.72 28.00 4746.47 4823.97 9663.13 8360.73 4845.05 LS 0.50 6.45 5986689.19 587907.52 N 70.37345620 W 149.28547781 11655.05 45.44 28.00 4785.00 4862.50 9702.43 8395.44 4863.51 LS 0.50 6.45 5986724.10 587925.59 N 70.37355102 W 149.28532760 OBe 11655.07 45.44 28.00 4785.01 4862.51 9702.44 8395.45 4863.51 LS 0.50 6.45 5986724.11 587925.60 N 70.37355104 W 149.28532756 11700.00 45.22 28.00 4816.60 4894.10 9734.38 8423.67 4878.51 LS 0.50 6.45 5986752.49 587940.28 N 70.37362810 W 149.28520548 11800.00 44.72 28.00 4887.35 4964.85 9805.00 8486.07 4911.69 LS 0.50 6.45 5986815.25 587972.77 N 70.37379851 W 149.28493550 11900.00 44.22 28.00 4958.71 5036.21 9875.01 8547.92 4944.58 LS 0.50 6.46 5986877.46 588004.96 N 70.37396743 W 149.28466787 11904.59 44.20 28.00 4962.00 5039.50 9878.21 8550.75 4946.08 LS 0.50 6.46 5986880.30 588006.43 N 70.37397516 W 149.28465563 TD / 7" Lnr 11905.05 44.19 28.00 4962.33 5039.83 9878.53 8551.03 4946.23 - -- 0.50 6.46 5986880.59 588006.58 N 70.37397593 W 149.28465442 Legal Description: Northing (Y) fftUS] Easting (X) fftUS1 Surface : 2554 FSL 3758 FEL S34 T12N R11E UM 5978276.00 583156.00 L -223 Tgt OBd : 329 FSL 4190 FEL S23 T12N R11E UM 5986665.00 587895.00 BHL : 544 FSL 4076 FEL S23 T12N R11E UM 5986880.59 588006.58 • WellDesign Ver SP 2.1 Bld( users) L- 223 \Plan L- 223 \Plan L- 223 \L -223 (P3b) Generated 4/21/2009 2:12 PM Page 3 of 3 bp Schlumberger WELL I FIELD I STRUCTURE L-PAD L-223 (P3b) Prudhoe Bay Unit - WOA Magnetic Parameters Surface Location 09021 Alaska Stale Planes. Zone 04. US Feet " Model: BGGM 2008 D 0 ip 8883 Dale: August 15. 2009 Lan, N70 21 2.231 North mg: S91821800 SUS Grid Con, ..63583412 s,07 TVD Ref. Rotary Table (77 500 above MSL) Mag Dec: 322 309° FS: 57700.3 nT Lon, W149 19 29.475 Easling. 583158.00 SUS Scale Fact: 09999078552 Plan, 0 (.3b) Srvy Date. Apnl 21, 2009 0 1200 2400 3600 4800 6000 7200 8400 9600 RTE 0 0 KOP Bld 1.5/100 Bld 31100 -••-••- Cry 3.5/100 1200 1200 (NJ 2400 2400 a) To 0 3600 Cry 4/100 Drp 0.5/1033 ensszs ....ssistesseattsessissusiusimisminsnasszmimpcsstansumszttsuansstirismensmost.nunzu•stimaissits::suanwissts:mmuslms::::=Issuzissysms:tausuzustssusunstisisznmeste 3 Ativrts I* L-223 (P3b) 0 1200 2400 3600 4800 6000 7200 8400 9600 Vertical Section (ft) Azim = 30.05°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E/-V by • • Schlumberger WELL I FIELD STRUCTURE L -223 (P3b) Prudhoe Bay Unit - WOA I L -PAD Magnetic Parameters I SuRace LoraSOn NAD27 Alaska Stale Planes. Zone 04. US Feet I Miscellaneous Mo0el: BGGM 2008 Dip' 80.883° Date'. August 15. 2009 Lat N70212.231 Northing 5978278.o0RUS Gn9 COnv: •0.83583012° Slot'. L -223 TVD Ref: Rotary Table (77.5011 above MSL) Mag Dec'. 422.309° FS' 57700.3nT Lon: W149 19 29 Eas9rg: 583156 00 MIS Scale Fact: 09999078552 Plan: L- 223(P3b) Sow Date: April 21.2009 0 1200 2400 3600 4800 TD /7" Lnr 8400 4 L -223 Tgt OBd `= 3 (P3b) 8400 ; Drp 0.5/100 II Cry 4/100 7200 N 7200 6000 6000 A A A Z 0 4800 4800 0 I I U 3600 3600 • v v v 2400 2400 Ehd Cry 1200 Cry al go .... 1200 Cry 3.5/100 0 0 Bld 3/100 RTE KOP Bld 1.5/100 0 1200 2400 3600 4800 «< W Scale = 1(in):1200(ft) E »> • BPEJ Alaska Antillieion Report Company: North America - ALASKA - BP Local Co Reference: Well Plan L-223 Project: Prudhoe Bay TVD Reference: L-223 Plan (4/ 77.50ft (Nabors 9ES) Reference Site: PB L Pad MD Reference: L-223 Plan (4) 77.50ft (Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well Plan L Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore Plan L Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #3 L Offset TVD Reference: Offset Datum Reference Plan #3 L-223 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refers Interpolation Meth Md: I/Interval 5I Error Model: 1SCWSA Depth Range: Unlimited Scan Method: Tray. Cylinder North Results-Limited-by: Maximum-center-center-distance of 1,38-T66ft Error-Surface Elliptical Conic Survey Tool Program Date 4/21/2009 From To (ft) (ft) Survey (Wellbore) Tool Name Description 28.50 900.00 Plan #3 L-223 (Plan L-223) GYD-GC-SS Gyrodata gyro single shots 900.00 2,300.00 Plan #3 L-223 (Plan L-223) MWD MWD - Standard 900.00 6,037.00 Plan #3 L-223 (Plan L-223) MWD+IFR+MS MWD + IFR + Multi Station 6,037.00 11,905.05 Plan #3 L-223 (Plan L-223) MVVD+IFR+MS MWD + 1FR + Multi Station 472172009 219:4 Page 2 of 5 COMPASS 2003.16 Build 70 BP Exploration ATaska ticollision Report Company: North America - ALASKA - BP Local Co- ordinate Reference: Well Plan L-223 Project: Prudhoe Bay TVD Reference: L -223 Plan @ 77.50ft (Nabors 9ES) Reference Site: PB L Pad MD Reference: L -223 Plan @ 77.50ft (Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Well: Plan L -223 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore! Plan L -223 Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #3 L -223 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No 43o Allowable Measured Measured Centre Distance Deviation warning Site Name Depth Depth Distance (ft) from Plan Offset Welt - Wellbore - Design (ft) (ft) (ft) (ft) PB L Pad L -01 = L01 = L01 284.61 285:00 __ _ .189.36 4.88 184:68 Pass = Major L -02 - L -02 - L -02 363.36 370.00 104.49 6.79 97/1 Pass - Major Risk L -02 - L -02A - L -02A 364.13 365.00 104.50 6.80 97.71 Pass - Major Risk L-02 - L -02APB1 - L- 02APB1 364.13 365.00 104.50 6.80 97.71 Pass - Major Risk L -02 - L -02PB1 - L -02PB1 363.36 370.00 104.49 6.79 97.71 Pass - Major Risk L -03 - L -03 - L -03 610.61 630.00 190.32 11.59 178.77 Pass - Major Risk L-04 - L -04 - L -04 298.98 300.00 181.28 5.57 175.71 Pass - Major Risk L -101 - L -101 - L- 101 444.01 450.00 164.80 7.96 156.84 Pass - Major Risk L -103 - L -103 - L -103 792.17 785.00 135.81 13.17 122.69 Pass - Major Risk L -105 - L -105 - L -105 322.04 325.00 234.19 5.87 228.32 Pass - Major Risk i -, -� na - i - 1.06 - - -L- -106 -- 723.4 74� 00 232.49 - -- -_ 12-51 220.05 Pass= -Major Risk - L -107 - L -107 - L -107 230.17 230.00 194.61 5.12 189.48 Pass - Major Risk L -108 - L -108 - L -108 600.00 615.00 217.88 11.06 206.85 Pass - Major Risk L-109 - L -1U9 = 61 - - - 289.41 29000 _ __ 180.53 6.07 174.46 Pass Major Risk L-110-L-110-L-110 264.68 265.00 191.07 4.95 186.12 Pass - Major Risk 1 -117 -I -117 -1,112 300.00_ _ 305.00 _ _ __ 12157 6 36 11520 -_ - Pass - MajorRisk_ L -114 - L -114 - L -114 326.73 330.00 224.45 5.43 219.03 Pass - Major Risk L -114 - L -114A - L -114A 326.73 330.00 224.45 5.42 219.03 Pass - Major Risk L -115 - L -115 - L -115 384.33 385.00 44.44 6.59 37.89 Pass - Major Risk L -116 - L -116 - L -116 332.55 335.00 184.91 5.46 179.45 Pass - Major Risk L-117-L-117 L-117-L-117-L-117 345.02 345.00 30.73 5.56 25.17 Pass - Major Risk I L -117 - Plan 2, L -117A - Plan 2 345.02 345.00 30.73 5.56 25.17 Pass - Major Risk L -118 -L-118-L-118 510.13 510.00 11.58 9.62 1.96 Pass - Major Risk L-149-- L -119 - L -1-19 901.55 88'5.00- 1- 80.36 1560- 164.98 Pass -Major Ris L -120 - L -120 - L -120 728.73 710.00 227.61 12.85 214.80 Pass - Major Risk L -121 - L -121 - L -121 216.09 215.00 203.80 3.89 199.91 Pass - Major Risk L -121 - L -121A - L -121A 216.09 215.00 203.80 3.89 199.91 Pass - Major Risk L -122 - L -122 - L -122 324.76 325.00 75.88 5.66 70.22 Pass - Major Risk L -123 - L -123 - L -123 300.86 300.00 90.79 5.59 85.21 Pass - Major Risk L -123 - L- 123PB1 - L- 123PB1 300.86 300.00 90.79 5.59 85.21 Pass - Major Risk L -123 - Plan L -123L1 - Plan #1 300.86 300.00 90.79 5.59 85.21 Pass - Major Risk L-12 [4 43T25 435.00 134.11 7.49 126.62 Pass - Major RIsk L -124 - L- 124PB1 - L- 124PB1 431.25 435.00 134.11 7.49 126.62 Pass - Major Risk L -174 - L- 124PB7 - L- 124PB2 - -- - - - ___43125__. _ __ 435.00_ 134 11 7 49 ___ __ -_126 67 Pass-Major Ri.sk L -200 - L -200 - L -200 1,528.73 1,505.00 44.67 37.68 9.88 Pass - Major Risk L -200 - L -200L1 - L -200L1 1,528.73 1,505.00 44.67 37.68 9.88 Pass - Major Risk L- 200 - L- 200L2- L -200L2 1,52813 '505.0( - - - 4 3 9.88 Pass-MajorRisk L -201 - L -201 - L -201 1,879.50 1,825.00 177.27 53.17 124.38 Pass - Major Risk L -201. L- 201L1- L -201L1 1,879.50 1,825.00 177.27 53.17 124.37 Pass - MajorRisk__ L- 201 - L -201 L1 PB1 - L -201 L1 PB1 1,879.50 1,825.00 177.27 53.12 124.42 Pass - Major Risk L -201 - L -201 L2 - L -201 L2 1,879.50 1,825.00 177.27 53.12 124.42 Pass - Major Risk L -201 - L -201 L3 - L -201 L3 1,879.50 1,825.00 177.27 53.17 124.37 Pass - Major Risk L -201 - L -201 L3PB1 - L -201 L3PB1 1,879.50 1,825.00 177.27 53.12 124.42 Pass - Major Risk L -201 - L- 201PB1 - L- 201PB1 1,879.50 1,825.00 177.27 53.12 124.42 Pass - Major Risk L -201 - L- 201PB2 - L- 201PB2 1,879.50 1,825.00 177.27 53.12 124.42 Pass - Major Risk L -202 - L -202 - L -202 702.05 700.00 61.68 11.96 49.77 Pass - Major Risk l - 2-0-2-- L- 202L1-- L- 202L-1 -- -70 05- - 700.00 61.68 - -1-L96 49.77 Pass -MajorRisk-- - - -- L -202 - L -202L2 - L -202L2 702.05 700.00 61.68 11.96 49.77 Pass - Major Risk L -202 - L -202L3 - L -202L3 702.05 700.00 61.68 11.96 49.77 Pass - Major Risk 55 - --2051=205 355.71 360.00 195.66 5.55 18.5.82Pass - Major k L -205 - L -205L1 - L -205L1 355.71 360.00 195.66 5.85 189.82 Pass - Major Risk - _- i -705 - L.-2019 - L-2051 9 355_71_ - -- _360_09 - 195 66_ -__ -.. __ 5,R _- 1R9 89 Pacs -_ Major R'sk - _ ._. L-205 - L -205L3 - L -205L3 355.71 360.00 195.66 5.85 189.82 Pass - Major Risk 4/21/2003 2J 1PM Page 3 of 5 COMPASS 200316 Build 70 • BP Exploration Alaska Anticojlision Repo Company: North America - ALASKA BP Local Co- ordinate Reference: Well Plan L -223 Project: Prudhoe Bay TVD Reference: L -223 Plan @ 77.50ft (Nabors 9ES) Reference Site: PB L Pad MD Reference: L -223 Plan @ 77.50ft (Nabors 9ES) Site Error: 0.00ft North Reference: True Reference Welk Plan L -223 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Refer Wellbore ! Plan L -223 Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #3 L -223 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation warning Site Name Depth Depth Distance (ft) from Plan Offset Well -- Welibore • Design (ft) (ft) (ft) (ft) PB L Pad L-205-- =205L4 - L -205L4 355.71 360.00 195.68 - -5 85 189.82 - Pass Major - L -205 - L -205L5 - L -205L5 355.71 360.00 195.66 5.85 189.82 Pass - Major Risk L -205 - L- 205PB1 - L- 205PB1 355.71 360.00 195.66 5.85 189.82 Pass - Major Risk L -210 - L -210 - L -210 233.20 235.00 205.05 4.00 201.05 Pass - Major Risk L -210 - L- 210PB1 - L- 210PB1 233.20 235.00 205.05 4.00 201.05 Pass - Major Risk L -211 - L -211 - L- 211 448.20 450.00 54.37 9.63 44.74 Pass - Major Risk L -211 - L- 211PB1 - L- 211PB1 448.20 450.00 54.37 9.63 44.74 Pass - Major Risk L -212 - L -212 - L -212 1,579.55 1,595.00 46.47 3 14.83 Pass - Major Risk L -212 - L- 212PB1 - L- 212PB1 549.82 545.00 81.36 9.36 72.01 Pass - Major Risk L -212 - L- 212PB2 - L- 212PB2 1,579.55 1,595.00 46.47 38.59 14.83 Pass - Major Risk L-2-13---L-213---L-213 _?13-- -L -213 - - - -- - - - - -- -_ _ -29&12 - 300-.00 . _ _ - 214.17 5.12 - 2-09,05- -Pass --- Major - Risk - - - - -- L -215 - L -215 - L -215 745.76 730.00 148.90 13.45 135.49 Pass - Major Risk L -215 - L- 215PB1 - L- 215PB1 745.76 730.00 148.90 13.45 135.49 Pass - Major Risk L -2 - - - : - - - : 745.76 - 730 14&g0 13.45 135.49 P - Majorfisk L -216 - L -216 - L -216 1,588.40 1,540.00 114.14 44.65 72.63 Pass - Major Risk - -_ - -__ I -917 - I -217 - 1 217 - - 763 59 - 7.60_00 _98_63_ - ___- ______13 88 84 75 _Pass - Major Risk L -218 - L -218 - L -218 440.19 445.00 151.91 8.45 143.46 Pass - Major Risk L -219 - L -219 - L -219 209.43 210.00 236.33 4.48 231.85 Pass - Major Risk L -220 - L -220 - L -220 291.91 295.00 187.83 6.01 181.82 Pass - Major Risk L -221 - L -221 - L -221 423.00 430.00 207.10 7.80 199.30 Pass - Major Risk L -250 - L-250 - L -250 804.27 805.00 34.15 15.80 18.45 Pass - Major Risk L -250 - L -250L1 - L -250L1 804.27 805.00 34.15 15.80 18.45 Pass - Major Risk L -250 - L -250L2 - L -250L2 804.27 805.00 34.15 15.84 18.40 Pass - Major Risk 1 L-250-- L- 250P81- - L -250P6 80417 005.00 34.15 15.80 18.45 Pass - Major Ris;- L -50 - L -50 - L -50 317.38 320.00 217.25 5.77 211.49 Pass - Major Risk L -50 - L -50PB1 - L -50PB1 317.38 320.00 217.25 5.77 211.49 Pass - Major Risk Plan L -203 (N -Q) - Plan L -203 OBd NW - Plan #11 589.40 585.00 114.03 11.20 102.87 Pass - Major Risk Plan L -203 (N-Q) - Plan L -203L1 OBd SE - Plan # 589.40 585.00 114.03 11.20 102.87 Pass - Major Risk Plan L -203 (N -Q) - Plan L -203L2 OBc SE - Plan # 589.40 585.00 114.03 11.20 102.87 Pass - Major Risk Plan L -203 (N -Q) - Plan L- 203L2 -01 OBc NW - PIE 589.40 585.00 114.03 11.20 102.87 Pass - Major Risk Plan L -203 (N -Q) - Plan L -203L3 OBa - Plan #6 L- 589.40 585.00 114.03 1120 102.87 Pass - Major Risk Plan L -203 (N -Q) - Plan L -203L4 Nb - Plan #7 L -2( 589.40 5800 114.03 - 11.20 102.87 Pass - Major Risk Plan L -203 (N -Q) - Plan L -203L5 Nb - Plan #2 L -2( 589.40 585.00 114.03 11.20 102.87 Pass - Major Risk Plan I - 799 - Plan I - 779 - Plan #2 I - 277 686 68 665 00 769 Al 17 17 747 78 Pass - Majnr Risk Plan L -52 (S-E) - Plan L -52 - Plan #1 368.57 375.00 210.19 6.99 203.20 Pass - Major Risk 4/21/2009 2:19:41PM Page 4 of 5 COMPASS 2003.16 Build 70 Project: Prudhoe Bay • Site:- PB L Pad Well: Plan L -223 Wellbore: Plan L -223 Design: Plan #3 L -223 From kop to TD Scan interval 100 ft Scale 1:100 All wells Major Risk c , 350 330 30 I ' 2' 200 300 60 L- 1 L-21 • , �` 5 �•, s7 . • 3 , 4 1 7 6- 270 c r 1id1.u., wsr 90 h9,,,, ,�wf1-124P6 12 11 1 z - ` , i & 6 -� 9 • ' _ : ate . b k. f � • a 5 z 14 13 12 # , }1 g r'` b" P, + 10 L- 2191E 219 iii ;Bi rk il" : te.4r 1 1 1 I r �{ 10 ` 1 T ; L-210/ -210PI 0 L-211 ?L -211P61 z�Y : s ° 11' 11 10 �_ 1 } / 12 Y 15 \ \ 1 r� t / t2 i � 1 ti t + r7 1 r \ � 1 S 241 y t _ ; 1 + 1 13 ` ,� ' ,. �„ J 13 ! P i a n L- 222 /Plan k: \z1` . 3 Q T.. , 1 • f 4 i` . ► L -122/L 122 �\ =9 yf �i.. ° e � 240 - 4 1 F : r 15 ' 40 — 120 ` X5 0 , � ry �� j A ,. ��� 4 - 17 Tp L -1201L 120 3 � " ' r "'tif '/i2 � 1� J�e��MBt 2. /L 250F4.1 11; :e - 3 t f : 4 , �'��� , �� 1 �i 00.1,!. C • : r ti. _!fir . rw y L /Plan 2 #'. s i k � .. � ) 11, r #. P _ � r � � fir. t 3J 1G t o � .1,,) ii L -213/L -213 f(I i�' *li � i f' L- 119/L -11# L- 200 /L- 2( 4 }�, 3t 29 $. J ° 210 L- 2 I ,� " j l �j �0 � +��44 _ S � �L -107/L -107 ` 1 L _ i 1 ' S � "J i ° 4 ' - /P ' w! r- ii. Ir �►• , "a an ` L ` 203 (N- Q) /Pbn #2 L -205L5 .` " N. � c j w , ' .. 220/L 2 — i L-0 . ., .. Bc NW Travelling Cylinder Azimuth (TFO +AZI) [ vs Centre to Centre Separation [100 ft/in] Alaska Department of Natural sources Land Administration System Page 1 of /I 'Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 375134 di Printable Case File Summary See Township, Range, Section and Acreage? 0 Yes 0 No New Search LAS Menu I C ase Abstract I Case Detail I Land Abstract File: ADL 375134 Search for Status Plat Updates As of 09/15/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 80 CLOSED Status Date: 04/02/2001 Total Acres: 2560.000 Date Initiated: 09/17/1990 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/31/2002 Case Subtype: NS NORTH SLOPE Last Transaction: EXN CLOSED - EXPIRED Meridian: U Township: 012N Range: 011E Section: 13 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 011E Section: 14 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 23 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 24 Section Acres: 640 Legal Description 09 -17 -1990 * *SALE NOTICE LEGAL DESCRIPTION ** TRACT 70A -134 T. 12N., R. 11E., UMIATMERIDIAN, ALASKA SECTION 13, UNSURVEYED, ALL, 640 ACRES; SECTION 14, UNSURVEYED, ALL, 640 ACRES; SECTION 23, UNSURVEYED, ALL, 640 ACRES; SECTION 24, UNSURVEYED, ALL, 640 ACRES. http : / /dnr. alaska. gov /prof ects /las /C ase_Summ ary. cf m ?FileType= ADL &FileNumber =3 751... 9/15/2009 Alaska Department of Natura sources Land Administration System • Page 1 of/ Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources I Alaska DNR Case Summary File Type: ADL File Number: 28239 8 Printable Case File Summary See Township, Range, Section and Acreage? Yes Q No New Search LAS Menu I Case Abstract I Case Detail I Land Abstract -laY File: ADL 28239 __ Search for Status Plat Updates As of 09/15/2009 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: 012N Range: 011E Section: 27 Section Acres: 640 Search Plats Meridian: U Township: 012N Range: 011E Section: 28 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 33 Section Acres: 640 Meridian: U Township: 012N Range: 011E Section: 34 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -17 012N- 011E -UM 27,28,33,34 2560.00 04 -01 -1977 * *UNITIZED,LEASE AND PARTICIPATING AREA LEGAL DESCRIPTION ** LEASE COMMITTED IN ENTIRETY TO PRUDHOE BAY UNIT AND OIL RIM GAS CAP PA'S PRUDHOE BAY UNIT http: / /dnr.alaska.gov /projects /las /Case Summary.cfm ?FileType= ADL &FileNumber = 2823... 9/15/2009 • • TRANSMITTAL LETTER CHECKLIST WELL NAME 7;g/ L v?,3 PTD# a2O90 Development ✓ Service Exploratory Stratigraphic Test Non- Conventional Well FIELD: `iE'4/ 4/ 'E 0,4). POOL: Q.e /Oit- =C',ideg1.e' 4Z Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole .must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN L-223 Program SER Well bore seg ❑ PTD #: 2090990 Company BP EXPLORATION (ALASKA) INC Initial Class/Type SER / PEND Geo Area 890 Unit 11650 On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes 3 Unique well name and number Yes 4 Well located in a defined pool Yes 5 Well located proper distance from drilling unit boundary Yes 6 Well located proper distance from other wells Yes 7 Sufficient acreage available in drilling unit Yes 8 If deviated, is wellbore plat included Yes 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Blanket Bond # 6194193. 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes ACS 9/15/2009 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes AIO 26 15 All wells within 1/4 mile area of review identified (For service well only) Yes 16 Pre- produced injector: duration of pre production less than 3 months (For service well only) NA 17 Nonconven. gas conforms to AS31.05.030(f.1.A),(j,2.A -D) NA 18 Conductor string provided Yes - - - -- - -- 9P Engineering 19 Surface casing protects all known USDWs NA No aquifers. WOA exemption No.1 (MO 26_finding 13) 20 CMT vol adequate to circulate on conductor & surf csg Yes 21 CMT vol adequate to tie -in long string to surf csg No TOC planned 1000' below surface casing. 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rig has steel pits. All waste to approved disposal wells. 25 If a re-drill, has a 10 -403 for abandonment been approved NA 26 Adequate wellbore separation proposed Yes Proximity analysis performed. Pass criteria. 27 If diverter required, does it meet regulations Yes paddle waived for first 1000 drilled. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max. formation pressure = 2279 psi (8.7 EMW) Drilling with 9.2 ppg mud GLS 9/21/2009 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 1775 psi BOP to be tested to 4000 psi. • 31 Choke manifold complies w /API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H28 gas probable Yes H2S present in PBU lift gas ... Rig has sensor and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes No wells within 1/4 nile in pool. 35 Permit can be issued w/o hydrogen sulfide measures No Max level H2S on Pad was 250ppm (10/20/06). Geology 36 Data presented on potential overpressure zones NA Appr Date 37 Seismic analysis of shallow gas zones NA ACS 9/15/2009 38 Seabed condition survey (if off-shore) NA 39 Contact name /phone for weekly progress reports [exploratory only] Yes Ryan Ciolkosz - 564 -5977. • Geologic Engineering Public Commissioner: Date: issioner: D >ate Commissioner Date