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Home My WebLink About205-194MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-123 PRUDHOE BAY UN BORE L-123 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 L-123 50-029-23290-00-00 205-194-0 G SPT 6348 2051940 3200 2581 2583 2587 2582 232 259 261 262 OTHER P Kam StJohn 9/8/2024 MIT-IA to Max anticipated injection pressure to inform possible AA application. Well currently under Evaluation for TxIA Max Header pressure = 3200 psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE L-123 Inspection Date: Tubing OA Packer Depth 672 3483 3435 3423IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240908132721 BBL Pumped:2.3 BBL Returned:2.2 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 999 99 9 9 9 9 9 Max anticipated injection pressure to inform possible AA application James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 16:21:54 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector L-123 (PTD #2051940) anomalous IA re-pressurization resolved Date:Tuesday, October 15, 2024 12:02:45 PM Attachments:image001.png L-123 TIO 241015.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, October 15, 2024 11:51 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Injector L-123 (PTD #2051940) anomalous IA re-pressurization resolved Mr. Wallace, Monitoring of the inner annulus (IA) pressure of injector L-123 (PTD #2051940), post dummy gas lift valve changeout has shown that the previous IA repressurization has stopped. The well is now classified as OPERABLE. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 3, 2024 3:23 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector L-123 (PTD #2051940) anomalous IA re- pressurization Mr. Wallace, Injector L-123 (PTD #2051940) extended packing dummy gas lift valves were set on 09/24. At this time, the IA re-pressurization appears to be resolved. With permission, we would like to extend the under evaluation period for an additional 14 days to confirm the leak has been mitigated as the original 28 day period is complete tomorrow 10/04. 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, September 6, 2024 3:10 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-123 (PTD #2051940) anomalous IA re-pressurization Mr. Wallace, Injector L-123 (PTD #2051940) had an IA bleed on 06/19/24. Since that bleed, a slow IA re- pressurization trend has been observed. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: AOGCC witnessed MIT-IA 3. Well Integrity: Additional diagnostics as needed and potential 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 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 responsibilityis 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: UPDATE UNDER EVALUATION: Injector L-123 (PTD #2051940) anomalous IA re-pressurization Date:Thursday, October 3, 2024 3:54:24 PM Attachments:image001.png From: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Sent: Thursday, October 3, 2024 3:40 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Re: UPDATE UNDER EVALUATION: Injector L-123 (PTD #2051940) anomalous IA re- pressurization Ryan, Additional 14 days is approved. Chris From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, October 3, 2024 3:23:06 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: UPDATE UNDER EVALUATION: Injector L-123 (PTD #2051940) anomalous IA re- pressurization Mr. Wallace, Injector L-123 (PTD #2051940) extended packing dummy gas lift valves were set on 09/24. At this time, the IA re-pressurization appears to be resolved. With permission, we would like to extend the under evaluation period for an additional 14 days to confirm the leak has been mitigated as the original 28 day period is complete tomorrow 10/04. 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, September 6, 2024 3:10 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-123 (PTD #2051940) anomalous IA re-pressurization Mr. Wallace, Injector L-123 (PTD #2051940) had an IA bleed on 06/19/24. Since that bleed, a slow IA re- pressurization trend has been observed. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: AOGCC witnessed MIT-IA 3. Well Integrity: Additional diagnostics as needed and potential 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 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No 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-123 (PTD #2051940) anomalous IA re-pressurization Date:Monday, September 9, 2024 8:08:11 AM Attachments:L-123.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, September 6, 2024 3:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-123 (PTD #2051940) anomalous IA re-pressurization Mr. Wallace, Injector L-123 (PTD #2051940) had an IA bleed on 06/19/24. Since that bleed, a slow IA re- pressurization trend has been observed. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Fullbore: AOGCC witnessed MIT-IA 3. Well Integrity: Additional diagnostics as needed and potential 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 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. TREE _ 4-1/16' CIW DATE REV BY COMMENTS DATE REV BY COMMENTS 01/07/06 NIIES ORIGINAL COMPLETION 01/07/16 ALWJMD MILL CMT/CBP/ADPERFS 12/30� 11/12/06 RAC/TLH GLV PORT SIZE EDITS 08/31/22 JLS/JMD ADPERFS O8/24/22 02/15/11 MB/JMD ADDED SSSV SAFETY NOTE 01/18/12 TMN/JMD ADDED H2S SAFETY NOTE 11/25/15 TBD/JMD GLV C/O 11/15/15 12/23/15 ALWJMD SQZPERFS 12/05/15 BOREALIS UNIT WELL: L-123 PERMIT No:'1051940 API No: 50-029-23290-00 Hilcorp North Slope, LLC Well: L-123 300 290 280 270 260 250 240 230 220 210 200 190 180 170 160 150 140 130 e 120 110 100 90 80 70 60 50 40 30 20 10 06ro624 Ml-124 0&2024 0&27+24 07/04/24 071124 0711824 072524 0&01i24 0&+0924 W15124 0&2224 087924 09,0524 TIO Plot —� Tubing On ■ Bleed * Operable + Not Oper ♦ Under Eval —F Man. IA —A Man.OA Man. OOA — Man.000A —0- Man. WHT MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, March 7, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-123 PRUDHOE BAY UN BORE L-123 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/07/2024 L-123 50-029-23290-00-00 205-194-0 G SPT 6348 2051940 1587 2582 2590 2584 2582 222 233 232 235 4YRTST P Austin McLeod 2/1/2024 MITIA 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 BORE L-123 Inspection Date: Tubing OA Packer Depth 621 1840 1814 1808IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240203122844 BBL Pumped:1.3 BBL Returned:1.1 Thursday, March 7, 2024 Page 1 of 1           By Anne Prysunka at 4:29 pm, Aug 31, 2022 MGR12SEP2022 ,ISHUIRUDWLQJ 7\SHRI5HTXHVW 2SHUDWRU1DPH $GGUHVV &XUUHQW:HOO&ODVV3HUPLWWR'ULOO1XPEHU $3,1XPEHU :HOO1DPHDQG1XPEHU 3URSHUW\'HVLJQDWLRQ/HDVH1XPEHU)LHOG3RROV $EDQGRQ 6XVSHQG 3OXJIRU5HGULOO 3HUIRUDWH1HZ3RRO 3HUIRUDWH 3OXJ3HUIRUDWLRQV 5HHQWHU6XVS:HOO 2WKHU6WLPXODWH )UDFWXUH6WLPXODWH $OWHU&DVLQJ 3XOO7XELQJ 5HSDLU:HOO 2WKHU &KDQJH$SSURYHG3URJUDP 2SHUDWLRQVVKXWGRZQ 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ĨƚĞƌDhD,ĂŶĚƉƵůůƚĞƐƚŝŶŐƚŚĞd͕ƚĂŐͲƵƉŽŶƚŚĞdƐƚƌŝƉƉĞƌƚŽĞŶƐƵƌĞ,ĐĂŶŶŽƚƉƵůůƚŚƌŽƵŐŚ ƚŚĞďƌĂƐƐƵƉŽŶWKK,ǁŝƚŚŐƵŶƐ͘ Ϯ͘ ƵůůŚĞĂĚΕϮϱϬ ďďůƐϭй<>ͬ^tĚŽǁŶƚƵďŝŶŐ͘DĂǆƚƵďŝŶŐƉƌĞƐƐƵƌĞ ϯϬϬϬƉƐŝ͘ ;dŚŝƐƐƚĞƉĐĂŶďĞ ƉĞƌĨŽƌŵĞĚĂŶǇƚŝŵĞƉƌŝŽƌƚŽŽƉĞŶͲŚŽůĞĚĞƉůŽǇŵĞŶƚŽĨƚŚĞƉĞƌĨŐƵŶƐ͘dŝŵŝŶŐŽĨƚŚĞǁĞůůŬŝůůŝƐĂƚƚŚĞ ĚŝƐĐƌĞƚŝŽŶŽĨƚŚĞt^^͘Ϳ 'RQRWH[FHHGIUDFWXUHJUDGLHQWRISVLIWSVLDWVDQGIDFH tĞůů͗ >ͲϭϮϯ Wd͗ϮϬϱͲϭϵϰ W/͗ϱϬͲϬϮϵͲϮϯϮϵϬͲϬϬ ϯ͘ DhĂŶĚZ/,ǁŝƚŚůŽŐŐŝŶŐƚŽŽůƐĂŶĚĚƌŝĨƚ,ͬ:^E ϰ͘ :ĞƚƚŚƌŽƵŐŚĂŶǇŚǇĚƌĂƚĞƐĞĞŶ Ă͘ ^ůŝĐŬůŝŶĞƚĂŐŐĞĚƵƉĂƚϭϰϲϲ͛ ď͘ KŶĐĞƚŚƌŽƵŐŚƚŚĞƚƵďŝŶŐ͕ĞǆƉĞĐƚƚŚĞĞǆŝƐƚŝŶŐƉĞƌĨŽƌĂƚŝŽŶƐƚŽďĞƉůƵŐŐĞĚǁŝƚŚƐĐŚŵŽŽ͕ĂƚƉĞƌĨ ĚĞƉƚŚƐ͕Ă^'ĐĂŶďĞƉƵŵƉĞĚŝĨƚŚĞƉĞƌĨƐĐĂŶŶŽƚďĞĐůĞĂŶĞĚƵƉǁŝƚŚũĞƚƚŝŶŐĂĐƚŝŽŶ ŝ͘ ϭϮ͕ϯϰϬ͛ďŽƚƚŽŵƉĞƌĨƚŽ ʹ ϭϭ͕ϴϯϬ͛ƚŽƉƉĞƌĨŝƐϱϭϬĨĞĞƚŽĨ ƉĞƌĨŽƌĂƚŝŽŶƐ ŝŝ͘ WƵŵƉ^'ƚƌĞĂƚŵĞŶƚƉĞƌZW͕ǀŽůƵŵĞŶĞĞĚĞĚŝƐϳϱďďů;ĚŽǁŶ͕ƵƉ͕ĚŽǁŶƉĂƐƐĞƐĂƚϮϬ ĨƉŵǁŚŝůĞƉƵŵƉŝŶŐϭďƉŵͿ ŝŝŝ͘ ƵůůŚĞĂĚŽƌƚĂŬĞƌĞƚƵƌŶƐƵŶƚŝů^'ĐŚĞŵŝĐĂůŝƐĂƚŶŽǌǌůĞ͕ƐǁĂƉƚŽďƵůůŚĞĂĚŝŶŐ^' ŝŶƚŽƉĞƌĨƐŽŶĐĞƚŚĞĐŚĞŵŝĐĂůŝƐŽŶďŽƚƚŽŵ ϭ͘ dŚŝƐZhŝƐ ƚŽŝŵƉƌŽǀĞŝŶũĞĐƚŝǀŝƚǇ͕ŝƚŵĂǇďĞƉƌƵĚĞŶƚƚŽƌĞĚƵĐĞƚŚĞǀŽůƵŵĞ ďƵůůŚĞĂĚĞĚĂǁĂǇƐŽ ĂƐƚŽŬĞĞƉůŽĐĂůƌĞƐĞƌǀŽŝƌƉƌĞƐƐƵƌĞůŽǁ͘/ĨǁĞĐŚĂƌŐĞŝƚ ƵƉƚŽŽŵƵĐŚ͕ŽƵƌ<t&ǁŝůůŚĂǀĞƚŽŐĞƚŚĞĂǀŝĞƌ͘ ŝƐĐƵƐƐǁŝƚŚK ϱ͘ &ůĂŐƉŝƉĞĂƐĂƉƉƌŽƉƌŝĂƚĞƉĞƌt^^ ĨŽƌĂĚƉĞƌĨͬWƌƵŶƐ͘ ϲ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨƚŽƌĞƚƵƌŶƚĂŶŬ͘<ŝůůǁĞůůǁͬ<t&͕ϴ͘ϰƉƉŐϭй<ůŽƌϴ͘ϱ ƉƉŐ ĂƐŶĞĞĚĞĚ ďǇƉƵŵƉŝŶŐĚŽǁŶƚŚĞĐŽŝůƚƵďŝŶŐďĂĐŬƐŝĚĞ͘DĂŝŶƚĂŝŶŚŽů ĞĨŝůůƚĂŬŝŶŐƌĞƚƵƌŶƐƚŽƚĂŶŬ ƵŶƚŝůůƵďƌŝĐĂƚŽƌĐŽŶŶĞĐƚŝŽŶŝƐƌĞͲĞƐƚĂďůŝƐŚĞĚ͘&ůƵŝĚƐŵĂŶͲǁĂƚĐ ŚŵƵƐƚďĞƉĞƌĨŽƌŵĞĚǁŚŝůĞĚĞƉůŽǇŝŶŐ ƉĞƌĨŐƵŶƐƚŽĞŶƐƵƌĞƚŚĞǁĞůůƌĞŵĂŝŶƐŬŝůůĞĚĂŶĚƚŚĞƌĞŝƐŶŽĞǆĐĞƐƐĨůŽǁ͘ Ă͘ KďƚĂŝŶŝŶũĞĐƚŝŽŶƚĞƐƚ ŝ͘ dĂƌŐĞƚt,ƉƌĞƐƐƵƌĞ͗ϮϮϬϬƉƐŝ ŝŝ͘ dĂƌŐĞƚƌĂƚĞ͗ϮďƉŵ ŝŝŝ͘ ŝƐĐƵƐƐǁŝƚŚKƚŚĞĚƵƌĂƚŝŽŶŽĨƚŚĞŝŶũĞĐƚŝŽŶƚĞƐƚĂŶĚĨŝŶĂ ůƌĞƐƵůƚƐ͘ tĞĂƌĞƵƐŝŶŐƚŚŝƐ ƚŝŵĞƚŽŐĞƚĨŝŶĂů<t&ĚĞŶƐŝƚǇŶĞĞĚĞĚĨŽƌK,ĚĞƉůŽǇŵĞŶƚ͕ŝƚŵĂǇďĞŶĞĐĞƐƐĂƌǇƚŽ ĐŝƌĐƵůĂƚĞĂƌŽƵŶĚŽƵƌ<t&ŝĨƌĞƐĞƌǀŽŝƌĐŽŶĚŝƚŝŽŶƐĚĞĞŵŝƚŶĞĐĞƐƐĂƌǇ;ƉŽŽƌŝŶũĞĐƚŝǀŝƚǇ ĐŚĂƌŐĞƐƵƉƚŚĞŶĞĂƌǁĞůůďŽƌĞƌĞƐĞƌǀŽŝƌͿ ϳ͘ WKK,ĂŶĚ ĨƌĞĞǌĞƉƌŽƚĞĐƚƚƵďŝŶŐĂƐ ŶĞĞĚĞĚ͘ ϴ͘ ŽŶĨŝƌŵŐŽŽĚ ůŽŐ ĚĂƚĂ͘ ϵ͘ ŽŶĨŝƌŵǁĞůůŝƐĚĞĂĚ͘ůĞĞĚĂŶǇƉƌĞƐƐƵƌĞŽĨĨƚŽƌĞƚƵƌŶƚĂŶŬ͘ ϭϬ͘ ƚƐƵƌĨĂĐĞ͕ƉƌĞƉĂƌĞĨŽƌĚĞƉůŽǇŵĞŶƚŽĨdWŐƵŶƐ͘ ϭϭ͘ ΎWĞƌĨŽƌŵĚƌŝůůďǇƉŝĐŬŝŶŐ ƵƉƐĂĨĞƚǇũŽŝŶƚ ǁŝƚŚ 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If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L-123 Extended Perf w CTU Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 205-194 50-029-23290-00-00 471 ADL 0028239 12405 Conductor Surface Intermediate Production Liner 6480 80 3615 10697 1883 12361 20" 9-5/8" 7" 4-1/2" 6482 29 - 109 29 - 3644 26 - 10723 10522 - 12405 2140 29 - 109 29 - 2618 26 - 6444 6377 - 6480 12361 3090 5410 7500 None 5750 7240 8430 11830 - 12340 4-1/2" 12.6# L-80 25 - 105236501 - 6483 Structural 4-1/2" Baker S3 Packer 4-1/2" MCX I-SSV 10456, 6348 2827, 2182 Date: Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, BOREALIS OIL 12/1/21 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2021 Approved application is valid for 12 months from the date of approval. 321-580 By Meredith Guhl at 7:30 am, Nov 12, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.11.11 13:57:46 -09'00' Stan Golis (880) DLB 11/12/2021 10-404X DSR-11/12/21 COMMISSSIONERR Commm.SSr Pet EngSetgComm.Sr Pet Eng Add Perf Procedure (rev1) L-123 PTD:205-194 Well Name:L-123 API Number:50-029-23290-00-00 Current Status:Operable Injector Rig:Service coil Estimated Start Date:12/1/2021 Estimated Duration:6days Regulatory Contact:Abbie Barker Permit to Drill Number:205-194 First Call Engineer:David Wages 713.380.9836 Second Call Engineer:Wyatt Rivard AFE Number:212-01188 Current Bottom Hole Pressure:~2800 psi @ 6600’ TVD (8.1 PPGE pattern estimate) Nearest and most recent offset shut in producer SBHP survey Max. Anticipated Surface Pressure:2140 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:0 psi (Current SITP) Min ID:3.725” ID, XN Nip @ 10,500’ MD Max Angle:94 Deg @ 12,000’ MD Reference Log: 12-29-2021 PDS coil flag Brief Well Summary: L-123 is an injector in the northwest portion of the Borealis reservoir supporting L-124 and L-122 producers. It’s historically struggled with PW injection and had been kept on MI until very recently where a trial of PWI was attempted to predictable results: the existing perfs appeared to plug with Schmoo. With the planned CTD sidetrack progressing, we need to make this well capable of taking injection. Objective: Ext Perf Add Sundry Procedure (Approval Required to Proceed): Note: The well will be killed and monitored during the FCO/tie-in run. This will provide guidance as to whether the well will be killed by bullheading or circulating bottoms up throughout the job. If pressure is seen immediately after perforating, it will either be killed by bullheading while POOH or circulating bottoms up through the same port that opened to shear the firing head. Coil Tubing 1. MIRU Coiled Tubing Unit and support equipment. 2. MU & Run JSN BHA with logging tools, if possible. Tag liner hanger or nipple, flag pipe for depth correction (flag will be used to tie-in for perforating runs). 3. Tag TD, ensure CIBP parts left in well are pushed below bottom shot. a. Cerberus modelling does not indicate we need safelube b. Confirm pickup weights as needed with OE/SLB coilcade c. Use RIH/POH weights to inform CoilCADE models to ensure guns can make it to target depth 4. Proceed to FCO/jet existing perfs a. Discuss with OE need for SBG or hot diesel while jetting b. Circulate in KWF as needed c. Obtain injection test i. Target WH pressure: 2200 psi ii. Target rate: 2 bpm iii. Chat with OE about this one, we can raise max injection pressure to 4000 psi if needed Prepare for deployment of TCP guns. * Bottom hole pressure not to exceed fracture gradient. mgr/AOGCC Add Perf Procedure (rev1) L-123 PTD:205-194 5. Pickup safety joint and TIW valve and space out before MU guns. “Review well control steps with crew prior to breaking lubricator connection and commencing makeup of TCP gun string. Once the safety joint and TIW valve have been spaced out, keep the safety joint/TIW valve readily accessible near the working platform for quick deployment if necessary” 6. Break lubricator connection at QTS and begin makeup of TCP guns and blanks per schedule below. *Use 2.875” 175 MaxForce, 6 spf, 60° phasing (or equivalent) guns 38.6” Penetration, 0.37 EHD x Calibrate friction factor on logging run. x Consult OE if Run 2 needs to be split into 2 runs. L-123 Add Perf Schedule Perf Interval Perf Length Gun Length Air Weight of Gun (lbs) at 12.41 ppf Comments Run 1 11,830’- 12,340’294 510 ~6330# Run 2 10,915’- 11,210’243 295 ~3660# Please shoot Toe first Perf targets: Top Bottom Length 11830 11850 20 Blank Length 95 11945 11980 35 Blank Length 50 Top to bottom shot Weight 12030 12080 50 Run #1 510 6329 Blank Length 35 Perf footage 12115 12234 119 294 Blank Length 36 Blank Footage 12270 12340 70 216 10915 11090 175 Top to bottom shot Weight Blank Length 12 Run #2 295 3661 11102 11140 38 Perf footage Blank Length 40 243 11180 11210 30 Blank Footage 52 7. RIH with perf gun and tie-in to coil flag correlate. Pickup and perforate interval per Perf Schedule above, note any change in tubing pressure in WSR. a. Obtain injection test i. Target WH pressure: 2200 psi ii. Target rate: 2 bpm Add Perf Procedure (rev1) L-123 PTD:205-194 iii. Chat with OE about this one, we can raise max injection pressure to 4000 psi if needed 8. POOH. Stop at surface for flow check, reconfirm well dead and hole full. a. Recalculate KWF weight as necessary and bullhead kill the well 9. Review well control steps with crew prior to breaking lubricatorconnection and commencing breakdown of TCP gun string. 10. Repeat run #1 steps to shoot run #2 11. Obtain full well injectivity test a. Target WH pressure: 2200 psi b. Target rate: 2 bpm c. Chat with OE about this one, we can raise max injection pressure to 4000 psi if needed 12. Ensure well is freeze protected while POOH on final run. 13. RDMO CTU. 14. Hand well over to operations for POI. Attachments: 1. Current Wellbore Schematic 2. Proposed Schematic 3. Coil Tubing BOPE Schematic 4. Equipment Layout Diagram 5. Standing Orders for Open Hole Well Control during Perf Gun Deployment 6. Cerberus modelling Add Perf Procedure (rev1) L-123 PTD:205-194 Current Wellbore Schematic Add Perf Procedure (rev1) L-123 PTD:205-194 Proposed Schematic Add Perf Procedure (rev1) L-123 PTD:205-194 Coiled Tubing BOPs Add Perf Procedure (rev1) L-123 PTD:205-194 Equipment Layout Diagram Add Perf Procedure (rev1) L-123 PTD:205-194 Standing Orders for Open Hole Well Control during Perf Gun Deployment Add Perf Procedure (rev1) L-123 PTD:205-194 Cerberus Modelling: Anticipated Surface Weights using 0.25 friction factor for Run #2 described above (510’ long, 6330# air weight): Add Perf Procedure (rev1) L-123 PTD:205-194 X-Section: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: November 11, 2021Subject: Changes to Approved Sundry Procedure for Well L-123Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date MEMORANDUM TO: Jim Regg�! ZI14/Zcn� P.I. Supervisor FROM: Guy Cook Petroleum Inspector State of Alaska Alaska Oil and Cas Conservation Commission DATE: Thursday, February 13, 2020 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. L-123 PRUDHOE BAY UN BORE L-123 Set: Inspector Reviewed By: P.I. Supry -JL32-- Comm Well Name PRUDHOE BAY UN BORE L-123 API Well Number 50-029-23290-00-00 Inspector Name: Guy Cook 205-194-0 2/12/2020 Permit Number: Inspection Date: lnsp Num: mitGDC2oo213081455 Rel Insp Num: Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min prep 2051940 e yp Inj � G "TVD 6348 Tubing '-s» - 2875 )882 zes4 Type Test SPT Test psi 1587 IA 193 2196 3179 2177 BBL Pumped: 1.5 BBL Returned: -- 1.5 OA 68 95 - 114 118' Interval_ 4YRTST — _P/F. P Notes: MIT performed with a Little Red Services pump truck and currently calibrated gauges. ✓ Thursday, February 13, 2020 Page I of I STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations H Fracture Stimulate II Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate El Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-194 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service El 6. API Number: 50-029-23290-00-00 7. Property Designation(Lease Number): ADL 0028239 8. Well Name and Number: BRLS L-123 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: Total Depth: measured 12405 feet Plugs measured .feet RECEIVED true vertical 6480 feet Junk12361 feet measured FEB 16 2016 Effective Depth: measured 12361 feet Packer measured 10457 feet true vertical 6482 feet Packer true vertical 6348.26 feet AOGGC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"215.5#A-53 30-109 30-109 0 0 Surface 3615 9-5/8"40#L-80 30-3645 30-2618 5750 3090 Intermediate 11366 7"26#L-80 27-11393 27-6519 7240 5410 Production Liner 1883 4-1/2"12.6#L-80 10523-12406 6378-6480 8430 7500 Perforation Depth: Measured depth: 10915 10960 feet 10975-11090 feet 11110-11140 feet 11180-11210 feet 11830-11850 feet 11945-11980 12030-12080 feet 12150-12190 feet 12270-12300 feet 12300-12340 feet True vertical depth: 6482-6489 feet 6491-6511 feet 6514-6519 feet 6523-6524 feet 6501-6500 feet 6493-6491 6488-6485 feet 6483-6484 feet 6484-6484 feet 6484-6483 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-10523 25-6378 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"MCX I-SSV 2827 2182 12.Stimulation or cement squeeze summary: 5! �.NNED APR Intervals treated(measured): 7�.�"�{�[�`if 0 8 [Q� See Attachment Treatment descriptions including volumes used and final pressure: �� • See Attachment pj rctw4 3118/2016 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 2280 700 250 Subsequent to operation: 3327 3077 260 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 (50.44 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data MGSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-698 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer SignatureC Phone +1 907 564 4424 Date 2/15/16 Form 10-404 Revised 5/2015 t ��ZII t 11 ,/ / -6 Y I v J �Df/�jf/ 1 6 2016 r61 # a' Submit Original Only °SW 3/11140/6 1!/ !! 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CO N _ID 0 E U > UID c r O Q ,(n c o U — � .°- ° ° U — rn m c a) a) a id Q Y 3 0-N 0 0 C p Cr) O i 0 -c r ii .§ c a y 0 >> c) a) - E ,° m a) '- 'E' 121- (1) Ecco 3 .�U g - -,, z < ,W a a o c ao m m o m -0 z -- Qui`. Q-arn 2 p E cad a) m 0 3 r _ O _ L m f p) p C N -0 C (n C - 0 a) Y o O = (,3 •_- 0 E o 0-.r ~ r O J o 0_ L Q a ° > co O d I( w C *k U 2 0 ° N C p 0 ° c '- '"' (,) U _ 0_ 0U (n +. O (n o_ E E a) E Q w rn r ? ° .E >=> O U D m J N N ° (6 co L O * 0 O z C N a) U) LO Q-C * as N > a) * ~ O a .7 C L U O o F- O p p)N ''' * O 0 — L N N Q. * Etiif= E * 0 -`ii2 0 L * 00 (h * 0 - 0 -' U ° r � * CO CO CO CO CO CO r r r V- C) O O O O O N N CLJN N N CO 0000 r U) CO (O r r r r r r --- II • I 2 m w Cl) Cl) 0_ O q / o_ \ \ w CO eb < R 2 $ Z C m c 0 CC CO § \ @ 4 fl 2 m >, o. q z / co I- 0 — " EZZz \ 7 •§ W - e E � � U on � § � $ o _1 o S 7 / ; po3 \ k % t ƒ E < _ - a) & O a > U) o Ce M / co £ @ / _ _ F- CC ( kk co 0 0 / 0 — ± ƒ 2k Z E m ¥ O b 2 5 ) U as ® $ h - 2 .g \ a / O ƒ / / \ / $ / / \ ( ± k / \ � G & u \ & ee � / / t % � / ƒ QU = R 2 2 o A o = 5 _1 _ .— w F- 4 O w z _ \ f $ % ƒ a I U k 7 § E/ » / / LL w < / $ 1-7- LL R n t f / 7 \ m 2 / t O./ < t « Om2t 5 » � � / 3m622 ƒ tea / 2 •% ¢ / co in o m ¥ # & c mv. mn co _ eo m / ƒ / / vLo (0 f- � / i / \ / / / \ Q © • I Schlumberger FracCAT Treatment deport Well :L-123 Field :Aurora Formation :Kuparuk C Well Location :Greater Prudhoe Bay State :Alaska Country :United States Prepared for Client :BP Exploration Alaska Client Rep :Dan Scarpella Date Prepared :08-Jan-2016 Prepared by Name :Alexander Martinez Division :Schlumberger Phone :561 389 5006 Initial Wellhead Pressure(psi) 862 Maximum Treating Pressure(psi) 5,515 Final Surface ISIP(psi) S/O DataFrac ISIP 1,832 Surface Shut in Pressure(psi) 2,207 Total Slurry Pumped(Water+Adds+Proppant)(bbls) 4,636 Total Proppant Pumped(lbs.);From Load Tickets 335,300 Total WF128 Past Wellhead(bbls) 1,286 Total Proppant in Formation(lbs.) 331,278 Total YF128FIexD Past Wellhead(bbls) 3,001 Total Freeze Protect Past Wellhead(bbls) 21 J957(mgal) 126,046 126,046 J475(Ib) 1,485 1,485 F103(gal) 164 164 J134(Ib) 27 0 L065(gal) 181 181 M002(Ib) 125 125 L071(gal) 345 345 J604(gal) 312 312 M275(Ib) 66 56 Freeze Protect(bbl) 0 21 J891(gal) 960 930 J660(lb) 750 750 J622(lb) 560 560 Disclaimer Notice This information is presented in good faith,but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service.The results given are estimates based on calculations produced by a computer model including various assumptions on the well,reservoir and treatment.The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model,the assumptions and such input data.The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values.The quality of input data,and hence results,may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well,the reservoir,the field and conditions affecting them.If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue.Actual charges may vary depending upon time,equipment,and material ultimately required to perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. • Sch1umheger Cpotion Alaska Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Executive Summary The fracturing treatment for L-123 was performed January 8th. The crew arrived to location at 7am on. A DataFrac was performed with no official changes being made to the schedule. 3 BroadBand Sequence pills were pumped between each of the 4 stages. During the job there were indications of diversion in the first and second pills. During flush on the final stage, pressure spiked and tripped all pumps approximately 3bbls before the planned shutdown point. • • Schiumberger Client:BP Exploration Alaska Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 1 : Stage 1 , Diagnostic: As Measured Pum s Schedule As Measured Pump Schedule Slurry Slurry Pump Fluid Max Prop Prop #Step Step Name Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass (bbl) (bbl/min) (min) (gal) Conc (PPA) (lb) (PPA) 1 Injection Test 41.0 20.7 2.7 WF128 1723 0.0 0.0 0 - 2 Calibration 200.0 32.0 6.8 YF128FIexD 8400 0.0 0.0 0 3 Displacement 189.6 38.3 5.0 WF128 7963 0.0 0.0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 Injection Test 20.7 27.3 3930 4725 862 2 Calibration 32.0 35.9 4303 5078 1384 3 Displacement 38.3 40.6 4001 4243 1271 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 430.6 14.5 18086 0 Average Treating Pressure: 4133 psi Maximum Treating Pressure: 5078 psi Minimum Treating Pressure: 862 psi Average Injection Rate: 33.7 bbl/min Maximum Injection Rate: 40.6 bbl/min Average Horsepower: 3431.6 hhp Maximum Horsepower: 4223.7 hhp Maximum Prop Concentration: 0.0 PPA Section 2: Stage 1 , Diagnostic: Job Messages Message Log Message Treating Annulus # Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 1 11:10:42 On Location 07:00 0 0 0 0 0 2 11:11:05 LRS finished rolling tanks @ 1100 0 0 0 0 0 3 11:12:42 Started batching gel to ship to vac truck for BBS 0 0 0 0 , 0 4 11:13:01 LRS rigging up to IA 0 0 0 0 0 5 11:33:08 BBS gel made and verified 28#.Shipping it to vac 0 0 0 0 0 truck. 6 11:49:09 Verified good POD denso air voltage 0 0 0 0 0 7 12:53:25 LRS pressure testing manifold 0 0 0 0 0 8 12:53:36 Bringing gel onboard Batch Mixer 0 0 0 0 0 9 12:53:44 PJSM Complete 0 0 0 0 0 10 13:02:22 Priming POD on LVT 0 0 0 0 0 11 13:06:03 Priming up BBS Pump 1 0 0 0 0 12 13:10:45 BroadBand pump primed 0 0 0 0 0 13 13:11:45 POD primed 0 0 0 0 0 • • Schlumberger Client:BP Exploration Alaska �a7! Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Mess.se Log Message Treating Annulus # Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 14 13:12:45 Flooding lines with LVT 0 0 0 0 0 15 13:24:22 Priming pumps 49 0 0 1.9 0 16 13:26:02 Priming Pumps 122 0 0 5.7 0 17 13:30:35 Verified denso Air voltage upon arriving on 113 0 0 0 location 0 18 13:30:52 Verified pod is in gear.Pull Test. 114 0 0 4.4 0 19 13:31:17 BBS pump bleed line is fluid packed with LVT 118 0 0 5.5 0 20 13:32:48 Completed location walk down with WSL prior to 125 0 0 5.8 0 PJSM 21 13:36:48 All pumps primed 114 0 0 0 0 22 13:41:09 low PT start 109 0 0 0 0 23 13:47:43 bumping pressure 243 0 0 0 0 24 13:57:51 Good Low PT 252 0 0 0 0 25 14:03:09 Global pumps tripped 7458 0 0 0 0 26 14:08:21 bumping pressure 7076 0 0 0 0 No visible leaks on any iron.Pressure drop 27 14:19:17 appears to be due to diesel shrinking in cold 7473 0 0 0 0 environment 28 14:25:00 Good High PT 7161 0 0 0 0 29 14:25:15 Check valve test good 7156 0 0 0 0 30 14:26:36 Batching Gel 88 0 0 0 0 31 14:26:41 BBS Pump Isolated 89 0 0 0 0 32 14:47:35 28#gel verified on PCM 93 0 0 0 0 33 14:47:41 Rolling out LAS hoses 93 0 0 0 0 34 14:48:49 Adjusting Pop Off 93 0 0 0 0 35 14:49:34 Priming POD on gel 94 0 0 0 0 36 14:52:44 Bringing IA to 3000 psi 96 0 0 0 0 37 14:59:42 Ready all around 841 4 0 0 0 38 15:00:12 Start Injection Test Automatically 836 3 0 0 0 39 15:00:12 Start Diagnostic Automatically 836 3 0 0 0 40 15:00:12 Start Stage 1 Automatically 836 3 0 0 0 41 15:00:12 Started Pumping 836 3 0 0 0 42 15:00:37 Activated Extend Stage 1514 3 0.6 3.6 0 43 15:03:00 injection test shutdown 2159 4 41 0 0 44 15:08:18 Deactivated Extend Stage 1474 5 41 0 0 45 15:08:18 Start Calibration Manually 1474 5 41 0 0 46 15:11:41 XL ads lined out 4796 6 67,5 27.6 0 47 15:15:26 Stage at Perfs:Injection Test 3798 9 190.1 34 0 48 15:15:47 XL pH=10.00 3949 10 202.3 35.5 0 49 15:16:35 Stage at Perfs:Calibration 3882 11 230.8 35.8 0 50 15:16:53 Start Displacement Automatically 3795 12 241.5 35.7 0 51 15:17:08 XL ads cuts 3997 12 250.4 35.5 0 52 15:17:35 Activated Extend Stage 3923 13 266.9 37.1 0 53 15:22:33 Shutdown 1822 21 430.6 0 0 • . Schlumberger Client:BP Exploration Alaska (7 Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 3: Stage 1 , Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Ste Slurry Slurry Pump Fluid Max PropPro #p Step Name Volume Rate Time Fluid Name Volume Proppant Name Pro Concc Mass (bbl) (bbl/min) (min) (gal) Conc (PPA) (Ib) (PPA) 1 PAD 300 37.4 8.8 YF128FIexD 12600 0 0 0 2 1.0 PPA 50 39.6 1.3 YF128FIexD 2013 CarboLite 16/20 1.2 0.6 2026 3 2.0 PPA 50 39.5 1.3 YF128FIexD 1944 CarboLite 16/20 2,1 1.2 3658 4 3.0 PPA 50 39.4 1.3 YF128FIexD 1867 CarboLite 16/20 3.1 1.6 5477 5 4.0 PPA 100 38.9 2.6 YF128FIexD 3585 CarboLite 16/20 4.1 0.6 14495 6 5.0 PPA 100 38,1 2.6 YF128FIexD 3458 CarboLite 16/20 5.3 3.8 17479 7 6.0 PPA 77.2 37.2 2.1 YF128FIexD 2725 16/20 CarboBond Lite 6.3 0 10631 8 BBS Pill 47.1 40.4 1.2 SFT Pill 1979 0 0 0 9 Spacer 40 40.4 1 WF128 1681 0 0 0 10 Displacement 80 40.1 2 WF128 3363 0 0 0 11 Placement 67.5 39 1.7 WF128 2835 , 0 0 0 12 SDT 24.2 26.8 1.3 WF128 1015 0 0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 37.4 41.0 3868 4158 1269 2 1.0 PPA 39.6 40.4 4106 4160 4059 3 2.0 PPA 39.5 39.6 4026 4058 3975 4 3.0 PPA 39.4 39.7 3950 3975 3914 5 4.0 PPA 38.9 40.1 3900 3955 3848 6 5.0 PPA 38.1 39.0 4008 4169 3908 7 6.0 PPA 37.2 40.4 3995 4266 3522 8 BBS Pill 40.4 40.4 4222 4286 4137 9 Spacer 40.4 40.4 4266 4333 4189 10 Displacement 40.1 40.4 4006 4210 3816 11 Placement 39.0 39.3 3821 3949 3628 12 SDT 26.8 39.0 2991 3952 1769 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 985.9 27.0 39066 53766 Average Treating Pressure: 3937 psi Maximum Treating Pressure: 4333 psi Minimum Treating Pressure: 1269 psi Average Injection Rate: 38.3 bbl/min Maximum Injection Rate: 41.0 bbl/min Average Horsepower: 3716.7 hhp Maximum Horsepower: 4278.5 hhp Maximum Prop Concentration: 6.3 PPA • • Schluinherger Client:BP Exploration Alaska Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States 0 • Schiumberger Client:BP Exploration Alaska Well.L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 4: Stale 1 , Pro* .ed Frac: Job Messases Message Log Message Treating Annulus i Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 1 15:56:15 Deactivated Extend Stage 1269 31 430.6 0.0 0.0 2 15:56:15 Start PAD Manually 1269 31 430.6 0.0 0.0 3 15:56:15 Start Propped Frac Manually 1269 31 430.6 0.0 0.0 4 15:56:46 Stage at Perfs:PAD 2514 31 1.2 7.2 0.0 5 16:02:24 Stage at Perfs:PAD 4075 37 190.3 40.3 0.0 6 16:05:05 Started Pumping Prop 4148 44 298.3 40.2 0.0 7 16:05:08 Start 1.0 PPA Automatically 4156 44 300.3 40.3 -0.0 8 16:06:24 Start 2.0 PPA Automatically 4073 47 350.4 39.5 1.0 9 16:07:40 Start 3.0 PPA Automatically 3989 51 400.4 39.3 2.0 10 16:08:56 Start 4.0 PPA Automatically 3926 54 450.4 39.6 3.0 11 16:09:57 Stage at Perfs:3.0 PPA 3742 57 491.0 39.0 4.1 12 16:11:05 pH=10 3967 59 534.3 37.7 4,0 13 16:11:15 Stage at Perfs:4.0 PPA 3860 59 540.6 37.7 4.0 14 16:11:30 Start 5.0 PPA Automatically 3991 60 550.1 37.9 4.0 15 16:12:34 Stage at Perfs:5.0 PPA 4030 63 590.5 37.7 5.1 16 16:13:53 Stage at Perfs:4.0 PPA 4165 66 640.8 38.8 4.8 17 16:14:08 Start 6.0 PPA Automatically 4184 66 650.5 39.2 5.0 18 16:14:47 Activated Extend Stage 4079 68 675.8 38.0 6.3 19 16:15:12 CarboBond falling at POD 3522 68 690.8 34.0 6.3 20 16:16:12 Deactivated Extend Stage 4288 70 727.2 40.3 -0.0 21 16:16:12 Start BBS Pill Manually 4288 70 727.2 40.3 -0.0 22 16:16:26 Activated Extend Stage 4113 71 736.6 40.2 -0.1 23 16:16:32 Stage at Perfs:BBS Pill 4184 71 740.6 40.3 -0.0 24 16:16:43 ;pumping BBS pill 4183 71 748,0 40.3 -0.0 25 16:17:22 Deactivated Extend Stage 4207 72 774.3 40.4 -0.0 26 16:17:22 Start Spacer Manually 4207 72 774.3 40.4 -0.0 27 16:17:31 on clean for BB side 4241 72 780.3 40.5 -0.0 28 16:18:22 Start Displacement Automatically 4186 73 814.7 40.4 -0.0 29 16:19:01 Stage at Perfs:Spacer 4056 75 840.9 40.4 0.0 30 16:19:17 shutting down BB pump 3971 75 851.6 39.2 -0.0 31 16:20:22 Start Placement Automatically 3793 78 894.8 39.3 -0.0 32 16:20:36 Stopped Pumping Prop 3729 78 903.9 39.3 -0.1 33 16:20:57 Stage at Perfs:Displacement 3627 79 917.6 38.9 0.0 34 16:21:43 Activated Extend Stage 3930 82 947.5 38.9 0.0 35 16:22:05 Deactivated Extend Stage 3966 83 961.8 39.0 0.0 36 16:22:05 Start SDT Manually 3966 83 961.8 39.0 0.0 37 16:22:09 Stage at Perfs:Placement 2942 82 964.4 38.9 0.0 38 16:22:54 Activated Extend Stage 2520 84 982.2 14.1 0.0 39 16:23:10 Shutting down for ISIP 2299 86 985.5 5.6 0.0 40 16:26:38 All CarboBond is loaded in chief 1815 90 985.8 0,0 0.0 • s ,I o Client:BP Exploration Alaska Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 5: Stage 2, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Slurry Slurry Pump Max Prop Prop Step Step Name Volume Rate Time Fluid Name Fluid Volume Proppant Name Prop Conc Mass (bbl) (bbl/min) (min) (gal) Conc (PPA) (lb) (PPA) 1 PAD 300 37.7 8.5 YF128FIexD 12600 0 0 0 2 1.0 PPA 50 39.4 1.3 YF128FIexD 2015 CarboLite 16/20 1.4 0.4 1990 3 2.0 PPA 50 39.1 1.3 YF128FIexD 1944 CarboLite 16/20 2.1 1.3 3661 4 3.0 PPA 50 39.2 1.3 YF128FIexD 1868 CarboLite 16/20 3.1 0.3 5429 5 4.0 PPA 50 39.5 1.3 YF128FIexD 1798 CarboLite 16/20 4.1 1 7112 6 6.0 PPA 100 39.3 2.5 YF128FIexD 3346 CarboLite 16/20 6.1 2.1 20122 7 7.0 PPA 100 39.5 2.5 YF128FIexD 3228 CarboLite 16/20 7.1 2.5 22930 8 8.0 PPA 85.1 39.5 2.2 YF128FIexD 2889 16/20 CarboBond Lite 8.4 0 14124 9 BBS Pill 61.3 40,4 1.5 SFT Pill 2571 0 0 0 10 Spacer 40 40.4 1 WF128 1680 0 0 0 11 Displacement 80 40.2 2 WF128 3360 0 0 0 12 Placement 68.2 39.7 1.7 WF128 2866 0 0 0 13 SDT 27.5 25.2 1.6 WF128 1153 0 0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 37.7 40.1 3990 4217 1844 2 1.0 PPA 39.4 39.9 4151 4213 4101 3 2.0 PPA 39.1 39.2 4073 4102 4032 4 3.0 PPA 39.2 39.3 3988 4025 3945 5 4.0 PPA 39.5 39.8 3917 3945 3901 6 6.0 PPA 39.3 39.7 3958 4104 3889 7 7.0 PPA 39.5 40.2 4288 4467 4105 8 8.0 PPA 39.5 40.4 4543 4671 4401 9 BBS Pill 40.4 40.4 4458 4683 4331 10 Spacer 40.4 40.5 43694459 4236 _ 11 Displacement 40.2 40.7 3970 4227 3666 12 Placement 39.7 39.8 3672 3745 3590 13 SDT 25.2 39.8 2871 3745 1694 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 1062.1 28.6 41318 75368 Average Treating Pressure: 4055 psi Maximum Treating Pressure: 4683 psi Minimum Treating Pressure: 1694 psi Average Injection Rate: 38.7 bbl/min Maximum Injection Rate: 40.7 bbl/min Average Horsepower: 3871.4 hhp Maximum Horsepower: 4633.8 hhp • • Schlumberger Client:BP Exploration Alaska Well L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Maximum Prop Concentration: 8.4 PPA Section 6: Stage 2, Proofed Frac: Job Messages Message Log Message Treating Annulus # Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 1 16:30:10 Deactivated Extend Stage 1823 91 985.9 1.3 0.0 2 16:30:10 Start PAD Manually 1823 91 985.9 1.3 0.0 3 16:30:10 Start Propped Frac Manually 1823 91 985.9 1.3 0.0 4 16:30:10 Start Stage 2 Automatically 1823 91 985.9 1.3 0.0 5 16:31:28 Stage at Perfs:SDT 3482 94 19.2 27.1 0.0 6 16:33:40 Stage at Perfs:PAD 4017 99 99.1 39.9 0.0 7 16:35:21 Stage at Perfs:SDT 4099 105 166.5 40.1 0.0 8 16:35:56 Stage At Perfs 4125 109 189.9 40.0 0.0 9 16:37:02 pH=9.95 4186 114 233.9 39.9 0.0 10 16:38:40 Started Pumping Prop 4224 126 299.0 39.9 0.0 11 16:38:42 Start 1.0 PPA Automatically 4040 126 300.4 39.9 -0.1 12 16:39:58 Start 2.0 PPA Automatically 4110 138 350.3 39.2 1.0 13 16:41:15 Start 3.0 PPA Automatically 4025 150 400.5 39.3 2.0 14 16:41:35 POD gate check:good 3982 155 413.6 39.2 2.9 15 16:42:31 Start 4.0 PPA Automatically 3926 161 450.1 39.4 2.9 16 16:43:03 BBS batched up 3915 166 471.2 39.5 4.2 17 16:43:33 Stage at Perfs:3.0 PPA 3908 170 491.0 39.4 4.0 18 16:43:47 Start 6.0 PPA Automatically 3905 171 500.2 39.5 4.0 19 16:44:49 Stage at Perfs:4.0 PPA 3898 176 540.9 39.6 5.9 20 16:46:06 Stage at Perfs:6.0 PPA 4087 176 591.1 39.0 5.9 21 16:46:20 Start 7.0 PPA Automatically 4116 176 600.2 39.5 6.0 22 16:47:21 Stage at Perfs:7.0 PPA 4245 179 640.4 40.0 7.0 23 16:48:37 Stage At Perfs 4418 174 690.5 38.8 7.0 24 16:48:52 Start 8.0 PPA Automatically 4477 174 700.2 38.9 6.6 25 16:49:01 dropping fiber now 4540 173 706.1 39.4 7.0 26 16:49:17 Batch mixer C-pump good discharge 4600 171 716.5 38.9 8.0 27 16:49:30 CarboBond falling 4480 169 724.9 38.6 8.1 28 16:49:46 Activated Extend Stage 4611 169 735.4 40.2 8.3 29 16:51:01 Deactivated Extend Stage 4683 163 785.1 40,4 0.0 30 16:51:01 Start BBS Pill Manually 4683 163 785.1 40.4 0.0 31 16:51:09 Stage at Perfs:BBS Pill 4461 162 790.5 40.6 0.0 32 16:51:11 BB pill going down hole 4451 161 791.8 40.4 0.0 33 16:51:21 Activated Extend Stage 4334 160 798.6 40.4 0.0 34 16:52:32 Deactivated Extend Stage 4422 156 846.4 40.3 0.0 35 16:52:32 Start Spacer Manually 4422 156 846.4 40.3 0.0 36 16:52:43 BB side on clean 4442 155 , 853.8 40.3 0.0 37 16:52:50 cutting fiber 4412 155 858.5 40.5 -0.0 38 16:52:55 Stopped Pumping Prop 4385 155 861.9 40.3 0.0 39 16:53:32 Start Displacement Automatically 4196 153 886.8 40.3 0.0 40 16:53:38 Stage at Perfs:Spacer 4171 153 890.8 40.5 0.0 41 16:55:00 BB pump shutdown 3833 152 945.9 40.0 0.0 42 16:55:31 Start Placement Automatically 3593 151 966.5 39.7 0.0 43 16:55:45 Stage at Perfs:Displacement 3611 152 975.8 39.8 0.0 44 16:57:02 Activated Extend Stage 3737 154 1026.7 39.7 0.0 45 16:57:14 Deactivated Extend Stage _ 3752 154 1034.6 39.7 0.0 • • Schiuruberger Client:BP Exploration Alaska Wet:L-123 Formation.Kuparuk C District Prudhoe Bay Country:United States Message Log Message Treating Annulus # Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 46 16:57:14 Start SDT Manually 3752 154 1034.6 39.7 0.0 47 16:57:17 Stage at Perfs:Placement 3267 153 1036.6 39.8 0.0 48 16:58:38 shutting down all pumps 2172 153 1062.0 0.2 0.0 • • Schlumherger Client:BP Exploration Alaska Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country.United States Section 7: Stage 3, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Slurry Max Slurry Prop Prop Step Step Name Volume Rate Pump Time Fluid Name Fluid Volume Proppant Name Prop Conc Mass # (bbl) (bbl/min) (min) (gal) Conc (PPA) (PPA) (lb) 1 PAD 300 38.2 8.4 YF128FIexD 12600 0 0 0 2 1.0 PPA 50 39.1 1.3 YF128FIexD 2018 CarboLite 16/20 1.1 0.9 1917 3 2.0 PPA 50 38.2 1.3 YF128FIexD 1944 CarboLite 16/20 2.1 0.7 3670 4 4.0 PPA 50 37.9 1.3 YF128FIexD 1809 CarboLite 16/20 4.1 0.8 6818 5 6.0 PPA 100 38.4 2.6 YF128FIexD 3345 CarboLite 16/20 6.1 4.9 20137 6 8.0 PPA 100 37.7 2.7 YF128FIexD 3127 CarboLite 16/20 8.2 5.4 25300 7 10.0 PPA 50 37.1 1.3 YF128FIexD 1478 CarboLite 16/20 10.3 7.4 14607 8 10.0 PPA 76.2 38.8 2 YF128FIexD 2452 16/20 CarboBond Lite 10.5 0 15415 9 BBS Pill 126.4 39.9 3.2 SFT Pill 5309 0 0 0 10 Spacer 40 40 1 WF128 1680 0 0 0 11 Displacement 80 39.3 2 WF128 3360 0 0 0 12 Placement 70 29.4 2.5 WF128 2940 0 0 0 13 SDT 58.9 28.8 2.4 WF128 2475 0 0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step I Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 38.2 40.0 3793 3966 1694 2 1.0 PPA 39.1 39.8 3889 3965 3847 3 2.0 PPA 38.2 38.7 3818 3847 3780 4 4.0 PPA 37.9 38.3 3771 3787 3752 5 6.0 PPA 38.4 38.8 3857 4031 3752 6 8.0 PPA 37.7 38.7 4194 4391 4033 7 10.0 PPA 37.1 37.8 4434 4467 4391 8 10.0 PPA 38.8 40.0 4631 4787 4473 9 BBS Pill 39.9 40.0 4517 4794 4179 10 Spacer 40.0 40.0 4060 4180 3948 11 Displacement 39.3 40.2 3638 3936 3558 12 Placement 29.4 39.0 3043 3616 2684 13 SDT 28.8 39.9 3200 3820 1792 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (Ib) 1151.5 32.0 44536 87864 Average Treating Pressure: 3922 psi Maximum Treating Pressure: 4794 psi Minimum Treating Pressure: 1694 psi Average Injection Rate: 37.5 bbl/min Maximum Injection Rate: 40.2 bbl/min Average Horsepower: 3640,7 hhp Maximum Horsepower: 4664.0 hhp • • Schlumberger Client:BP Exploration Alaska r(7� Well:L-123 Formation:Kuparuk C District Prudhoe Bay Country:United States Maximum Prop Concentration: 10.5 PPA Section 8: Stale 3, Pro• sed Frac: Job Messa•es Message Log Message Treating Annulus I Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 1 17:17:26 Start PAD Manually 1905 116 1062.1 0.1 0.0 2 17:17:26 Start Propped Frac Manually 1905 116 1062.1 0.1 0.0 3 17:17:26 Start Stage 3 Automatically 1905 116 1062.1 0.1 0.0 4 17:18:33 Stage at Perfs:SDT 3340 118 15.0 27.2 0.0 5 17:20:40 Stage at Perfs:PAD 3778 118 94.8 39.8 0.0 6 17:22:23 Stage At Perfs 3846 126 163.0 39,7 0.0 7 17:23:04 Stage At Perfs 3903 127 190.1 39.7 0.0 8 17:23:04 pH=10.0 3903 127 190.1 39.7 0.0 9 17:25:41 Started Pumping Prop 3964 133 294.0 39.7 0.0 10 17:25:51 Start 1.0 PPA Automatically 3964 135 300.6 39.7 0.0 11 17:25:55 Sand is falling 3964 136 303.2 39.8 0.6 12 17:27:08 Start 2.0 PPA Automatically 3840 140 350.6 38.6 1.0 13 17:27:42 PCM swap L071 totes 3835 140 372.4 38.0 2.1 14 17:28:26 Start 4.0 PPA Automatically 3778 140 400.2 37.5 2.0 15 17:29:45 Start 6.0 PPA Automatically 3761 141 450.1 38.2 4.1 16 17:30:43 XL pH=9.9 3799 140 487.2 38.1 6.0 17 17:30:49 Stage at Perfs:4.0 PPA 3790 140 491.0 38.0 5.9 18 17:31:23 POD gate check:good 3906 140 512.8 38.3 6.0 19 17:32:05 XL pH=10.0 3973 139 539.6 38.6 6.0 20 17:32:07 Stage at Perfs:6.0 PPA 4015 139 540.9 38.6 6.0 21 17:32:22 Start 8.0 PPA Automatically 4064 138 550.5 38.6 6.1 22 17:33:25 Stage at Perfs:8.0 PPA 4116 137 590.5 37.7 8.1 23 17:34:45 Stage At Perfs 4379 135 640.5 37.1 8.0 24 17:35:01 Start 10.0 PPA Automatically 4389 134 650.4 37.3 8.0 25 17:36:22 Start 10.0 PPA Automatically 4469 131 700.5 36.8 9.5 26 17:36:28 CarboBond falling 4489 131 704.1 36.7 9.4 27 17:36:37 Activated Extend Stage 4550 131 709.7 36.9 9.7 28 17:37:25 Stage at Perfs:10.0 PPA 4578 129 740.8 39.6 10.5 29 17:38:19 Deactivated Extend Stage 4795 127 776.2 39.7 0.0 30 17:38:19 Start BBS Pill Manually 4795 127 776.2 39.7 0.0 31 17:38:41 Stopped Pumping Prop 4639 126 790.7 39.7 0.0 32 17:39:01 Activated Extend Stage 4719 126 804.0 39.9 0.0 33 17:39:56 Stage at Perfs: BBS Pill 4542 127 840.6 40.0 0.0 34 17:41:11 Stage At Perfs 4198 127 890.6 40.0 0.0 35 17:41:29 Deactivated Extend Stage 4149 128 902.6 40.0 0.0 36 17:41:29 Start Spacer Manually 4149 128 902.6 40.0 0.0 37 17:41:36 BB side clean 4107 128 907.2 40.0 0.0 38 17:42:25 10 bbls away on clean 3936 129 939.9 40.0 0.0 39 17:42:30 Start Displacement Automatically 3882 129 943.2 40.0 0.0 40 17:43:05 Stage at Perfs:Displacement 3591 128 966.3 40.5 0.0 41 17:44:32 Start Placement Automatically 3619 132 1023.0 39.0 0.0 42 17:44:41 dropping rate for BB pill on formation 3486 133 1028.8 37.8 0.0 43 17:47:02 Start SDT Automatically 2710 135 1092.6 21.1 0.0 44 17:47:03 Stage at Perfs:Placement 2703 135 1093.0 21.1 0.0 45 17:47:21 bringing rate up to 40bpm 3156 137 1099.5 24.4 0.0 • • Schlumberger Client:BP Exploration Alaska (j Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Message Log Message Treating Annulus i Time g Pressure Pressure Total Slurry Slurry Rate Prop.Conc. (psi) (psi) (bbl) (bbl/min) (PPA) 46 17:48:21 Stage at Perts:SDT 3021 138 1133.8 27.6 0.0 47 17:49:28 hard shutdown 2359 136 1151.5 0.0 0.0 48 17:51:36 ISIP 1884psi 1844 138 1151.5 0.0 0.0 • • Schlumberger Client:BP Exploration Alaska {J Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 9: Stage 4, Propped Frac: As Measured Pump Schedule As Measured Pump Schedule Ste Slurry Slurry Pump Fluid Max PropPro #p Step Name Volume Rate Time Fluid Name Volume Proppant Name Prop Conc Mass (bbl) (bbl/min) (min) (gal) Conc (PPA) (Pb) (PPA) 1 PAD 300 38.6 8.3 YF128FIexD 12599 CarboLite 16/20 0 0 0 2 1.0 PPA 50 39.3 1.3 YF128FIexD 2015 CarboLite 16/20 1.1 0.1 1991 3 2.0 PPA 50 38.9 1.3 YF128FIexD 1943 CarboLite 16/20 2 0 3677 4 4.0 PPA 50 39.3 1.3 YF128FIexD 1807 CarboLite 16/20 4.1 3 6872 5 6.0 PPA 100 39.4 2.5 YF128FIexD 3345 CarboLite 16/20 6.1 2 20152 6 8.0 PPA 100 39.3 2.5 YF128FIexD 3126 CarboLite 16/20 8.2 6.2 25320 7 10.0 PPA 100 38.6 2.6 YF128FIexD 2935 CarboLite 16/20 10.3 2.3 29810 8 12.0 PPA 112.2 38 3 YF128FIexD 3223 16/20 CarboBond Lite 12.5 0 30450 9 WF Flush 144 39 3.7 WF128 6048 0.2 0 0 10 Freeze Prot 31.3 23 1.6 Freezeprotect 1312 0 0 0 Stage Pressures & Rates Average Slurry Maximum Slurry Average Treating Maximum Treating Minimum Treating Step# Step Name Rate Rate Pressure Pressure Pressure (bbl/min) (bbl/min) (psi) (psi) (psi) 1 PAD 38.6 40.4 3775 3954 1792 2 1.0 PPA 39.3 40.0 3871 3954 3830 3 2.0 PPA 38.9 39.0 3808 3830 3776 4 4.0 PPA 39.3 39.6 3769 3788 3748 5 6.0 PPA 39.4 39.9 3886 4098 3752 6 8.0 PPA 39.3 39.9 4281 4461 4100 7 10.0 PPA 38.6 39.2 4597 4716 4468 8 12.0 PPA 38.0 38.5 4924 5114 4716 9 WF Flush 39.0 39.8 4931 5327 3766 10 Freeze Prot 23.0 32.3 3711 5515 2218 As Measured Totals Slurry Pump Time Clean Fluid Proppant (bbl) (min) (gal) (lb) 1037.4 28.1 37041 118272 I Average Treating Pressure: 4203 psi Maximum Treating Pressure: 5515 psi Minimum Treating Pressure: 1792 psi Average Injection Rate: 38.3 bbl/min Maximum Injection Rate: 40.4 bbl/min Average Horsepower: 3960.1 hhp Maximum Horsepower: 5137.0 hhp Maximum Prop Concentration: 12.5 PPA • • Schlumbe tiger Client:BP Exploration Alaska u 1 �j Well:L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 10: Stage 4, Pro. sed Frac: Job Messages Mess.!e Log # Time Message Treating Annulus Total Slurry Slurry Rate Prop.Conc. Pressure Pressure (bbl) (bbl/min) (PPA) (psi) (psi) 1 17:56:48 Start PAD Manually 1792 135 0.0 0.0 0.0 2 17:56:48 Start Propped Frac Manually 1792 135 0.0 0,0 0.0 3 17:56:48 Start Stage 4 Automatically 1792 135 0.0 0.0 0.0 4 17:59:12 Stage at Perfs:PAD 3743 139 61.7 40.2 0.0 5 18:00:56 Stage At Perfs 3797 141 131,1 40.0 0.0 6 18:01:47 XL pH=10.0 3836 143 165.1 40.1 0.0 7 18:02:24 Stage At Perfs 3883 145 189.8 40.0 0.0 8 18:05:05 Started Pumping Prop 3957 151 297.0 39.9 0.0 9 18:05:10 Start 1.0 PPA Automatically 3954 151 300.3 40.1 0.4 10 18:06:26 Start 2.0 PPA Automatically 3825 152 350.0 39.0 1.0 11 18:07:43 Start 4.0 PPA Automatically 3775 153 400.0 39.1 2.0 12 18:08:07 XL pH=10.0 3780 153 415.8 39.6 4.1 13 18:09:00 Start 6.0 PPA Automatically 3744 153 450.5 39.5 4.0 14 18:10:01 Stage at Perfs:4.0 PPA 3809 152 490.7 39.1 6.1 15 18:11:17 Stage at Perfs:6.0 PPA 4071 152 540.4 39.4 6.0 16 18:11:32 Start 8.0 PPA Automatically 4122 152 550.2 39.1 5.9 17 18:11:48 XL pH=10.0 4185 151 560.7 39.0 7.6 18 18:12:33 Stage at Perfs:8.0 PPA 4228 150 590.3 40.0 8.0 19 18:13:24 POD gate check:good 4384 148 623.9 39.3 7.8 20 18:13:50 Stage At Perfs 4442 148 640.8 38.9 8.1 21 18:14:05 Start 10.0 PPA Automatically 4479 148 650.5 39.0 8.0 22 18:16:25 Stage At Perfs 4682 143 740.6 38.3 10.2 23 18:16:40 Start 12.0 PPA Automatically 4703 141 750.1 38.5 9.9 24 18:16:55 CarboBond falling 4760 142 759.7 37.7 10.7 25 18:17:02 Activated Extend Stage 4816 141 764.1 37.7 11.3 26 18:19:03 Stage At Perfs 5026 136 840.7 38.3 12.1 27 18:19:37 Deactivated Extend Stage 5142 135 862.2 38.4 0.1 28 18:19:37 Start WF Flush Manually 5142 135 862.2 38.4 0.1 29 18:19:43 Stopped Pumping Prop 5198 135 866.0 39.0 0.0 30 18:21:36 Stage At Perfs 4949 131 940.4 39.6 0.0 31 18:23:20 Start Freeze Prot Automatically 3567 130 1006.4 29.5 0.0 32 18:23:26 feathering in LVT 3415 129 1009.3 26.9 0.0 33 18:23:32 on LVT 3371 130 1011.9 25.8 0.0 34 18:25:29 down on pumps 2843 126 1036.5 0.0 0.0 35 18:25:44 LVT at WH 4659 2729 126 1036.5 0.0 0.0 36 18:39:39 bleeding down IA 2206 115 1037.4 5.6 0.0 37 18:43:02 cleaning BB side 2022 -9 1037.4 5.6 0.0 • • SchIurnbeger Client:BP Exploration Alaska Well,L-123 Formation:Kuparuk C District:Prudhoe Bay Country:United States Section 11 : Post Job Plots Pressure Test — Treating Pressure BP Eaepsatatlar Masks ^^–^+ Annea/us PrI10,04r. N-8111-761i - Slurry Rate 8000 - Prop Consent.eteon 20 6000- 15 a O. 'a 4000 . la X 3 I 2000 e to 44"1- i 13_48:23 14:00:53 ` 14:15:23 14;23:53 19:33.23 ?Y1114-INr:mm:li • • Schiumberger Client:BP Exploration Alaska Well:L-123 Formation,KuparukC District:Prudhoe Bay Country:United States D•toFrrc -- 'fronting Profanity. BP i wWyrawl&AMsikA L.913 Annnrus Pressor* a7 on ee96 --- tiii Presort. -o— Stony Roof 6000 - Prop t oncenttation --• tiff t'Fnix. aroma.gnrt+4{ff ri ' -SO 5000- 40 7O 4000- �pj 9 304 3000 a. _.._.__...,..-_. .,._.._....._ ... ._ 20 # 2000" 23 p a 1000 1ti J ____ . 14:30:14 14:57:04 15:17:54 15.38:44 15:59 34 Time-hh:mm:ss Main T atrii0flt ..— Treating Pressure &w r ArmlOf AltitAk Malaita Annulus Prossurs 0't 27 t39-f}ri.stet ...... 6H PIt9+}9lfcH .m1*+ Slurry Rate B Pta,Coto;entration 7000 -- ski P,, ff.rr : -- Pal Vai.aairy S0 : rlt .. . . R -40I aet• : r4 _risil\I 300 o. 20 1 2000- 1 10 e1 1000- Ai NI er er A e.dm"IP pomp III/am rwo.MUM MIMI/MM.4ii AMU Imo momms moo 1 15:51:34 18:41:34 17:31:34 = 18:21:34 18:11434 Time-hh:mm:se IIMMINIMIL S 0 Scffiumb '-i '1 er client BP Exploration Alaska Well L-123 Formation.Kuparuk C District Prudhoe Bay Country:United States POD Additives OetsFrec BP Exploration Alaska •••••••-• Shiny Rake L-123 01.4164016 ..-.. ,•,*440 1.tiki -••••••••• Prop t'Ain SO , •••••••• J4,O,Avg(„mit - 12 110 — 0028 100 ---- k, 1,s, ,a>,= ',, •"--- Deck Gate% 40. 90 4n 9 a., V. 80 i i 4 g I li 10 30• ..„W ! 60 6 1 50 r 20. CI at Vt ! a 40 10-1 L i 3 ...... 3 ..' P. 30 20 10 0 0 14:42:12 16:0.3:02 16:23-52 16-44:42 16:06-32 Time-hh-mill:es POO Additives Main Treatment 23 . ..,.................---- JE:PS:unYeip4eloe7pcs5knAcivi::naulttec:cd: . 11.:*'!"-Pilcs.2°111:43on20 iklaska 60- - - -100 — .1004 --- U028 -90----- t,-,,, ,..s.,.:,...att.9,---0 40. 16 5"; •80 ,; , 1 114 •70 30 1 14110 id9 12 4" ... a 3- - IL SO I 0 Ao t 1 I r cc ,", i 8 :o.go ,•3400 ,3.i.- M v .4 = CO _..---. _. .-........... NM lir .10 0 -0 16:60;06 16..21746 1713:26 11,46:06 18:36-46 MTh!.hh:Mft1;SS • 0 Schlumberger oient.BP Exploration Alaska WellL-123 Formauon Kuparuk C District Prudhoe Bay Country United States PCM Additives DateFree ki0 l X144,14Ittatt AlismIt a ...m. Slurry KM* I 171 01 PS 7010 ..... Claim IF Iu4d Rote - 14..1.1 VIscottatv *cll.., 50 , — ' 40 -10 --- 1011 coitc 40 30 1 30 0 6 1 o W , , g * 20 042' i 411111° r• o % . , g („--J 20 0 w • 4 r> 10 1:1 10 2 ii , it , 0 o 0 Yin,. ...me.sni ....... Slurry Hata PCM Additives Main Thiatinent -- (loan 111.*10 Hato kiP ExpIorarkem Atalka L.113 PCM ViAr ily kti mA Awl q - L071 Com' 50 — , , ---,-- ...... ___ 40 10 36 40 ' 1 -8 r -30 = 26 0 r- 2 30 o 6 -5- o W n )0 g , 20 -C3 eo O. cs eel o = . < o M , • Di d 20 0 4 vo 16 0 el In w 3 V. 10- 2 r, j7.1y611111:4141 '1100011/41.000.0' 5 i f 1 II 0 It la 2s It za ot . is 28cfs • • I I 1 I 11 111 II co c a) E E -' O :J 0 4.0 4. n V — CO 0) CC) N r N In `� ,.1 _ * CO o N CO ami o CO in CO o CD E C O -C ao LO N N N .,- 000 CO C a) co, .5 o 00 CO O O O 0 0 0 O g (1) E i5 ,- il E X C (l :x i LisA 0)C = moo z t O °� CZ _o 0 u co co I r E c O O O . c, c2 c7 N V . a) -� ,> ca rn T o 0 0 0 0 to 'C E L -= E X N c -O D V CC oQ O � a( ' 61 5 U4.11RfE .- (i) _o E u) cr opL aU CQ W r O T O N O Lcz 0 - Z co d- o _ c%) V W NNc7 en u) opM� U Q < 71- O V O N CO N O O LO Z ,c) CO M c r N. n) r 4... 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Q co T O as C E mu) O Z d N a m Q` iU m 0 ro 3 o E 0 > m E DI o CUOj-o�o� 0 CD 0 a; 0 C 0 E - _ ma) 'L as cz co c _o E � 73 � cg c � `2 --,- m a) o -0 0 _ ? _ '•fsa � � a) 0u- a 0 c° c Z O Z 0 -JE > co ip CD (!} Lu CL ca D J U = N CI E L ID -O Q a) as Ta •-r- > '1' 0 7 Q a) - > z co CD ca 0 0) ca Q V i a) m Z LL. it Z tL E ) a) m vz u) I m m a -0 o 13 -FS CZ L mET O T F coN I 2 } ! 0 111111111111111 II 111111 11111111 II I I II u) N -) U) L, U) r a M (u N N N N N i.n IC) v u C) L, u) (U u) U) CO (u u) v CO CO 10 N CO N CO M CO CO CO O) CO N CO COo O 0) N CO 0 0 0 0 0 0 0 O O O O CO CO CO N N- CO CO M COM V N N(C) 7 M O O 0 0 0 0 0 0 0 0 0 0 0 0 0 00 O O 000000000000 000000 00000000 O O O O O O 00000000000000000 000000 00000000 O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O V 71' V V 7 r d' N ,- .- r'ln CO LC)-(n O .- CO 0-0 V N (O O-(f) 0) ,- (0 '(O CO ZO O O CO (O CA O N O O O) N (O V CO N N N O) CO O) O) N (1) N O O) CO N V V' CO N N CD V CO 0) V O) (0 r r (t) 0) 0) O) O) CO N (D V CO N O O 0 0 0 0 0 0 0 0 O O O O O O N (O CO CD M M M C) CV 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O O O O O O O O O O O O O O CCCCCC O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O N (O M O V CO CO N CO co 7t. O r d D O N 4- O) N . . O' (. N co LO CO m M O CO (O O h co O (t7 M O ^ 7 (C CO O O M CO (p (� O N O (`7 CO CO CO M M CO CO CO O M O (O (t� O O O N V CO O CO N.M co C CO N 7 41 M r c1) r ('O N co V CO M N N N V CO N M p MO d' N CO 7 M CO M N. (:) I� co co O O) CO O O) O M N V V' V (O (f) O n N N O O N O, N O) t() O) O CO O CO 'V O O O O O N CO O) CO00 A (O V CO C` - NM O O COCV N LO N N N r o') CO CO CO M CO CO CO O r O h co co V COC COO O co N M N V CO N V N V O O V N r ,- r r CO N. r r N. C) r N. col r r r C)) (Si N. IC r N N r r r CO CO r (C, L U r -C Q) �, O 3 -0 L v -rsc(v CO a) >, N C N U C �. >, C N N N r CO� N _E O c O c O >. >. O t X a O (0 "O _O N 7 O a M (On >. N.,? U O >+ r oQ� o73 m o 0CD 0 t m E o t N o E o CL r a x m o -00 m C NCD N -OO N E N CD 06 O (4 N x0 �" L N N_6 o 9 '� �'N N E T "O ._�.. 0. O 5t o c -a m "' E o a v _� o o CD > c`o u7 1E rn E` `a x o Q �• C = 0 x x O .O N O C = C 2 L O Q) `p O L [4 O N O -� O p Q V O N L r LO 2 O 0 a) o O a E a c6.0 u) C ,6 L o O N U u) L .N 0 E C °.0 r-> U«. Q O O oLmE oa-5 0 >, mro _c,, 0 oc _o � E29 - C _oEEE " No_ 2Eoon ��_s^� � ` c c Q C O N ]. _ . o U 'O U o 7.� O T' '5 (6 N o o 7 E -- N E C N N -O (6 N Q F cu a) E c x v, E () o m () O o 5 w 5, >. _ p O'� .N 2 7, ay ay N c C 3 >`o E v > 0 c 'O O Ca O LO N = c = _C O 'U N U as o O a O '.O C C 5 O X CD O - C C coCu) N V YO N C-o-4 0 ,- L- 0, 0-00 O- w E "0 _C L S O .O U O O O E O c0 O O O N 7 .0 L E c4 (4 2 N >. V.J (6) ZP S N N _ @ N U m p (6 Q N S] N u)> U U 0 N Q U (9 2 (/) < S/) 0 LL 07 2 0 r C9 E O Q 75° 9 U x x O ) V o>.2,2 L Q O Q m� � v (v Cl. (n 2 � O a,(� Q U C7 n r� ) _ m m a, o.Q U N S S / CD\ 2 � ci a) 3 9 2a- -0§ vu) / _§ cp�/ 42- / CO \ ), ° EI i )'/ ) / $ K %% a E0 j K{ W g 0 .as co c_c \/ «_ 2 § 0 730 22 0G =q \f }- /� -/ k8 1-11 o _c )q \\ \7-3 7E # : E 3a � /) fi aE §/ c ) 0 �\ o E) >2 \c ciE §/ ƒ{ 8 0\ J\ ) A Z_ TREE= 4-1/16'aw — • VVB_LFEAD= FMCNOTES:I-QS READINGS AVERAGE 125 ppm ACTUATOR= LEO L-1 2 3 WHEN ON MI.WELL REQUIRES A SSSV WHEN ON KB.ELEV= 750' ML"'WELL ANGLE>-70°ta 10584'*" BF.aEV= 49,6' 1 il 1 --- -- KOP= 400' 1 ! Max Angle= 94°@ 1196.2 Datum MD= 7684' I I r 2827' H4-112HES X NP,ID=3.813^ Datum1VD= 6600'SS? l _A . 1 GAS LFT MANDRELS 9-5/8"CSG,40#,L-80 BTC,13=8.835' — 3644' , • ST MD ND DEV TY FE VLV LATCH FORT DATE 2' 3594 2590 57 KBG2 DMY BK 0 03/29/06 1 6641 4130 1 58 KBG2 DMY BK 0 11/15/15 • 8697' —7"FES ES CEMENTER Minimum ID = 3.725" @ 10500' 4-1/2" HES XN NIPPLE D 0438' 1-4-1/2"FE.S X MP,ID=3.813' 10488' HIT'-x 4-1/2"BKR S-3 RKR,ID=3.875" 0.1 , , P1-' 10480' —14-1/2'FES X MP,ID=3.81r 1 1 1 10600' —14-1/2"I ICS XN NIP,ID=3.725" ' , 1 ! ! 10527 —17"X 5"BKR HAD ZXP LNR TOP PKR, I w TIEBACK SLV,ID=4.410" f, 4-1/2"TBG,12.6#,L-80 TCS, 0152 bpf,D=1958" — 10523' ) ( 10823' —4-1/2'WLEG,ID=3.958" I MI i 6 10542' —Rs RACKOFF SEAL NIP,ID=4.250" I I 10844' H X 5'BKR F1MC LM FINGR,ID=4.41" 10554' —5"X 4-1/2'X0.13=3.98' ! 10889' ---I4-1/2"RA MARkER.77-- BKR WHFSTOCK(12/29/05) --1 10723' MIL LOOT MOON(L-123) 7"FES EZSV(12/28)05) — 10743' 10723' -10736' i 7'CSG,26#,L-80 BTC-M,ID=6.276" — 11393' i 11111011111 PERFORATION SUIMARY 11277' 4-1/2"RA REF LOG: MHD ON??/??P? MARKER JT ANGLE AT TOP FERF-. 940©11830' lib Note:Refer to Production 08 for historical pert data rtivttivirirrt SIZE SPF fsTTERVAL Opri/Sqz DATE 0.......f.. ••••••111,44 2-7/8" 6 10915-10960 S 12/05/15 2-7/8' 6 10975- 11090 S 12/05/15 \ 12362'CTM FISH:MLLED 2-7/8' 6 11110-11140 S 12/05/15 \& CBP(12/19/15) 2-7/8' 6 11180-11210 S 12/05/15 2-7/8" 6 11830-11850 0 01/03/06 2-7/8' 6 11945-11980 0 01/03/06 2-7/8" 6 12030-12080 0 01/03/06 2-7/8" 6 12150-12190 0 01/03/06 2-7/8' 6 12270-12300 0 12/30/15 2-7/8' 6 12270-12340 0 01/03/06 FBTD H 12361' Alava__ ‘4,11...viir vir 4-1/2'LiP., 12.6#,L-80 ET-M, 0152 bpf,13=3.958" H 12405' '111166 DATE REV BY COMAENTS DATE REV BY COMMENTS BOREALIS LINT 01/07/06 N9EE ORIGINAL COMPLETION 01/07/16 ALAVIC Md.CMT/C8PIADPERFS(12/30/15) WB_L: L-123 11/12/06 RAC/TU-1 GLV PORT SIZE CORRECTIONS PERMIT No-. 2051940 02/15/11 M3/JM) ADDED SSSV SAFETY NOTE API No' 50-029-23290-00 01/18/12 7M4/JAC ADDED Ff2S SAFETY NOTE SEC 34,712N,R11E,2748'FM_&3845 Fa 11/25/15 TBD/JM) GLV GO(11/15/15) - 12/23/15 I ALIVIJIM SQZ FERFS(12/05/15) EP Exploration(Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,February 10,2016 TO: Jim jZe gg ( �I1( P.I.Supervisor SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-123 FROM: Chuck Scheve PRUDHOE BAY UN BORE L-123 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-123 API Well Number 50-029-23290-00-00 Inspector Name: Chuck Scheve Permit Number: 205-194-0 Inspection Date: 2/7/2016 Insp Num: mitCS160208064842 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-123 Type Inj G 'TVD 6348 Tubing 3162 3168 - 3177 - 3184 • PTD-- ---- ---- - --_. 2051940 - Type Test SPT Test psi 1587 IA 639 2502 - 2492 2491 - --- i --- -I 124 --- 227 ---227 230 Interval4'TST - P/F P OA Notes: SCNNED SEP 2 6 2016 Wednesday,February 10,2016 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, February 08, 2016 11:10 AM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead;AK, OPS Well Pad LV; Shrider, James; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: OPERABLE:Injector L-123 (PTD#2051940)AOGCC MIT-IA Passed All, Injector L-123 (PTD#2051940) passed an AOGCC MIT-IA to 2500 psi on February 07, 2016. This passing tests confirms two competent barriers. The well is reclassified as Operable and may be kept online as needed. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GW scAtitiED MAY 1 9 2016 WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: A , &C Well Integrity Coordinator Sent: Wednes , ebruary 03, 2016 11:49 AM To: AK, OPS GC2 OSM; K, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C-Wireline Operations Superintendent; AK, D&C Well Services Operations Superintendent; AK, RES GPB East Wells Opt Engr; AIS;RES GPB West Wells Opt Engr; AK, OPS PCC Ops Lead; AK, OPS Well Pad LV; Shrider, James; 'chris.wallace@alaska.gov'` Cc: AK, D&C Well Integrity Coordinator; AK, D& D Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pe Whitney; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; 'Regg, James B (DOA) (iim.regg@alaska.gov)' Subject: UNDER EVALUATION: Injector L-123 (PTD #2051940) P on Injection for Compliance Testing All, Injector L-123 (PTD#2051940) was due for its AOGCC MIT-IA in July of 2014 and is now reay to be placed on injection. At this time,the well has been reclassified as Under Evaluation to facilitate compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1 �� 4- io • C tr r; _ o�W a) u 3 w u opm o Q °' _1 " � h ¢pryS O f.., CU L J Z".. 01) Y 1- W []- a1 J O 0 'D 1-- fD += (O >. Q a CI Cra J l7 .�- r ra O v E _E m 1- Q F' O V N N a) C C4-1 " .L C C m - 2 J.0 0 0 0 ' 1 E +' CO WCU N H O 'V Of N CC _O Q > V z Q. N N C r0 a1 Q a) 2 CtO _O E O >- I-<I CC a) a) u .1-' ) - 0 0 0 0 0 0 m N U d J J J J J J L W W W W W W pCp is O p H U. LL LL LL LL LL " a1 E - N 0 a Q Q Q Q Q Q O_ (D C Z a) a z z z z z zv, v,a) • 0 LL LL LL LL. LL LL a) -C a) Q 0 - > y u O , u5 Y � O O �.: E a) Q) W c o CO c a V 0 a a > > c O j 2 v °roLI/ w N s > a cwt it • L O o ►= U F- U o W 0) 0 0) 0 a 0 cn W 13 V • J. 0 J 0 J E C E. O c 0 co 0 ) a co U LU Q G4 al ° -0 � # ro aor z ,x m co W O T T T 0 al co — F < c' ._ w,o4 tu V > 0 N J \ t"..,4). 111r. 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E mcql Ma) co U >J O zs M'I R1 V a) W 0 Q Al a o kr" . . 11 LLI 1 x (-- w • >, > > L to3M J▪ � o > EEEE zi E Z� a> a) a a a coMw ---..""Ilr. ._Vir#11 S >- >- >- >- >- Q Q Q Q Q m m m m m N W W W W W ...- O 0 0 O O W 2 2 2 2 2 ix 0 0 0 0 0 0 I v = MDDDLL' Q' Q' Q' CC m O.. a a a a c t) m ) v} n0.; IA W o m N 'CI' X N C CO u' LO o o a 00 mm ‘7., �' ° 0 0 0 0 C. o ,g.,'"'w 1 ° 0 0 0 0 0 - m di ra > omo >- >00 ID Z X E Q 0 0 0 U 0 U ai C0 b.0 X > ro 4 a o O O O O m L (D O O O O O O U 0 N ON 61 N O 4.. Q T N CD CO N- a) N NCD N N O O 0 0 ,,,, > N Q N r O N COM '6 N N N N N N N pp n O O 8 O T O •E c 0 N N N N N N N 0 01 O O O O O O C v, O 0 0 0 0 0 illc U) I)) UC) )f) U) )f) i+ y m r a OE C ' O W w W ,n u CD U aJ Q g E E a ac y Q m v al we Rl z M O O N N r a+ _= d Q N -J. X 0 - O J E Z w U :r.W' c _ 0 CD c n. a fO m n tioFTir. • • ,§)" X77. ,v THE STATE Alaska Oil and Gas ►,;.-s� � ;� of tAsKA Conservation Commission S - 2 333 West Seventh Avenue o �- ht GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS'' Fax: 907.276.7542 www.aogcc.alaska.gov David Wages MMMU DEC 0 2 2015, Well Intervention Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Q95— C Lid Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, BRLS L-123 Sundry Number: 315-678 Dear Mr. Wages: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this day of November, 2015 Encl. RBDMS DEC 012015 STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMON APPLICATION FOR SUNDRY APPROVALS NOV 0 2 2015 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate RI - Pull Tubing D Operations shutdown 0 Suspend ❑ Perforate Dy '""Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well p ❑ Re-enter Susp Well 0 Other Coil" Si 4 tcc-2 <- [ 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 205-194 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service p 6- API Number: 50-029-23290-00-00 . 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No Iva BRLS L-123 - 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028239 - PRUDHOE BAY,BOREALIS OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12405 " 6480 - 12361 6482 Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20"215.5#A-53 30-109 30-109 Surface 3615 9-5/8"40#L-80 30-3645 30-2618 5750 3090 Intermediate 11366 7"26#L-80 27-11393 27-6519 7240 5410 Production Liner 1883 4-1/2"12.6#L-80 10523-12406 6378-6480 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 25-10523 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program Q Exploratory 0 Stratigraphic 0 Development 0 Service RI 14.Estimated Date f r Commencing Operations: 15. Well Status after proposed work: 7(10 LI, 3 2_6 t ) Oil ❑ Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG H ' Abandoned ❑ Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Wages,David Email David.Wages@bp.com Printed Name Wages,David Title Well Interventions Engineer Signature Phone 907.564.5669 Date /0 ' 7 2,6 (5 0 t) 51,-.':'.77-7, , COMMISSION USE ONLY Conditions of approval:Notify ommission so that a representative may witness Sundry Number 31 5 7 QTY^ ' Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: TOS 1 i'f d e,„ v fAcci 'J--o l'e4Q. FatC, FOGv j Ofe...4144.G(J C.1 www. C.fi .mss . or� efus tM ,o—oc rc ,r. ie. 's or 20 AftG 2S 2.3,g (.3Spacing Exception Required? Yes 0 No V f/Subsequent Form Required: I 0— 4-0 4- aVAPPROVED BYTHE Approved by: P COMMISSIONER COMMISSION Date:/r ,L �� '' `�— f- ."4,�� RBDM DEC 0 12015 0 R INAL �Jr 07/13' (l.•z� r� - Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate w N f0 m CO LO in. NJ- CO N- CJD CO n, 00 O(DCO _ Nt o) O Nt 00 N O• M O O (0 (0 (0 (0 O O 2 0 I- M 0) - LO M CO OO IC) t LON CO C) '- N CO N d' fl M N M I� M 0 0 d CO CA v- N O CD CO CD OD W In LC) L() V > CMCOMMUDMMMM 0 W � O O O W z w F � a 0 g g Y U 0 > 00 W Y Y g 0 0 0 O O O O O O - - J U U W z W r CO ) .qLo OD 00 CA J J J Q Q (/) W CL' O) O N 00 0) 40 ,- M Q < < w d 0 Z W w 0 0 CD cyo Q Q Q as o a a U U• imz U 0 0 0 I- 0 Lu 0 W W Z O Z � N2220c' ctcc/ ou¢) < J ,2 c (n r LCLc) 000Ia000 _ d A M CI.°O J d rnrn � 000 � N • no' C 0 O N N N y d L O G! U7Y = N I d J d z 2 2 O co co co co co o. 0 U c E W W W W W W W W W w 0_ 0_ 0_ aaaaaa. 0_ 0 t d a o cocoo0m0cocoo 0 0 000000000 C 000000000 0 N N N N N N N N N z W W W O. � = � � Z CL 0 1.11 o J J LL w cc O CO O D W J -1 .7t- O W W < < a CO LL LL Cn (1 W' m E m M M M M M M M M M S N N N N N N N N N W a co 0 LL N CC LL_ i i i i i CO a CL 0- 0 J J J J J J J J J J < < CO CO L_ LL co co a LY s • Packers and SSV's Attachment BRLS L-123 SW Name Type MD TVD Depscription L-123 TBG PACKER 10456.56 6348.26 4-1/2" Baker S-3 Perm Packer L-123 PACKER 10534.55 6382.37 5" Baker ZXP Top Packer • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AFFIDAVIT OF NOTICE OF OPERATIONS Before me, the undersigned authority, on this day personally appeared DcW0 A z°5 , who being duly sworn states: U 1. My name is David Wages. I am 18 years of age or older and I have personal knowledge of the facts stated in this affidavit. 2. I am employed as an Engineer by BP Exploration (Alaska) Inc. ("BPXA") and I am familiar with the Application for Sundry Approvals to stimulate the L-123 Well (the "Well") by hydraulic fracturing as defined in 20 AAC 25.283(m). 3. Pursuant to 20 AAC 25.283(1), BPXA prepared a Notice of Operations regarding the Well, a true copy of which is attached to this Affidavit as Attachment 1 ("Notice of Operations"). 4. On October 6, 2015, the Notice of Operations was sent to all owners, landowners, surface owners and operators within a one-half mile radius of the current or proposed wellbore trajectory of the Well. The Notice of Operations included: a. A statement that upon request a complete copy of the Application for Sundry Approvals is available from BPXA; b. BPXA's contact information. Signed this 7❑d day of October, 2015. a (Signature) STATE OF ALASKA THIRD JUDICIAL DISTRICT Subscribed and sworn to or affirmed before me at 41,\ ,t1Y-k-fie._ L on the day of CX-/r„ 11Pf ,$tl1111IIIIUgy,, •Q��E Jo?0 Signature of Officer ° `ry% <S-r0-te digs ISTOT '• Title of Off er .r* P 16 c 2b„ow OF kijk5. 2eM1e . i1 111 • • Wellwork Procedure Request To: Well Services Operations Team Lead Date: 9/30/15 Wireline Operations Team Lead VER1 AFE: APBFRACS From: David Wages -Well Intervention Engineer Tyson Shiver-Well Intervention Engineer IOR: 200 Est. Cost: 1,300K Subject: L-123i - Pre and Post Frac Procedure Please perform the following steps 1. S/F D&T, Pressure survey, Set Plug, install circ valve, circ packer fluid, install dmy valve, MIT-IA, MIT-T, Pull Plug 3. C D&T, Set Bridge plug, Squeeze perfs - -" 4. C Mill Cement/Plug, Perforate 6. F/S Injection Test w/mem. gauges on slickline 7. 0 Install Tree-saver, Hydraulic Fracture Treatment 8. C/T Post frac FCO, Flowback well 9. S Install MCX 10. F MI Injector, AOGCC witnessed MITIA to 2000 psi. Current Status: Shut-In Minimum ID: 3.725"XN Nipple @ 10,500' Max Deviation: 94 deg at 11,962' MD Top Perf Deviation: 80 deg at 10,915' MD Last TD Tag: NA well angle > 70deg at 10,678' MD. Last Downhole Op: 8/28/2011: Brush and flush to 10,683', Caliper from 10,550' SBHP/SBHT: 8/28/2011: 3510 psi and 161F at 6600' TVDss datum. Latest H2S: N/A Program Contacts Contact Phone-Work Phone-Mobile/Home Interventions Engineer David Wages 907-564-5669 713-380-9836 Interventions Engineer Tyson Shriver 907-564-4133 406-690-6385 >Latest slickline run was able to get to 10,683' Page 11 of 7 • • 5# e D&T, Pressure survey, Set Plug, install circ valve, circ packer fluid, install dmy valve, MIT-IA, MIT-T, Pull Plug 1. Drift to deviation w/ -3.6" OD toolstring and TEL • OD of bridge plug: 3.4" 2. RIH and obtain a static pressure survey . • Per request form in SOR 3. Install plug in XN nipple • Records indicate pressure rating from above: 5920 psi 4. Install Circ Valve in Sta 1 @ 6640' 5. Circ 9.8 ppg NaCI Brine • Wellbore volume from Sta 1 to surface: 225 bbls; IA vol: 124 bbls • -5bbl methanol or crude spear as required • 225 bbls 9.8 ppg NaCI w/corrosion inhibitor • 17 bbls crude or diesel for freeze protect • U-tubed IA and tubing to equalize 6. Install dmy valve in Sta 1 at 6641' 7. MITT to 4000 psi • Do not hold pressure on the IA, must have a differential of 4000 psi per AOGCC requirements 8. MIT-IA to 4500 psi • Hold 3000 psi on tubing during MIT-IA 9. Pull XN plug 10. Obtain 5 BPM injection pressure and record in AWGRS Futibctre Assist SL w/ NaCI circ, MIT-IA, MIT-T 11.Wellbore volume from Sta 1 to surface: 225 bbls; IA vol: 124 bbls • -5bbl methanol or crude spear as required • 225 bbls 9.8 ppg NaCI w/corrosion inhibitor • 17 bbls crude or diesel for freeze protect • U-tubed IA and tubing to equalize 12.Assist with MIT-T and MIT-IA and injection rate Drift to PBTD, Set CBP, Squeeze perfs, Mill CBP, Perforate Page j 2 of 7 • • 13. Drift to PBTD with GR/CCL for depth control and -3.6" mill or nozzle • OD of Baker CBP is 3.4" 14. Set Composite Bridge plug @ -11,300' • -90' below bottom perf to be squeezed w. 15. Obtain 5 BPM injection rate with fresh water and record in AWGRS • To be compared with rate pre-bridge plug Footage (top to Feet of Total # of Volume (top to Volume (top to bottom perf) perforations perfs bottom perf), bbls bottom perf), gal 295' 220 1320 4.5 190 Max pressure: 3800 psi (95% of MIT-T) 16. RIH w/ nozzle to Bottom perf 17. Reciprocate acid across perfs • 18. Squeeze acid into perforations, over displace with 10 bbls of fresh water - • Max Rate: 1 bpm with acid on perfs, 5 bpm when pumping water in perfs • Obtain 5 BPM injection pressure with the over displacement and record 19. RIH to 11,210' Cement Details: Type Weight, ppg Fluid Loss, Thickening Time, hrs 10sec/10min Gel cc/30sec strength: Class G 15.8 (-1.15ft3/sk) 300-400 4+, discuss with WIE <100/<500 20. Pump fresh water spacer u<s7.____semis caught then swap over to cement • Est. Cement volumbls21. Lay in cement to cover per - 00' 22. Squeeze perfs per RP • If unable to catch pressure with cement in perfs, hesitate to allow gel strength to build. 23. POOH ,t ' f.FWS e rr f Mill Cement, MIT, Perforate 24. Pick up milling BHA for 3.958" ID tubing 25. Continue to mill though cement past bottom perf 26. MIT the perforations to 4000 psi - • MIT does not need to pass per the group practice, we just want to make sure when we frac, our fluid is going to the toe, Discuss with WIE. 27. If the MIT passes, continue to mill up the bridge plug and push to TD 28. Obtain 5 BPM injection rate and record in AWGRS .A.7 29. RIH with perf guns: ` ,- • 30', 2-1/2" Powerflow 2506, HMX (EH: 0.64in, Pen: 5.2in �" '-4 • 6 SPF, 60 deg Phasing, random orientation r 30. Perforate from 12,270'-12,300' per perf procedure � A ;f Jr � , �� ,F �%, Injection Test w/S/L Assist • Please call David Wages prior to pumping injection test. Note: The purpose of SL assisting fullbore is to gather accurate DH pressure decline data for frac modeling. 31. Wait for SL to perform the baseline pass with the PL string. Page 1 3 of 7 • • 32. Pump the following down the TBG at max rate (8 bpm) not to exceed 4500 psi. Please attempt to keep a stable rate if possible. 1. 5 bbls neat meth (if necessary) 2. -250 bbls diesel (the fluid type is subject to change depending on injection pressure from previous tests, please discuss with WIE) • 8 BPM is important, please RU hardline. • Record surface pressure and rate at 1 second intervals. • Work with SLB to obtain BH gauge data at 1 second intervals. • Perform hard shut down of pumps (do not operate tree valves) and monitor pressure decline for 1 hour, then shut well in and RD. • Send pump rate and pressure data to David Wages Stickline Assist Fullbore with Injection Test 33. Drift to deviation 34. RIH with PL tool string (w/out spinner) • Dual Temp and Pressure gauges, GR, CCL 35. Fullbore pump injection test. FuOCtre Hydraulic Fracture Treatment 36. Install Tree-Saver 37. Frac treatment per pump schedule. Pressure testing Maximum Allowable Treating Pressure: 6600 psi • Stagger Pump Kickouts between: 6270 psi and 5940 psi (90% to 95% of MATP) Global Kickout 6270 psi (95% of MATP) • IA pop-off set pressure 3375 psi (75% of MIT-IA) • Treating Line Test Pressure 7600 psi Sand Requirement 337,000# 16/20 Carbolite Minimum Water Requirement 3600 bbls (pump schedule: 3432 bbls) IA Min Hold Pressure .. 3000 psi 4r>r�.� `+f `` ' ", OA Monitor and maintain open to atmosphere Coded Tu. Post frac FCO See Appendix B for FCO procedure 38. Would like to not have to install LGLVs, N2 may be necessary Stinkrme D&T 39. Install MCX • Expect 1-5 MMSCF/D injection Page 14 of 7 • • Appendix A - CT FCO Procedure Notes: • This is a generic FCO procedure for a post frac FCO. Specific info such as amount of proppant left in tubing and estimated sand top will not be known until after the job is pumped. • The objective of this procedure is to get the well cleaned to facilitate post frac well test. • Recommend reviewing PE Manual section for Coiled Tubing Fill Cleanouts for specifics on reversing rates, speeds and CT loading. Planned Procedure 1. MIRU CT 2. MU BHA. 3. RIH down to estimated sand top and begin cleaning out with slick1% KCL. 4. Continue down to 11,500' CTMD. 5. If screened out, pump and injection test and/or MIT, this will test the injectivity of the perfs that we squeezed. 6. Continue to 11,830' at this point we are at the first open perforations. Ensure CT is clean as it is expected that returns will begin to fall off as the nozzle nears the sleeve. If returns begin to fall off, reducing BHP by lowering rate may keep returns at a manageable level. 7. Slowly continue to clean out until returns fall off to -80%. If returns are still good even after the nozzle is past the sleeve (not likely but possible), continue to clean out to PBTD 8. FP to 2500'. 9. Pump a gel pill at surface out to the tanks to ensure CT is clean if necessary. 10. RDMO. Page 1 5 of 7 • • Wellbore Schematic: ' VREE= 4-1/16"CMJ WELLIf.AD- RE SAFETY NOTES:1125 READINGS AVERAGE 125 ppm ACTUATOR= LEDL-1 WHEN ON ML WELL REQUIRES A SSSV WHEN ON KB ELEV 760' MI."'WELLANGLE>-70°@10584 '" 8F ELEV= 49.6 KOP=_ 400' Max Angle= 94'(t11962' Datum MD= 7684' ' 2827' —4-1i2'HES XNP,0=3.813" Datum TVO= 6600'SS? GAS LFT MANDRELS 9-518"CSG,40M,L-80 BTC ID=8835" 3644' ST MD TVD DEV TYPE V LV ,A'CF" PORT DATE IF 2 3594 2590 57 !KSG2 DAN BK 0 03/29/06 1 6641 4130 58 1(802 DMY BFC i 0 03/29/C6 a 13 1 8697' 7"HESS,ES CEMENTER I SMinimum ID =3.725"@ 10500' 4-1/2" HES XN NIPPLE II 10436' —41/2"HES X NIP,ID=3.613' X ' I 10466' T'X 4-112"BKR S-3 PKR,o"3.875* I 10480' I---41/2"HES X NP,ID=3 813' , 10600'—f 41/2'f/ES XN NP,ID=3.725" I I .1 ubZL' I--/"X b'•UKK HHLI LXY LW 10P PKR, l w/TIEBACK Sly,ID=4.410" 4-1/2"TBD,12.6#,L-80 TCI, 0152 bpF ID=3.958" — 10523' 10523' 4112"WLEG,D=3.958" siiii, 10542' RS PACKOFF SEA L MP.D=4.250" 10544' 7"X 5"BKR HMC LNR HMGR,ID=4 41' 10554' —5"X 4-112'XO 10=398" 10669' —41/2"RA MARKER JT; !!BKR WHIPSTOCK(12129/05) --- 10723' 1 7"HES EZSV(12128105)H 10743' MILLOUT WINDOW(L-123) 10723'-10736' 7'CSG,2611,L-00 8TC-M,ID=8 278' H 11393' S PERFORATION SUMMARY ` P"`4'a REF LOG. MAD ON 2?/P?/?? ANGLE AT TOP PERF 80' 10915' 1111111111 Note.Refer to Production DB for hislor cal perf data A104aWt.A SIZE Sly INTERVAL Opn/Sqz DATE 2-7/8" 6 10915-10960 0 01/03106 , 11277' 41/2'RA 2.7/3" 6 10975.11090 0 01103/ 4)Y i! MARKER JT 2-7/8' 6 11110-11140 0 01/03106 5 2-7/8 6_11160..1.121,F O 01/03/06 `� .40 j 2-7/8" 6 11830.11850 O 01!03106 / y*t- 2-7/d" b 11114b 119tIU v u1/T31t3f7 / 4% 2-7/8" 6 12030.12080 O 0110310E ,Qt' ♦rain. 2-7/8" 6 12150-12190 O 01103/106 L_PBI() _1.__12361' i .`i 2.7/8" 6 12270-12340 0 01/03/06 4112'LNR,12.611.L-80 BT-M, 0152 bpf,0=3.958" H 12405' I DATE (I REV BY COMMENTS DATE REV BY COMMENTS BOREAUS UNIT 01107106? 196 ORIGINALCOMPLEFION 11/12/06 RAC/TLH GLV PORT SIZE CORRECTIONS WELL. L-123 01/25/06 BMcN✓TLH DRLG DRAFT CORRECTIONS 02/15/11M8/JMD ADDED SSSV SAFETY NOTE PERMIT Na`2051940 02105/06 CTR/PJC GLV GO 01/18/12 TIUNYJ(ND ADDED I-12S SAFETY NOTE _ API No. 50-029-2329C-00 03128/36 DAV/PJC KB&BF,ELVE CORRECTIONS SEC 34 T12N,R11 F,2748 FNl &3845'FP. 03/29/36+ DAV/PJC GLV C/O 04/21/06, ?/PJC GLV CORRECTIONS I BP Exploration(Alaska) Page 16 of 7 • • Tube Move Analysis: ...--_, C., 0 10 0 C '... ,- S,,:.--• 8 .2 0 0 0 C4 ''-- c to 0 • • • l• 0 O• 0 .... a r—'7' •••,, 0 0 1 01 1'0 t 4 t i +• x • • • ei 0 a) t v ij • ... ---$ to _...,-(.1.1',.. 1.,- ' c, • • to. 4. i' ,,,,- -,. • C9 u., a. a, el o al o 0, g Et) I o 0 z I . 6i g OD V. . ..--.. . 0 . .'.'- -- '4• 0 a' ; ^,-4,e't I ....,,,,,,,,, 8 s 's • to ! •,.:. a c tu a != I 2' ar 1 0 -.- ti 8 o • 0 c? ct• t a ,. 0 i I c ,r,' A: • c 0 ...* [t ... 0 . § 4 (r_ , o -4. A .. 8 • . .... c0 0 0 a. 1 1 1 0 e 0 0 0 0 V a 8 8 1 8 0 0 0 0 c, 0 0 8 ' To" LO V) 0 41 0 ICI to :T) 8 c, 0 0 0 0 0 0 0 0 8 § 0 0 e• .4... , 6 ''''' ,r en 4,1 e- s- <ii '.? 'T .c co : .-... (on)a n a_ (ansual+)(j(11)mod 0 o o o 42 . 0 C ' . M .. o 0 = ' 2 'oc o co 0 o • • c3 c, 0 Zr, "Ci. e .0. co a To 17 -f CP • ..." tr, CV C KV C 7 C .:.; o UI 63 •••. ol co c 13 <3 c 2 c — 2 a." 0 Ce 0 o (,) 0 • • • to• o a) f3 c 0 V ..._ \\ \.. c., co' ; ts -ci G co 0 0 I- 0 ft ;•73 if. a 0 , a9; G.4 '-- C •••4- 0 to) .4. 1,•• .t alla1111111111111F 2 0 E 0 0. 4 col — MOOMMONEMNIMMINMENMEM 0 ...-: • t . 0 N. -- -- -----—o 15 c ,c IIIIIIIIIIIIIIIIIIIIIIMIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIDI 4. . ,.. 11.11111 - en ' A 11111111111111111111111111% .. U1 {11 tA 01 0 7 8 . 5.1 1 .. 10 0 0 0 0 c A 49 to •<1. U'l I, tt, 0 ,t 0 _ i I g 0 t" a. ......iT...-1' . .._ _ 4i . 1 I; 0 § A 0 5 c C's1 Cil 0 5— 7. 3 0 (Isd)aingteid 0111.11916121(1 9.413443 Page I 7 of 7 • • Date: October 28, 2015 Subject: L-123 Fracture Stimulation From: David Wages Engineer, BP Alaska o: 907.564.5669 c: 713.380.9836 To: Chris Wallace Attached is BP's proposal and supporting documents to fracture stimulate the Kuparuk interval of well L- 123. L-123 is a long horizontal injector completed January 2006 as a cased and perforated completion. L-123 has multiple perf intervals with a total of 435' of perfs in the Kuparuk C3 and C4 sands. L-123 lateral production section crosses a fault near the heel section and has 220' of perfs in the heel (before the fault) and another 215' of perfs in the toe. There were no losses experienced during drilling of the fault. L-123 had a high pressure break down (HPBD) treatment performed in November of 2006. L-123 had a caliper in 2011 indicating that the production tubing was in good condition. L-123 was shut in early Q4 2013 for low injectivity. To date L-123 has injected 0.123 mmbbls of produced water and 0.440 Bcf of miscible injection. The objective of the program is to perform a hydraulic fracture stimulation in the toe section to increase L-123's injectivity as such to support L-124 in producing the remaining recoverable reserves in this area. We are requesting a variance to sections 20 AAC 25.283,a,3-4 which require identification of fresh • water aquifers and a plan for basewater sampling. Please direct questions or comments to David Wages • Affidavit of Notification (20 AAC 25.283,a, 1): Partners notified 10/06/2015: ConocoPhillips ExxonMobil Chevron Department of Natural Resources Plat Identifying Wells(20 AAC 25.283,a,2): *See Figure 4 in section "Location of Wells and Faults(20 AAC 25.283, a, 10-11)" Exemption for Freshwater Aquifers(20 AAC 25.283,a, 3-4): Well L-123 is in the West Operating Area of Prudhoe Bay. Per Aquifer Exemption Order No. 1 dated July 11, 1986 where Standard Alaska Production Company requested the Alaska Oil and Gas Conservation Commission to issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II Injection activities. Findings 1-4 state: 1. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit are reported to have total dissolved solids content of 7000 mg/I or more. 4. By letter of July 1, 1986, EPA-Region 10 advises that the aquifers occurring beneath the Western Operating and K pad areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a non-substantial program revision not requiring notice in the Federal Registrar. Per the above findings, "Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AC . 25.440" thus allowing BP exemption from 20 AAC 25.283, a, 3-4 which require identification of freshwater aquifers and establishing a plan for basewater sampling. l�j' • Detailed Casing and Cement Information (20 AAC 25.283,a, 5-6A): Well L-123 was spudded on 12/14/2005 A 12-1/4" hole was drilled to 3650' MD where 9-5/8",40#, L-80, BTC casing was run (casing shoe at 3644' MD) and cemented in place with 446 bbls of ArticSet lite 10.7 ppg lead and 64 bbls of 15.8 ppg Class G cement followed by 15 bbls of 16.5 ppg Durastone slurry. Cement returns of 110 bbls at surface • were seen. A passing pressure test was conducted on the 9-5/8" casing to 3500 psi for 30 min. Cement and formation were drilled out to 3670' and a LOT was performed with 8.8 ppg, 92 ppg EMW A 8-3/4" intermediate hole was drilled to 11,406' MD where 7", 26#, BTC-M casing was run to 11,393' and cemented in place with 47 bbls of 12.5 ppg LiteCRETE lead, 51 bbls of 15.8 ppg GASBLOK in the first stage and 141 bbls of 12.5 ppg LiteCRETE during the second stage. No cement returned to surface but 70 bbls of spacer did come back. Casing was successfully pressure tested to 4000 psi for 30 min.A window was milled from 10,723'-10,736' MD a FIT was performed with 9.4 ppg fluid to 11 ppg EMW. A 6-1/8" production hole was drilled to TD at 12,405' MD. #fid liner,4-1/2", 12.6#, L- 80, IBT-M was run to 12,405' MD. Cemented with 45.5 bbls of 15.8 ppg Gasblok. Pressure tested liner to 4000 psi for 30 min. Perforated liner with 2-7/8" HSD 6psf perfs: 10,915'-12,340' in 9 intervals(4 intervalse above fault in middle of lateral, 5 below). The completion assembly consisting of 4-1/2", 12.6#, L-80,TCII tubing was run to 10,523' MD with the packer at 10,466' MD. *See Mechanical report and cement evaluation Table 4 in section "Location of Wells and Faults (20 AAC 25.283, a, 10-11)"for conformance with 20 AAC 25.283, a, 6B) Pressure Testing(20 AAC 25.283,a,7): Table 1—Tubing and Production Casing Pressure Testing Tubing Pressure Production Casing Differential Pressure Date (psi) Pressure (psi) (psi) TBD 4000 0 *4000 TBD 3000 4500 1500 *The tubing will be pressure tested to 4000 psi which is 110%of max differential pressure (3600 psi) during fracture stimulation per 20 AAC 25.283,c, 2. 6 (te- e i! • • Accurate Pressure Ratings of Tubulars and Schematic(20 AAC 25.283,a,8): Wellbore Schematic IRE}_= 4 /18 CM/ WELLFEAO' FMC SAFETY NOTES:IS READINGS AVERAGE 125 ppm ACTUATOR. —LEO L-123 WHEN ON MI.WELL REQUIRES A SSSV WHEN ON Ml.""wELLANGLE>-70° 10584 BF ELEV- 49.6' KOP- 400' Max Afxgle= 94'@ 11962' Datum MD= 7684' 1 I 2827 - 2'HES X NP.ID=3.313" LAtum(VG= 6600 5S? -.-- - -- ---- 19.5/8"CSG.400,1--80 OTC ID=8 835'. ) + 3644' GAS LFT MANDRELS --__-- --- -. 1ST MD IVO DEVTYRE VLV LATCH;PORT CATS 2 3594 2590 57 !10362 11W BK 0 0329/06 6641 4130 58 I KBG2 DIM' BK 0 0325/06 a 8 r 8697' 17'HES FS CEMENTER I !Minimum ID=3.725"t 10500' 4-112"HES XN NIPPLE 1 { 10435' 4-12'HES X NP,a)=3.81:3' `. , 10456' T'X 4-1/7-8KR S-3 ROE,iD=3.875' 10480' --4-12"HES X NP,ID=3 813' 10500'_.1-14-1/2"HES XN Na?ICI=3.725" I 1U9 2' r X b'BKI(HFUGXPLNH t U'PKR, w/TEBACK SLV,10=4.41C' 4-1/29E10 1261,L-80 TCI 0152 bpf,ID=3 958" I--1 10523' 10623' 412'V/EG,D=3.958' • 141110444 10542' ;-RS PACKOPF SEAL WP ID=4.250' 10544' LI--7"X 5"8KR HMC LNR[NOR,ID=4 41' 1 10554' } 15"X 4.1/7 XO ID=398" 10+559' I4 1,2'RA MARKER J !SKRNh#PSTOCK(1229/05) I 10723'1 ----_- V HES EZ SV(12128105)H 10743' MILLOUT WINDOW(L 123) 10723'-10736' T'CSG,260,L-80 8TGM,ID=6 276' H 11393' PERFORATION SUMMARY REF LOG MWD ON?VW?? ` ANGLE AT TOP PERF 80' 10915' • • • •• 4 . , Note Refer toF oducton DB for hislor cal perfdata ' a,��id141't1'4 SIZE SPF INTERVAL 'Opn/Sg2 DATE 27/8" 6 10915-10960 0 01/03/06 ` 11277 412'RA 2.7/8" 6 10975 11090 0 01/03106 MARKER JT 2-7/8" 6 111110.11140 0 01/03/06 2-7/8" 6 i 11180.11210 0 01/03/06 2-7(3" 6 ( 11830.11850 0 01/03/06 2.716" b 11949-11980 0 1118J.9tb .'. 2-7/8" 6 ! 12030.12080 0 01/03/06 �"��•° 2-7(8' 6 12150.12190 0 01103/06 ---STD 12361' J N�`;.1 2-7/8" 6 12270 12340 0 01/03/06 141/2'LNR.12.6#.L-80 BT-M,0152 bpf.0=3.958'1-I 12405' I DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 01107/061 N9EB ORGINAL COMPLETION 11/12106 RAC/TLH GLV PORT SZE CORRECTIONS WELL:L-123 0125/06'BMcNYTL-1 DRLG DRAFT CORRECTIONS 02/15/1' MB/JMD AIDED SSSV SAI-c1 Y NC I E PERMT No:`2051940 02/05/06 CTR/PJC GLV 0/0 01/18/12 TMNYJMD AC0FD HRS SAFETY NC'_ API No.50-029.23290-00 0328/06 DAV/PJC KB&3=FIVE CORRECTIONS SEC 34 T12N,R11 E,2748 FNI.8 3845'FFL. 03/29/06 j DAV/PJC Gl V C/O 04/21/06;, ?/PJC GLV CORRECTIONS BP Exploration(Alaska) Figure 1-Wellbore schematic for well L-123. ��j • • Table 2—Pressure Ratings Size/Name Weight Grade Connection ID Burst, psi Collapse,psi 9-5/8"Surface 40# L-80 BTC 8.835" 5750 3090 7" Liner Production#1 26# L-80 BTC-M 6.276" 7240 5410 4-1/2" Liner Production#2 12.6# L-80 IBT-M 3.958" 8430 7500 4-1/2"Tubing 12.6# L-80 IBT-M 3.958" 8340 7500 Wellhead Wellhead: FMC manufactured wellhead, rated to 5000 psi. I ••. gyp = iti , ' .: - ..., ....‘' ,,,,t _„....,...., ____-___::,t4t1.11,,,r7 „ :.,., .,..i,...t„.„, :;,.. ....... ito,:,:,..:..,,, :.,;,,,,,,,. „.„4:.:„., .. A \* .s.„,,,,,,.. ,,.. , 7.7...._ .... Figure 2—Well L-123 FMC wellhead. Tree:4-1/16" 5,000psi Tubing head adaptor: 11" 5,000psi x 4-1/16" 5,000psi Tubing Spool: 11" 5,000psi w/2-1/16" side outlets Casing Spool: 11" 5,000psi w/2-1/16" side outlets / • Tree-saver: Top connection is 3" 1502 hammer union which will be crossed over to 4" 1002 in order to connect to the frac treating iron. Bottom connection is 7-1/16" The tree-saver is rated to 10,000 psi. I I 0 roti rg1 `:tri gnu■ 1 ' Nim 3 v W 39 _ X Cf:' s � � J • Figure 3—Diagram of tree-saver to be used during fracture stimulation. 14 • Geological Frac Information(20 AAC 25.283,a,9): Table 3-Geological Information Formation MD Top MD Bot TVDss TVDss TVD Frac Lithological Desc. top bot Thickness Grad HRZ 9,948 10,348 6012 6219 7 .7 Shale Kalubik 10,348 10,787 6219 6384 65 .69 Shale TKUD 10,787 10,908 6,384 6,405 21 0.68 SS TKC4 10,908 11,014 6,405 6,422 17 0.6 SS TKC3E 11,014 11,096 6,422 6,436 14 0.61 SS TKC3D 11,096 N/A 6,436 6,426 10 0.62 SS Fault 11,150 N/A 6,443 N/A TKC1B* 11,306 N/A 6,446 6,456 10 0.67 SS TKC1C* 11,402 11,306 6,443 6,446 3 0.66 55 TKC2B* 11,449 11,402 6,441 6,443 2 0.66 SS TKC2D* 11,563 11,449 6,438 6,441 3 0.66 SS TKC2E* 11,618 11,563 6,436 6,438 2 0.66 SS TKC3A* 11,680 11,618 6,433 6,436 3 0.66 SS TKC3B* 11,794 11,680 6,427 6,433 6 0.63 SS TKC3C* 11,919 11,794 6,419 6,427 8 0.63 SS TKC3D* 12,087 11,919 6,408 6,419 11 0.62 SS TKC3E* 12,267 12,087 6,408 6,408 0 0.61 SS TKC4* 12,338 12,267 6,407 6,408 1 0.6 SS TKUD* N/A 12,338 6,407 0.62 SS 0.62 SS *Invert Section ie • Location of Wells, Mechanical Information and Faults(20 AAC 25.283,a, 10-11): Location of wells and faults .1.11111101.11111.1 lt L-123P B1 A L-124P 81 14 N :LEEN-1 e 3C Mer— VI -446 OCR -1111111k 40' L11 L-122 Figure 4—Plat of wells within one-half mile of 1-123 wellbore trajectory and location of faults. Blue markers on the wellpath indicate perforations,the red line indicates probable location of frac(s) The primary fault of concern is the one in the mid-section of the wellbore.This fault nearly parallels the anticipated primary stress direction and therefore should not interfere with the frac.The remaining faults are far enough away that we shouldn't see the faults. rk/W C; ' is 51- -416-0 The Primary well of concern is NWEILEEN-1. Per the Mechanical report and cement evaluation below, �57 S=-a., the Kuparuk interval of NWEILEEN-1 is isolated and should not be affected by frac pressures. eto $ /tom If a sudden drop in treating pressure is seen, indicating frac fluids have found a fault or wellbore, pumping operations will immediately stop. /(� • • LL' 16 0 .c O W I la L > • U 0 U m Q, O 1,',, bo G 1l1 W ••' y N ru c _N U _ Cr U - 12 ✓ O 1 O .r.-- y c a �iN W 43 x N O 11 P 0 u T u .O PI • a ` en "CO N 'U vi C L W K 0 N W 0 IA Y VI O VI " V1 VI < 0 v N N BJ W YI W W '�-. 73 0 N 76 N .4- d � > in. W St IY! 40 D 'I) 90 SO 40 2'p N M m rot 41 m rr1 1 0 'D '0 'L 50 0 'D 'D 'D ,0 '0 O O H a,41 V umatep Lrl - WM,y O r, *D O z 5) 4-1- , v n Ch r0 .-I I^. Z.-- D ,r. 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I'hp#PJata t.r admarogy CAS Number Chemical Name Mass traction Water(Including Mix Water Supplied try Client)' -77% 50.70-4 Sorbitol <0.1% 52-51-7 2-bromo-2-nitropropane-1,3-diol _- <0.00001% 64-19-7 Acetic acid(impurity) <0.0001% 67-484 2-hydroxy-N,N,N-trenethylethanamirarm chloride <1% 67-63-0 Propan-2-ol <0.1% 107-21-1 Ethylene Glycol <0.1% 110-17-8 Fumaric acid <0_01% 111-46-6 2,2"-oxydiethanel(impurity) <0.001% 111-76-2 2-butoxyethanol <01% _ 112-42-5 1-u decanal <0.01% 112-53-8 C12 fatty alcohol <0.00001% 127-08-2 Acetic otic,potmsiiae sit <0.0001% 557-04-0 Marlesilnrt stearate <0.001% T-. _-1309-48-4 .__-.____ -- -.--_ -Ma�resarm oxide <OA1 Y 1310-73-2 Sodium hydroxide(impurity) <0.01% 1319-33-1 Boronatrocalcite <0.1% 1330-43-4 Sodium tetraborate <0.01% 2682-20-4 2-methyl-2h-isothiaaol-3-one <0.0001% 7447-40-7 Potassium chloride(impurity) <0.0001% 7631-86-9 Simon Dioxide <0.001% 7647-14-S Sodium chloride <0.01% 7704-73.6 Monosodium furnarate <0.01% 7727-54-0 Diammonium peroxrclisuulphate <0.1% 7786-30-3 Magnesium chloride <0.001% 9000-30-0 Guar gum <1% 9002-84-0 poly(tetraluoroethylenel <0.001% - 9012-Sh8 Nemice8ulase enmme <0.01% 9016 88-0 1,4-Benzenedicarboxylic add,polymer with 1,2-ethanediol and a-hydro-w-hydroxypoty <ODDOl% (oxy-1,2-ethanedyl) 9043-30-5 C13 alcohol ethoxylate <0.00001% 9051-89-2 - 1,4-Dioxane-2,5-bone,3,6-dinethyl-,(3Rcis)-,polymer with(3S-cis)-3.6-dixfe hyl- <0.1% 10043-35-3 Boric acid <0.01% 10043-52-4 CakamChloride <0.01% 10377-60.3 Magnum nitrate <0.001% 1446446-1 Ctistobahte <0.0001 5 14 07-96-6 Magnesium silicate hydrate(talc) <0.001% 14808-60-7 Quartz,Crystallin silica < .001% 25038-72-6 lAnylicdene cnlaride/methybuylate copolymer <0.1 5 -__ 26172-55-4 5-chloro-2-methyl-2h-iso hiazdd-3-one <0.001% 34398-01-1 Alcohol,C11 linear,ethoxytated <0.1% _ 39322-78-6 Phosphoric add,dodecyl ester,potassium salt <0.0001% 64742-47-8 Distillates(petroleum),hydrotreated light <1% 66402-68-4 Ceramic materials and wares,chemicals -22% 68131-39-S C12-15 alcohol ethyoxylated <0.01% 68153-30.0 Amine treated smecttte clay <0.1% 72283-36-4 Octane,2-methyl-,polymer with oxirane,mono-(9Z)-9-ociadecenoate,methyl ether <0.0001% 91053-39-3 Diatomaceous earth,calcined <0.01% 125005.87-0 Diutan gum 7 <0.0001% 129898-01-7 ' 2-Prepenoic acid,polymer with sodium plaosphinate <0.1% r • 0 Anticipated Treating Pressures Table 5—Anticipated Pressures Maximum Anticipated Treating Pressure: 5800 psi ° Maximum Allowable Treating Pressure: 6600 psi Stagger Pump Kickouts Between: 6270 psi and 5940 psi (90%to 95%of MATP) Global Kickout: 6270 psi(95%of MATP) IA Pop-off Set Pressure: 3375 psi (75%of MIT-IA) IA Minimum Hold Pressure: 3000 psi Treating Line Test Pressure: 7600 psi Sand Requirement: 337,000 lbs 16/20 CarboBOND Minimum Water Requirements: 3600 bbls(pump schedule: 3432 bbls) OA Pressure: Monitor and maintain open to atmosphere There are three overpressure devices that protect the surface equipment and wellbore from overpressure. 1) Each individual frac pump has an electronic kickout that will shift the pumps into neutral as soon as the set pressure is reached. Since there are multiple pumps,these set pressures are set staggered between 90%and 95%of the maximum allowable treating pressure. 2)A primary pressure transducer in the treating line will trigger a global kickout that will shift all the pumps into neutral. 3)There is a manual kickout that is controlled from the frac van that can shift all pumps into neutral. All three of these shutdown systems will be individually tested prior to high pressure pumping operations. Additionally,the treating pressure, IA pressure and OA pressure will be monitored in the frac van. i1260 400 870 800 103DZ9C 60� �— US wnego et r 5 2g9 J$ .2636 44 c<' t 1 r- --------.----T_____ ____ _, `_� = ``_ = _1-,,,L.12-1------------ ,;,.,, -1 ___ __------__ -----------____ --__ _-�� 6500 �� I I I I I 1 000 8000 8200 0400 8600 8999 0060 9200 9400 9,00 980i' 10000 Figure 5—L-123 cross-section with approximate perforation locations labeled by the red line. S The maximum horizontal stress has been determined to be nearly perpendicular to the wellbore, this is • based on a regional stress map. The maximum horizontal stress means that the induced hydraulic fractures will be perpendicular to the wellbore. Frac Dimensions: TVDss, feet MD, feet Frac Half Length, ft Top 6400 10,900* ^'300 ft Bottom 6500 Exceeds bottom MD *We are fracing the toe of the well, 10,900' MD will not see frac fluids. The above values were calculated using modeling software. Maximum Anticipated Treating Pressure: 5500 psi Surface pressure is calculated based on a closure pressure of—0.6 psi/ft or 4000 psi, this plus the anticipated net pressure to be built (500 psi) and the friction minus the hydrostatic gives a surface pressure of 5500 psi at the time of flush. 4000 psi (closure)+500 psi (net)+3900 psi (friction—2900 hydrostatic= 5500 psi (Max anticipated surface pressure) The frac height is primarily based on closure pressure differences between the confining shale layers and the harder, more brittle sandstone reservoir.Average confining layer stress is anticipated to be"'0.7 psi/ft. Half length is based on confining layer stress as well as leak-off and formation modulus. Given the values,the above half lengths are calculated. We are attempting to create multiple fractures without mechanically staging to a different area of the wellbore.The pump schedule describes a stage of pad+slurry being pumped, then a stage labeled BBS. BBS stands for Broadband Sequence which is a fancy way of saying that we are going to pump a dissolvable slug of fibers and beads that will cause a screenout on purpose at the end of each stage of slurry pumped.This will hopefully create multiple fractures further and further into the wellbore. The goal of pumping this sort of treatment is to create a complex fracture network that will allow decreased injection pressure due to multiple, high conductivity fracs being placed (per the map describing offset wells and faults). / • • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Friday, November 20, 2015 1:27 PM To: Davies, Stephen F (DOA) Subject: FW: PBU L-123 (PTD#205-194) Sundry Application to Hydraulically Fracture - Questions Steve, Please see the email below describing the fault. It was mislabeled on the map view. Our comment on the previous email about a good cement job and the orientation of the fault vs the direction the frac still stands that we should not communicate with the fault.As always, if we get an indication that we have crossed into something that indicates communication with a neighboring well/fault,we will pause and assess prior to continuing operations. Thanks, David Wages o. 907.564.5669 c. 713.380.9836 W I E-AK From: Maraj, Shoba Sent: Thursday, November 19, 2015 4:48 PM To: Emerson, Graham Subject: RE: PBU L-123 (PTD #205-194) Sundry Application to Hydraulically Fracture - Questions Hey, Ok, we'd agreed that the should be re-labelled as 55'. The top of the fault is at 6050'which is in the colville, and the fault tips out at 7000' in the Miluveach. Therefore,the fault cuts the Colville, HRZ, KLB, Kup and MLV. Regarding the risk of fault conductivity—the well lost 72 bbls of mud during drilling, possibly at that fault (the recorded MD is around 100MD past the fault, but,that doesn't mean it's not from the fault..). These losses were very minor,with a peak loss rate of 6 bbls/hour. I think covered all of his questions, let me know if he needs anything else -Shoba From: Emerson, Graham Sent: Tuesday, November 17, 2015 10:06 AM To: Maraj, Shoba Subject: FW: PBU L-123 (PTD #205-194) Sundry Application to Hydraulically Fracture- Questions 1 . • Hey Shoba, Take a look at the bottom paragraph regarding the fault. Can you check the following questions he has asked. We can round up again and update the sundry map as appropriate.... (I think I may have just wrongly labelled the throw as 15'!) Thanks From: Wages, David Sent: Tuesday, November 17, 2015 6:08 AM To: Emerson, Graham Subject: FW: PBU L-123 (PTD #205-194) Sundry Application to Hydraulically Fracture- Questions Graham, Could you take a look at the last paragraph of the email below?I can come down and talk if you like but basically the Y2 mile circle map and the cross section don't agree on the throw of the fault. Thanks David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK From: Davies, Stephen F(DOA) [mailto:steve.davies(Thalaska.gov] Sent: Friday, November 13, 2015 11:33 AM To: Wages, David Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: PBU L-123 (PTD #205-194) Sundry Application to Hydraulically Fracture - Questions David, I'm a bit confused by a portion of the text in the"Detailed Casing and Cement Information"section of BP's application. The fourth paragraph states: "A 6-1/8" production hole was drilled to TD at 12,405' MD. Uncemented slotted liner,4-1/2", 12.6#, L-80, IBT-M was run to 12,405' MD. Cemented with 45.5 bbls of 15.8 ppg Gasblok." Is this correct? Or is the 4-1/2" liner a solid liner that was subsequently cemented and then later perforated? How was the top of cement determined for L-123? How can BP be certain that the NW-trending fault that lies between the two perforated intervals in this well is isolated by good-quality cement? In the nearby NW Eileen State 1 well,the top of the Kuparuk C sand lies at 6385'TVDSS and the base of the lowest Kuparuk Sand lies at 6715'TVDSS. In that well, BP's estimated top of cement for the 7" production casing(set at 9789' MD) lies at 6945'TVDSS, which is about 230 true vertical feet below the Kuparuk sands. The DV collar used for the second stage of cement was placed at 5717'TVDSS (5786' MD), which is about 670'true vertical feet above the Kuparuk sands. So, if I'm reading BP's application correctly it appears as though the Kuparuk sands within NW Eileen State 1 are not covered by cement. How were BP's cement tops determined for this well? Are there bond logs in NW Eileen State 1 or other evidence that clearly location and quality of cement within the well? What is the likelihood that a fracture 2 • • wing will extend from L-123 to NW Eileen State 1? If this occurs, what are the implications? What are BP's contingency plans to ensure that fracturing fluids will be contained? On Figure 5,well L-123 intersects a fault that is labeled "15'SW", but on the cross-section depicted in Figure 5,the vertical displacement of the fault appears to be slightly greater than 50' (if I'm reading the vertical scale on the cross- section correctly). Based on BP's seismic data,what is the vertical displacement of this fault? How shallow does the top of this fault reach, and how deep does it penetrate? Please provide TVDSS depths for the upper and lower extents of the fault and please list all formations affected by the fault. What is the likelihood that this fault may serve as a conduit for migration of the fracturing fluids? What information is used for that assessment? Thank you for your help! Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies(a alaska.gov. Sent from my desktop PC 3 • • Davies, Stephen F (DOA) From: Davies, Stephen F (DOA) Sent: Friday, November 20, 2015 9:50 AM To: 'Wages, David' Cc: Bettis, Patricia K (DOA) Subject: RE: PBU L-123 (PTD#205-194) Sundry Application to Hydraulically Fracture - Questions David, From your last email: ...will ask the geologist...)will get back to you on the specifics of the fault, but in the meantime, please let me know if you need anything else. I haven't heard from you or the geologist about the 15' or 50' displacement normal fault. I'll assume that it has a vertical displacement of 50' rather than 15'. How far upward through the geologic section does this fault penetrate? Does it cut through the overlying Kalubik, Pebble, and HRZ shales? I'll be in the office until about 5 PM today,then will be gone until December 1ST. If you need anything in my absence, please contact Patricia Bettis. Thanks, Steve Davies AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC From: Wages, David [mailto:David.Wages@bp.com] Sent: Tuesday, November 17, 2015 6:06 AM To: Davies, Stephen F (DOA) Cc: Shriver, Tyson; Emerson, Graham Subject: RE: PBU L-123 (PTD #205-194) Sundry Application to Hydraulically Fracture - Questions Steve, Please see answers below in red. David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK From: Davies, Stephen F (DOA) [mailto:steve.daviesOalaska.gov] Sent: Friday, November 13, 2015 11:33 AM To: Wages, David 1 • • Davies, Stephen F (DOA) From: Wages, David <David.Wages@bp.com> Sent: Tuesday, November 17, 2015 6:06 AM To: Davies, Stephen F (DOA) Cc: Shriver,Tyson; Emerson, Graham Subject: RE: PBU L-123 (PTD#205-194) Sundry Application to Hydraulically Fracture - Questions Steve, Please see answers below in red. David Wages o. 907.564.5669 c. 713.380.9836 WIE-AK From: Davies, Stephen F (DOA) [mailto:steve.davies@alaska.gov] Sent: Friday, November 13, 2015 11:33 AM To: Wages, David Cc: Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Subject: PBU L-123 (PTD #205-194) Sundry Application to Hydraulically Fracture - Questions David, I'm a bit confused by a portion of the text in the"Detailed Casing and Cement Information" section of BP's application. The fourth paragraph states: "A 6-1/8" production hole was drilled to TD at 12,405' MD. Uncemented slotted liner, 4-1/2", 12.6#, L-80, IBT-M was run to 12,405' MD. Cemented with 45.5 bbls of 15.8 ppg Gasblok." Is this correct? Or is the 4-1/2" liner a solid liner that was subsequently cemented and then later perforated? [his was a typo, ' it is a fully cemented solid liner How was the top of cement determined for L-123? Volumetric calculations. How can BP be certain that the NW- trending fault that lies between the two perforated intervals in this well is isolated by good-quality cement? During the cement job,they had good returns, an efficiency of 95% upon bumping the plug,they reciprocated while cementing and circulated cement out of the well on cleanup. In the nearby NW Eileen State 1 well,the top of the Kuparuk C sand lies at 6385'TVDSS and the base of the lowest Kuparuk Sand lies at 6715'TVDSS. In that well, BP's estimated top of cement for the 7" production casing(set at 9789' MD) lies at 6945'TVDSS,which is about 230 true vertical feet below the Kuparuk sands. The DV collar used for the second stage of cement was placed at 5717'TVDSS (5786' MD),which is about 670'true vertical feet above the Kuparuk sands. So, if I'm reading BP's application correctly it appears as though the Kuparuk sands within NW Eileen State 1 are not covered by cement. How were BP's cement tops determined for this well? Are there bond logs in NW Eileen State 1 or other evidence that clearly location and quality of cement within the well? What is the likelihood that a fracture wing will extend from L-123 to NW Eileen State 1? If this occurs,what are the implications? What are BP's contingency plans to ensure that fracturing fluids will be contained? 'ur files say we lost returns while cementing the 7"casing in both the first and second stage: 1 • S Re ti. 1.108.4.5 '1" 2L,`'* ..q/1.3-SS") 11S^-8a 4 PIR) s.e31-45a. ai"1$$�S�o� ►.�:�4. rtias�r C. ltac.G Gig DV ` A4 0V cotlatc' 5x7861. Cerwe ej FS #- C N6te.�4 14S-66X e-lagt��T t-ie Gh-s wYr 1,a14N6 ekl-tter. 1-i ti+ !"e�scwy (A y�' 950 Cu&T. w13z00r5; © !OiOoAt Ce.ne.Ae Sec DKcl Stove, w/ 400s t o 1 1^�t{ 'SK CCIaE� L Tgos C C3-6 'Nov, 3 pS,e Q+ i'2 C.O. armLeso �T u n t� GA..e..l rn a D( p tfte1�.4'-`1p 20001 f--1,441 w/t)ier..et, In 54-.Heel !2"3OC'opSi 5p iOben .F��le-Asc4tl % ,2.COM;I.;irk'fl:'J�'r sik.6ArntnErJ — _r Which leads me to believe that the cement tops per the wellbore diagram below are from a log.As we understand,the Kuparuk interval is between the two cement plugs of the 7"casing. 2 • • Alt casing strings and Whirl cut 5 feet below original Tundra glade level and a steel ararkc,plaxe has been installed with the Weil Identify-alit-in Northwest Eileen j S la y "'- "t] .utcam:g..nnhead welded NsrtsnurfacC *1 a 91 "�'9S 4 InT I Salt structural conductor at 121'. State No. 1 --,. CGrsentui w._7.5 pits Ftmdu Final Status: P&A'd " CI$PSC(atlab' d, d'0_,:',,,,,,,,,,,),,.. .c. 2$-Mar-2004 "�f ,�4J* T'Caxirtgpunchedoll8l'rigs'4.1 . '' 24 bbls IS 8 ppg Aretrcaee 1 cement dtsplarel rn Ifs `i 7"x 9 5.8"annulus and inside 7"from 184'to 1;11.! ♦' surface 6 7 tisk 15.8 ppg Arcttcses I cement placed in upper 95.v x 13 318"annulus with rr'p FISH SIickhne tools lett to Hole 8170+87 *Si •"94411-al:3z 485',cemented to mince Depth to TOf 648',LOF 14 17' Casarg Y�5'�9 'It ws'1026 sks Fondue appears tri he cul lapsed m19.2"baud nn ,i 02121,2004 sleckl ine run Suspected casing collapse 192'-724' 4 -----1 3 31S"DV collar at 100 7' f,i. 13 318"34.59&6I f 1.55 lrr('Cmld at 2102' 9 S/5"DV Colt*a$2406' w/040 Sks Fendu areand shoe,870 Cks Fonda 'l through DV Collar ad 1007'and 75 CA Fonda Top lab - Drilling MK. TOC in 7'x 9 318" annulus at-2720' Ili' ' 9 5111" rest Perforation Info: 3� Test Peri Depth Somers Am: TOC in 9 511"x 12?L" 3152'-3944' 370 5x-0" OH annulus at-33313' i 4093'-4131' 920Sx-Cr 4240'-4244' 90 Sx'G y+. 4349'-4373' 95 sx-Cr' '-' 4365'-4377 3' 4192 Sit'Cr 111A- Attachment I k; 9318"40&43.502-tl0andP-I t0castrresete: r.: SO2'6Stage cemented w:650 tics Nd"wound tit- sloe and 4110 sits randy heat through 101 collar at 74106• 7"DV Cdlar 113716' . ''''''-• tit:sisral MID D at 5786' TO'tn7"x8Ai"011ar-6945' t. - tti Test Peds;8960'-5912' A t� 7"Float col inr 019/03' !i 7"26 d 294 3-55.N-80 and NI 10 caring sea at 9785' 7 - F rst slags cciner:ed w?1450 sks snood shoe Second •"74! .4 rT r siege through DV o l lar at 5786'w/41'J on fondu and TO at 9997'MD a TVD --lit `' " 780xks"C;"cement Isolation to surface is provided with two different barriers:the first barrier would be the cement plug at the DV tool. When they cemented,they bumped the plug at the collar and did not drill it out thus making the new PBTD 5786' as noted above.The second barrier is the surface bridge plug and cement which was verified after cutting the wellhead off. In our opinion, even if frac fluid nears or hits the well,the Kuparuk formation is still isolated to prevent fluid from getting / to the surface. On Figure 5,well L-123 intersects a fault that is labeled "15' SW", but on the cross-section depicted in Figure 5,the vertical displacement of the fault appears to be slightly greater than 50' (if I'm reading the vertical scale on the cross- section correctly). Based on BP's seismic data,what is the vertical displacement of this fault? How shallow does the top of this fault reach, and how deep does it penetrate? Please provide TVDSS depths for the upper and lower extents of the fault and please list all formations affected by the fault. What is the likelihood that this fault may serve as a conduit for migration of the fracturing fluids? What information is used for that assessment? 3 • • Good catch, I didn't notice that and will ask the geologist. To the likelihood of the fault taking frac fluids,there are a couple things helping us out on this front: 1) As previously stated,we had a good cement job that will prevent fluids from traveling up the wellbore to the fault. 2) The fault nearly parallels the primary stress direction which means that the fracture we create will nearly parallel the fault. I will get back to you on the specifics of the fault, but in the meantime, please let me know if you need anything else. Thank you for your help! Regards, Steve Davies Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission (AOGCC) Phone: 907-793-1224 AOGCC: 907-279-1433 Fax: 907-276-7542 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 CONFIDENTIALITY NOTICE: This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov. Sent from my desktop PC 4 U.S OPIONMENTAL PROTECTION AC 11!.,Y REGION 10 412 DST ATes 1200 SIXTH AVENUE Z SEATTLE, WASHINGTON 98101 3r• ;;— I � fi JUL 10 1986 tilq� PRO 7' '-a I IMO M/S 409 ; L Yea C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Standard Alaska Production Company Aquifer Exemption Request May 16, 1986. Dear Mr. Chatterton: Based on a July 7, 1986, telephone conversation between Lonnie Smith and Harold Scott, I understand there were no comments during the public comment period regarding the proposed exemption. Therefore, we concur with your decision to exempt the aquifers beneath the Western Operating Area of the Prudhoe Bay Unit for Class II injection activities only. This is a "non-substantial program revision" in accordance with Section 13 of our Memorandum of Agreement. Sincerely, 026&0-1,-/ Robert S. Burd Director, Water Division usi..3. 419'16 � Gommtssaa pyaska 11 G• & Gas Cons. i , Anchorage /il .1 • 'ENVIRONMENTAL PROTECTION •NCY J.00S7-47, REGION 10 Fs 1200 SIXTH AVENUE _,f1f� _ _ tot 'Z SEATTLE, WASHINGTON 98101 1'n 14 `stir •`° JUL 01 1986 ` ° -`471ZZ � Pnol - REPLY TO M/S 409 1~ ATTN OF: C. V. Chatterton, Chairman ALaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Standard Alaska Production Company Aquifer Exemption Request . May 16, 1986 Dear Mr. Chatterton: As you know, the UIC permit application submitted by the Standard Alaska Production Company (formerly Sohio Alaska Petroleum Company) to EPA on June 6, 1984, indicated there were no underground sources of drinking water (USDW's) at the Prudhoe Bay Oil Field (Western Operating Area). However, in their May 16, 1986, aquifer exemption request to AOGCC, it appears there are USDW's in the area. We will be contacting the operator for clarification as to when they became aware of the existence of USDW's. We will keep you informed of our findings and any subsequent actions. In accordance with our Memorandum of Agreement, EPA has conducted a preliminary review of the aquifer exemption request. We believe that the subject aquifers qualify for an exemption. Our final concurrence/ non-concurrence with your decision will be based on the results of your detailed evaluation of the exemption request and any additional information developed through your public comment process. This action is considered to be a minor exemption and a "nonsubstantial program revision" and will not require notice in the Federal Register. Sincerely, Robert S. Burd Director, Water Division ' RECEIVED J U0 7 1986 laska Oil&L.Gas I;r,Rs, �cinmi•sion ftnc!mAe TtEC) "4, / 111 ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage , Alaska 99501-3192 Re: THE REQUEST OF STANDARD ) Aquifer Exemption Order No. 1 ALASKA PRODUCTION COMPANY ) for an Aquifer Exemption ) Western Operating Area Order for that portion of ) including the K Pad Area the Prudhoe Bay Unit t. ) commonly Known as the ) Western Operating Area ) including the contiguous K ) Prudhoe Bay Unit Pad Area ) Prudhoe Bay Field July 11 , 1986 IT APPEARING THAT: 1. Standard Alaska Production Company, by letter of May 16, 1986 , requested that the Alaska Oil and Gas Conservation Commission issue an order exempting those portions of all aquifers lying directly below the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for Class II injection activities . 2. Notice of an opportunity for a public hearing on July 21 , 1986 , was published in the Anchorage Times on June 13 , 1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly, the Commission will , in its discretion, issue an order without a public hearing. 4. A copy of Standard Alaska Production Company' s request was forwarded to the U. S. Environmental Protection Agency (EPA) - Region 10 , on May 21 , 1986 , in conformance with Section 13 of the Memorandum of Agreement , between the Alaska Oil and Gas Conservation Commission and EPA, effective June 19 , 1986. FINDINGS: 1 . Those portions of freshwater aquifers occurring beneath the Western Operating and K Pad Areas of the Prudhoe Bay Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Western Operating and K Pad Areas of the Prudhoe Bay Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable. x • Aquifer Exemption Order No. 1 q P Page 2 July 11 , 1986 3 . Those portions of freshwater aquifers occurring beneath the Western Operating and K Pad Areas of the Prudhoe Bay Unit are reported to have a total dissolved solids content of 7000 mg/1 or more. 4 . By letter of July 1 , 1986 , EPA-Region 10 advises that the aquifers occurring beneath the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify for exemption. It is considered to be a minor exemption and a nonsub- stantial program revision not requiring notice in the Federal Register. 5 . The Western Operating Area and the contiguous K Pad Area constitute a compact land parcel which can readily be described by governmental subdivisions . CONCLUSION: Those portions of freshwater aquifers lying directly below the Western Operating and K Pad Areas of the Prudhoe Bay Unit qualify as exempt freshwater aquifers under 20 AAC 25 . 440 . NOW, THEREFORE, IT IS ORDERED THAT the portions of aquifers on the North Slope described by the 1/4 mile area beyond and lying directly below the following tracts of land are exempted for Class II injection activities only. UMIAT MERIDIAN T12N R10E Sections 13 and 24 . T12N R11E Sections 9 , 10 , 11 , 12 , 13 , 14 , 15 , 16 , 17 , 18 , 19 , 20 , 21 , 22 , 23 , 24 , 25 , 26 , 27 , 28 , 29 , 30 , 32 , 33 , 34 , 35 and 36 . T12N R12E Sections 7 , 17 , 18 , 19 , 20 , 21 , 22 , 23, 24 , 25 , 26 , 27 , 28 , 29 , 30 , 31 , 32 , 33 , 34 , 35 and 36. T12N R13E Sections 19 , 20 , 21 , 22 , 23 , 26 , 27 , 28 , 29 , 30 , 31 , 32 , 33 , 34 , 35 and 36. T12N R14E Sections 27 , 28 , 29 , 31 , 32 , 33 and 34 . T11N R11E Sections 1 , 2 , 3 , 4 , 9 , 10 , 11 , 12 , 13 , 14 , 15 , 24 and 25 . 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They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q~ - ~ ~ ~- Well History File Identifier s , ~ .~„dea iiummmuuu ~ R,.~,~~eeded iiiuiiiiiiiiiim RE CAN Color Items: ~j Greyscale Items: ~ ~~ ^ Poor Quality Originals: ^ Other: NOTES: BY: DIGITAL DATA iskettes, No. ^ Other, No/Type: Date: ~ I ~ / OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: /s/ Project Proofing III II~III VIII II III BY: Maria Date: ,~ ~ S lsl Scanning Preparation ~ x 30 = ~ + ~ =TOTAL PAGES / o'- (Count does not include cover soh et) BY: Maria Date: ~ ' ~ /s/ Production Scanning III (VIII VIII II III Stage 1 Page Count from Scanned File: ~I ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ 1 ~ ~ ©~j /s/ :~ Stage 1 If ND in stage 1, page(s) discrepancies were found: YES NO BY: Maria pate: /s/ Scanning is complete at this point unless rescanning is required. III II ~) II I II II I I III ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll III II'I III P P P 10/6/2005 Well History File Cover Page.doc MEMORANDUM To: Jim Regg ~q P.I. Supervisor (~. 7(~, ~i0 FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-123 PRUDHOE BAY iJN BORE L-123 Src: Inspector N(1N-C'nNFiDENTIAL Reviewed By: P.I. Suprv ~~~ Comm Well Name: PRUDHOE BAY UN BORE L-123 Insp Num: mitCS100711170412 Rel Insp Num: API Well Number: 50-029-23290-00-00 Permit Number: 205-194-0 Inspector Name: Chuck Scheve Inspection Date: 7/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T-L-123 Type Inj. G ' TVD 6348 IA 820 3980 ~ 3940 3930 P.T.D 2051940 TypeTest SPT Test psi 1587 ~ QA 270 680 640 610 Illterval4YRTST pig P Tubing 3060 3060 3060 3060 Notes: pre-test pressures observed and found stable. ~' '~( ~1'`. Wednesday, July 14, 2010 Page 1 of I r~ f~J • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phcebe.txooks~alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhce.bay~alaska.gov OPERATOR: BP Exploration (Alaska}, Inc. FIELD /UNIT /PAD: Prudhoe Bay /PBU / L Pad DATE: 7!8!10 OPERATOR REP: Tiffany Quy AOGCC REP: Chuck Scheve Packer Pretest Initial 15 Min. 30 Min. Well L-111 T In'. W TVD 4,015 T 1,300 1,300 1,300 1,300 Interval V ~~'~ P.T.D. 2020300 T test P Test 1500 520 2,500 2,420 2,410 P/F P Notes: AOGCC MIT-IA to 2500 psi for AA oompFar-ce OA 160 160 160 160 Well L-119 T In'. G TVD 6,446' TuIH 2,550 2,550 2,550 2,550 Interval 4 ~$'(~. P.T.D. 2020640 T test P Test 1611.5 Casi 100 4,000 3,940 3,940 P/F P t Notes: AOGCC MIT-IA to 4000 psi for 4 year UIC OA 20 40 40 40 Well L-123 T In'. G TVD 6,348' T 3,060 3,060 3,060 3,060 Interval 4 ,~g` ~P.T.D. 2051940 T test P Test 1587 820 3,9t~ 3,940 3,930 P/F P ~ YJ Notes: AOGCC MIT-IA to 4000 psi for 4 year UIC OA 270 6'80 640 610 Well T In'. TVD Tul>i Interval P.T.D. T test Test i P/F Notes: OA Well T In'. TVD T Interval P.T.D. T test Test Cali PJF Notes: OA TYPE INJ Codes TYPE TEST Codes `~ ") ~ ~'- INTERVAL Codes "~¢~ ~` "` ~' D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R = Interval Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11!27/07 MIT PBU L-111, 119 & 123 07-08-10 xls ~ ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 t. ~A~s~ ~~ i ~ •' ~~ :> ~~~sa August 14, 2009 ~ , ~;~' , ~ ~ f " ` ~~`~ ,~~;r^~..ti ~- Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, bp ~~~~~~~~ 0 C T 0 5 2009 ~iask~ ~il ~ Gas Cons. Canxr~is~ioa Anchoraga aa~~ ~~ ~ l~ - ~ ~ 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 ~ BP Exploration (Alaska ) Inc. nar.. Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Su~dry Operationa (10-404) r i L pad ~ an ~nna Well Name PTD # API # Inftial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al 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 6I25l2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 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 To 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!6/20Q9 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 ~-109 2Q12010 5002923~460000 MA 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-11 S 2011870 50029230430000 NA 1.4 NA 15.3 6l27/2U~9 L-119 2020640 50029230770000 NA 225 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2~3U390 50029231380100 NA 22 NA 25.5 6127/2009 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(t0/20~9 L410 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 ~-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2U50300 SU029232520000 NA 1.8 NA 17 6J26l2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 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 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surtace NA NA L-220 2080470 50029233870000 NA 2 NA 2U.4 6128l2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2~5136~ 50029232770000 NA 1.8 NA 20.4 6/2712009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 I( ~'"2~~ DATA SUBMITTAL COMPLIANCE REPORT 2i2si2oos Permit to Drill 2051940 Well Name/No. PRUDHOE BAY UN BORE L-123 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23290-00-00 MD 12405 TVD 6480 Completion Date 1/4/2006 Completion Status WAGIN Current Status WAGIN UIC1Y, ~, REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Log s Run: Surface Gyro, GR, GR /RES /DEN / NEU / PWD, USIT, GR /RES / (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~D D Asc Directional Survey 0 12405 Open 2/14/2006 j~t Directional Survey 0 12405 Open 2/14/2006 1'ED D Asc Directional Survey 0 11406 Open 2/14/2006 PB 1 iRpt Directional Survey 0 11406 Open 2/14/2006 PB 1 Cement Evaluation 5 Blu 1 3344 10700 Case Ultra Sonic Cement Eval. USIT/GR/CCL 1-Jan-2006 ~kD C Lis 15171 ' Neutron 54 12405 Open 5/31/2007 LIS Veri, GR, ROP, FET, ~+ DRHO, NPHI w/Graphics ~g 15171 Induction/Resistivity 25 Blu 90 12405 Open 5/31/2007 TVD Vision Service 1-Jan- 2006 , ~ ~Xog 15171 Induction/Resistivity 25 Blu 90 12405 Open 5/31/2007 MD Vision Service 1-Jan- 2006 /ED C Lis 15172 Neutron 54 11405 Open 5/31/2007 PB1 LIS Veri, GR, ROP, ', NPHI w/Graphics (;tog 15172 Induction/Resistivity 2 Blu 108 11405 Open 5!3112007 PB1 TVD CDR Res Den ~,' Neu 25-Dec-2005 tri!og 15172 Induction/Resistivity 2 BIu 108 11405 Open 5/31/2007 PB1 MD CDR Res Den Neu 25-Dec-2005 -- Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2i2si2oos Permit to Drill 2051940 Well Name/No. PRUDHOE BAY UN BORE L-123 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23290-00-00 MD 12405 TVD 6480 ADDITIONAL INFORMATION Well Cored? Y 6 Chips Received? YTId~--- Analysis ~. Received? Comments: Compliance Reviewed By: Completion Date 1/4/2006 Completion Status WAGIN Current Status WAGIN UIC Y Daily History Received? / N Formation Tops / N Date: Schluouherger Sehtumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ /Sly! #~ rs~r~a ;~~~ Well Job # log Description N0.4262 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Orion Date BL Color CD L-123 L-123PB7 40012830 40012830 OH EDIT MWD/LWD OH EDIT MWD/LWD 01/01/06 12/25/05 2 2 1 1 L-213 40013428 OH EDIT MWD/LWD 04/25106 2 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) inc. Ff M Petrotechnieal Data Center LR r ''1 „~ , 900 E Benson Bivd. ,. Anchorage AK 99508-4254 ~~~~ I Dale Delivered: ~~ ~~ r"d~F%C.;A S>.,IAI. f0 ,`:;'~ry,9~p°G~~~pt~tV'4~~0.: R-9tre°°'l F' "" 9~^ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Belh 1 l/ y ._........ Received by:v 05/17/07 •°`~~ STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS~I REPORT OF SUNDRY WELL OPERATIONS ~tE~EIV~I~ NOV 2 4 2006 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate0 Oy~ g , Hltl~ a~ ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well A(iChOf8Q8 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory " 205-1940 3. Address: P.O. Box 196612 Stratigraphic € Service ~' 6. API Number: Anchorage, AK 99519-6612 50-029-23290-00-00 7. KB Elevation (ft): 9. Well Name and Number: 76 RT L-123 8. Property Designation: 10. Field/Pool(s): ADLO-028239 Prudhoe Bay Field Field/ Borealis Pool Pool 11. Present Well Condition Summary: Total Depth measured 12405 feet Plugs (measured) None true vertical 6479.98 feet Junk (measured) None Effective Depth measured 12361 feet true vertical 6481 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" A-53 215.5# 29' - 109' 29' - 109' Intermediate 3615' 9-5/8" 40# L-80 29' - 3644' 29' - 2618' 5750 3090 Production 10697' 7" 26# L-80 26' - 10723' 26' - 6444' 7240 5410 Liner 1883' 4-1/2" 12.6# L-80 10522' - 12405' 6377 - 6480' 8430 7500 Perforation depth: Measured depth: 10915' - 12340' True Vertical depth: 6482' - 6483' Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 27' - 10523' Packers and SSSV (type and measured depth) 7" x 4-1/2" BKR S-3 10456' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 0 0 1 0 1090 Subsequent to operation: 0 0 shut in 0 0 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~ WAG ~ GINJ ~ WINJ ~' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Gary Preble Printed Name Gary Pre Title Data Engineer Signature Phone 564-4944 Date 11/22/2006 OSStp h '`1 Form 10-404 Revi ed 04/2004 W. ~ ~ (~! ~~,, f~~)Gr ~ ~ 20~~ Submit Original Only ~ S ~ t • • L-123 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/5/2006T/I/0=2250/950/250 (MIT IA /Inject. Test TBG) MIT IA Initial Press= .2250/4000/580. 15 min press=1900/3880/540.= 30 min press=1800/3820/500. MIT x IA is a Pass. Bleed back IA press. to 750psi.. Rig-Up To TBG for Inject. Step Test. Injected. meth down TBG @ 2000 Psi. Coudn't establish a rate @ 2000 '. -;psi. Raised press. to 2500 Psi and established a rate @ .25 bpm. Raised press. 'to 3000 psi and established a 2.3 bpm rate for about 8 minutes then rate fell off to '2 bpm towards the last 7 minutes of test. Retested Inject. Test. could not establish a rate @ 2000 psi or 2500 psi. I did establish a rate @ 2750 @ about .6 bpm. :Raised press. to 3000 psi and established a rate C 2.23 bpm .Rate fell off :towards end of test to 2 bpm. RDMO.FWHP=2050/660/0 (Note: all well head 'valves normalized. ) 11/6/2006 Awgers Continued from previous day. Refer to 1 i-05-06 awgers for complete .summary of MITx IA and Infectivity test on TBG. 11/16/2006"**WELL S/I ON ARRIVAL"** (brush tree for frac saver rubber) '!'CYCLE SWAB & MASTER VALVE , 23.5 TURNS ON BOTH .RIG UP SLICKLINE ;,UNIT . ***CONTINUED ON 11/17/06 WSR*** 11/16/2006MIRU for HPBD w/4 DS Super Pumps. Fluid system WF 120 (seawater @ 70 `;:deg). Delay due to Well Support tattle tail line frozen solid. Second delay, unable "to get tree saver to set fully in the tubing. Measurements show problem occuring "at the base of the tubing hanger. 40 bbls warm diesel thru tree (no ice). Rubber ',,cups show heavy wear marks and damage around circumference. of element. '',Redress tree saver and attempt again, unable to make tree saver travel down. `Job postponed until slickline can troubleshoot tubing and hanger issue, Dowell to !rebuild and troubleshoot tree saver. Well left shut in and freeze protected. 11/16/2006Heat diesel on Santa Fe Pad for HPBD on L-123 11/16/2006'T/I/0=1500/600/100 HPBD - Pumped 2 bbls diesel to assist w/HPBD, Job :incomplete, Freeze protect tubing w/ 10 meth, FL w/ 7 bbls MW Final ` W H P's=2320/820/60 11/17/2006`T/I/0=1500/600/100 Assist SLB w. HPBD Heated 100 bbls DSL to 80* for SLB. ''Pumped up IA to 2200 psi. w. 1.6 bbls DSL. Held 2500 psi on IA while SLB "'4,performed HPBD. Final WHP's=?/500/100 • • 11/17/2006: MIRU for HPBD w/ 4 DS Super Pumps. Fluid system WF 120 (seawater based @ ~70 deg). First HPBD obtain ~41 bpm @ 5200 psi, ISIP around 2300 psi, ';suggests frac gradient around .80 psi/ft. Second HPBD after 2100 # of 1 ppa of ",.16/20 proppant, get ISIP around 2200 psi. Stage 2: Pump 1550# of rock salt (unable to see diversion) followed by 2100# of 16/20, get ISIP around 2200 psi at 'end of stage. Stage 3: Pump 2350# of rock salt (see possible diversion masked `° by pump rate increase) followed by reduced amount of 1150# of 16/20 scour, get ISIP around 2300 psi. Stage 4: 2350 # of rock salt (wait before increasing pump 'rate and confirm diversion -200 psi), follow with 1150# of 1.6/20 scour, S/D and `estimate ISIP around 2280 psi. Stage 5: pump remaining rock salt of 2000# (hold ;pump rate steady and see 600 psi diversion and breakback) follow with 1150# ;.16/20 scour and remaining balance of water on location of 390 bbls at 45 bpm and '!4900 psi. FP pumps and well with remaining diesel. All cups recovered. Notifiy "operator to POI. Job complete. 1 i/17/2006:***CONTINUED FROM 11/16/06 WSR"* (brush tree for frac saver rubber) ::BRUSHED TREE W/STIFF 4.5 BLB & 3.85 CENT .RAN 3.88 BROACH !'THROUGH TREE ';';W/NO PROBLEMS .DRIFTED W/3.25 CENT & S.B. TO 8000'SLM W/NO ``PROBLEMS . *"*WELL LEFT S/I ON DEPARTURE*** FLUID SUMMARY 1700 bbls YF 120 (seawater) 120 bbls Gelled Diesel 90 bbls Diesel 7350 Ibs 16/20 Carb 8225 Ibs Rocksalt ~ ~ ~ STATE OF ALASKA ~ J?1N 2 7 2006 ALAS IL AND GAS CONSERVATION COM ISSION e~,, WELL COMPLETION OR RECOMPLETION REPORT AND LOv~°ska Oil ~CppGars~,,Cons. Cotrki~ission Revised: 06/26/O~,~ii4`injaction 1 a. Wefl Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 1 b. Well Class: zoAACZS.ios 2oAACZS.~~o ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ^ Stratigraphic ®Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 1/6/2006 205-194 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 12/14/2005 50-029-23290-00-00 4a. Location of Wel1(Governmental Section): 7. Date T.D. Reached 14. Weli Name and Number: Surface: ' ' 1/1/2006 PBU L-1231 2532 FSL, 3845 FEL, SEC. 34, T12N, R11 E, UM g. KB Elevation (ft): 15. Field /Pool(s): Top of Productive Horizon: 2357' FSL, 3658' FEL, SEC. 28, T12N, R11 E, UM 76' Prudhoe Bay Field /Borealis Pool Total Depth: 9. Plug Back Depth (MD+TVD) 3239' FSL, 2458' FEL, SEC. 28, T12N, R11 E, UM 12361 + Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 583069 y- 5978252 Zone- ASP4 12405 + 6480 Ft ADL 028239 TPI: x- 577911 y- 5983302 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 579099 Y- 5984196 Zone- ASP4 None MD 19 if ff h W f P f Thi k t 20 ater depth, ore . o s ness o erma ros . c 18. Directional Survey ®Yes ^ No N/A MSL 1900' (Approx.) 21. Logs Run: Surface Gyro, GR, GR /RES /DEN /NEU /PWD, USIT, GR /RES /DEN /NEU /PWD 2 ASING, INER AND EMENTING ECORD CASMNG ETTING EPTH MD ; ETTtNG EPTH.,Np HOLE MOUNT SIZE WT. PER FT. GRAQE OP OTTOM' OP OTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 29' 109' 29' 109' 42" 260 sx Arctic Set Approx. 9-518" 40# L-80 29' 3644' 29' 2618' 12-1 /4" 563 sx AS Lite, 296 sx 'G', 72 sx 'G' 7" 26# L-80 26' 10723' 26' 6444' 8-3/4" 117 sx 'G', 245 sx 'G', 353 sx 'G' 4-1/2" 12.6# L-80 10522' 12405' 6377' 6480' 6-1/8" 213 sx Class 'G' 23. Perforations open to Production (MD +TVD of Top and " ' `24. TuawG RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10523' 10456' MD TVD MD TVD 10915' - 10960' 6482' - 6489' ' ' 26, ACID CEMENT SQUEEZE, ETC. FRACTURE 10975 - 11090' 6491 - 6511' , , 11110' - 11140' 6514' - 6519' 11180' 11210' 6523' 6524' DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED - - 11830' - 11850' 6501' - 6500' 10743' Set EZSV 11945' - 11980' 6493' - 6491' 10723' stock for Kick-Off from Pilot Hole Set Whi 12030' - 12080' 6488' - 6485' p 12150' - 12190' 6483' - 6484' ' ' ' ' 12270 - 12340 6484 - 6483 Freeze Protect w/ 98 Bbls of Diesel 26• PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 1, 2006 Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED E OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) Press. 24-HOUR RAT 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~~~5 BF~ JUN 2 8 2006 Form 10-407 Revised 12/2003` ~ i 4 *,, t (~O TINUED ON REVERSE SIDE ~ l~, 1 i r ~ 28. GEOLOGIC MARK 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4015' 2814' None Ugnu M Sands 6085' 3903' Schrader Bluff N Sands 6572' 4166' Schrader Bluff O Sands 6850' 4314' Base Schrader /Top Colville 7441' 4625' HRZ 9948' 6088' Kalubik 10348' 6295' Kuparuk D 10696' 6437' Kuparuk C 10910' 6481' Kuparuk C 12341' 6483' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. // I Signed ~b ~~ / Q Title Technical Assistant Date Terrie Hubble PBU L-1231 205-194 Prepared ey Name/Number.• Terrie Hubble, 564-4628 Well Number Permit NO. /Approval No. Drilling Engineer: Blandon Peltier, 564-5912 INSTRUCTIONS GeNeRnt,: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification ofi 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 complete{y segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ao3-~s~------ Ssh(emherger Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2638 ATTN: Beth Well Job # ~-~ .».a ,m+eef1O. :.<°i/'$aeald'st~oi's~s~ icy Log Description NO. 3680 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 133 West 7th Ave, Suite 100 Mchorage,AK 99501 Field: Polaris Borealis Aurora Oate BL Color CD S-03 I 11057082 PERF/SBHP 01(03106 1 V-114A REVISED 40009730 OH LDWG EDIT OF MWO/LWD 12N5/03 1 S-111 11058510 USIT 05/28/05 1 L-123 - V-114A PB1 10987558 40009730 USIT OH LDWG EDIT OF MWD/LWD 01101!06 11103103 6 1 1 V-114A P62 40009730 OH LDWG EDIT OFMWD/LWD 12/15/03 1 1 W-207 P81 40008886 OH LDWG EDIT OF MWD/LWD 04104!03 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Patrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: ~1 a~'~~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth~~ Received bw I l lU tl ~ A ~ 02/13/06 ~~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~8 FEB 1 7 ZUU6 Ita Dit & Gas Cons. Cofnrhil ~. a. •~.~ Anchorage ia. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 1b. Well Class: 2oAAC 2s.~os 2oAAC 2s.~ ~o ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ^ Stratigraphic ®Service 2. Operator Name: 5. Date Comp., Susp., or Aband. ,~~. 12. Permit to Driil Number BP Exploration (Alaska) Inc. 1/ / Zp 205-194 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 12!1412005 50-029-23290-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 253 ' FS ' 1/1/2006 PBU L-1231 2 L, 3845 FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: g. KB Elevation (ft): 15. Field /Pool(s): 2357' FSL, 3658' FEL, SEC. 28, T12N, R11E, UM 76' Prudhoe Bay Field /Borealis-Pool Total Depth: 9. Plug Back Depth (MD+TVD) 3239' FSL, 2458' FEL, SEC. 28, T12N, R11 E, UM 12361 + Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 583069 y- 5978252 Zone- ASP4 12405 + 6480 Ft ADL 028239 _ _ _ TPI: x- 577911 y- 5983302 Zone- ASP4 11 • Depth where SSSV set 17. Land Use Permit: Total Depth: x- 579099 Y- 5984196 Zone-~ASP4 None MD ----- ---"-~---- -----~~- -~-"---"-- ~----_---~-- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey ®Yes ^ No N/A MSL 1900' (Approx.) 21. Logs Run: Surface Gyro, GR, GR /RES /DEN /NEU / PWD, USIT, GR /RES /DEN /NEU / PWD 2. ASING, LINER AND EMENTING ECORD CASING INCi PTH MD ETTINO EPTH TVD t~O~ MOUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTINl3 REGARD PULLED 20" 215.5# A-53 29' 109' 29' 109' 42" 60 sx Arctic Set A rox. 9-518" 40# L-80 29' 3644' 29' 2618' 12-1/4" 563 sx AS Lite, 296 sx'G', 72 sx'G' 7" 26# L-80 26' 10723' 26' 6444' 8-3/4" 117 sx 'G' 245 sx 'G', 353 sx 'G' 4-i/2" 12.6# L-80 10522' 12405' 6377' 6480' 6-1/8" 13 sx Class 'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TuBtNt.RECORo Bottom Interval, Size and Number; if none, state none ): $IZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10523' 10456' MD TVD MD TVD 10915' - 10960' 6482' -6489' ' ' ' ' 25. ' ACtq FRACTURE CEMENT SCXIEEZE ETC. 10975 - 11090 6491 - 6511 , , 11110' - 11140' 6514' - 6519' 11180' - 11210' 6523' - 6524' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11830' - 11850' 6501' - 6500` 10743' et EZSV 11945' - 11980' 6493' -6491' 12030' - 12080' 6488' - 6485' 10723' et Whipstock for Kick-Off from Pilot Hole 12150' - 12190' 6483' - 6484' ' ' ' ' 12270 - 12340 6484 -6463 Freeze Protect w! 98 Bbls of Diesel 26. 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 Flow Tubing Casing Pressure CALCULATED E OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) Press. 24-HOUR RAT 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~ ~ _ ~ ~ ~~ l=~B ~ ~ ZQQ~ None ~ ~` . ~ ~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ,~ S 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4015' 2814' None Ugnu M Sands 6085' 3903' Schrader Bluff N Sands 6572' 4166' Schrader Bluff O Sands 6850' 4314' Base Schrader /Top Colville 7441' 4625' HRZ 9948' 6088' Kalubik 10348' 6295' Kuparuk D 10696' 6437' Kuparuk C 10910' 6481' Kuparuk C i234i' 6483' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Signed Terrie Hubble Title Technical Assistant Date 1 `~~~~ PBU L-1231 205-194 Prepared ByName/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Brandon Peltier, 564-5912 INSTRUCTIONS GENERA: This form is designed for submitting a complete and correct well completion. report and log on all types of lands and leases in Alaska. ITEM 1a: 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. tTEM 4b: TPI (Top of Producing Interval). Frets 8: The Kelly Bushing elevation in feet above mean low low water. 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). IreM 20: True vertical thickness. Frets 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only gp Page 1 of 1 Leak-Off Test Summary Legal Name: L-123 Common Name: L-123 Test Date Test Type i Test Depth (TMD) ~ Test Depth (TVD) AMW li Surface Pressure ,Leak Off Pressure (BHP) ~ _ _EMW 12/19/2005 LOT _ - - 3,644.0 (ft) _ ~ - - 2,617.0 (ft) - _ _ 8.80 (ppg) 560 (psi) 1,756 (psi) 12.92 (ppg) 12/29/2005 LOT 10,723.0 (ft) 6,444.0 (ft) 9.40 (ppg) 540 (psi) 3,687 (psi) 11.01 (ppg) Printed: 1/9/2006 9:42:56 AM gp Page 1 of 14 Operations Summary Report Legal Well Name: L-123 Common Well Name: L-123 Spud Date: 12/14/2005 Event Name: DRILL+COMPLETE Start: 12/13/2005 End: 1/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/6/2006 Rig Name: NABOBS 9ES Rig Number: Date j From - To i Hours I Task ~ Code ~ NPT Phase ~, Description of Operations 12/13/2005 00:00 - 06:30 6.50 RIGU P PRE Prepare for rig move. PJSM with crane operator and L-Pad operator. Shut in adjacent wells, bleed off process lines in preparation for diverter line installation. Pre-move installation necessary due to space restricted area behind well. Set in surface annular preventer. Nipple up diverter lines over pad flow lines. 06:30 - 08:00 1.50 MOB P PRE Lower pipe chute, lower derrick. 08:00 - 09:00 1.00 MOB P PRE Move mud pit complex down pad row. 09:00 - 13:00 4.00 MOB P PRE Jack rig up, pull out matting boards. Turn key rig move, well to well, same row to L-1231. Remove gauges from adjacent well. Set matting boards, position sub base over conductor pipe. Shim and level rig. 13:00 - 14:00 1.00 MOB P PRE Spot mud pit complex, set matting boards, hook up inner-connect. 14:00 - 15:00 1.00 MOB P PRE Raise derrick, raise pipe chute. 'Accept rig for operations on L-123i @ 15:00 hr, 12/13/2005" 15:00 - 17:00 2.00 RIGU P PRE Rig up floor and take on water for spud mud. 17:00 - 00:00 7.00 RIGU P PRE NU diverter riser, install bolts on diverter line, install 4" dump valves on diverter spool. Connect grounding strap, berm cellar area. 12/14/2005 00:00 - 03:00 3.00 RIGU P PRE Pre Spud Meeting. Install dresser sleeve on riser. Finish installing bolts in diverter line. 03:00 - 04:00 1.00 RIGU P PRE Pick up pipe handling subs, xo's, etc. to rig floor. 04:00 - 06:00 2.00 RIGU P PRE Prep drill pipe, HWDP, and BHA in pipe shed. Prep rig floor to pick up drill pipe. Mix spud mud. 06:00 - 06:30 0.50 RIGU P PRE Pick up surface BHA jewelry to rig floor. 06:30 - 10:30 4.00 RIGU P PRE Pick up 102 joints 4" HT-40 drill pipe and stand back in derrick. 10:30 - 13:00 2.50 RIGU P PRE Pick up 23 joints 4" HWDP, 1 joint 4" DP, 2 joints 5" HWDP, jars and stand back in derrick. `Held Pre Spud Meeting with noon -midnight crew' 13:00 - 13:30 0.50 DIVRTR P PRE Pertorm diverter system function test. Witness of test waived by AOGCC rep Jeff Jones. Test witnessed by BP Wellsite Leader Bill Decker and NAD Toolpusher Bill Bixby. 13:30 - 14:30 1.00 RIGU P PRE Flow check new mud system. Test lines to 3,500 psi. 14:30 - 18:00 3.50 RIGU P PRE Continue make up of 12 1/4" BHA #1. RR bit, 1.83 mud motor, lead CLR, stab, MWD, stab, XO, orienting sub. Orient MWD. 18:00 - 18:30 0.50 RIGU P PRE Rig up Gyro survey sheaves and tools. 18:30 - 19:00 0.50 DRILL P SURF Spud in L-1231 12 1/4" surface hole @ 18:30 hr, 12/14/2005. Drill from 109' to 165'. 550 gpm, 760 psi on bottom, 785 psi off bottom. 60 rpm, 3-4k TO. PU - 48k, SO - 48k, RT - 48k, WOB - 5-10k. 19:00 - 20:00 1.00 DRILL P SURF Gyro survey @ 165' bit depth. 20:00 - 23:30 3.50 DRILL P SURF Directionally drill from 165' to 354'. 550 gpm, 760 psi on bottom, 785 psi off bottom. 60 rpm, 3-4k TO. PU - 48k, SO - 48k, RT - 48k, WOB - 5-10k. AST - .45 hrs, ART - .60 hrs. 23:30 - 00:00 0.50 DRILL P SURF Gyro survey @ 354' bit depth. 12/15/2005 00:00 - 02:00 2.00 DRILL P SURF Directionally drill from 354' to 537'. 590 gpm, 1000 psi on bottom, 890 psi off bottom. 60 rpm, 2k TO on, 890 TO off. PU - 65k, SO - 60k, RT - 50k, WOB - 20k. CBU X 2. MW - 8.9 Printed: 1/9/2006 9:43:02 AM BP Operations Summary Report Page 2 of 14 Legal Well Name: L-123 Common W ell Name: L-123 Spud Date: 12/14/2005 Event Nam e: DRILL+C OMPLE TE Start: 12/13/2005 End: 11612006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 1/6/2006 Rig Name: NABOB S 9ES Rig Number: Date ; From - To !Hours I, Task ~ Code ~I NPT i Phase I Description of Operations 12/15/2005 00:00 - 02:00 2.00 DRILL P SURF ppg. 02:00 - 02:30 0.50 DRILL P SURF POOH from 537' to 166' for jar stand. PU - 65k, SO - 60k. 02:30 - 03:00 0.50 DRILL P SURF Pick up jar stand and TIH from 166' to 537', 03:00 - 13:30 10.50 DRILL P SURF Directionally drill from 537' to 1,653'. 700 gpm, 2,400 psi on bottom, 2,360 psi off bottom. 60 rpm, TQ on - 4.5k, TO off - 2.4k, PU - 80k, SO - 80k, RT - 75k, WOB - 35-40k. AST - 7.93 hrs. ART - 2.48 hrs. 13:30 - 14:00 0.50 DRILL P SURF Circulate bottoms up X 3. 700 gpm, 2,360 psi, 60 rpm, 2.4k TQ, 9.3 ppg, 300 vis. 14:00 - 15:30 1.50 DRILL P SURF Gyro surveys from 1,557' survey depth and every 100' to surface. 15:30 - 16:30 i.00 DRILL P SURF Rig down gyro tools and Sperry wireline sheaves. 16:30 - 18:00 1.50 DRILL P SURF POH with BHA #1 from 1,653' to 231'. PU - 88k, SO - 76k. Pulled 10-15k over @ 1,510' and 1,240'. Wipe same with no problem. 18:00 - 18:30 0.50 DRILL P SURF Stand back jar and DC stand, pull bit to rig floor. 18:30 - 19:00 0.50 DRILL P SURF Clear and clean rig floor. 19:00 - 19:30 0.50 DRILL P SURF Change out 12 1/4" bit, adjust motor bent housing from 1.83 deg to 1.5 deg. 19:30 - 20:00 0.50 DRILL P SURF Service top drive and crown. 20:00 - 20:30 0.50 DRILL P SURF Add NM stab in DC stand. Pick up jar stand and 8 stands 4" HWDP. 20:30 - 21:30 1.00 DRILL P SURF RIH with BHA #2 on 4" drill pipe. Work through tight spot from 1200' to 1250' by filling pipe and working down. Continue RIH to 1,650' without problem. Wash last stand down from 1,560' to 1,653' 21:30 - 00:00 2.50 DRILL P SURF Directionally drill from 1,653" to 1,841'. 700 gpm, 2,460 psi. on bottom, 2,360 psi off bottom. 80 rpm, TO on - 4.7k, TQ off - 2.4k, PU - 86k, SO - 75k, RT - 81 k, WOB - 35k. AST - .04 hrs. ART - .67 hrs. 12/16/2005 00:00 - 08:00 8.00 DRILL P SURF Directionally drill from 1,841" to 3,646'. 700 gpm, 3,420 psi on bottom, 3,310 psi off bottom. 80 rpm, TO on - 7-8k, TO off - 5k, PU - 112k, SO - 72k, RT - 86k, WOB - 35k. `Encountered normal hydrates @ 2,100', 2,200', and 2,600'. Reduced pump rate @ 3,056' to 650 gpm, 3,380 psi on bottom, 3,280 psi off bottom. AST - 2.38 hrs., ART - 2.76 hrs. 08:00 - 09:30 1.50 DRILL P SURF CBU X 3. 680 gpm, 3,310 psi, 100 rpm, TQ - 5.1 k, RT - 86k. MW - 9.7 ppg. 09:30 - 13:30 4.00 DRILL P SURF Monitor well - OK. POH, short trip from 3,646' to 1,000'. PU - 118k, SO - 75k. Work through tight spots from 3,240' to 2,760'. 15-25k over pull without pumping. 13:30 - 16:00 2.50 DRILL P SURF RIH from 1,000' to 1,935'. Fill pipe, pump and rotate to 2,028', 60 rpm, 175 gpm, 650 psi. Continue RIH dry to 3,615'. Wash last stand down from 3,615' to 3,646'. Drill 4' new hole to 3,650'. ART - .04 hrs. 16:00 - 17:30 1.50 DRILL P SURF CBU X 3. 680 gpm, 3,400 psi, 100 rpm, 5k TO, RT - 86k, MW - 9.5 pP9~ 17:30 - 20:00 2.50 DRILL P SURF Monitor well - OK. POH from 3,650' to 3,110'. Started pulling 25-30k over. Attempt to work through tight spot at 3,060' without success. Unable to work down. Connect top drive, pump and rotate pipe back down @ 60 rpm, 222 gpm, 2,000 psi. Able to work pipe up and down without pump. Same Printed: 1/9/2006 9:43:02 AM BP Page 3 of 14 Operations Summary Report Legal Well Name: L-123 Common Well Name: L-123 Spud Date: 12/14/2005 Event Name: DRILL+COMPLETE Start: 12/13/2005 End: 1/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/6/2006 Rig Name: NABOBS 9ES Rig Number: Date ~, From - To ---- i, Hours ~, Task ~~ Code ~ NPT ! Phase ~, Description of Operations j _---- 12/16/2005 17:30 - 20:00 - --- 2.50 DRILL - --- - --- ----- - - --_---- P SURF problem and solution at 3,025'. Continue POH dry to 2,776' without problem. 20:00 - 20:30 0.50 DRILL P SURF RIH from 2,776' to 3,650' without problem. 20:30 - 21:30 1.00 DRILL P SURF CBU X 2. 670 gpm, 3,230 psi, 100 rpm, 5k TO, RT - 86k, MW - 9.4 ppg. 21:30 - 00:00 2.50 DRILL P SURF Monitor well - OK. POH from 3,650' to 2,028'. PU - 120k, SO - 70k. Work through tight spot @ 2,100'. No success working dry. Work through with pump - OK. Able to work up and down without pump. 12/17/2005 00:00 - 01:00 1.00 DRILL P SURF Continue POH for 9 5/8" casing from 2,028' to 1000'. Worked intermittent drag 20-25k over pull from 1,900' to 1,650' 01:00 - 02:00 1.00 DRILL P SURF Stand back 8 stands HWDP and jar stand from 1,000' to 168'. 02:00 - 04:00 2.00 DRILL P SURF Pump 5 bbls water through BHA to clean same. Lay down BHA #2. 04:00 - 05:00 1.00 DRILL P SURF Clear and clean floor. Lay down vendor tools. 05:00 - 07:00 2.00 CASE P SURF Rig up to run 9 5/8" surface casing. Make dummy run with casing hanger. 07:00 - 19:00 12.00 CASE P SURF PJSM. Make up and baker-loc shoe track. Check floats - OK. RIH with 88 joints of 9 5/8" 40# L-80 BTC casing. Make up to mark with 8,600 ftllbs torque using Best O Life 2000 pipe lubricant. Filled every joint with Frank's fill-up tool. Set down at 1,200'. Work through tight spot from 1,200' to 1,300' with 233 gpm, 240 psi, 100k up wt. Continue RIH from 1,300' to planned casing depth of 3,644'. Circulated down casing @ 2,338' to 2,380', 3,158' to 3,238', 3,521' to 3,603' @ 222 gpm, 450/500psi. Landed casing on hanger with PU - 175k, SO - 90k. 19:00 - 19:30 0.50 CASE P SURF 19:30 - 22:30 3.00 CEMT P SURF 22:30 - 00:00 1.50 CEMT P SURF 12/18!2005 00:00 - 02:00 2.00 CEMT P t SURF Ran total of 88 joints 9 5/8" 40# L-80 BTC casing Float Shoe @ 3,644' Float Collar @ 3,559' (1) 10' 9 5!8" space out pup joint under hanger 25 Halliburton bow spring centralizers 3 stop rings Rig down fill-up tool, rig up cementing head. Circulate and condition mud to 16 YP, 59 vis, 9.3 ppg MW. Staged pumps up to 10 bpm, 580 psi. Reciprocated pipe 12' strokes throughout circulation. PU - 190k, SO - 100k. No mud losses. `Held cementing PJSM with all involved parties while circulating. Switch valves to Dowell and pump 5 bbls. of fresh water @ 4 BPM. Test lines to 3,500. Pump 20 bbls of CW-100 @ 6 BPM, followed by 80 bbls. of Mudpush II @ 6 BPM. Drop bottom plug. Pump 446 bbls., 563 sx. of 10.7 ppg. Arctic Set Lite ,lead slurry @ 7 BPM, followed by 64 bbls., 296 sx of 15.8 ppg Class 'G' tail slurry @ 3 BPM. Followed by 15 bbls of 16.5 ppg Durastone slurry. Drop top plug and chase with 10 bbls. of water. Swap over to rig and chase plug with mud @ 7 bbls. per minute. Continue displace cement with rig pumps with total of 261 bbls of mud @ 7 bbls. per minute Slow to 3 BPM 20 bbls. Prior to bump. Bump plug and pressure up to 1200 PSI and hold for 5 Printed: x/9/2006 9:43:02 AM BP Page 4 of 14 Operations Summary Report Legal Well Name: L-123 Common W ell Name: L-123 Spud Date: 12/14!2005 Event Nam e: DRILL+C OMPLE TE Start : 12/13/2005 End: 1/6/2006 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 1/6/2006 Rig Name: NABOR S 9ES Rig Number: Date ~ From - To , Hours ~ Task ~ Code NPT ' Phase ~ Description of Operations 12/18/2005 00:00 - 02:00 2.00 CEMT P SURF minutes. Check floats - OK. Bumped plug @ 01:30 hr. Reciprocated pipe throughout cement job until 5 min into dispiacing with mud. Had full, 100% returns throughout job. 'Returned total of 110 bbis 10.7 ppg lead cement to suface. 02:00 - 04:00 2.00 CEMT P SURF Flush and blow down surface equipment. Rig down cement head, back out and lay down landing joint, flush diverter knife valve and surface stack. Rig down casing equipment. 04:00 - 06:30 2.50 DIVRTR P SURF Nipple down diverter stack and riser. Secure diverter stack in cellar. 06:30 - 09:00 2.50 WHSUR P SURF Bring in casing head and tubing spool into cellar and install same. Tested metal to metal seals to 1,000 psi - 10 minutes - OK. 09:00 - 12:30 3.50 BOPSU P SURF Change out riser nipple flange, NU BOPE. 12:30 - 13:30 1.00 BOPSU P SURF Function test BOPE, check for hydraulic leaks. Rig up to test BOPE 13:30 - 17:00 3.50 BOPSU P SURF Pressure test BOPE and related surface equipment. 250 psi 1 4,000 psi -high pressure test on all rams and valves, 250 psi 1 3,500 psi -pressure test on annular preventer. Hold all tests for 5 minutes each. Witnessing of test was waived by AOGCC rep. Chuck Scheve. Test was witnessed by BP W SL Bill Decker and NAD TP Bill Bixby. 17:00 - 18:00 1.00 BOPSU P SURF Blow down all lines, rig down test equipment, install wear bushing. 18:00 - 19:00 1.00 BOPSU P SURF Service rig and top drive. 19:00 - 00:00 5.00 DRILL P INT1 Pick up 4" 15.7# HT-40 drill pipe 1 X 1 and stand back in derrick. (23 stands, 2,174') 12/19/2005 00:00 - 03:30 3.50 DRILL P INT1 RIH picking up singles 1 X 1 with 110 jts 4" 14# HT-40 drill pipe to 3,492' 03:30 - 05:00 1.50 DRILL P INTi POH standing back drill pipe from 3,492' to surface. 05:00 - 06:00 1.00 DRILL P INTi RIH picking up singles 1 X 1 with 23 jts 4" 14# HT-40 drill pipe to 713' 06:00 - 06:30 0.50 DRILL P INT1 POH standing back drill pipe from 713" to surface. 06:30 - 07:30 1.00 DRILL P INT1 Clean rig floor, bring vendor tools to rig floor. 07:30 - 10:00 2.50 DRILL P INT1 PJSM, pick up, make up 8.75" BHA #3 per directional driller. RIH with 4" HWDP. 10:00 - 11:00 1.00 DRILL P INT1 Slip and cut drilling line 88'. 11:00 - 11:30 0.50 DRILL P INT1 Shallow hole test MWD - OK. 524 gpm, 840 psi. 11:30 - 14:00 2.50 DRILL P INT1 RIH with BHA #3 from 675' picking up 4" 14# HT-40 drill pipe to 3,005'. 14:00 - 15:00 1.00 DRILL P INT1 RIH with BHA #3 from 3,005' on 4" HT-40 drill pipe out of derrick to 3,484'. 15:00 - 15:30 0.50 DRILL P INT1 Circulate bottoms up @ 500 gpm, 1900 psi. 15:30 - 16:00 0.50 DRILL P INT1 Pressure test 9 5J8" casing to 3,500 psi - 30 minutes - 0 pressure loss. 16:00 - 18:00 2.00 DRILL P INT1 Wash down from 3,484' to float Collor @ 3,559'. Tagged cement stringers @ 3,531'. Drill out shoe track from 3,559' to 3,644', Rat hole from 3,644' to 3,650'. Drill 20' new hole from 3,650' to 3,670'. 500 gpm, 1,800 psi, 50 rpm, 5-6k TO, PU - 120k, SO - 65k, RT - 85k, WOB - 5k. New hole ART - .11 hrs. 18:00 - 19:00 1.00 DRILL P i INT1 Displace well from 9.3 ppg mud to 8.8 ppg LSND mud @ 525 gpm, 1,060 psi. 19:00 - 19:30 0.50 DRILL P INT1 Perform LOT to EMW of 12.92 ppg, 8.8 ppg MW. 19:30 - 22:30 3.00 DRILL ~ N ~ DFAL ~ INTi Monitor well - OK. POH for MWD failure from 3,644' to 931'. Printed: 1/9/2006 9:43:02 AM BP Page 5 of 14 Operations Summary Report Legal Well Name: L-i23 Common W ell Name: L-123 Spud Date: 12/14/2005 Event Nam e: DRILL+C OMPLE TE Start : 12/13/2005 End: 1/6/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 1/6/2006 Rig Name: NABOB S 9ES Rig Number: Date ! From - To , Hours ! Task i Code ~ NPT ~ Phase ' Description of Operations - 12/19/2005 - 19:30 - 22:30 - 3.00 DRILL N DFAL INT1 PU - 120k, SO - 65k. 22:30 - 00:00 1.50 DRILL N DFAL INT1 PJSM on nuclear source. Stand back HWDP and lay down MWD. 12/20(2005 00:00 - 02:00 2.00 DRILL N DFAL 1NT1 Check bit - OK. Change out MWD. PJSM on nuclear source. Load source. 02:00 - 02:30 0.50 DRILL N DFAL INT1 RIH with BHA #4 on HWDP to 934'. Shallow hole test MWD - OK. 02:30 - 04:00 1.50 DRILL N DFAL INT1 RIH with BHA #4 on 4" HT-40 drill pipe to 3,580'. 04:00 - 04:30 0.50 DRILL P INT1 Circulate to shear mud prior to establishing benchmark ECD's. Washed from 3,580' to 3,635'. 04:30 - 05:00 0.50 DRILL P INT1 Establish benchmark ECD's. Cale. ECD - 9.38 ppg 05:00 - 15:30 10.50 DRILL P INT1 Directionally drill 8 3/4" hole from 3,670' to 5,565'. 588 gpm, 2,360 psi on bottom, 2,060 psi off bottom, 80 rpm, 7k TO on, 6k TO off. PU - 128k, SO - 87k, RT - 99k. 15:30 - 16:00 0.50 DRILL P INT1 Circulate high vise sweep surface to surface at 588 gpm, 2,030 psi, 80 rpm, 5k TO. Saw no appreciable amount of cuttings returned to surface. 16:00 - 00:00 8.00 DRILL P INT1 Directionally drill 8 3/4" hole from 5,565' to 6,511'. 588 gpm, 2,450 psi on bottom, 2,300 psi off bottom, 80 rpm, 6k TO on, 4k TO off. PU - 124k, SO - 91 k, RT - 107k. CECD - 9.79, AECD - 10.38. Daily ART - 5.82, Daily AST - 1.65. 12/21/2005 00:00 - 03:30 3.50 DRILL P INT1 Directionally drill 8 3/4" hole from 6,511' to 7,265', 588 gpm, 2,710 psi on bottom, 2,410 psi off bottom, 80 rpm, 7k TO on, 5k TO off, PU - 128k, SO - 96k, RT - 112k, CECD - 9.8, AECD - 10.6. 03:30 - 04:30 1.00 DRILL P INT1 Circulate to reduce ECD's - 588 gpm, 2,410 psi -final AECD - 10.24. 04:30 - 12:00 7.50 DRILL P INT1 Directionally drill 8 3/4" hole from 7,265' to 8,125, 588 gpm, 3,000 psi on bottom, 2,700 psi off bottom, 80 rpm, 7k TO on, 5k TO off. PU - 139k, SO - 99k, RT - 118k. AST - 1.38, ART - 4.69, CECD - 10.09, RECD - 11.00. 12:00 - 13:00 1.00 DRILL P INTi Directionally drill 8 3/4" hole from 8,125' to 8,316', 588 gpm, 3,000 psi on bottom, 2,700 psi off bottom, 80 rpm, 7k TO on, 5k TQ off. PU - 145k, SO - 102k, RT - 118k, CECD - 10.09, AECD - 11.2. 13:00 - 14:00 1.00 DRILL P INT1 Circulate to reduce ECD's - 600 gpm, 3,000 psi -final AECD - 10.8. 14:00 - 00:00 10.00 DRILL P INTi Directionally drill 8 3/4" hole from 8,316' to 9,173', 588 gpm, 3,600 psi on bottom, 3,300 psi off bottom, 80 rpm, 7k TO on, 5k TO off. PU - 150k, SO - 110k, RT - 126k, AST - 2.95, ART - 2.45, CECD - 10.03, AECD - 10.92 12/22/2005 00:00 - 18:00 18.00 DRILL P INT1 Directionally drill 8 3/4" hole with difficulty sliding from 9,173' to 9,875', 530 gpm, 3,750 psi on bottom, 3;550 psi off bottom, 80 rpm, 7k TO on, 5k TQ off. PU - 162k, SO - 114k, RT - 132k, CECD - 11.57, RECD - 11.74. AST - 9.61, ART - 0.88. Weight up on the fly to 10.6 ppg LSND at 9,400'. 18:00 - 20:00 2.00 DRILL P INT1 Circulate to remove any possible cuttings beds and improve ability to slide - 540 gpm, 3,550 psi, 80 rpm, 5k TO. 20:00 - 20:30 0.50 DRILL P INT1 Directionally drill 8 3/4" hole from 9,875' to 9,882', 530 gpm, 3,750 psi on bottom, 3,550 psi off bottom, 80 rpm, 7k TO on, 5k TO off. PU - 162k, SO - 114k, RT - 132k, CECD - 11.57, AECD - 11.74. Unable to slide. Confer with town and agree to trip for bit/BHA. MW in - 10.6, MW out - 10.6. Printed: 1/912006 9:43:02 AM BP Page 6 of 14 Operations Summary Report Lega{ Well Name: L-123 Common W ell Name: L-123 Spud Date: 1 211 4/2 005 Event Nam e: DRILL+C OMPLE TE Start : 12/13/2005 End: il6/2006 Contractor Name: NABOR S ALASK A DRI LLING I Rig Release: 1!612006 Rig Name: NABOR S 9ES Rig Number: Date ~ From - To ~ Hours Task Code ! NPT ~ Phase ' Description of Operations 12122!2005 20:30 - 00:00 3.50 DRILL P INT1 Monitor the well -stable. Backream out of the hole to 8,890' placing the upper ghost reamer in the surface casing shoe and wiping the UG4 - 530 gpm, 3,600 psi, 80 rpm, 5k TO. 12!23!2005 00:00 - 08:00 8.00 DRILL P INTi Attempt POH -hole trying to swab. Continue to backream out of the hole from 8,890' to 6,606', placing the lower ghost reamer in the surface casing shoe - 530 gpm, 3,600 psi, 80 rpm, 5k TO. 08:00 - 12:00 4.00 DRILL P INT1 Monitor well -stable. Attempt to pull pipe without pumps - good. Pump dry job and POH standing back 4" DP to 290' without swabbing. PU - 125k, SO - 90k. 12:00 - 14:00 2.00 DRILL P INT1 Monitor well -stable. Hold PJSM for handling nuclear source. Stand back the jar stand, nm dc's, pull source and continue to POH with BHA#4. Function the Blind/shear rams. 8-3/4" DSX619M-D1 graded: 2-2-CT-T-X-1/16-BT-BU. 14:00 - 14:30 0.50 DRILL P INT1 Clean and clear the rig floor. 14:30 - 16:30 2.00 DRILL P INT1 Changeout the motor and the bit and RIH with BHA#5 to 257'. Hold PJSM prior to loading the nuclear source. BHA#5: Rebuilt 8-3/4" DSX70FVPV, 6-3/4" 4/5 7 stg motor with 1.5 degree bend, float sub, nm stab, LWD{CDR, MWD, ADN, 2 x nm dc's, saver sub, 1 x 5" HWDP, jars, 1 x 5" HWDP. 16:30 - 17:00 0.50 DRILL P INT1 Shallow test MWD -good. 17:00 - 18:00 1.00 DRILL P INT1 XO and RIH with 4" HWDP and 4" DP to 3,600'. 18:00 - 19:30 1.50 DRILL P INT1 Slip and cut drilling line. Service top drive, crown and blocks. 19:30 - 00:00 4.50 DRILL P INTi Continue RIH with 4" DP from the derrick. Install ghost reamer in the drill string 5,277' behind the bit. Precuationary wash and ream the last stand to bottom - no excess fill observed. Orient and prepare to drill 8-3/4" hole directionally ahead. PU - 173k, SO - 108k 12/24/2005 00:00 - 12:00 12.00 DRILL P INTi Directionally drill 8 3/4" hole from 9,882' to 10,377', 500 gpm, 3,680 psi on bottom, 3,500 psi off bottom, 60 rpm, 8k TO on, 7k TO off. PU - 165k, SO - 120k, RT - 130k. AST - 6.72, ART - 0.2, CECD - 11.02, AECD - 11.39 12:00 - 23:30 11.50 DRILL P INT1 Directionally drill 8 3/4" hole from 10,377' to 11,406' (TD), 495 gpm, 4,100 psi on bottom, 3,850 psi off bottom, 60 rpm, 9k TQ on, 7k TO otf. PU - 175k, SO - 109k, RT - 138k. AST - 2.73, ART - 5.37, CECD - 11.16, RECD - 11.71 23:30 - 00:00 0.50 DRILL P INT1 Circulate a high visc sweep at 500 gpm, 3,900 psi. No appreciable amount of cuttings returned to surface. 12/25J2005 00:00 - 01:30 1.50 DRILL P INT1 Circulate and condition mud for trip out of the hole, 495 gpm, 3850 psi, CECD - 11.17, AECD - 11.57 MW in - 10.6, MW out - 10.6 01:30 - 05:00 3.50 DRILL P INT1 Backream out of the hole from 11,406' to 9,820', 60 rpm, 495 gpm, 3,850 psi, 7k TO, CECD - 11.17. Backream at rate maintaining ECD below 12.1. Lost 25 bbls. 05:00 - 09:00 4.00 DRILL P INT1 POH from 9,820'. Pulled 3 stands without swabbing. Pump dry job while pulling another stand. Blow down the top drive. POH to the top of the BHA at 259' without swabbing and losses 6 bph. 09:00 - 12:00 3.00 DRILL P INT1 Hold PJSM for LD of BHA and handling of nuclear source. LD 8-3/4" BHA #5 from 259'. LD XO, 1 x 5" HWDP, Jars, 1 x 5" HWDP saver sub and 2 x nm dc's. Remove nuclear source and LD ADN. LD MWD, LWD/CDR, nm stab, float sub, motor and bit. Re-built DSX70FVPV graded: 1-1-WT-A-X-I-CT-TD. Printed: 1/9/2006 9:43:02 AM BP Operations Summary Report Page 7 of 14 Legal Well Name: L -123 Common Well Name: L -123 Spud Date: 12/14/2005 Event Name: DRILL+C OMPLE TE Start: 12/1312005 End: 1/6!2006 Contractor Name: NABOB S ALASK A DRILLING I Rig Release: 1/6/2006 Rig Name: NABOB S 9ES Rig Number: Date ~ From - To Hours Task ~ Code ! NPT Phase Description of Operations 12/25/2005 09:00 - 12:00 3.00 DRILL P INT1 Total losses from 0000-1200: 72 bbls. 12:00 - 12:30 0.50 DRILL P INT1 Clean and clear the floor. Pull the wear ring. 12:30 - 13:30 1.00 BOPSU P INT1 Change out the top set of rams to 7", function rams and test the door seals to 3,500 psi -good. 13:30 - 14:30 1.00 CASE P INT1 RU the rig floor to run 7", 26#, L-80, BTC-m longstring -change out the bails and make a dummy run with the casing hanger. 14:30 - 21:00 6.50 CASE P INT1 Hold PJSM for running casing. PU shoe track, Bakerlok and RIH. RU the fillup tool and fill pipe. Check floats -holding. RIH with 7" casing and ES cementer to the surface casing shoe at 3,644'. Connections torqued to mark at with 7,500 ft-Ibs and BOL 2000NM thread lubricant. Connections above and below the ES Cementer stage tool were Bakerlok'd. 21:00 - 21:30 0.50 CASE P INT1 Circulate 1.5 times bottoms up at 3,644' -the surface casing shoe. Stage up the pumps to 6 bpm, 475 psi - PU - 114k, SO - 92K. 21:30 - 00:00 2.50 CASE P INT1 Continue RIH with 7" casing to 4,553'. Break circulation every 10 joints for 10 minutes. Total losses from 1200 - 0000: 21 bbls 12126!2005 00:00 - 14:00 14.00 CASE P INT1 Continue RIH with 7", 26#, L-80 BTC-m casing from 4,553' to 11,393'. Break circulation every 10 joints for 10 minutes. All connections torqued to 7,500 ft-Ibs and used BOL2000NM thread lubricant. 14:00 - 14:30 0.50 CASE P INT1 RD the fillup tool and RU cement head. 14:30 - 17:30 3.00 CEMT P INT1 Circulate and condition the mud while staging up the pumps to 7 bpm, 900 psi. 17:30 - 18:00 0.50 CEMT P INTi Hold PJSM for the cement job with all personnel. 18:00 - 18:30 0.50 CEMT P INT1 Continue circulating while batching up the 15.8 ppg tail cement and the 11.5 ppg spacer. 18:30 - 21:00 2.50 CEMT P INT1 Line up to Dowell. Pump 5 bbls of fresh water ahead. Shut down and pressure test lines to 4,000 psi. Pump 20 bbls of 11.5 ppg Mudpush II spacer at 4 bpm, ICP - 450 psi, FCP - 450 psi. Load and drop the bottom bypass plug. Pump 47 bbls of 12.5 ppg LiteCRETE lead cement at 5 bpm, ICP - 570 psi and 4 bpm, FCP - 425 psi. Pump 51 bbls of 15.8 ppg GASBLOK tail slurry at 4.5 bpm, ICP - 425 psi, FCP - 260 psi. Close the annular preventer to reduce the rate of cement falling. Load the top plug and the 2nd stage closing plug. Open the annular preventer and kick out the top plug with 5 bbls of water from Dowell. Turn over to the rig and displace with 428 bbls of 10.6 ppg LSND drilling fluid. Catch the cement after 15 bbls of displacement. Displace initially at 6 bpm, 377 psi. Pressure gradually increased to 490 psi by 128 bbls into the displacement. Pressure held fairly constant until 306 bbls into the displacement when the rate was dropped to 3 bpm, 240 psi to for the top plug to pass the stage tool and the bypass plug to land. At 341 bbls into the displacement, the rate was brought back up to 6 bpm, 520 psi. Pressure increased to 860 psi by 396 bbfs when the rate was reduced to 4 bpm. The rate was subsequently dropped to 3 bpm and then 2 bpm keeping the pressure below 800 psi. The plug was bumped with 764 psi at 428 bbls of fluid pumped and 93% efficiency. The pressure i was increased to 1,500 psi and held for 5 minutes -good. The pressure was bled off and the floats were holding. Good lift Printed: 1!9/2Q06 9:43:02 AM BP Operations Summary Report Legal Well Name: L-123 Common Wel! Name: L-123 Event Name: DRILL+COMPLETE Start: 12/13/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/6/2006 Rig Name: NABOBS 9ES Rig Number: Date I From - To I Hours i Task 12/26/2005 18:30 - 21:00 2.50 CEMT 21:00 - 00:00 3.00 CEMT I Code j NPT Phase P INT1 P INTi 12/27/2D05 ~ 00:00 - 01:30 ~ 1.50 ~ CEMT ~ P 01:30 - 04:00 I 2.501 CEMT I P 04:00 - 04:30 I 0.501 CEMT I P 04:30 - 05:30 I 1.001 CEMT I P 05:30 - 06:30 I 1.001 WHSUR I P 06:30 - 07:00 I 0.501 WHSUR I P 07:00 - 09:00 I 2.00{ BOPSUFIP 09:00 - 09:30 0.50 WHSUR P 09:30 - 12:00 2.50 STWHIP P INTi INT1 INT1 INT1 INT1 INT1 INT1 INT1 WEXIT Page 8 of 14 Spud Date: 12/14/2005 End: 1 /612006 Description of Operations and full returns. CIP - 2253 hours 12/26!2005. Increase the pressure to 3,300 psi and observe the opening of the ES Cementer. Circulate and stage the pumps up to 6 bpm, 790 psi. Circulated 15 bbls of lead cement to surface. Hold PJSM. Continue circulating while hatching up the 12.5 ppg LiteCRETE slurry and the 11.5 ppg Mudpush II spacer. Line up to Dowell. Pump 60 bbls of CW100 at 5.5 bpm, ICP - 620 psi, FCP - 750 psi. Switch to 11.5 ppg Mudpush II spacer and pump 45 bbls at 5 bpm, ICP - 700 psi, FCP - 612 psi. Switch to 12.5 ppg LiteCRETE cement and pump 141 bbls at 5 bpm, ICP - 663 psi, FCP - 400 psi. Drop the closing plug and kick out with 5 bbls of fresh water. Line up to displace with the rig and 10.6 ppg LSND drilling fluid. Caught the cement after 3 bbls pumped. Displaced at 5.25 bpm, ICP - 420 psi. Pressure gradually increased to 450 psi by 41 bbls pumped. Pressure held until 64 bbls displaced and then started to gradually decrease to 245 psi by 140 bbls displaced. Pressure increased gradually to 650 psi with 230 bbls displaced. Rate was dropped to 4 bpm, ICP - 570 psi. Pressure increased to 665 psi by 254 bbls displaced. The rate was dropped to 3 bpm and then 2 bpm attempting to stay below 700 psi. The plug was bumped with 2 bpm, 994 psi and 328 bbls pumped and 93% efficiency. Full returns throughout the cement job and good lift was seen. CIP - 0400 12/27/2005. Estimate 60 bbls of CW 100 and 10 bbls of spacer returned to surface. Pressure up on the plug to 2,200 psi and hold for 5 minutes to ensure ES Cementer shut. Bleed off and check for flow - no flow, cementer shut. RD the cement head, casing handling tools, long bails and LD landing joint. PU test joint and install packoff. RILDS. Test packoff to 5,000 psi -good. Line up and inject 10 bbls of 10.6 ppg drilling fluid down the OA to ensure clear. Changeout the 7" rams to 3.5" x 6". Test the door seals to 250/3,500 psi -good Install wear ring and RU short bails. MU Cleanout BHA #6 and RIH to 1,045'. BHA#6: 6-118" RR Hughes ATJ4, bit sub, 9 x 4-3/4" DC's, jars, 24 x 4" HWDP. Simops: Compressive strength test on the 2nd stage cement > 500 psi. Inject 154 bbls of 10.6 ppg LSND drilling fluid to clear the OA prior to freeze protecting - 2 bpm, 800 psi. 12:00 - 15:00 3.00 STWHIP P WEXIT RIH with 4" DP from 1,045' to 8,606'. Wash down and tag the ES Cementer at 8,696'. 15:00 - 16:30 1.50 STWHIP P WEXIT Drili out the ES cementer - 250 gpm, 1,295 psi, 9.5k TO, 15k W OB. 16:30 - 17:30 1.00. STWHIP P WEXIT Circulate bottoms up - 400 gpm, 2,350 psi. 17:30 - 18:30 1.00 STWHIP P WEXIT RIH with 4" DP from the derrick from 8,696' to 11,044'. 18:30 - 19:30 1.00 STWHIP P WEXIT Circulate bottoms up prior to casing test - 385 gpm, 2,850 psi. 19:30 - 20:30 1.00 CASE P INT1 RU to pressure test the 7" casing. Test the 7" casing to 4,000 psi -chart and hold for 30 minutes -good test. RD testing equipment. Printed: 1/9/2006 9:43:02 AM BP Operations Summary Report Page 9 of 14 Legal Well Name: L-123 Common Well Name: L-123 Spud Date: 12/14/2005 Event Name: DRILL+COMPLETE Start: 12/13/2005 End: 1!6!2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11612006 Rig Name: NABORS 9ES Rig Number: Date li From - Ta 'Hours ' Task i Code ~ NPT ' Phase I Description of Operations 12/27/2005 20:30 - 21:30 1.00 STWHIP P WEXIT Circulate a high visc sweep from surface to surface to remove anything from the wellbore prior to RIH with EZSV on DP - 450 gpm, 3,800 psi, 12k TQ, 105 rpm, PU - 195k, SO - 70k, ROT - 116. 3 pieces of rubber returned to the surface. 21:30 - 23:00 1.50 STWHIP P WEXIT Slip and cut drilling line. Service the top drive, crown and blocks. 23:00 - 00:00 1.00 STWHIP P WEXIT Monitor the well -stable. Pump dry job and POH to 10,112'. 12!2812005 00:00 - 03:00 3.00 STWHIP P WEXIT POH with 4" DP from 10,112 to 1,045'. Simops: RU LRHOS and freeze protect the OA with 82 bbls of dead crude at 2.5 bpm, 1,500 psi. SITP - 800 psi. RD LRHOS 03:00 - 04:00 i 1.00 STW W P P WEXIT LD cleanout BHA#6. Stand back 8 stands of 4" HWDP, LD jars, LD xo, stand back 3 stands of DG's, LD bit sub and bit. 04:00 - 05:00 1.00 BOPSU P WEXIT Drain the stack and pull the wear ring. Install the test plug and RU to test BOPE. 05:00 - 08:30 3.50 BOPSU P WEXIT Test BOPE and all related valves to 250 psi low and 4,000 psi high. Test the annular preventer to 250 psi low and 3,500 psi high. No test failures. Witness of the test was waived by John Crisp of the AOGCC. Witness of the test was done by BP Wellsite Leader Alan Madsen and Nabors Rig Supervisor Kelly Cozby. 08:30 - 09:00 0.50 STWHIP P WEXIT Install wear ring and RD the test joint. Blow down the choke manifold and kill line. 09:00 - 10:00 1.00 STWHIP P WEXIT Bring tools to the rig floor. Make a dummy run with the setting tool. MU EZSV, setting tool and ported sub. 10:00 - 17:00 7.00 STWHIP P WEXIT RIH with EZSV with 3 stands of DC's, 8 stands of 4" HWDP and 4" DP and place the EZSV top on depth at 10,743'. 17:00 - 17:30 0.50 STWHIP P WEXIT Spot EZSV on depth and put 38 turns to the right. PU 10k overpull and hold for 5 minutes. PU 15k overpull and hold for 5 minutes. PU and shear off with 50k overpull. Slackoff and verify plug set at 10,743' with 20k. 17:30 - 21:30 4.00 STWHIP P WEXIT Monitor the well -stable. Pump dry job and POH to the top of the BHA at 1,045'. 21:30 - 22:15 0.75 STWHIP P WEXIT Stand back the 8 stands of 4" HWDP and 3 stands of DC's. LD the setting tool and ported sub 22:15 - 22:45 0.50 STWHIP P WEXIT Clean and clear the floor. Bring Baker Whipstock tools to the rig floor. 22:45 - 00:00 1.25 STWHIP P WEXIT MU Whipstock BHA and RIH -Bottom trip anchor, Gent Whipstock, starting mill, bit sub, upper string mill, 1 joint 3-112" HWDP, float sub, MWD and bumper sub. 12/29/2005 00:00 - 01:00 1.00 STWHIP P WEXIT Continue to MU Whipstock BHA and RIH - 3 stands 4-3/4" DC's, xo, 8 stands 4" HWDP to 1,118'. Shallow test MWD - good. 01:00 - 07:30 6.50 STWHIP P WEXIT RIH with Whipstock BHA on 4" DP from the derrick to 10,648' - 1.5 minutes per stand and easy in and out of the slips. PU - 205k, SO - BOk, 300 gpm, 3,034 psi. 07:30 - 08:30 1.00 STWHIP P WEXIT Orient Whipstock at 10,648' -positioned whipstock at 31 RHS. Wash down and tag the EZSV on depth at 10,743'. Set the anchor with 15k set down. PU 10k over to verify anchor set. Set down 30k and shear off of the whipstock. PU free of whipstock -TOW @ 10,723'. 08:30 - 10:30 2.00 STWHIP P WEXIT Pump 75 bbls of water and 50 bbls high visc sweep. Displace 1 ~ the well over to 9.4 ppg FloPro at 350 gpm, 2,452 psi. Printed: 1/9/2006 9:43:02 AM gp Page 10 of 14 Operations Summary Report Legal Wel{ Name: L-123 Common W ell Name: L-123 Spud Date: 12/1412005 Event Nam e: DRILL+C OMPLE TE Start : 12/13/2005 End: 1/6/2006 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 1/6/2006 Rig Name: NABOB S 9ES Rig Number: Date ~ From - To ' Hours ~ Task ~ Code ' NPT Phase ~ ! Description of Operations - - - I - - - -. - -- - ~ - - - ~ - _ _ _ - - - _ _ - - 12/29/2005 10:30 - 15:30 I 5.00 STWHIP P WEXIT Mill window from 10,723' to 10,736' - PU - 169, SO - 97, ROT - 125, TO - 9k, 350 gpm, 2,600 psi, 120 rpm. Drill 20' of new hole, measured from the center of the window, to 10,750'. 15:30 - 17:00 1.50 STWHIP P WEXIT Work pipe through the window several times. Pump high visc sweep surface to surface - 350 gpm, 2,600 psi. 17:00 - 17;30 0.50 STWHIP P WEXIT Place the Starting Mill inside the window and perform an FIT to 11 ppg EMW with 9.4 ppg fluid and 540 psi surface pressure at 6,444' TVD -good test. 17:30 - 21:30 4.00 STWHIP P WEXIT Monitor the well -stable. Pump dry job and POH from 10,720' to top of the BHA at 1,100'. 21:30 - 23:00. 1.50 STWHIP P WEXIT POH standing back the 4" HWDP and LD the 4-3/4" drill collars. 23:00 - 23:30 0.50 STWHIP P WEXIT LD bumper sub, MWD, float sub, 1 x 3-1/2" HWDP, upper mill, bit sub and starting mill. Starting mill - 1/16" undergauge, upper mill - in gauge. 23:30 - 00:00 0.50 STWHIP P WEXIT Flush the stack and clear the floor of tools. 12130!2005 00:00 - 02:45 2.75 DRILL P PROD1 PJSM for picking up the 6-1/8" BHA and handling the nuclear source. PU BHA#8 and RIH on 4" DP to 1,159'. Test MWD - good. BHA#8: RR7 6-1/8" DSX146H, 4-3/4" motor 1.5 bend 4Rf5S 6 stg, bypass sub w/float, nm stabilizer, MWDlLWD, ADN, 2 x nm flex collars, circ sub, xo, 1 x 4" DP, jars. 02:45 -03:30 0.75 DRILL P PROD1 Slip and cut drilling line. Service the top drive, crown and blocks. 03:30 - 07:30 4.00 DRILL P PROD1 RIH with 6-1/8" BHA#8 on 4" DP and 4" HWDP to 10,623'. Orient the BHA to 30 RHS and slide through the window to 10,740. 07:30 - 08:30 1.00 DRILL P PROD1 With the bit in the open hole and without rotating the drill string, circulate an EP Mud Lube sweep around to coat the casing - 280 gpm, 2,125 psi. 08:30 - 00:00 15.50 DRILL P PROD1 RIH to 10,750'. Directionally drill 6-118" hole from 10,750' to 11,233', taking surveys every 30'. PU - 178k, SO - 100k, ROT - 125k, 280 gpm, 1,960 psi off, 2,500 psi on, 60 RPM, 7.5k TO off, 9.5k TO on, AST - 3.05, ART - 8.13. 12/31/2005 00:00 - 12:00 12.00 DRILL P PROD1 Directionally drill 6-1/8" hole from 11,233' to 11,672', taking surveys every 30'. PU - 177k, SO - 90k, ROT - 127k, 280 gpm, 2,300 psi off, 2,530 psi on, 60 RPM, 7k TO off, 8.5k TQ on, AST - 2.46, ART - 5.44 12:00 - 00:00 12.00 DRILL P PROD1 Directionally drill 6-1/8" hole from 11,672' to 12,365', taking surveys every 30'. PU - 178k, SO - 104k, ROT - 127k, 280 gpm, 2,300 psi off, 2,530 psi on, 60 RPM, 7k TO off, 8.5k TO on, AST - 1.66, ART - 8.53 11il2006 00:00 - 02:15 2.25 DRILL P PROD1 Directionally drill 6-1/8" hole from 12,365' to 12,405' (TD). PU - 170k, SO - 101 k, ROT - 133k, 280 gpm, 2,150 psi off, 2,620 psi on, 60 RPM, 6.1 k TO off, 8.2k TO on, ART - 1.47 02:15 - 02:45 0.50 DRILL P PROD1 Circulate an open hole volume - 280 gpm, 2,200 psi, 60 rpm. 02:45 - 08:00 5.25 DRILL P PROD1 Backream /MAD Pass from 12,405' to 10,825' - 600 fph, 280 gpm, 2,150 psi, 60 rpm, 8k TO. Without pumps - PU - 188k, SO - 113k. 08:00 - 09:30 1.50 DRILL P PROD1 Drop 1-15/16" ball and shear open the circ sub. Circulate bottoms up at 325 gpm, 1,490 psi, 60 rpm, 7.5k TO. 09:30 - 14:00 4.50 DRILL P PROD1 Monitor the well -stable. Pump a dry job and POH standing back 4" DP and 4" HWDP from 10,825' to 217'. 14:00 - 16:00 2.00 DRILL P PROD1 , PJSM for laying down the BHA and removing the nuclear Printed: 1/9/2006 9:43:02 AM BP Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: L-123 L-123 DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 12/13/2005 Rig Release: 1/6/2006 Rig Number: Page 11 of 14 Spud Date: 12/14/2005 End: 1 /6/2006 Date I From - To Hours ' Task '~ Code NPT Phase Description of Operations 1 /1 /2006 14:00 - 16:00 16:00 - 16:30 16:30 - 17:30 17:30 - 00:00 1 /2/2006 00:00 - 03:00 03:00 - 04:00 04:00 - 07:30 07:30 - 08:00 08:00 - 15:00 15:00 - 16:00 16:00 - 18:00 18:00 - 20:30 20:30 - 22:00 2.00 DRILL P PROD1 source. LD 6-1/8" BHA#8. LD jars, 1 x 4" DP, xo, circ sub, 2 x nm dc's, ADN, MWD/LWD, nm stab, bypass sub w/float, motor and bit. RR7 6-1/8" DSX146H graded: 1-1-WT-A-X-I-BU-TD. 0.50 DRILL P PROD1 Service and lubricate the rig and the top drive. 1.00 EVAL P PROD1 Hold PJSM for rigging up and running a-line. RU Schlumberger to run USIT. 6.50 EVAL P PROD1 RIH with USIT. Log from 10,723'. 3.00 EVAL P PROD1 Log with USIT from 10,723' to 3,344'. POH. RD Schlumberger E-line. 1.00 CASE P RUNPRD RU casing handling equipment. 3.50 CASE P RUNPRD PJSM. PU and RIH with 4-1/2" 12.6# L-80 IBT-m liner. PU float shoe joint #1 and RIH. PU landing collar joint #2. MU float collar to the bottom of the landing collar and to the top of joint #1. Shoe track shortened to 41' to accomodate perforation interval. All connections below the landing collar are Bakerloc'd. Fill the pipe and check the floats -holding. PU remaining 4-1/2" liner, pups, HMC hanger and ZXP liner top packer and RIH on a stand of 4" DP to 1,981', PU - 57k, SO - 53k. Ran a total of 44 joints of 4-1/2" 12.6# L-80 IBT-m liner, 2 x 20' pups w/RA tags in the collars and 40 centralizers. Utilized BOL2000NM thread lubricant and torqued connections to mark with 3,900 ft-Ibs. Float Shoe - 12,405' Float Collar - 12,361' Landing Collar - 12,360' RA tag - 11,276' RA tag - 10,559' HMC Liner Hanger - 10,544' ZXP Packer w/11.72' tieback - 10,522' 0.50 CASE P RUNPRD Circulate a liner volume. 7.00 CASE P RUNPRD RIH with 4-1/2" Liner to 10,723' on 4" DP and 4" HWDP filling pipe every 10 stands. MU cement head to a single joint of 4" DP and LD until needed. 1.00 CASE P RUNPRD Circulate and condition the mud prior to entering the open hole - 250 gpm, 1,170 psi. 2.00 CASE P RUNPRD RIH with 4.5" Liner on 4" DP. Tagged fill at 12,401'. MU cement head and circulate down to 12,405'. 2.50 CEMT P ' RUNPRD Circulate and condition mud prior to cement job. Stage up the pumps to 6 bpm, 1,440 psi. PJSM with Schlumberger and the rig team for the cement job. Continue to circulate while batch mixing the 10.5 ppg spacer and the 15.8 ppg cement. 1.50 CEMT P RUNPRD Lined up to Schlumberger. Pumped 5 bbls of fresh water ahead. Shut in and pressure tested the lines to 4,000 psi. Bled off pressure and pumped 10 bbls of CW 100 at 4.5 bpm, ICP - 1,049 psi, FCP - 1,030 psi. Pumped 24 bbls of 10.5 ppg Mudpush II spacer at 4.8 bpm, ICP - 1,100 psi, FCP - 1,030 psi. Pumped 45.5 bbls of 15.8 ppg Gasblok cement slurry at 4.7 bpm, ICP - 943 psi, FCP - 500 psi. Aligned valves and pumped water to wash the cement lines through a "T" on the rig floor. Lined up to the rig, dropped the dart and displaced with 30 bbls of Perf Pill and 9.4 ppg FloPro drilling fluid. ~ Caught the cement after 14 bbls pumped. Continued the Printed: 1/9/2006 9:43:02 AM BP Operations Summary Report Legal Well Name: L-123 Common Well Name: L-123 Event Name: DRILL+COMPLETE Start: 12/13/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/6/2006 Rig Name: NABOBS 9ES Rig Number: Date 'From - To ', Hours Task ', Code 1/2/2006 120:30 - 22:00 1.501 CEMT P 22:00 - 22:15 1 /3/2006 22:15 - 22:45 22:45 - 23:15 23:15 - 00:00 00:00 - 01:00 01:00 - 02:00 02:00 - 07:30 07:30 - 08:00 08:00 - 08:30 08:30 - 09:30 09:30 - 11:00 11:00 - 14:30 14:30 - 20:30 20:30 - 21:00 21:00 - 22:00 22:00 - 00:00 1/4/2006 00:00 - 06:30 06:30 - 07:30 07:30 - 09:30 0.251 CASE I P 0.50 CEMT P 0.50 CEMT P 0.75 CASE P 1.00 CASE P 1.00 CASE P 5.50 CASE P 0.50 CASE P 0.50 PERFO P 1.00 PERFO P 1.50 PERFO P 3.50 PERFO P 6.00 PERFO P 0.50 PERFO P 1.00 PERFOB~ P 2.00 PERFO P Page 12 of 14 Spud Date: 12/14/2005 End: 1 /6/2006 NPT ' Phase Description of Operations RUNPRD displacement at 5 bpm, ICP - 530 psi. FCP - 1,128 psi. Dropped rate to 2 bpm to observe the dart landing in the liner wiping plug with 106 bbls displaced -pipe was reciprocated until this point, when the hole started to get sticky. Brought the rate back up to 4.5 bpm until 122 bbls pumped, FCP - 1,100 psi, when the rate was dropped back to 2 bpm to bump the plug. Bumped the plug with 132 bbls displaced - 95% efficiency, 650 psi prior to bumping the plug - CIP 2200 hours. RUNPRD Pressured up to 2,700 psi to set the hanger, SO 60k and increased pressure to 4,000 to release the running tool. Bled off the pressure and checked the floats -holding. PU to verify liner released and to expose the dogs. Rotated down with 15 rpm while slacking off with 50k. Good indication of packer set. Pressured up to 1,000 psi while pulling up out of the seals. Observed pressure drop off and circulated -30 bbls up the hole. Pull up and position the bottom of the running tool in the middle of the tieback sleeve. RUNPRD Circulated hole clean with spacer and a trace of cement in the returns at 10 bpm, 2,000 psi. RUNPRD RD the cement head and blow down the surface lines. LD 2 x 4" DP pups. RUNPRD Circulate a 50 bbl Safe Clean pill and begin displacing the well over to 9.4 ppg brine - 430 gpm, 2,035 psi. RUNPRD Continue displacing the well over to 9.4 ppg brine - 290 gpm, 1,170 psi. RUNPRD Clean trip tank and surface mud cleaning equipment. RUNPRD POH standing back 4" DP and LD 4" HWDP from 10,522'. LD Baker running tooi. RUNPRD Clean and clear rig floor. OTHCMP Service top drive and crown sheaves. OTHCMP Rig up and pressure test 4-1/2" liner to 4,000 psi - 30 min - 0 psi loss. Rig down test equipment. OTHCMP Rig up to run DPC pert guns. OTHCMP Pick up, make up 2-7/8" HSD 6SPF DPC perforating assembly per Schlumberger to 1,938'. OTHCMP RIH with DPC perforating assembly on 4" HT-40 drill pipe from 1,938' to landing collar on depth at 12,360'. Pick up to 12,340' to position pert guns on firing depth. PU - 175k, SO - 105k. OTHCMP Perforate well, 6SPF from (10,915' to 10,960'), (10,975' to 11,090'), (11,110'to 11,140'), (11,180'to 11,210'), (11,830'to 11,850'), (11,945'to 11,980'), (12,030'to 12,080'), (12,150'to 12,190'), (12,270' to 12,340'). 435' total, 2,610 total shots. Had positive indication of both heads fired. 5 bbl initial loss. OTHCMP POH 17 stands from 12,340' to 10,725'. 5 BPH loss rate OTHCMP Circulate bottoms up Q 245 gpm, 1,020 psi. 5 BPH loss rate. Monitor well, static loss rate - 0 bbls. Pump dry job. Total brine losses from perforating - 20 bbls. 6.50 PERFO P OTHCMP POH with DPC pert guns, laying down 4" HT-40 drill pipe from 10,725' to 1,938'. 0 bbl loss rate 1.00 PERFO P OTHCMP Rig up and lay down 15 jts. 2 7/8" PAC drill pipe. 2.00 PERFO P OTHCMP PJSM for laying down pert guns. Lay down 16 guns. 'All guns fired. Printed: 1/9/2006 9:43:02 AM BP Page 13 of 14 Operations Summary Report Legal Well Name: L-123 Common Well Name: L-123 Spud Date: 12/14/2005 Event Name: DRILL+COMPLETE Start: 12/13/2005 End: 1/6/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/6/2006 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours ~~ Task I Code NPT ~ Phase ' Description of Operations I 1!412006 09:30 - 11:00 1.50 PERFO P OTHCMP Rig up and lay down 18 jts. 2 7/8" PAC drill pipe. 11:00 - 13:00 2.00 PERFO P OTHCMP Rig up and lay down 26 guns. 'All guns fired. Clear rig floor. 13:00 - 14:30 1.50 PERFO P OTHCMP RIH with remaining 4" HT-40 drill pipe from derrick to 3,008'. 14:30 - 15:30 1.00 PERFO P OTHCMP Cut and slip drilling line 85'. 15:30 - 17:30 2.00 PERFO P OTHCMP POH laying down 4" HT-40 drill pipe. 17:30 - 18:00 0.50 BUNCO RUNCMP Pull wear bushing, drain BOP stack. 18:00 - 20:00 2.00 BUNCO P RUNCMP Rig up to run completion string. Make tubing hanger dummy run. 20:00 - 00:00 4.00 BUNCO RUNCMP PJSM. Make up tail pipe and packer assembly and RIH to 1,880' with 4.5" 12.6# L-80 TCII tubing completion string. Baker-Lok all connections below packer. Make up connections to 3,850 fUlbs with computer assisted torque turn. Utilized Jet Lube Seal Guard lubricant. 1 /5/2006 No brine filuid loss for the day. 00:00 - 08:30 8.50 BUNCO P RUNCMP Continue RIH with 4.5" 12.6# L-80 TCII completion string from 1, 880' to 8, 650'. 08:30 - 10:00 1.50 BUNCO WAIT RUNCMP Stopped operation due to Nabors Casing rep. unable to continue due to excessive hours and no available relief. 10:00 - 13:30 3.50 BUNCO RUNCMP Change out casing operators. Continue RIH with 4.5" 12.6# L-80 TCII completion string from 8,650' to liner top @ 10,522'. Space out and land tubing. PU - 125k, SO - 90k. 13:30 - 14:00 0.50 R 14:00 - 18:00 4.00 R 18:00 - 19:30 19:30 - 20:00 20:00 - 22:00 22:00 - 00:00 1 /6/2006 00:00 - 03:00 1.50 0.501 WHSUR I P 2.00 WHSUR P 2.00 WHSUR P 3.001 WHSURIP Ran total of 249 jts of 4.5" 12.6# L-80 TCII tubing. WLEG @ 10,522.51'. XN Nipple 3.725" ID w! No go @ 10,500'. X Nipple 3.813" ID w/ RHC-M Plug @ 10,480'. 7" X 4.5" Baker S-3 Hydroset Packer @ 10,466'. X Nipple 3.813" ID @ 10,425'. GLM #1:4.5" X 1" KBG-2-1 R, 9CR w/ DCK-2 Shear Valve @ 6,641'. GLM #2: 4.5" X 1" KBG-2-1 R, 9CR w/ Dummy & BK-5 latch @ 3,593'. X Nipple 3.813" ID @ 2,827'. RUNCMP RILDS, rig down tubing running equipment. RUNCMP Rig up to reverse circulate. Reverse circulate 356 bbls 9.4 ppg brine followed with 71 bbls corrosion inhibited 9.4 ppg brine, and followed with 123 bbls clean 9.4 ppg brine. 123 gpm, 240 psi. Rig down lines. RUNCMP Drop 1.875" roller ball assembly. Lay down landing joint. Close blind rams and pressure up on tubing to 4,200 psi and set packer. Hold pressure 30 minutes for tubing test. 0 psi loss. Bleed tubing pressure down to 1,500 psi. Pressure up annulus to 4,000 psi and hold and test for 30 minutes. 0 psi loss. Bleed off annulus pressure to 0 psi, bleed tubing pressure to 0 psi. Pressure up annulus to 2,500 psi to shear out DCK-2 valve. Test circulation both ways - OK. RUNCMP Drain stack, set 2-way check. Test 2-way check from below to 1,000 psi - OK. RUNCMP Nipple down BOPE. RUNCMP Bring adapter flange and tree into cellar. Prep same. NU tree adapter flange. POST Test hanger and adapter flange 5,000 psi - 10 min - OK. NU Printed: 1/9/2006 9:43:02 AM BP Page 14 of 14 Operations Summary Report Legal Well Name: L-123 Common Well Name: L-123 Spud Date: 12114/2005 Event Name: DRILL+COMPLETE Start: 12/13/2005 End: 1/6/2006 Contractor Name: NABOBS ALASKA DRI LLING I Rig Release: 1(6/2006 Rig Name: NABOBS 9ES Rig Number: Date ', From - To ~ Hours j Task i Code I NPT ~ Phase I Description of Operations 1/6!2006 00:00 - 03:00 3.00 WHSUR P POST and test production tree to 5,000 psi - OK. 03:00 - 03:30 0.50 WHSUR P POST Pull 2-way check valve with lubricator. 03:30 - 08:00 4.50 WHSUR P POST PJSM with Little Red. Pressure test line lines to 3,500 psi - OK. Freeze protect well by pumping 98 bbls of heated diesel down annulus taking returns from tubing @ 2 bpm, ICP - 650 psi, FCP - 1,000 psi. Shut down and u-tube diesel back to tubing. SIP - 0 psi. 08:00 - 08:30 0.50 WHSUR P POST Blow down lines, rig down u-tube lines. 08:30 - 10:30 2.00 WHSUR P POST Install BPV with lubricator. Test BPV from below to 1,000 psi - OK. Bleed off pressure. Rig down lubricator, LRHOS. 10:30 - 12:00 1.50 WHSUR P POST Secure wellhead and production tree. Install VR plugs in annulus valves. Remove outer annulus working valve, install blind flange. *Release rig for derrick down, pad to pad rig move to V-203 @ 12:00 hr 1/6/2006 Printed: 7/9/2006 9:43:02 AM L-123PB1 Survev Resort ~chlumherger Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: L-PAD / N-F Well: L-123 Borehole: L-123PB1 UWUAPI#: 500292329070 Survey Name /Date: L-123PB1 /December 25, 2005 Tort (AHD / DDI ! ERD ratio: 247.187° (8744.73 ft / 6.568 ! 1.313 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaUlong: N 70 21 2.003, W 14919 32.023 Location Grid NIE Yfl(: N 5978251.860 fiUS, E 583069.090 ftUS Grid Convergence Angle: +0.63516733° Vertical Section Azimuth: 303.000° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 76.00 ft relative to MSL Sea Bed (Ground level Elevation: 47.50 ft relative to MSL Magnetic Declination: 24.387° Total Field Strength: 57577.928 nT Magnetic Dip: 80.849° Declination Date: December 13, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.387° Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Nortning Easting Latitude Longitude Depth Section Departure ft de de ft it ft ft ft ft ft de 100 ft ftUS itUS H I t U.UU U.VU U.VV -/6.UU U.VU U.UU U.UU U.UU U.UU U.UU U.VU by1tSZ51.t56 btf3U6y.Uy N !U 21 "L.UU3 W 14y ly :iZ.U23 First GYD GC MS 100.00 0.21 33.43 24.00 100.00 0.00 0.18 0.18 0.15 0.10 0.21 5978252.01 583069.19 N 70 21 2.005 W 149 19 32.020 200.00 1.44 343.86 123.99 199.99 0.95 1.58 1.52 1.51 -0.15 1.31 5978253.37 583068.93 N 70 21 2.018 W 149 19 32.027 300.00 3.27 336.22 223.90 299.90 4.28 5.68 5.58 5.33 -1.65 1.85 5978257.17 583067.38 N 70 21 2.056 W 149 19 32.p71 400.00 4.00 333.81 323.70 399.70 9.67 12.02 11.89 11.07 -4.34 0.75 5978262.88 583064.63 N 70 21 2.112 W 149 19 32.149 500.00 5.30 327.67 423.37 499.37 16.86 20.12 19.93 18.10 -8.35 1.39 5978269.87 583060.54 N 70 21 2.181 W 149 19 32.267 600.00 8.14 329.47 522.67 598.67 27.40 31.82 31.59 28.11 -14.41 2.85 5978279.80 583054.37 N 70 21 2.280 W 149 19 32.444 700.00 11.72 331.44 621.16 697.16 42.67 49.06 48.82 43.13 -22.87 3.60 5978294.73 583045.75 N 70 21 2.428 W 149 19 32.691 800.00 15.96 331.48 718.23 794.23 63.69 72.98 72.73 64.14 -34.29 4.24 5978315.61 583034.09 N 70 21 2.634 W 149 19 33.025 900.00 19.42 329.42 813.49 889.49 90.67 103.36 103.10 90.54 -49.32 3.52 5978341.84 583018.77 N 70 21 2.894 W 149 19 33.464 1000.00 23.24 326.20 906.62 982.62 123.71 139.71 139.40 121.26 -68.76 3.99 5978372.34 582999.00 N 70 21 3.196 W 149 19 34.032 1100.00 26.45 321.33 997.37 1073.37 163.00 181.70 181.15 155.05 -93.66 3.80 5978405.85 582973.73 N 70 21 3.528 W 149 190 1200.00 29.20 319.69 1085.80 1161.80 207.51 228.37 227.42 191.05 -123.36 2.85 5978441.51 582943.63 N 70 21 3.882 W 149 19 8 1300.00 32.51 315.10 1171.64 1247.64 257.18 279.63 278.04 228.70 -158.13 4.06 5978478.77 582908.45 N 70 21 4.253 W 149 19 4 1400.00 35.20 312.65 1254.69 1330.69 311.88 335.33 332.80 267.27 -198.30 3.02 5978516.89 582867.86 N 70 21 4.632 W 149 19 37.818 Last GYD GC MS 1500.00 39.54 306.30 1334.17 1410.17 372.12 395.97 391.87 305.68 -245.19 5.80 5978554.77 582820.55 N 70 21 5.010 W 149 19 39.189 FirstMWD+IFR+MS 1597.13 44.98 303.55 1406.04 1482.04 437.37 461.26 454.86 342.98 -298.77 5.91 5978591.48 582766.57 N7021 5.377 W1491940.754 1688.78 48.99 303.78 1468.55 1544.55 504.36 528.26 519.79 380.13 -354.53 4.38 5978628.00 582710.41 N 70 21 5.742 W 149 19 42.384 1783.18 51.21 305.46 1529.10 1605.10 576.74 600.67 590.73 421.28 -414.11 2.72 5978668.49 582650.38 N 70 21 6.146 W 149 19 44.126 1875.79 50.25 304.92 1587.72 1663.72 648.39 672.37 661.39 462.60 -472.70 1.13 5978709.15 582591.34 N 70 21 6.553 W 149 19 45.838 1969.31 53.27 304.50 1645.59 1721.59 721.80 745.81 733.90 504.42 -533.07 3.25 5978750.29 582530.51 N 70 21 6.964 W 149 19 47.603 2063.03 56.07 305.32 1699.79 1775.79 798.21 822.27 809.59 548.18 -595.76 3.07 5978793.35 582467.34 N 70 21 7.394 W 14919 49.435 2155.77 56.70 305.45 1751.13 1827.13 875.37 899.50 886.26 592.90 -658.73 0.69 5978837.36 582403.89 N 70 21 7.834 W 149 19 51.275 2249.91 58.49 303.71 1801.58 1877.58 954.81 978.97 965.12 637.99 -724.17 2.46 5978881.73 582337.96 N 70 21 8.278 W 149 19 53.188 2343.48 57.75 303.97 1851.00 1927.00 1034.26 1058.43 1043.94 682.24 -790.16 0.83 5978925.23 582271.49 N 70 21 8.713 W 149 19 55.117 2436.52 58.29 303.16 1900.27 1976.27 1113.17 1137.35 1122.27 725.87 -855.92 0.94 5978968.13 582205.25 N 70 21 9.142 W 149 19 57.039 SurveyEditor Ver SP 1.0 Bld( doc40x_56) N-F\L-123\L-123PB1\L-123PB1 Generated 2/1 7/2006 1 1:48 AM Page 1 of 4 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS Gb3V.Ly 5/.b25 3VG.yb lybV.Ub LVLb.Vb 11yL.b4 ILl b.251 7LV 1.14 /by.LL -`JCG.bL V./25 5y/yV1V./4 b23L I.StS.I`J IV /V Ll y.bbt5 VV 74y 1y b25.y2Sb 2623.98 58.96 302.98 1999.33 2075.33 1272.32 1296.50 1280.29 812.58 -989.37 1.47 5979053.35 582070.86 N 70 2 1 9.994 W 149 20 0.940 2716.74 57.72 303.15 2048.01 2124.01 1351.28 1375.45 1358.79 855.66 -1055.54 1.35 5979095.69 582004.23 N 70 21 10.418 W 149 20 2.874 2809.87 58.61 303.15 2097.14 2173.14 1430.40 1454.57 1437.52 898.93 -1121.78 0.96 5979138.21 581937.52 N 70 21 10.843 W 149 20 4.811 2904.01 57.90 302.72 2146.67 2222.67 1510.45 1534.63 1517.19 942.45 -1188.97 0.85 5979180.99 581869.86 N 70 21 11.271 W 149 20 6.775 2996.72 57.01 303.12 2196.54 2272.54 1588.60 1612.78 1595.00 984.92 -1254.58 1.03 5979222.72 581803.79 N 70 21 11.689 W 149 20 8.692 3089.02 58.53 303.97 2245.76 2321.76 1666.67 1690.85 1672.84 1028.07 -1319.64 1.82 5979265.14 581738.26 N 70 21 12.113 W 149 20 10.594 3182.17 57.65 303.86 2295.00 2371.00 1745.74 1769.92 1751.73 1072.19 -1385.26 0.95 5979308.53 581672.16 N 70 21 12.547 W 149 20 12.513 3276.40 58.69 302.71 2344.70 2420.70 1825.79 1849.98 1831.55 1116.12 -1452.19 1.51 5979351.71 581604.76 N 70 21 12.979 W 149 20 14.469 3368.06 58.08 303.25 2392.75 2468.75 1903.85 1928.04 1909.37 1158.61 -1517.67 0.83 5979393.47 581538.82 N 70 21 13.397 W 149 20 16.383 3461.68 57.68 303.23 2442.53 2518.53 1983.14 2007.33 1988.46 1202.07 -1583.98 0.43 5979436.19 581472.03 N 70 21 13.824 W 149 20 18.322 3555.02 57.04 303.05 2492.87 2568.87 2061.74 2085.93 2066.87 1245.04 -1649.80 0.70 5979478.42 581405.75 N 70 21 14.246 W 149 20 6 3589.02 56.93 303.03 2511.39 2587.39 2090.25 2114.44 2095.31 1260.59 -1673.70 0.33 5979493.70 581381.68 N 70 21 14.399 W 149 2 5 3692.64 55.11 302.95 2569.31 2645.31 2176.17 2200.36 2181.03 1307.37 -1745.76 1.76 5979539.68 581309.11 N 70 21 14.859 W 149 20 51 3785.75 56.78 300.61 2621.45 2697.45 2253.28 2277.49 2257.87 1347.98 -1811.34 2.75 5979579.55 581243.09 N 70 21 15.258 W 149 20 24.968 3880.02 60.18 298.52 2670.73 2746.73 2333.48 2357.84 2337.62 1387.60 -1881.23 4.07 5979618.39 581172.77 N 70 21 15.648 W 149 20 27.012 3971.58 59.79 298.81 2716.53 2792.53 2412.53 2437.12 2416.20 1425.63 -1950.80 0.51 5979655.64 581102.79 N 70 21 16.022 W 149 20 29.045 4066.16 59.51 298.94 2764.32 2840.32 2493.94 2518.74 2497.18 1465.04 -2022.27 0.32 5979694.26 581030.90 N 70 21 16.409 W 149 20 31.135 4160.53 58.87 298.73 2812.66 2888.66 2574.77 2599.79 2577.63 1504.13 -2093.27 0.70 5979732.55 580959.47 N 70 21 16.793 W 149 20 33.211 4253.99 58.18 298.90 2861.45 2937.45 2654.27 2679.50 2656.78 1542.55 -2163.11 0.75 5979770.19 580$89.22 N 70 21 17.171 W 149 20 35.252 4347.61 57.71 299.10 2911.14 2987.14 2733.42 2758.85 2735.64 1581.02 -2232.51 0.53 5979807.88 580819.40 N 70 21 17.549 W 149 20 37.281 4444.71 59.10 298.92 2962.01 3038.01 2815.93 2841.55 2817.86 1621.12 -2304.84 1.44 5979847.18 580746.64 N 70 21 17.943 W 149 20 39.396 4539.54 58.10 300.02 3011.42 3087.42 2896.71 2922.49 2898.41 1660.94 -2375.31 1.45 5979886.21 580675.74 N 70 21 18.335 W 149 20 41.456 4634.14 57.51 301.12 3061.82 3137.82 2976.69 3002.54 2978.24 1701.65 -2444.23 1.16 5979926.15 580606.37 N 70 21 18.735 W 149 20 43.471 4729.50 58.85 299.82 3112.10 3188.10 3057.64 3083.57 3059.03 1742.73 -2514.07 1.82 5979966.45 580536.09 N 70 21 19.139 W 149 20 45.513 4824.60 59.19 300.70 3161.05 3237.05 3139.08 3165.10 3140.32 1783.82 -2584.49 0.87 5980006.75 580465.23 N 70 21 19.543 W 149 20 47.572 4919.14 58.62 300.31 3209.88 3285.88 3219.95 3246.06 3221.07 1824.91 -2654.24 0.70 5980047.07 580395.03 N 70 21 19.947 W 149 20 49.612 5014.26 58.21 300.78 3259.70 3335.70 3300.91 3327.09 3301.91 1866.09 -2724.03 0.60 5980087.47 580324.80 N 70 21 20.351 W 149 20 51.652 5109.01 57.69 300.73 3309.98 3385.98 3381.16 3407.40 3382.06 1907.16 -2793.04 0.55 5980127.76 580255.34 N 70 2i 20.755 W 149 20 53.670 5203.21 57.21 300.86 3360.66 3436.66 3460.50 3486.80 3461.32 1947.81 -2861.25 0.52 5980167.65 580186.70 N 70 21 21.154 W 149 20 5303.90 56.48 300.95 3415.73 3491.73 3544.74 3571.10 3545.47 1991.11 -2933.58 0.73 5980210.14 580113.90 N 70 21 21.580 W 149 20 5396.75 56.91 301.20 3466.71 3542.71 3622.30 3648.70 3622.96 2031.16 -3000.04 0.51 5980249.45 580047.00 N 70 21 21.974 W 149 20 2 5491.40 58.03 301.10 3517.61 3593.61 3702.05 3728.49 3702.66 2072.44 -3068.33 1.19 5980289.97 579978.26 N 70 21 22.379 W 149 21 1.719 5586.17 59.43 299.19 3566.81 3642.81 3782.95 3809.49 3783.47 2113.11 -3138.38 2.27 5980329.85 579907.78 N 70 21 22.779 W 149 21 3.767 5680.66 60.21 298.69 3614.31 3690.31 3864.42 3891.17 3864.85 2152.63 -3209.86 0.94 5980368.58 579835.87 N 70 21 23.167 W 149 21 5.858 5776.04 58.66 300.58 3662.81 3738.81 3946.40 3973.30 3946.75 2193.23 -328125 2.36 5980408.37 579764.04 N 70 21 23.566 W 149 21 7.945 5870.39 58.21 303:54 3712.21 3788.21 4026.77 4053.68 4027.09 2235.89 -3349.37 2.72 5980450.27 579695.46 N 70 21 23.986 W 149 21 9.937 5964.41 57.48 303.47 3762.25 3838.25 4106.36 4133.28 4106.69 2279.83 -3415.74 0.78 5980493.47 579628.61 N 70 21 24.417 W 149 21 11.878 6058.60 57.36 303.95 3812.97 3888.97 4185.72 4212.65 4186.05 2323.87 -3481.76 0.45 5980536.78 579562.11 N 70 21 24.850 W 149 21 13.808 6153.14 57.07 304.93 3864.16 3940.16 4265.18 4292.13 4265.53 2368.82 -3547.31 0.92 5980580.99 579496.08 N 70 21 25.292 W 149 21 15.725 6247.79 57.51 303.10 3915.31 3991.31 4344.80 4371.77 4345.16 2413.37 -3613.32 1.69 5980624.80 579429.58 N 70 21 25.730 W 149 21 17.656 6342.43 56.80 305.10 3966.64 4042.64 4424.29 4451.27 4424.66 2457.94 -3679.16 1.93 5980668.63 579363.26 N 70 21 26.168 W 149 21 19.581 6437.42 56.71 302.83 4018.72 4094.72 4503.71 4530.71 4504.10 2502.32 -3745.04 2.00 5980712.27 579296.90 N 70 21 26.604 W 149 21 21.508 6531.69 58.55 303.21 4069.19 4145.19 4583.33 4610.33 4583.71 2545.70 -3811.79 1.98 5980754.92 579229.67 N 70 21 27.030 W 149 21 23.460 SurveyEditor Ver SP 1.0 Bld( doc40x_56) N-F\L-123\L-123P61\L-123PB1 Generated 2/17/2006 11:48 AM Page 2 of 4 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft h de 100 ft ftUS ftUS 6625.21 58.31 304.36 4118.15 4194.15 4663.00 4690.01 4663.39 2590.01 -3878.02 1.08 5980798.48 579162.97 N 70 21 27.466 W 149 21 25.397 6719.32 57.82 304.41 4167.93 4243.93 4742.84 4769.88 4743.25 2635.11 -3943.93 0.52 5980842.85 579096.57 N 70 21 27.909 W 149 21 27.324 6813.89 57.83 302.44 4218.30 4294.30 4822.88 4849.92 4823.29 2679.20 -4010.73 1.76 5980886.19 579029.29 N 70 21 28.342 W 149 21 29.278 6908.81 57.63 301.69 4268.98 4344.98 4903.13 4930.18 4903.51 2721.81 -4078.74 0.70 5980928.04 578960.81 N 70 21 28.761 W 149 21 31.267 7002.96 58.45 301.58 4318.81 4394.81 4982.98 5010.06 4983.34 2763.71 -4146.75 0.88 5980969.17 578892.35 N 70 21 29.173 W 149 21 33.256 7097.84 57.96 302.08 4368.80 4444.80 5063.61 5090.70 5063.94 2806.24 -4215.27 0.68 5981010.94 578823.37 N 70 21 29.591 W 149 21 35.260 7190.96 57.40 301.61 4418.59 4494.59 5142.28 5169.39 5142.59 2847.76 -4282.11 0.74 5981051.71 578756.08 N 70 21 29.999 W 149 21 37.215 7286.33 58.11 301.42 4469.47 4545.47 5222.92 5250.05 5223.20 2889.92 -4350.88 0.76 5981093.10 578656.86 N 70 21 30.413 W 149 21 39.226 7380.80 59.37 300.55 4518.49 4594.49 5303.62 5330.81 5303.87 2931.49 -4420.11 1.55 5981133.90 578617.17 N 70 21 30.821 W 149 21 41.251 7477.05 58.51 299.86 4568.15 4644.15 5385.97 5413.26 5386.18 2972.97 -4491.36 1.08 5981174.58 578545.47 N 70 21 31.229 W 149 21 43.334 7572.63 57.59 302.12 4618.74 4694.74 5467.01 5494.35 5467.19 3014.72 -4560.88 2.23 5981215.55 578475.50 N 70 21 31.639 W 149 28 7668.61 57.77 303.61 4670.05 4746.05 5548.12 5575.46 5548.29 3058.73 -4629.01 1.33 5981258.81 578406.90 N 70 21 32.072 W 149 2 0 7763.95 57.01 303.04 4721.43 4797.43 5628.43 5655.77 5628.60 3102.85 -4696.11 0.94 5981302.18 578339.32 N 70 21 32.505 W 149 21 23 7860.06 58.00 302.37 4773.07 4849.07 5709.49 5736.83 5709.66 3146.65 -4764.32 1.19 5981345.21 578270.63 N 70 21 32.935 W 149 21 51.318 7955.40 58.89 303.43 4822.96 4898.96 5790.73 5818.07 5790.89 3190.78 -4832.53 1.33 5981388.58 578201.94 N 70 21 33.369 W 149 21 53.313 8051.04 59.26 304.23 4872.11 4948.11 5872.76 5900.12 5872.93 3236.46 -4900.68 0.82 5981433.49 578133.29 N 70 21 33.818 W 149 21 55.307 8146.30 58.69 304.56 4921.21 4997.21 5954.37 5981.75 5954.56 3282.57 -4968.04 0.67 5981478.85 578065.43 N 70 21 34.271 W 149 21 57.277 8241.91 57.94 304.11 4971.43 5047.43 6035.70 6063.11 6035.90 3328.46 -5035.22 0.88 5981523.99 577997.75 N 70 21 34.722 W 149 21 59.242 8337.66 57.57 305.65 5022.52 5098.52 6116.64 6144.09 6116.86 3374.77 -5101.66 1.41 5981569.55 577930.82 N 70 21 35.177 W 149 22 1.185 8433.24 55.86 310.14 5074.99 5150.99 6196.22 6223.97 6196.49 3423.80 -5164.70 4.31 5981617.88 577867.24 N 70 21 35.658 W 149 22 3.030 8528.97 53.74 313.66 5130.18 5206.18 6273.48 6302.19 6273.88 3476.00 -5222.93 3.73 5981669.42 577808.45 N 70 21 36.171 W 149 22 4.733 8625.04 51.53 317.20 5188.49 5264.49 6348.03 6378.53 6348.62 3530.35 -5276.52 3.72 5981723.17 577754.26 N 70 21 36.706 W 149 22 6.301 8721.02 49.12 320.70 5249.77 5325.77 6419.04 6452.39 6419.94 3586.02 -5325.04 3.77 5981778.29 577705.13 N 70 21 37.253 W 149 22 7.721 8816.12 49.10 322.96 5312.03 5388.03 6487.08 6524.28 6488.39 3642.53 -5369.47 1.80 5981834.30 577660.08 N 70 21 37.808 W 149 22 9.021 8912.24 49.61 325.79 5374.65 5450.65 6554.98 6597.20 6556.86 3701.80 -5411.94 2.30 5981893.10 577616.96 N 70 21 38.391 W 149 22 10.264 9004.93 50.48 328.08 5434.18 5510.18 6619.91 6668.25 6622.52 3761.35 -5450.69 2.11 5981952.20 577577.56 N 70 21 38.976 W 149 22 11.399 9099.44 51.44 330.68 5493.71 5569.71 6685.65 6741.65 6689.22 3824.51 -5488.06 2.37 5982014.95 577539.49 N 70 21 39.597 W 149 2212.493 9192.83 51.06 332.09 5552.17 5628.17 6749.73 6814.48 6754.47 3888.45 -5522.94 1.25 5982078.48 577503.90 N 70 21 40.226 W 149 22 13.514 9286.02 50.45 335.43 5611.13 5687.13 6811.74 6886.64 6817.91 3953.16 -5554.85 2.85 5982142.83 577471.28 N 70 21 40.862 W 149 22 14.448 9379.83 50.27 339.07 5670.99 5746.99 6871.43 6958.87 6879.38 4019.76 -5582.78 2.99 5982209.11 577442.62 N 70 21 41.517 W 149 227 9472.68 49.85 343.26 5730.62 5806.62 6927.39 7030.05 6937.51 4087.10 -5605.76 3.49 5982276.19 577418.90 N 70 21 42.179 W 149 22140 9566.80 50.44 347.05 5790.94 5866.94 6980.92 7102.29 6993.73 4156.93 -5624.26 3.15 5982345.80 577399.63 N 70 21 42.865 W 149 22 16.482 9659.38 52.21 350.91 5848.81 5924.81 7031.11 7174.56 7047.14 4227.85 -5638.04 3.77 5982416,56 577385.06 N 70 21 43.563 W 149 22 16.887 9752.24 54.73 353.99 5904,09 5980.09 7079.58 7249.16 7099.52 4301.80 -5647.81 3.80 5982490.39 577374.48 N 70 21 44.290 W 149 22 17.174 9777.11 55.81 354.88 5918.26 5994.26 7092.32 7269.60 7113.44 4322.15 -5649.79 5.24 5982510,71 577372.27 N 70 21 44.490 W 149 22 17.233 9808.88 56.28 357.05 5936.00 6012.00 7108.19 7295.95 7130.91 4348.43 -5651.64 5.86 5982536.97 577370.13 N 70 21 44.749 W 149 22 17.287 9839.67 56.45 359.28 5953.06 6029.06 7122.83 7321.58 7147.21 4374.05 -5652.46 6.06 5982562.57 577369.02 N 70 21 45.001 W 149 22 17.312 9870.46 57.11 1.10 5969.93 6045.93 7136.79 7347.34 7162.94 4399.80 -5652.38 5.39 5982588.33 577368.82 N 70 21 45.254 W 149 22 17.310 9901.63 57.16 3.01 5986.84 6062.84 7150.25 7373.52 7178.30 4425.97 -5651.44 5.15 5982614.50 577369.47 N 70 21 45.511 W 149 22 17.283 9932.39 57.06 5.46 6003.55 6079.55 7162.68 7399.35 7192.71 4451.72 -5649.53 6.70 5982640.27 577371.09 N 70 21 45.765 W 149 22 17.228 9963.71 57.38 6.54 6020.51 6096.51 7174.63 7425.68 7206.79 4477.91 -5646.78 3.07 5982666.48 577373.56 N 70 21 46.022 W 149 22 17.148 9994.69 57.98 9.74 6037.07 6113.07 7185.63 7451.86 7220.02 4503.82 -5643.07 8.94 5982692.43 577376.98 N 70 21 46.277 W 149 22 17.040 10025.45 57.31 13.11 6053.54 6129.54 7195.19 7477.84 7231.92 4529.29 -5637.93 9.51 5982717.95 577381.84 N 70 21 46.527 W 149 22 16.890 SurveyEditor Ver SP 1.0 Bld( doc40x_56) N-F\L-123\L-123P61\L-123P61 Generated 2/17/2006 11:48 AM Page 3 of 4 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hote Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft d 100 ft ftUS ftUS IVVbb.bV 5/.t5i3 Ib.JZ OV/V.ZJ 014b.Z3 /GV3.44 /bV4.14 /L4Z.Ot3 4Jb4./Z -Db31.Z4 25.t3y ~yCZ/43.4b 10087.66 58.36 18.25 6086.64 6162.64 7210.58 7530.52 7252,46 4579.90 -5623.41 5.50 5982768.71 10117.23 59.35 21.70 6101.94 6177.94 7216.28 7555.82 7260.81 4603.68 -5614.76 10.53 5982792.58 10148.85 59.85 25,84 6117.94 6193.94 7220.65 7583.09 7268.18 4628.63 •5603.77 11.40 5982817.65 10179.08 60.48 27.59 6132.98 6208.98 7223.52 7609.31 7274.05 4652.05 -5591.98 5.44 598284120 10209.76 60.09 30.31 6148.19 6224.19 7225.40 7635.96 7279.09 4675.36 -5579.09 7.80 5982864.65 10241.39 59.08 31.66 6164.21 6240.21 7226.36 7663.23 7283.40 4698.75 -5565.04 4.87 5982888.19 10271.75 58.76 33.71 6179.88 6255.88 7226.50 7689.23 7286.84 4720.63 -5551.01 5.88 5982910.22 10302.65 59.07 37.53 6195.84 6271.84 7225.29 7715.69 7289.08 4742.13 -5535.60 10.63 5982931.90 i 0334.13 59.45 41.59 6211.93 6287.93 7222.20 7742.75 7289.61 4762.99 -5518.37 11.15 5982952.94 10365.50 59.41 43.58 6227.89 6303.89 7217.70 7769.76 7288.82 4782.87 -5500.09 5.46 5982973.02 10397.04 60.28 43.68 6243.73 6319.73 7212.67 7797.03 7287.62 4802.61 -5481.28 2.77 5982992.97 10490.10 63.68 46.08 6287.45 6363.45 7195.74 7879.17 7282.82 4860.79 -5423.30 4.30 5983051.78 10583.98 68.50 49.77 6325.50 6401.50 7173.60 7964.96 7274.22 4918.23 -5359.60 627 5983109.92 10677.68 74.13 50.97 6355.51 6431.51 7147.09 8053.68 7262.65 4974.81 -5291.25 6.13 5983167.24 10770.54 73.20 50.94 6381.62 6457.62 7119.62 8142.80 7251.22 5030.94 -5222.05 1.00 5983224.14 10865.03 72.60 51.17 6409.41 6485.41 7091.63 8233.11 7240.57 5087.71 -5151.81 0.68 5983281.67 10958.74 72.46 50.69 6437.54 6513.54 7064.12 8322.50 7231.33 5144.05 -5082.41 0.51 5983338.77 11051.53 72.15 51.45 6465.74 6541.74 7036.70 8410.90 7223.05 5199.60 -5013.64 0.85 5983395.07 11145.62 71.11 50.40 6495.40 6571.40 700921 8500.19 7215.99 5255.88 -4944.32 1.53 5983452.12 11238.30 70.17 50.36 6526.12 6602.12 6983.09 8587.63 7210.98 5311.64 •4876.97 1.02 5983508.61 Last MWD+IFR+MS 11330.28 69.28 50.79 6557.99 6633.99 6957.04 8673.91 7206.79 5366.43 -4810.32 1.06 5983564.14 TD (Projected) 11406.00 69.28 50.79 6564.78 6660.78 6935.40 8744.73 7203.84 5411.20 -4755.44 0.00 5983609.51 Survey Type: Definitive Survey NOTES: GYD-GC-MS - (Gyrodata - gyro com passing m/s -- Older G yrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata mult ishot into open hole" model. Not to be run above 70 degrees inclination.. ) MWD + tFR + MS - (In-field referenced MWD w ith mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhan ce inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 2531 FSL 3846 FEL S34 T 12N R11 E UM 5978251.86 583069.09 BHL : 2661 FSL 3311 FEL S28 T12N Ri 1 E UM 5983609.51 578254.41 b//3iStl.ZJ IV /V ZI 4b.//t3 VV 14`J GG Ib.b`JO 577395.79 N 70 21 47.025 W 149 2216.467 577404.17 N 70 21 47.259 W 149 22 16.214 577414.89 N 70 21 47.505 W 149 22 15.894 577426.41 N 70 21 47.735 W 149 22 15.549 577439.05 N 70 21 47.965 W 149 22 15.173 577452.83 N 70 21 48.195 W 149 22 14.763 577466.62 N 70 21 48.410 W 149 22 14.353 577481.79 N 70 21 48.622 W 149 22 13.902 577498.79 N 70 21 48.827 W 149 22 13.399 577516.84 N 70 21 49.022 W 149 22 12.865 577535.43 N 70 21 49.217 W 149 215 577592.75 N 70 21 49.789 W i 49 22 21 577655.81 N 70 21 50.355 W 149 22 8.759 577723.52 N 70 21 50.912 W 149 22 6.762 577792.09 N 70 21 51.464 W 149 22 4.739 577861.69 N 70 21 52.023 W 149 22 2.686 577930.45 N 70 21 52.577 W 149 22 0.658 577998.59 N 70 21 53.124 W 149 21 58.648 578067.28 N 70 21 53.678 W 149 21 56.621 578134.01 N 70 21 54.227 W 149 21 54.653 578200.03 N 70 21 54.766 W 149 21 52.705 578254.41 N 70 21 55.207 W 149 21 51.100 SurveyEditor Ver SP 1.0 Bld{ doc40x_56) N-F\L-123\L-123P61\L-123P61 Generated 2/17/2006 11:48 AM Page 4 of 4 L-123 Survey Regort ~~~'~n~ ~r Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: L-PAD / N-F Well: L-123 Borehole: L-123 UWUAPI#: 500292329000 Survey Name /Date: L-123 /January 1, 2006 Tort /AHD / DDI / ERD ratio: 315.849° / 9770.86 ft / 6.768 / 1.497 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVlong: N 70 21 2.003, W 14919 32.023 Location Grid WE Y/X: N 5978251.860 ftUS, E 583069.090 ftUS Grid Convergence Angle: +0.63516733° Grid Scale Factor: 0,99990784 Vertical Section Azimuth: 303.000° Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 76.00 ft relative to MSL Sea Bed /Ground level Elevation: 47.50 ft relative to MSL Magnetic Declination: 24.387° Total Field Strength: 57577.928 nT Magnetic Dip: 80.849° Declination Date: December 13, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.387° Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS H I ~ U.UU U.UU O.UU -76.00 U.VU U.UU U.UU U.UU U.UU U.UU U.UU 59/tt'Lbl.ttti bk13U69.V9 N /U 21 2.003 W 149 19 32.023 First GYD GC MS 100.00 0.21 33.43 24.00 100.00 0.00 0.18 0.18 0.15 0.10 0.21 5978252.01 583069.19 N 70 21 2.005 W 149 19 32.020 200.00 1.44 343.86 123.99 199.99 0.95 1.58 1.52 1.51 -0.15 1.31 5978253.37 583068.93 N 70 21 2.018 W 149 19 32.027 300.00 3.27 336.22 223.90 299.90 4.26 5.6B 5.58 5.33 -1.65 1.85 5978257.17 583067.38 N 70 21 2.056 W 149 19 32.071 400.00 4.00 333.81 323.70 399.70 9.67 12.02 11.89 11.07 -4.34 0.75 5978262.88 583064.63 N 70 21 2.112 W 149 19 32.149 500.00 5.30 327.67 423.37 499.37 16.86 20.12 19.93 18.10 -8.35 1.39 5978269.87 583060.54 N 70 21 2.181 W 149 19 32.267 600.00 8.14 329.47 522.67 598.67 27.40 31.82 31.59 28.11 -14.41 2.85 5978279.80 583054.37 N 70 21 2.280 W 149 19 32.444 700.00 11.72 331.44 621.16 697.16 42.67 49.06 48.82 43.13 -22.87 3.60 5978294.73 583045.75 N 70 21 2.428 W 149 19 32.691 800.00 15.96 331.48 7i 8.23 794.23 63.69 72.98 72.73 64.14 -34.29 4.24 5978315.61 583034.09 N 70 21 2.634 W 149 19 33.025 900.00 19.42 329.42 813.49 889.49 90.67 103.36 103.10 90.54 -49.32 3.52 5978341.84 583018.77 N 70 21 2.894 W 149 19 33.464 1000.00 23.24 326.20 906.62 982.62 123.71 139.71 139.40 121.26 -68.76 3.99 5978372.34 582999.00 N 70 21 3.196 W 149 19 34.032 1100.00 26.45 321.33 997.37 1073.37 163.00 181.70 181.15 155.05 -93.66 3.80 5978405.85 582973.73 N 70 21 3.528 W 149 19 34.760 1200.00 29.20 319.69 1085.80 1161.80 207.51 228.37 227.42 191.05 -123.36 2.85 5978441.51 582943.63 N 70 21 3.882 W 149 1 8 1300.00 32.51 315.10 1171.64 1247.64 257.18 279.63 278.04 228.70 -158.13 4.06 5978478.77 582908.45 N 70 21 4.253 W 149 1 4 1400..00 35.20 312.65 1254.69 1330.69 311.88 335.33 332.80 267.27 -198.30 3.02 5978516.89 582867.86 N 70 21 4.632 W 149 19 37.818 Last GYD GC MS 1500.00 39.54 306.30 1334.17 1410.17 372.12 395.97 391.87 305.68 -245.19 5.80 5978554.77 582820.55 N 70 21 5.010 W 149 19 39.189 First MW D+IFR+MS 1597.13 44.98 303.55 1406.04 1482.04 437.37 461.26 454.86 342.98 -298.77 5.91 5978591.48 582766.57 N 70 21 5.377 W 149 19 40.754 1688.78 48.99 303.78 1468.55 1544.55 504.36 528.26 519.79 380.13 -354.53 4.38 5978628.00 582710.41 N 70 21 5.742 W 149 19 42.384 1783.18 51.21 305.46 1529.10 1605.10 576.74 600.67 590.73 421.28 -414.11 2.72 5978668.49 582650.38 N 70 21 6.146 W 149 19 44.126 1875.79 50.25 304.92 1587.72 1663.72 648.39 672.37 661.39 462.60 -472.70 1.13 5978709.15 582591.34 N 70 21 6.553 W 149 19 45.838 1969.31 53.27 304.50 1645.59 1721.59 721.80 745.81 733.90 504.42 -533.07 325 5978750.29 582530.51 N 70 21 6.964 W 149 19 47.603 2063.03 56.07 305.32 1699.79 1775.79 798.21 822.27 809.59 548.18 -595.76 3.07 5978793.35 582467.34 N 70 21 7.394 W 149 19 49.435 2155.77 56.70 305.45 1751.13 1827.13 875.37 899.50 886.26 592.90 -658.73 0.69 5978837.36 582403.89 N 70 21 7.834 W 149 19 51.275 2249.91 58.49 303.71 1801.58 1877.5$ 954.81 978.97 965.12 637.99 -724.17 2.46 5978881.73 582337.96 N 70 21 8.278 W 149 19 53.188 2343.48 57.75 303.97 1851.00 1927.00 1034.26 1058.43 1043.94 682.24 -790.16 0.83 5978925.23 582271.49 N 70 21 8.713 W 149 19 55.117 SurveyEditor Ver SP 1.0 Bld( doc40x_56) N-F1L-123\L-123\L-123 Generated 2/17!2006 11:48 AM Page 1 of 5 Measured Vertical Along Hole Comments Inclination Azimuth SutrSea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS 2436.52 58.29 303.16 1900.27 1976.27 1113.17 1137.35 1122.27 725.87 -855.92 0.94 5978968.13 582205.25 N 70 21 9.142 W i 49 19 57.039 2530.29 57.58 302.96 1950.05 2026.05 1192.64 1216.81 1201.14 769.22 -922.52 0.78 5979010.74 582138.19 N 70 2 1 9.568 W 149 19 58.986 2623.98 58.96 302.95 1999.33 2075.33 1272.32 1296.50 1280.29 812.58 -989.37 1.47 5979053.35 582070.86 N 70 2 1 9.994 W 149 20 0.940 2716.74 57.72 303.15 2048.01 2124.01 1351.28 1375.45 1358.79 855.66 -1055.54 1.35 5979095.69 582004.23 N 70 21 10.418 W 149 20 2.874 2809.87 58.61 303.15 2097.14 2173.14 1430.40 1454.57 1437.52 898.93 -1121.78 0.96 5979138.21 581937.52 N 70 21 10.843 W 149 20 4.811 2904.01 57.90 302.72 2146.67 2222.67 1510.45 1534.63 1517.19 942.45 -1188.97 0.85 5979180.99 581869.86 N 70 21 11.271 W 149 20 6.775 2996.72 57.01 303.12 2196.54 2272.54 1588.60 1612.78 1595.00 984.92 -1254.58 1.03 5979222.72 581803.79 N 70 21 11.689 W 149 20 8.692 3089.02 58.53 303.97 2245.76 2321.76 1666.67 1690.85 1672.84 1028.07 -1319.64 1.82 5979265.14 581738.26 N 70 21 12.113 W 149 20 10.594 3182.17 57.65 303.86 2295.00 2371.00 1745.74 1769.92 1751.73 1072.19 -1385.26 0.95 5979308.53 581672.16 N 70 21 12.547 W 149 20 12.513 3276.40 58.69 302.71 2344.70 2420.70 1825.79 1849.98 1831.55 1116.12 -1452.19 1.51 5979351.71 581604.76 N 70 21 12.979 W 149 20 14.469 3368.06 58.08 303.25 2392.75 2468.75 1903.85 1928.04 1909.37 1158.61 -1517.67 0.83 5979393.47 581538.82 N 70 21 13.397 W 149 2 3 3461.68 57.68 303.23 2442.53 2518.53 1983.14 2007.33 1988.46 1202.07 -1583.98 0.43 5979436,19 581472.03 N 70 21 13.824 W 149 2 2 3555.02 57.04 303.05 2492.87 2568.87 2061.74 2085.93 2066.87 1245.04 -1649.80 0.70 5979478.42 581405.75 N 70 21 14.246 W 149 20 46 3589.02 56.93 303.03 2511.39 2587.39 2090.25 2114.44 2095.31 1260.59 -1673.70 0.33 5979493,70 581381.68 N 70 21 14.399 W 149 20 20.945 3692.64 55.11 302.95 2569.31 2645.31 2176.17 2200.36 2181.03 1307.37 -1745.76 1.76 5979539.68 581309.11 N 70 21 14.859 W 149 20 23.051 3785.75 56.78 300.61 2621.45 2697.45 2253.28 2277.49 2257.87 1347.98 -1811.34 2.75 5979579.55 581243.09 N 70 21 15.258 W 149 20 24.968 3880.02 60.18 298.52 2670.73 2746.73 2333.48 2357.84 2337.62 1387.60 -1881.23 4.07 5979618.39 581172.77 N 70 21 15.648 W 149 20 27.012 3971.58 59.79 298.81 2716.53 2792.53 2412.53 2437.12 2416.20 1425.63 -1950.80 0.51 5979655.64 581102.79 N 70 21 16.022 W 149 20 29.045 4066.16 59.51 298.94 2764.32 2840.32 2493.94 2518.74 2497.18 1465.04 -2022.27 0.32 5979694.26 581030.90 N 70 21 16.409 W 149 20 31.135 4160.53 58.87 298.73 2812.66. 2888.66 2574.77 2599.79 2577.63 1504.13 -2093.27 0.70 5979732.55 580959.47 N 70 21 16.793 W 149 20 33.211 4253.99 58.18 298.90 2861.45 2937.45 2654.27 2679.50 2656.78 1542.55 -2163.11 0.75 5979770.19 580889.22 N 70 21 17.171 W 149 20 35.252 4347.61 57.71 299.10 2911.14 2987.14 2733.42 2758.85 2735.64 1581,02 -2232.51 0.53 5979807.88 580819.40 N 70 21 17.549 W 149 20 37.281 4444.71 59.10 298.92 2962.01 3038.01 2815.93 2841.55 2817.86 1621.12 -2304.84 1.44 5979847.18 580746.64 N 70 21 17.943 W 149 20 39.396 4539.54 58.10 300.02 3011.42 3087.42 2896.71 2922.49 2898.41 1660.94 -2375.31 1.45 5979886.21 580675.74 N 70 21 18.335 W 149 20 41.456 4634.14 57.51 301.12 3061.82 3137.$2 2976.69 3002.54 2978.24 1701.65 -2444.23 1.16 5979926.15 580606.37 N 70 21 18,735 W 149 20 43.471 4729.50 58.85 299.82 3112.10 318$.10 3057.64 3083.57 3059.03 1742,73 -2514.07 1.82 5979966.45 580536.09 N 70 21 19.139 W 149 20 45.513 4824.60 59.19 300.70 3161.05 3237.05 3139.08 3165.10 3140.32 1783.82 -2584.49 0.87 5980006.75 580465.23 N 70 21 19.543 W 149 20 47.572 4919.14 58.62 300.31 3209.88 3285.88 321.9.95 3246.06 3221.07 1824.91 -2654.24 0.70 5980047.07 580395.03 N 70 21 19.947 W 149 20 49.612 5014.26 58.21 300.78 3259.70 3335.70 3300.91 3327.09 3301.91 1866.09 -2724.03 0.60 5980087.47 580324.80 N 70 21 20.351 W 149 20 51.652 5109.01 57.69 300.73 3309.98 3385.98 3381.16 3407.40 3382.06 1907.16 -2793.04 0.55 5980127.76 580255.34 N 70 21 20.755 W 149 20 70 5203.21 57.21 300.86 3360.66 3436.66 3460.50 3486.80 3461.32 1947.81 -2861.25 0.52 5980167.65 580186.70 N 70 21 21.154 W 149 204 5303.90 56.48 300.95 3415.73 3491.73 3544.74 3571.10 3545.47 1991.11 -2933.58 0.73 5980210.14 580113.90 N 70 21 21.580 W 149 20 57.779 5396.75 56.91 301.20 3466.71 3542.71 3622.30 3648.70 3622.96 2031.16 -3000.04 0.51 5980249.45 580047.00 N 70 21 21.974 W 149 20 59.722 5491.40 58.03 301.10 3517.61 3593.61 3702.05 3728.49 3702.66 2072.44 -3068.33 1.19 5980289.97 579978.26 N 70 21 22.379 W 149 21 1.719 5586.17 59.43 299.19 3566.81 3642.81 3782.95 3809.49 3783.47 2113.11 -313$.38 2.27 5980329.85 579907.78 N 70 21 22.779 W 149 21 3.767 5680.66 60.21 298.69 3614.31 3690.31 3864.42 3891.17 3864.85 2152.63 -3209.86 0.94 5980368.58 579835.87 N 70 21 23.167 W 149 21 5.858 5776.04 58.66 300.58 3662.81 3738.81 3946.40 3973.30 3946.75 2193.23 -3281.25 2.36 5980408.37 579764.04 N 70 21 23.566 W 149 21 7.945 5870.39 58.21 303.54 3712.21 3788.21 4026.77 4053.68 4027.09 2235.89 -3349.37 2.72 5980450.27 579695.46 N 70 21 23.986 W 149 21 9.937 5964.41 57.48 303.47 3762.25 3838.25 4106.36 4133.28 4106.69 2279.83 -3415.74 0.78 5980493.47 579628.61 N 70 21 24.417 W 149 21 11.878 6058.60 57.36 303.95 3812.97 3888.97 4185.72 4212.65 4186.05 2323.87 -3481.76 0,45 5980536.78 579562.11 N 70 21 24.850 W 149 21 13.808 6153.14 57.07 304.93 3864.16 3940.16 4265.18 4292.13 4265.53 2368.82 -3547.31 0,92 5980580.99 579496.08 N 70 21 25.292 W 149 21 15.725 6247.79 57.51 303.10 3915.31 3991.31 4344.80 4371.77 4345.16 2413.37 -3613.32 1.69 5980624.80 579429.58 N 70 21 25.730 W 149 21 17.656 SurveyEditor Ver SP 1.0 Bld( doc40x_56) N-F\L-123\L-123\L-123 Generated 2/17/2006 11:48 AM Page 2 of 5 Comments Measured inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 h ftUS ftUS bJ4L.4J bb.iSV :iVb.1V :S`Jbb.b4 4V4L.b4 44L4."Ly 4451.L/ 44L4.bb 'L4b/.y4 -:Sb/y.lb 1.y:3 byiSUblitS.bi b/y3b3.Gb IV /U Ll Lb.lbt3 VV 14`JLl ly.bt31 6437.42 56.71 302.83 4018.72 4094.72 4503.71 4530.71 4504.10 2502.32 -3745.04 2.00 5980712.27 579296.90 N 70 21 26.604 W 149 21 21.508 6531.69 58.55 303.21 4069.19 4145.19 4583.33 4610.33 4583.71 2545.70 -3811.79 1.98 5980754.92 579229.67 N 70 21 27.030 W 149 21 23.460 6625.21 58.31 304.36 4118.15 4194.15 4663.00 4690.01 4663.39 2590.01 -3878.02 1.08 5980798.48 579162.97 N 70 21 27.466 W 149 21 25.397 6719.32 57.82 304.41 4167.93 4243.93 4742.84 4769.88 4743.25 2635.11 -3943.93 0.52 5980842.85 579096.57 N 70 21 27.909 W 149 21 27.324 6813.89 57.83 302.44 4218.30 4294.30 4822.88 4849.92 4823.29 267920 -4010.73 1.76 5980886.19 579029.29 N 70 21 28.342 W 149 21 29.278 6908.81 57.63 301.69 4268.98 4344.98 4903.13 4930.18 4903.51 2721.81 -4078.74 0.70 5980928.04 578960.81 N 70 21 28.761 W 149 21 31.267 7002.96 58.45 301.58 4318.81 4394.81 4982.98 5010.06 4983.34 2763.71 -4146.75 0.88 5980969.17 578892.35 N 70 21 29.173 W 149 21 33.256 7097.84 57.96 302.08 4368.80 4444.80 5063.61 5090.70 5063.94 2806.24 -421527 0.68 5981010.94 578823.37 N 70 21 29.591 W 149 21 35.260 7190.96 57.40 301.61 4418.59 4494.59 5142.28 5169.39 5142.59 2847.76 -4282.11 0.74 5981051.71 578756.08 N 70 21 29.999 W 149 21 37.215 7286.33 58.11 301.42 4469.47 4545.47 5222.92 5250.05 5223.20 2889.92 -4350.88 0.76 5981093.10 578686.86 N 70 21 30.413 W 149 21 39.226 7380.80 59.37 300.55 4518.49 4594.49 5303.62 5330.81 5303.87 2931.49 -4420.11 1.55 5981133.90 578617.17 N 70 21 30.821 W 149 21 7477.05 58.51 299.86 4568.15 4644.15 5385.97 5413.26 5386.18 2972.97 -4491.36 1.08 5981174.58 578545.47 N 70 21 31.229 W 149 2 4 7572.63 57.59 302.12 4618.74 4694.74 5467.01 5494.35 5467.19 3014.72 -4560.88 2.23 5981215.55 578475.50 N 70 21 31.639 W 149 21 45.368 7668.61 57.77 303.61 4670.05 4746.05 5548.12 5575.46 5548.29 3058.73 -4629.01 1.33 5981258.81 578406.90 N 70 21 32.072 W 149 21 47.360 7763.95 57.01 303.04 4721.43 4797.43 5628.43 5655.77 5628.60 3102.85 -4696.11 0.94 5981302.18 578339.32 N 70 21 32.505 W 149 21 49.323 7860.06 58.00 302.37 4773.07 4849.07 5709.49 5736.83 5709.66 3146.65 -4764.32 1.19 5981345.21 578270.63 N 70 21 32.935 W 149 21 51.318 7955.40 58.89 303.43 4822.96 4898.96 5790.73 5818.07 5790.89 3190.78 -4832.53 1.33 5981388.58 578201.94 N 70 21 33.369 W 149 21 53.313 8051.04 59.26 304.23 4872.11 4948.11 5872.76 5900.12 5872.93 3236.46 -4900.68 0.82 5981433.49 578133.29 N 70 21 33.818 W 149 21 55.307 8146.30 58.69 304.56 4921.21 4997.21 5954.37 5981.75 5954.56 3282.57 -4968.04 0.67 5981478.85 578065.43 N 70 21 34.271 W 149 21 57.277 8241.91 57.94 304.11 4971.43 5047.43 6035.70 6063.11 6035.90 3328.46 -5035.22 0.88 5981523.99 577997.75 N 70 21 34.722 W 149 21 59.242 8337.66 57.57 305.65 5022.52 5098.52 6116.64 6144.09 6116.86 3374.77 -5101.66 1.41 5981569.55 577930.82 N 70 21 35.177 W 149 22 1.185 8433.24 55.86 310.14 5074.99 5150.99 6196.22 6223.97 6196.49 3423.80 -5164.70 4.31 5981617.88 577867.24 N 70 21 35.658 W 149 22 3.030 8528.97 53.74 313.66 5130.18 5206.18 6273.48 6302.19 6273.88 3476.00 -5222.93 3.73 5981669.42 577808.45 N 70 21 36.171 W 149 22 4.733 8625.04 51.53 317.20 5188.49 5264.49 6348.03 6378.53 6348.62 3530.35 -5276.52 3.72 5981723.17 57775426 N 70 21 36.706 W 149 22 6.301 8721.02 49.12 320.70 5249.77 5325.77 6419.04 6452.39 6419.94 3586.02 -5325.04 3.77 598177829 577705.13 N 70 21 37.253 W 149 22 7.721 8816.12 49.10 322.96 5312.03 5388.03 6487.08 6524.28 6488.39 3642.53 -5369.47 1.80 5981834.30 577660.08 N 70 21 37.808 W 149 22 9.021 8912.24 49.61 325.79 5374.65 5450.65 6554.98 6597.20 6556.86 3701.80 -5411.94 2.30 5981893.10 577616.96 N 70 21 38.391 W 149 22 10.264 9004.93 50.48 328.08 5434.18 5510.18 6619.91 6668.25 6622.52 3761.35 -5450.69 2.11 5981952.20 577577.56 N 70 21 38.976 W 149 22 11.399 9099.44 51.44 330.68 5493.71 5569.71 6685.65 6741.65 6689.22 3824.51 -5488.06 2.37 5982014.95 577539.49 N 70 21 39.597 W 149 22 93 9192.83 51.06 332.09 5552.17 5628.17 6749.73 6814.48 6754.47 3888.45 -5522.94 125 5982078.48 577503.90 N 70 21 40.226 W 149 2 4 9286.02 50.45 335.43 5611.13 5687.13 6811.74 6886.64 6817.91 3953.16 -5554.85 2.85 5982142.83 577471.28 N 70 21 40.862 W 149 2 48 9379.83 50.27 339.07 5670.99 5746.99 6871.43 6958.87 6879.38 4019.76 -5582.78 2.99 5982209.11 577442.62 N 70 21 41.517 W 149 22 15.267 9472.68 49.85 343.26 5730.62 5806.62 6927.39 7030.05 6937.51 4087.10 -5605.76 3.49 5982276.19 577418.90 N 70 21 42.179 W 149 22 15.940 9566.80 50.44 347.05 5790.94 5866.94 6980.92 7102.29 6993.73 4156.93 -5624.26 3.15 5982345.80 577399.63 N 70 21 42.865 W 149 22 16.482 9659.38 52.21 350.91 5848.81 5924.81 7031.11 7174.56 7047.14 4227.85 -5638.04 3.77 5982416.56 577385.06 N 70 21 43.563 W 149 22 16.887 9752.24 54.73 353.99 5904.09 5980.09 7079.58 7249.16 7099.52 4301.80 -5647.81 3.80 5982490.39 577374.48 N 70 21 44.290 W 149 22 17.174 9777.11 55.81 354.88 5918.26 5994.26 7092.32 7269.60 7113.44 4322.15 -5649.79 5.24 5982510.71 577372.27 N 70 21 44.490 W 149 22 17.233 9808.88 56.28 357.05 5936.00 6012.00 7108.19 7295.95 7130.91 4348.43 -5651.64 5.86 5982536.97 577370.13 N 70 21 44.749 W 149 22 17287 9839.67 56.45 359.25 5953.06 6029.06 7122.83 7321.58 7147.21 4374.05 -5652.46 6.06 5982562,57 577369.02 N 70 21 45.001 W 149 22 17.312 9870.46 57.11 1.10 5969.93 6045.93 7136.79 7347.34 7162.94 4399.80 -5652.38 5.39 5982588.33 577368.82 N 70 21 45.254 W 149 22 17.310 9901.63 57.16 3.01 5986.84 6062.84 7150.25 7373.52 7178.30 4425.97 -5651.44 5.15 5982614,50 577369.47 N 70 21 45.511 W 149 22 17.283 9932.39 57.06 5.46 6003.55 6079.55 7162.68 7399.35 7192.71 4451.72 -5649.53 6.70 598264027 577371.09 N 70 21 45.765 W 149 22 17.228 SurveyEditor Ver SP 1.0 Bld( doc40x_56) N-F\L-123\L-123\L-123 Generated 2/17/2006 11:48 AM Page 3 of 5 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft it ft ft ft de /100 ft ftUS ftUS 9963.71 57.38 6.54 6020.51 6096.51 7174.63 7425.68 7206.79 4477.91 -5646.78 3.07 5982666.48 577373.56 N 70 21 46.022 W 149 22 17.148 9994.69 57.98 9.74 6037.07 6113.07 7185.63 7451.86 7220.02 4503.82 -5643.07 8.94 5982692.43 577376.98 N 70 21 46.277 W 149 22 17.040 10025.45 57.31 13.11 6053.54 6129.54 7195.19 7477.84 7231.92 4529.29 -5637.93 9.51 5982717.95 577381.84 N 70 21 46.527 W 149 22 16.890 10056.60 57.88 16.32 6070.23 6146.23 7203.44 7504.14 7242.68 4554.72 -5631,24 8.89 5982743.45 577388.23 N 70 21 46.778 W 149 22 16.695 10087.66 58.36 18.25 6086.64 6162.64 7210.58 7530.52 7252.46 4579.90 -5623.41 5.50 5982768.71 577395.79 N 70 21 47.025 W 149 22 16.467 10117.23 59.35 21.70 6101.94 6177.94 7216.28 7555.82 7260.81 4603.68 -5614.76 10.53 5982792.58 577404.17 N 70 21 47.259 W 149 22 16.214 10148.85 59.85 25.84 6117.94 6193.94 7220.65 7583.09 7268.18 4628.63 -5603.77 11.40 5982817.65 577414.89 N 70 21 47.505 W 149 22 15.894 10179.08 60.48 27.59 6132.98 6208.98 7223.52 7609.31 7274.05 4652.05 -5591.98 5.44 5982841.20 577426.41 N 70 21 47.735 W 149 22 15.549 10209.76 60.09 30.31 6148.19 6224.19 7225.40 7635.96 7279.09 4675.36 -5579.09 7.80 5982864.65 577439.05 N 70 21 47.965 W 149 22 15.173 10241.39 59.08 31.66 6164.21 6240.21 7226.36 7663.23 7283.40 4698.75 -5565.04 4.87 5982888.19 577452.83 N 70 21 48.195 W 149 2214.763 10271.75 58.76 33.71 6179.88 6255.88 7226.50 7689.23 7286.84 4720.63 -5551.01 5.88 5982910.22 577466.62 N 70 21 48.410 W 149 2 3 10302.65 59.07 37.53 6195.84 6271.84 7225.29 7715.69 7289.08 4742.13 -5535.60 10.63 5982931.90 577481.79 N 70 2i 48.622 W 149 2 2 10334.13 59.45 41.59 6211.93 6287.93 7222.20 7742.75 7289.61 4762.99 -5518.37 11.15 5982952.94 577498.79 N 70 21 48.827 W 149 22 99 10365.50 59.41 43.58 6227.89 6303.89 7217.70 7769.76 7288.82 4782.87 -5500.09 5.46 5982973.02 577516.84 N 70 21 49.022 W 149 22 12.865 10397.04 60.28 43.68 6243.73 6319.73 7212.67 7797.03 7287.62 4802.61 -5481.28 2.77 5982992.97 577535.43 N 70 21 49.217 W 149 22 12.315 10490.10 63.68 46.08 6287.45 6363.45 7195.74 7879.17 7282.82 4860.79 -5423.30 4.30 5983051.78 577592.75 N 70 21 49.789 W 149 22 10.621 10583.98 68.50 49.77 6325.50 6401.50 7173.60 7964.96 7274.22 4918.23 -5359.60 6.27 5983109.92 577655.81 N 70 21 50.355 W 149 22 8.759 10677,68 74.13 50.97 6355.51 6431.51 7147.09 8053.68 7262.65 4974.81 -5291.25 6.13 5983167.24 577723.52 N 70 21 50.912 W 149 22 6.762 Tie-In Survey 10677.68 74.13 50.97 6355.51 6431.51 7147.09 8053.68 7262.65 4974.81 -5291.25 0.45 5983167.24 577723.52 N 70 21 50.912 W 149 22 6.762 Top Window (Inc Only) 10723.00 73.87 50.95 6368.07 6444.07 7133.67 8097.23 7256.93 5002.23 -5257.43 1.02 5983195.04 577757.03 N 70 21 51.182 W 149 22 5.773 Base Window (Inc Only) 10736.00 75.46 52.05 6371.53 6447.53 7129.69 8109.76 7255.21 5010.03 -5247.63 16.00 5983202.95 577766.75 N 70 21 51.258 W 149 22 5.487 Inc Only 10779.46 77.07 54.18 6381.85 6457.85 7115.17 8151.97 7248.40 5035.37 -5213.86 6.03 5983228.65 577800.22 N 70 21 51.508 W 149 22 4.500 Inc Only 10811.02 79.86 55.71 6388.16 6464.16 7103.61 8182.89 7242.59 5053.13 -5188.55 10.04 5983246.69 577825.34 N 70 21 51.683 W 149 22 3.760 First MW D+IFR+MS 10841.05 80.39 57.15 6393.31 6469.31 7091.85 8212.48 7236.40 5069.48 -5163.90 5.04 5983263.32 577849.80 N 70 21 51.844 W 149 22 3.039 10874.71 80.57 58.83 6398.88 6474.88 7077.83 8245.67 7228.72 5087.08 -5135.75 4.95 5983281.22 577877.75 N 70 21 52.017 W 149 22 2.216 10905.17 80.46 58.36 6403.90 6479.90 7064.85 8275.72 7221.57 5102.74 -5110.11 1.56 5983297.16 577903.21 N 70 21 52.171 W 149 221.467 10936.16 80.54 58.31 6409.02 6485.02 7051.77 8306.28 7214.56 5118.78 -5084.10 0.30 5983313.49 577929.05 N 70 21 52.329 W 149 22 0.706 10966.25 80.85 59.18 6413.88 6489.88 7038.87 8335.98 7207.66 5134.19 -5058.71 3.03 5983329.17 577954.26 N 70 21 52.481 W 149 21 59.964 10998.70 79.91 56.72 6419.31 6495.31 7025.38 8367,97 7200.79 5151.16 -5031.60 8.02 5983346.45 577981.18 N 70 21 52.648 W 149 22 11029.65 80.36 57.71 6424.61 6500.61 7012.87 8398.46 7194.75 5167.67 -5005.96 3.47 5983363.24 578006.63 N 70 21 52.810 W 149 2 2 11061.28 80.46 57.68 6429.88 6505.88 6999.84 8429.65 7188.45 5184.34 -4979.60 0.33 5983380.20 578032.80 N 70 21 52.974 W 149 21 57.652 11092.37 80.70 57.58 6434.97 6510.97 6987.06 8460.32 7182.41 5200.76 -4953.70 0.83 5983396.90 578058.52 N 70 21 53.136 W 149 21 56.894 11124.51 80.73 58.41 6440.15 6516.15 6973.65 8492.04 7176.10 5217,57 -4926.80 2,55 5983414.01 578085.22 N 70 21 53.302 W 149 21 56.108 11155.51 82.98 57.97 6444.54 6520.54 6960.59 8522.73 7170.02 5233.75 -4900.72 7.39 5983430.47 578111.12 N 70 21 53.461 W 149 21 55.346 11186.30 86.52 57.28 6447.36 6523.36 6947.82 8553.38 7164.37 5250.16 -4874.83 11.71 5983447.17 578136.82 N 70 21 53.622 W 149 21 54.589 11216.34 88.40 57.84 6448.69 6524.69 6935.35 8583.39 7158.99 5266.26 -4849.51 6.53 5983463.55 578161.97 N 70 21 53.781 W 149 21 53.849 11247.85 91.57 58.24 6448.70 6524.70 6922.01 8614.90 7153.22 5282.94 -4822.78 10.14 5983480.52 578188.51 N 70 21 53.945 W 149 21 53.067 11279.65 92.29 57.07 6447.63 6523.63 6908.76 8646.68 7147.74 5299.94 -4795.93 4.32 5983497.81 578215.16 N 70 21 54.112 W 149 21 52.282 11310.26 92.32 57.31 6446.40 6522.40 6896.22 8677.26 7142.85 5316.51 -4770.22 0.79 5983514.67 578240.68 N 70 21 54276 W 149 21 51.531 11340.59 92.47 53.87 6445.13 6521.13 6884.58 8707.57 7138.96 5333.63 -4745.22 11.34 5983532.07 578265.49 N 70 21 54.444 W 149 21 50.800 11372.73 92.09 52.72 6443.85 6519.85 6873.44 8739.68 7136.26 5352.83 -4719.48 3.77 5983551.54 578291.02 N 70 21 54.633 W 149 21 50.047 SurveyEditor Ver SP 1.0 Bld( doc40x_56) N-F\L-123\L-123\L-123 Gen erated 2/17/2006 11:48 AM Page 4 of 5 Measured Vertical Along Hole Comments inclination Azimuth Sub-Sea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS 114V4.:i1 yL.1'L 51.13 Ei441.tiy (iblti.Eiy tiki(i3.Ll tl//1.'L4 /1:i4.bU b:i/"L.1y -4tiy4.ti:i b.U3 byt53b/1.118 5/2S;ilb.fi4 N /UGl 54.t51b W 14yL1 4y.3'Ll 11434.56 92.16 49.03 6441.56 6517.56 6854.33 8801.47 7133.92 5391.69 -4671.45 6.94 5983590.93 578338.60 N 70 21 55.016 W 149 21 48.644 11466.08 91.62 49.18 6440.52 6516.52 6845.59 8832.97 7133.98 5412.31 -4647.64 1.78 5983611.81 578362.18 N 70 21 55.219 W 149 21 47.948 11496.52 91.77 49.81 6439.62 6515.62 6836.95 8863.40 7133.96 5432.07 -4624.50 2.13 5983631.83 578385.09 N 70 21 55.413 W 149 21 47.271 11527.50 91.28 49.32 6438.80 6514.80 6828.12 8894.37 7134.05 5452.16 -4600.93 2.24 5983652.17 578408.44 N 70 21 55.611 W 149 21 46.582 11558.42 91.29 48.77 6438.10 6514.10 6819.58 8925.28 7134.54 5472.42 -4577.59 1.78 5983672.69 578431.56 N 70 21 55.810 W 149 21 45.900 11589.50 91.70 50.40 6437.29 6513.29 6810.71 8956.35 7134.88 5492.56 -4553.93 5.41 5983693.09 578454.99 N 70 21 56.008 W 149 21 45.208 11620.06 92.29 51.80 6436.23 6512.23 6801.22 8986.89 7134.54 5511.74 -4530.16 4.97 5983712.53 578478.54 N 70 21 56.197 W 149 21 44.514 11651.17 93.19 55.27 6434.74 6510.74 6790.33 9017.96 7133.01 5530.21 -4505.18 11.51 5983731.27 578503.31 N 70 21 56.379 W 149 21 43.783 11681.34 93.09 56.64 6433.09 6509.09 6778.58 9048.09 7130.38 5547.07 -4480.22 4.55 5983748.41 578528.08 N 70 21 56.545 W 149 21 43.054 11712.74 93.11 56.64 6431.39 6507.39 6766.01 9079.44 7127.41 5564.31 -4454.03 0.06 5983765.94 578554.08 N 70 21 56.715 W 149 21 42.288 11743.83 93.13 56.98 6429.70 6505.70 6753.47 9110.49 7124.51 5581.31 -4428.05 1.09 5983783.22 578579.86 N 70 21 56.882 W 149 2 28 11775.22 92.94 56.03 6428.04 6504.04 6740.97 9141.83 7121.88 5598.61 -4401.91 3.08 5983800.80 578605.81 N 70 21 57.052 W 149 64 11806.92 92.82 56.54 6426.44 6502.44 6728.46 9173.49 7119.49 5616.18 -4375.57 1.65 5983818.67 578631.94 N 70 21 57.225 W 149 21 .994 11838.24 93.88 55.68 6424.61 6500.61 6716.18 9204.76 7i i7.36 5633.61 -4349.62 4.36 5983836.38 578657.70 N 70 21 57.397 W 149 21 39.235 11869.46 94.06 54.53 6422.45 6498.45 6704.46 9235.90 7115.92 5651.43 -4324.07 3.72 5983854.48 578683.04 N 70 21 57.572 W 149 21 38.489 11900.21 93.78 54.41 6420.35 6496.35 6693.24 9266.58 7114.97 5669.26 -4299.11 0.99 5983872.58 578707.81 N 70 21 57.748 W 149 21 37.759 11930.95 94.04 52.78 6418.25 6494.25 6682.45 9297.25 7114.63 5687.46 -4274.43 5.36 5983891.05 57873229 N 70 21 57.927 W 149 21 37.037 11961.55 94.12 51.17 6416.08 6492.08 6672.52 9327.77 711528 5706.26 -4250.38 5.25 5983910.12 578756.12 N 70 21 58.112 W 149 21 36.334 11993.27 93.66 51.08 6413.92 6489.92 6662.68 9359.42 7116.56 5726.12 -4225.75 1.48 5983930.25 578780.53 N 70 21 58.307 W 149 21 35.614 12024.20 93.46 51.43 6412.00 6488.00 6653.01 9390.29 7117.87 5745.44 -4201.67 1.30 5983949.84 578804.39 N 70 21 58.497 W 149 21 34.910 12056.17 93.29 52.03 6410.12 6486.12 6642.76 9422.20 7119.11 5765.21 -4176.61 1.95 5983969.88 578829.22 N 70 21 58.692 W 149 21 34.178 12086.82 93.28 48.69 6408.36 6484.36 6633.63 9452.80 7121.16 5784.73 -4153.05 10.88 5983989.65 578852.56 N 70 21 58.884 W 149 21 33.489 12118.88 90.95 50.51 6407.18 6483.18 6624.48 9484.84 7123.87 5805.49 -4128.66 9.22 5984010.68 578876.73 N 70 21 59.088 W 149 21 32.776 12148.59 88.79 49.70 6407.25 6483.25 6615.74 9514.55 7126.25 5824.54 -4105.86 7.76 5984029.99 578899.30 N 70 21 59.276 W 149 21 32.109 12180.24 88.83 49.79 6407,91 6483.91 6606.63 9546.19 7129.12 5844.99 -4081.71 0.31 5984050.70 578923.22 N 70 21 59.477 W 149 21 31.403 12210.94 89.03 49.46 6408.48 6484.48 6597.54 9576.89 7132.10 5864.88 -4058.33 126 5984070.84 578946.38 N 70 21 59.673 W 149 21 30.720 12241.96 90.02 51.11 6408.74 6484.74 6588.63 9607.90 7134.89 5884.69 -4034.47 6.20 5984090.92 578970.02 N 70 21 59.868 W 149 21 30.022 12272.84 91.25 51.82 6408.39 6484.39 6578.85 9638.78 7137.16 5903.93 -4010.32 4.60 5984110.42 578993.95 N 70 22 0.057 W 149 21 29.316 12303.87 91.21 52.60 6407.73 6483.73 6568.64 9669.80 7139.18 5922.94 -3985.80 2.52 5984129.70 579018.26 N 70 22 0.244 W 149 2 99 12335.69 92.13 50.37 6406.80 6482.80 6558.56 9701.61 7141.78 5942.75 -3960.92 7.58 5984149.78 579042.92 N 70 22 0.439 W 149 72 Last MW D+IFR+MS 12360.38 92.38 50.13 6405.83 6481.83 6551.24 9726.28 7144.43 5958.52 -3941.95 1.40 5984165.76 579061.71 N 70 22 0.594 W 149 2 17 TD (Projected) 12405.00 92.38 50.13 6403.98 6479.98 6538.11 9770.86 7149.53 5987.10 -3907.73 0.00 5984194,71 579095.60 N 70 22 0.876 W 149 21 26.317 Survey Type: Definitive Survey NOTES: GYD-GC-MS - (Gyrodata - gyro com passing m/s -- Older Gyrodata gyro multishots-plus all battery/memory tool surveys (RGS-BT). Replaces ex-BP "Gyrodata multishot into open hole" model. Not to be run above 70 degrees inclination.. ) MWD +IFR + MS - (In-field referenced MWD with mutt-station analysis and correctio n applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) LegaLDescription: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 2531 FSL 3846 FEL S34 T12N Ri 1 E UM 5978251.86 583069.09 BHL : 3237 FSL 2462 FEL S28 T12N Ri 1 E UM 5984194.71 579095.60 SurveyEditor Ver SP 1.0 Bld( doc40x_56) N-F\L-123\L-123\L-123 Generated 2/1 7/2006 1 1:48 AM Page 5 of 5 TREE = 4-1/16" C,M! WELLHEAD= FMC ACTUATOR = LEO KB. ELEV = 28.5' AMSL _.. BF. ELEV = 47.50' AMSL KOP = _ _ 400' Max Angle = 94 @ 11962' -Datum MD = 7684` Datum TV D = 6600` SS? ~ L-123 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" --r 3644' Minimum ID = 3.725" @ 10500' 4-1/2" HES XN NIPPLE SAFETY NOTES: 2827' I-(4-112" HES X NIP, ID = 3.813" 17" HES ES CEMENTER I 10435' ~4-1l2" HES X NIP, ID = 3.813" 10456' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 10480' 4-112" HES X NIP, ID = 3.813" 10500' 4-1/2" HES XN NIP, ID = 3.725" 10522' 7" X 5" BKR HRD ZXP LNR TOP PKR, wiTIEBACK SLV, ID = 4.410" 4-1/2" TBG, 12.6#, L-80 TCII, .0152 bpf, ID = 3.958" 10523' 10523' 4-1l2" WLEG, ID = 3.958" 10542' RS PACKOFF SEAL NIP, ID = 4.250" 10544' 7" X 5" BKR HMC LNR HNGR, ID = 4.41" 10554' 5" X 4-1/2" XO, ID = 3.98" 10559' 4-1/2" RA MARKERJT BKR WHIPSTOCK (12129/05) ~ 10723' 7" HES EZSV (12/28105) 10743' 7" CSG, 26#, L-80 BTGM, ID = 6.276~ 11393' PERFORATION SUMMARY REF LOG: MWDON'?'?%`%%'%? ANGLE AT TOP PERF: 80 @ 10915' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2-7l8" 6 10915 - 10960 O 01/03/06 2-7/8" 6 10975 - 11090 O 01103(06 2-7/8" 6 11110 - 11140 O 01/03!06 2-718" 6 11180 - 11210 O 01/03/06 2-7/8" 6 11830 - 11850 O Oi/03/06 2-7l8" 6 11945 - 11980 O 01!03/06 2-718" 6 12030 - 12080 O 01103!06 2-718" 6 12150 - 12190 O 01/03/06 2-718" 6 12270 - 12340 O 01!03/06 MILLOl1T WINDOW (L-123) 10723' - 10736' 11277' Ia-1/2" RA MARKER JT PBTD 12361' 4-1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" -~ DATE REV BY COMMENTS DATE REV BY COMMENTS 01/07106 N9ES ORIGINAL COMPLETION 01/25/06 BMcN~TLH DRLG DRAFT CORRECTIONS 02/05/06 DTRlPJC GLV C10 BOREALIS UNIT WELL: L-123 PERMfT' No: 2051940 API No: 50-029-23290-00 SEC 34 , T12N, R11 E, 2748' FNL & 3845' FEL BP Exploration (Alaska) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3594 6641 2590 4130 57 58 KBG2 KBG2 DOME SO BK BK 16 20 02/05/06 02/05!06 ~~~® ~~ Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 December 27, 2005 Ms. Sharmaine Copeland BP Exploration (Alaska) inc. 900 E. Benson Blvd. Petrotechnical Data Center, LR2-1 Anchorage, Alaska 99508 Re: L-Pad, VVe91 #L-'i 23BP'i Prudhoe Bay, Alaska Enclosed, please find one (1) original, two (2) copies, and two (2) disks of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, .~~ ~~ Rob Shoup ~~ ~~ North American Operations Manager RS:tf er~~ng ti18 Worldwide Energy ~rtdustry with Precisian Survey ~nstrumentatian gyro d . Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP L-PAD #L-123P61 NABORS #9-ES PRUDHOE BAY, AK AK1205G_575 DECEMBER 15, 2005 Serving the Worldwide Energy Industry with Rrecision Survey Instrumentation A Gyrodata Directi onal Survey for BP EXPLORATION (ALASKA), INC. Lease: L-Pad Well: L-123PB1, 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska Job Number: AK1205G 575 Run Date: 15 Dec 2005 Surveyor: Henry Drew Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350556 deg. N Longitude: 149.325562 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location • Horizontal Coordinates Calculated from Well Head Location L A Gyrodata Directi oval Survey BP Exploration (Alaska), Inc. Lease: L-Pad Well: L-123PB1, 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska Job Number: AK1205G 575 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg. min. deg./ feet feet deg. feet 100 ft. 0.00 oo 0 0 00 N 0 0 E 0.00 0.00 - - -- 0 0- ---- O-O----------- ---0.00 N---- ------- O-oo- E- - ----------------- ---- --------------- ---------------------- ----------- ------ -------- ------------ - - 0 - 1557 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 4" DRILLPIPE ------ ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9-ES ROTARY TABLE OF 76 FT. TO MSL ---------------------------------------------------------------------------------------------------------------------------------------------------------------- ---------------- ------------------ 100.00 0.21 33.43 N 33 26 E 0.21 100.00 0.2 33.4 0.16 N 0.10 E 200.00 1.44 343.86 N 16 9 W 1.31 199.99 1.5 354.6 1.52 N 0.14 W 300.00 3.27 336.22 N 23 47 W 1.86 299.90 5.6 342.9 5.33 N 1.64 W 400.00 4.00 333.81 N 26 12 W 0.75 399.70 11.9 338.6 11.07 N 4.33 W 500.00 5.30 327.67 N 32 20 W 1.39 499.37 19.9 335.3 18.10 N 8.34 W 600.00 8.14 329.47 N 30 32 W 2.85 598.67 31.6 332.9 28.10 N 14.41 W 700.00 11.72 331.44 N 28 34 W 3.60 697.16 48.8 332.1 43.12 N 22.86 W 800.00 15.96 331.48 N 28 31 W 4.24 794.23 72.7 331.9 64.13 N 34.28 W 900.00 19.42 329.42 N 30 35 W 3..51 889.49 103.1 331.4 90.53 N 49.31 W 1000.00 23.24 326.20 N 33 48 W 4.00 982.63 139.4 330.4 121.25 N 68.75 W 1100.00 26.45 321.33 N 38 40 W 3.80 1073.37 181.1 328.9 155.04 N 93.65 W 1200.00 29.20 319.69 N 40 19 W 2.85 1161.80 227.4 327.1 191.04 N 123.35 W 1300.00 32.51 315.10 N 44 54 W 4.06 1247.65 278.0 325.3 228.69 N 158.12 W 1400.00 35.20 312.65 N 47 21 W 3.02 1330.69 332.8 323.4 267.27 N 198.30 W 1500.00 39.54 306.30 N 53 42 W 5.80 1410.17 391.9 321.3 305:67 N 245.19 W 1557.00 42.26 305.57 N 54 26 W 4.84 1453.24 428.0 319.9 327.57 N 275.41 W Final Station Closure: Distance: 427.96 ft Az: 319.94 deg. 2 BP Exploration (Alaska), Inc. Well: L-Pad L-123PB1 4" Drill pipe Location: Nabors #9-ES, Prudhoe Bay, Alaska outrun Gyrodata AK1205G_575 DEFINITIVE s, 300 ---g~-~°~-p 0 LOCATED MD: 1557.0 250 200 ,-. ~. z p 150 z 100 50 0 • __ I • -250 -200 -150 -100 FASTING (ft) -50 0 BP Exploration (Alaska), Inc. Well: L-Pad L-123PB1 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bav, Alaska 15.0 12.5 10.0 0 0 a~ 7.5 w w C7 w J C~ ~ 5.0 0 2.5 0.0 -outrun Gyrodata AK1205G 575 DEFINITIVE i BOTTOM HO E LOCATE D MD: 1557.00 - - ~ - ~~_ ~ ~~ -- ---_~ .A' ~ ~~ ~~~' _ , ~" e n 250 500 750 1000 1250 1500 1750 MEASURED DEPTH (ft) f BP Exploration (Alaska), Inc. Well: L-Pad L-123P61 4" Drillpipe Location: Nabors #9-ES, Prudhoe Bay, Alaska 40 35 30 ~" z 25 O I- Q z v 20 z 15 10 5 0 'Outrun Gyrodata AK1205G_575 DEFINITIVE ~. a __•- -- -_ BOTTOM HC - ~O~AT€9--- MD: 1557.0 250 500 750 1000 1250 1500 175 MEASURED DEPTH (ft) C S.CHLiJMBERGER Survey report Client .................... Field ..................... Well ...................... API number ................ Engineer .................. Rig :...................... STATE :.................... ----- Survey calculation m Method for positions.....: Method for DLS............ BP Exploration (Alaska) Inc. Borealis L-123 50-029-23290-00 Davies Nabors 9ES Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 47.50 ft KB above permanent.......: 0.00 ft DF above permanent.......: 76.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)........: 0.00 ft Azimuth from Vsect Origin to target: 303.00 degrees y,, `' ~ [(c)2006 IDEAL ID10 2C O1] ~. - - -~ 1-Jan-2006 08:00:31 Page 1 of 8 Spud date ................. 12-Dec-05 Last survey date.........: Ol-Jan-06 Total accepted surveys...: 183 MD of first survey.......: 0.00 ft MD of last survey........: 12405.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date............. 13-Dec-2005 Magnetic field strength..: 1151.56 HCNT Magnetic dec (+E/W-).....: 24.39 degrees Magnetic dip....... ..... 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip.......... Tolerance of G............ Tolerance of H............ Tolerance of Dip.......... Criteria ~--------- 1002.68 meal 1151.56 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.38 degrees Grid convergence (+E/W-).: O.OO degrees Total az corr (+E/W-)....: 24.38 degrees (Total az corr = magnetic dec - grid cony) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • SCI-LUMBERGER Survey Report 1-Jan-2006 08:00:31 Page 2 of 8 Seq Measured Incl Azimuth Course -- TVD Vertical Displ Displ ------- Total -------- At ----- DLS ====- Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 -- -- 0.00 --------- 0.00 ------- 0.00 -------- 0.00 ----- 0.00 ----- ------ TIP None 2 100.00 0.21 33.43 100.00 100.00 -0.00 0.15 0.10 0.18 33.43 0.21 GYR None 3 200.00 1.44 343.86 100.00 199.99 0.95 1.51 -0.15 1.52 354.44 1.31 GYR None 4 300.00 3.27 336.22 100.00 299.90 4.28 5.33 -1.65 5.58 342.83 1.85 GYR None 5 400.00 4.00 333.81 100.00 399.70 9.67 11.07 -4.34 11.89 338.61 0.75 GYR None 6 500.00 5.30 327.67 100.00 499.37 16.86 18.10 -8.35 19.93 335.25 1.39 GYR None 7 600.00 8.14 329.47 100.00 598.67 27.40 28.11 -14.41 31.59 332.85 2.85 GYR None 8 700.00 11.72 331.44 100.00 697.16 42.67 43.13 -22.87 48.82 332.07 3.60 GYR None 9 800.00 15.96 331.48 100.00 794.23 63.69 64.14 -34.29 72.73 331.87 4.24 GYR None 10 900.00 19.42 329.42 100.00 889.49 90.67 90.54 -49.32 103.10 331.42 3.52 GYR None 11 1000.00 23.24 326.20 100.00 982.62 123.71 121.26 -68.76 139.40 330.44 3.99 GYR None 12 1100.00 26.45 321.33 100.00 1073.37 163.00 155.05 -93.66 181.15 328.87 3.80 GYR None 13 1200.00 29.20 319.69 100.00 1161.80 207.51 191.05 -123.36 227.42 327.15 2.85 GYR None 14 1300.00 32.51 315.10 100.00 1247.64 257.18 228.70 -158.13 278.04 325.34 4.06 GYR None 15 1400.00 35.20 312.65 100.00 1330.69 311.88 267.27 -198.30 332.80 323.43 3.02 GYR None 16 1500.00 39.54 306.30 100.00 1410.17 372.12 305.68 -245.19 391.87 321.27 5.80 GYR None 17 1597.13 44.98 303.55 97.13 1482.04 437.37 342.98 -298.77 454.86 318.94 5.91 MWD IFR MSA 18 1688.78 48.99 303.78 91.65 1544.55 504.36 380.13 -354.53 519.79 317.00 4.38 MWD IFR MSA 19 1783.18 51.21 305.46 94.40 1605.10 576.74 421.28 -414.11 590.73 315.49 2.72 MWD IFR MSA 20 1875.79 50.25 304.92 92.61 1663.72 648.39 462.60 -472.70 661.39 314.38 1.13 MWD IFR MSA 21 1969.31 53.27 304.50 93.52 1721.59 721.80 504.42 -533.07 733.90 313.42 3.25 MWD IFR MSA 22 2063.03 56.07 305.32 93.72 1775.79 798.21 548.18 -595.76 809.59 312.62 3.07 _ _ MWD IFR MSA 23 2155.77 56.70 305.45 92.74 1827.13 875.37 592.90 -658.73 886.26 311.99 0.69 _ _ MWD IFR MSA 24 2249.91 58.49 303.71 94.14 1877.58 954.81 637.99 -724.17 965.12 311.38 2.46 _ _ MWD IFR MSA 25 2343.48 57.75 303.97 93.57 1927.00 1034.26 682.24 -790.16 1043.94 310.81 0.83 MWD IFR MSA 26 2436.52 58.29 303.16 93.04 1976.27 1113.17 725.87 -855.92 1122.27 310.30 0.94 MWD IFR MSA 27 2530.29 57.58 302.96 93.77 2026.05 1192.64 769.22 -922.52 1201.14 309.82 0.78 MWD IFR MSA 28 2623.98 58.96 302.98 93.69 2075.33 1272.32 812.58 -989.37 1280.29 309.40- 1..47 MWD IFR MSA 29 2716.74 57.72 303.15 92.76 2124.01 1351.28 855.66 -1055.54 1358.79 309.03 1.35 _ _ MWD IFR MSA 30 2809.87 58.61 303.15 93.13 2173.14 1430.40 898.93 -1121.78 1437.52 308.71 0.96 _ _ MWD IFR MSA • • [(c)2006 IDEAL ID10 2C 01] SCfTLUMBERGER Survey Report 1-Jan-2006 08:00:31 Page 3 of 8 Seq Measured Incl - Azimuth ------ Course -------- TVD -------- Vertical ==-==P= Dis 1 =======p= Dis 1 __=____ Total ________ At ___-_ DLS _____ Srvy Tool # depth angle angle length depth section +NJS- +EjW- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2904.01 57.90 302.72 94.14 2222.67 1510.45 942.45 -1188.97 1517.19 308.40 0.85 MWD IFR MSA 32 2996.72 57.01 303.12 92.71 2272.54 1588.60 984.92 -1254.58. 1595.00 308.13 1.03 MWD IFR MSA 33 3089.02 58.53 303.97 92.30 2321.76 1666.67 1028.07 -1319.64 1672.84 307.92 1.82 MWD IFR MSA 34 3182.17 57.65 303.86 93.15 2371.00 1745.74 1072.19 -1385.26 1751.73 307.74 0.95 MWD IFR MSA 35 3276.40 58.69 302.71 94.23 2420.70 1825.79 1116.12 -1452.19 1831.55 307.55 1.51 MWD IFR MSA 36 3368.06 58.08 303.25 91.66 2468.75 1903.85 1158.61 -1517.67 1909.37 307.36 0.83 MWD IFR MSA 37 3461.68 57.68 303.23 93.62 2518.53 1983.14 1202.07 -1583.98 1988.46 307.19 0.43 MWDr IFR _ MSA 38 3555.02 57.04 303.05 93.34 2568.87 2061.74 1245.04 -1649.80 2066.87 307.04 0.70 _ MWD IFR _ MSA 39 3589.02 56.93 303.03 34.00 2587.39 2090.25 1260.59 -1673.70 2095.31 306.99 0.33 _ MWD IFR _ MSA 40 3692.64 55.11 302.95 103.62 2645.31 2176.17 1307.37 -1745.76 2181.03 306.83 1.76 _ MWD IFR _ MSA 41 3785.75 56.?8 300.61 93.11 2697.45 2253.28 1347.98 -1811.34 2257.87 306.66 2.75 MWD IFR MSA 42 3880.02 60.18 298.52 94.27 2746.73 2333.48 1387.60 -1881.23 2337.62 306.41 4.07 MWD+ IFR _ MSA 43 3971.58 59.79 298.81 91.56 2792.53 2412.53 1425.63 -1950.80 2416.20 306.16 0.51 MWD IFR MSA 44 4066.16 59.51 298.94 94.58 2840.32 2493.94 1465.04 -2022.27 2497.18 305.92 0.32 MWD IFR MSA 45 4160.53 58.87 298.73 94.37 2888.66 2574.77 1504.13 -2093.27 2577.63 305.70 0.70 MWD IFR MSA 46 4253.99 58.18 298.90 93.46 2937.45 2654.27 1542.55 -2163.11 2656.78 305.49 0.75 MWD IFR MSR 47 4347.61 57.71 299.10 93.62 2987.14 2733.42 1581.02 -2232.51 2735.64 305.31 0.53 _ MWD IFR _ MSA 48 4444.71 59.10 298.92 97.10 3038.01 2815.93 1621.12 -2304.84 2817.86 305.12 1.44 _ MWD IFR _ MSA 49 4539.54 58.10 300.02 94.83 3087.42 2896.71 1660.94 -2375.31 2898.41 304.96 1.45 _ MWD IFR _ MSA 50 4634.14 57.51 301.12 94.60 3137.82 2976.69 1701.65 -2444.23 2978.24 304.85 1.16 MWD IFR MSA 51 4729.50 58.85 299.82 95.36 3188.10 3057.64 . 1742.73 -2514..07 3059.03 304.73 1.82 MWD IFR MSA 52 4824.60 59.19 300.70 95.10 3237.05 3139.08 1783.82 -2584.49 3140.32 304.61 0.87 _ MWD IFR _ MSA 53 4919.14 58.62 300.31 94.54 3285.88 3219.95 1824.91 -2654.24 3221.07 304.51 0.70 MWD IFR MSA 54 5014.26 58.21 300.78 95.12 3335.70 3300.91 1866.09 -2724.03 3301.91 304.41 0.60 _ MWD IFR _ MSA 55 5109.01 57.69 300.73 94.75 3385.98 3381.16 1907.16 -2793.04 3382.06 304.33 0.55 _ MWD IFR _ MSA 56 5203.21 57.21 300.86 94.20 3436.66 3460.50 1947.81 -2861.25 3461.32 304.25 0.52 MWD IFR MSA 57 5303.90 56.48 300.95 100.69 3491.73 3544.74 1991.11 -2933.58 3545.47 304.17 0.73 MWDy IFR _ MSA 58 5396.75 56.91 301.20 92.85 3542.71 3622.30 2031.16 -3000.04 3622.96 304.10 0.51 MWD IFR MSA 59 5491.40 58.03 301.10 94.65 3593.61 3702.05 2072.44 -3068.33 3702.66 304.04 1.19 _ MWD IFR _ MSA 60 5586.17 59.43 299.19 94.77 3642.81 3782.95 2113.11 -313$.38 3783.47 303.95 2.27 MWD IFR MSA • • [(c)2006 IDEAL ID10 2C O1] SC~fLUMBERGER Survey Report 1-Jan-2006 08:00:31 Page 4 of 8 5eq Measured Incl -- Azimuth ------ Course -------- TVD --=-=--- Vertical =====p========p= Dis 1 Dis 1 =______ Total ________ At ____= DLS =_~ __.____ S Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - {ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5680.66 60.21 298.69 94.49 3690.31 3864.42 2152.63 -3209.86 3864.85 303.85 0 94` MWD IFR MSA 62 5776.04 58.66 300.58 95.38 3738.81- 3946.40 2193.23 -3281.24 3946.75 303.76 2.36 M4VD _ IFR _ MSA 63 5870.39 58.21 303.54 94.35 3788.21 4026.77 2235.89 -3349.37 4027.09 303.73 2.72 MWD IFR MSA 64 5964.41 57.48 303.47 94.02 3838.25 4106.36 2279.83 -3415.74 4106.69 303.72 0.78 MWD _ IFR _ MSA 65 6058.60 57.36 303.95 94.19 3888.97 4185.72 2323.87 -3481.76 4186.05 303.72 0.45 MWD +IFR _ MSA 66 6153.14 57.07 304.93 94.54 3940.16 4265.18 2368.82 -3547.31 4265.53 303.73 0.92 MWD IFR MSA 67 6247.79 57.51 303.10 94.65 3991.31 4344.80 2413.37 -3613.32 4345.16 303.74 1.69 MWD _ IFR _ MSA 68 6342.43 56.80 305.10 94.64 4042.64 4424.29 2457.94 -3679.16 4424.66 303.75 1.93 MWD IFR MSA 69 6437.42 56.71 302.83 94.99 4094.72 4503.71 2502.32 -3745.04 4504.10 303.75 2.00 MWD IFR MSA 70 6531.69 58.55 303.21 94.27 4145.19 4583.33 2545.70 -3811.79 4583.71 303.74 1.98 MWD IFR MSA 71 6625.21 58.31 304.36 93.52 4194.15 4663.00 2590.01 -3878.02 4663.39 303.74 1.08 MWD IFR MSA 72 6719.32 57.82 304.41 94.11 4243.93 4742.84 2635.11 -3943.93 4743.25 303.75 0.52 MWD IFR MSA 73 6813.89 57.83 302.44 94.57 4294.30 4822.88 2679.20 -4010.73 4823.29 303.74 1.76 MWD~ IFR _ MSA 74 6908.81 57.63 301.69 94.92 4344.98 4903.13 2721.81 -4078.74 4903.51 303.72 0.70 MWD IFR MSA 75 7002.96 58.45 301.58 94.15 4394.81 4982.98 2763.71 -4146.75 4983.34 303.68 0.88 _ MWD IFR _ MSA 76 7097.84 57.96 302.08 94.88 4444.80 5063.61 2806.24 -4215.27 5063.94 303.65 0.68 MWD IFR MSA 77 7190.96 57.40 301.61 93.12 4494.59 5142.28 2$47.76 -4282.11 5142.59 303.63 0.74 MWD IFR MSA 78 7286.33 58.11 301.42 95.37 4545.47 5222.92 2889.92 -4350.88 5223.20 303.59 0.76 _ MWD IFR _ MSA 79 7380.80 59.37 300.55 94.47 4594.49 5303.62 2931.49 -4420.11 5303.87 303.55 1.55 MWD IFR MSA 80 7477.05 58.51 299.86 96.25 4644.15 5385.97 2972.97 -4491.36 5386.18 303.50 1.08 MWDl IFR _ MSA 81 7572.63 57.59 302.12 95.58 4694.74 5467.01 3014.72 -4560.88 5467.19 303.46 2.23 MWD IFR MSA 82 7668.61 57.77 303.61 95.98 4746.05 5548.12 3058.73 -4629.01 5548.29 303.46 1.33 MWD IFR MSA a 83 7763.95 57.01 303.04 95.34 4797.43 5628.43 3102.85 -4696.11 5628.60 303.45 0.94 _ MWD IFR _ MSA 84 7860.06 58.00 302.37 96.11 4849.07 5709.49 3146.65 -4764.32 5709.66 303.44 1.19 _ MWD IFR _ MSA 85 7955.40 58.89 303.43 95.34 4898.96 5790.73. 3190.78 -4832.53 5790.89 303.44 1.33 _ MWD IFR _ MSA 86 8051.04 59.26 304.23 95.64. 4948.11 5872.76 3236.46 -4900.68 5872.93 303.44 0.82 MWD IFR MSA 87 8146.30 58.69 304.56 95.26 4997.21 5954.37 3282.57 -4968.04 5954.56 303.45 0.67 _ MWD IFR _ MSA 88 8241.91 57.94 304.11 95.61 5047.43 6035.70 3328.46 -5035.23 6035.90 303.47 0.88 _ MWD IFR _ MSA 89 8337.66 57.57 305.65 95.75 5098.52 6116.64 3374.77 -5101.66 6116.86 303.48 1.41 _ MWD IFR _ MSA 90 8433.24 55.86 310.14 95.58 5150.99 6196.22 3423.80 -5164.70 6196.49 303.54 4.31 _ MWD IFR _ MSA [(0)2006 IDEAL ID10 2C O1) SChLUMBERGER Survey Report 1-Jan-2006 08:00:31 Page 5 of 8 Seq Measured Incl Azimuth ------. Course -------- TVD -------- Vertical ==-==p= Dis 1 =======p= Dis 1 ________ Total _______ At _____ DLS _____ ______ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8528.97 53.74 313.66 95 73 5206 18 6273.48 3476.00 -5222 93 6273 88 303 64 3.73 MWD IFR MSA 92 8625.04 51.53 317.20 96.07 5264.49 6348.03 3530.35 -5276.52 6348.62 303.79 3.72 _ MWD IFR _ MSA 93 8721.02 49.12 320.70 95.98 5325.77 6419.04 3586.02 -5325.04 6419.94 303.96 3.77 _ MWD IFR _ MSA 94 8816.12 49.10 322.96 95.10 5388.03 6487.08 3642.53 -5369.47 6488.39 304.15 1.80 _ MWD IFR _ MSA 95 8912.24 49.61 325.79 96.12 5450.65 6554.98 3701.80 -5411.94 6556.86 304.37 2.30 MWD IFR MSA 96 9004.93 50.48 328.08 92.69 5510.18 6619.91 3761.35 -5450.69 6622.52 304.61 2.11 MWD IFR MSA 97 9099.44 51.44 330.68 94.51 5569.71 6685.65 3824.51 -5488.06 6689.22 304.87 2.37 _ MWD IFR _ MSA 98 9192.83 51.06 332.09 93.39 5628.17 6749.73 3888.45 -5522.94 6754.47 305.15 1.25 MWD IFR • MSA 99 9286.02 50.45 335.43 '93.19 5687.13 6811.74 3953.16 -5554.85 6817.91 305.44 2.85 _ MWD IFR _ MSA 100 9379.83 50.27 339.07 93.81 5746.99 6871.43 4019.76 -5582.78 6879.38 305.75 2.99 MWD IFR MSA 101 9472.68 49.85 343.26 92.85 5806.61 6927.39 4087.10 -5605.76 6937.51 306.10 3.49 MWD IFR MSA 102 9566.80 50.44 347.05 94.12 5866.94 6980.92 4156.92 -5624.26 6993.73 306.47 3.15 MWD IFR MSA 103 9659.38 52.21 350.92 92.58 5924.81 7031.11 4227.85 -5638.04 7047.14 306.87 3.77 MWD IFR MSA 104 9752.24 54.73 353.99 92.86 5980.09 7079.58 4301.80 -5647.81 7099.53 307.30 3.80 MWD IFR MSA 105 9777.11 55.81 354.88 24.87 5994.26 7092.32 4322.15 -5649.79 7113.44 307.42 5.24 _ MWD IFR _ MSA 106 9808.88 56.28 357.05 31.77 6012.00 7108.19 4348.43 -5651.64 7130.91 307.58 5.86 MWD IFR MSA 107 9839.67 56.45 359.28 30.79 6029.06 7122.83 4374.05 -5652.46 7147.21 307.73 6.06 _ MWD IFR _ MSA 108 9870.46 57.11 1.10 30.79 6045.93 7136.79 4399.80 -5652.38 7162.94 307.90 5.39 _ MWD IFR _ MSA 109 9901.63 57.16 3.01 31.17 6062.84 7150.25 4425.97 -5651.44 7178.30 308.07 5.15. _ MV7D IFR _ MSA 110 9932.39 57.06 5.46 30.76 6079.55 7162.68 4451.72 -5649.53 7192.71 308.24 6.70 MWD IFR MSA 111 9963.71 57.38 6.54 31.32 6096.51 7174.63 4477.91 -5646.78 7206.79 308.41 3.07 MWD IFR MSA 112 9994.69 57.98 9.74 30.98 6113.07 7185.63 4503.82 -5643.07 7220.02 308.59 8.94 MWD IFR MSA 113 10025.45 57.31 13.11 30.76 6129.54 7195.19 4529.29 -5637.93 7231.92 308.78 9.51 _ MWD IFR _ MSA 114 10056.60 57.88 16.32 31.15 6146.23 7203.44 4554.72 -5631.25 7242.68 308.97 8.89 MWD IFR MSA 115 10087.66 58.36 18.25 31.06 6162.64 7210.58 4579.90 -5623.41 7252.46 309.16 5.50 _ MWD IFR _ MSA 116 10117.23 59.35 21.70 29.57 6177..94 7216.28 4603.68 -5614.76 7260.81 309.35 10.53 MWD IFR MSA .117 10148.85 59.85 25.84 31.62 6193.94 7220.65 4628.63 -5603.77 7268.18 309.56 11.40 _ MWD IFR _ MSA 118 10179.08 60.48 27.59 30.23 6208.98 7223.52 4652.05 -5591.98 7274.05 309.76 5.44 MWD IFR MSA 119 10209.76 60.09 30.31 30.68 6224.19 7225.40 4675.36 -5579.09 7279.09 309.96 7.80 MWD IFR MSA 120 10241.39 59.08 31.66 31.63 6240.20 7226.36 4698.75 -5565.05 7283.40 310.18 4.87 MWD IFR MSA [(c)-2006 IDEAL ID10 2C Ol] SCI-iLUMBERGER Survey Report 1-Jan-2006 08:00:31 Page 6 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At^ DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (f t) (ft) (deg) 100f) type (deg) 121 10271.75 58.76 33.71 30.36 6255.88 7226.50 4720.63 -5551.01 7286 84 310 38 5.88 MWD IFR MSA 122 10302.65 59.07 37.53 30.90 6271.84 7225.29 4742.13 -5535.60 7289.08 310.59 10.63 MWD IFR MSA 123 10334.13 59.45 41.59 31.48 6287.93 7222.20 4762.98 -5518.37 7289.61 310.80 11.15 MWD IFR MSA 124 10365.50 59.41 43.58 31.37 6303.89 7217.70 4782.87 -5500.09 7288.82 311.01 5.46 MWD IFR MSA 125 10397.04 60.28 43.68 31.54 6319.73 7212.67 4802.61 -5481.27 7287.62 311.22 2.77 _ MWD IFR _ MSA 126 10490.10 63.68 46.08 93.06 6363.45 7195.74 4860.79 -5423.30 7282.82 311.87 4.30 MWD IFR MSA 127 10583.98 68.50 49.77 93.88 6401.50 7173.60 4918.23 -5359.60 7274.22 312.54 6.27 MWD IFR MSA 128 10677.68 74.13 50.97 93.70 6431.51 7147.09 4974.81 -5291.25 7262.65 313.23 6.13 MWD IFR MSA 129 10723.00 73.67 50.95 45.32 6444.07 7133.67 5002.23 -5257.43 7256.92 313.58 1.02 _ Top _ of Window 130 10736.00 75.46 52.05 13.00 6447.53 7129.69 5010.03 -5247.63 7255.21 313.67 16.00 Bottom of Window 131 10779.46 77.07 54.18 43.46 6457.85 7115.17 5035.37 -5213.86 7248.40 314.00 6.03 Inc Only 132 10811.02 79.86 55.71 31.56 6464.16 7103.61 5053.12 -5188.55 7242.59 314.24 10.04 Inc Only 133 10841.05 80.39 57.15 30.03 6469.31 7091.85 5069.48 -5163.90 7236.40 314.47 5.04 MWD IFR MSA 134 10874.71 80.57 58.83 33.66 6474.88 7077.82 5087.08 -5135.75 7228.72 314.73 4.95 MWD IFR MSA 135 10905.17 80.46 58.36 30.46 6479.90 7064.85 5102.73 -5110.11 7221.57 314.96 1.56 MWD IFR MSA 136 10936.16 80.54 58.31 30.99 6485.02 7051.77 5118.78 -5084.10 7214.56 315.19 0.30 MWD IFR MSA 137 10966.25 80.85 59.18 30.09 6489.88 7038.87 5134.19 -5058.71 7207.66 315.42 3.03 MWD IFR MSA 138 10998.70 79.91 56.72 32.45 6495.30 7025.37 5151.16 -5031.60 7200.79 315.67 8.02 MWD IFR ~MSA 139 11029.65 80.36 57.71 30.95 6500.61 7012.87 5167.67 -5005.96 7194.75 315.91 3.47 MWD IFR MSA 140 11061.28 80.46 57.68 31.63 6505.88 6999.84 5184.34 -4979.60 7188.45 316.15 0.33 MWD IFR MSA 141 11092.37 80.70 57.58 31.09 6510.96 6987.05 5200.76 -4953.69 7182.41 316.39 0.83 MWD IFR MSA 142 11124.51 80.73 58.41 32.14 6516.15 6973.65 5217.57 -4926.80 7176.10 316.64 2.55 _ MWD IFR~ MSA 143 11155.51 82.98 57.97 31.00 6520.54 6960.59 5233.75 -4900.72 7170.02 316.88 7.39 MWD IFRy MSA 144 11186.30 86.52 57.28 30.79 6523.36 6947.82 5250.16 -4874.83 7164.37 317.12 11.71 _ MWD _ IFR MSA 145 11216.34 88.40 57.84 30.04 6524.69 6935.35 5266.26 -4849.50 7158.99 317.36 6.53 _ MWD _ IFR MSA 146 11247.85 91.57 58.24 31.51 6524.70 6922.01 5282.93 -4822.77 7153.22 317.61 10.14 MWD IFR MSA 147 11279.65 92.29 57.07 31.80 6523.63 6908.75 5299.94 -4795.92 7147.74 317.86 4 32 MWD IFR~ MSA 148 11310.26 92.32 57.31 30.61 6522.40 6896.22 5316.51 -4770.22 7142.85 318.10 . 0.79 MWD IFR MSA 149 11340.59 92.47 53.87 30.33 6521.13 6884.58 5333.63 -4745.22 7138.96 318.34 11 34 _ MWD _ IFR MSA 150 11372.73 92.09 52.72 32.14 6519.85 6873.44 5352.83 -4719.47 7136.26 318.60 . 3.77 MWD IFR MSA [(c)2006 IDEAL ID10 2C O1] SCHLUMBERGER Survey Report 1-Jan-2006 08:00:31 Page 7 of 8 Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 151 11404.31 92.12 51 13 152 11434.56 92.16 49.03 153 11466.08 91.62 49.18 154 11496.52 91.77 49.81 155 11527.50 91.28 49.32 156 11558.42 91.29 48.77 157 11589.50 91.70 50.40 158 11620.06 92,29 51.80 159 11651.17 93.19 55.27 160 11681.34 93.09 56.64 161 11712.74 93.11 56.64 162 11743.83 93.13 56.98 163 11775.22 92.94 56.03 164 11806.92 92.82 56.54 165 11838.24 93.88 55.68 166 11869.46 94.06 54.53 167 11900.21 93.78 54.41 168 11930.95 94.04 52.78 169 11961.55 94.12 51.17 170 11993.27 93.66 51.08 171 12024.20 93.46 51.43 172 12056.17 93.29 52.03 173 12086.82 93.28 48.69 174 12118.88 90.95 50.51 175 12148.59 88.79 49.70 176 12180.24 88.83 49.79 177 12210.94 89.03 49.46 178 12241.96 90.02 51.11 179 12272.84 91.25 51.82 180 12303.87 91.21 52.60 Course length (ft) 31.58 30.25 31.52 30.44 30.98 30.92 31.08 30..56 31.11 30.17 31.40 31.09 31.39 31.70 31.32 31.22 30.75 30.74 30.60 31.72 30.93 31.97 30.65 32.06 29.71 31.65 30.70 31.02 30.88 31.03 TVD depth (ft) 6518.69 6517.56 6516.52 6515.62 6514.79 6514.10 6513.29 6512.23 6510.74 6509.09 6507.39 6505.70 65-04.03 6502.44 6500.61 6498.45 6496.35 6494.25 6492.07 6489.92 6486.00 6486.12 6484.36 6483.18 6483.25 6483.90 6484.48 6484.73 6484.39 6483.73 Vertical Displ Displ Total section +N/S- +E/W- displ (ft) (ft) (ft) (ft) 6863.21 5372.29 -4694.63 7134 50 6854.33 5391.69 -4671.45 7133.91 6845.59 5412.31 -4647.64 7133.98 6836.95 5432.07 -4624.50 7133.96 6828.12 5452.16 -4600.93 7134.04 6819.58 5472.42 -4577.58 7134.54 6810.71 5492.56 -4553.93 7134.88 6801.22 5511.74 -4530.16 7134.54 6790.32 5530.21 -4505.18 7133.01 6778.57 5547.07 -4480.22 7130.38 6766.00 5564.31 -4454.03 7127.41 6753.47 5581.31 -4428.05 7124.51 6740.97 5598.61 -4401.91 7121.88 6728.45 5616.18 -4375.57 7119.49 6716.18 5633.61 -4349.62 7117.36 6704.46 5651.43 -4324.08 7115.92 6693.23 5669.26 -4299.11 7114.97 6682.45 5687.46 -4274.43 7114.63 6672.52 5706.26 -4250.38 7115.28 6662.68 5726.12 -4225.75 7116.56 6653.01 5745.44 -4201.67 7117.87 6642.76 5765.21 -4176.61 7119.11 6633.63 5784.73 -4153.05 7121.16 6624.48 5805.49 -4128.66 7123.87 6615.74 5824.54 -4105.86 7126.25 6606.62 5844.99 -4081.72 7129.12 6597.84 5864.88 -4058.33 7132.10 6588.63 5884.69 -4034.47 7134.89 6578.85 5903.93 -4010.32 7137.16 6568.64 5922.94 -3985.80 7139.18 At Azim (deg) 318.85 319.09 319.35 319.59 319.84 320.09 320.34 320.58 320.83 321.07 321.32 321.57 321.82 322.08 322.33 322.58 322.83 323.07 323.32 323.57 323.82 324.08 324.32 324.58 324.82 325.07 325.32 325.57 325.81 326.06 DLS Srvy Tool (deg/ tool Corr 100f) type (deg) 5.03 MWD IFR MSA 6.94 MWD IFR MSA 1.78 MWD IFR MSA 2.13 MWD IFR MSA 2.24 MWD IFR MSA 1.78 MWD_IFR_MSA 5.41 MWD_IFR_MSA 4.97 MWD IFR MSA 11.51 MWD IFR MSA 4.55 MWD IFR MSA 0.06 MWD_IFR_MSA 1.09 MWD IFR MSA 3.08 MWD IFR MSA 1.65 MWD IFR MSA 4.36 MWD IFR MSA 3.72 MWD_IFR_MSA 0.99 MWD IFR MSA 5.36 MWD IFR MSA 5.25 MWD IFR MSA 1.48 MWD IFR MSA 1.30 MWD IFR MSA • 1.95 MWD IFR MSA 10.88 MWD_IFR_MSA 9.22 MWD IFR MSA 7.76 MWD IFR MSA 0.31 MWD_IFR_MSA 1.26 MWD IFR MSA 6.20 MWD IFR MSA 4.60 MWD IFR MSA 2.52 MWD IFR MSA [(c)2006 IDEAL ID10 2C O1] SCH•LLJMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 181 12335.69 92.13 50 37 182 12360.38 92.38 50.13 Projection to Bit: 183 12405.00 92.38 50.13 ((c)2006 IDEAL ID10 2C OlJ Course TVD length depth (f t) (f t) 31.82 6482.80 24.69 6481.83 44.62 6479.97 1-Jan-2006 08:00:31 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 6558.55 5942.75 -3960.92 6551.24 5958.52 -3941.95 6538.11 5987.10 -3907.73 Pa Total displ (ft) 7141.79 7144.43 7149.53 ~e 8 of At Azim (deg) 326.32 326.51 326.87 8 DLS Srvy Tool (deg/ tool Corr 100f) type (deg) 7.58 MWD IFR MSA 1.40 MWD IFR MSA 0.00 Projection • c~ ..-~ 1 .~ ~. SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Borealis Well ...................... L-123PB1 API number ................ 50-029-23290-70 Engineer .................. St. Amour Rig :...................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS............ Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 47.50 ft KB above permanent.......: N/A (Top Drive) DF above permanent.......: 76.00 ft ----- Vertical section origin---------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)......... 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).......... 0.00 ft Departure (+E/W-)......... 0.00 ft Azimuth from Vsect Origin to target: 303.00 degrees 25-Dec-2005 13:49:27 Page 1 of 6 Spud date ................. 12-Dec-05 Last survey date.........: 25-Dec-05 Total accepted surveys...: 136 MD of first survey.......: 0.00 ft MD of last survey........: 11406.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............. 13-Dec-2005 Magnetic field strength..: 1151.56 HCNT Magnetic dec (+E/W-).....: 24.39 degrees Magnetic dip .............. 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............. Tolerance of G............ Tolerance of H............ Tolerance of Dip.......... Criteria --------- 1002.68 meal 1151.56 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.38 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.38 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction SCHLUMBERGER Survey Report 25-Dec-2005 13:49:27 Page 2 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) {ft) (deg} 100f} type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.21 33.43 100.00 100.00 -0.00 0.15 0.10 0.18 33.43 0.21 BP _GYD CT DMS 3 200.00 1.44 343.86 100.00 199.99 0.95 1.51 -0.15 1.52 354.44 1.31 BP _GYD CT DMS 4 300.00 3.27 336.22 100.00 299.90 4.28 5.33 -1.65 5.58 342.83 1.85 BP GYD CT DMS 5 400.00 4.00 333.81 100.00 399.70 9.67 11.07 -4.34 11.89 338.61 0.75 BP GYD CT DMS 6 500.00 5.30 327.67 100.00 499.37 16.86 18.10 -8.35 19.93 335.25 1.39 BP _GYD CT DMS 7 600.00 8.14 329.47 100.00 598.67 27.40 28.11 -14.41 31.59 332.85 2.85 BP _GYD CT DMS 8 700.00 11.72 331.44 100.00 697.16 42.67 43.13 -22.87 48.82 332.07 3.60 BP _GYD CT DMS 9 800.00 15.96 331.48 100.00 794.23 63.69 64.14 -34.29 72.73 331.87 4.24 BP _GYD CT DMS 10 900.00 19.42 329.42 100.00 889.49 90.67 90.54 -49.32 103.10 331.42 3.52 BP GYD CT DMS 11 1000.00 23.24 326.20 100.00 982.62 123.71 121.26 -68.76 139.40 330.44 3.99 BP _GYD CT DMS 12 1100.00 26.45 321.33 100.00 1073.37 163.00 155.05 -93.66 181.15 328.87 3.80 BP _GYD CT DMS 13 1200.00 29.20 319.69 100.00 1161.80 207.51 191.05 -123.36 227.42 327.15 2.85 BP _GYD CT DMS 14 1300.00 32.51 315.10 100.00 1247.64 257.18 228.70 -158.13 278.04 325.34 4.06 BP _GYD CT DMS 15 1400.00 35.20 312.65 100.00 1330.69 311.88 267.27 -198.30 332.80 323.43 3.02 BP GYD CT DMS 16 1500.00 39.54 306.30 100.00 1410.17 372.12 305.68 -245.19 391.87 321.27 5.80 BP _GYD CT DMS 17 1597.13 44.98 303.55 97.13 1482.04 437.37 342.98 -298.77 454.86 318.94 5.91 BP _MWD+IFR+MS 18 1688.78 48.99 303.78 91.65 1544.55 504.36 380.13 -354.53 519.79 317.00 4.38 BP _MWD+IFR+MS 19 1783.18 51.21 305.46 94.40 1605.10 576.74 421.28 -414.11 590.73 315.49 2.72 BP _MWD+IFR+MS 20 1875.79 50.25 304.92 92.61 1663.72 648.39 462.60 -472.70 661.39 314.38 1.13 BP MWD+IFR+MS 21 1969.31 53.27 304.50 93.52 1721.59 721.80 504.42 -533.07 733.90 313.42 3.25 BP _MWD+IFR+MS 22 2063.03 56.07 305.32 93.72 1775.79 798.21 548.18 -595.76 809.59 312.62 3.07 BP _MWD+IFR+MS 23 2155.77 56.70 305.45 92.74 1827.13 875.37 592.90 -658.73 886.26 311.99 0.69 BP _MWD+IFR+MS 24 2249.91 58.49 303.71 94.14 1877.58 954.81 637.99 -724.17 965.12 311.38 2.46 BP _MWD+IFR+MS 25 2343.48 57.75 303.97 93.57 1927.00 1034.26 682.24 -790.16 1043.94 310.81 0.83 BP MWD+IFR+MS 26 2436.52 58.29 303.16 93.04 1976.27 1113.17 725.87 -855.92 1122.27 310.30 0.94 BP _MWD+IFR+MS 27 2530.29 57.58 302.96 93.77 2026.05 1192.64 769.22 -922.52 1201.14 309.82 0.78 BP _MWD+IFR+MS 28 2623.98 58.96 302.98 93.69 2075.33 1272.32 812.58 -989.37 1280.29 309.40 1.47 BP _MWD+IFR+MS 29 2716.74 57.72 303.15 92.76 2124.01 1351.28 855.66 -1055.54 1358.79 309.03 1.35 BP _MWD+IFR+MS 30 2809.87 58.61 303.15 93.13 2173.14 1430.40 898.93 -1121.78 1437.52 308.71 0.96 BP MWD+IFR+MS •~ SCHLUMBERGER Survey Report 25-Dec-2005 13:49:27 Page 3 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth Section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ --- 31 -------- 2904.01 ------ 57.90 ------- 302.72 ------ 94.14 -------- 2222.67 -------- 1510.45 ------- 942.45 --------- -1188.97 ------- 1517.19 -------- 308.40 ----- 0.85 - BP ---- ------ _MWD+IFR+MS 32 2996.72 57.01 303.12 92.71 2272.54 1588.60 984.92 -1254.58 1595.00 308.13 1.03 BP _MWD+IFR+MS 33 3089.02 58.53 303.97 92.30 2321.76 1666.67 1028.07 -1319.64 1672.84 307.92 1.82 BP _MWD+IFR+MS 34 3182.17 57.65 303.86 93.15 2371.00 1745.74 1072.19 -1385.26 1751.73 307.74 0.95 BP _MWD+IFR+MS 35 3276.40 58.69 302.71 94.23 2420.70 1825.79 1116.12 -1452.19 1831.55 307.55 1.51 BP MWD+IFR+MS 36 3368.06 58.08 303.25 91.66 2468.75 1903.85 1158.61 -1517.67 1909.37 307.36 0.83 BP _MWD+IFR+MS 37 3461.68 57.68 303.23 93.62 2518.53 1983.14 1202.07 -1583.98 1988.46 307.19 0.43 BP _MWD+IFR+MS 38 3555.02 57.04 303.05 93.34 2568.87 2061.74 1245.04 -1649.80 2066.87 307.04 0.70 BP _MWD+IFR+MS 39 3589.02 56.93 303.03 34.00 2587.39 2090.25 1260.59 -1673.70 2095.31 306.99 0.33 BP _MWD+IFR+MS 40 3692.64 55.11 302.95 103.62 2645.31 2176.17 1307.37 -1745.76 2181.03 306.83 1.76 BP MWD+IFR+MS 41 3785.75 56.78 300.61 93.11 2697.45 2253.28 1347.98 -1811.34 2257.87 306.66 2.75 BP _MWD+IFR+MS 42 3880.02 60.18 298.52 94.27 2746.73 2333.48 1387.60 -1881.23 2337.62 306.41 4.07 BP _MWD+IFR+MS 43 3971.58 59.79 298.81 91.56 2792.53 2412.53 1425.63 -1950.80 2416.20 306.16 0.51 BP _MWD+IFR+MS 44 4066.16 59.51 298.94 94.58 2840.32 2493.94 1465.04 -2022.27 2497.18 305.92 0.32 BP _MWD+IFR+MS 45 4160.53 58.87 298.73 94.37 2888.66 2574.77 1504.13 -2093.27 2577.63 305.7Q 0.70 BP MWD+IFR+MS 46 4253.99 58.18 298.90 93.46 2937.45 2654.27 1542.55 -2163.11 2656.78 305.49 0.75 BP _MWD+IFR+MS 47 4347.61 57.71 299.10 93.62 2987.14 2733.42 1581.02 -2232.51 2735.64 305.31 0.53 BP _MWD+IFR+MS 48 4444.71 59.10 298.92 97.10 3038.01 2815.93 1621.12 -2304.84 2817.86 305.12 1.44 BP _MWD+IFR+MS 49 4539.54 58.10 300.02 94.83 3087.42 2896.71 1660.94 -2375.31 2898.41 304.96 1.45 BP _MWD+IFR+MS 50 4634.14 57.51 301.12 94.60 3137.82 2976.69 1701.65 -2444.23 2978.24 304.85 1.16 BP MWD+IFR+MS 51 4729.50 58.85 299.82 95.36 3188.10 3057.64 1742.73 -2514.07 3059.03 304.73 1.82 BP _MWD+IFR+MS 52 4824.60 59.19 300.70 95.10 3237.05 3139.08 1783.82 -2584.49 3140.32 304.61 0.87 BP _MWD+IFR+MS 53 4919.14 58.62 300.31 94.54 3285.88 3219.95 1824.91 -2654.24 3221.07 304.51 0.70 BP _MWD+IFR+MS 54 5014.26 58.21 300.78 95.12 3335.70 3300.91 1866.09 -2724.03 3301.91 304.41 0.60 BP _MWD+IFR+MS 55 5109.01 57.69 300.73 94.75 3385.98 3381.16 1907.16 -2793.04 3382.06 304.33 0.55 BP MWD+IFR+MS 56 5203.21 57.21 300.86 94.20 3436.66 3460.50 1947.81 -2861.25 3461.32 304.25 0.52 BP _MWD+IFR+MS 57 5303.90 56.48 300.95 100.69 3491.73 3544.74 1991.11 -2933.58 3545.47 304.17 0.73 BP _MWD+IFR+MS 58 5396.75 56.91 301.20 92.85 3542.71 3622.30 2031.16 -3000.04 3622.96 304.10 0.51 BP MWD+IFR+MS 59 5491.40 58.03 301.10 94.65 3593.61 3702.05 2072.44 -3068.33 3702.66 304.04 1.19 BP _MWD+IFR+MS 60 5586.17 59.43 299.19 94.77 3642.81 3782.95 2113.11 -3138.38 3783.47 303.95 2.27 BP MWD+IFR+MS • SCHLUMBERGER Survey Report 25-Dec-2005 13:49:27 Page 4 of 6 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ --- 61 -------- 5680.66 ------ 60.21 ------- 298.69 ------ 94.49 -------- 3690.31 -------- 3864.42 ------- 2152.63 --------- -3209.86 ------- 3864.85 -------- 303.85 ----- 0.94 - BP ---- ------ _MWD+IFR+MS 62 5776.04 58.66 300.58 95.38 3738.81 3946.40 2193.23 -3281.24 3946.75 303.76 2.36 BP MWD+IFR+MS 63 5870.39 58.21 303.54 94.35 3788.21 4026.77 2235.89 -3349.37 4027.09 303.73 2.72 BP MWD+IFR+MS 64 5964.41 57.48 303.47 94.02 3838.25 4106.36 2279.83 -3415.74 4106.69 303.72 0.78 BP _MWD+IFR+MS 65 6058.60 57.36 303.95 94.19 3888.97 4185.72 2323.87 -3481.76 4186.05 303.72 0.45 BP MWD+IFR+MS 66 6153.14 57.07 304.93 94.54 3940.16 4265.18 2368.82 -3547.31 4265.53 303.73 0.92 BP MWD+IFR+MS 67 6247.79 57.51 303.10 94.65 3991.31 4344.80 2413.37 -3613.32 4345.16 303.74 1.69 BP _MWD+IFR+MS 68 6342.43 56.80 305.10 94.64 4042.64 4424.29 2457.94 -3679.16 4424.66 303.75 1.93 BP _MWD+IFR+MS 69 6437.42 56.71 302.83 94.99 4094.72 4503.71 2502.32 -3745.04 4504.10 303.75 2.00 BP MWD+IFR+MS 70 6531.69 58.55 303.21 94.27 4145.19 4583.33 2545.70 -3811.79 4583.71 303.74 1.98 BP MWD+IFR+MS 71 6625.21 58.31 304.36 93.52 4194.15 4663.00 2590.01 -3878.02 4663.39 303.74 1.08 BP _MWD+IFR+MS 72 6719.32 57.82 304.41 94.11 4243.93 4742.84 2635.11 -3943.93 4743.25 303.75 0.52 BP _MWD+IFR+MS 73 6813.89 57.83 302.44 94.57 4294.30 4822.88 2679.20 -4010.73 4823.29 303.74 1.76 BP _MWD+IFR+MS 74 6908.81 57.63 301.69 94.92 4344.98 4903.13 2721.81 -4078.74 4903.51 303.72 0.70 BP _MWD+IFR+MS 75 7002.96 58.45 301.58 94.15 4394.81 4982.98 2763.71 -4146.75 4983.34 303.68 0.88 BP MWD+IFR+MS 76 7097.84 57.96 302.08 94.88 4444.80 5063.61 2806.24 -4215.27 5063.94 303.65 0.68 BP _MWD+IFR+MS 77 7190.96 57.40 301.61 93.12 4494.59 5142.28 2847.76 -4282.11 5142.59 303.63 0.74 BP _MWD+IFR+MS 78 7286.33 58.11 301.42 95.37 4545.47 5222.92 2889.92 -4350.88 5223.20 303.59 0.76 BP _MWD+IFR+MS 79 7380.80 59.37 300.55 94.47 4594.49 5303.62 2931.49 -4420.11 5303.87 303.55 1.55 BP _MWD+IFR+MS 80 7477.05 58.51 299.86 96.25 4644.15 5385.97 2972.97 -4491.36 5386.18 303.50 1.08 BP MWD+IFR+MS 81 7572.63 57.59 302.12 95.58 4694.74 5467.01 3014.72 -4560.88 5467.19 303.46 2.23 BP _MWD+IFR+MS 82 7668.61 57.77 303.61 95.98 4746.05 5548.12 3058.73 -4629.01 5548.29 303.46 1.33 BP _MWD+IFR+MS 83 7763.95 57.01 303.04 95.34 4797.43 5628.43 3102.85 -4696.11 5628.60 303.45 0.94 BP _MWD+IFR+MS 84 7860.06 58.00 302.37 96.11 4849.07 5709.49 3146.65 -4764.32 5709.66 303.44 1.19 BP _MWD+IFR+MS 85 7955.40 58.89 303.43 95.34 4898.96 5790.73 3190.78 -4832.53 5790.89 303.44 1.33 BP MWD+IFR+MS 86 8051.04 59.26 304.23 95.64 4948.11 5872.76 3236.46 -4900.68 5$72.93 303.44 0.82 BP _MWD+IFR+MS 87 8146.30 58.69 304.56 95.26 4997.21 5954.37 3282.57 -4968.04 5954.56 303.45 0.67 BP _MWD+IFR+MS 88 8241.91 57.94 304.11 95.61 5047.43 6035.70 3328.46 -5035.23 6035.90 303.47 0.88 BP _MWD+IFR+MS 89 8337.66 57.57 305.65 95.75 5098.52 6116.64 3374.77 -5101.66 6116.86 303.48 1.41 BP _MWD+IFR+MS 90 8433.24 55.86 310.14 95.58 5150.99 6196.22 3423.$0 -5164.70 6196.49 303.54 4.31 BP MWD+IFR+MS ~I SCHLUMBERGER Survey Report 25-Dec-2005 13:49:27 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft} (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8528.97 53.74 313.66 95.73 5206.18 6273.48 3476.00 -5222.93 6273.88 303.64 3.73 BP _MWD+IFR+MS 92 8625.04 51.53 317.20 96.07 5264.49 6348.03 3530.35 -5276.52 6348.62 303.79 3.72 BP _MWD+IFR+MS 93 8721.02. 49.12 320.70 95.98 5325.77 6419.04 3586.02 -5325.04 6419.94 303.96 3.77 BP _MWD+IFR+MS 94 8816.12 49.10 322.96 95.10 5388.03 6487.08 3642.53 -5369.47 6488.39 304.15 1.80 BP _MWD+IFR+MS 95 8912.24 49.61 325.79 96.12 5450.65 6554.98 3701.80 -5411.94 6556.86 304.37 2.30 BP MWD+IFR+MS 96 9004.93 50.48 328.08 92.69 5510.18 6619.91 3761.35 -5450.69 6622.52 304.61 2.11 BP _MWD+IFR+MS 97 9099.44 51.44 330.68 94.51 5569.71 6685.65 3824.51 -5488.06 6689.22 304.87 2.37 BP _MWD+IFR+MS 98 9192.83 51.06 332.09 93.39 5628.17 6749.73 3888.45 -5522.94 6754.47 305.15 1.25 BP _MWD+IFR+MS 99 9286.02 50.45 335.43 93.19 5687.13 6811.74 3953.16 -5554.85 6817.91 305.44 2,85 BP _MWD+IFR+MS 100 9379.83 50.27 339.07 93.81 5746.99 6871.43 4019.76 -5582.78 6879.38 305.75 2.99 BP MWD+IFR+MS 101 9472.68 49.85 343.26 92.85 5806.61 6927.39 4087.10 -5605.76 6937.51 306.10 3.49 BP _MWD+IFR+MS 102 9566.80 50.44 347.05 94.12 5866.94 6980.92 4156.92 -5624.26 6993.73 306.47 3.15 BP _MWD+IFR+MS 103 9659.38 52.21 350.92 92.58 5924.81 7031.11 4227.85 -5638.04 7047.14 306.87 3.77 BP _MWD+IFR+MS 104 9752.24 54.73 353.99 92.86 5980.09 7079.58 4301.80 -5647.81 7099.53 307.30 3.80 BP _MWD+IFR+MS 105 9777.11 55.81 354.88 24.87 5994.26 7092.32 4322.15 -5649.79 7113.44 307.42 5.24 BP MWD+IFR+MS 106 9808.88 56.28 357.05 31.77 6012.00 7108.19 4348.43 -5651.64 7130.91 307.58 5.86 BP _MWD+IFR+MS 107 9839.67 56.45 359.28 30.79 6029.06 7122.83 4374.05 -5652.46 7147.21 307.73 6.06 BP ,MWD+IFR+MS 108 9870.46 57.11 1.10 30.79 6045.93 7136.79 4399.80 -5652.38 7162.94 307.90 5.39 BP _MWD+IFR+MS 109 9901.63 57.16 3.01 31.17 6062.84 7150.25 4425.97 -5651.44 7178.30 308.07 5.15 BP _MWD+IFR+MS 110 9932.39 57.06 5.46 30.76 6079.55 7162.68 4451.72 -5649.53 7192.71 308.24 6.70 BP MWD+IFR+MS 111 9963.71 57.38 6.54 31.32 6096.51 7174.63 4477.91 -5646.78 7206.79 308.41 3.07 BP _MWD+IFR+MS 112 9994.69 57.98 9.74 30.98 6113.07 7185.63 4503.82 -5643.07 72.20.02 308.59 8.94 BP _MWD+IFR+MS 113 10025.45 57.31 13.11 30.76 6129.54 7195.19 4529.29 -5637.93 7231.92 308.78 9.51 BP _MWD+IFR+MS 114 10056.60 57.88 16.32 31.15 6146.23 7203.44 4554.72 -5631.25 7242.68 308.97 8.89 BP _MWD+IFR+MS 115 10087.66 58.36 18.25 31.06 6162.64 7210.58 4579.90 -5623.41 7252.46 309.16 5.50 BP MWD+IFR+MS 116 10117.23 59.35 21.70 29.57 6177.94 7216.28 4603.68 -5614.76 7260.81 309.35 10.53 BP MWD+IFR+MS ` 117 10148.85 59.85 25.84 31.62 6193.94 7220.65 4628.63 -5603.77 7268.18 309.56 11.40 BP _MWD+IFR+MS 118 10179.08 60.48 27.59 30.23 6208.98 7223.52 4652.05 -5591.98 7274.05 309.76 5.44 BP MWD+IFR+MS 119 10209.76 60.09 30.31 30.68 6224.19 7225.40 4675.36 -5579.09 7279.09 309.96 7.80 BP MWD+IFR+MS 120 10241.39 59.08 31.66 31.63 6240.20 7226.36 4698.75 -5565.05 7283.40 310.18 4.87 BP MWD+IFR+MS SCHLUMBERGER Survey Report 25-Dec-2005 13:49:2.7 Page 6 of 6 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ --- 121 -------- 10271.75 ------ 58.76 ------- 33.71 ------ 30.36 -------- 6255.88 -------- 7226.50 ------- 4720.63 --------- -5551.01 ------- 7286.84 -------- 310.38 ----- 5.88 - BP ---- ------ _MWD+IFR+MS 122 10302.65 59.07 37.53 30.90 6271.84 7225.29 4742.13 -5535.60 7289.08 310.59 10.63 BP _MWD+IFR+MS 123 10334.13 59.45 41.59 31.48 6287.93 7222.20 4762.98 -5518.37 7289.61 310.80 11.15 BP _MWD+IFR+MS 124 10365.50 59.41 43.58 31.37 6303.89 7217.70 4782.87 -5500.09 7288.82 311.01 5.46 BP _MWD+IFR+MS 125 10397.04 60.28 43.68 31.54 6319.73 7212.67 4802.61 -5481.27 7287.62 311.22 2.77 BP MWD+IFR+MS 126 10490.10 63.68 46.08 93.06 6363.45 7195.74 4860.79 -5423.30 7282.82 311.87 4.30 BP _MWD+IFR+MS 127 10583.98 68.50 49.77 93.88 6401.50 7173.60 4918.23 -5359.60 7274.22 312.54 6.27 BP _MWD+IFR+MS 128 10677.68 74.13 50.97 93.70 6431.51 7147.09 4974.81 -5291.25 7262.65 313.23 6.13 BP _MWD+IFR+MS 129 10770.54 73.20 50.94 92.86 6457.62 7119.62 5030.94 -5222.05 7251.22 313.93 1.00 BP _MWD+IFR+MS 130 10865.03 72.60 51.17 94.49 6485.41 7091.63 5087.71 -5151.81 7240.57 314.64 0.68 BP MWD+IFR+MS 131 10958.74 72.46 50.69 93.71 6513.54 7064.11 5144.05 -5082.41 7231.33 315.35 0.51 BP _MWD+IFR+MS 132 11051.53 72.15 51.45 92.79 6541.74 7036.69 5199.60 -5013.64 7223.05 316.04 0.85 BP _MWD+IFR+MS 133 11145.62 71.11 50.40 94.09 6571.40 7009.21 5255.88 -4944.32 7215.99 316.75 1.53 BP _MWD+IFR+MS 134 11238.30 70.17 50.36 92.68 6602.12 6983.09 5311.64 -4876.97 7210.98 317.44 1.02 BP _MWD+IFR+MS 135 11330.28 69.28 50.79 91.98 6633.99 6957.04 5366.43 -4810.32 7206.79 318.13 i.06 BP MWD+IFR+MS 136 11406.00 69.28 50.79 75.72 6660.78 6935.40 5411.20 -4755.44 7203.84 318.69 0.00 Projected to TD [(c)2005 IDEAL ID10_2C_01] • • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: AOGCC -Librarian ` ~~~ Well No L-123 ~~ " Date Dispatched: 10-Jan-06 Installation/Rig Nabors 9ES Dispatched By: Mauricio Perdomo LWD Log Delivery Vl.i, 10-02-03 Data No Of Prints No of Floppies Surveys 2 1 ~~ ~V~V FEB 1 4 2006 IE~~ Cons. lease sign and return to: James H. Jonnson R2CeIVed By: BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@bp.com ~( • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration ~Alaska)1nc. nn L-123PB1 ~®~ ~ `t' Nabors 9ES Dispatched To Date Dispatched: Dispatched By: A06CC -Librarian 29-Dec-05 Mauricio Perdomo Data No Of Prints No of Floppies Surveys 2 1 ~~ e + ~ ~~ ~fl0~ ~~~S Received By: Please sign and return to: Drilling & Measurements LWD Division 2525 Gambell Street, Suite 400 Anchorage, Alaska 99501 nrosel~slb.com fax:907-561-8317 LWD Log Delivery V1.1,10-02-03 ~;~( ~ Re: Variance Request - L-1231 Prod Packer~op Shot MD Subject: Re: Variance Request - L-123i Prod Packer to Top Shot MD From: Wintor Hubert<wintori._aubert@admin.state.ak.us> Date: Tue, 03 Jan 2006 07:49:05 -0900 To: "Pettier, Brandon" <Brandon.Peltier@bp.com> Brandon, 1 of 2 This confirms AOGCC's approval of the attached packer depth variance request for PBU L-123i (PTD -205-194). All other permit stipulations apply.. Winton Hubert AOGCC 793-1231 Peltier, Brandon wrote: As per our phone conversation on 1/2/06, I am sending you a written variance request for L-123i regarding its tubing packer to top shot placement measured depth. The variance request below was granted verbally during our conversation. I am requesting a variance from 20 AAC 25.412 (b) which requires the tubing packer to be placed within 200 feet measured depth above the. top of the perforations. For the case of L-123i, the tubing packer Will be set at approximately 1,0480 feet measured depth and the top perforation will be at approximately 10915 feet measured depth. This places the tubing. packer approximately 435 ft measured depth above the top perforation. Brandon,Peltier BP Exploration (Alaska), Inc. Operations.DrilTing,Engineer GPB Rotary Drihling {907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon.Feltier@bp.com From: Peltier, Brandon Sent: Mon 1/2/2006 12:54 AM 'i To: canton aubert@admin.state.ak. us Cc: Tirpack, Robert''B Subject: L-123i Prod Packer to Top Shot MD i WYrtbn ~. ~I The horizontal section has been drilled to TD. The top perforation will be placed approx 400-450 feet,I~1D below the tubing packer. The rig will begin running the production liner ~ Monday 1 i 2/ u 6 . Brandon Peltier ;,34.4-0531 (Home) f 748-7838 '(Mobile) ~~ From: Peltier, Brandon Sent: Thu 12/2912005 11:35 AM To: canton aubert@admin.state.ak.us Subject: L-123i Prod Packer to Top Shot MD 1 /3/2006 7:50 AM Re: Variance Request tY1~3i Prod Packe~op Shot MD `^ v ~~ Winton We will be drilling out the horizontal section of L-1231 over the next few days. My reliminar calculations show that the MD between the tubing packer and top shot will be p Y approximately-3-19 ft. This depth may increase slightly after drilling the section. I will update you as I know more about shot placement. Brandon Peltier I BP Exploration (Alaska), Inc. ~ Operations Dr-filling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) I~ (90'7) 7.48-7838 (Mobile) i Brandon.Peltier@bp.com 2 of 2 1 /3/2006 7:50 AM ~ ' x~ ' ~~ ~ FRANK H. MURKOWSKI, GOVERNOR a 1 ALASKA OIL A1~TD GAS CO1~ItSERQATI011T CpMI-IISSIOI~T ~~' 333 W. 7"' AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Robert Tirpack FAx tso7> 27sa5a2 Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU L-1231 BP Exploration (Alaska), Inc. Permit No: 205-194 Surface Location: 2532' FSL, 3845' FEL, SEC. 34, T12N, R 11 E, UM Bottomhole Location: 3322' FSL, 2376' FEL, SEC. 28, T12N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development 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. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (PBU L-1231 PH) and API number (50-029-23290) from records, data and logs acquired for well PBU L- 123i. 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). 205-194 J Sincerely hairman DATED this~~ day of November, 2005 cc: Department of Fish 8a Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA AND GAS CONSERVATION COSSION PERMIT TO DRILL 20 AAC 25.005 WG r4- I t (2q ?.~05" ~ECE VEC~ Nov 2 2 2005 Alaska 4e1 & Gas Cona. Ctlmmissitin 1 a. Type of work ®Drill ^ Redrill ^ Re-Entry ib. Current Well Class ^ Exploratory ^ Development Oil ne ^ Stratigraphic Test ®Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L-1231 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12403 TVD 6423 12. Field /Pool(s): Prudhoe Bay Field /Borealis Pool 4a. Location of Well (Governmental Section): Surface: 2532' FSL 3845' FEL 34 T12N R11 E SEC UM 7. Property Designation: ADL 028239 , , , . , , Top of Productive Horizon: 3437' FSL, 3845' FEL, SEC. 28, T12N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud D Decembe 005 Total Depth: 3322' FSL, 2376' FEL, SEC. 28, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 7000' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583069 - 5978252 Zone- ASP4 10. KB Elevation (Height above GL):Plan 72.6 feet 15. Distance to Nearest Well Within Pool 1400' to L-124 ~ 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole Angle: 93 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.00 Downhole: 3350 Surface: 2698 18. a ng rogrem: i Specifications Setting Depth To Bottom uantrty o emertt c.f, or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 Weid 80' Surface Surface 109' 109' 60 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3633' Surface Surface 3633' 2663' 59 sx Arcticset Lite, 384 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 11023' Surface Surface 11023' 6573' 7 sx Class 'G', 254 sx 'G', 316 sx 'G' 6-1/8" 4-112" 12.6# L-80 IBT-M 1795' 10608' 6397' 12403' 6423' 23 sx Class 'G' 19. PRESENT WELL CONDITION SUMM ARY (To be compl®ted for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casin Len th Size Cement Volume MD TVD r Po n Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ® Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Brandon Peltier, 564-5912 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number. Si nature ,rte Phone 564-4166 Date ~`/ ~~ Terrie Hubble,,564-4628 Commission Use Onl Permit To Drill Number: ~O ~. API Number: 50- ~ ,Z, ,~ Z 3 Z O Permit prova Date: See cover letter for other requirements Conditions of Approval: Samp equired ^ Yes ~No Mud Log Required ^ Yes ,'~ No Hy gen Sulfide Measures ZSQYes =i No Directional Survey Required Yes ^ No Other. T~es ~' ~v p E o 0 0 'p S,! . M LT-~ c..e rvc.e.~-~ v rca~Gc~~ p ~ v~ u.r red . leer Zn , o~, C~a (t ~, a.l~a.~uu.,~e R~Prr ~-,es~ ~yu~ccw-e -~s ~,y'j''i~~l~c(. APPROVED BY A roved B THE COMMISSION Date ~ ~v Form 10-401 2004 ' 'a Submit In Duplicate i • Well Name: L-123i Well Plan Summary • T e of Well roducer or in'ector : Injector Surface Location: 2,747.71 FNL & 3,845.08 FEL, Sec. 34, T12N, R11 E ~ X = 583,069.3 Y = 5,978,252.1 L-1231 Pilot Hole BHL 3,566.83 FEL & 2,775.17 FNL, Sec 28, T12N, R11 E 7" Casin Point X = 578,018 Y = 5,983,470 Z = 6620 TVDss L-1231 Target Start: 3,436.84 FEL & 2776.54 FNL, Sec. 28, T12N, R11 E X = 578,130 Y = 5,983,450 Z = 6,355 TVDss L-123i Target End: 2,376.13 FEL & 1,957.63 FNL, Sec. 28, T12N, R11 E % X = 579,180 Y = 5,984,280 Z = 6,350 TVDss AFE Number: BRD5M4144 Ri Nabor 9ES GL: 44.1 RT: 28.5' Estimated Start Date: December 3, 2005 O eratin da s to com lete: 24.61 TD: 12,404' TVD: 6,422' Max Inc: 97° RTE: 72.6 Well Desi n: Grassroots, Ultra Slim Hole, Borealis Kuparuk Horizontal Injector Well Information General Distance to Nearest Property: Distance to Nearest Well in Pool: API Number: Well Type: Current Status: Conductor: BHP: BHT: 7000 ft to PBU Boundary 1400 ft to L-124 50-029-XXXXX New Well -Borealis Injector No Conductor Set No Conductor Set ~ 3000 psi C~ 6360' TVDss (9.1 ppg EMW) 154 degF C«~ 6360' TVDss L-123i Permit to Drill Page 1 Formation Markers and Estimated Pore Pressures Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation (TVDss) (eet) (Yes/No) (Psi) ( EMW) Base Gubik -260 +/- 30 no 117 8.7 SV6 -900 +/- 30 no 405 8.7 SVS -1545 +1- 50 no 695 8.7 Base Permafrost -1675 +/- 50 no 754 8.7 SV4 -1680 +/- 50 Gas H drates 756 8.7 SV3 -2010 +/- 50 .Gas H drates 905 8.7 SV2 -2160 +/- 50 Gas H drates 972 8.7 SV1 -2470 +/- 50 Gas H drates 1112 8.7 UG4 -2750 +/- 50 no 1238 8.7 UG4A -2775 +/- 50 Heav Oil: 2780 - 2850' SS 1249 8.7 UG3 -3070 +/- 50 no 1382 8.7 UGl -3500 +!- 50 Minor Heavy Oi13620-3850' SS 1575 8.7 SB-MA -3845 +/- 50 Heavy Oil: 4050 - 4070' SS (Mb2) 1730 8.7 SB-NA -4105 +!- 50 Minor Residual Oil 1847 8.7 SB-OA -4260 +/- 50 Yes: maim OBc 1917 8.7 SB-OBd -4465 +/- 50 Minor Residual Oil 2009 8.7 SB-OBf Base -4600 +/- 50 no 2070 8.7 Fault 1 -4610 +/- 100 n/a CM2 (Colville Shales) -4870 +/- 50 no CMl (Colville Shales K- 10) -5540 +/- 50 no Fault 2 -5940 +/- 100 n/a THRZ (faulted) -5940 +/- 100 no BHRZ (Kalubik) -6160 +/- 100 no K-1 -6220 +/- 50 no TKD -6330 +/- 50 no TKC4 -6360 +/- 50 es 3000 9.1 TKC1A -6500 +/- 50 es LCU( KUP B) -6520 +/- 50 no 3350 9.8 ~ TD -6620 +/- 50 no OWC -6655 FWL -6680 CasingiTubing Program Hole Size Csg / Tb O.D. WUFt Grade ~ Cortn / Burst si Collapse si Length Top MD /TVD Bottom MD /TVD 42" 20" 215.5# A-53 Weld GL 109' / 109' 12-'/a" 9 5/e" 40# L-80 BTC 5,750 3,090 3,633' GL 3,633' / 2,663' 8-3/a" 7" 26# L-80 BTC-M 7,240 5,410 11,023' GL 11,023' / 6,573' 6-'/e" 4-'/z" 12.60# L-80 IBT-M 8,430 7,500 1,795 10,608' / 6,397' 12,403' / 6,423' Tubin 4-'/z" 12.60# L-80 TC-II 8,430 7,500 10,458' GL 10,458' / 6,333' L-1231 Permit to Drill Page 2 • CJ Mud Pro ram: 12'/a" Surface Hole Mud Properties: Spud -Freshwater Mud Interval Densi Funnel Vis PV YP FL Chlorides PH Initial 8.5 - 9.2 250-300 20-50 50-70 NC-8.0 <500 8.5-9.0 Base Perm 9.0 - 9.5 300-250 20-45 40-55 8.0 <500 8.5-9.0 Interval TD 9.5 - 9.6 200-250 20-35 35-45 5.0-7.0 <500 8.5-9.0 8 314" Intermediate Hole Mud Properties: Freshwater Mud (LSND) Interval Density Funnel Vis PV YP FL pH Chlorides MBT Surface shoe to 9,600' 9.0 - 38-50 12-18 26-35 4-6 9.0-9.5 <600 < 20 9,600' -11,023' 38-50 12-18 24-32 3.0-4.5 9.0-9.5 <600 < 15 6'/8" Injection Hole Mud Properties: Freshwater Mud (Flo Pro SF) Interval Density PV YP LSRV HTHP FL pH 10,608'-12,403' 9.3 - 9.6 8-15 22-28 >20,000 4-6 9.0 - 9.5 Surve and Lo in Pro ram: 12-'/a" Hole Section: Surface Gyro MWD J LWD: GR O n Hole: None Cased hole: None 8-3/4" Hole Section: MWD /LWD: GR / Res /Den / Neu /PWD (Neutron Density in record mode) O en Hole: None Cased Hole: USIT 6-'/e" Hole Section: MWD /LWD: GR / Res /Den / Neu /PWD (All real time) O en Hole: None Cased Hole: None Surface and Anti-Collision Issues Surface Shut-in Wells: Nearb Wells L-02 L-122 L-112 L-211 Center to Center Distance 15.19 14.92 29.95 30.03 L-02 and L-122 will require surface shut-in and well house removal in order to move over well L-123. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: j Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautiona Comment L-02 13.93 ft 456 ft 8.11 ft Use Travelin C linder G ro L-122 12.85 ft 535 ft 3.65 ft Use Travelin C linder G ro L-112 33.24 411 24.71 Use Travelin C linder G ro L-115 46.48 336 40.69 Use Travelin C linder G ro L-124 26.47 916 9.82 Use Travelin C linder G ro L-211 31.81 216 27.7 Use Travelin C linder G ro L-123i Permit to Drill Page 3 • ~ Cement Calculations: Casing Size: 9 5/8" in 40-Ib/ft L-80 BTC -Single Stage Calculations Basis: Lead: 250% exc ver gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: a Tail: 1000' o en hole with 30% excess, plus 80' shoe track Tail TOC: 2633' MD, 1000' MD above the shoe Total Cement Volume: Spacer 80 bbls of Viscosified er wei hted to 10.0 ppg (Mud P ) Lead 442 bbls, 2,482 cuft sks 10.7 ASL G + adds uft/sk Tail 79 bbls, 441 cuft 3 ks 15.8 Class G + adds 1. 5 uft/sk Temp BHST = 58° F `'" 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: 7" 26 Ib/ft L-80 BTC-M -Two Stage Basis: Stage 1: Lead: 1,169' of open hole with 30% excess over gauge hole Lead TOC: 8,439' MD (Stage cementer C«3 8,439', Colville Shales) Tail: 1,415' of open hole with 30% excess, plus 80' shoe track Tail TOC: 9,608' MD 1000' MD / 500' TVD above tanned to Ku aruk Stage 2: Lead: 3,806' pen hole with 30% excess Lead TOC: 4,633,MD (1000' MD below surface shoe, 765` MD above Ma) Total Cement Volume: Spacer 1: 35 bbls of Viscosified cer (Mudpush II Design) Wei hted to 10.8 ppg Sta e 1 Lead 40.7 bbls, 229 cuft _.sks 12.0 G +Gasblock - cuft/sk Sta e 1 Tail: 53 bbls, 294 cuft, sks, 15.8 G +Gasblock - cuft/sk S acer 2: 35 bbls of Viscosi ie acer Mud ush II Desi n hted to 10.8 Sta e 2 Lead 133 bbls 744 cuft 1 sks 12 G +Gasblok - cuft/sk Tem BHST =154° F Note: Single stage 7" cement job may be done with same cement tops. Casino Site 4-~/~" Production Liner Basis: Tail: Based on 1,795' of open hole w/ 30% excess + 150' liner lap + 200' excess (4" DP) + 80' shoe track Cement Placement: From shoe to 10458' MD TOL Total Cement Volume: Lead N/A Tail 48 bbls / 8 ft / 23 ks of Dowell Premium "G" with Gasblok at 15.8 an 1.2'cuftls Centralizer Recommendations: 9 5/s" Casing Centralizer Placement a) Run (25) 9 5/8" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2633' MD (1,000' MD above the shoe). b) Run 2Bow-spring centralizers on either side of the TAM Port Collar (if run). c) This centralizer program is subject to change due to actual hole conditions. 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 4633' MD (665' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. 4-'/s" Liner Centralizer Placement a) Place 1 rigid straight blade centalizer per joint, floating across the entire joint up to 10688' MD (two joints from window). L-123i Permit to Drill Page 4 ~ • Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Due to anticipated surface pressures not exceeding 3,000psi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for L-123 will be 14 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 7" Casing Test: • Leak Off Test - 8-3/4" hole: • Kick Tolerance: • Planned completion fluid: Production Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 4 ~/z" Casing Test: • Integrity Test - 6-'/e" hole: • Kick Tolerance: • Planned completion fluid: Disposal 3,350 psi -Base of Kuparuk B (9.8 ppg C~3 6,520' TVDss) 2,698 psi -Based on a full column of gas C~3 0.10 psi/ft / 4,000 psi/250 psi Rams 2,500 psi/250 psi Annular 4,000 psi 11.$ ppg minimum EMW LOT 20' from 9 5/8' shoe 52~bbls with a 10.8 ppg mud Lxstimated 9.1 ppg Brine / 6.8 ppg Diesel 3,000 psi - Kuparuk C (9.1 ppg C~3 6,360' TVDss) 2,364 psi -Based on a full column of gas C~ 0.10 psi/ft ~ 4,000 psi/250 psi Rams 2,500 psi/250 psi Annular 4,000 psi 1 <~'p g minimum EMW FIT 20' from 7" shoe nfini with a 9.4 ppg mud mated 9.1 ppg Brine / 6.8 ppg Diesel • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. L-123i Permit to Drill Page 5 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Kuparuk C sands are expected to be slightly under pressured ~ 9.1 EMW. The Kuparuk B sands are expected to be pressured @ 9.8 EMW. II. Hydrates and Shallow gas A. Gas Hydrates are present at L-pad and have been encountered in wells as close as L-02 and L-1121 and throughout the 4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Occasionally hydrates are encountered below the SV1. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Offset wells L-02 and L-1121 had to have the mud treated and were able to drill to section TD. III. Lost Circulation/Breathing A. Low risk of lost circulation. However, losses were encountered at L-118 in the HRZ and Kuparuk as we11 as in the surface hole because of high ECD's. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9 5/8" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail and 12.0 Ib/gal lead cement to 765' MD above the Top Ma. a. The Kick Tolerance for the surface casing is 52.3 bbls with 10.8 ppg mud, 11.8 ppg LOT, and a 9.8 ppg pore pressure. C. The 4-'/z" production liner will be cemented with 15.8 ppg tail cement to the liner top. a. The Kick Tolerance for the intermediate casing is infinte with 9.4 ppg mud, 11.0 ppg FIT and a 9.1 ppg pore pressure. V. Stuck Pipe A. Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. B. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions VI. Hydrogen Sulfide L Pad is,~ot designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-122 <5 ppm / L-122 <5 ppm L-02A 10 ppm L-124 <5 ppm VII. Faults A. Four faults are expected to be crossed by L-123. Low risk of lost circulation expected with these faults. Details are listed below for reference: Formation Where Encounter Fault MD Intersect TVDss Intersect Est. Throw Throw Direction Uncertaint Fault #1 -Base Schrader OBf 7540 4610 60' down to southwest +/-100' Fault #2 - To HRZ 9840 5940 170' down to west +/-100' Fault #3 - Ku aruk (HAW) 11300 6370 60' down to east +/-100' Fault #4 - Ku aruk (HAW) 11800 6390 20' down to west +/-100' CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION L-123i Permit to Drill Page 6 • • L-1231 Drill and Complete Procedure Summary Pre-Rig 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. 3. Prepare neighboring wells for the rig move and simops production. Shut in L-02 & L-122 and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 9ES. r 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-~/a" drilling assembly with MWD GR and directionally drill surface hole to approximately 3,633' MD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. An intermediate wiperlbit trip to ~ surface will be performed prior to exiting the permafrost. 4. Run and cement the 9 5/", 40.0-Ib/ft, L-80, BTC surface casing~aek to surface. A TAM Port Collar should be on location. A TAM port collar will be run in the casing string only if hole conditions dictate. Bump plug and test float. ~ 5. ND diverter spool and NU casing /tubing head. NU BOPE and test to 4,000 psi. 6. MU 8-3/a" drilling assembly with MWDILWD GR/Res/Azi-Den/Neu(recorded)/PWD and RIH to float collar. Circulate and condition cement contaminated mud. Displace over to new 8.8 ppg LSND mud. Test the 9 5/8" casing to 4,000 psi for 30 minutes. ~ 7. Drill new formation to 20' below 9 5/e" shoe and perform LOT. (If 11.8 EMW is not obtained contact ODE). 'r 8. Drill to ~ 200' MD above the HRZ, ensure mud is conditioned to $,{5pg and perform short trip as needed. Ensure pre-reservoir meeting is held highlighting kick tolerance an detection prior to entering the Kuparuk. 9. Drill ahead to target TD at 11,023' MD, (approx 250' MD below LCU Kup B). 10. Circulate and condition hole, POOH to run casing. Perform wiper trip only if hole conditions dictate. 11. Run the 7", 26-Ib/ft, L-80, BTC-M casing and cement in 2 stages. Displace the casing with seawater during cementing operations. Bump plug and ensure float holds. Freeze protect the 7" x 9 5/8" annulus. 12. MU 7" EZSV and RIH. Set (at 10,631 MD) such that Baker window top is at top Kuparuk C sand (10,608' MD). 13. MU and RIH w/ 7" Whipstock assembly. Set Whipstock such that window top is at the top of the Kuparuk C ' /. sand (10,608 MD). Pressure test casing to 4,000 psi for 30 minutes. Displace seawater to 9.4 ppg FloPro SF. Mill Window and drill 20' of new formation. Perform FIT test to 11.0 ppg EMW. POOH and LD milling assembly. 14. MU 6-'/8" drilling assembly with MWDILWD GR/Res/Azi-Den/Neu/PWD (All real time). 15. Build to horizontal C~3 12+°/100 ft and then drill ahead to proposed TD (a~ 12,403'MD / 6,422' TVD. Short trip as required and condition hole for running 4-~/2" liner. \ 16. RU Schlumberger a-line. RIH wl GR-000JB to float co r. un USIT Cement Evaluation Log for the state to confirm cement integrity over Kupurak and Schrader. I og from 7" TD to TOC. 17. Run 4-'/z ", 12.6 Ib/ft, L-80, IBT-M solid liner. There i I be 150' of overlap into the 7" intermediate casing. Cement finer as directed. Set liner top packer. Release from liner and displace well to filtered 9.4 ppg KCI brine and POOH. 18. Wait on cement to reach 2000 psi compressive strength, test 4-1/2" liner to 4,000 psi for 30 minutes. 19. PU DPC guns and RIH w/ 600' of 2 '/a" HSD PJ HMX 2906 6 spf, 60° phasing perf guns. Tag PBTD for i depth control. Perforate w/ depths TBD from town. 20. Run 4-1/2", 12.6 Ib/ft, L-80, Premium Thread TC-II completion. Set packer C~3 10,200' MD (200' TVD above TKUP) and test tubing to 4,000 psi and annulus to 4,000 psi for 30 minutes. ~ 21. Shear DCK valve and install TWC. 22. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. Remove TWC. 23. RU hot oil truck. Freeze protect the well from lowest GLM. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-'/2" annulus valve and secure the well. Assure that 1A/OA are both protected with two barriers. 24. Rig down and move off. Post-Rig Work: 1. R!U Slickline and pull ball and rod / RHC. 2. Replace the DCK shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with gas lift valves. 4. Pull VR plug. L-123i Permit to Drill Page 7 Variance Request Issue Compliance with AOGCC testing requirements for BOP rams after they have been used in the normal coarse of operations. Request The AOGCC is in the process of developing a guideline document clarifing the intent of the regulations pertaining to function pressure testing ram type BOP's. BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, exce t when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Background AOGCC regulations require rams that have been used in the course of primary drilling & completion, workover and through tubing drilling operations be function pressure tested before the next wellbore entry. This is not a new regulation. The intent of this regulation is to ensure that ram type equipment has integrity after it has been utilized in a wellbore...for example; to ensure integrity if a ram was closed on a tool joint. The exact regulation language is: "if BOP sealing ram type equipment has been used, it must be function pressure-tested, before the next wellbore entry, to the required working pressure specified in the approved Permit to Dri11, using anon-compressible fluid, except that an annular type preventer need not be tested to more than 50 percent of its rated working pressure;" The pertinent sections are: 20 AAC 25.035 (e)(10)C PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036 (d)(4) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285 (f)(2) TUBING WORKOVERS; 20 AAC 25.286(e)(1) WORKSTRING SERVICE OPERATIONS This issue has been discussed with Winton Hubert at the AOGCC. The test requirement in the regulation is intended to apply to ram type equipment only. The AOGCC understands that ram type BOP's are utilized for purposes other than well control in the normal coarse of operations. The regulations allowing a variance are at 20 AAC 25.035(h) PRIMARY DRILLING AND COMPLETION; 20 AAC 25.036(f) THROUGH TUBING DRILLING AND COMPLETION; 20 AAC 25.285(h) TUBING WORKOVERS; 20 AAC 25.286(g) WORKSTRING SERVICE OPERATIONS...which says generally: 20 AAC 25.035{h)... Upon request of the operator, the commission will, in its discretion, approve a variance {1) Pram the BOPS requirements in {e) of this section if the variance provides at least an equally effective means of well control; L-1231 Proposed Completion ~ 9 5/8", 40.0#, L-80, BTC 3,633 Minimum ID = 3.813" @ -2500 TVD' TBD HES 4 1/2"'X' nipple; I.D. = 3.813" TREE = 4 1116" CM/ WELLHEAD = FMC Gen5 ACTUATOR = LEO KB. ELEV - XXX' AMSL CB. ELEV = XXX' AMSL KOP = 400' Max Angle = 93° @ 11,693' Datum MD =. XXX' Datum TV D = XXX' GAS LIFT MANDRELS ST MD TVD TYPE VLV LATCH PORT DATE 1 2 TBD TBD 2600 4200 MMG MMG Dum DCK BK-5 BK-5 PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: Note: Refer to Production DB for historical pert data Baker 7" X 4 1 /2" Premier Packer ^'10200 4 1/2", 12.6#, L-80, 10458 TCII tubin / a r ine hngr,ZXPpkr,w/ -10458 TBS Baker Whip stock, J (Top of w indow) "10608 HES 7" ¢SV 10,650 7", 26.0#, L-80, BTGM 11, 023 -10150 HES 4 1/2" 'X' nipple; I.D. = 3.813" -10230 HES 4 1/2"'X' nipple; I.D. = 3.813" -10260 HES 4 1/2"'XN' nipple; I.D. = 3.725" TBD Pup W/'RA' Tag TBD ~pW/'RA'Tag TBD Pup W/'RA' Tag 0 0 0 PBTD 12,300 4 1!2", 12.6 #, L-80 IBT-M liner 12,403 PRUDHOE BAY UNIT WELL: L-123i PERMfr No: API No: 50-029-??~~? BP Exploration (Alaska) DATE REV BY COMMENTS DATE REV BY COMMENTS 10/18/05 MJM Proposed Completion by Schlumberger L-123PB1 (P1) Proposal Report Date: September 13, 2005 Survey 1 DLS Computation Method: Minimum Curvature ! Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 316.570° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 102.393 ff, E 158.427 ff Structure 1 Slot: L-PAD I N-F ~ ud~ TVD Reference Datum: Rotary Table Well: Plan L-123 (N-F) ~ ~~ f i~ TVD Reference Elevation: 72.60 ff relative to MSL Borehole: Plan L-123PB1 FI~aS Sea Bed I Ground Level Elevation: 44.10 ff relative to MSL l1WIlAPI#: 50029 Magnetic Declination: 24.387° Survey Name I Date: L-123P61 (P1) /September 13, 2005 Total Field Strength: 57577.955 nT Tort 1 AHD I DDI 1 ERD ratio: 143.654° / 8351.07 ft ! 6.304 11.271 Magnetic Dip: 80.849° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US feel Declination Date: December 13, 2005 Location LatlLong: N 70.35055728, W 149.32556029 Magnetic Declination Model: BGGM 2005 Location Grid NIE YIX: N 5978252.150 ffUS, E 583069.280 ffUS North Reference: True North Grid Convergence Angle: +0.63516881 ° Total Corr Mag North -> True North: +24.387° Grid Scale Factor. 0.99990784 Local Coordinates Referenced To: Structure Reference Point Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Tool Face DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft d de ft ft ft ft ft de de N00 ft de 1100 ft de 1100 ft ftUS ftUS RIC v.uu v.uu 33U.uu -rG.bu U.uU U.UU "IUG.3y 1b25.43 -3U.UUM U.UU U.UU U.UU 5y/ifZ5Z.15 5tf3U6y.Ztt N /0.35U55/Zif W 14y.32556UZ9 KOP Crv 1.5/100 300.00 0.00 330.00 227.40 300.00 0.00 102.39 158.43 -30.OOM 0.00 0.00 0.00 5978252.15 583069.28 N 70.35055728 W 149.32556029 Crv 3.5/100 400.00 1.50 330.00 327.39 399.99 1.27 103.53 157.77 -30.OOM 1.50 1.50 0.00 5978253.28 583068.61 N 70.35056037 W 149.32556560 500.00 5.00 330.00 427.21 499.81 6.79 108.44 154.94 -30.OOM 3.50 3.50 0.00 5978258.15 583065.73 N 70.35057378 W 149.32558861 600.00 8.50 330.00 526.50 599.10 18.22 118.61 149.06 O.OOG 3.50 3.50 0.00 5978268.26 583059.74 N 70.35060159 W 149.32563631 700.00 12.00 330.00 624.89 697.49 35.52 134.02 140.17 O.OOG 3.50 3.50 0.00 5978283.57 583050.67 N 70.35064368 W 149.32570852 800.00 15.50 330.00 722.01 794.61 58.64 154.60 128.28 O.OOG 3.50 3.50 0.00 5978304.02 583038.56 N 70.35069991 W 149.32580498 Crv 3.5/100 900.00 19.00 330.00 817.50 890.10 87.48 180.28 113.46 -35.61 G 3.50 3.50 0.00 5978329.53 583023:46 N 70.35077006 W 149.32592532 1000.00 21.94 324.54 911.18 983.78 121.82 209.60 94.48 -30.49G 3.50 2.94 -5.46 5978358.63 583004.15 N 70.35085016 W 149.32607942 1100.00 25.01 320.34 1002.90 1075.50 161.42 241.10 70.14 -26.64G 3.50 3.08 -4.20 5978389.86 582979.47 N 70.35093621 W 149.32627699 1200.00 28.18 317.02 1092.31 1164.91 206.15 274.66 40.54 -23.67G 3.50 3.17 -3.32 5978423.09 582949.50 N 70.35102790 W 149.32 0 1300.00 31.42 314.32 1179.08 1251.68 255.82 310.15 5.78 -21.33G 3.50 3.23 -2.69 5978458.19 582914.36 6 N 70.35112487 W 149.32 1400.00 34.70 312.09 1262.89 1335.49 310.25 347.45 -34.00 -19.45G 3.50 3.28 -2.24 5978495.04 582874.17 N 70.35122676 W 149.32" 2 1500.00 38.01 310.19 1343.41 1416.01 369.25 386.42 -78.66 -17.93G 3.50 3.32 -1.89 5978533.50 582829.09 N 70.35133320 W 149.32748497 1600.00 41.36 308.56 1420.36 1492.96 432.59 426.90 -128.03 -16.67G 3.50 3.34 -1.63 5978573.43 582779.28 N 70.35144379 W 149.32788577 1700.00 44.72 307.14 1493.45 1566.05 500.03 468.74 -181.92 -15.63G 3.50 3.36 -1.43 5978614.68 582724.93 N 70.35155811 W 149.32832330 1800.00 48.10 305.87 1562.39 1634.99 571.32 511.80 -240.14 -14.76G 3.50 3.38 -1.27 5978657.09 582666.25 N 70.35167574 W 149.32879596 1900.00 51.49 304:73 1626.94 1699.54 646.20 555.91 -302.46 -14.02G 3.50 3.39 -1.14 5978700.50 582603.44 N 70.35179624 W 149.32930196 2000.00 54.89 303.70 1686.85 1759.45 724.39 600.91 -368.66 -13.40G 3.50 3.40 -1.04 5978744.76 582536.75 N 70.35191915 W 149.32983943 End Crv 2096.79 58.19 302.77 1740.22 1812.82 802.94 645.15 -436.20 O.OOG 3.50 3.41 -0.95 5978788.24 582468.74 N 70.35204000 W 149.33038775 9-5/8" Csg Pt 3632.87 58.19 302.77 2550.00 2622.60 2070.58 1351.73 -1533.71 O.OOG 0.00 0.00 0.00 5979482.58 581363.58 N 70.35396994 W 149.33929922 Crv 4/100. 8439.71 58.19 302.77 5084.03 5156.63 6037.39 3562.85 -4968.15 115.OOG 0.00 0.00 0.00 5981655.35 577905.22 N 70.36000642 W 149.36719661 8500.00 57.19 305.37 5116.26 5188.86 6087.13 3591.39 -5010.35 113.61 G 4.00 -1.65 4.31 5981683.42 577862.70 N 70.36008431 W 149.36753954 WeIlDesign Ver SP 1.0 Bld(doc40x_56) N-F\Plan L-123 (N-F)\Plan L-123P61\L-123P61 (P1) Generated 9/13/2005 12:10 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical NS EW Tool Face DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de ft ft ft ft k de de 1100 ft de 1100 ft de 1100 k ftUS ftUS ovvv .w oJ .o/ JV~.oI a1/ IA/ OL44.I1 OIOy.Jy J04L. 1/ -OU/O .JO ll I .IVV 4.VV -I.DL 4.44 Dy01/JJ.4/ V///y0.14 IV /U .JOULLLy4 VV l4y.Jb2fU/Dy4 8700 .00 54 .31 314.41 5228 .96 5301.56 6251.01 3697. 05 -5137 .11 108 .51 G 4.00 -1.36 4.59 5981787.66 577734.79 N 70 .36037274 W 149.36856965 8800 .00 53 .13 319.15 5288. 16 5360.76 6331.58 3755. 75 -5192 .31 105 .71G 4.00 -1.18 4.74 5981845.74 577678.96 N 70 .36053300 W 149.36901829 8900 .00 52 .15 324.03 5348. 86 5421.46 6410.72 3817. 99 -5241 .68 102 .75G 4.00 -0.98 4.88 5981907.42 577628.90 N 70 .36070293 W 149.36941966 9000 .00 51 .37 329.03 5410. 78 5483.38 6488.04 3883. 45 -5284 .99 99. 65G 4.00 -0.78 5.00 5981972.40 577584.87 N 70 .36088170 W 149.36977180 9100 .00 50 .81 334.12 5473. 61 5546.21 6563.16 3951. 84 -5322 .03 96. 45G 4.00 -0.56 5.09 5982040.36 577547.09 N 70 .36106845 W 149.37007301 9200 .00 50 .47 339.27 5537. 05 5609.65 6635.72 4022. 80 -5352. 61 93. 18G 4.00 -0.34 5.16 5982110.98 577515.73 N 70 .36126226 W 149.37032180 9300 .00 50 .37 344.46 5600. 79 5673.39 6705.36 4096. 00 -5376. 59 89. 88G 4.00 -0.11 5.19 5982183.90 577490.94 N 70 .36146219 W 149.37051698 9400. 00 50 .49 349.65 5664. 52 5737.12 6771.75 4171. 08 -5393 .84 86. 57G 4.00 0.12 5.19 5982258.78 577472.86 N 70 .36166726 W 149.37065758 9500 .00 50 .85 354.80 5727. 92 5800.52 6834.56 4247. 68 -5404. 30 83. 30G 4.00 0.35 5.15 5982335.25 577461.56 N 70 .36187649 W 149.37074292 9600. 00 51 .42 359.88 5790. 70 5863.30 6893.48 4325. 41 -5407. 89 80. 11 G 4.00 0.58 5.08 5982412.93 577457.11 N 70 .36208884 W 149.3 8 9700 .00 52 .22 4.87 5852. 53 5925.13 6948.23 4403. 90 -5404. 61 77. 03G 4.00 0.79 4.99 5982491.45 577459.51 N 70 7 .36230328 W 149.37 1 9800 .00 53 .21 9.74 5913. 13 5985.73 6998.54 4482. 78 -5394. 48 74. 08G 4.00 1.00 4.87 5982570.42 577468.78 N 70 .36251878 W 149.37066455 9900. 00 54 .41 14.47 5972. 20 6044.80 7044.17 4561. 64 -5377. 54 71. 28G 4.00 1.19 4.73 5982649.46 577484.84 N 70. 36273427 W 149.37052739 10000 .00 55 .78 19.06 6029. 45 6102.05 7084.89 4640. 12 -5353. 87 68. 66G 4.00 1.37 4.58 5982728.19 577507.64 N 70 .36294871 W 149.37033559 10100. 00 57 .31 23.48 6084. 59 6157.19 7120.51 4717. 83 -5323. 59 66. 22G 4.00 1.54 4.43 5982806.22 577537.05 N 70. 36316105 W 149.37009009 10200. 00 59 .00 27.75 6137. 37 6209.97 7150.84 4794. 38 -5286. 85 63. 96G 4.00 1.69 4.27 5982883.17 577572.94 N 70 .36337026 W 149.36979208 10300. 00 60 .82 31.87 6187. 52 6260.12 7175.75 4869. 41 -5243. 82 61. 90G 4.00 1.82 4.12 5982958.66 577615.13 N 70 .36357533 W 149.36944301 10400. 00 62 .76 35.84 6234. 80 6307.40 7195.12 4942. 56 -5194. 72 60. 02G 4.00 1.94 3.97 5983032.34 577663.41 N 70. 36377524 W 149.36904458 10500. 00 64 .81 39.67 6278. 98 6351.58 7208.84 5013. 45 -5139. 79 58. 33G 4.00 2.05 3.83 5983103.83 577717.55 N 70. 36396903 W 149.36859874 End Crv 10508. 86 65 .00 40.00 6282. 74 6355.34 7209.78 5019. 62 -5134. 65 O. OOG 4.00 2.10 3.76 5983110.05 577722.63 N 70. 36398588 W 149.36855700 L-125PB1 Kup Tgt 1 10608. 86 65 .00 40.00 6325. 00 6397.60 7220.15 5089. 04 -5076. 39 O. OOG 0.00 0.00 0.00 5983180.11 577780.10 N 70. 36417565 W 149.36808414 TD / 7" Csg Pt 11022. 95 65 .00 40.00 6500. 00 6572.60 7263.09 5376. 53 -4835. 16 O. OOG 0.00 0.00 0.00 '5983470.22 578018.12' N 70. 36496148 W 149.36612602 • WeIlDesign Ver SP 1.0 Bld( doc40x_56) N-F\Plan L-123 (N-F)\Plan L-123P61 \L-123P61 (P1) Generated 9/13/2005 12:10 PM Page 2 of 2 by Schlumberger WELL L-123PB1 (P1) F,ELD Prudhoe Bay Unit - WOA STRDGTDRE L-PAD Magne~c Pa~ame~ars SuOace La:alan NND2/ Alaaka Bale PNnes. lure 04. US Fuel Miscellanaous MJEtlI. BGGM 1005 Dip. &(1.849" Dada. Decem5er t3. 2005 Lal N]02t 200f. NOflflmg'. 59]0252.1511US GnC Cmv: ro8J516081' Sbl: N-F TVD ReI: Ro~ay TaEle (]2.60flaMvu MSL~ Maq Dec. .24.38]° FS. !5]80 nT Lun. W149 19 32 01/ Easing 58308B2BflU5 Sale Fact. 099990]8388 Pon. L-123PB~IPt1 Srvy Dale. Sepfembe]t3. 1005 0 1200 2400 3600 4800 6000 7200 0 ,200 2400 O O N C 0) m 3600 U H .................. ~ RTF....................:..................................:...................................:.......... KOP Crv 1.5/100 Crv 3.51100 Crv 3.51100 End Crv 0 1200 2400 3600 •i •i 4800 6000 4800 6000 0 1200 2400 3600 4800 6000 7200 Vertical Section (ft) Azim = 316.57°, Scale = 1(in):1200(ft) Origin = 102.393 N/-S, 158.427 E/-V by Schlumberger WELL FIELD STRUCTURE L-123PB1 (P1) Prudhoe Bay Unit - WOA L-PAD M1fagrlaic Parainnbrs Surface LOCafon NFDI/NasXa Safe Plares. Zo~W.GS FcuI M'acNlaieuus Monet. BGGM1I 1006 Py: bi9' Dale Docempyr 132005 N)0311006 5/b15"1 i5 bU5 GnC Cunv •0635iFbb t- Sbl N~F TVD RaI Rotary Ta61e 1.1260 NaMVe MSLf Mag Dec. •2a 3b ]' FS 675180 nT Lon Wta9193101] Eas4yy 58 b651tl XUS Scale Fac3099950 /63bF PNn. L-t 13PB'. iPtf Srvy Dale Segem6er t3. 2005 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 5000 4000 n n n Z 0 °0 3000 c _~ c~ ~ 2000 v v v 1000 0 -6000 -5000 -4000 -3000 -2000 c« W Scale = 1(in):1000(ft) E »> -1000 0 10( 5000 4000 3000 2000 1000 0 ~i •i BP Anticollision Report Company:: BP Amoco Date: 9/13/2005 Field: Prudhoe Bay Reference Site: PB L Pad' Co-ordinate(NE) Reference R'eferenceWell: Plan L-123 (N-F) YerticaF(TVD) Reference: Reference Wellpath: Plait L-123P81 -- - NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 20.00 ft ', Depth Range: 28.50 to 11022.95 ft Maximum Radius:10000.00 ft Survey Program for Definitive Wellpath Date: 8/15/2005 Validated: No Planned From To Survey ft ft 28.50 1000.00 Planned: Plan #1 V2 it 1000.00 2400.00 Planned: Plan #1 V2 1000.00 11022.95 Planned: Plan #1 V2 Time: 12:15:58 Page: Reference: Error Model: Well: Plan L-123 (N-F), True North L-125 Plan N-F 72.6 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing __~ Version: 1 Toolcode Tool Name ~I - _ _ ___ __ --- GYD-GC-SS Gyrodata gyro single shots MWD MWD -Standard MWD+IFR+MS MWD +IFR + Multi Station Casing Points - -- - -- MD T'Vp I)i~meter Hole Size Name - ~I ft ft' in in ~ 3632.87 2622.60 9.625 12.250 9 5/8" I~ 11022.95 6572.60 7.000 8.750 7" Summary <-------- ------- offset Wellpath ,- -------_-> Reference Offset Ctr-Ctr Vo-Gn Allo~tahlc Site WeII Wellpath MD MD Distance Area Deviation Warning - ft ft ft ft ft ~ I PB L Pad L-01 - L-01 V14 - - 315.05 - --- 320.00 - -- 231.99 -- 5.22 - --- 226.77 --- Pass: Major Risk '~ PB L Pad L-02 L-02 V1 470.01 480.00 14.13 8.21 5.92 Pass: Major Risk ~~ PB L Pad L-02 L-02A V5 455.89 460.00 13.93 8.11 5.82 Pass: Major Risk '~, PB L Pad L-02 L-02APB1 V2 455.89 460.00 13.93 8.11 5.82 Pass: Major Risk ', PB L Pad L-02 L-02P61 V21 470.01 480.00 14.13 8.32 5.81 Pass: Major Risk ', ', PB L Pad L-03 L-03 V5 496.31 520.00 244.00 9.42 234.57 Pass: Major Risk ', PB L Pad L-101 L-101 V4 810.64 820.00 55.11 14.73 40.38 Pass: Major Risk ~, PB L Pad L-102 L-102 V2 253.60 260.00 358.98 4.15 354.83 Pass: Major Risk ',' PB L Pad L-102 L-102P61 V10 253.60 260.00 358.98 4.24 354.73 Pass: Major Risk ', PB L Pad L-102 L-102P62 V2 253.60 260.00 358.98 4.24 354.73 Pass: Major Risk ', PB L Pad L-103 L-103 V23 392.59 400.00 236.19 6.60 229.59 Pass: Major Risk ', PB L Pad L-104 L-104 V7 350.23 360.00 331.34 6.01 325.33 Pass: Major Risk ~I PB L Pad L-105 L-105 V4 331.80 340.00 298.52 6.05 292.47 Pass: Major Risk PB L Pad L-106 L-106 V14 493.88 520.00 304.69 8.25 296.44 Pass: Major Risk ', PB L Pad L-107 L-107 V14 195.28 200.00 241.94 4.34 237.59 Pass: Major Risk PB L Pad L-108 L-108 V18 459.83 480.00 279.71 8.54 271.17 Pass: Major Risk PB L Pad L-109 L-109 V12 315.42 320.00 194.69 6.59 188.10 Pass: Major Risk ', PB L Pad L-110 L-110 V11 275.49 280.00 183.60 5.08 178.52 Pass: Major Risk 'i PB L Pad L-111 L-111 V24 296.39 300.00 196.69 5.32 191.37 Pass: Major Risk ~i ~~ PB L Pad L-112 L-112 V8 410.72 420.00 33.24 8.53 24.71 Pass: Major Risk 'I PB L Pad L-114 L-114 V15 411.05 420.00 183.83 6.59 177.24 Pass: Major Risk ' PB L Pad L-114 L-114A V4 411.05 420.00 183.83 6.59 177.24 Pass: Major Risk ', PB L Pad L-115 L-115 V7 335.46 340.00 46.48 5.79 40.69 Pass: Major Risk PB L Pad L-116 L-116 V10 372.76 380.00 191.06 5.83 185.23 Pass: Major Risk ', PB L Pad L-117 L-117 V11 474.23 480.00 60.55 7.70 52.86 Pass: Major Risk ', PB L Pad L-118 L-118 V9 255.67 260.00 77.45 4.78 72.67 Pass: Major Risk i PB L Pad L-119 L-119 V9 411.20 420.00 282.69 6.95 275.74 Pass: Major Risk PB L Pad L-120 L-120 V8 293.48 300.00 312.18 5.09 307.09 Pass: Major Risk PB L Pad L-121 L-121 V14 196.19 200.00 181.93 3.60 178.33 Pass: Major Risk PB L Pad L-121 L-121A V1 196.19 200.00 181.93 3.60 178.33 Pass: Major Risk PB L Pad L-122 L-122 V5 534.82 540.00 12.85 9.20 3.65 Pass: Major Risk '~ PB L Pad L-124 L-124 V11 915.79 920.00 26.47 16.65 9.82 Pass: Major Risk ', PB L Pad L-124 L-124PB1 V5 915.79 920.00 26.47 16.65 9.82 Pass: Major Risk PB L Pad L-124 L-124P62 V4 915.79 920.00 26.47 16.65 9.82 Pass: Major Risk PB L Pad L-200 L-200 V7 393.87 400.00 145.27 7.01 138.26 Pass: Major Risk PB L Pad L-200 L-200L1 V3 393.87 400.00 145.27 7.01 138.26 Pass: Major Risk PB L Pad L-200 L-200L2 V6 393.87 400.00 145.27 7.01 138.26 Pass: Major Risk PB L Pad L-200 Plan L-200L3 OA V1 Pla 393.87 400.00 145.27 723 138.04 Pass: Major Risk '~ PB L Pad L-200 Plan L-200L3PB1 OA V4 393.87 400.00 145.27 7.12 138.15 Pass: Major Risk ~i PB L Pad L-201 L-201 V6 293.88 300.00 265.30 5.11 260.19 Pass: Major Risk PB L Pad L-201 L-201 L1 V9 293.88 300.00 265.30 5.11 260.19 Pass: Major Risk PB L Pad L-201 L-201 L1 P61 V10 293.88 300.00 265.30 5.11 260.19 Pass: Major Risk BP Anticollision Report Company: , BP Amoco Date. 9!13!2005 't'ime: 12:15 :58 Page: 2 Eieldc Prudhoe Bay RefercnceSiteC PB L Pad Co-ordinatc (NI!:) Reierence: Well: Pla n L-123 (N-F), True North Reference Well: Plan L-123 (N-F) Vertical (TV D) Refere nce: L-125 Plan N-F 72.6 Reference Wellpath: Plan L-123P61 Db: Oracle Summary <--------____ -..Offset Wellpath -- ----.> Reference Offset Ctr-Ctr Nu-Co Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft ~I PB L Pad L-201 L-201 L2 V5 293.88 300.00 265.30 5.11 260.19 Pass: Major Risk PB L Pad L-201 L-201 L3 V2 293.88 300.00 265.30 5.11 260.19 Pass: Major Risk ~, I PB L Pad L-201 L-201 L3P61 V6 293.88 300.00 265.30 5.11 260.19 Pass: Major Risk ~I ', PB L Pad L-201 L-201 P61 V12 293.88 300.00 265.30 5.11 260.19 Pass: Major Risk ', PB L Pad L-201 L-201 P62 V3 293.88 300.00 265.30 5.11 260.19 Pass: Major Risk ', PB L Pad L-202 L-202 V5 433.24 440.00 161.54 7.37 154.17 Pass: Major Risk ', PB L Pad L-202 L-202L1 V7 433.24 440.00 161.54 7.37 154.17 Pass: Major Risk PB L Pad L-202 L-202L2 V6 433.24 440.00 161.54 7.37 154.17 Pass: Major Risk ', ', PB L Pad L-202 L-202L3 V6 433.24 440.00 161.54 7.37 154.17 Pass: Major Risk PB L Pad L-210 L-210 V6 233.30 240.00 295.07 4.00 291.07 Pass: Major Risk ', PB L Pad L-210 L-210PB1 V8 233.30 240.00 295.07 4.00 291.07 Pass: Major Risk PB L Pad L-211 L-211 V6 215.59 220.00 31.81 4.12 27.70 Pass: Major Risk ', ~~ PB L Pad L-211 L-211 P61 V6 215.59 220.00 31.81 4.12 27.70 Pass: Major Risk ', PB L Pad L-212 L-212 V11 432.66 440.00 176.44 7.35 169.09 Pass: Major Risk PB L Pad L-212 L-212PB1 V9 432.66 440.00 176.44 7.35 169.09 Pass: Major Risk PB L Pad L-212 L-212PB2 V2 432.66 440.00 176.44 7.35 169.09 Pass: Major Risk PB L Pad L-214 L-214 V9 369.11 380.00 344.39 6.87 337.52 Pass: Major Risk ' ', PB L Pad L-215 L-215PB1 V2 Plan: Plan 392.67 400.00 251.05 7.55 243.50 Pass: Major Risk PB L Pad L-215 Plan L-215 V5 Plan: PI 392.67 400.00 251.05 7.44 243.61 Pass: Major Risk ' ', PB L Pad L-216 L-216 V6 254.19 260.00 220.32 4.47 215.86 Pass: Major Risk PB L Pad L-218 L-218 V4 555.98 560.00 57.00 9.60 47.40 Pass: Major Risk PB L Pad NWE1-01 L-100 V2 275.58 280.00 189.78 4.85 184.93 Pass: Major Risk PB L Pad NWE1-01 NWE1-01 V5 275.58 280.00 189.78 4.85 184.93 Pass: Major Risk ', PB L Pad Plan L-203 (N-Q) Plan L-203 V6 Plan: PI 392.70 400.00 205.93 7.49 198.44 Pass: Major Risk !, PB L Pad Plan L-213 (S-Q) Plan L-213 V5 Plan: PI 332.55 340.00 273.19 6.32 266.88 Pass: Major Risk ', PB L Pad Plan L-250 (NM-15) Plan L-250 V2 Plan: PI 452.91 460.00 130.98 8.61 122.37 Pass: Major Risk PB L Pad Plan L-250 (NM-15) Plan L-250L1 V9 Plan: 452.91 460.00 130.98 8.68 122.30 Pass: Major Risk PB L Pad Plan L-250 (NM-15) Plan L-250L2 V6 Plan: 452.91 460.00 130.98 8.73 122.25 Pass: Major Risk I PB L Pad Plan L-50 (S-D) Plan L-50 V2 Plan: Pla 373.12 380.00 183.33 7.18 176.15 Pass: Major Risk PB L Pad Plan L-51 (S-B) Plan L-51 V1 Plan: Pla 392.38 400.00 190.77 7.44 183.34 Pass: Major Risk PB L Pad Plan L-52 (S-E) Plan L-52 V1 Plan: Pla 465.00 480.00 180.86 8.94 171.92 Pass: Major Risk ', ', I'i Field: Prudhoe Bay ~', ' Site: PB L Pad Well: Plan L-123 (N-F) ', Wellpath: Plan L-123PB1 loo 0 loo ItSV Travelling Cylinder.4zimuth (TFO+AZI) [deg] vs Centre to Centre Separntion [IOOR/in] by L-123 (P2) Proposal Schlumberger Report Date: September 13, 2005 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 52.470° Field: Structure 1 Slot: Prudhoe Bay Unit - WOA L-PAD I N-F ~ Vertical Section Origin: ud~ TVD Reference Datum: N 0.000 ft, E 0.000 ft Rotary Table Well: Plan L-123 (N-F) ~ ~~' ~~ TVD Reference Elevation: 72.60 ft relative to MSL Borehole: ~ Plan L-123 ~ea Sea Bed I Ground Level Elevation: 44.10 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 24.387° Survey Name I Date: L-123 (P2) I September 13, 2005 Total Field Strength: 57577.955 nT Tort 1 AND 1 DDI 1 ERD ratio: 201.915° 19759.61 ft 16.578 / 1.51 C Magnetic Dip: 80.849° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: December 13, 2005 Location LatlLong: N 70.35055728, W 149.32556029 Magnetic Declination Model: BGGM 2005 Location Grid NIE YIX: N 5978252.150 ftUS, E 583069.280 ftUS North Reference: True North Grid Convergence Angle: +0.63516881 ° Total Corr Mag North -> True North: +24.387° Grid Scale Factor: 0.99990784 Local Coordinates Referenced Toy Wr ll Hraad Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Tool Face DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section R de de R R ft ft ft de de 1100 ft de 1100 ft de 1100 ft RUS RUS I UIJ vviuNswcn iVOVO.VV tlV.VU 9U.VU tl3L4.tlJ tlJ01/.L3 -11-14.41 4yt3tl.Vb -SLStl.3Z U.UVG U.UU U.UU U.UU C)`JifS1 /y.3y 5////y.SU N /U.3641 /371 W 149.36t3Ut39U9 Base Whipstock 10621.00 67.08 40.00 6329.91 6402.51 -1102.81 4995.15 -5227.69 O.OOG 16.00 16.00 0.00 5983188.58 577787.04 N 70.36419858 W 149.36802711 KOP Crv 14/100 10633.00 87.08 40.00 6334.59 6407.19 -1092.02 5003.62 -5220.58 35.65G 0.00 0.00 0.00 t, 5983197.12 '" 577794.05 . N 70.36422173 W 149.36796945 10700.00 74.80 45.65 6356.47 6429.07 -1029.65 5049.96 -5177.54 33.80G 14.00 11.52 8.43 5983243.93 577836.57 N 70.36434840 W 149.36762003 10800.00 86.53 53.40 6372.68 6445.28 -931.35 5113.76 -5102.60 32.53G 14.00 11.74 7.75 5983308.56 577910.79 N 70.36452286 W 149.36701160 End Crv 10885.71 96.65 59.86 6370.30 6442.90 -846.05 5160.82 -5031.18 O.OOG 14.00 11.80 7.54 5983356.39 577981.67 N 70.36465153 W 149.36643172 Crv 10/00 10973.45 96.65 59.86 6360.14 6432.74 -759.63 5204.58 -4955.82 -138.46G 0.00 0.00 0.00 5983400.98 578056.55 N 70.36477122 W 149.36581970 11000.00 94.66 58.09 6357.52 6430.12 -733.38 5218.19 -4933.18 -138.63G 10.00 -7.50 -6.65 5983414.85 578079.03 N 70.36480845 W 149.36563587 " L-123 Kup Tgt 1 11062.01 90.00 54.00 6355.00 6427.60 -671.58 5252.78 -4881.81 -139.55G 10.00 -7.52 -6.60 5983450.00 578130.00 N 70.36490304 W 149.36521879 11100.00 87.11 51.53 6355.96 6428.56 -633.60 5275.76 -4851.58 -139.49G 10.00 -7.61 -6.49 5983473.31 578159.98 N 70.36496586 W 149.36497329 End Crv 11109.56 86.38 50.91 6356.50 6429.10 -624.06 5281.73 -4844.14 O.OOG 10.00 -7.60 -6.51 5983479.36 578167.35 N 70.36498220 W 149.364 0 Crv 10/100 11621.43 86.38 50.91 6388.79 6461.39 -113.40 5603.84 -4447.63 19.63G 0.00 0.00 0.00 5983805.82 578560.22 N 70.36586284 W 149.361 L-123 Kup Tgt 2 11659.82 90.00 52.20 6390.00 6462.60 -75.04 5627.69 -4417.59 19.64G 10.00 9.42 3.36 5983830.00 578590.00 N 70.36592805 W 149.361 End Crv 11693.34 93.16 53.33 6389.08 6461.68 -41.54 5647.96 -4390.92 O.OOG 10.00 9.42 3.36 5983850.56 578616.44 N 70.36598347 W 149.36123275 s TD / 4-1/2" Lnr 12403.01 93.16 53.33 6350.00 6422.60 666.98 6071.17 -3822.58 O.OOG 0.00 0.00 0.00 5984280.00 579180.00 N 70.36714047 W 149.35661723 WeIlDesign Ver SP 1.0 Bld( doc40x_56) N-F\Plan L-123 (N-F)\Plan L-123\L-123 (P2) Generated 9/13/2005 12:45 PM Page 1 of 1 by Schlumberger WELL FIELD STPUCTIIRE L-123 (P2) Prudhoe Bay Unit - WOA L-PAD Magne is Par Su~ace N~U2]Rlas aSlateP~i i~. ~~ii«i SFua Miss a~ 1 amelars LUGaII1N1 F L - 'i ~ '.J i ell woos Motlal BGGM 2W6 DiV: 80849° Dole Du~vinl+cr ll. 2005 Lal N~0212906 NurlM1ilg. 59 /826115 XU9 I,~~~ ~~ -U O3 S'tiNot- SbT. N-F ND ReI. nary Table 1]260 M1aWVU MSL) Mag Dec ~2a 38T' FS Len 4149 19 31 01] Eas6ng: 58308528 IIUS PWn L12J iP21 Srvy Dale Sa{Nembae 13. 2005 -1200 -900 -600 -300 0 300 600 900 6000 6300 `o 0 M C N m 6600 U 6900 -1200 -900 -600 -300 0 300 600 900 Vertical Section (ft) Azim = 52.47°, Scale = 1(in):300(ft) Origin = 0 N/-S, 0 E/-V 6000 6300 6600 6900 by Schlumberger ~" L-123 (P2) FIELD Prudhoe Bay Unit - WOA STR~ETDRE L-PAD Magretw Parameters SWxe Lwalnn NA021 ALlska Sule Planes. tare W US Fens Miscellaneous MaEnl 9GGM 2005 Diy 60.609° OMe December r3. 2WS Lal. N~0 21 G 006 M1uMiny Y/H2S2 tS XUS Grit Denv •0 6)516661' SXN. N-F TVD Rel. Rotary Tack ~/G t011 uve MSLI Maq Dee •20.36]' FS 5/5 /60 nT Wt0919320t/ Eas6ng IIUS Scaly Fav.099990i636H Plan L~1231P21 Srvy Dale. SeWem6er 13. 2005 ~ -5400 -5100 -4800 -4500 -4200 -3900 -3600 6300 6000 n n n Z ~ 5700 0 0 ch c m m U ~ 5400 v v v 5100 -5400 -5100 -4800 -4500 -4200 -3900 -3600 «< W Scale = 1(in):300(ft) E »> 6300 6000 5700 5400 5100 • • • BP Anticollision Report Company: BP AnlOC0 Field: Prudhoe Bay Reference Site: PB L Pad Reference Well: Plan L-123 (IV-F) Reference, Well'lsath: Plan L-123 NO GLOBAL SCAN: Using user defined selection & scan criteri j Interpolation Method: MD Interval: 20.00 ft ', Depth Range: 10608.00 to 12403.01 ft Maximum Radius:10000.00 ft Survey Program for Definitive Wellpath Date: 8/15/2005 Validated: No Planned From To Survey ft ft 28.50 1000.00 1000.00 10608.00 ', 10608.00 12403.01 Casing Points MD 'I'VD ft ft- - 3632.87 2622.60 10608.00 6397.23 12403.01 6422.60 Planned: Plan #1 V2 (0) Planned: Plan #1 V2 (0) Planned: Plan #2 V1 r~ L~ -Date: 9/13/2005 Time: 12:49:48 Page: 1 Co•ordinate(N~)Reference: Well: Plan L-123 (N-F), True North Vertical (TVD) Reference: L-125 Plan N-F 72.6 Db: Oracle -_ __- -,J -- - -- -_ __ i a Reference: Principal Plan ~ PLANNED PROGRAM Error Model: ISCWSA Ellipse ', Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing Version: 1 Toolcode ---- - - GYD-GC-SS MWD+IFR+MS MWD+IFR+MS Tool Name __ .__- Gyrodata gyro single shots MWD +IFR + Multi Station MWD +IFR + Multi Station I - Diameter -- - - -- - Hole Size Name in in 9.625 12.250 9 5/8" 7.000 8.750 7" 4.500 6.125 4 1 /2" Summary <---_w-=--____-- Offset ~~'ellpath -=-- ----------> Reference Offset Gtr-C'tr ~o-Go :1llowahlc °Site ~i'ell Wellpath r MD MD Distance ;1rea Deviation ft ft ft ft ft PB L Pad L-01 L-01 V14 12014.69 6640.00 8736.98 97.45 8639.53 PB L Pad L-02 L-02 V1 11050.00 6720.00 5211.32 110.37 5100.96 PB L Pad L-02 L-02A VS 11056.37 6020.00 5339.93 107.34 5232.59 PB L Pad L-02 L-02AP61 V2 11056.37 6020.00 5339.93 107.34 5232.59 PB L Pad L-02 L-02P61 V21 11050.00 6720.00 5211.32 110.39 5100.93 ', PB L Pad L-03 L-03 VS 12300.00 1800.00 8762.45 85.73 8676.72 PB L Pad L-101 L-101 V4 12300.09 1620.00 8577.56 87.17 8490.39 ', PB L Pad L-102 L-102 V2 PB L Pad L-102 L-102PB1 V10 ~ PB L Pad L-102 L-102PB2 V2 ~ PB L Pad ~ L-103 L-103 V23 I PB L Pad L-104 L-104 V7 PB L Pad ~ L-105 L-105 V4 , PB L Pad L-106 L-106 V14 PB L Pad L-107 L-107 V14 12254.34 1940.00 9029.67 87.31 8942.36 j PB L Pad L-108 L-108 V18 12194.17 2380.00 8671.23 88.39 8582.84 PB L Pad L-109 L-109 V12 11100.00 2500.00 8772.23 78.95 8693.28 PB L Pad L-110 L-110 V11 11062.01 2560.00 8718.94 89.35 8629.59 PB L Pad L-111 L-111 V24 11062.01 5860.00 7188.48 101.83 7086.65 PB L Pad L-112 L-112 V8 11062.01 3060.00 7283.73 89.34 7194.39 PB L Pad L-114 L-114 V15 11062.01 4300.00 6637.13 94.41 6542.72 ', PB L Pad L-114 L-114A V4 11062.01 3700.00 7213.36 91.31 7122.06 ~~ PB L Pad L-115 L-115 V7 12185.71 8435.00 3091.02 110.41 2980.61 ~~ PB L Pad L-116 L-116 V10 11862.45 6880.00 5919.46 98.13 5821.33 PB L Pad I L-117 L-117 V11 12296.84 1540.00 8567.76 84.73 8483.02 II PB L Pad L-118 L-118 V9 12300.12 1200.00 8846.67 83.64 8763.03 ~, PB L Pad L-119 L-119 V9 I~ PB L Pad L-120 L-120 V8 PB L Pad L-121 L-121 V14 11062.01 1940.00 8974.26 90.92 8883.34 PB L Pad L-121 L-121A V1 11062.01 1940.00 8974.26 90.92 8883.34 PB L Pad L-122 L-122 V5 11062.01 2600.00 7545.00 86.63 7458.38 PB L Pad L-124 L-124 V11 12140.42 10774.00 1430.04 123.90 1306.13 PB L Pad L-124 L-124P61 V5 12300.30 1760.00 8248.08 85.44 8162.64 PB L Pad L-124 L-124P62 V4 12253.44 10615.00 1552.15 127.05 1425.11 PB L Pad L-200 L-200 V7 PB L Pad L-200 L-200L1 V3 PB L Pad L-200 L-200L2 V6 PB L Pad L-200 Plan L-200L3 OA V1 Pla PB L Pad L-200 Plan L-200L3P61 OA V4 PB L Pad L-201 L-201 V6 PB L Pad L-201 L-201 L1 V9 Warning Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Out of range Out of range Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Pass: Major Ri k Out of range Out of range Out of range Out of range Out of range Out of range Out of range ` • BP Anticollision Report Gumpany: BP Amoco Date: 9/13/2005 Time: 12:49:48 Page: 2 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NN:) Reference: Well: Plan L-123 (N-F), True North REferenee'Wel1; Plan L-123 (N-F) Vertical ('I'C'U) Reference: L-125 Plan N-F 72.6 Reference Wellpatic Plan L-123 Summary <---___~~ -_ Offset Wellpath -- -----------> Reference Site Well Wellpath A4D ft PB L Pad L-201 L-201 L1 P61 V10 PB L Pad L-201 L-201 L2 V5 PB L Pad L-201 L-201 L3 V2 PB L Pad L-201 L-201 L3PB1 V6 PB L Pad L-201 L-201 P61 V12 PB L Pad L-201 L-201 PB2 V3 PB L Pad L-202 L-202 VS PB L Pad L-202 L-202L1 V7 PB L Pad L-202 L-202L2 V6 ', PB L Pad L-202 L-202L3 V6 PB L Pad L-210 L-210 V6 PB L Pad L-210 L-210P61 V8 Offset Ctr-Ctr No-Go MD Distance Arca ft ft ft Db: Oracle Allowable Deviation Warning ft PB L Pad L-211 L-211 V6 12299.28 2800.00 7273.36 85.00 7188.36 ~, PB L Pad L-211 L-211 P61 V6 11478.73 9840.00 2307.78 118.50 2189.28 ', PB L Pad L-212 L-212 V11 !, PB L Pad L-212 L-212P61 V9 !i PB L Pad L-212 L-212PB2 V2 PB L Pad L-214 L-214 V9 PB L Pad L-215 L-215P61 V2 Plan: Plan !i PB L Pad L-215 Plan L-215 V5 Plan: PI PB L Pad L-216 L-216 V6 PB L Pad L-218 L-218 V4 12297.41 2540.00 7608.57 86.66 7521.90 PB L Pad NWE1-01 L-100 V2 11062.01 1920.00 8465.87 92.90 8372.97 PB L Pad NWE1-01 NWE1-01 V5 11062.01 1920.00 8465.87 92.90 8372.97 ~~i PB L Pad Plan L-203 (N-O) Plan L-203 V6 Plan: PI ~ PB L Pad Plan L-213 (S-0) Plan L-213 V5 Plan: PI 12299.88 1000.00 9263.91 84.06 9179.84 PB L Pad Plan L-250 (NM-15) Plan L-250 V2 Plan: PI 12300.52 1020.00 8978.64 83.92 8894.72 ~ PB L Pad Plan L-250 (NM-15) Plan L-250L1 V9 Plan: 12300.52 1020.00 8978.64 83.98 8894.66 PB L Pad Plan L-250 (NM-15) Plan L-250L2 V6 Plan: 12300.52 1020.00 8978.64 84.03 8894.61 PB L Pad Plan L-50 (S-D) Plan L-50 V2 Plan: Pla 11109.56 6000.00 7452.45 101.01 7351.44 PB L Pad Plan L-51 (S-B) Plan L-51 V1 Plan: Pla 11910.88 7040.00 6477.35 108.42 6368.92 '~B L Pad Plan L-52 (S-E) Plan L-52 V1 Plan: Pla 12300.94 5060.00 6552.53 101.86 6450.67 Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Out of range Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk ' • Field: Prudhoe Bay Site: PB L Pad ' ' Well: Plan L-123 (N-F) Wellpath: Plan L-123 0 loo 0 loo t e~ Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100tt/in] i PLANT - ~15'00'08" GRID I I I I L-PAD I I ~-' I I I I I I I ^ N-L (NWE-1) I I I I I I I ~~ m0 I I I I I L-1111 ^ ' ^ N-A (NWE-2) I I I i ^ L-2181 I i L-114 ^ ^ L-124 I I L-50 ^ ^ L-112i I I L-02 I I L-121 ^ L-1231 I L-122 I I L-110 ^ ^ L-211 i I L-SI ^ ^ L-1151 I L-116 ^ ^ L-117 I I L-109 ^ ^ L-118 I L-SL ^ I I ^ L-250 I L-01 ^ ^ L-200 I L-107 ^ L-03 ^ ~'o ~z ^ L-202 ^ L-2121 I I I ^ L-SPARE I L-2131 ^ ~ ^ L-203 I I L-108i ^ ~ Y N ^ L-2161 ~ I L-1051 ^ ~ ^ L-103i I L-106 ^ ~ ` ^ L-2151 ~ I SLOT L-SU ^ ^ L-201 I I L-104 ^ ^ L-119i I I L-214i ^ ^ L-210i I I I L-102 ^ ~~ ^ L-120 I I I I I I I I I I ~ SKID SD6 SKID 513 I ,~ 34 .' 35~ ~IIN L-PAD ~ ~~ PROJECT T12N .AREA T11 N ?~ ;... w `, ~ VICINITY MAP N.T.S. LEGEND NOTES AS-STAKED CONDUCTOR 1. DATE OF SURVEY: NOVEMBER 18 & 19, 2005. 2. REFERENCE FIELD BOOK: W005-18 PAGES 50-56. ^ EXISTING CONDUCTOR 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD 27. 4. BASIS OF HORIZONTAL LOCATION IS OPERATOR MONUMENTS, WOA L-PAD MONUMENTATION. 5. BASIS OF ELEVATION IS OPERATOR MONUMENTS PER F.R. BELL & ASSOCIATES. ELEVATIONS ARE BPX MEAN SEA LEVEL DATUM. 6. MEAN PAD SCALE FACTOR IS 0.999907827. LOCATED WITHIN PROTRACTED SEC. 34, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GROUND SECTION N0. COORDINATES COORDINATE POSITION(DMS} POSITION(D.DD) ELEV. OFFSETS L-123i Y= 5,978,252.13 N 10,000.00 70'21'02.006° ' " 70.3505572' 47 3 2,532 FSL X= 583,069.26 E 5,075.00 149'19 32.017 149.3255603' ' 3,845 FEL DATE: it ® 'W IJIJOO ~O SCALE: ,~(~rjF~.(\I\~u(w~s~\u. assaa JOB NO: - 1°- lse' by WOA L-PAD AS-STAKED CONDUCTOR WELL L-123i SHEET: t aFt • ,/ by Brandon Peltier Operations Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 900 East Benson Boulevard Anchorage, AK 99519-6612 November 23, 2005 Bob Crandall Alaska Oil & Gas Conservation Commission 333 West 7~' Avenue, Ste. 100 Anchorage, AK 99501 (907) 279-1433 • ,~'~,~~ %: ~~i This document serves as an Area of Review (AOR) addendum to the Permit to Drill, submitted November 22, 2005, for well PBU L-1231. The investigation of well-bores lying within a'/4 mile radius of the horizontal path, from reservoir to TD, of L-1231 resulted in the following well: Northwest Eileen State No. 1 (NWEileen-1) API: 50-029-20013-00 PTD: 169-022 Status: Plugged & Abandoned Distance to L-1231: 400 ft The final P&A'd NWEileen-1 schematic is attached for reference. Please contact me if there are further issues or concerns. Regards, Brandon Peltier (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon.Peltier@bp. com a ~ • • All easing strings and tubing cut 5 feet below original Tundra grade level and a steel marker piste has been itutalied with the well [dcntifirauon ' M ~ ~ x^ Northwest Eileen . ~ ~ .`. ~ ml ormahon bcad «•cldcd to its surface 1 ~ ~`" ~ State NO l ~~ ~ ~ 30" 154# svuctural conductor at t 22', . , r ', ~ t' ~ ° ~`~''p' ~ y cemented «/?75 sks Fondu ' - Final Status: P&A'd ~ ~ '~ ~ .~: . , "~" ~~ ' 28-Mar-2UO4 ~~ CIIIP set a[ 186' ' '~ T' Casing punched at 181' - 184'. t ; 24 bbls 15 8 ppg Arcucset 1 cement d~splsced in ~ ' T' x 9 Sib" annulus and inside T' from i 84' to r surface b 7 bbls 1 S.8 ppg Arcucsct l ceme~u ` ?; ~"'F placed m upper 9 5/8" x 13 3/8" annulus with top FISH Shckhne tools left m Hole 8/30!87 / ~'0" 94t1 H-40 Qa 485', cemented to surface Depth to TOF 648', LOF 14 1 T Casing w/ 1026 sks Forxlue appears to be collapsed at 192' based on 02121!2004 slickline run Suspected casing collapse 192' - n4' 13 318'° DV collar at 1067' 133/8" 54.5# & 61 q 1-55 BTC Cmtd at 2102' 9 5/8" DV Collar at 2406' w/ 840 Sks Fondu around shoe, 870 Sks Fondu through DV Collar at 100T and 75 Sk Fondu Top lab Drilling Mud TOC in 7' x 9 518" annalus at -2no' 95/8" Test Perfora>;~pg Info: Test Pcrf Depth• Squeeze Ami TOC in 9 5/8" x 12 '/." 3852' - 3944' 370 Sx "G" OH annulus at - 3330' 4095' - 4 ] 31' 920 Sx "G" 4240' - 4244' 90 5x "G" 4369' - 4373' 95 Sx "G" 4368' - 4377 5' 492 Sx "G" Attachment I 9 518" 40 & 43.5# N-80 and P-1 ] 0 casing set at 5602' Stage cemented w! 550 sks "G" around shoe and 400 sks Fondu Neat through DV collar at 240b' 7" DV Collar at 5786' / 1 ~ ~ ~ ~ (htginal PBTD at 5786' TOC m T' x 8 %" OH at -6945' Test Perfs: 8960' - 8982' 7"Float collar at 9703' 7" 26 & 29k 1-55, N-80 and P-1 IO casing set at 9789'. ''l First stage cemented w/ 1450 sks around shoe Second stage through DV collar at 578b' w/ 400 sx Ftxdu and TD at 9997 MD & TVD ------- -4 780 sks "G" cement Northwest Eileen St No 1 Fairweather EBcP Servkes, Inc Rev 2 0 DHV 5110104 Draw' Not to Scak Prepared By: Fairweather E&P Services, Inc. Page b of h • • TERRIE L RUBBLE ss-sirzaz 240 BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 DATE ~~_~ PAY TO THE ~ ~ I ~~ r'"171 ORDER OF l•(,~ ~1~.~ ,~s First National Bank Alaska Anchorage; AK 99507 MEMO ~~I~`,~ c ~: ~ 25 200060:99 14~~~6 2 27~~~ L S 56u' 0 240 e • • OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~ ! ' ~Z PTD#~ Ste- ~ ~`7' CHECK WHAT I ADD-ONS APPLIES ~ (OPTIONS MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well , Permit No, API No. Production should continue to be reported as a function of .the original API number stated above. all 005(f) AC 25 , . PILOT HOLE ~ In accordance with 20 A records, data and logs acquired for the pilot ~~ i hole must be clearly differentiated in both ~ (name on permit plus PH) name and API number (50 data and logs acquired ~ d I s, 70/80) from recor for well (name on permit}. I ct to full b d ~ je su SPACIl~TG ~ The permit is approve EXCEPTION ~ compliance with 20 AAC 25.055. Approval to i ent contin t i f g s ec { ~ perforate and produce_/in ~ ;upon issuance of a conservation order exception. cin g approving a spa ~ i (Company Name) assumes the liability of any protest to the spacing j exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE ~ Commission must be in no greater than 30' sample intervals from below the permafrost ~ or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 Cljody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, BOREALIS OIL - 640130 __^_ _ Well Name: PRUDHOE BAY UN BORE L-123 _ __Program DEV _~ Well bore leg ^ PTD#:2051940 Company BP EXPLORATION (ALASKR) INC _ Initial Class(Type DEV! 1WINJ GeoArea Unit _____ On/off Shore On Annular Disposal ^ Administration !1 Permit fee attached Yes 2 Lease number appropriate- _ - - - Yes 3 Uniquewell_nameandnumber_____________________________ Yes__--_-___-__--___-___-__, ------------------------- Well located in a_de_finedpool. - - - - - - - - Yes - 5 -Weil locatedp[operdistancefromdrillingunit_boundary--__-__---------------- Yes___-_____-___--__-----___--__--__-- 6 Well located proper distance_f[om other wells- . _ Yes -------------------- ----------------------- ---------------- - 7 Sufficientacreageavail_ablein_drillingun~________________________________ ---- -------- ---- Yes___-_________ 8 If deviated,is_wellboreplat_included___ _____---------------------- -- Yes--_______________- - 9 Ope[atoron/y affected party_ - - , - _ _ _ _ _ _ _ - . _ ye$ - 10 Operatorhas-appropriate_bondinforce______________________________ __ Yes-__--__-___-__..__-_ 11 PeCmitcan be issued without conservation order_ _ - - _ - _ _ Yes - - - _ - - - _ - Appr Date 12 Permit can be issued without administrative-approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ - _ - - - _ - - _ - - _ _ _ _ _ - - - - - _ ------------------------------ - - RPC 11/28!2005 13 Can permit be approved before 15-day wait -- - ------- Yes 14 Well located within area and strata authorized by-Injection Order # (put-10# in_comments)-(For_ Yes _ _ _ _ _ _ - AIQ22_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - -- 15 All wells within 1/4_mile area of review ident~ed (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - -The-only well in the AOR for PBU t.-123i is the NW Eileen-1-exploratory well ~p&a'd)-RPC _ _ _ _ - _ _ _ _ - - - _ _ 16 Pre-produced injector; duration_of pre-production less than 3 months (For service well only) NA- - - i ACMP_Finding of Consistency_has been issued_forthis project, - - - - _ _ NA - . - , Engineering 18 Conductor string-provided__________________________________ ____ __Yes__- __--20".@109'.__________,-_. 19 Surface casing_protecfs all known USDWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - 20 CMT_vol adequate_to circulate on conductor-& surf_csg - Yes - _ Adequate excess, - - - - - 21 CMT-vol adequate_to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ 22 CMT_will coverall know_n_productiye horizon_s_ Yes - - . - - - - - 23 Casing designsadegoateforC,_T,B&_permafrost_________--.__-__ ____-Yes__ __________________ ' 24 Adequate tankage-or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - - _ _ Yes - - _ _ - _ Nabors_9ES, 25 If a_re-drill, has_a_ 10-403 for abandonment been approved _ - - - - NA_ New well 26 Adequatevaellboreseparationproposed__________________________ ____ __Yes____ ___-____-_ 27 If divertertequired,doel it meet regu_lations_ _ _ _ - _ - _ - _ - - - _ - Yes - - Appr Date 28 Drilling fluid-program schematic & equip list adequake_ _ - - - _ - - _ - . - - Yes - - _ Max MW 10,8_ppg.- - _ _ - - - _ , WGA 11/29120051 29 BOPEs,dotheymeet-regulation- __--______------- -------- Yes_-_ _--__----_-____ 30 BOPE_press rating appropriate; test to_(put psig in comments)- - - Yes . - - Test to 4000 psi. MSP 2698 si.- .. _ p 31 Choke_manifoldcompNeswlAPI-RP-53 (May84)_ _ - - - - - - - - - - - - - - - - - - - - - - Yes X 32 Work v~nll occur without operation shutdown_ - - Yes - - 33 Is presence-of H2S gas_probable - - - - No Notan H2S pad. - - - - - - - - ~ - . - ~ 34 Mechanical_condition of wells w(thin AOR verified ~Fors_ervice well onlya Yes One P&A'd well_within AOR. Geology 35 Permit_can be (slued w/o hydrogen, sulfide measures - - - - No- - 36 Dafa_presented on_ pote_ntial overpressure zones - - . - _ _ _ - _ - NA Appr Date 37 Seismic analysis of shallow gas_zones - - NA RP 11128!2005 38 Seabed condition suruey_(if off-share) NA X 39 Contact name/phone for weekly-progress reports [exploratory only] _ - - - - _ NA- - _ _ - Geologic Commissioner: Engineering Public Date: Commissioner: Date r Date •