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Home My WebLink About201-140CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Request: UNDER EVALUATION: Injector L-115 (PTD #2011400) TxIA communication Date:Wednesday, December 3, 2025 9:41:22 AM Attachments:L-115.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, December 3, 2025 9:27 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Request: UNDER EVALUATION: Injector L-115 (PTD #2011400) TxIA communication Mr. Wallace, Injector L-115 (PTD # 2011400) exhibited IA re-pressurization during the recent monitoring period. The well passed a PPPOT-T to 5,000 psi on 11/25/25. A slickline job has been planned to replace the existing DGLVs with extended packing DGLVs, the slickline is unit is scheduled to perform that work today. Tomorrow is the last day of the initial 28-day Under Evaluation period. With your approval, Hilcorp would like to put the well back on injection for another 28-day monitoring period after slickline performs the DGLV work in an attempt resolve the TxIA communication before applying for an AA. Plan Forward: 1. Slickline: Set extended packing DGLVs 2. Well Integrity: Monitor for IA re-pressurization 3. Well Integrity (pending): Apply for AA if IA re-pressurization still exists Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 6, 2025 9:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-115 (PTD #2011400) possible TxIA communication Mr. Wallace, While reviewing the TIO pressure plots for injector L-115 (PTD # 2011400) it was discovered to have a slow IA re-pressurization trend that is not associated with thermal or rate increases after a pressure bleed on 09/19/25. The well is due for it’s 4-year AOGCC MIT-IA in November and was performed on 11/05/25, the test passed. It will now be classified as UNDER EVALUATION for further monitoring. Plan Forward: 1. Well Integrity: Monitor for re-pressurization 2. Well Integrity (pending): Apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MILL -IN •2V 9V a1W m aro] 240 IW dWJ qp 2]W 3W] dWJ 1% 2W] y0 >TA 31W 21W A 3m I.ID] S10 }pq iW 2Tp 1W 2W] 2W] ip 2NJ IA 21W 19g iL B 2W] ib 6 t.eW 1W] ID i.ml IW iW] 110 tqW tW tA] W Im ttW W iWo m � Wo W mo W wo Wo M aoo A w m m im IW 1.1V 1. t.l. 1. 1o'tl'6 11. lln. ll Y. 11(N15 12W15 IbIV6 1]/11I15 1MY15 1LJN5 no PIN �TVbinp —On ■ a OW ♦ Op + UW"Eow ♦ Mx EwI 7—Men. IA —� Men. OA Men. 00A t Men. OWA YMf TREE= 4-1116" CNV VW3-LHEAD= FMC SAFETY NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= CNV SH 3000 L-115 WHEN ON M 1. WELL EQUIRES A HEN ON MI.GLMS@STA#1R&#2ARE3-112SXl-1/2"MMG- KB.AEV _ 7NA W'S, WHICH AREWATERFLOOD MANDRELS. BF. ELEV = NA KOP= 1350' Max Angle = 44" @ 4562' 1011' 9-5/8" TAM PORT COLLAR Datum MD= 8039' DatumTVD= 6600'SS 2�p9� 4-1/2"HESXNP,11)=3.813" 9-5/8" CSG, 40#, L-80, D = 8.835" 273W Minimum ID = 2.813" @ 7547' 3-1/2" HES X NIPPLE 4-12" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 4426' 312" TBG, 92#, L-80, .0087 bpf, D = 2.992" GAS LIFT MANDRELS STI MD I TVD I DEVI TYPE I VLV I LATCH FORT DATE 4 3 389E 4248 1 3420 3690 41 39 KBG-2 KBG-2 DMY DMY I BK-5 BK-5 0 0 06/07/02 06/07/02 WATERFLOOD MANDRELS ISTI MD I TVD DEV I TYPE I VLV I LATCH PORT DATE 2 1 4507 4575 1 3881 3930 44 44 MMG-W MMG-W I RKED I RKED I RKP I RKP 0 0 1 02/20/02 02/2a02 1 7" X4-1/2" BKR PREMIER PKR, ID = 3.875- 4430' — 4-12" X 3-1/2" XO, D = 2.992" SCHRADER-ORION UNAUTHORIZED FOR PWI OR WAG INJECTION 756W H 7" X 4-1/2" BKR S-3 PKR D = 3.875" 3-12" TBG, 92#, L-80, .0087 bpf, D = 2.992" 7617' 7586' �� 3-12" HES X NP, D= 2.813" 7606' 3-12" HES X NP, D = 2.813" PERFORATION SLAMARY REF LOG: TCP PEW 7618' 3-12" WLEG, ID = 2.875" ANGLE AT TOP PHRF: 43" @ 4820' ELMD TT NOT LOGGED Note: Refer to Production 1313 for historical pert data SIZE SPF 14ERVAL Opn/Sqz DATE 4-5/8" 6 4820 - 4866 O 02/25102 4-518" 6 4978 - 5025 O 02/2a02 4-5/8" 6 5069 - 5110 O 02/20102 7682' 7" 26# X 21' PUP JT W/ RA TAG 4-518" 6 5206-5218 O 02/20/02 KUPARUK- BOREALIS 4-s/a" s szos-szla o ovzaoz 4-518" 6 5287-5316 O 02/20/02 AUTHORIZED FOR WAG INJECTION 2-12" 6 7791 - 7830 O 03/18/02 8151' 7" 26# X 20' PUP Ji W/ RA TAG 2-12" 6 7844 - 7854 O 03/18/02 2-12" 6 7865 - 7876 O 03/18/02 I�TD 8270' 7" CSG, 26#, L-80, .0383 bpf, D = 6.276" 8417' DATE REV BY COMMENTS DATE REV BY COMMENTS 0220102 ORIGINAL COMPLETION 02/15111 MB/JMD ADDED SSSV SAFETY NOTE 03102N2 CWTP CORRECTIONS 01/17/12 TMWJMD ADDED HiSSAFETY NOTE 03M9)02 RL/ih GLV CORRECTIONS 0107119 KP/JMD TREE CJO 03/18N2 CV4SAh ADD PERFS 06/07102 RL/1h GLV IPDATE 04/08N3 DRS/TP TVD/MD CORRECTIONS BOREALIS LINT WELL: L-115 PERMIT No: '2011400 API No: 50-029-23035-00 T12N, R11E, 2543' NSL & 3801' WEL Hikorp North Slope, LLC uhN Ln6 4= YO IW 4.. xWg xWg m xmo xWg � xWg zW xwo xWo � >mg zW Ugg zWg M Wg zwg Wg zgg 1° Z. zaaM* Im e zlW IW� 3 imo 10= 8 .sW W I m] m tADD 1� I10 1M] IW 1S] W dL ttW W xmg m °00 W mo W wo w wo W m W d10 Ig tW WUY6 W'ID,5 W 70 MQu2S Iwo Ignnb IVIy6 VQ225 I&M IAWS 1.m 11,IM n1N15 In 6 no clw +Tubing On ■ Winn] + OW b.. + but owr ♦ VMx E", y—M.n. IA —� M.n. on M.n. COA M.n. "n �— Men.. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, December 11, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-115 PRUDHOE BAY UN BORE L-115 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/11/2025 L-115 50-029-23035-00-00 201-140-0 G SPT 3860 2011400 1500 1555 1557 1554 1552 0 0 0 0 4YRTST P Guy Cook 11/5/2025 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE L-115 Inspection Date: Tubing OA Packer Depth 545 2287 2179 2150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC251105135743 BBL Pumped:1.5 BBL Returned:1.4 Thursday, December 11, 2025 Page 1 of 1           CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Request: UNDER EVALUATION: Injector L-115 (PTD #2011400) TxIA communication Date:Wednesday, December 3, 2025 9:41:34 AM From: Wallace, Chris D (OGC) Sent: Wednesday, December 3, 2025 9:41 AM To: 'PB Wells Integrity' <PBWellsIntegrity@hilcorp.com> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: RE: Request: UNDER EVALUATION: Injector L-115 (PTD #2011400) TxIA communication Andy, Your request for an additional 28 days injection monitoring is approved. Thanks and Regards, Chris Wallace, Sr. Petroleum Engineer, Alaska Oil and Gas Conservation Commission, 333 West 7th Avenue, Anchorage, AK 99501, (907) 793-1250 (phone), (907) 276-7542 (fax), chris.wallace@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, December 3, 2025 9:27 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: Request: UNDER EVALUATION: Injector L-115 (PTD #2011400) TxIA communication Mr. Wallace, Injector L-115 (PTD # 2011400) exhibited IA re-pressurization during the recent monitoring period. The well passed a PPPOT-T to 5,000 psi on 11/25/25. A slickline job has been planned to replace the existing DGLVs with extended packing DGLVs, the slickline is unit is scheduled to perform that work today. Tomorrow is the last day of the initial 28-day Under Evaluation period. With your approval, Hilcorp would like to put the well back on injection for another 28-day monitoring period after slickline performs the DGLV work in an attempt resolve the TxIA communication before applying for an AA. Plan Forward: 1. Slickline: Set extended packing DGLVs 2. Well Integrity: Monitor for IA re-pressurization 3. Well Integrity (pending): Apply for AA if IA re-pressurization still exists Please respond at your earliest convenience. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 6, 2025 9:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-115 (PTD #2011400) possible TxIA communication Mr. Wallace, While reviewing the TIO pressure plots for injector L-115 (PTD # 2011400) it was discovered to have a slow IA re-pressurization trend that is not associated with thermal or rate increases after a pressure bleed on 09/19/25. The well is due for it’s 4-year AOGCC MIT-IA in November and was performed on 11/05/25, the test passed. It will now be classified as UNDER EVALUATION for further monitoring. Plan Forward: 1. Well Integrity: Monitor for re-pressurization 2. Well Integrity (pending): Apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of 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, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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-115 (PTD #2011400) possible TxIA communication Date:Thursday, November 6, 2025 9:40:59 AM Attachments:L-115.pdf From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, November 6, 2025 9:34 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector L-115 (PTD #2011400) possible TxIA communication Mr. Wallace, While reviewing the TIO pressure plots for injector L-115 (PTD # 2011400) it was discovered to have a slow IA re-pressurization trend that is not associated with thermal or rate increases after a pressure bleed on 09/19/25. The well is due for it’s 4-year AOGCC MIT-IA in November and was performed on 11/05/25, the test passed. It will now be classified as UNDER EVALUATION for further monitoring. Plan Forward: 1. Well Integrity: Monitor for re-pressurization 2. Well Integrity (pending): Apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307) 399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of 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= 4-1116" CNV VW3-LHEAD= FMC SAFETY NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= CNV SH 3000 L-115 WHEN ON M 1. WELL EQUIRES A HEN ON MI.GLMS@STA#1R&#2ARE3-112SXl-1/2"MMG- KB.AEV _ 7NA W'S, WHICH AREWATERFLOOD MANDRELS. BF. ELEV = NA KOP= 1350' Max Angle = 44" @ 4562' 1011' 9-5/8" TAM PORT COLLAR Datum MD= 8039' DatumTVD= 6600'SS 2�p9� 4-1/2"HESXNP,11)=3.813" 9-5/8" CSG, 40#, L-80, D = 8.835" 273W Minimum ID = 2.813" @ 7547' 3-1/2" HES X NIPPLE 4-12" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 4426' 312" TBG, 92#, L-80, .0087 bpf, D = 2.992" GAS LIFT MANDRELS STI MD I TVD I DEVI TYPE I VLV I LATCH FORT DATE 4 3 389E 4248 1 3420 3690 41 39 KBG-2 KBG-2 DMY DMY I BK-5 BK-5 0 0 06/07/02 06/07/02 WATERFLOOD MANDRELS ISTI MD I TVD DEV I TYPE I VLV I LATCH PORT DATE 2 1 4507 4575 1 3881 3930 44 44 MMG-W MMG-W I RKED I RKED I RKP I RKP 0 0 1 02/20/02 02/2a02 1 7" X4-1/2" BKR PREMIER PKR, ID = 3.875- 4430' — 4-12" X 3-1/2" XO, D = 2.992" SCHRADER-ORION UNAUTHORIZED FOR PWI OR WAG INJECTION 756W H 7" X 4-1/2" BKR S-3 PKR D = 3.875" 3-12" TBG, 92#, L-80, .0087 bpf, D = 2.992" 7617' 7586' �� 3-12" HES X NP, D= 2.813" 7606' 3-12" HES X NP, D = 2.813" PERFORATION SLAMARY REF LOG: TCP PEW 7618' 3-12" WLEG, ID = 2.875" ANGLE AT TOP PHRF: 43" @ 4820' ELMD TT NOT LOGGED Note: Refer to Production 1313 for historical pert data SIZE SPF 14ERVAL Opn/Sqz DATE 4-5/8" 6 4820 - 4866 O 02/25102 4-518" 6 4978 - 5025 O 02/2a02 4-5/8" 6 5069 - 5110 O 02/20102 7682' 7" 26# X 21' PUP JT W/ RA TAG 4-518" 6 5206-5218 O 02/20/02 KUPARUK- BOREALIS 4-s/a" s szos-szla o ovzaoz 4-518" 6 5287-5316 O 02/20/02 AUTHORIZED FOR WAG INJECTION 2-12" 6 7791 - 7830 O 03/18/02 8151' 7" 26# X 20' PUP Ji W/ RA TAG 2-12" 6 7844 - 7854 O 03/18/02 2-12" 6 7865 - 7876 O 03/18/02 I�TD 8270' 7" CSG, 26#, L-80, .0383 bpf, D = 6.276" 8417' DATE REV BY COMMENTS DATE REV BY COMMENTS 0220102 ORIGINAL COMPLETION 02/15111 MB/JMD ADDED SSSV SAFETY NOTE 03102N2 CWTP CORRECTIONS 01/17/12 TMWJMD ADDED HiSSAFETY NOTE 03M9)02 RL/ih GLV CORRECTIONS 0107119 KP/JMD TREE CJO 03/18N2 CV4SAh ADD PERFS 06/07102 RL/1h GLV IPDATE 04/08N3 DRS/TP TVD/MD CORRECTIONS BOREALIS LINT WELL: L-115 PERMIT No: '2011400 API No: 50-029-23035-00 T12N, R11E, 2543' NSL & 3801' WEL Hikorp North Slope, LLC WN L-is no clm +Tubing —On ■ el..e + OW.bi. + Nal Oger ♦ VMx Evl y—Man. IA —� Man. Oa M.n.00A Man. "A �— Men. VAT Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 6/18/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250618 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# AN 07RD2 50733200120200 195113 6/1/2025 AK E-LINE LDL AN 24RD 50733202850100 207170 6/1/2025 AK E-LINE LDL BRU 221-24 50283202020000 225027 5/29/2025 AK E-LINE CBL KALOTSA 10 50133207320000 224147 5/21/2025 AK E-LINE Perf KALOTSA 2 50133206590000 216155 5/25/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/27/2025 AK E-LINE Perf PAXTON 11 50133207040000 221114 5/26/2025 AK E-LINE Perf PBU 06-12C 50029204560300 225022 5/17/2025 HALLIBURTON RBT-COILFLAG PBU 15-32C 50029224620300 217104 5/27/2025 HALLIBURTON RBT PBU D-01B 50029200540200 224155 5/18/2025 BAKER MRPM PBU D-01B 50029200540200 224155 5/18/2025 HALLIBURTON RBT-COILFLAG PBU H-18A 50029208800100 224011 5/14/2025 BAKER MRPM PBU H-18A 50029208800100 224011 5/14/2025 HALLIBURTON RBT-COILFLAG PBU L-109 50029230460000 201201 5/24/2025 HALLIBURTON IPROF PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF PBU L-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF PBU N-07B 50029201370200 223122 6/7/2025 HALLIBURTON RBT PBU S-100A 50029229620100 224083 5/26/2025 HALLIBURTON PPROF-LDL PBU Z-34 50029234690000 212061 5/17/2025 HALLIBURTON IPROF-LDL Please include current contact information if different from above. T40566 T40567 T40568 T40569 T40570 T40571 T40571 T40572 T40573 T40574 T40574 T40575 T40575 T40576 T40577 T40578 T40579 T40580 T40581 PBU L-115 50029230350000 201140 5/19/2025 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.18 12:03:53 -08'00' MEMORANDUM TO: Jim Regg r 7 P.I. Supervisor�� FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 30, 2021 SUBJECT: Mechanical Integrity Tests Hileorp North Slope, LLC L-115 PRUDHOE BAY UN BORE L-115 Sre: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UN BORE L-115 API Well Number 50-029-23035-00-00 Inspector Name: Bob Noble Permit Number: 201-140-0 Inspection Date: 11/12/2021 ' Insp Num: mitRCN21 1112163301 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-115 Type Inj W TVD 3860 Tubing 1876 1876 . 1875 - 1875 - PTD 2011400 Type Test SPT Test psi 1500 IA 752 2660 - 2561 2551 - BBL Pumped: 1.6 BBL Returned: 1.3 - OA 52 52 52 - 52 - Interval 4YRTST p/F P Notes: Thursday, December 30, 2021 Page I of 1 MEMORANDUM TO: Jim Regg ---' P.I. Supervisor�Z] I i�) Z'( FROM: Bob Noble Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, November 24, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC L-115 PRUDHOE BAY UN BORE L-115 Src: Inspector Reviewed By: n P.I. Supry Comm Well Name PRUDHOE BAY UN BORE L-115 API Well Number 50-029-23035-00-00 Inspector Name: Bob Noble Permit Number: 201-140-0 Inspection Date: 11/12/2021 Insp Num: mitRCN211112163301 Rel Insp Num: Wednesday, November 24, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L -us Type Inj �' TVD — -- 3860 i Tubing 1116 IsI6 - —87 --- 1875 is�s PTD 2011400 :Type Test, SPT Test psi YP P 1500 - IA � 752 2660 � - — 2561 i 2551 BBL Pumped: p Interval 1-6 BBL Returned 4YRTST WIT is A 52 O 52 I i _ --L - I P ✓' 52 52 -- — - — Notes: Wednesday, November 24, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,November 08,2017 TO: Jim Regg P.I.Supervisor fN e )( pI 17 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. L-115 FROM: Brian Bixby PRUDHOE BAY UN BORE L-115 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry--WOK-- NON-CONFIDENTIAL NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-115 API Well Number 50-029-23035-00-00 Inspector Name: Brian Bixby Permit Number: 201-140-0 Inspection Date: 11/8/2017 Insp Num: mitBDB171108133426 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well L-115 Te In' 1 W TVD3860 i Tubing 2181 2179 - 2186 2192 PTD 2011400TypeTestSPT Testpsi 1500 IA 416 coos 'F 2915 2904 BBL Pumped: 1.6 ' BBL Returned: 1.6 OA 118 - 118 - 118 ' 118 - Interval 4YRTST P/F P Notes: %moo FEB 2 0 Wednesday,November 08,2017 Page 1 of 1 MEMORANDUM To~ Jim Regg 1~~~ ~ZI ~G P.I. Supervisor ~ 1 FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 03, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-115 PRUDHOE BAY iJN BORE L-] 15 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: PRUDHOE BAY UN BORE L-115 API Well Number: 50-029-23035-00-00 Inspector Name: Bob Noble Insp Num: mitRCN091202064122 permit Number: 201-140-0 Inspection Date: 11/30/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --~_ ~ --~- ~ - _-- ~- 420 4010 3960 3950 ~ Well I L-t is iT~pe In . ~' ~ TVDp ~i 3s6o _~ IA 1 ~ i ~_ --- ---- --- P.T D, ~-- --r- r-- - zoilaoo ITYpeTest SPT'~ Test st aolo pp ~ 160 ~ 160 16o i t6o -- -- -- --- ~_ _ ----- --1--- --_ -~ --1------ -~- --- ---- ~- +-- Interval 4~TST ~ P/F P ~ Tubing I 1600 ~ 1600 ~ 1600 , 1600 -- = ----- -~---- -~_ _----! -1----- Notes: , ~~~. Thursday, December 03, 2009 Page 1 of 1 ~ BP Exploration (Alaskaj Inc. Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August i 4, 2009 ~: ~~ ~ ,~ ~~~~ ~d~r~g~..~~ , - .y-~:..~7~ u y u*-'~` 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, C~ bp ~~~~~~~~ 0 C T 0 5 2009 ~~asVca pii ~ Gas Cons. Gomrni~~ion Anchoiage ~~~^ ~ ~ (_,- ~ ~ ~' Enciosed please find multiple copies of a spreadsheet with a list of we!!s 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. Surface Casing by Conductor Mnulus Cement, Corrosion inhibitor, Seala~t Top-off Report of Sundry Operations (10-404) Date L pad 8/13/2009 Well Name PTD # API # IniGal 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 6127I2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 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 102 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6(2~09 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 1-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L.-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 1-112 2022290 50029231290000 NA 5.5 NA 51 6J27I2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27l2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 S/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA t.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 102 5/6/2009 1.-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 ~-216 2040650 500292320600~0 NA 1.3 NA 11.9 6f2612009 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 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 162 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, November 30,2005 §{,LBJEÇI: _M¡:cl!anis:a,l IntegriJy Tests. BP EXPLORATION (ALASKA) INC L-115 PRUDHOE BAY UN BORE L-115 '0 \/ \~ ~D TO: ~~~S~::;iSO"- ~fVI IZ(110)'- Src: Inspector Reviewed By: P.I. Suprv ..JfS.£- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UN BOREL-lIS API Well Number 50-029-23035-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS051I29160417 Permit Number: 201-140-0 Inspection Date: 11/28/2005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-1l5 ¡Type Inj. ! w I TVD I 3860 I IA 1500 I 4000 3920 I 3920 I I ¡ P.T. 2011400 ITypeTest I SPT I Test psi I 965 lOA 300 ¡ 300 300 300 ¡ ¡ Interval OTHER P/F P Tubing 1600 I 1600 1600 1600 I I Notes MIT performed pre-wag swap. :~~^MN,f;:" ~~ Wednesday, November 30, 2005 Page I of 1 ~~ ~~~lii DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 \;r~ 7 ð 'ìJ.-).Jj{j ( Permit to Dri 2011400 Well Name/No. PRUDHOE BAY UN BORE L-115 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23035-00-00 MD 8435 TVD 7014 ~ Completion Date 2/20/2002 .-- Completion Status 1-01L Current Status WAGIN ~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Nõ y /A.-, DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint' Well Log Information: J Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Na. Scale Media No Start Stop CH Received Comments Æ6 C <::.-11)436J\!ªûf¡ 3 100 8435 Open 11/13/2001 Well Cores/Samples Information Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? y~ Daily History Received? ~ Chips Received? ~ Formation Tops Y N Analysis ~ Received? ì - Comments: Compliance Reviewed By: Date: ~ ',~ ~ '-< . ~-, -~ -. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Pre-Prod Converted to WAG Ini 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Operation shutdown_ Pull tubing 2736' FNL, 3798' FEL, Sec. 34, T12N, R11E, UM At top of productive interval 4801' FNL, 521' FEL, Sec. 28, T12N, R11 E, UM At effective depth 4573' FNL, 668' FELt Sec. 28, T12N, R11 E, UM At total depth 4504' FNL, 713' FEL, Sec. 28, T12N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Stimulate _ Alter casing _ 5. Type of Well: Development _ ExplDratory_ Stratigraphic_ Service_X (asp's 583116, 5978264) (asp's 581072, 5981457) (asp's 580922, 5981683) (asp's 580876,5981752) 8435 feet 7014 feet Plugs (measured) Effective depth: measured 8270 feet Junk (measured) true vertical 6871 feet Casing Length Size Cemented Conductor 80' 20" 260 sx Arctic Set (Approx Surface 2709' 9-5/8" 484 sx AS Lite, 249 sx Class 'G' Production 8389' 7" 210 sx LiteCrete, 345 sx LARC Plugging _ Perforate _ Repair well Other X 6. Datum elevation (DFor KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-115 9. Permit number / approval number 201-140/302-180 10. API number 50-029-23035-00 11. Field / Pool Prudhoe Bay Field 1 Borai{.Þ6õ11:' I \ I a: r\ , , "-...... La» II a... IJ" JUL 3 2002 Alaska Oil & Gas Cons. Commisslo Anchorage Measured Depth 107' 2735' True Vertical Depth 107' 2735' 8417' 6925' Perforation depth: measured Open Perfs 4820'-4866',4978'-5025',5069'-5110', 5132'-5147', 5206'-5218', 5287'-5316', 7791 '-7830', 7844'-7854', 7865'-7876' true vertical Open Perfs 4185'-4219', 4302'-4336', 4369'-4400', 4416'-4427', 4472'-4481', 4533'-4555', 6474'-6505',6517'-6525',6534'-6543' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 4428'.4-1/2" XO 3-1/2" TBG @ 4428'.3-1/2" 9.2# L-80 TBG @ 7558' 3-1/2" XO 4-1/2" TBG @ 7558'.4-1/2" 12.6# L-80 TBG @ 7565'.4-1/2" XO 3-1/2"TBG @ 7565'. 3-1/2" 9.2# L-80 TBG @ 7618'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4372' MD. 7" x 4-1/2" Baker S-3 Packer @ 7560' MD. 4-1/2" HES 'X' Nipple @ 2093'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Met Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 06/28/2002 2306 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations Oil Gas Suspended 17. I hereby certify that the foregoing ~ tl! and correct to the best of my knowledge. A~· ~ J~ Title: TechnicalAssistant DeWayne ::;,~ Form 10-404 Rev 06/15/88 . RBOMS 8Ft 1810 Service WAG Iniector Date Julv 02. 2002 Prepared by DeWayne R. Schnorr 564-5174 JUL 8 2002 .... SUBMIT IN DUPLICATE ¡-..,. .~ L-115 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/06/2002 FRACTURING: GAS LIFT--TO DUMMY VALVES; STATIC BOTTOM HOLE PRESSURE SURVEY 06/06/2002 FRACTURING: HOT OIL TREATMENT; MIT-IA 06/07/2002 FRACTURING: GAS LIFT--TO DUMMY VALVES; HOT OIL TREATMENT 06/07/2002 FRACTURING: MIT-IA 06/08/2002 FRACTURING: MIT-IA 06/09/2002 FRACTURING: FRACTURING 06/11/2002 ANN-COMM (UIC PROGRAM): AC-MITIA 06/13/2002 ANN-COMM (UIC PROGRAM): AC-MITIA 06/19/2002 ANN-COMM (UIC PROGRAM): AC-BLEED EVENT SUMMARY 06/06/02 (WELL SHUT IN ON ARRIVAL) DIT W/2.48" CENT, TEL,SB, TAG TD @ 8183' CORR TO MD. RAN SBHPS WITH PETREDAT. RAN INTO PARAFFIN WHILE RUNNING CATCHER SUB. CALLED OUT LITTLE RED AND PUMPED HOT DIESEL TO CLEAN UP TUBING - JOB IN PROGRESS 06/06/02 HOT OIL TBG WITH 30 BBLS OF 190* F DIESEL. 06/07/02 HOT OILED TUBING, SET CATCHER SUB, PULLED 16/64" OGLV (BK) FROM GLM #3 - PULLED LGLV FROM STA #416/64' PORTS 1750 TRO BK LATCH, SET DGLV BK LATCH STA#4 AND STA #3. JOB IN PROGRESS. 06/07/02 LOAD IA WITH 80 BBLS OF DIESEL. MIT IA TO 4000 PSI. 06/08/02 MIT/IA TO 4000 PSI PASSED - PULLED CATCHER SUB. RDMO. «< WELL LEFT SHUT-IN AND NOTIFY DSO »>. 06/09/02 MIRU DOWELL FRAC EQUIPMENT. SET TREE-SAVER. PT TREATING LINE TO 8500 PSI (GOOD). RU LRS TO IA. PT LINE AND FUNCTION TEST PRV SKID. PUMP HPBD PER PROGRAM. OBSERVE EXCELLENT DEIVERSION WITH ROCK SALT. SCOPE OUT TREE-SAVER (FULL RECOVERY OF CUPS). RDMO. 06/10/02 STARTED WATER INJECTION. 06/11/02 MIT-IA PASSED TO 3000 PSI. (Pre-AOGCC) 06/13/02 MITIA PASSED TO 2480 PSI. (AOGCC Witnessed) 06/19/02 BLEED IA TO 500 PSI, MONTOR BU. (Requested by AOGCC) FLUIDS PUMPED BBLS 1 PRESSURE TEST LUBRICATOR W/1 BBL OF DIESEL, Page 1 ~ ~ L-115 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 160 DIESEL 70 GELLED DIESEL 1768 SLICK WATER (W/2% EQUIVALENT KCL ---> L-64). ROCK SAL T (2100# TOTAL) 16x20 CARBO LITE (7040# TOTAL) 1999 TOTAL Page 2 r-... ~ lREE = 4-1/16" CIW WELLHEAD = FIv'C AClUATOR= NA KB. 8..EV = 77.1' L-115 SAFElY NOTES: GLM'S @ STA #1 & #2 ARE 3-1/2" X 1-1/2" Mfv'G-WS, WHCHARE WATffiFLOOD MANDR8..S. BF. 8..EV = NA KOP= 1350' : -4 1011' H 9-518" TAM PORT COlLAR I Wax Angle = 44 @ 4562' £ßtum fill) = I 1 4-1/2" I-£S X NIP, ID = 3.813" I £ßtum lVD = 8800' SS I 2093' I 9-518" CSG. 40#, L-80, ID = 8.835" 2735' -µ ~ GAS LIFT MANDRELS . ST MD lVD DEV lYPE VLV LATCH PORT I)c\TE L 4 3896 3420 41 KBG-2 DMY BK-5 0 06107/02 3 4248 3690 39 KBG-2 DMY BK-5 0 06107/02 WA TERR...OOD MANDRELS ST fill) lVD DEV lYPE VLV LATCH PORT I)c\ TE I Minimum ID = 2.813" @ 7547' 2 4507 3881 44 Mfv'G-W RKED RKP 0 02120102 3-1/2" HES X NIPPLE 1 4575 3930 44 Mfv'G-W RKED RKP 0 02120/02 I I 4358' 4-1/2" I-£SX NIP, ID =3.813"1 :8 ......., 4372' 7" X 4-1/2" BKR FREMERPKR, D = 3.875" ð I I 4-1/2"TBG, 12.6#, L-80, .0152 bpf,lD =3.958" 4428' ~ r 4430' 4-1/2" x 3-1/Z' XO, ID = 2.992"1 ::J I 3-1/2" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" 1 I . I 7547 ..... 3-1/2" I-£S X NIP, ID = 2.813"-1 I I...--- 7558' 3-1/2" X 4-1/Z' XO I ß( ~ 7560' 7" x 4-1/2" BKR &3 A<R, ID = 3.875'1 ~ 7565' 4-1/2" X3-1/Z' XO,ID= 2.937" I I I 'I 7585' 3-1/2" I-£S X NlP,ID = 2.813" I rt 7617 1-- I 1 7606' 3-1/2" I-£S X NIP, ID = 2.813" 'I 3-1/2" TBG, 9.2#, L-80, .0087 bpf. ID = 2.992" I ............ PERFORATION SUMMA RY r 7618' 3-1/2" WL83,ID = 2.875" I -I REF LOG: TCP PffiF I H ELfIII) TT NOT LOGGED I ANGLE AT TOP PERF: 43 @ 4820' f\bte: Refer to Ffoduction DB for historical perf data SIZE SPF INTERV AL OpnlSqz DATE 7" 26# X 21' RJP Jf WI RA TAG 1 4-518" 6 4820 - 4866 0 02120102 -. 7682' 4-518" 6 4978 - 5025 0 02120102 I 4-518" 6 5069 - 5110 0 02120102 4-518" 6 5132-5147 0 02120102 I 8151' 7" 26# X 20' RJP Jf WI RA TAGI 4-518" 6 5206 - 5218 0 02120102 4-518" 6 5287 - 5316 0 02120102 2-1/2" 6 7791 - 7830 0 03118/02 2-1/2" 6 7844 - 7854 0 03118/02 2-1/2" 6 7865 - 7876 0 03/18/02 r FBTD 8270' 17"CSG, 26#,L-80, .0383 bpf, ID=6.276" 8417 1 ~~ Ot\TE REV BY CO tvfv1ENTS DATE REV BY 02120102 ORIGINAL COMPLETON 03102102 CH/lP CORREC1l0NS 03109102 RUth GLV CORRECTIONS 03118102 CWSltlh AOO ÆRFS 06107102 RUth GLV LPDATE eOMtÆNTS GPB'BOREALIS WELL: '1..-115 PffiMT f\b: 201-1400 AA No: 50-029-23035-00 SEe 34, T12N, R11E 2543' NSL & 3801' W8.. BP Exploration (Alas ka) ~....¡q"",,,cn 1\1\ ,I""., ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 TaYlo~<: Chairman THRU: Tom Maunder ~ ,() ~ P.I. Supervisor (fY' ~ Á) ':J FROM: Chuck Scheve (::p Petroleum Inspector NON- CONFIDENTIAL DATE: June 13, 2002 SUBJECT: Mechanical Integrity Tests BPX L Pad PBU Borealis Well P,T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well PT.D. Notes: Well P.T.D. Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALTWATER INJ. N = NOT INJECTING I p I P I p Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs L Pad and witnessed the initial MIT on wells L-Il1 ,L-115and L-l17. The pretest tubing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: ~ Attachments: Number of Failures: º Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. MIT PBU L Pad 6-13-02 CS1.xls 6/20/2002 .. 1iJG)- ~/7/f) L ~&./7 OvS ill? APPLICATION FOR SUNDRY APPROVALS ,-..., ~ '..,~' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Type of request: Abandon_ Suspend_ Operational shutdDwn _ Re-enter suspended well _ Pre-Producer Converted Pre-Producer Alter casing _ Repair well _ Plugging _ Time extension - Stimulate - to Injector Converted to Inject Change approved program Pull tubing Variance Perforate Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development _ RKB 76.5 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 196612 Stratigraphic _ Anchoraç¡e, AK 99519-6612 Service X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2736' FNL, 3798' FEL, Sec. 34, T12N, R11 E, UM (asp's 583116, 5978264) L-115 At top of productive interval 9. Permit number / approval number 4801' FNL, 521' FEL, SEC 28, T12N, R11 E, UM (asp's 581072, 5981457) 201-140 At effective depth 10. API number 4573' FNL, 668' FEL, Sec. 28, T12N, R11 E, UM (asp's 580922, 5981683) 50-029-23035-00 At total depth 11. Field / Pool 4504' FNL, 713' FEL, Sec 28 T12N, R11 E, UM (asp's 580876, 5981752) Prudhoe Bay Field / Borealis Pool 12. Present well condition summary Total depth: measured 8435 feet Plugs (measured) true vertical 7014 feet RECEIVED Effective depth: measured 8270 feet Junk (measured) true vertical 6871 feet JUN 0 6 2002 Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 20" 260 sx ArcticSet (Approx) Alaska Oi..ïtJ~.u. (;onÞi iJWW!$Q¡¡I! Surface 2709' 9-5/8" 484 sx AS Lite, 249 sx And'u¡r~l)f' 2735' Class 'G' 2735' 210 sx LiteCrete, 345 sx 8417' 6925' Production 8389' 7" LARC Perforation depth: measured Open Perfs 4820'-4866',4978'-5025',5069'-5110', 5132'-5147', 5206'-5218', 5287'-5316', 7791'-7830',7844'-7854',7865'-7876' true vertical Open Perfs 4185'-4219', 4302'-4336', 4369'-4400', 4416'-4427', 4472'-4481', 4533'-4555', 6474'-6505',6517'-6525',6534'-6543' Tubing (size, grade, and measured depth 4-1/2" 12.6# L-80 TBG @ 4428'.4-1/2" XO 3-1/2" TBG @ 4428'.3-1/2" 9.2# L-80 TBG @ 7558'. 3-1/2" XO 4-1/2" tbg @ 7558'. 4-1/2" 12.6# L-80 TBG @ 7565'. 4-1/2" XO 3-1/2" TBG @ 7565'. 3-1/2" 9.2# L-80 TBG @ 7618'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 4372' MD. 7" x 4-1/2" Baker S-3 Packer @ 7560' MD. 4-1/2" HES 'X' Nipple @ 2093'. 13. Attachments Description summary of proposal X Detailed operations program _ BOP sketch - 14. Estimated date for commencing operation 15. Status of well classification as: June 5, 2002 16. If proposal was verbally approved Oil - Gas - Suspended _ Tom Maunder 31-May-02 Name of approver Date approved Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Bruce W. Smith @ 564-5093. Signed ~ 1..J ~ Title: Borealis Development Petroleum Engineer Date June 04. 2002 Bruce w. Smith Prepared bv DeWavne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. - -j ft. .., Plug integrity - IP Test_ Location clearance - L/Ot./ . JCJd-- V Mechanical Integrity Test Subsequent form required 10- OnglOal Signed By fJ/¡qlod Approved by order of the Commission Cammy Oechsli T aylof Commissioner Date (J i~ I l:J n\J A L , Form 10-403 Rev 06/15/88 . SUBMIT IN TRIPLICATE ". bp ~ ~ .,. .'I~I", ..'~" "'~...- ,..,- .e:...- .~ ~. ·'I~·~'\~ ". BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 June 04, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for L-115 Conversion from Pre-Produced Injector to WAG Injector BP Exploration Alaska, Inc. proposes to convert well L-115 from a pre-produced injection well to an active injector (both water and MI (WAG flood» as part of the Borealis Pool Flood Development project. The procedure includes the following major steps: S OfT, Dummy off GL Design, Run Static Survey. MITIA to 4000 psig. Stirn Pump HPBD Slickline Work: 1. Drift and tag to at least 7880' MD, to verify access to perfs. 2. DGL Vs 3. Obtain SBHPS stop counts at: 8159' - 40-min, 8039' - 20/30min, 7917'- 20min. MITIA to 4000 psig. 3500 psig will need to be held on IA for frac job. HPBD Treatment: 1. Load Frac tanks with - 60 of seawater; - 1500 bbls are required (excluding tank bottoms). 2. RU the tree-saver/isolation tool for 4"Y2 "- 12.6 #/ft. tubing. PT backside to 4000 psi and maintain 3500 psi throughout treatment (set inner annulus pop- off at 4000 psi). Pressure test treating lines to 8500 psi. Set Nitrogen pressure relief valve at 8000 psig. Set pump trips afterwards to 7500 psi. The tubing and packer are good to 8500 psig, with 3500 psig on the annulus. This well is expected to treat at ± 6000 psi, but Borealis wells have treated at up to 7500 to 8000 psi. 7500 psig for pump trip-out and 8000 psig for PRV dumping is a reasonable setting to allow realistic tip screen-out development and provide tubular protection. It is recommended that 4 pumps be on location (1 backup). 3. Begin pumping HPBD, initial rate will be 40 bpm while displacing wellbore fluid, after displacement of wellbore fluids an initial scour will be pumped at 40 A ~ BPM l. J 20/40 at 1 ppa. Flush with water/di(~ shut down for ISIP, monitor for closure time. 4. Pump stage two Diversion / HPBD#2 and scour stage. Pump rocksalt and spacers as per attached schedule. Flush as per schedule and shut down for ISIP, monitor for closure time. 5. Pump Stage Three Diversion / HPBD#3 and scour stage. Pump rocksalt and spacers as per attached achedulo. FIUôh élô par ðuhüdu/ü and ðhut down. Flush will be made with water and diesel, pump diesel freeze protect as soon into the flush as possible. 6. Bleed off excess annulus pressure. Rig down Service Company. Leave well shut-in until permit to inject is recieved. Water is circulating currently. Last test: Max Deviation: Perf deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S value: Wellbore Fluids: BHT & BHP: Reference Log: 4/9/02515 BOPD 440 @ 4562' MD 340 @ 8011' MD 2.813"X nipple @ 7547,7585 & 7606" MD Perf job 3/18/02 8222 MD Perf Job 3/18/02 o ppm 4/9/02. Freeze protected tubing & IA to 2200' with diesel. L-115i 158°F & 2800 psia @ 6600' TVDSS SchlumbergerVision Density 10/17/01 Note: Simops on QoinQ Construction. drillinQ. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345·2948, cell: 440-8008 or e-mail me at SmithBW@BP.com Sincerely, k ~ ~ Bruce W. Smith GPB Borealis Development Engineer .~ ~ TREE = WElLHEAD = AClUA TOR = KB. B..BI = BF B..EV 4-1/16" CIW FWC NA 77.1' NA L-115 SAFETY N01ES: GLM'S @ STA #1 & #2 ARE 3-1/2" X 1-1/2" Mtv'G-WS, WHCHARE WATffiFLOOD WANDRB..S. = KOP= 1350' : '-1 1011' H 9-518" TAM PORT COLLAR I tl/ax Angle = 44 @ 4562' Datum M) = r 4-1/2" I-ES X NIP, ID = 3.813"1 Datum 1VD = 8800' SS . I 2093' I 9-5/8" CSG, 40#, L-BO, 10 = 8.835" 2735' µ ~ GAS LIFT MANDRELS U ST MD 1VO ŒV lYPE VLV LATCH PORT DA1E 4 3896 3420 41 KBG-2 DOIvE BK-5 16 03109/02 3 4248 3690 39 KBG-2 S/O BK-5 16 03109/02 WA 1ERFLOOD MANDRELS ST MD 1VD ŒV lYPE VLV LA TCH PORT DA1E Minimum ID = 2.813" @ 7547' 2 4507 3881 44 Mtv'G-W RKED RKP 0 02120/02 3-1/2" HES X NIPPLE 1 4575 3930 44 Mtv'G-W RKED RKP 0 02120/02 I I 4358' 4-1/2" I-ESX NIP, ID =3.813"1 8: ,...-, 4372' ð ~ 7" X4-1/2" BKR FREMERPKR, D = 3.875" I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 4428' I 4430' 4-1/2" X 3-1/2:' XO, ID = 2.992" I \ I 3-1/2" TBG, 9.2#, L-BO, .0087 bpf, D - 2.992" I I I 7547' 3-1/2" I-ES X NIP, 10 = 2.813" I --- 7558' 3-1/2" X 4-1/2:' XO ~ ..- 7" X 4-112" BKR 8-3 A<R, ID = 3.875" I ~ 7560' I 7565' 4-1/2" X 3-1/2" XO, ID = 2.937" I . I 7585' 3-1/2" I-ES X NIP, ID = 2.813" I I 3-1/2" TBG, 9.2#, L-BO, .0087 bpf, ID = 2.992" H 7617' 1---.. .......... I 7606' 3-1/2" I-ES X NIP, ID = 2.813" I PERFORATION SUMWARY ~ 7618' 3-1/2" WLEG, ID = 2.875" I REF LOG: TCP PffiF I H ELM) TT NOTLOGGED I ANGLE AT TOP PERF: 43 @ 4820' I\bte: Refer to Froduction DB for historical perf data SIZE SPF INTERV AL OpnlSqz DATE r 4-518" 6 4820 - 4866 0 02f20/02 I 7682' 7" 26# X 21' FUP Jf WI RA TA G I 4-518" 6 4978 - 5025 0 02f20/02 IJ 4-518" 6 5069 - 5110 0 02f20/02 4-518" 6 5132-5147 0 02f20/02 4-5/8" 6 5206 - 5218 0 02f20/02 8151' 7" 26# X 20' FUP Jf WI RA TA G I 4-518" 6 5287 - 5316 0 02f20/02 2-112" 6 7791 - 7830 0 03/18/02 2-1/2" 6 7844 - 7854 0 03118/02 2-1/2" 6 7865 - 7876 0 03/18/02 r A3TD 8270' ~ I 7" CSG, 26#, L-80, .0383 bpf, ID = 6.276" 8417' -¡ ~ DA1E RBI BY COWMENTS DATE REV BY 02120102 ORIGINAL COMPLEfON 03102102 CH/lP CORRECllONS 03109102 RUth GLV OORREGfIONS 03118102 CWSltlh ADD ÆRFS COMI'vENTS GPB BOREALIS WELL: L-115 PffiMT lib: .20~-'\.400'-- .,.~. o' AR No: 5O-029-.f3035-00 SEC 34, T12N, R11E 2543' NSL & 3B01' WB.. BP Exploration (Alaska) SCANNED JUL 1 5 LOO~ ----, ............ . MECHANI CAL INTEGRITY REPORT . "'" 5?UD IìÞ.!E:: OPER & FIELD . ßP - P BU. 'W""ELL NUM:EER L - liS t' :~~G RELE.;_S'::: TD :~;tl~S .till.. 701t/ TVD j ~BTD: fZ70 MD b'fl/ TVD Shoe: 8417 HD L+rZS TV!) i DV: MD -TVD ~¡;.LL DATA 711 Casi~g: _:":ïe~: '<~..--- Shoe: MD , I :~oi.:1g: t.fíý.. "Sl Packer ~/f,.lg· till TVD i :CP: TV1) i Set ê. t t./-t10 P er£s »r¡q( ::ole Size ~'IIt; " ana ~C?..Þ~-1IC;·..L INTEGRITY - ?lŒ.T fl Annulus Press Test: 7~ IS min i 30 .¡. ..'~ /-. L;~)' ! ^·'1.e«A~,¡..- .I C01IiID.e~ts: MTT (~Ó,,(lr-ßd r)t~\)k' HD ;:~lD . ,/"'7"¡ f - I r..¡ ~ " ,7':;;; ho . ~~/"'- ar.I..1 W" to 7 ·fl(¿, min --- !f1 hU, 1/'~(2/~~ Cs g 7 L bf;;/s I; DV !O é.ð,Iß ,/ J&l v.vv;f , 2-Œ:CHJü'ncÞ~ INTEGRITY - PART 42 Cement: Volumes:' Þ-..mt. Liner C¡¡¡t 701 to cover Der.::s 'L/~ þ/.;,{(;. I .... ( t ~OO . Theoretical Toe -; i;c' ~ I ,Iv!'. 30tìo &f ~,œ(",<'", + If "}~l? r2'l.V1 \ Cement Bond Log U (Yes or No) l ~ . ^/ o é)LJ (X µt~ v ; In AOGCC File (;',,0(1 c#lAi ii1 "(-('/l / It It. . CBL Evaluation, J~l> "L fl /, (~" zone aoove perfs I J I P J..f, {' "~J"; t \. Iff ¡i of r " \.: ,¡, t/'"" 1'\/1 '4;...1../" , Jh" i Prociu~tion Log: Type Evaluati.on '. ",. . ! CONC;LUSIONS: 1-. '1) rÞ\~ ' /.I.. 14 'J1A.",'''zLt¡,,_ ç'\l". (, ',"", \ " ?art f1: (0Jr~eT' V..,p 17 "4.; ~.Þ d r Þ'¡ ) ," . !j fJ\ r ¡¡., dj (' ~ ¡£¡1J l:~.,.j C·t"~ ~ ar:: :2: i: ¡ .--... , ! t..{i"",~e'j, '. ~ ",1. t,.,,({,AlÌ,./\ J \¡þ W rrß)., SCANNED JUL 1 5 2004 .,. ,,-- /"""'.. ,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 181 Oil o Gas o Suspended o Abandoned o Service Pre-Produced Injector 2. Name of Operator iœA'ùØt¥ 7. Permit Number BP Exploration (Alaska) Inc. 201-140 301-299/302-062 3. Address '7 ¡: 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 ß~r'; 50- 029-23035-00 4. Location of well at surface i~''''~~:=:==ø..\¡;~ 9. Unit or Lease Name 2543' NSL, 3802' WEL, SEC. 34, T12N, R11 E, UM I COMP1..E11W Prudhoe Bay Unit At top of productive interval ! Dè.r~ ! " 480' NSL, 521' WEL, SEC. 28, T12N, R11E, UM I :¿,lo, D-- ,-- 10. Well Number At total depth v~ .t ~j -, L-115i 776' NSL, 713' WEL, SEC. 28, T12N, R11E, UM ~ ---- 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Borealis Pool RKB = 76.48' ADL 028239 (Undefined) 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. 115. Water depth, if offshore 16. No. of Completions 10/7/2001 10/17/2001 2/20/2002 N/A MSL One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)rI19. Directional Survey 120. Depth where SSSV se~121. Thickness of Permafrost 8435 7014 FT 8335 6927 FT 181 Yes 0 No (Nipple) 2093' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, GR, CCL, USIT, GYRO 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 27' 107' 30" 60 sx Arctic Set (ADDrox.) 9-5/8" 40# L-80 26' 2735' 12-1/4" 84 sx Articset Lite, 249 sx Class 'G' 7" 26# L-80 25' 8417' 8-3/4" 10 sx CemCrete 345 sx LARC 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-5/8" Gun Diameter, 6 spf 2-1/2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 4430' 4372' MD TVD MD TVD 3-1/2", 9.2#, L-80 4430' - 7618' 7560' 4820' - 4866' 4185' - 4219' 7791' - 7830' 6474' 6505' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 4978' - 5025' 4302' - 4336' 7844' - 7854' 6517' - 6525' 5069' - 5110' 4369' - 4400' 7865' - 7876' 6534' - 6543' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5132' - 5147' 4416' - 4427' Freeze Protect with 10 Bbls of MeOH and 5206' - 5218' 4472' - 4481' 190 Bbls of Hot Diesel. 5287' - 5316' 4533' - 4555' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 29, 2002 Pre-Produced Injector (Pending Agreement of Pool Rules) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED No core samples were taken. - [\ii.w 0 .., ?002 ¡r,¡ I "- Alaska Oil & Gas Cons. ljOllllmSSlon Anchorage Form 10-407 Rev. 07-01-80 URIGINAL RBDMS SF Submit In Duplicate L MAY I 5 2002 t,~ ,...-....., ~ 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top of Ugnu 2972' 2782' Top of Schrader Bluff 4420' 3895' Base of Schrader Bluff 5464' 4669' Top of Kuparuk C 7786' 6470' Top of Kuparuk B 7923' 6581' Top of Kuparuk A 8118' 6743' Base Kuparuk / Top Miluveach 8238' 6844' RECEIVED - ~'1AY 0 7 2002 Alaska Oil & Gas Gons.l,;ommlssion Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary, Post Rig Work Summary 32. I ~erebY certify that the fOr'Oi~9 is true and correct to the best of my knowledge Signed Terrie Hubble ---1íAAù ¡.¿ I Ur& Title Technical Assistant L-115i 201-140 301-299/302-062 Well Number Permit No. / ADDroval No. Date 05-fJ7"0:;1.. Prepared By Name/Number: Sondra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. .:1 I Form 10-407 Rev. 07-01-80 (psi (ppg) ,783 (psi) 3.18 (ppg) ) , ) - Printed: 2/25/2002 2:31 :35 PM (psi 525 (psi) (ppg) 9.30 (ppg) (ft) 2,604.0 (ft) (ft) 2,735.0 (ft) 10/11/2001 I LOT 0/12/2001 LOT ~ ;--.., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 10/6/2001 2/20/2002 Spud Date: 10/7/2001 End: 10/20/2001 10/6/2001 06:00 - 09:00 3.00 MOB P PRE Complete Rig Down in preparation for moving rig to scales 09:00 - 17:00 8.00 MOB P PRE Weigh Rig on scales - derrick up and derrick down. 17:00 - 20:00 3.00 MOB P PRE Move & Spot sub-base and pits over L-115 20:00 - 00:00 4.00 MOB P PRE Repair Top Drive and replace brake bands & pads. RIU Diverter line, hook up lines at interconnect - water, air, steam ect. 10/7/2001 00:00 - 06:00 6.00 RIGU P PRE Cont top dr I brake band repair while take on H20, place bha and dp in pipe shed. 06:00 - 10:00 4.00 RIGU P PRE Cont take on H20, load pipe shed tubulars. 10:00 - 10:30 0.50 BOPSU P SURF Test diverter I all related equip. Test successful. No re-test. 10:30 - 14:00 3.50 DRILL P SURF Pick up 4" dp in sgls, std bk in mast. 14:00 - 15:00 1.00 DRILL P SURF Change out saver sub on top drive, inspect new installed brake bands. 15:00 - 15:30 0.50 DRILL P SURF Pre spud meeting all personnel. 15:30 - 16:00 0.50 DRILL P SURF Fill conductor, inspect mud system for leaks. 16:00 - 21 :00 5.00 DRILL P SURF Make up DCs, hwdp, remainder bha, std bk in mast. Orient mwd, record orientation I strap. 21 :00 - 21 :30 0.50 DRILL P SURF Tag btm at 102 ft, commence drill out conductor shoe I formation. 21 :30 - 00:00 2.50 DRILL P SURF Drill ahead 12 1/4 hole drctnl, 102 - 171 ft. WOB 5, Rot 50, PSI 780, GPM 500, SPM 168 Note: Rig 9-ES accepted this date 0600 hrs. 1 0/8/2001 00:00 - 02:30 2.50 DRILL P SURF Circ I cond mud during wait for vac trucks detained behind Doyon rig move. 02:30 - 00:00 21.50 DRILL P SURF Resume drill ahead 12 1/4 hole 171 - 1566 ft. Gyro surveys 90 ft intervals. WOB 30, RPM 50, SPM 200, PSI 1760, GPM 600, Up 80, Dn 79, Rot 80 ART 5, AST 3 No fill on connections, torque normal, 100 % returns. 1 0/9/2001 00:00 - 02:00 2.00 DRILL P SURF Drlg f/1566' to 1753'. 02:00 - 03:00 1.00 DRILL P SURF Circ sweep. Hole cleaned up. Blow down. Monitor well-OK. Spill Drill-OS-1 :45 min. 03:00 - 05:00 2.00 DRILL P SURF POH. Pulled 35k over @ 1285'. 05:00 - 06:00 1.00 DRILL P SURF Stand back BHA. Break out bit. 06:00 - 06:30 0.50 DRILL P SURF PJSM. Service top drive. Change out grabber dies. 06:30 - 07:00 0.50 DRILL P SURF MU bit & BHA. 07:00 - 08:00 1.00 DRILL P SURF RIH. Work through tight spots f/1110' to 1285'. 08:00 - 08:30 0.50 DRILL P SURF Circ thick mud out of hole. 08:30 - 11 :30 3.00 DRILL P SURF Drlg f/1753' to 2125', 11:30-12:00 0.50 DRILL P SURF Change shacker screens. 12:00 - 16:30 4.50 DRILL P SURF Drlg f/2125' to 2756'--TD. PU: 96k; SO: 80k; Rot: 93k. 650 gpm wI 2380 psi; 60 rpm; 35k on bit. 16:30 - 18:00 1.50 DRILL P SURF Circ & cond mud for short trip. Pump survey @ TD. Orient to Hi-side. Monitor well-OK. 18:00 - 20:00 2.00 DRILL P SURF POH. Intermittent swabbing f/2756' to 2311'. 30k overpulls f/ 1469' to 1250'. 50k overpull @ 1115'. Swabbing @ same depths. Pushing mud away on downstrokes. Wiped all areas. 20:00 - 23:00 3.00 DRILL P SURF Stand back HWDP & jars. LD BHA. Clean & clear floor. 23:00 - 00:00 1.00 DRILL P SURF MU 12.25" porcupine hole opener BHA. Printed: 2/25/2002 2:31 :45 PM ~. ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: Rig Release: Rig Number: 10/6/2001 2/20/2002 Spud Date: 10/7/2001 End: 10/20/2001 10/10/2001 00:00 - 02:30 2.50 DRILL P SURF Make up bha #3 I hole opener. Layout 2 galled DCs. 02:30 - 06:00 3.50 DRILL P SURF Flow check, rih hole opener assy to 2604 ft. 06:00 - 06:30 0.50 DRILL P SURF Ream 150 ft to btm. 06:30 - 07:30 1.00 DRILL P SURF Prepare and poh for 9 5/8 csg run. 07:30 - 09:30 2.00 DRILL P SURF Layout BHA #3, clear rig floor. 09:30 - 12:30 3.00 CASE P SURF PJSM, place 9 5/8 running equip on floor, rig up same. Perform dummy run 9 5/8 hgr, record strap. 12:30 - 17:00 4.50 CASE P SURF Flow check, Make up shoe track, thread lock critical connections. Check float equip. Commence rih 9 5/8, 40#, L80, BTC csg. Make up hgr, land at 2735 ft. 17:00 - 20:30 3.50 CASE P SURF Make up cmt hd, circ I cond mud, recip pipe at all times. 20:30 - 00:00 3.50 CASE P SURF Pump 10 bbl CW 100. Test lines to 3500 psi. Test good. Drop btm plug, pump 75 bbls Mudpush XL spacer. Commence cmt 9 5/8 csg as follows: Pump 382 bbls 10.7 lead slurry @ 6 bpm. Pump 52 bbls 15.8 ppg tail slurry. Drop top plug, chase with 10 bbls H2o. Change over rig pumps, displace at 8 bpm, 201 bbls drill mud. ICP 490 psi at 8 bpm, FCP 700 psi at 3 bpm. Bump plug wth 1500 psi. Hold 5 min. Bleed, check floats, no flowback. Flow check 30 min. Pipe reciprocated constantly during cmt. Stop at start of flush. Circ 30 bbls cement to surface. Plug bumped at 2326 hrs. 10/11/2001 00:00 - 02:00 2.00 BOPSU P SURF Nipple dn diverter system. 02:00 - 04:00 2.00 BOPSU P SURF Nipple up csg hd I tbg hd, test all packoffs I seals 1000 psi 15 min. All tests successful. 04:00 - 07:00 3.00 BOPSU P SURF Nipple up bope, all related plumbing I hydraulics. 07:00 - 11 :30 4.50 BOPSU P SURF Test bope to BP I AOGCC specs as follows: Accumulator test, time I press. test. All floor safety valves I equip. Standpipe top drive, to pumps. Annular 250 13500 psi 110 min. Rams 250/4000 psi 110 min. Choke and kill systems 250 I 4000 psi. All tests successful and witness waived by John Crisp AOGCC. 11:30-12:30 1.00 CASE P SURF Handle bha #4. Make up 8 3/4 motor I drctnl assy. Load source, prepare Iwd tools. Orient, rih same. 12:30 - 20:00 7.50 CASE P SURF PU 4" dp in sgls from pipe shed, stand back in mast. 20:00 - 22:00 2.00 CASE P SURF Follow DCs with hwdp. Shallow test Iwd, test good. 22:00 - 00:00 2.00 CASE P SURF Pick up remainder 4" dp from pipe shed in sgls. 10/12/2001 00:00 - 01 :00 1.00 CASE P SURF Cont pu 4" dp in sgls from pipe shed. 01 :00 - 02:30 1.50 CASE P SURF Slip I cut drlg line, service top drive. 02:30 - 03:00 0.50 CASE P SURF Rih 4" dp to 2503 ft. 03:00 - 03:30 0.50 CASE P SURF Test 9 5/8 csg to 4000 psi I 30 min. Test successful. No re-tests. 03:30 - 05:30 2.00 CASE P SURF Wash to float collar, drill out float, shoe track, guide shoe, 20 ft new formation. 05:30 - 06:30 1.00 CASE P SURF Flow check, eire, displace hole with 9.3 ppg KCL mud. 06:30 - 07:00 0.50 CASE P SURF Pull inside csg, perform LOT. Results = 13.18 EMW ( 9.3 ppg, 525 psi, 2604 tvd ) 07:00 - 14:30 7.50 DRILL P PROD1 Commence drill ahead 8 3/4 hole drctnl, 2775 - 3807 ft. Control Printed: 2/25/2002 2:31:45 PM ,.-..., I~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: 2/20/2002 Rig Number: Spud Date: 10/7/2001 End: 10/20/2001 10/12/2001 07:00 - 14:30 7.50 DRILL P PROD1 drld to limit PR @ -200 fph. Sweeps @ -200' intervals. 590-600 gpm; 60-70 rpm. 14:30 - 15:30 1.00 DRILL P PROD1 Circ, pump hi - vis sweep, no abnormal cutting returns with sweep. 15:30 - 16:30 1.00 DRILL P PROD1 Flow check, poh for wiper trip. Swabbing with 20 - 40 overpull. Wipe clear. Hole tight 3530 to shoe at 2735. 16:30 - 17:30 1.00 DRILL P PROD1 Rih, wash I ream 3250 - 3342 ft. Cont rih to btm, precautionary wash 90 ft. 17:30 - 00:00 6.50 DRILL P PROD1 Resume drill 8 3/4 hole 3807 - 4366 ft. AST 6 hrs, ART 4 hrs. Up 122, Dn 89, Rot 102 WOB 5 -12, RPM 60, GPM 590, Press 2370 10/13/2001 00:00 - 04:30 4.50 DRILL P PROD1 Cont drill ahead 8 3/4 hole 4366 - 4831 ft. 04:30 - 05:30 1.00 DRILL P PROD1 Pump hi-vis sweep, follow with wt pill. Flow check. 05:30 - 08:30 3.00 DRILL P PROD1 Poh for wiper trip. Interrmittent swabbing, work free at various intervals. Back ream 3990 - 3780 ft., 3020 - shoe. Flow check. 08:30 - 09:00 0.50 DRILL P PROD1 Service top drive. 09:00 - 10:00 1.00 DRILL P PROD1 Flow check, rih to 4736 ft. No down drag. 10:00 -11:00 1.00 DRILL P PROD1 Precautionary wash I ream to btm. No fill. 11 :00 - 00:00 13.00 DRILL P PROD1 Resume drill ahead 4831 - 5703 ft. AST 9.25, ART 5.5 hrs, WOB 10, RPM 80, SPM 200, GPM 590, Press 3200, TQ 6000 10/14/2001 00:00 - 01 :30 1.50 DRILL P PROD1 Cont drill ahead 8 3/4 hole 5703 - 5858 ft. 01 :30 - 03:00 1.50 DRILL P PROD1 Circ, pump hi-vis for wiper trip. No increase cuttings return with hi-vis. 03:00 - 10:00 7.00 DRILL P PROD1 Flow check, poh. 25 - 75 K over pull at 5600 ft. Slight swabbing. Recip pipe, work free. Identical conditions at 4100 - 3100 ft. Begin backream 3100 - csg shoe. Note wall cake substance at shakers. Trouble spots correllate with previous wiper trip. 10:00 - 10:30 0.50 DRILL P PROD1 Flow check, service rig. 10:30 - 12:00 1.50 DRILL P PROD1 Flow check, rih to 5764 ft. No abnormal down drag. 12:00 - 13:00 1.00 DRILL P PROD1 Precautionary wash I ream to btm. No fill. 13:00 - 00:00 11.00 DRILL P PROD1 Resume drill ahead 8 3/4 hole 5858 - 6481 ft. ART 10 hrs, AST 1 hr Up 153, Dn 104, Rot 131 WOB 10, RPM 60 - 90, GPM 585, Press 3316, Tq 7,000 10/15/2001 00:00 - 12:30 12.50 DRILL P PROD1 Cont drill ahead 8 3/4 hole 6481 - 6977 Ft. ART 10 hrs, AST.5 hr, Up 153, Dn 104, Rot 136 WOB 12, RPM 60, SPM 200, GPM 580, Press 3380 12:30 - 13:00 0.50 DRILL P PROD1 Circ I cond mud, orient highside, prepare poh for bit. 13:00 - 18:30 5.50 DRILL P PROD1 Flow check, 6977 - 6604 ft good condo 6604 - 5018 ft swabbing with 20 - 50K overpull. Work free, fill pipe, 100% circ returns. Good cond 5018 ft to shoe at 2735 ft, pull slow to prevent swabbing. Resume poh to hwdp. 18:30 - 20:30 2.00 DRILL P PROD1 Flow check, handle bha #4, break bit and inspect. Mechanical damage to cutters. 20:30 - 22:00 1.50 DRILL P PROD1 Flow check, make up bit #5 I bha #5, rih same to hwdp. 22:00 - 22:30 0.50 DRILL P PROD1 Shallow test motor I mwd. Printed: 2/25/2002 2:31:45 PM r--- ,..-....." Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: 2/20/2002 Rig Number: Spud Date: 10/7/2001 End: 10/20/2001 10/15/2001 22:30 - 00:00 1.50 DRILL P PROD1 Follow bha with 4" dp to shoe at 2755 ft for rig service. 10/16/2001 00:00 - 01 :00 1.00 DRILL P PROD1 Slip and cut drilling line. 01 :00 - 01 :30 0.50 DRILL P PROD1 Service top-drive. Flow check, OK. 01 :30 - 02:00 0.50 DRILL P PROD1 RIH one stand. Fill pipe and break circulation. 02:00 - 04:00 2.00 DRILL P PROD1 RIH. Fill pipe and break circ. at 4600', 6884' and on bottom. Hole condition good. 04:00 - 05:30 1.50 DRILL P PROD1 Stage pumps up and pump hi-visc sweep around. 05:30 - 00:00 18.50 DRILL P PROD1 Dir. drill from 6977' to 8329'. ART = 11.5 hrs; AST = 3.25 hrs; ADT = 14.75 hrs. 10/17/2001 00:00 - 01 :00 1.00 DRILL P PROD1 Drill from 8329' to 8435', TD. AST= 0; ART = 1 hr. 01 :00 - 02:30 1.50 DRILL P PROD1 Pump weighted sweep and cond mud. Flow check, OK. Pump dry job. Rotate at 100 rpm and recip. while circ. 02:30 - 07:30 5.00 DRILL P PROD1 POOH for short trip to shoe. Swabbing from 8255'. Tight hole. Back ream from 8160' to 6977'. Pulling from 25K to 80K over. 07:30 - 08:00 0.50 DRILL P PROD1 Circ bottoms up. Circ out considerable material. Flow check, OK. 08:00 - 12:00 4.00 DRILL P PROD1 Try to POH without pump. Pulled one stand and swabbing. Back ream every other stand from 6977' to 6600'. Pulled OK to 5390' then started swabbing. Work pipe. POH and work pipe when swabbing occurred. Pulled to shoe and flow check, OK. 12:00 - 12:30 0.50 DRILL P PROD1 Service top drive. Circ BU at shoe. 12:30 - 15:00 2.50 DRILL P PROD1 RIH. Fill pipe at 4700'. Took weight at 7760'. Work pipe and push thru with 20K over. Wash last stand down, precautionary. 15:00 - 18:30 3.50 DRILL P PROD1 Pump sweep. Circ and cond mud. Spot casing running pill. Recip DP and rotate at 110 rpm while circ. 18:30 - 23:00 4.50 DRILL P PROD1 Flow check, OK. Blow down TD. POOH. Slight swabbing from TD up to 7760'. Wiped occasional tight spots (10K to 15K over). Pulled OK from 7741'. Flow check at shoe, OK. POOH to HWDP. 23:00 - 00:00 1.00 DRILL P PROD1 PJSM. Pull BHA standing back HWDP. Change to 5" elevators. 10/18/2001 00:00 - 03:00 3.00 DRILL P PROD1 LD BHA #5. Unload RA sources. Remove all components from floor. 03:00 - 03:30 0.50 CASE P COMP Clear rig floor to RU casing tools. PJSM. 03:30 - 04:00 0.50 CASE P COMP Pull wear bushing. Make dummy run with landing jt. and mark. Install test plug. 04:00 - 05:30 1.50 CASE P COMP Change upper ram blocks, install 4 1/2 X 7". Pressure test door seals to 250 psi and 4000 psi, OK. RD test equip. 05:30 - 08:00 2.50 CASE P COMP PJSM. Pick up casing running tools and rig up same. Change to long bails and pick up Franks Tool. 08:00 - 10:00 2.00 CASE P COMP Run 7", 26#, L-80, BTC-M casing. Make up shoe track, Baker-Ioc, and check floats, OK. Run in to first marker jt. Has wrong threads. Lay down and replace with next marker jt. Continue to run in to next marker jt. location. 10:00 - 12:00 2.00 CASE N WAIT COMP Wait on installation of RA PIP in new marker joint. Make up same. 12:00 - 12:30 0.50 CASE P CaMP Tour change. PSJM for casing job with new crew. 12:30 - 15:00 2.50 CASE P caMP Continue running 7" casing to 9 5/8" csg shoe. PU = 105K, SO = 91K. 15:00 - 15:30 0.50 CASE P CaMP Circ. casing volume at surf. csg shoe. 15:30 - 22:00 6.50 CASE P CaMP Run 7" casing in open hole. Pushed with 30K to 40K added weight from 8100' to 8180'. Continued running in without Printed: 2/25/2002 2:31:45 PM ~ ¡-""""<., Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: 2/20/2002 Rig Number: Spud Date: 10/7/2001 End: 10/20/2001 10/18/2001 15:30 - 22:00 6.50 CASE P COMP incident. Lost approx. 19 bbls mud while running casing. 22:00 - 22:30 0.50 CASE P COMP Lay down Franks Tool. Blow down top drive. MU landing jt. and land casing at 2215 hrs. Make up cement head. PU = 320K, SO = 135K without pump. 22:30 - 00:00 1.50 CASE P COMP Break circulation, staging pumps up slowly to 6 BPM at 880 psi. Reciprocate casing while circulating. PU = 250K, SO = 130K with circ. Full returns while circ. 10/19/2001 00:00 - 01 :00 1.00 CASE P COMP Circ. and condo mud at 6 bpm and 900 psi for cementing. Reciprocate casing 20' in 1 imino cycles. PU = 250K; SO = 130K. 01 :00 - 04:00 3.00 CEMT P COMP Pump 10 bbl CW100 flush. Test lines to 4000 psi, OK. Pump 30 bbls more of CW1 00, 40 bbls MudFlush, bottom plug, 89 bbls 12 ppg CemCRETE lead slurry, 72 bbls 15.8 ppg Latex tail slurry, and top plug. Displace with 320 bbls 9.2 ppg brine at 6 bpm slowing to 2 bpm for the last 10bbls of displ. Recip. pipe throughout. Did not bump plug. CIP at 0335 hrs. Final displ press. = 1034 psi. 04:00 - 05:00 1.00 CEMT P COMP Check floats, OK. Monitor well, OK. Blow down lines, RO cmting equip. LD cmt head and landing joint. 05:00 - 06:00 1.00 WHSUR P COMP Run and install casing hanger packoff. Run in and torque test LOS. Pressure test to 5000 psi, OK. Spill Orill-OS-1 :30 min. 06:00 - 07:00 1.00 BOPSU P COMP RD casing equipment. Change bails. RU floor to run DP 07:00 - 09:00 2.00 BOPSU P COMP Change top rams fl 7" to variable. Test doors to 250 /4000 psi-OK. Install wear ring. 09:00 - 09:30 0.50 CASE P COMP RU to pump down annulus. Pumped mud and broke down wI 470 psi. EMW=13.8 ppg. Pump 1 bbl each hr to keep annulus clear. 09:30 - 10:30 1.00 CLEAN P COMP MU BHA #6-bit, HWDP, & jars. 10:30 - 13:00 2.50 CLEAN P COMP RIH wI 4" DP to 7858'. Circ down to cement plug @ 8270.5' 13:00 - 14:30 1.50 CLEAN P COMP CBU @ 8 bpm. Hole clean. 14:30 - 17:00 2.50 CLEAN P COMP Start LOOP. Simultaneous operation. Inject mud down annulus @ 3 bpm wI 700 psi. Pumped 85 bbls total. RU Little Red to freeze protect annulus wI dead crude. 17:00 - 21 :00 4.00 CLEAN N CEMT COMP Pumped 13 bbls crude and noted returns coming from conductor. Shut down & pump cellar out. Monitor until returns stopped--approximately 42 bbls. Spill Drill-OS-1 min. 21 :00 - 22:00 1.00 CLEAN P COMP RU & test 7" casing to 4000 psi fl 30 min-OK. RD test equipment. 22:00 - 00:00 2.00 CLEAN P COMP Continue LDDP while finalizing freeze protect plan & WO cement, water, and vac trucks. 10/20/2001 00:00 - 02:30 2.50 CLEAN P COMP Lay down drill pipe to the HWOP. 02:30 - 13:00 10.50 REMCM N CEMT COMP PJSM. Re-establish circulation to surface through 7" X 9 5/8" annulus by pumping 3 bbls of mud wI rig pump at 1.8 bpm. Hook up Dowell. PT lines, OK. Mix and pump 250 bbls 10.7 ppg ArcticSet Lite down annulus at 1.8 bpm and 450 psi. Had returns until 90 bbls pumped. Returns diminished to nil. RD Dowell and RU Hot Oil Servo Freeze protect 7" X 9 5/8" annulus to 2100' TVD with 58 bbls of dead crude. Work 3/4" pipe down 9 5/8" X 20" annulus to 60'. Fire drill at 0400 wI all on station in 70 sec. 13:00 - 14:00 1.00 REMCM N CEMT COMP RU Dowell. Mix and pump 16.5 bbls of 11 ppg, ArcticCRETE cement down 3/4" lines circ from 60' to surf. in 9 5/8" X 20" annulus. Printed: 2/25/20D2 2:31:45 PM ".-....... ,.-..." Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: 2/20/2002 Rig Number: Spud Date: 10/7/2001 End: 10/20/2001 10/20/2001 14:00 -15:00 1.00 REMCM N CEMT COMP Wash out and blow down cementing lines. RD Dowell. Clear and clean floor. 15:00 - 16:30 1.50 CLEAN P COMP Lay down HWDP. 16:30 - 18:00 1.50 WHSUR P COMP Pull wear bushing. Make dummy run with tbg hanger. RU to run 4 1/2" tlubing. 18:00-21:30 3.50 COMP PJSM. PU mule shoe and run 75 jts, 4 1/2" 12.6#, L-80, NSCT temporary kill string. Land at 2995.5' MD. 21 :30 - 23:30 COMP Pick up hanger and landing jt. Land tubing. RILDS. Backout landing jt. and lay down. RD tbg handling equip. Clear floor. 23:30 - 00:00 COMP Set TWC. Test to 1000 psi, OK. 10/21/2001 00:00 - 01 :00 COMP Blow down secondary kill line, choke, mud manifold. Flush out BOP stack. 01 :00 - 03:00 2.00 BOPSU COMP Nipple down BOPE. Set back on stump. H2S drill, 1 min. 40 sec. on station. 03:00 - 06:30 3.50 WHSUR P COMP Nipple up adapter flange and tree. Test seals and tree to 5000 psi. 06:30 - 07:30 1.00 WHSUR P COMP Rig up DSM lubricator and pull TWC. 07:30 - 09:30 2.00 WHSUR P COMP Rig up HOS. Test lines to 2500 psi, OK. Pump 100 bbls diesel down annulus and out tubing to freeze protect. Balance heads and blow down lines. 09:30 - 10:30 1.00 WHSUR P COMP Rig up DSM and install BPV in wellhead. Test below to 1500 psi, OK. RD DSM. 10:30 - 12:00 1.50 WHSUR P COMP Rig down all lines and valves and clean up cellar area. Secure tree. Rig Released at 1200 hrs, 10/21/2001. 2/16/2002 00:00 - 06:00 6.00 MOB P PRE Move rig from L-120 to L-115i. 06:00 - 08:00 2.00 RIGU P PRE Spot Sub, Pits and Camp. ACCEPT RIG @ 08:00 Hrs. 08:00 - 12:00 4.00 RIGU P COMP Continue rigging up while taking on water and 9.2 ppg. Brine. RlU lines on Tree to circulate diesel out of well bore. 12:00 - 15:00 3.00 CLEAN P COMP Test lines and surface equipment to 3500 psi. Displace Freeze protect diesel from 4.5" Tbg and 4.5" X 7" annulus with 9.2 ppg Brine. Wellbore clean. Blow down lines. 15:00 - 15:30 0.50 PERF P COMP Install TWC and test from below to 1000 psi. 15:30 - 17:00 1.50 PERF P COMP NID Tree and adapter flange, clean Tbg. spool, clean and check Hanger threads. 17:00 - 19:30 2.50 PERF P COMP N/U BOP & Riser. Shell test BOP to 4000 psi. Shell test approved by John Crisp, AOGCC. 19:30 - 20:30 1.00 PERF P COMP RlU DSM. Pull TWC. RID DSM. 20:30 - 23:00 2.50 PERF P COMP RlU to pull tbg. kill string. M/U 4.5" landing Jt. wI safety valve. Screw into Hanger. Function Hydril and upper Pipe Rams. B.O.L.D.S. Pull Hanger to floor, inspect same - OK to re - run. B/O and UD Hgr. and landing Jt. 23:00 - 00:00 1.00 PERF P COMP POH wI 4.5" Tbg. laying down same. 2/17/2002 00:00 - 02:00 2.00 PERF P COMP Complete POH wI 4.5" Tbg. Kill String. UD all tbg.. 02:00 - 05:00 3.00 PERF P COMP Test BOPE - 250 psi Low, 4000 psi High. Witness waived by John Crisp, AOGCC. 05:00 - 05:30 0.50 PERF P COMP Install wear bushing 05:30 - 06:30 1.00 PERF P COMP Test 7" Casing to 4000 psi for 30 minutes. 06:30 - 09:00 2.50 PERF P COMP M/U 6 1/8" bit & Float sub. RIH P/U singles. 09:00 - 10:30 1.50 PERF P COMP Cut & slip drilling line, service top drive. 10:30 - 13:00 2.50 PERF P COMP RIH to 5550'. 13:00 - 14:30 1.50 PERF P COMP CBU. Spot Perf Pill. Pump slug. 14:30 - 17:30 3.00 PERF P COMP POH SLM - no correction. 17:30 - 23:30 6.00 PERF P COMP PJSM wI HES and rig team. M/U perf guns as per program & Printed: 2/25/2002 2:31:45 PM "" ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: 2/20/2002 Rig Number: Spud Date: 10/7/2001 End: 10/20/2001 2/17/2002 17:30 - 23:30 6.00 PERF P COMP RIH on 4" DP to 5317'. 23:30 - 00:00 0.50 PERF P COMP PJSM wI Schlumberger. RlU for correlation logging. 2/18/2002 00:00 - 01 :30 1.50 PERF P COMP Log GRlCCL & correlate to USIT Log for perf depths. Guns 8' low. POH wI SWS. 01 :30 - 02:00 0.50 PERF P COMP Screw into DP wI Top Drive. Pull up 8'. Pressure to 2500 psi & bleed oft. Put on trip tank. Guns fired @ planned 6 minute delay. Shot 176' Perfs from 4820' to 5316' as per program. 02:00 - 03:00 1.00 PERF P COMP Observe well: Lost only 1 bbl. fluid in 15 minutes. Break circulation and circulate bottoms up. No additional losses. 03:00 - 05:00 2.00 PERF P COMP POH wI 4" DP to guns. 05:00 - 07:30 2.50 PERF P COMP PJSM. POH, UD perf guns. All fired. Total losses 8 bbl. since perforating. 07:30 - 09:00 1.50 CLEAN P COMP M/U 6 1/8" bit, boot basket & scraper, 3 - 4 3/4" DC's, jars & 21 Jts. HWDP. 09:00 - 13:00 4.00 CLEAN P COMP RIH to TOC @ 8265'. 13:00 - 14:30 1.50 CLEAN P COMP CBU - 7 BPM @ 1000 psi. Spot 28 bbls clean, filtered 9.2 ppg. brine on bottom. 14:30 - 15:30 1.00 CLEAN P COMP POH stand back 25 stands 4" DP 15:30 - 19:00 3.50 CLEAN P COMP UD 168 Jts. 4" DP. 19:00 - 20:00 1.00 CLEAN P COMP Stand back 4" HWDP. Lay down BHA. Clean out JB - no junk or perf debris noted. Minor amt pipe scale. 20:00 - 21 :00 1.00 RUNCO COMP Clear floor, Pull Wear Bushing, C/O to long bails. 21 :00 - 22:30 1.50 RUNCO COMP RlU to run 3.5" X 4.5" Completion Tubing String 22:30 - 23:00 0.50 RUNCO COMP PJSM wI Rig Team, and all service hands. 23:00 - 00:00 1.00 RUNCO COMP P/U W.L.E.G. Assy. & start running completion string as per program. 2/19/2002 00:00 - 16:00 16.00 RUNCO COMP Cont. rih 4 1/2 X 3 1/2 comp assy. 16:00 - 17:00 1.00 RUNCO COMP Flow check, make up tbg hgr Ildg jt. Land, record space out, PU 3 ft out of tbg hd. 17:00 - 18:30 1.50 RUNCO COMP Displace well with 40 bbls 9.2 ppg "Corexit" treated brine. Follow with 220 bbls brine. 18:30 - 19:30 1.00 RUNCO COMP Land tbg hgr, drop ball rod, lay dn Idg jt. 19:30 - 22:00 2.50 RUNCO COMP Set S3 pkr with 2800 psi. Bleed, build to 4200 psi and set Upper Premier pkr. Hold and chart 30 min tbg test. Bleed tbg to 2000 psi, press annulus to 4000 psi, hold and chart 30 min for pkr test. Bleed tbg to shear DCK valve in lower 4 1/2 glm. Shear at 1300 psi. All tests successful, no re-tests. Bleed lines, drain bop stack. Install TWC, test to 2800 psi from below. 22:00 - 00:00 2.00 BOPSU P COMP Commence ND bope, all related equip. Prep tbg spool I prod tree. 2/2012002 00:00 - 01 :30 1.50 WHSUR P COMP NU prod tree 01 :30 - 02:30 1.00 WHSUR P COMP Press test prod tree, adptr flange, all seals, body test, all valves to 5000 psi. All tests successful, no re-test. 02:30 - 05:00 2.50 WHSUR P COMP Layout test equip, remove TWC. 05:00 - 08:00 3.00 WHSUR P COMP Rig up Little Red Hot Oiler to tree. Test lines to 3500 psi. Freeze Protect 4.5" X 7" annulus and inside tubing down to 4248' with 78 bbls diesel. Let diesel U-Tube to stabilization. Shut in well. RID Little Red. FCP = 1000 psi 08:00 - 11 :00 3.00 WHSUR P COMP Install BPV, test to 1000 psi, test fail, replace BPV, re-test, test successful. Layout DSM equip, secure well, tag master valve. Printed: 2/25/2002 2:31 :45 PM ,r-... .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: 2/20/2002 Rig Number: Spud Date: 10/7/2001 End: 10/20/2001 2/20/2002 11 :00 - 12:00 1.00 WHSUR P COMP Clean pits, blow down, release rig. NABORS RIG 9-ES RELEASED THIS DATE 2/20/2002 1200 HRS Printed: 2/25/2002 2:31:45 PM ~, ~ Well: Field: API: L-115 Prudhoe Bay Field / Borealis 50-029-23035-00 Rig Accept: 10/07/01 Rig Spud: 10/07/01 Rig Release: 10/21/01 Rig Accept: 02/16/02 Rig Release: 02/20/02 POST RIG WORK 03/09/02 SET XN CS, INSTALL GENERIC GAS LIFT, PULL RP & DGLV. STA 3-4, SET LGLV STA 4 OGLV STA 3 PULL CS, PULL BALL & ROD & RHC PLUG @ 7586' SLM. 03/10/02 TAG TD W /2.5" DUMMY GUN @ 8210' SLM (TARGET DEPTH IS 7876' MD) 03/17/02 PERF 21/2" 6 SPF GUNS, ORIENTED 10 DEG OFF BOTTOM ON THE INTERVALS: 7844'-7854' & 7865' -7876'. WHP = 0 PSI BEFORE AND AFTER FIRING BOTH GUNS, TAGGED TD AT 8222', 03/18/02 PERF 21/2" 6 SPF GUNS, ORIENTED 10 DEG OFF BOTTOM ON THE INTERVAL: 7791'-7830'. WHP = 0 PSI BEFORE AND AFTER FIRING BOTH GUNS. 04102102 PUMP 10 BBLS MEOH AND 190 BBLS HOT DIESEL DOWN TBG. ) ) ANADRILL SCHLUMBERGER Survey report 17-0ct-2001 11:31:37 Page 1 of 4 Client BP Exploration (Alaska) Inc. Field. Prudhoe Bay Well. . L-115i Spud date.... ............ 07-0ct-01 API number 50-029-23035-00 Last survey date.... ..... 17-0ct-01 Engineer. . Nutter Total accepted surveys... 92 MD of first survey....... 0.00 ft COUNTY: . . . Nabors 9ES MD of last survey........ 8435.00 ft STATE: . . . . Alaska ----- Survey calculation methods------------- ----- Geomagnetic data -- ------------------ Method for positions.....: Minimum curvature Magnetic model...........: BGGM version 2000 Method for DLS. ..........: Mason & Taylor Magnetic date... .........: 07-0ct-2001 Magnetic field strength..: 1149.02 HCNT ----- Depth reference ----------------------- Magnetic dec (+E/W-) . . . . . : 26.22 degrees Permanent datum... .......: MEAN SEA LEVEL Magnetic dip.. ...........: 80.75 degrees Depth reference..........: Driller's pipe tally GL above permanent... ....: 48.50 ft ----- MWD survey Reference Criteria --------- KB above permanent... ....: n/a Reference G... ... ........: 1002.68 mGal DF above permanent.......: 76.48 ft Reference H..... .........: 1149.02 HCNT Reference Dip...... ... ...: 80.75 degrees ----- Vertical section origin---------------- Tolerance of G...... .....: (+/- ) 2.50 mGal Latitude (+N/S-)......... : 0.00 ft Tolerance of H.. .........: (+/-) 6.00 HCNT Departure (+E/W-) . . . . . . . . : 0.00 ft Tolerance of Dip.. ... ....: (+/-) 0.45 degrees ----- Platform reference point--------------- ----- Corrections --------------------------- Latitude (+N/S-)......... : -999.25 ft Magnetic dec (+E/W-) . . . . . : 26.22 degrees Departure (+E/W-) . . . . . . . . : -999.25 ft Grid convergence (+E/W-) . : 0.00 degrees Total az corr (+E/W-) . . . . : 26.22 degrees Azimuth from rotary table to target 328.16 degrees (Total az corr = magnetic dec - grid conv) Sag applied Y/N : No degree: 0.00 c}2001 Anadrill IDEAL ID6_1C_10 ) ) ANADR~LL SCHLUMBERGER Survey Report 17-0ct-2001 11:31:37 Page 2 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 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 qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- -------- ------ ------- ------ -------- -------- ---------------- --------------- 1 0.00 0.00 165.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.17 7.40 100.00 100.00 0.11 0.15 0.02 0.15 7.40 0.17 GYR 3 178.00 0.37 24.51 78.00 178.00 0.34 0.49 0.14 0.51 15.75 0.27 GYR 4 269.00 0.60 123.78 91. 00 269.00 0.07 0.49 0.66 0.82 53.07 0.83 GYR 5 361. 00 2.05 142.09 92.00 360.97 -2.00 -1.07 2.07 2.33 117.42 1. 62 GYR 6 453.00 2.67 145.20 92.00 452.89 -5.78 -4.13 4.30 5.96 133.84 0.69 GYR 7 548.00 2.70 144.92 95.00 547.79 -10.22 -7.78 6.85 10.37 13 8.63 0.03 GYR 8 638.00 2.51 149.53 90.00 637.69 -14.31 -11.21 9.07 14.42 141.03 0.31 GYR 9 731. 00 1. 84 148.96 93.00 730.63 -17.84 -14.25 10.87 17.92 142.65 0.72 GYR 10 821.00 1.22 165.44 90.00 820.59 -20.20 -16.41 11.86 20.25 144.15 0.84 GYR 11 917.00 1.10 247.44 96.00 916.58 -21.02 -17.75 11.26 21. 03 147.61 1. 59 GYR 12 1039.98 3.99 322.56 122.98 1039.45 -16.57 -14.81 7.57 16.63 152.93 3.14 IFR_MSA 13 1133.81 5.83 334.53 93.83 1132.93 -8.59 -7.91 3.54 8.67 155.93 2.23 IFR_MSA 14 1226.89 6.85 340.54 93.08 1225.44 1. 53 1. 59 -0.35 1. 63 347.69 1. 31 IFR_MSA 15 1318.97 8.42 343.95 92.08 1316.70 13.38 13 .25 -4.04 13.85 343.04 1. 77 IFR_MSA 16 1412.44 11.51 345.04 93.47 1408.75 28.90 28.83 -8.34 30.02 343.87 3.31 IFR_MSA 17 1506.65 13.78 349.12 94.21 1500.67 48.37 48.94 -12.89 50.61 345.25 2.59 IFR_MSA 18 1598.38 16.16 348.78 91.73 1589.28 70.52 72.19 -17.43 74.26 346.42 2.60 IFR_MSA 19 1693.70 17.70 350.02 95.32 1680.47 96.39 99.47 -22.52 101.99 347.24 1. 66 IFR_MSA 20 1816.24 17.34 344.09 122.54 1797.33 131. 24 135.38 -30.76 138.83 347.20 1. 49 IFR_MSA 21 1880.53 17.14 338.78 64.29 1858.74 149.76 153.43 -36.81 157.79 346.51 2.47 IFR_MSA 22 1974.01 19.04 338.02 93.48 1947.59 178.33 180.41 -47.51 186.56 345.25 2.05 IFR_MSA 23 2066.23 21. 05 340.03 92.22 2034.22 209.36 209.93 -58.80 218.01 344.35 2.30 IFR_MSA 24 2159.26 23.45 339.51 93.03 2120.32 243.86 242.98 -70.98 253.14 343.71 2.59 IFR_MSA 25 2249.31 25.59 338.71 90.05 2202.25 280.55 277.89 -84.32 290.40 343.12 2.40 IFR_MSA 26 2343.01 27.91 336.94 93.70 2285.91 322.13 316.93 -100.26 332.41 342.45 2.62 IFR_MSA 27 2434.79 31.41 333.06 91. 78 2365.66 367.20 358.03 -119.52 377.45 341. 54 4.35 IFR_MSA 28 2528.19 34.95 331.06 93.40 2443.83 418.19 403.15 -143.50 427.93 340.41 3.97 IFR_MSA 29 2621.45 38.41 326.25 93.26 2518.62 473.85 450.64 -172.53 482.54 339.05 4.82 IFR_MSA 30 2696.38 42.23 325.54 74.93 2575.74 522.29 490.77 -199.72 529.85 337.86 5.13 IFR_MSA c)2001 Anadrill IDEAL ID6_1C_10 ). ) ANADRFLL SCHLUMBERGER Survey Report 17-0ct-2001 11:31:37 Page 3 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- -------- ------ ------- ------ -------- -------- ---------------- --------------- 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 (degl tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- = -------- ------ ------- ------ -------- -------- ---------------- --------------- 31 2794.06 41. 49 324.80 97.68 2648.49 587.38 544.28 -236.95 593.62 336.47 0.91 IFR_MSA 32 2887.44 41.44 324.42 93.38 2718.47 649.09 594.69 -272.76 654.25 335.36 0.27 IFR_MSA 33 2980.25 40.56 324.09 92.81 2788.51 709.84 644.10 -308.33 714.10 334.42 0.98 IFR_MSA 34 3073.61 38.78 326.65 93.36 2860.38 769.35 693.11 -342.21 772.99 333.72 2.59 IFR_MSA 35 3166.81 38.15 327.76 93.20 2933.35 827.31 741.84 -373.62 830.61 333.27 1. 00 IFR_MSA 36 3260.16 38.83 326.96 93.35 3006.42 885.41 790.76 -404.95 888.42 332.88 0.90 IFR_MSA 37 3352.98 38.10 328.10 92.82 3079.09 943.14 839.47 -435.95 945.92 332.56 1.10 IFR_MSA 38 3445.65 37.62 328.42 92.67 3152.26 1000.01 887.84 -465.87 1002.64 332.31 0.56 IFR_MSA 39 3537.98 38.42 328.63 92.33 3225.00 1056.88 936.34 -495.57 1059.40 332.11 0.88 IFR_MSA 40 3631.20 39.18 328.41 93.22 3297.64 1115.29 986.15 -526.07 1117.70 331.92 0.83 IFR_MSA 41 3723.33 40.63 328.02 92.13 3368.32 1174.39 1036.39 -557.20 1176.68 331.74 1. 60 IFR_MSA 42 3816.89 42.51 326.19 93.56 3438.31 1236.45 1088.50 -590.93 1238.56 331.50 2.39 IFR_MSA 43 3910.12 41. 66 326.69 93.23 3507.50 1298.91 1140.57 -625.47 1300.81 331.26 0.98 IFR_MSA 44 4002.32 40.29 326.34 92.20 3577.11 1359.34 1190.99 -658.83 1361.07 331.05 1. 51 IFR_MSA 45 4095.74 39.39 326.70 93.42 3648.84 1419.16 1240.91 -691.84 1420.74 330.86 0.99 IFR_MSA 46 4189.30 39.16 324.83 93.56 3721.27 1478.33 1289.87 -725.16 1479.74 330.66 1. 29 IFR_MSA 47 4282.05 40.34 324.49 92.75 3792.58 1537.53 1338.25 -759.46 1538.73 330.42 1. 29 IFR_MSA 48 4375.53 42.11 323.33 93.48 3862.89 1598.96 1388.02 -795.76 1599.95 330.17 2.06 IFR_MSA 49 4468.96 44.10 323.14 93.43 3931.10 1662.57 1439.16 -833.97 1663.34 329.91 2.13 IFR_MSA 50 4562.05 44.15 325.18 93.09 3997.92 1727.21 1491.70 -871.92 1727.83 329.69 1. 53 IFR_MSA 51 4654.97 43.80 325.04 92.92 4064.79 1791.64 1544.62 -908.82 1792.15 329.53 0.39 IFR_MSA 52 4747.57 42.69 325.60 92.60 4132.24 1855.00 1596.79 -944.92 1855.43 329.38 1.27 IFR_MSA 53 4840.25 42.73 326.25 92.68 4200.35 1917.82 1648.86 -980.14 1918.18 329.27 0.48 IFR_MSA 54 4934.18 42.60 326.21 93.93 4269.41 1981.44 1701.77 -1015.53 1981.75 329.17 0.14 IFR_MSA 55 5027.28 42.24 326.31 93.10 4338.14 2044.20 1754.00 -1050.41 2044.47 329.08 0.39 IFR_MSA 56 5120.78 41. 67 326.45 93.50 4407.68 2106.68 1806.05 -1085.02 2106.91 329.00 0.62 IFR_MSA 57 5213.70 40.78 327.08 92.92 4477.56 2167.90 1857.27 -1118.58 2168.10 328.94 1. 06 IFR_MSA 58 5307.58 40.10 325.94 93.88 4549.01 2228.77 1908.05 -1152.18 2228.94 328.87 1. 07 IFR_MSA 59 5402.00 39.80 325.62 94.42 4621.40 2289.34 1958.19 -1186.27 2289.48 328.79 0.39 IFR_MSA 60 5494.72 39.05 325.50 92.72 4693.02 2348.17 2006.75 -1219.57 2348.28 328.71 0.81 IFR_MSA c)2001 Anadrill IDEAL ID6_1C_10 ) ) ANADR~LL SCHLUMBERGER Survey Report 17-0ct-2001 11:31:37 Page 4 of 4 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- -------- ------ ------- ------ -------- -------- ---------------- --------------- 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 (degl tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ---- = -------- ------ ------- ------ -------- -------- ---------------- --------------- 61 5587.73 38.73 325.16 93.01 4765.41 2406.49 2054.77 -1252.79 2406.57 328.63 0.41 IFR_MSA 62 5681.18 39.40 325.33 93.45 4837.97 2465.31 2103.16 -1286.36 2465.36 328.55 0.73 IFR_MSA 63 5774.11 40.17 325.30 92.93 4909.38 2524.70 2152.06 -1320.20 2524.74 328.47 0.83 IFR_MSA 64 5868.10 41. 46 326.64 93.99 4980.52 2586.08 2202.97 -1354.57 2586.11 328.41 1. 66 IFR_MSA 65 5961.16 41. 90 327.62 93.06 5050.02 2647.95 2254.95 -1388.16 2647.97 328.38 0.84 IFR_MSA 66 6054.81 41. 63 327.72 93.65 5119.87 2710.33 2307.66 -1421.52 2710.35 328.37 0.30 IFR_MSA 67 6147.26 41. 20 327.15 92.45 5189.20 2771.48 2359.20 -1454.43 2771.49 328.35 0.62 IFR_MSA 68 6241. 35 41.10 326.49 94.09 5260.05 2833.38 2411.02 -1488.31 2833.39 328.31 0.47 IFR_MSA 69 6333.43 40.74 326.92 92.08 5329.63 2893.67 2461.43 -1521.42 2893.68 328.28 0.50 IFR_MSA 70 6426.38 40.65 327.72 92.95 5400.11 2954.27 2512.44 -1554.15 2954.27 328.26 0.57 IFR_MSA 71 6521.13 40.82 327.42 94.75 5471.90 3016.09 2564.63 -1587.31 3016.10 328.25 0.27 IFR_MSA 72 6614.84 41.10 327 . 84 93.71 5542.67 3077 . 52 2616.51 -1620.19 3077.52 328.23 0.42 IFR_MSA 73 6707.09 41.17 327.76 92.25 5612.15 3138.21 2667.86 -1652.53 3138.21 328.23 0.09 IFR_MSA 74 6801. 41 40.22 327.96 94.32 5683.66 3199.70 2719.94 -1685.25 3199.71 328.22 1. 02 IFR_MSA 75 6893.63 39.47 327.00 92.22 5754.46 3258.78 2769.76 -1717.01 3258.79 328.20 1. 05 IFR_MSA 76 6987.17 38.76 327.30 93.54 5827.04 3317.79 2819.33 -1749.02 3317.79 328.19 0.79 IFR_MSA 77 7080.33 38.22 327.36 93.16 5899.96 3375.76 2868.14 -1780.32 3375.76 328.17 0.58 IFR_MSA 78 7174.64 37.65 327 . 06 94.31 5974.34 3433.73 2916.88 -1811.72 3433.73 328.16 0.64 IFR_MSA 79 7267.49 36.16 326.15 92.85 6048.58 3489.46 2963.43 -1842.40 3489.47 328.13 1. 71 IFR_MSA 80 7361.21 36.19 326.46 93.72 6124.24 3544.75 3009.46 -1873.09 3544.76 328.10 0.20 IFR_MSA 81 7452.57 35.27 326.71 91. 36 6198.40 3598.08 3053.99 -1902.47 3598.09 328.08 1. 02 IFR_MSA 82 7545.59 36.12 327.54 93.02 6273.94 3652.35 3099.57 -1931.92 3652.35 328.07 1. 05 IFR_MSA 83 7638.07 34.75 326.35 92.48 6349.29 3705.95 3144.52 -1961.16 3705.96 328.05 1. 66 IFR_MSA 84 7731. 67 35.90 326.54 93.60 6425.66 3760.05 3189.62 -1991.07 3760.06 328.03 1. 23 IFR_MSA 85 7824.93 35.62 327.07 93.26 6501.34 3814.53 3235.22 -2020.91 3814.54 328.01 0.45 IFR_MSA 86 7918.28 35.29 327.37 93.35 6577.38 3868.67 3280.75 -2050.23 3868.69 328.00 0.40 IFR_MSA 87 8011. 82 34.28 327.14 93.54 6654.20 3922.03 3325.63 -2079.09 3922.05 327.99 1. 09 IFR_MSA 88 8105.72 33.13 326.94 93.90 6732.32 3974.13 3369.35 -2107.44 3974.15 327.98 1. 23 IFR_MSA 89 8199.38 32.45 326.82 93.66 6811. 05 4024.83 3411.83 -2135.15 4024.86 327.96 0.73 IFR_MSA 90 8292.77 31.11 327.26 93.39 6890.44 4074.01 3453.10 -2161.91 4074.04 327.95 1.46 IFR_MSA 91 8351.60 30.16 327.10 58.83 6941.06 4103.98 3478.29 -2178.16 4104.01 327.94 1. 62 IFR_MSA Projected to TD 92 8435.00 30.16 327.10 83.40 7013.17 4145.88 3513.47 -2200.92 4145.91 327.94 0.00 MWD Sehlamberuer L-115 bp Lubinski ) MSL MSL Minimum Curvature 327.900° N 0.000 It, E 0.000 f1 KB 77.000 It relative to 44.100 It relative to +26.216° 57465.926 nT 80.757° Geodetic Survey Report - Survey I DLS Computation Method: Vertical Section Azimuth: Vertical Section Origin: TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Declination Date: 500292303500 L-115 I October 19, 2001 108.895° I 4204.62 Itl 5.741 October 19, 2001 BGGM 2001 True North +26.216° Well Head Magnetic Declination Model North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: US Feet 10.600 NAD27 Alaska State Planes, Zone 4, N 70.35058776, W 149.3252065C N 5978263.790 ItUS, E 583112.730 ItUS +0.63550213° 0.99990785 Structure I Slot: Well: Borehole: UWUAPI#: ey Name I Date: ratio: Grid Coo stem: LOt Long: Locatit :: VIX: Surv TortI AHD DDIIERD Grid Convergence Angle: Grid Scale Factor Pads) 18-Apr-2002 BP Exploration Alaska Prudhoe Bay Unit - WOA (Dri L-Pad/L-115 L- 5 L- 5 Report Date: Client: Field: Longitude 149.32520650 149.32520634 149.32520537 149.3252 149.3251 0117 8971 w w w w w N 70.35058776 N 70.35058816 N 70.35058910 N 70,35058911 N 70.35058483 G 2.73 2.75 2.86 3.38 4.8 Grid Coordinates Easting (ftUS) 58311 58311 58311 58311 5831 Northing ftUS: 5978263.79 5978263.94 5978264.28 5978264.29 5978262.74 DLS '/100ft' 0.17 0.27 0.83 .62 0.14 0.66 2.07 0.15 0.49 0.49 -1.07 0.11 0.34 0.07 -2.01 100.00 178.00 269.00 360.97 123.78 142.09 7.40 24.51 0.17 0.37 0.60 2.05 00.00 78.00 269.00 361.00 Station ID ) 149.32517157 149.3251508f 149.3251328& 149.32511825 49.32511024 w w w w w N 70,35057648 N 70.35056651 N 70.35055713 N 70.35054884 N 70.35054292 5831 5831 58312 583123.76 583124.77 7.08 9.67 .92 5978259.71 5978256.09 5978252.68 5978249.67 5978247,51 0.69 0.03 0,31 0.72 0.84 4.30 6.85 9.07 10.87 11.86 -4.13 -7.78 -11,21 -14.25 -16.41 -5.79 -10.23 -14.32 -17.85 -20.20 452.89 547.79 637.69 730.63 820.59 145.20 144.92 149.53 148.96 65.44 2.67 2.70 2.51 .84 .22 453.00 548.00 638.00 731.00 821,00 49.32511507 49.32514504 49.32517779 49.32520931 49.32523930 w w w w w N 70.35053926 N 70.35054730 N 70.35056614 N 70.35059210 N 70.35062394 583124.19 583120.46 583116.35 583112.37 583108.54 5978246.16 5978249.07 5978255.92 5978265.37 5978276.99 1.59 3.14 2.23 1.31 .77 11.26 7.57 3.54 -0.35 -4.04 -17,75 -14.81 -7.91 1.59 13.25 -21.03 -16.57 -8.58 1.53 13.37 916.58 1039.45 1132.93 1225.44 1316.70 247.44 322.56 334.53 340.54 343.95 o 3.99 5,83 6.85 8.42 917.00 1039.98 1133.81 1226.89 318.97 49.32527421 49.32531110 w w N 70.35066653 N 70.35072145 583104.07 583099.30 5978292,53 5978312.58 3.31 2.59 -8.34 -12.89 28.83 48.94 28,86 48.30 1408.75 1500.67 345.04 349.12 11.51 13.78 1412.44 1506.65 4/18/2002-1 :40 PM of 4 Page L-115 ASP Final Survey,xls Station ID DLS g Longitude - U'/100.!!; nUS) 2.60 583094.50 N 70.35078498 W 149.32534801 1.66 583089.11 N 70.35085951 W 149.32538936 1.49 583080.47 N 70.35095762 W 149.32545621 1880.53 17.14 338.78 1858.74 149.54 153.43 -36.81 2.47 5978416.79 583074.22 N 70.35100692 W 149.32550537 1974.01 19.04 338.02 1947.59 178.08 180.41 -47.51 2.05 5978443.65 583063.23 N 70,35108063 W 149.32559218 2066.23 21.05 340.03 2034.22 209.08 209.93 -58.80 2.30 5978473.04 583051.61 N 70.35116127 W 149.32568382 2159.26 23.45 339.51 2120,32 243,55 242.98 -70.98 2.59 5978505.94 583039.06 N 70.35125155 W 149.32578277 2249.31 25,59 338.71 2202.25 280.21 277.89 -84.32 2.40 5978540.70 583025.34 N 70.35134692 W 149.32589102 2343.01 27,91 336.94 2285.91 321.75 316.93 -100.26 2.62 5978579.55 583008.97 N 70,35145357 W 149.32602043 ) 2434.79 31.41 333.06 2365.66 366.80 358.03 -119.52 4.35 5978620.44 582989.26 N 70.35156585 W 149.3261767ï 2528.19 34.95 331.06 2443.83 417.77 403.15 -143.50 3.97 5978665.29 582964,79 N 70.35168913 W 149.32637146 2621 .45 38.41 326.25 2518.62 473.43 450.64 -172.53 4.82 5978712.45 582935.23 N 70.35181886 W 149.32660720 2696.38 42.23 325.54 2575,74 521.87 490.77 -199.72 5.13 5978752.27 582907.60 N 70.35192849 W 149.32682795 2794.06 41 .49 324.80 2648.49 586.98 544.28 -236.95 0.91 5978805.36 582869,78 N 70.35207467 W 149.32713018 2887.44 41.44 324.42 2718.47 648.71 594.69 -272.76 0.27 5978855.36 582833.42 N 70.35221237 W 149.32742092 2980.25 40.56 324.08 2788.51 709.48 644.10 -308.33 0.98 5978904.37 582797,31 N 70.35234737 W 149.32770974 3073.61 38.78 326.65 2860.38 769.00 693.11 -342.21 2.59 5978953.00 582762.88 N 70.35248126 W 149.32798486 3166.81 38.15 327.76 2933.35 826.97 741.84 -373.62 1.00 5979001.37 582730,94 N 70.35261438 W 149.32823983 3260,16 38.83 326.96 3006.42 885.07 790.76 -404.95 0,90 5979049.94 582699.07 N 70.35274802 W 149.32849428 3352.98 38.10 328.1 0 3079.09 942,80 839.47 -435.95 1.10 5979098.29 582667.53 N 70.35288108 W 149.32874599 3445.65 37.62 328.42 3152.26 999.67 887.84 -465.87 0.56 5979146.32 582637.08 N 70.35301321 W 149.32898893 3537.98 38.42 328.63 3225.00 1056.54 936.34 -495.57 0.88 5979194.49 582606,86 N 70.35314571 W 149.32923003 3631 .20 39.18 328.41 3297.64 1114.95 986.15 -526.07 0.83 5979243.96 582575.81 N 70.35328179 W 149.32947772 3723.33 40.63 328.02 3368.32 1174.05 1036.39 -557.20 1.60 5979293.84 582544.12 N 70.35341903 W 149.32973052 3816.89 42.51 326.19 3438.31 1236.11 1088.50 -590.93 2.39 5979345.57 582509.82 N 70.35356138 W 149.3300043£ ) 3910.12 41.66 326.69 3507,50 1298.58 1140.57 -625.47 0.98 5979397.24 582474.70 N 70.35370361 W 149.33028489 4002.32 40.29 326.34 3577.11 1359.02 1190.99 -658.83 1.51 5979447,29 582440.80 N 70.35384136 W 149.33055573 4095,74 39.39 326.70 3648.84 1418.85 1240.91 -691.84 0.99 5979496.83 582407,23 N 70.35397772 W 149.33082384 4189.30 39.16 324.83 3721 .27 1478.03 1289.87 -725.16 1.29 5979545.42 582373.38 N 70.35411147 W 149.33109438 4282.05 40.34 324.49 3792.58 1537.24 1338.25 -759.46 1.29 5979593.41 582338.54 N 70.35424363 W 149.33137297 4375.53 42.11 323.33 3862.89 1598.69 1388.02 -795.76 2.06 5979642.77 582301.70 N 70.35437959 W 149.33166770 4468.96 44.10 323.14 3931.10 1662.32 1439.16 -833.97 2.13 5979693.48 582262.93 N 70.35451929 W 149.33197802 4562.05 44.15 325.18 3997,92 1726.98 1491.70 -871.92 1.53 5979745.58 582224.41 N 70.35466280 W 149.33228616 4654.97 43.80 325.04 4064.79 1791.43 1544.62 -908.82 0.39 5979798.09 582186.92 N 70.35480736 W 149.33258587 4747.57 42.69 325,60 4132.24 1854.80 1596.79 -944.92 1.27 5979849.85 582150.25 N 70.35494987 W 149.33287904 L-115 ASP Final Survey.xls Page 2 of 4 4/18/2002-1 :40 PM Longitude 149.33316508 149.33345245 149.33373575 w w w N 70.35509211 N 70.35523666 N 70.3553793 G -1015.53 -1050.41 N/-S ft' 1648.86 1701.77 1754.00 vSec ..a. 1917.63 1981.26 2044.03 4200.35 4269.42 4338.14 .21 .31 Station ID 149.33401684 149,33428944 149.33456231 149.33483923 149.33510970 w w w w w N 70.35552150 N 70.35566141 N 70.35580014 N 70.35593708 N 70.35606974 582007.85 581973.72 581939.57 581904.92 581871.09 5980005.86 5980057.52 5980108.36 5980158.77 5980208.5 5980256.70 0.39 0.62 1.06 1.07 0.39 0.81 -1085.02 -1118.58 -1152.18 -1186.27 -1219.57 1806.05 1857.27 1908.05 1958.19 2006.75 2106.52 2167.74 2228.62 2289.21 2348.04 4407.68 4477.56 4549,01 4621.40 4693.02 326.45 327.08 325.94 325.62 325.50 41.67 40.78 40.10 39.80 39.05 5027.28 5120.78 5213.70 5307,58 5402,00 5494.72 ) 149.33537950 149.3356521 Ó 149.33592704 149.33620621 49.33647899 w w w w w N 70.35620092 N 70.35633309 N 70.35646666 N 70.35660574 N 70.35674772 581837.35 581803.24 581768.87 581733.94 581699.78 5980304.35 5980352.36 5980400.87 5980451 .40 5980502.99 0.41 0.73 0.83 1.66 0.84 -1252.79 -1286.36 -1320.20 -1354.57 -1388.16 2054.77 2103.16 2152.06 2202.97 2254.95 2406.38 2465.20 2524.6 2586.00 2647.88 4765.41 4837,97 4909.38 4980.52 5050.02 325.16 325.33 325.30 326.64 327.62 38.73 39.40 40.17 41 .46 41.90 5587.73 5681 .18 5774.11 5868.10 5961 .16 49.33674997 49.33701735 49,33729259 149.33756154 149.33782736 w w w w w N 70,35689169 N 70.35703248 N 70.35717403 N 70.35731173 N 70.35745107 581665.84 581632.36 581597.91 581564,24 581530.96 5980555.32 5980606.49 5980657,92 5980707.96 5980758.60 0.30 0.62 0.47 0.50 0,57 -1421.52 -1454.43 -1488.32 -1521 .42 -1554.15 2307.66 2359.20 .02 .43 2512.44 2411 2461 2710.26 2771.41 2833.31 2893.61 2954.21 5119.87 5189.20 5260.05 5329.63 5400.11 327.72 327.15 326.49 326.92 327.72 41.63 41.20 41.10 40.74 40.65 6054.81 6147.26 6241 .35 6333.43 6426.38 149,33809672 149.33836389 149.33862659 149.33889239 149.33915040 w w w w w 581497.23 N 70.35759362 581463.77 N 70.35773535 581430.87 N 70.35787561 581397.58 N 70.35801786 581365.27 N 70.35815395 5980810.41 5980861.92 5980912.91 5980964.61 5981014.08 0.27 0.42 0.09 .02 .05 -1587.31 -1620.19 -1652.53 -1685.25 -1717.01 2564.63 2616.51 2667.86 2719.94 2769.76 3016.04 3077.47 3138.16 3199.66 3258.74 5471.90 5542.67 5612.15 5683.66 5754.46 327.42 327.84 327.76 327.96 327.00 40,82 41.10 41,17 40.22 39.47 6521.13 6614.84 6707.09 6801.41 6893.63 ) 149.33941046 149.3396647: 149.33991982 149.34016907 149.34041840 w w w w w N 70.35828936 N 70.35842268 N 70.35855581 N 70.35868297 N 70.35880868 581332.71 581300,88 581268.95 581237.75 581206.56 5981063.29 5981111.74 5981160.12 5981206.33 5981252.01 0,79 0.58 0.64 1.71 0.20 -1749.02 -1780.32 -1811.72 -1842.40 -1873.09 2819.33 2868.14 2916.88 2963.43 3009.46 3317.75 3375.72 3433.70 3489.44 3544.73 5827.04 5899.96 5974.34 6048.58 6124.24 327.30 327.36 327.06 326.15 326.46 38,76 38.22 37.65 36.16 36.19 6987.17 7080.33 7174.64 7267.49 7361 .21 149,34065710 149,34089642 149.34113395 149.34137699 149,34161942 w w w w w N 70.35893032 N 70.35905483 N 70.35917758 N 70.35930077 N 70.35942534 581176.69 581146.73 581117.00 581086.59 581056.25 5981296.21 5981341.45 5981386.07 5981430,83 5981476.10 .02 .05 .66 .23 0.45 -1902.47 -1931.92 -1961.16 -1991.07 -2020.91 3053.99 3099.57 3144.51 3189.62 3235.22 3598.07 3652.34 3705.94 3760.05 3814.54 6198.40 6273.94 6349.29 6425.66 6501,34 326.71 327.54 326.35 326.54 327,07 35.27 36,12 34.75 35.90 35.62 7452,57 7545,59 7638.07 7731 .67 7824,93 149.34185762 149.34209214 w w N 70.35954969 N 70.35967229 581026.44 580997.08 5981521.29 5981565.85 0.40 .09 -2050.23 -2079.09 3280.75 3325.63 3868.68 3922.04 6577.38 6654.20 327.37 327.14 35.29 34.28 7918.28 8011 .82 4/18/2002-1 :40 PM Page 3 of 4 L-115 ASP Final Survey.xls Geol hie Coordinates Station ID DLS Latitud~ ] Longitude U'/100ft' - ;;1_ 1.23 580968.25 N 70.35979171 W 149,34232247 8199.38 ,2 6811.05 0.73 5981651.41 580940.07 N 70.35990774 W 149.34254765 8292.776 6890.44 1.46 5981692.38 580912.86 N 70.36002045 W 149.34276509 8351.60 30.16 327.10 6941.06 4104.01 3478.29 -2178.16 1.62 5981717.38 580896.33 N 70,36008927 W 149.34289711 8435.00 30.16 327,10 7013.17 4145.91 3513.47 -2200.92 0.00 5981752.31 580873.19 N 70.36018536 W 149.34308205 ) ) L-115 ASP Final Survey.xls Page 4 of 4 4/18/2002-1 :40 PM bp .i. ,\,f.'". ...''Ot;. ~~. ..~i ¡~. .,~,.~\\.. ". ~ ~ To: Date: February 10, 2002 From: Bruce W. Smith GPB Borealis Development Engineer Subject: Dual Injector Intee:ritv The Borealis Field has been developed in Kuparuk aged hydrocarbon zones, in an area that directly over lays oil discoveries in the Schrader Bluff Pool, which is expected to be called the Orion Field. The Orion field development is in the study and planning stage, with Borealis in the full development stage. Using the planning information currently developed for the Orion field it was determined that many of the same identified injection well locations planned for Borealis were near the planned intersection points needing injection in the Orion horizon. Dual Injectors are planned to be used for certain injector locations. These injectors would be based on a BP design called Ultra-Slim Hole basis. This basis is 9 5/8 inch surface casing set in the SV-1 formation at approximately 2900 TVD. A long string would be placed to TD and cemented to 500 ft above the Schrader Bluff formation. This string would be evaluated using a cement evaluation log such as a USIT, CBl, CPT or other approved devices with the rig on location. Once cement integrity is proven, the Schrader Bluff Formation would be selectively perforated, A straddle completion would be run with packers placed above and below the perforated interval. The straddle would consist a permanent packer (such as a Baker S- 3 style) set approximately 200 feet above the Kuparuk Formation, a second permanent packer (such as a Baker Premium style) would be set approximately 200 feet above the Schrader Bluff perforations. The straddle tubular would be made up of 3 Y2 inch l-80 material standard tubing such as 9.2# l-80 premium thread and 4 Y2" 12.6# l-80 premium thread materials. Flow and integrity control of the straddle would be maintained with two or more Schlumberger (Camco) MMG-W water flood injection mandrels. These mandrels accept injection valves, which are double-checked. Additionally the mandrels each an external check as part of the body. A proposed testing procedure is listed below; this method is split between original installation and future testing procedures. ~~<è: <;~\\.'" ~~,Ù~~ -\\r..\,> ~~~~~ \.t'\ ~ ~\-\,,~ \c ~~~~<> +\Nt.~~ ~~c:...\ <'2.O'4\.e. \~~~~~. I'~ð\~~O~ ~~ ~fè. ~(è~~~-\icl-~ A.~~ro~\ 't> Ç'q tl:>""""<è.~~ ~ ?yv(7~ cc: ~\\~--Ö~ ~ .~ Dual Injector Integrity Welllntearitv TestinQ MechanicallnteQritv Test (MIT) OriQinal Completion (RiQ present) 1. After Well Has been cased and cemented, casing, wellhead and BOP will be pressured tested to meet or exceed the requirements of 20 AAC 25.410. 2. The casing will be evaluated with a cement evaluation log. 3. Once this log has been evaluated and cement is deemed to provide isolation, the rig will perforate using TCP guns to shoot the Schrader Bluff formation at or slightly above balance. 4. The completion will be run and set. 5. The completion will be run with dummy valves in place in the water injection mandrels. 6. The lower injection zone of the Kuparuk will be perforated after the rig moves off. 7. Pressure Test Tubing for 30 min. 8. Pressure test tubing and annulus 9. Bleed off tubing with pressure on annulus. Prior to placinQ well on Kuparuk Injection (Initial AOGCC witnessed MIT) 1. Well on injection and warmed up and stable 2. Pressure test the annulus and hold for 30 min. UsinQ the same MIT testinQ schedule as PBU (AOGCC Witnessed normal scheduled testing) 1. Safe out injector 2. Freeze protect injector 3. Place plug in tubing tail profile 4. Pressure test tubing to required pressure. This test will prove integrity of tubing, plug in tail pipe, water injection mandrels and dummies in water Injection mandrels. 5. Bleed off pressure 6. Pressure test annulus to required pressure. This test will prove integrity of casing, wellhead, packer and reverse flow to tubing. 7. Bleed off pressure. 8. Pull plug and return well to injection. InteQritv issues durina Injection (Kuparuk injection only) 1. Water Injection mandrels have external check valves 2. Water Injection valves will be dummied wi pressure test. 3. Annulus, Injection Rate and Pressure will be monitored daily. 4. Normal cycle of AOGCC Witnessed testing (AOGCC MIT) Intearitv Issues durina dual injection (Kuparuk and Schrader Bluff) .~ .- /' .... Dual Injector Integrity 1. Water Injection mandrels have external check valves 2. Water Injection valves have two check valves internally 3. An Injection safety valve, (similarly to a Halliburton MC flapper type injection valve) would be installed in the tailpipe. When the injector is shut-in, this flapper would close and prevent cross flow from the Kuparuk to the Schrader Bluff. 4. Annulus, Injection Rate and Pressure will be monitored daily. 5. Normal cycle of AOGCC Witnessed testing (AOGCC MIT) Intearitv issues durina In¡ection (Schrader Bluff injection only) 1. A plug would be placed in the tailpipe to prevent injection into the Kuparuk. 2. Water Injection mandrels have external check valves 3. Water Injection valves have dual check valves. 4. Annulus, Injection Rate and Pressure will be monitored daily. 5. Normal cycle of AOGCC Witnessed testing (AOGCC MIT) Please call (Bruce Smith 440-8008, hm: 345-2948, office: 564-5093) if there are any questions. ';~ ~. J1Alt ~J\SJ'bV k ~r ~/1'1 v0sz. '-..:. STATE OF ALASKA .~. ALASKAulL AND GAS CONSERVATION COMM,~.310N APPLICATION FOR SUNDRY APPROVAL 1, Type of Request: 0 Abandon o Alter Casing o Change Approved Program 2. Name of Operator BP Exploration (Alaska) Inc. o Suspend 0 Plugging 0 Time Extension 0 Perforate o Repair Well 0 Pull Tubing 0 Variance II Other o Operation Shutdown 0 Re-Enter Suspended Well 0 Stimulate Re-Enter Ops Shutdown 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: o Development o Exploratory o Stratigraphic 181 Service 6. Datum Elevation (DF or KB) RKB = 76.48' 7. Unit or Property Name Prudhoe Bay Unit 4. Location of well at surface 2543' NSL, 3802' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 479' NSL, 521' WEL, SEC. 28, T12N, R11 E, UM At effective depth 734' NSL, 685' WEL, SEC. 28, T12N, R11 E, UM At total depth 776' NSL, 712' WEL, SEC. 28, T12N, R11 E, UM 12. Present well condition summary Total depth: measured 8. Well Number L-115i 10. API Number 50- 029-23035-00 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) Effective depth: true vertical measured true vertical 8435 feet 7014 feet 8335 feet 6927 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 80' 2709' 20" 9-5/8" 260 sx Arctic Set (Approx.) 484 sx Articset Lite, 249 sx Class 'G' 107' 2735' 107' 2735' 8389' 7" 210 sx CemCrete, 345 sx LARC 8417' 6925' Perforation depth: measured None RECEIVED true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 2996' FEB 0 4 2002 Packers and SSSV (type and measured depth) None AlalklOiI & Ga&ConI. CGmmi88iOn Anchorage 13. Attachments 181 Description Summary of Proposal o Detailed Operations Program 15. Status of well classifications as: o Oil 0 Gas 0 Suspended Service Injector o BOP Sketch 14. Estimated date for commencing operation February 18, 2002 16. If proposal was verbally approved Name of approver Date Approved Contact Engineer Name/Number: Robert Odenthal, 564-4387 17. I hereby certify that the fo going i~~U( and correct to the best of my knowledge Signed ·L)-PV-II C· . <',~ Title Senior Drilling Engineer owe rane' ~. Prepared By Name/Number: Terrie Hubble, 564-4628 Date J / '$ /)01- Approval No. ~ l\O~ Commissioner '- '"'" .t- ~ ~ January 30, 2002 Alaska Oil and Gas Conservation Commission 333 West ih Ave, Suite 100 Anchorage, Alaska 99501 Re: Narrative L-115i Prudhoe Bay API # 50-029-23035 Drilling Permit # 201-140 Operations shutdown # 301-299 On October 21, 2001 operations were suspended/shutdown on the captioned well. We would like to re-enter the well to finish operations as approved by the drilling permit. This re-entry of operations would take place roughly around February 18, 2002. Operations would be comprised of the following: 1. MIRU. 2. N/U BOP's. 3. Pull BPV. 4. Removal of temporary kill string consisting of 75 joints of 4 W' 12.6 Ib/ft L-80 NSCT tubing (2995.5'). 5. Test the casing to 4000 psi for 30 min. 6. Perforate Schrader interval on TCP. 7. Make scraper run and POOH laying down excess drill-pipe. 8. Run the combination 3-1/2" 9.3#, L-80 NSCT / 4-1/2",12.6#, L-80 NSCT completion assembly. Completion as Follows: a 3.813" X nipple at 2000' TVDss. a Two GLMs (4 %" KBG2 upper on with RP shear, lower with dummy) at 3500' TVD (confirm) and two joints above uppermost packer. a 3.813" ID X nipple on a pup joint just above the top Premier packer a Top Baker Premium packer +/- 50' above top Schrader. a 3-1/2" NSTC tubing below top. a Two Injection Mandrels (3 %" x 1-1/2" MMGW with dummies): spaced in the straddle section with 3-1/2" NSCT tubing between. a 3-1/2" tubing NSTC below injection mandrels to lower S-3 packer. a 2.813" ID X nipple on a 10' 3-1/2" pup above Premier packer a Lower packer at approximately 230' above the top Kuparuk interval. Ensure end of tailpipe is 150' above Kuparuk. a 2.813" ID X Nipples in the 3-1/2" tailpipe below the lower packer. (S-3 Packer, 20' pup, X nipple, 10' pup, 10' pup, X nipple, 10' pup, WLEG) a RHC plug in lower 2.813" X nipple 9. Set packers and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. 10. Shear RP valve and install TWC. Test below to 2800 psi. 11. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 12. Remove TWC. 13. Freeze protect the well to -2200' TVD. Allow diesel to U-tube from the annulus to tubing and equalize at 2000' TVD, 14. Rig down and move off. ..! ~. STATE OF ALASKA /----- ALASKAvIL AND GAS CONSERVATION COMMI,;,).:;)ION REPORT OF SUNDRY WELL OPERATIONS 1¡1~. ILh{.:J I 1. Operations performed: B Operation Shutdown 0 Stimulate o Pull Tubing 0 Alter Casing o Plugging 0 Perforate o Repair Well 0 Other 5. Type of well: o Development o Exploratory o Stratigraphic a Service 6. Datum Elevation (DF or KB) RKB = 76.48' 7. Unit or Property Name Prudhoe Bay Unit 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2543' NSL, 3802' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 479' NSL, 521' WEL, SEC. 28, T12N, R11 E, UM At effective depth 734' NSL, 685' WEL, SEC. 28, T12N, R11 E, UM At total depth 776' NSL, 712' WEL, SEC. 28, T12N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8. Well Number L·115i 9. Permit Number / Approval No. 201-140 301-299 10. API Number 50- 029-23035-00 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) Casing Structural Conductor Surface Intermediate Production Liner 8435 feet Plugs (measured) 7014 feet 8335 feet Junk (measured) 6927 feet Length Size Cemented MD TVD 80' 20" 260 sx Arctic Set (Approx.) 107' 107' 2709' 9-5/8" 484 sx Articset Lite, 249 sx Class 'G' 2735' 2735' 8389' 7" 210 sx CemCrete, 345 sx LARC 8417' 6925' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 to 2996' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure NOV 1 5 Z001 ecø.c.t-- AndØ8IJ8 Casing Pressure Tubing Pressure 14. Reoresentative Dailv Average Production or Iniection Data Oil·Bbl Gas·Mcf Water-Bbl Prior to well operation: Subsequent to operation: 15. Attaohments o Copies of Logs and Surveys run a Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge ¡ Si ned Title Technical Assistant 16. Status of well classifications as: o Oil 0 Gas 0 Suspended Service Injector Date U - l ') -0 I Form 10-404 Rev. 06/15/88 Prepared By NameINumber: Sandra Stewman, 564·4750 Submit In Duplicate ., .~ /'"'-. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: Rig Number: Spud Date: 1017/2001 End: 1 0/6/2001 06:00 - 09:00 3.00 MOB P PRE Complete Rig Down in preparation for moving rig to scales 09:00 - 17:00 8.00 MOB P PRE Weigh Rig on scales - derrick up and derrick down. 17:00 - 20:00 3.00 MOB P PRE Move & Spot sub-base and pits over L-115 20:00 - 00:00 4.00 MOB P PRE Repair Top Drive and replace brake bands & pads. RIU Diverter line, hook up lines at interconnect - water, air, steam ect. 10/7/2001 00:00 - 06:00 6.00 RIGU P PRE Cont top dr I brake band repair while take on H20, place bha and dp in pipe shed. 06:00 - 10:00 4.00 RIGU P PRE Cont take on H20, load pipe shed tubulars. 10:00 - 10:30 0.50 BOPSU P SURF Test diverter I all related equip. Test successful. No re-test. 10:30 - 14:00 3.50 DRILL P SURF Pick up 4" dp in sgls, std bk in mast. 14:00 - 15:00 1.00 DRILL P SURF Change out saver sub on top drive, inspect new installed brake bands. 15:00 - 15:30 0.50 DRILL P SURF Pre spud meeting all personnel. 15:30 - 16:00 0.50 DRILL P SURF Fill conductor, inspect mud system for leaks. 16:00 - 21 :00 5.00 DRILL P SURF Make up DCs, hwdp, remainder bha, std bk in mast. Orient mwd, record orientation I strap. 21 :00 - 21 :30 0.50 DRILL P SURF Tag btm at 102 ft, commence drill out conductor shoe I formation. 21 :30 - 00:00 2.50 DRILL P SURF Drill ahead 12 1/4 hole drctnl, 102 - 171 ft. WOB 5, Rot 50, PSI 780, GPM 500, SPM 168 Note: Rig 9-ES accepted this date 0600 hrs. 1 0/8/2001 00:00 - 02:30 2.50 DRILL P SURF Circ I cond mud during wait for vac trucks detained behind Doyon rig move. 02:30 - 00:00 21.50 DRILL P SURF Resume drill ahead 12 1/4 hole 171 - 1566 ft. Gyro surveys 90 ft intervals. WOB 30, RPM 50, SPM 200, PSI 1760, GPM 600, Up 80, Dn 79, Rot 80 ART 5, AST 3 No fill on connections, torque normal, 100 % returns. 1 0/9/2001 00:00 - 02:00 2.00 DRILL P SURF Drlg f/1566' to 1753'. 02:00 - 03:00 1.00 DRILL P SURF Circ sweep. Hole cleaned up. Blow down. Monitor well-OK. Spill Drill-OS-1:45 min. 03:00 - 05:00 2.00 DRILL P SURF POH. Pulled 35k over @ 1285'. 05:00 - 06:00 1.00 DRILL P SURF Stand back BHA. Break out bit. 06:00 - 06:30 0.50 DRILL P SURF PJSM. Service top drive. Change out grabber dies. 06:30 - 07:00 0.50 DRILL P SURF MU bit & BHA. 07:00 - 08:00 1.00 DRILL P SURF RIH. Work through tight spots f/1110' to 1285'. 08:00 - 08:30 0.50 DRILL P SURF Circ thick mud out of hole. 08:30 - 11 :30 3.00 DRILL P SURF Drlg f/1753' to 2125'. 11 :30 - 12:00 0.50 DRILL P SURF Change shacker screens. 12:00 - 16:30 4.50 DRILL P SURF Drlg f/2125' to 2756'--TD. PU: 96k; SO: 80k; Rot: 93k. 650 gpm wI 2380 psi; 60 rpm; 35k on bit. 16:30 - 18:00 1.50 DRILL P SURF Circ & cond mud for short trip. Pump survey @ TD. Orient to Hi-side. Monitor well-OK. 18:00 - 20:00 2.00 DRILL P SURF POH. Intermittent swabbing f/2756' to 2311'. 30k overpulls fl 1469' to 1250'. 50k overpull @ 1115'. Swabbing @ same depths. Pushing mud away on downstrokes. Wiped all areas. 20:00 - 23:00 3.00 DRILL P SURF Stand back HWDP & jars. LD BHA. Clean & clear floor. 23:00 - 00:00 1.00 DRILL P SURF MU 12.25" porcupine hole opener BHA. Printed: 10/22/2001 10:45:23 AM ,.r--\ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: Rig Number: Spud Date: 1017/2001 End: 10/10/2001 00:00 - 02:30 2.50 DRILL P SURF Make up bha #3 I hole opener. Layout 2 galled DCs. 02:30 - 06:00 3.50 DRILL P SURF Flow check, rih hole opener assy to 2604 ft. 06:00 - 06:30 0.50 DRILL P SURF Ream 150 ft to btm. 06:30 - 07:30 1.00 DRILL P SURF Prepare and poh for 9 5/8 csg run. 07:30 - 09:30 2.00 DRILL P SURF Layout BHA #3, clear rig floor. 09:30 - 12:30 3.00 CASE P SURF PJSM, place 9 5/8 running equip on floor, rig up same. Perform dummy run 9 5/8 hgr, record strap. 12:30 - 17:00 4.50 CASE P SURF Flow check, Make up shoe track, thread lock critical connections. Check float equip. Commence rih 9 5/8, 40#, L80, BTC csg. Make up hgr, land at 2735 ft. 17:00 - 20:30 3.50 CASE P SURF Make up cmt hd, circ I cond mud, recip pipe at all times. 20:30 - 00:00 3.50 CASE P SURF Pump 10 bbl CW 100. Test lines to 3500 psi. Test good. Drop btm plug, pump 75 bbls Mudpush XL spacer. Commence cmt 9 5/8 csg as follows: Pump 382 bbls 10.7 lead slurry @ 6 bpm. Pump 52 bbls 15.8 ppg tail slurry. Drop top plug, chase with 10 bbls H2o. Change over rig pumps, displace at 8 bpm, 201 bbls drill mud. ICP 490 psi at 8 bpm, FCP 700 psi at 3 bpm. Bump plug wth 1500 psi. Hold 5 min. Bleed, check floats, no flowback. Flow check 30 min. Pipe reciprocated constantly during cmt. Stop at start of flush. Circ 30 bbls cement to surface. Plug bumped at 2326 hrs. 10/11/2001 00:00 - 02:00 2.00 BOPSU SURF Nipple dn diverter system. 02:00 - 04:00 2.00 BOPSU SURF Nipple up csg hd I tbg hd, test all packoffs I seals 1000 psi 15 min. All tests successful. 04:00 - 07:00 3.00 BOPSU SURF Nipple up bope, all related plumbing I hydraulics. 07:00 - 11 :30 4.50 BOPSU SURF Test bope to BP I AOGCC specs as follows: Accumulator test, time I press. test. All floor safety valves I equip. Standpipe top drive, to pumps. Annular 250 I 3500 psi 110 min. Rams 250/4000 psi 110 min. Choke and kill systems 250 I 4000 psi. All tests successful and witness waived by John Crisp AOGCC. 11 :30 - 12:30 1.00 CASE P SURF Handle bha #4. Make up 8 3/4 motor I drctnl assy. Load source, prepare Iwd tools. Orient, rih same. 12:30 - 20:00 7.50 CASE P SURF PU 4" dp in sgls from pipe shed, stand back in mast. 20:00 - 22:00 2.00 CASE P SURF Follow DCs with hwdp. Shallow test Iwd, test good. 22:00 - 00:00 2.00 CASE P SURF Pick up remainder 4" dp from pipe shed in sgls. 10/12/2001 00:00 - 01 :00 1.00 CASE P SURF Cont pu 4" dp in sgls from pipe shed. 01 :00 - 02:30 1.50 CASE P SURF Slip I cut drlg line, service top drive. 02:30 - 03:00 0.50 CASE P SURF Rih 4" dp to 2503 ft. 03:00 - 03:30 0.50 CASE P SURF Test 9 5/8 csg to 4000 psi 130 min. Test successful. No re-tests. 03:30 - 05:30 2.00 CASE P SURF Wash to float collar, drill out float, shoe track, guide shoe, 20 ft new formation. 05:30 - 06:30 1.00 CASE P SURF Flow check, circ, displace hole with 9.3 ppg KCL mud. 06:30 - 07:00 0.50 CASE P SURF Pull inside csg, perform LOT. Results = 13.18 EMW ( 9.3 ppg, 525 psi, 2604 tvd ) 07:00 - 14:30 7.50 DRILL P PROD1 Commence drill ahead 8 3/4 hole drctnl, 2775 - 3807 ft. Control Printed: 10/22/2001 10:45:23 AM ~ ,-.,... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: Rig Number: Spud Date: 10/7/2001 End: 10/12/2001 07:00 - 14:30 7.50 DRILL P PROD1 drld to limit PR @ -200 fph. Sweeps @ -200' intervals. 590-600 gpm; 60-70 rpm. 14:30 - 15:30 1.00 DRILL P PROD1 Circ, pump hi - vis sweep, no abnormal cutting returns with sweep. 15:30 -16:30 1.00 DRILL P PROD1 Flow check, poh for wiper trip. Swabbing with 20 - 40 overpull. Wipe clear. Hole tight 3530 to shoe at 2735. 16:30 - 17:30 1.00 DRILL P PROD1 Rih, wash I ream 3250 - 3342 ft. Cont rih to btm, precautionary wash 90 ft. 17:30 - 00:00 6.50 DRILL P PROD1 Resume drill 8 3/4 hole 3807 - 4366 ft. AST 6 hrs, ART 4 hrs. Up 122, Dn 89, Rot 102 WOB 5 -12, RPM 60, GPM 590, Press 2370 10/13/2001 00:00 - 04:30 4.50 DRILL P PROD1 Cont drill ahead 8 3/4 hole 4366 - 4831 ft. 04:30 - 05:30 1.00 DRILL P PROD1 Pump hi-vis sweep, follow with wt pill. Flow check. 05:30 - 08:30 3.00 DRILL P PROD1 Poh for wiper trip. Interrmittent swabbing, work free at various intervals. Back ream 3990 - 3780 ft., 3020 - shoe. Flow check. 08:30 - 09:00 0.50 DRILL P PROD1 Service top drive. 09:00 - 10:00 1.00 DRILL P PROD1 Flow check, rih to 4736 ft. No down drag. 10:00 - 11 :00 1.00 DRILL P PROD1 Precautionary wash I ream to btm. No fill. 11 :00 - 00:00 13.00 DRILL P PROD1 Resume drill ahead 4831 - 5703 ft. AST 9.25, ART 5.5 hrs, WOB 10, RPM 80, SPM 200, GPM 590, Press 3200, TO 6000 10/14/2001 00:00 - 01 :30 1.50 DRILL P PROD1 Cont drill ahead 8 3/4 hole 5703 - 5858 ft. 01 :30 - 03:00 1.50 DRILL P PROD1 Circ, pump hi-vis for wiper trip. No increase cuttings return with hi-vis. 03:00 - 10:00 7.00 DRILL P PROD1 Flow check, poh. 25 - 75 K over pull at 5600 ft. Slight swabbing. Recip pipe, work free. Identical conditions at 4100 - 3100 ft. Begin backream 3100 - csg shoe. Note wall cake substance at shakers. Trouble spots correllate with previous wiper trip. 10:00 - 10:30 0.50 DRILL P PROD1 Flow check, service rig. 10:30 - 12:00 1.50 DRILL P PROD1 Flow check, rih to 5764 ft. No abnormal down drag. 12:00 - 13:00 1.00 DRILL P PROD1 Precautionary wash I ream to btm. No fill. 13:00 - 00:00 11.00 DRILL P PROD1 Resume drill ahead 8 3/4 hole 5858 - 6481 ft. ART 10 hrs, AST 1 hr Up 153, Dn 104, Rot 131 WOB 10, RPM 60 - 90, GPM 585, Press 3316, Tq 7,000 10/15/2001 00:00 - 12:30 12.50 DRILL P PROD1 Cont drill ahead 8 3/4 hole 6481 - 6977 Ft. ART 10 hrs, AST.5 hr, Up 153, Dn 104, Rot 136 WOB 12, RPM 60, SPM 200, GPM 580, Press 3380 12:30 - 13:00 0.50 DRILL P PROD1 Circ I cond mud, orient highside, prepare poh for bit. 13:00 - 18:30 5.50 DRILL P PROD1 Flow check, 6977 - 6604 ft good condo 6604 - 5018 ft swabbing with 20 - 50K overpull. Work free, fill pipe, 100% circ returns. Good cond 5018 ft to shoe at 2735 ft, pull slow to prevent swabbing. Resume poh to hwdp. 18:30 - 20:30 2.00 DRILL P PROD1 Flow check, handle bha #4, break bit and inspect. Mechanical damage to cutters. 20:30 - 22:00 1.50 DRILL P PROD1 Flow check, make up bit #5 I bha #5, rih same to hwdp. 22:00 - 22:30 0.50 DRILL P PROD1 Shallow test motor I mwd. Printed: 10/22/20D1 10:45:23 AM ~ ~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: Rig Number: Spud Date: 1017/2001 End: 10/15/2001 22:30 - 00:00 1.50 DRILL P PROD1 Follow bha with 4" dp to shoe at 2755 ft for rig service. 10/16/2001 00:00 - 01 :00 1.00 DRILL P PROD1 Slip and cut drilling line. 01 :00 - 01 :30 0.50 DRILL P PROD1 Service top-drive. Flow check, OK. 01 :30 - 02:00 0.50 DRILL P PROD1 RIH one stand. Fill pipe and break circulation. 02:00 - 04:00 2.00 DRILL P PROD1 RIH. Fill pipe and break circ. at 4600', 6884' and on bottom. Hole condition good. 04:00 - 05:30 1.50 DRILL P PROD1 Stage pumps up and pump hi-visc sweep around. 05:30 - 00:00 18.50 DRILL P PROD1 Dir. drill from 6977' to 8329'. ART = 11.5 hrs; AST = 3.25 hrs; ADT = 14.75 hrs. 10/17/2001 00:00 - 01 :00 1.00 DRILL P PROD1 Drill from 8329' to 8435', TD. AST= 0; ART = 1 hr. 01:00 - 02:30 1.50 DRILL P PROD1 Pump weighted sweep and cond mud. Flow check, OK. Pump dry job. Rotate at 100 rpm and recip. while circ. 02:30 - 07:30 5.00 DRILL P PROD1 POOH for short trip to shoe. Swabbing from 8255'. Tight hole. Back ream from 8160' to 6977'. Pulling from 25K to 80K over. 07:30 - 08:00 0.50 DRILL P PROD1 Circ bottoms up. Circ out considerable material. Flow check, OK. 08:00 - 12:00 4.00 DRILL P PROD1 Try to POH without pump. Pulled one stand and swabbing. Back ream every other stand from 6977' to 6600'. Pulled OK to 5390' then started swabbing. Work pipe. POH and work pipe when swabbing occurred. Pulled to shoe and flow check, OK. 12:00 - 12:30 0.50 DRILL P PROD1 Service top drive. Circ BU at shoe. 12:30 - 15:00 2.50 DRILL P PROD1 RIH. Fill pipe at 4700'. Took weight at 7760'. Work pipe and push thru with 20K over. Wash last stand down, precautionary. 15:00 - 18:30 3.50 DRILL P PROD1 Pump sweep. Circ and cond mud. Spot casing running pill. Recip DP and rotate at 110 rpm while circ. 18:30 - 23:00 4.50 DRILL P PROD1 Flow check, OK. Blow down TD. POOH. Slight swabbing from TD up to 7760'. Wiped occasional tight spots (10K to 15K over). Pulled OK from 7741'. Flow check at shoe, OK. POOH to HWDP. 23:00 - 00:00 1.00 DRILL P PROD1 PJSM. Pull BHA standing back HWDP. Change to 5" elevators. 10/18/2001 00:00 - 03:00 3.00 DRILL P PROD1 LD BHA #5. Unload RA sources. Remove all components from floor. 03:00 - 03:30 0.50 CASE P COMP Clear rig floor to RU casing tools. PJSM. 03:30 - 04:00 0.50 CASE P COMP Pull wear bushing. Make dummy run with landing jt. and mark. Install test plug. 04:00 - 05:30 1.50 CASE P COMP Change upper ram blocks, install 4 1/2 X 7". Pressure test door seals to 250 psi and 4000 psi, OK. RD test equip. 05:30 - 08:00 2.50 CASE P COMP PJSM. Pick up casing running tools and rig up same. Change to long bails and pick up Franks Tool. 08:00 - 10:00 2.00 CASE P COMP Run 7", 26#, L-80, BTC-M casing. Make up shoe track, Baker-Ioc, and check floats, OK. Run in to first marker jt. Has wrong threads. Lay down and replace with next marker jt. Continue to run in to next marker jt. location. 10:00 - 12:00 2.00 CASE N WAIT COMP Wait on installation of RA PIP in new marker joint. Make up same. 12:00 -12:30 0.50 CASE P COMP Tour change. PSJM for casing job with new crew. 12:30 - 15:00 2.50 CASE P COMP Continue running 7" casing to 9 5/8" csg shoe. PU = 105K, SO = 91K. 15:00 -15:30 0.50 CASE P COMP Circ. casing volume at surf. csg shoe. 15:30 - 22:00 6.50 CASE P COMP Run 7" casing in open hole. Pushed with 30K to 40K added weight from 8100' to 8180'. Continued running in without Printed: 10/22/2001 10:45:23 AM '. /"'.... .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: Rig Number: Spud Date: 10/7/2001 End: 10/18/2001 15:30 - 22:00 6.50 CASE P COMP incident. Lost approx. 19 bbls mud while running casing. 22:00 - 22:30 0.50 CASE P COMP Lay down Franks Tool. Blow down top drive. MU landing jt. and land casing at 2215 hrs. Make up cement head. PU = 320K, SO = 135K without pump. 22:30 - 00:00 1.50 CASE P COMP Break circulation, staging pumps up slowly to 6 BPM at 880 psi. Reciprocate casing while circulating. PU = 250K, SO = 130K with circ. Full returns while circ. 10/19/2001 00:00 - 01 :00 1.00 CASE P COMP Circ. and condo mud at 6 bpm and 900 psi for cementing. Reciprocate casing 20' in 1 imino cycles. PU = 250K; SO = 130K. 01 :00 - 04:00 3.00 CEMT P COMP Pump 10 bbl CW100 flush. Test lines to 4000 psi, OK. Pump 30 bbls more of CW1 00, 40 bbls MudFlush, bottom plug, 89 bbls 12 ppg CemCRETE lead slurry, 72 bbls 15.8 ppg Latex tail slurry, and top plug. Displace with 320 bbls 9.2 ppg brine at 6 bpm slowing to 2 bpm for the last 10bbls of displ. Recip. pipe throughout. Did not bump plug. CIP at 0335 hrs. Final displ press. = 1034 psi. 04:00 - 05:00 1.00 CEMT P COMP Check floats, OK. Monitor well, OK. Blow down lines, RD cmting equip. LD cmt head and landing joint. 05:00 - 06:00 1.00 WHSUR P COMP Run and install casing hanger packoff. Run in and torque test LDS. Pressure test to 5000 psi, OK. Spill Drill-OS-1 :30 min. 06:00 - 07:00 1.00 BOPSU P COMP RD casing equipment. Change bails. RU floor to run DP 07:00 - 09:00 2.00 BOPSU P COMP Change top rams fl 7" to variable. Test doors to 250 I 4000 psi-OK. Install wear ring. 09:00 - 09:30 0.50 CASE P COMP RU to pump down annulus. Pumped mud and broke down wI 470 psi. EMW=13.8 ppg. Pump 1 bbl each hrto keep annulus clear. 09:30 - 10:30 1.00 CLEAN P COMP MU BHA#6-bit, HWDP, & jars. 10:30 -13:00 2.50 CLEAN P COMP RIH wI 4" DP to 7858'. Circ down to cement plug @ 8270.5' 13:00 -14:30 1.50 CLEAN P COMP CBU @ 8 bpm. Hole clean. 14:30 -17:00 2.50 CLEAN P COMP Start LDDP. Simultaneous operation. Inject mud down annulus @ 3 bpm wI 700 psi. Pumped 85 bbls total. RU Little Red to freeze protect annulus wI dead crude. 17:00 - 21 :00 4.00 CLEAN N CEMT COMP Pumped 13 bbls crude and noted returns coming from conductor. Shut down & pump cellar out. Monitor until returns stopped--approximately 42 bbls. Spill Drill-OS-1 min. 21 :00 - 22:00 1.00 CLEAN P COMP RU & test 7" casing to 4000 psi fl 30 min-OK. RD test equipment. 22:00 - 00:00 2.00 CLEAN P COMP Continue LDDP while finalizing freeze protect plan & WO cement, water, and vac trucks. 1 0/20/2001 00:00 - 02:30 2.50 CLEAN P COMP Lay down drill pipe to the HWDP. 02:30 - 13:00 10.50 REMCM N CEMT COMP PJSM. Re-establish circulation to surface through 7" X 9 5/8" annulus by pumping 3 bbls of mud wI rig pump at 1.8 bpm. Hook up Dowell. PT lines, OK. Mix and pump 250 bbls 10.7 ppg ArcticSet Lite down annulus at 1.8 bpm and 450 psi. Had returns until 90 bbls pumped. Returns diminished to nil. RD Dowell and RU Hot Oil Servo Freeze protect 7" X 9 5/8" annulus to 2100' TVD with 58 bbls of dead crude. Work 3/4" pipe down 9 5/8" X 20" annulus to 60'. Fire drill at 0400 wI all on station in 70 sec. 13:00 - 14:00 1.00 REMCM N CEMT COMP RU Dowell. Mix and pump 16.5 bbls of 11 ppg, ArcticCRETE cement down 3/4" lines circ from 60' to surf. in 9 5/8" X 20" annulus. Printed: 10/22/2001 10:45:23 AM ~. /'"'. ~, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-115 L-115 DRILL +COMPLETE NABORS NABORS 9ES Start: 10/6/2001 Rig Release: Rig Number: Spud Date: 1017/2001 End: 10/20/2001 14:00 - 15:00 1.00 REMCM N 18:00 - 21 :30 CEMT COMP COMP COMP COMP COMP COMP Wash out and blow down cementing lines. RD Dowell. Clear and clean floor. Lay down HWDP. Pull wear bushing. Make dummy run with tbg hanger. RU to run 4 1/2" tlubing. PJSM. PU mule shoe and run 75 jts, 4 1/2" 12.6#, L-80, NSCT temporary kill string. Land at 2995.5' MD. Pick up hanger and landing jt. Land tubing. RILDS. Backout landing jt. and lay down. RD tbg handling equip. Clear floor. Set TWC. Test to 1000 psi, OK. 15:00 -16:30 16:30 -18:00 1.50 CLEAN P 1.50 WHSUR P 21 :30 - 23:30 23:30 - 00:00 Printed: 10/22/2001 10:45:23AM /8/200 1 Sc~lunIb.,. 601 NO. Comm 00 Alaska Oil & Gas Cons Aftn: Lisa Weepie 333 West 7th Ave, Suite Anchorage, AK 99501 Company: Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-57 ATTN: Sherrie ) Borealis Field: ) CD L-115 dlO/-jt.l0 21467 USIT 10/22/01 i7 L-117 dO'~/v,7 21465 USIT 10/02/01 2'/ BL Sepia Color Date Log Description Job # Wel Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. RECEIVED Petrotectnical Data Center LR2- 900 E Benson Blvd. Anchorage AK 99508-4254 NOV 1 J 2001 Date Delivered: mission /7/200 1 SI~IunI~..,er 596 NO. Comm 00 Alaska Oil & Gas Cons Aftn: Lisa Weepie 333 West 7th Ave, Suite Anchorage, AK 99501 Company: Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-57 ATTN: Sherrie ) Borealis Field: ) CD 1 BL 1 1 1 1 Sepia ..,..- ...t- x- --1. Color Date 10/17/01 10/17/01 10/17101 10/17/01 10/17/01 Log Description DIN & ARC MD VISION RESISTIVITY TVD VISION RESISTIVITY MD VISION DIN QUADRANT TVD VISION DIN QUADRANT Job # 21450 21450 21450 21450 21450 Wel L-115 L-115 L-115 L-115 L-115 ~ """ 6 Q) Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2- 900 E Benson Blvd. Anchorage AK 99508-4254 Received RECEIVED Alaska Oil & Gas Cons. Com_ion Anchorage NOV Date Delivered Customer Well No Installation/Rig Data Surveys Received By ~ MWD/LWD Log Product Delivery BP Exploration (Alaska) Inc. L -115i Nabors 9ES dOJ-/4D LWD Log Delivery V1.1, Dec '97 Dispatched To: Date Dispatche Dispatched By: ,,-..., Lisa Weepie 2-Nov-01 Nate Rose No Of Prints No of Flo ies RECEIVED Alaska Oil & Gas Cons. Commission Ancoorage 2 Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 1/l /2001 Se.",.pger 590 NO. Comm 100 Alaska Oil & Gas Cons Attn: Lisa Weepie 333 West 7th Ave, Suite Anchorage, AK 99501 Company: Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Borealis Aurora Field: ) ) CD 1 BL .Æ ...r r ...... ..y ~ Sepia 1 1 1 1 1 1 . . . . Color 7 Date 08/20/01 10/20/01 10/22/01 07/27/01 07/27/01 07/27/01 07/27/01 07/27/01 Log Description USIT PROD PROFILEIDEFT TEMPERATURE LOG DIN & IMP (PDC) MD VISION RESISTIVITY TVD VISION RESISTIVITY MD VISION DEN/NEUTRON TVD VISION DEN/NEUTRON Job # 21419 21381 21381 21381 21381 21381 Wel -;:J.VJ" ¡¡::p, d. DD-l#o~ /),DI- 140 rlf))- I ~"?::> S-110 S-103 L-115 L-110 L-110 L-110 L-110 L·110 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrle PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: RECEIVED BP Exploration (Alaska) Inc, Petrotectnlcal Data Center LR2- 900 E Benson Blvd. Anchorage AK 99508-4254 Receiv f<O\l 0 2 2001 Anch~rage Date Delivered: Oct-ZO-ZOOt 00:40 . FrOlll"NABORS 9ES .~ +90T-859"4833 ,--.., T-325 P.OOZIOOZ F-T63 ~()I- /1(J .. BPXA· NABORS 9ES- P U " x 9 5/8n Freeze Protect Plan Forward The plan ;s to cement the 9 518" X 20" annulus and freeZe protect the 711 x 9 518" annulus to 2100' TVD. ..****...*.............*.**...***..**.........**....................***.....****..*..**.*..*..................*. 1. RU to 1" x 9 518" annulus. Position vac trucks to take returns from çeUar. 2. Break circulation slowly with 10.3# mud and work rate up to approximately 2 bpm w/1 0.31 mud. Restrict pumping to 2 to 3 bbls. Do not exceed previous circulation rate of 2 bpm (700 psi) established during aborted freeze protect. 3. RU Dowell. Mix & pump ArcticSet Lite until good cement returns to the surface aM observed. Do not exceed pump rate of approximately 2 bpm at 100 psi. 4. RU Hot Oil Services and displace cement wI 60 bbls dead crude for freeze protection to 2100' TVD. Restrict displacement pump rates not to exceed 2 bpm. 5. Shut in annulus. RD trucks & equipment. Note: Be prepared to perform conventional top job should cement job not provide the desired cement isolation in the 9 518" X 20" annulus. Current well configuration: 20" conductor @ -80' 9 518" Swface @ 2735' 7" Casing @ 8416' Reference Lw 11 S Wen Plan. Plan Forward is a guid~line. and subject to change at any time. Report changes from well plan, and any suggestions to ìmprove operations to Driller, Tool Pusher. Co-Rep at any time. 10/21/01 10155P P.001 ~. ~ AOGCC Fax To; Tom Maunder ~ From: Jeff JOr'Iè$ ~ 90727(i 7542 Pages: 24 (including ooversheet) .. 101Z2101 ..... 007793 1250 flee BPX L~ 115 cement report attachments cc: [J urgent I!I 'or Revt.w d P..... Ccønmltld 0 PI.... Reply 1:1 PI.... Recyde Hello Tom, These are the attachments to file: Remedial SurfaCe cement BPX L-' 151 '0-20.01 JJ.doc I hope yolJ'~ I10t getting buried ali\'e by all that froze" future river 'Hater! see you later, Jeff RECEIVED OCT 2 2 2001 Alaska Oil & Gas Cons. CommissIon Anchoraoe Scblumbergør wen FIeld 10/21/01 10:55P P.002 .~ .~ Cement Job Report CemCAT Vl,.O m...._..__·___..__ -.- . . .....--.J--------.---.- .... ... ......- u._____....._.·_·_...____.. ..-- -. Client SÞX SIR No. 2201018207 Job Type ANNUlAA ÇeMENT Jab Ò.. 10-20-2001 .._. ____._____ø..._.._____·__·· ",.. . ,,,.. ",.....__. ~____.______... , ",... .......... . . ..........-------.-.- "...-.-...-......... L·llS AURORA Engineer RANOY)OSr Country United St<ltés .-'._"..'.0 ,"'.....,.. ...____...______...._.. ... _____.".u .,., I. Time .... ....---...-----..-. Pressure .__. ..__...____._______.__., n,"''''''' . .--.......--------, I M~BAøes I .,'"........~,-_............~ ...____._.. __.,. ,I. Rete Density ()I;23::S1 __. __....... 'I... ._.____.__..__________. ',,' , _,.,..,......,....______,__..·..·_..,~·,·I·I'''''·'I....__......__...____.______ a..T TO WT 04:4!i'10 0$;00;29 05:30:46 05:53;07 06:15:26 01>;3'1:45 07,ot):M 07:'-':2:1 07~44:4~ ; t ,,:~~~~.; r I I i r':'~ L... 1';'" P~$SIIAI fll!lt 1.1_ :;"'" c..m..,,\ Slurry " :, ¡ I ,L: 511l1T OOWN EM Jot¡ St(lp~ III:qutslllon i ··..··..---1 , .."'~. _._~----~-- ......-,.....------- -'."'-" '.', "..~--_._----_..'.'... ..----...........---..--.-...., ~ ~ ~~ s~ ~ M U U ~I ~i ~, iR M ~ "3 'fA i~. 1~. 3~O -----...,--..-,..-........ ..... .-...............--- ...--...-...."."........-.... .,..." ... 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I Tíme mm:dd:yyyy~hh:mm:ss 10:20:2001 :04:23:51 10:20:2001:04;24:18 10:20:2001 :04:24: 18 10:20:2001 :04:24:51 10:20:2001 :04:25:51 10:20:2001 ;04:26:51 10:20:2001:04:27:51 10:20:2001 :04:28:51 10:20:.2001 :04:29:51 10:20:2001:04:30:51 10:20:2001:04:31:51 10:20:2001 :04: 32:51 10:20:2001 :04:32:59 10:20:2001:04:32;59 10:20:2001:04:33:51 10:20:2001 :04:34:52 10:20:2001:04:35:52 10:20:2001 :04:36:33 10:20:2001 :04:36:33 10:20:2001 :04:36:52 10:20:2001:04:37:52 10:20:2001 ;04;38;52 10:20:2001 :04:39:52 10:20:2001:04:40:52 10:20:2001:04:41:52 10:20:2001 :04:42: 52 10:20:2001 :04:43: 52 10:20:2001 ;04:44:52 10:20:2001 :04:45:52 10:20:2001:04:46:53 10:20:2001 :04:47:53 10:20:2001 :04:48:53 10:20:2001 :04:49:53 10;20:2001 :04: 50:53 10:20:2001 :04:51:53 10:20:2001:04:52:53 10:20:2001 :04:53:53 10:2Ô:~D01:04:G4:53 10:20:2001:04:55:53 10:20:2001 :04:56:53 10:20:2001 :04:57:54 10:.20:2001 :04:58:54 10:20:200tQ4:59:54 1 0:20:200 1: Q5: 00:54 10:20:2001:05:01:54 10:20:2001:05:02:54 10:20:2001 :05:03:54 .~ . 'l I I I Customer: . District: Representative: DS Supervisor: Well: ".' "-'-~'-"._"."'. ",...-., -""'.'" "' 10/21/01 10:55P P.Ø0S ~ BPX PRUDHOE SAY BRETT ALLARD RANOYJOST L-115 .-...,...........-............. .. ..........-..... ! T" CMT DENS I CMTTREATPRE$ : MM RATE Ib/gal! psi I bbl/min 10.73 CMT TO wr 10.56 10.56 10.56 10,58 10,62 10.63 10.63 10.63 11,82 10,66 Pressul'é Test Unes 10.66 10,65 10.66 12,01 Start Cêment Sluny 10.87 10.92 11.15 10.79 10.73 10.66 10,70 10.67 10.69 10.68 10.68 10.68 10.66 10,69 10,69 10,69 10.67 10.71 10,71 10.70 10.70 10.70 10.70 10.70 10.71 10,71 10.70 10.71 10.71 Page 1 Of 5 55 55 50 55 50 50 55 SO 50 197 206 206 1355 174 169 183 224 311 389 444 435 449 453 453 458 449 444 435 430 426 430 430 435 444 449 449 449 458 462 462 471 462 4($7 467 0,0 0.0 0.0 0.0 0.0 0.0 0,0 0.0 0,0 0.0 0.0 0.0 0,0 0,0 0.0 0,3 1,1 1.4 1,8 1.8 1.9 1,8 1.8 1,8 1,7 1,8 1,7 1.7 1.7 1.8 1.7 1.8 1.8 1,7 1.9 1,8 1,6 1.9 1.8 1.7 1.8 1.e 1.7 1.9 .... ..~..~ . on '. .....,_..._........... ,,_. j MM TOTAL bbl 0.0 0,0 0,0 0,0 0.0 0,0 0,0 0,0 0.0 0.0 0.0 0,0 0,0 0.0 0.0 0.1 0.4 17 3.3 5.0 6.8 8.6 10.4 12,1 13.9 15,7 17.5 19.3 :21.1 22.9 24,6 26.4 28,2 30,0 31,8 33,5 35,3 37,1 38.8 40.ß 42.4 44.2 45.9 47.7 10/21/01 10:55P P.004 ~, ~ Job Date: 10·20-2001 ... '''"''--.-.---''-'''. .. ·...-----r-····....· .............-. ..--..-¡-...' .-...........---..... ..'..'W._..¡__......._ ., -··--T···" -.--.---..... .." , .. ..... I Time . CMT DENS ! CMT TREAT PRES ¡ MM RATE MM TOTAL . mm:dd:yyyy;hh:mm:ss: Ib/gal' psi i bbUmin I bbl . ! .........' .1.. Well: L-116 ...,._ _.1 10:20:2001:05:05:54 10:20:2001:05:06:54 10;20:2001 :05:07:54 10:20:2001 :05;08;54 10:20:2001 :05:09:55 10:20:2001 :05~ 1 0:55 10:20:2001:05:11:55 10:20:2001 :05: 12;55 10:20:.2001 :05: 13:55 10:20:2001 :05: 14: 55 10:20:2001 ;05: 1 5~55 10:20:2001 :05: 16;55 10:20:2001:05:17:55 10:20:2001: 05: 1 8: 55 10:20:2001 :05:19:55 10:20:2001 :05:20:55 10:20:2001 :05:21:5e 10:20:2001 :05:22:66 10:20:2001 :05:23:56 10:20:2001 :05:24:56 10:20:2001 :05:25:56 10;20:2001 :05:26:56 10:20:2001 :05:27:56 10;20:2001 :05:26:56 10:20: 2001 :05:.29:56 10:20:2001 :05:30:56 10:20:2001 :05:31:56 10:20:2001:05:32:57 10:20:2001 :05:33:57 10:20:200 1 :06:34: 57 10:20:2001:05:35:57 10:20:2001 :05:38:57 10:20:2001 :05:37:57 10:20:2001:05:38:57 10:20:2001 :05:39: 57 10:20:2001 :05:40: 57 10:20:2001 :05:41:57 10:20:2001 :05:42: 57 10:20:2001:05:43:57 10:20:2001 :05:44: 58 10:20:2001 :05:45: 56 10:20;2001:05:46:56 10:20:2001 :05:47:58 10:.20:2001 :05:48:58 10:20:2001:05:49:56 10:20:.2001 :05:50:58 10:20:2001:05:51:56 10;20:2001 :05: 52: 58 10:20:2001 :05:53:58 10:20:2001 :05:54:58 10:20:2001 :05: 55: 59 10:20:2001 :05: 56: 59 10:20:2001 :05: 57: 59 10.70 10,68 10.71 10.72 10,69 10.69 10.72 10.71 10.72 10,69 10.71 10.69 10.71 10.70 10,70 10,70 10.71 10.71 10_70 10.69 10.72 10.70 10.71 10.70 10.72 10.72 10.67 10.73 10.71 10.71 10.71 10.71 10.71 10.11 10.69 10.72 10.11 10,69 10.71 10,71 10,70 10,11 10,69 10.71 10.70 10.69 10,72 10.69 10,71 10.69 10.70 10.71 10,70 467 471 467 471 467 411 467 471 467 471 471 458 458 453 453 449 449 453 453 453 453 453 453 453 458 453 453 449 453 453 453 449 449 449 449 449 449 453 453 449 449 444 444 449 444 444 449 449 449 449 444 444 444 1.8 1.7 1.7 1,8 1.8 1,8 1,7 1.8 1.8 1.7 1,8 1.& 1.8 1.8 1.8 1.8 1.8 1,8 1.9 1.8 1.8 1.7 1.8 1,8 1.8 1.7 1.8 1.7 1.7 1.8 1.7 1.7 1.8 1.8 1.6 1,8 1.7 1.7 1.a 1.8 1.8 1.6 1.a 1.1 1.8 1.8 1.8 1.7 1.7 1.8 1.8 1,8 1.7 51.3 53.1 54,6 66.6 58.4 60.2 61,9 63.7 655 67,3 69.1 70.8 72.6 74.4 76.1 77.9 19,7 61.5 03.3 85.1 86,8 88.6 90.4 92.1 93.9 95.7 97.5 99,3 101.0 102,8 104.6 106,4 108.1 109.9 111,7 113.5 115.2 117.0 118,7 120.5 122.3 124.1 125.9 127. ., 129.4 131.2 133.0 134.8 136,6 138.3 1401 141.9 143.7 page 2 of 5 10/21/01 10:5SP P.00S ~ ~ Well: L·115 Job Data: 10-20-2001 1"-î1~;"---" ¡ CM~Ö~~S''''~'CMTT~Ë~~'~~~'~'j MMR~~~·n í' MMTOT~~----'-''':: .__~~~~?:!ffl:h~:mm:$S _._.1...... .~~~~~~_.___L___... h"'~'~~ ....____L~~~i~ ...__L..___~~'.~ ....._ ___..___J 10:20:2001:05:58:59 10.70 444 1.6 14~,4 10:20:2001:05:59:59 10.69 444 1.8 147.2 10:20:2001:06:00:59 10.10 444 1,8 149,0 10:20:2001:06:01:59 10.70 449 1.6 150.8 10:20:2001:06:02:ö9 10.70 439 1.7 152.5 10:20:2001;06:03:59 10.72 439 1.8 154,3 10:20:2001:06:04:59 10.70 439 1.7 156.1 10:20:2001:06:05:59 10,66 444 1.8 157.9 10:20:2001:06:00:59 10.72 439 1.8 159,6 10:20:2001:06:08:00 10.10 444 1,8 161.4 10:20:2001:06:09:00 10.70 444 1.7 163.2 10:20:2001:06:10:00 10.S9 444 1.8 165.0 10:20:2001:06:11:00 10.71 444 1,8 166.8 10:20:.2001:06:12:00 1070 444 1.8 168.5 10:20:2001:06:13:00 10.70 444 1,7 170,3 10:20:2001:06:14:00 '10,70 439 1.8 H2.1 10:20:2001:06:15:00 10.69 444 1.8 173,8 10:20:2001:06:16:00 10.70 439 1.7 175.6 10:20:2001:06:11:00 10.70 444 1.8 177.4 10:20:2001'06:18:00 10.S6 439 1.8 179.2 10:20:2001:06:19:01 10,72 439 1,6 181.0 10:20:2001:06:20:01 10,71 444 1.7 182.7 10:20:2001:06:21:01 10,70 444 1.8 184.6 10;20:2001:06:22:01 10.69 444 1.8 186.3 10:20:2001:06:23:01 10,73 444 1.8 186,0 10:20:2001:06:24:01 10,63 449 1.7 189,6 10:20:2001:06:25:01 10,70 449 1,8 191.6 10:20:2001:06:26:01 10.69 444 1,7 193,3 10:20:2001:06:27:01 10.67 449 1.8 195.1 10:20:2001;06:28:01 10.66 449 1.8 196,9 10:20:2001:06:29:01 10.70 449 1.7 196.6 10:20:2001:06:30:01 10.72 444 1.8 200.4 10:20:2001:06:31:02 10.67 449 1.8 202.2 10:20:2001:06:32;02 10.67 444 1.7 204.0 10:20:2001:06:33:œ2 10.69 444 1,8 205,8 10:20:2001:06:34:02 10,69 444 1.7 207.6 10:20:2001:06:35:02 10,70 444 1.8 209.3 10:20:2001 :06:36:02 10.69 444 1.8 211.1 10:20;2001:06:37:02 10,69 449 1.7 212.9 10:20:2001:06:38:02 10.69 449 1.7 214.6 10:20:2001:06:39:02 10.66 444 1.7 216.4 10:20:2001:06:40:02 10.69 453 '.8 218.1 10:20:2001:06:41:02 10.74 449 1.8 219,9 10:20:2001:06~42:02 10.66 449 1,8 221,7 10:20:2001:06:43:03 10.69 453 1.7 223,5 10:20:2001:06:44:03 10.69 453 1.8 225.2 10:20:2001:06:45:03 10.73 449 1.7 227.0 10:20:2001:06:46:03 10,64 458 1,6 228.7 10~20:2001:oe:47:03 10.67 453 1.7 230.5 10:20:2001:06:48:03 10,73 458 '.8 232.2 10;20:2001:06:49:03 10.76 453 1.7 234.0 10:20:2001:06:60:03 10.72 458 1.7 235.7 10:20:2001:06:51:03 10.66 456 1.7 237.5 Page 3 of 5 10/21/01 10155P P.00S .~. .~ Well: L-115 Job Date: 10-20-2001 "-'-~;;e .., OMiOENS ¡. C~~T~E~;'~~~s--r'- MM'R~TË-'-r-~M'~OTÄL d_ "-.. 'mm_~:.~~:~~~~:~m:s~.... J._ ..1~~~..___.~. . n _. . . ,PSi .., no"""" .L._._b~~jn .. ..' L._ _.~b! . .,.. '" ._" 10:20:2001:06:52:03 10.70 456 1.8 239.3 10:20:2oo1:08:S3:03 10.69 458 1.7 241,0 10:20:2001;06:54:04 10.70 462 1,7 242.6 10:2Q:2001:06:55:04 10.63 462 1.6 244.5 10:20:2001:06:56:04 10,62 462 1.7 246.3 10:20:2001:06:57:04 10.70 467 1.7 248,0 10;20:2001:06:56:04 10,55 435 1.1 249.5 10:20:2001:06:59:04 10.75 436 1.1 250.6 10:20:2001:01:00:04 10.49 362 . 0,0 251.4 10:20:2001 :07:00: 13 SHUT DOWN 10:20:2001:07:00:13 10.49 351 0.0 251.4 10:20:2001:01:44:39 End Job 10:20:2001:07:44:39 8.30 0 0.0 251.4 10:20:2001 :07:44:47 Stopped Acquisition 10:20:2001: 12:51 :32 Started Acquisition 10:20:2001:12:53:13'CMT ARR F/PAK 10:20:2001:12:53:24 REPRIME UNIT 10:20:2001:13:06:03 8.31 0 0.0 0.0 10:20:2001:13:06:37 8.31 18 0,0 0.2 10:20:2001:13:07:28 Start Pumping Watêr 10:20:2001:13:07:28 8,31 27 0.4 0.4 10:20:2001:13:07:37 8.31 27 0.4 0.5 10:20:2001:13:06:37 8.31 23 0.4 0.8 10:20:2001:13:09:$7 8.31 41 0.5 1.2 10:20:2001:13:10:37 8.31 5 0.0 1.7 10:20:2001:13;11:25 START BATCHING CMT 10:20:2001:13:11:25 8.$1 60 0.0 1.7 10:20:2001:13:11:37 8.18 64 4,2 2,2 10:20:2001:13:12:37 10.39 60 4,2 6.5 10:20:2001:13:13:37 10,95 50 4.5 10_9 10:20:2001:13:14:31 10.99 0 0.0 13.0 10:20:2001:13:14:49 Reset Totel, Vol = 0,00 bbl 10:20:2001:13:14:49 11.21 5 0,0 13,0 10:20:2001:13:14:53 start Cement stUJTy 10:20:2001:13:14:53 11,24 0 0.0 0.0 10:20;2001:13:15:38 11.19 46 0.5 0,4 10:20:2001:13:16:38 11.37 60 0.5 0,9 10:20:2001:13:17:38 11.15 69 0.3 1.3 10:20:2001:13:18:38 10_89 124 0,5 1.5 10:20:2001:13:19:38 11.30 133 0,6 2.0 10:20:2001:13:20:38 11.36 92 0.6 2.6 10:20:2001:13:21:38 11,21 96 0.5 3,2 10:2Q:2oo1: 13:22: 36 11.01 105 0.5 3_7 10:20:2001:13:23:38 10.9a 92 0.5 4_3 10:20:2001:13:24:38 10.99 82 0.6 4.8 10:20:2001:13:25:38 11.02 79 0.6 5A 10:20:2001:13:26:38 11.12 87 0,6 6.0 10:20:2001:13:27:39 11.13 87 0.6 6.6 10:~0;2001:13:2a:39 10.98 87 0,5 7,2 10:20:2001:13:29:39 1099 82 0.6 7.8 10:20:2001:13:30:39 10.98 87 0.6 8.5 10:20:2001:13:31:39 11.01 78 0.7 9.1 10:20:2001:13:32:39 10.99 78 0.7 97 Page 4 of 5 10/21/01 10155P P.007 ~ ~ Wen: L-115 Job Date: 10-20-2001 r"-·'--- -.........-.-...--¡..-................" ·······--··..r..-·..·· ,.. '"." .....__._......_..._u .,. ......_.__....¡..______....__..___....__.__m_..' ¡Time ¡ CMTDENS : CMTTREATPRES MMR~TE: MMTOTAL ¡ ! mm:dd:yyyy:hh:mm:ss! Ib/gsl: psi I bbllmln: bbl : i..__.. _._._ ..........__.___..._._..... ..". ".. .1.. ......... ..... ...... . ..._ .. ....... ......... ... .... ....... ..1.. ._.... ............ ........! .. ....._..... .._.__ m ,.,.." ....J 10:20:2001:13:33:39 11.16 78 0.7 10.4 10:20:2001:13:34:39 11.20 67 0,7 11.1 10:20:2001:13:35:39 11.21 82 0,7 11.8 10:20:2001:13:36:39 11.25 87 0.7 12.6 10:20:2001:13:37:39 11.27 67 0.7 13,3 10:20:2001:13:38:40 11.29 78 0.8 14.1 10:20:2001:13:39:40 11.38 87 0.7 14.8 10:20:2001:13:40:40 11.40 87 0.7 15.5 10:20:2001:13:41:40 11.37 82 0.5 16.1 10:20:2001:13:42;40 10.92 9 0.0 16.4 10:20:2001:13:43:01 SHUT DOWN 10:20:2001:13:43:01 10.92 S 0.0 16.4 10:20:2001:13:43:16 GOOD CMT RETURNS 10:20:2001:13:43:16 10.93 5 0,0 16.4 10:20:2001:13:43:30 WASH UP UN1T 10:20:2001:13:43:30 .10.95.. 5 {),O 16.4 10:20:2001:13:43:38 Ene! Job 10:20:2001:13:43:38 10,96 5 0.0 16.4 10:20:2001:13:43:40 10.97 5 0,0 16.4 Page 5 of 5 SChlumberger Wl!tI Field Enlllneer cou"try L-ll5 8o",,~lis Dennis D¡Ms United St<!tes .... ...·__.·__····w..· ,.--.-.. ,.-- .---.-...-----.--....... ~ ,~~~.~,~'" I 17 51;30 8:27:~0 \;¡;Q3;~O I~:~O:OO 20:16:10 20: 52:20 21:26:30 21:04:40 22:~0:SO I \ "hmm'"< I I·,'~(n"\ r' "." 73:17;00 Pressure 10/21/01 10:55P P.00S ~ Cement Job Report ~ CUent SIR No. Job Type Job Date DPX Surfa!:e 10-10-2001 .....---.........-.......--.,..-.. Rate ... .~.,~..._._._-,_..__._._..._- ~--" ------..---.-........- ...... ." ;..~.¡(\ "'c'llY\ ,,;f,,' ·,I'I('~ .)(} I':' '.1 .,(, P~J ~IM Densltv ~ t ~C1 '~J --f I l/,1 I"),f" I.' ~ It LB/G Cp.rT1CAT'I1.0 ......-. "'--"'" .--..--.------.,...... .~ Messages ......-- S\xJpp@( ACQ\.lsltlon 5t1!1rred ACQUI'S-Itlon stopped AcQ\I'sl~lon StM~d !\CQulsltlon Stopped AcQulgltlon st"rted Ac~ul<ltlon 5topped AcqlJls;ltJon ¡;Þ\rt~d kQUl51tlon Stopped ACQuisition !;tl>r't>ed AcqulslUon gtt>pp"d ACqulSIUOn s:t..,rtttd Acqutsltfon 5topp~d Acqulsltjon St!lrt<!'1 ACQU'sltlon gtopped !\CQU1s1tlon 5tt1lÙ<I AcquIsitIOn Stopped Acquisition ~JrT1~ LIp ~to!!rt~ ^cqtJ~sljon 5tðrt Jol:> 5t~~d /l<;qulsl~ion Pressure T~t Cð5,no Bð~h ~'uct Pugh R~.t Total, VOl" 10,29 bbl 51;ðrt Muå PU!Rh ~hlt DDwn Drop DOUm PluQ FI.....t To"", Vol: 7),61 b~1 St/'lrt lJ11!id C'Amt'lnt ç~~nO@ "'"1:<3 6~tc~ ~""rt $t!lrt Tðll Cement R....tTotðl. Vol ~ J17.99 Dbl Si"Jt Down Drop TOD PIUQ 1t..."tT,,~..I. \101 D 52,69 bbl Pumping W~t>!r End Jot> S"'ltc~ b> RIg Rig Dlspleclng07.5 bpm Rip S~I! DlspleclnQ<t!'7 ,5 bpm 73~ p" l'lVmp plug (I¡¡71'D ""9k". 3000 P" HOld 5 "'In" sropþ"" IICOu..IClM . -... «-.-.--------.--..---' ... .,.......,.....j 10,20/200109:22: 17 10/21/01 10:55P P.00S ~, ~ Customer: BPX ScItln~.I. District: Prudhoe-Bay Representative: Tom Anglen OS SupervÎsor; Dennis DélvÎs Job Oate: 10-10-2001 Well: L-115 ... .--..-.,.--.. -.......-...,.-..--..--. ---.---... l r Time Treating Pressure Flow Rate CMT STG VOL CMT DENS mm:dd:yyyy;hh:mm:ss psi bbl/min bbt I Ib/gal .'.. ......" -. ....."".. " I 10: 10;2001 ;17: 51 ;30 4 0.0 0.0 009 10: 10:2001:17:54:18 2 0,0 0,0 0,09 10: 10:2001 :17:55:18 1 0,0 0,0 0,09 10: 10:2001 :17:56:19 -1 0,0 0.0 0.08 10:10:2001: 19:0e;19 1 0.0 0.0 0.08 10: 10:2001: 19:09:20 -0 0.0 0.0 0,08 10: 1 0:2001: 19:18:49 1 0,0 0,0 0,08 10: 10:2001:20:04:19 Stàrted Acquisition 10: 10:2001 :20: 04:25 Prime Up 10:10:2001:20:23:43 Started Acquisition 10:10:2001 :20:23:45 3 0,7 0.0 0.08 10: 1Ó:2001:20:24:32 -17 0.7 0.4 0.09 10: 10:2001:20:26:27 -41 0.5 0.1 0.09 10; 1 0:2001; 20:27:28 93 5.3 4,6 0,08 10:10:2001:20:28:28 84 5,1 8,3 0.08 10: 10:200120:28:45 Start Job w/CW-100 10:10:2001 :20:58:36 Started Acquisition 10: 1 0:2001 :20:58:38 54 0.0 0.0 8,08 10: 1 0:2001 :20;59:23 8 1,7 0,1 8.08 10:10:2001 :21 :00:24 424 5.3 4.3 8.08 10: 10:2001 :21:01 :25 359 4.7 9.8 8.08 10: 10:2001 :21 :02:25 22 0,0 10,2 8.08 10: 10:2001 :21:02:59 Pressure Test 10:10:2001:21:02:59 22 0,0 10.2 808 10: 10:2001 :21:03:26 118 0,0 10.2 8,08 10: 10:2001 :21 :04:27 3080 0,1 10.2 B.08 10: 10:2001 :21:05:27 1899 0.0 10,2 8.09 10:10:2001 :21:05:50 Batch Mud Push 10: 10:2001 :21 :05:50 -9 0.0 10,2 8.08 10: 10:2001 :21 ;OG:.2e 19 0,2 10.3 8.39 10: 10:2001 :21 :07:29 47 0.0 10,3 8,21 10: 10:2001 :21:07:33 Reset Total, Vol = 10.29 bbl 10: 10:2001 :21 :07:33 51 0,0 10.3 8.1$ 10: 10:2001 :21:08:30 78 0.0 0,0 9.43 10: 10:2001 :21:08:50 Start Mud Pusn 10: 10:2001 :21:08:50 27 0.0 0.0 984 10: 10:2001 :21:09:30 183 2.6 O,g 10,33 10: 10:2001 :21: 10:31 189 2.6 3,6 10.17 10: 10:2001 :21:11 :3.2 411 5.2 7,7 10.21 10;10:2001 :21: 12'32 397 5,2 13.0 10,24 10: 1 0:2001 :21: 13:33 398 5.2 18,3 10.12 10:10:2001 :21: 14:34 399 5.2 23.7 10,27 10:10:2001 :21: 15:34 399 5.2 28.9 10.28 10: 10:2001 :21: 16:35 386 5.2 34,2 10.15 10: 10:2001 :21: 17:36 395 5.2 39.5 10.24 10:10:2001 :21: 18:36 398 5.2 44.7 10,30 10: 10:2001 :21 :19:37 385 5.2 49.9 10,18 10: 10:2001:21:20:38 400 5,2 55.3 10.19 10:10:2001 :21 :21 :38 389 5,2 60.5 10.17 10: 10:2001:21:22:39 391 5.2 65.8 10.22 10:10:2001:21:23:40 263 3,7 70.7 10.61 Page 1 of 4 10/21/01 10:55P P.010 r---\ ~ Well: L-115 Job Date: 10"10"2001 r T . .-... .,., .",... . I Time Treating Pressure Flow Rate CMT STG VOL CMT DENS ! mm:dd:yyyy:hh:mm:ss ; psi bbl/min i bbl Ib/gal I .I.. , 10: 10:2001 :21:24:35 27 0.0 73.6 10.61 10:10:2001 :21:24:41 25 0.0 73.6 10.61 10: 1 0;2001 :21 :24:49 Reset Total, Vol;;; 73.64 bbl 10:10:2001 :21:24:49 22 0.0 73.6 10,62 10:10:2001 :21:25:41 13 0.0 0.0 8.92 10:10:2001 :21:26:42 15 0,0 0,0 9.75 10:10:2001 :21 :26;52 Start Lead Cement 10:10:2001 :21 :26:52 11 0.0 0.0 9.87 10: 10:2001 :21:27:43 162 2,6 0,6 10,60 10: 1 0:2001 :21 :26:43 370 3,8 3.5 10.72 10:10:2001 :21:29:44 706 6.0 B.6 10.82 10: 10:2001 :21:30:45 627 6.0 14.8 10.56 10: 10:2001 :21 :31 :45 649 6,1 20,9 10,81 10:10:2001:21:32:46 590 6.1 27.0 10.41 10: 10:2001 :21 :33:47 757 6,6 33,$ 10,95 10:10:2001 :21:34:01 Change Rate 10:10:2001 :21 :34:01 757 6.6 35,0 10.76 10:10:2001 :21:34:47 670 6.6 40.1 10.72 10:10;2001 :21 :35;48 711 6.7 46.8 10.86 10: 1 0:2001 :21 :36:49 698 6.7 53.6 10,74 10:10:2001:21 :37:49 692 6.7 60,3 10.78 10: 10:2001:21:38:50 688 6,7 67.1 10.59 10: 10:2001:21 :39:51 673 6.7 73.9 10.59 10: 10:2001 :21 :40:52 e8S 6,7 80,7 10,66 10: 10:2001 :21 :41 :52 666 6,7 87,4 .\ 10.73 10: 10:2001 :21 :42: 53 714 6,7 94.2 10.81 10: 10:2001 :21 :43:54 711 6.7 101.0 10.76 10: 10:2001 ;21 :44:54 726 6.7 107.7 10.90 10:10;2001 :21:45;55 893 6,6 114.4 11,24 10:10:2001 :21 :46:56 7a6 6.7 121,2 11.00 10: 10:2001:21:47:56 920 6.6 127.9 11.15 10:10;2001:21 :48:57 686 6,7 134,7 10.76 10: 10:2001 :21 :49:58 730 6,7 141,5 10.77 10: 10:2001 :21 :50:58 736 6.7 148.2 10.82 10: 1 0:2001 :21 :51 :59 724 6.6 155.0 10.95 10: 1 0:2001 :21: 53: 00 714 6.6 161.8 10.91 10: 1 0:2001 :21 :54:00 685 6,7 168.5 10,88 10: 10:2001:21:55:01 711 6.7 175.2 10,93 10: 10:2001:21:56:02 707 6,7 182,0 10.81 10: 10:2001 :21 :57:03 715 6.7 188.9 10,93 ~.... ~.- .............. ..... ........ ....... . . ******************************************************************************************************** * ' , p, 01 * * ~ TRANSACTION REPORT ~ * *OCT-22-01 MON 12:26 AM * * * * DATE START SENDER RX TIME PAGES TYPE NOTE DP * * * * OCT-22 12:22 AM 2'42" 9 RECEIVE COM.E-7 ~ * * ******************************************************************************************************** Oct-20-200l 00:40 < F r OIII-ftABORS 9E S r"-. +90r-659-4833 ".-..,. T-325 P.OOI/002 F-163 Phone: 659-4806 FlOC 659-4833 Fax To: Tom Maunder. Commissioner-AOGCC From: Nabors 9ES - Fax: 345-1851 Date: 10120101 PhOMf Pages: 1 -+ cover ReI Freeze Protection Plan, L-115 cc: C Urgent X FOT Review CJ ...... eo........ C3 ,..... Reply Q ...... Recycle -Comments: [ClìÇk here and type any comments] Tom. Attached is the latest version of the plan forward to manage the freeze prot~ion process on L-115 you have been dÌ$CUssing with Neil Magee and Tom Anglen. Please call if you Wish to comment or diSCUSS further. Thanks, erst Allard Nabors 9ES (659-4831) TO: CamilleO. Taylor,ro\ DATE: Chair Tom Maunder, Ilt.~ P. I. Supervisor O'-~ ":>d-\ October 20, 2001 .~ " ~, MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission THRU: FROM: Jeff Jones, Petroleum Inspector SUBJECT: Remedial Cementing BPX . ;!l;'~' f,\i:";" "i~~\~J"" ;, )M¡)~2Ø ~ONy¡ii '. ';~åF'~rB<5~êalis Po~1 October 20. 2001: I traveled to Nabors Rig 9ES in the Prudhoe Bay Field to witness a remedial surface casing cementing operation on BPX's proposed injection well L-115i. Tom Anglin, BPX representative on Nabors Rig 9ES notified me on 10/19/01 that while performing a freeze protection operation with "dead" crude oil on the 7" X 9 5/8" annulus on well L-115i, rig personnel noted drilling fluid returns from the 20" conductor by 9 5/8" surface pipe annulus into the cellar, indicating insufficient surface pipe cement integrity. Mr. Anglin said he witnessed all indications of a successful initial surface pipe cementing operation, with normal fluid weight and returns during the operation. He also indicated that 9 5/8" Casing Pressure Test and Leak-off Test results were normal and that the current well configuration is: 20" conductor pipe set @ -80' 9 5/8" surface casing set @ 2735' 7" casing set @ 8416' not drilled out; tested to 4000 PSI On my arrival I met with Bret Allard (BPX rep.) and Kelly Cozby (Nabors Rig 9ES rep.) and discÜssed possible reasons why the surface pipe was cemented inadequately. Problems with cement "channeling" or a "thaw bulb" in the formation from drilling the adjacent well 15' away approx. 14 days previously causing the cement to "fall away" were theories proposed. We then reviewed and discussed the plan for remedial action. I inspected the visible L-115i welt casings and detected semi-solid cement in the 20" X 9 5/8" annulus. I inspected the pad and the area around the well and found no evidence of a broach to surface. I did note fresh drilling fluid in the well cellar adjacent to L-115i, but it Remedial Surface Cement BPX L·115ì 1O-20-orfi{fJ'!NEf.» JUL R 62D04' ,~ ,~ ....... appeared that this fluid had overflowed into this cellar from the L-115i cellar. This adjacent cellar was monitored throughout the L-115i remedial cementing with no further influx noted. The remedial cementing proceeded with approx. 6 BBLS of 10.3 PPG drilling mud pumped down the 7" X 9 5/8" annulus with returns taken in the cellar to establish circulation, followed by Schlumberger pumping 252 BBLS of 10.7 PPG Arcticset lite cement at a rate of approx. 2BBlS/min. and 450 PSI. Initially good fluid returns were noted into the cellar containing drilling mud, green cement, and chunks of soft and hard cement. These returns were sampled during the cementing at 10 BBl intervals for weight and PH; however, none of the remedial cement could be detected in the samples. When approx. 50 BBLS of cement was pumped, "dead" crude oil was evident in the returns. At this point returns began to diminish, and ceased intermittently until returns were lost altogether when approx. 180 BBlS of cement had been pumped. The remaining 72 BBLS of cement were pumped and then displaced with 56 BBlS of "dead" crude oil for \),CWs 'o\:)\~ freeze protection of the upper section of the 7" X 9 5/8" annulus, without returns. At this time I advised Mr. Allard (BPX rep.) that a "top job" cementing operation would be necessary, and he concurred. Nabors personnel attempted to insert 1" pipe into the 20" X 9 5/8" annulus to inject cement without success. Several hours later, after considerable effort, they were able to insert approx. 60' of 3/4" pipe into this annulus, where it fetched up solid. Repeated attempts to achieve further penetration failed, and the "top job" cementing operation commenced from this depth. Circulation with water was established and continued until clean returns were taken in the cellar. 16.5 BBlS of 11.0 PPG Arcticset cement was then injected into the 20" X 95/8" annulus to the 60' depth, and I witnessed good returns of 11.0PPG "green" cement to the surface around the circumference of the 9 5/8" surface pipe. SUMMARY: I witnessed a remedial surface casing cementing operation on BPX's proposed injection well L-115i in the Prudhoe Bay Field. Attachments: Schlumberger cement job report 10-20-01 (6 pages) Schlumberger cement job report 10-10-01 (5 pages) BPX cementing report 10-10-01 (3 pages) BPX daily operations report 10-10-01 (3 pages) BPX Casing Test! LOT reports 10-11-01 (6 pages) ~ NON~CONFIDENTIAL Remedial Surface Cement BPX L-1l5i 10-20-01 JJ.doc 10/21/01 10=59P P.0Ø2 ,~, ,~ Well; L-115 Job Date: 10-10-2001 I Flow Rate CMT STG VOL CMT DENS ' . Time Treating Pressure I mrn:dd:yyyy:hh:mm:s$ psi bbl/min bbl Ib/gal 10: 10:2001 :22: is: 15 847 6.7 310-7 10.88 10;10:2001:22:16:16 84$ 6.7 317,5 10.89 10: 10:2001 :22: 17: 16 923 6.7 324.2 10.98 10:10:2001 :22: 18:17 858 6,7 330.9 10,81 10:10:2001 :22: 19:18 927 6.6 337.7 10.96 10:10:2001 :22:20:1 a 933 6.6 344.4 10.94 10:10:2001 :22:21 :19 904 6.7 351,1 10.76 10: 1 0:2001 :22:22:20 849 6,7 357.9 10,56 10: 1 0:2001 :22:23:20 449 3.8 363.4 10.62 10:10:2001:22:24:21 489 3.7 367.2 10.24 10:10:2001:22:24:52 Batch iail 10:10:2001:22:24:52 120 0,0 368.0 10.86 10: 10:2001 :22:25:22 101 0.0 368.0 9.31 10: 1 0:2001 :22:25;45 Start Tail Cement 10: 1 0:2001 :22:25:45 84 0.0 368.0 9.93 10: 1 0:2001 :22:25:49 Reset Total, Vol = 367.99 bbl 10: 1 0:2001 :22;25:49 83 0.0 368.0 10.28 10: 10:2001 :22:26:22 61 0:0' '0:0 13.36 10:10:2001:22:27:23 584 1.1 0,8 15.57 10:10:2001:22:26:24 607 2.6 3,5 15.51 10:10:2001:22:29:25 771 3.7 6.1 1562 10: 10:2001 :22: 30: 25 786 3.7 $.9 1$.80 10:10:2001:22:31:26 770 3.8 13,7 15.84 10: 10:2001 :22:32:21 750 3,8 17.5 15.76 10: 10:2001 :22:33:27 763 3.8 21.2 15.93 10:10:2001:22:34:28 727 3,8 25,0 15.77 10:10:2001 :22:35:29 732 3.8 28,9 15.96 10:10:2001:22:36:29 712 3.7 32.6 15,78 10:10:2001:22:37:30 714 3.8 36,4 1'5.93 10:10:2001 :22:38:31 697 3.7 40.2 1'5.96 10:10:2001 :22:39:31 671 3,$ 44.0 1'5.87 10:10:2001:22:40:32 662 3.8 47.8 15.81 10:10:2001:22:41 :33 694 3.8 51,6 15.27 10:10:2001 :22:41 :55 Shut Down Drop Top Plug 10: 1 0:2001 :22:41 :55 39 0.0 52,7 15.29 10:10;2001:22:42:03 Reset Total, Vol = 52,69 bbl 10:10:2001 :22:42:03 35 0.0 52.7 16.09 10:10:2001 :22:42:33 30 0.0 0.0 11.13 10~10:2001:22:43;34 31 0.0 0.0 11,05 10:10:2001:22:44:35 493 5.4 2.3 10.34 10:10:2001:22:45:06 Pumping Water 10:10:2001 :22:45:06 489 5.4 5.1 10.22 10: 1 0:2001 :22:45:36 492 5.4 7.8 10.16 10~10:2001:22:4e:06 End JOb Switch to Rig 10:10:2001:22:46:06 25 0,0 10.1 10.16 10:10:2001 :22:46:36 19 0.0 10.1 10,10 10: 10:2001 :22:41:37 20 0.0 10.1 9.99 10:10:2001 :22:48:38 21 0.0 10.1 8.91 10:10:2001 :22:49:38 19 0.0 10.1 8.78 10:10:2001:22:50:39 22 0.0 10.1 8.71 10: 1 0:2001 :22:51 :40 21 0.0 10.1 B.68 10:10:2001 :22:$2:40 23 0.0 10.1 10.71 10:10:2001:22:53:41 24 0.0 10.1 10,33 10;10:2001 :22:54:42 116 0.0 10.1 10.01 10:10:2001 :22:55:42 35 0.0 10.1 9.76 10: 10:2001 :22;56:43 1 0,0 10.1 9.63 10; 1 0:2001 :22:57:44 2 0.0 10.1 10.14 page 3 of <4 ...0\ \ ~ I;>,,~ 10/21/01 10:5SP P.001 ,~ ~. Well: L·115 Job Date: 10-10-2001 ,. ... 'p' ..... . , ..... .. ,,~...... __"_"_'~' M'__'" ,.. ,... . , , Time Treating Pressure Flow Rate CMT STG VOL CMT DENS I mm:dd:yyyy:hh:mm:s5 psi bblfmin bbl I big:;! I 10:10:2001:22:58:44 0 0,0 10.1 10.16 10:10:2001;22:59:07 Rig Displðcing@7.5 bpm 10: 1 0:2001 :22:59~O7 4 0.0 10,1 10.19 10:10:2001:22:59:45 1 0.0 10,1 10,20 10:10:2001:23:00:46 1 0,0 10.1 10.18 10: 1 0:2001 :23:01 :47 2 0,0 10.1 10.20 10:10:2001 :23:02:47 4 0.0 10,1 10.20 10:10:2001:23:03:48 3 0.0 10,1 10,21 10:10:2001:23:04:49 1 0.0 10.1 10.20 10: 1 0:2001 :23:05:49 2 0.0 10.1 10,:20 10: 1 0:200 1 :23:06:50 2 0,0 10.1 10.20 10:10:2001:23:06:57 Rig Still Displacing@7.5 bpm 730 psi 10:10:2001 :23:06:57 2 0.0 10.1 10.21 10:10:2001:23:07:51 2 0.0 10.1 10,21 10: 1 0:2001 :23:08:51 4 0.0 10,1 10.21 10:10:2001:23:09:52 3 0.0 10.1 10,21 10:10:2001 :23:10:53 5 0.0 10.1 10.21 10:10:2001:23: 11 :53 4 0,0 10.1 10,21 10:10:2001 :23:12:54 6 0,0 10,1 10.21 10:10:2001:23:13:55 4 0.0 10.1 10.21 10:10:2001 :23:14:55 4 0.0 10.1 10.21 10: 10:2001 :23:15:48 Bump Plug @2760 strokes 3000 psi 10:10:2001 :23:15:48 5 0,0 10,1 10.21 10:10:2001 :23;15:56 3 0.0 10.1 10,21 10:10:2001:23: 16:46 Hold 5 mins 10:10:2001 :23:16:46 2 0.0 10.1 10,21 10:10;2001:23:16:57 4 0.0 10.1 10.21 RECE\VED OCT 22 200\ . ,'rom\SS\QI' . . .'" ,~"', ,-.O!l~ GO A\aSKö u.. u"'·· þ,ncl'lOcaoe Page4of4 r---.. lØ/21/Øl lØ:5SP p.øøa ~ BP EXPLORATION Cementing Report Page 1 of 3 Legal Well Name: 1.-115 Common Well Name: L-115 Event Name: DRILL +COMPLETE 1-····--.--·"··"'· ."., ,. ,. r..~:=~=~~....._ ,. ,Primary Hole Size; 12.250 (in) TMD Set: 2,735.0 (It) Date Set: 10/8/2001 Csg Type: Surface C&sing Csg Size: 9.625 (in) Report #: Start: 1 10'6'2001 -~--""'--""'-" Cement Job Type: Primary . ...._._~~:·:;~~~~~~~JÆ.~m.~~i:·....:~::,T~:~·:ize~q~~;~;Ca~;9"~---- :SQTMD: (ft) ITMD Set: : sa Date: I Date Sot: : SQ Type: : Csg Type: : sa TMD: 'SO Date: I 'Cmtt!, Csg: I Cmtd. C5g: OPEN HOLE , ,,,;~~td. Csg: Cement Co: DOWEI.I. SCHLUMSER.GER ·_·..·""..w·....., . . ... ...........·.M Rot Time Start; : Ree Time Start:17:00 ..-.......--....-. ._._...~~"",.".". Pipe Movement Spud Date: 1 0/7/2001 Report Date: 1 0/1 0'2001 End: . .-. .-.'" ..-.---.-..-....... -........ ............... .. .-...... .-.... "., , . ...F~lu9 _.___ Hole Size: Top Set: (1\) 8TM set: (ft) Plug Date: : Plug Type: : Drilled Out: !.?~:~'. .G~~.~....._ ... n". ........ .... M' ..._"._~ _~._.'__'H"" . . ,........' ..... ,.. "",...., ...... ,. ........,...... ....."..... .......... ........_--. ..------.---............-.. , RPM: SPM: Init Torque: (ft-Ibf) Stroke Length: 30.0 (It) Avg Torque: (ft-Ibf) Drag Up: 25,000 (Ibs) .. ~._. --.........- Time end: Time End: 23:00 .,... ,. ....,.,....""'.____._._._____...___.._..........·H.....__... ........ ,.. ...------..... ..._,...... Type: CW 100 spacer Volume Excess %: Meas. From: Est. Gauge Hole Time Clrc Prior To Cementing: 3.50 Mud Circ Rate: 200 (gpm) Mud Circ Press: 400 (psi) -..._-_._...._--~._.-._,-'''"....... . Stage No: 1 of 2 ·..·.__n....__....___.__.______.._ ..._. ..... Start Mix Cmt 21 :24 ,Disp Avg Rate: 8.00 (bbllmin) Start Slurry Disþl: 21:~ Olsp Max Rate: 9.00 (bbl/min) Start Displ: 22:46 Bump Plug: Y End Pumping: 23:15 Press Prior. (ft) End Pump Date: 10/1112001 Press Bumped: 1,100 (psi) Top Plug: Y Press Held: 5 (min) BQttom Plug: Y Float Held: Y ,... ,.--.------ -----..---.......,..-" .,. -....---....-.-...--..------..--....-..-.- ..-...... Mud Data .. "'...........".."................,..... Iype: SPUD MUO Density: 9,5 (ppg) Vise: 60. (slqt) Bottom Hole Circulating Temperatl,lre:5Â (oJ:) Displar;:ement Fluid Type:OLD MUD Max Torque: (fI·lbf) Or¡¡g Down: 15,000 (Ibs) Retl,lrns: 30 bbls to surf Total Mud Lost (bbl) Cmt Vol to Surf: (bbl) Ann ¡:Iow After: N Mixing Method: On-thê-~Iy DenSity Meas By: Densometer . ._.~,._"..,_...._......_- PVIYP: 30 (cp)/26 (lb/100ft2) Gels 10 see: 10 (lb/100ft2) Gels 10 min: 20 (lb/100ft') Bottom Hole Static Temperature: 50 (OF) Density: 9.5 (PI)9) Volume: 201.00 (bbJ) . ._.._-------_......_.~~_.""..,,".., Slurry Dew Fluid Type: CEMENT Slurry Interval: 26,0 (ft) Water Source: Lake . .. ...n..... .._.._....·.n.....·.'.__·...." Stage No: 1 Slurry No: 1 of 2 ,.'. .... ., ...~.. ...,...'....-_...,,,.._--_._,-,,...,.._..,.._...~._.__._._--_.,,..,,. .-..-.........."'....-.." "". . ...-..._.._-- ......-..-.. .........--.. ASIII Lito Description: LEAD SLURRY Class: G-CLASS To: 2,047,0 (ft) Cmt Vol: 484 (sk) Density: 10.7 (ppg) Yield: 4.44 (ft"/sk) Slurry Vol:382.4 (bbl) Water Vol: 232.00 (bbl) Othor Vol: (bbl) ~LlIPOSQ: FILLER SLUR Mix Water: 1 0 FOflm Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: rF) Temperature: ("F) Temperature: (OF) Temperature: rF) Time Compressive Strength 1: Compressive Strength 2; .------.--.-..--...... Tern" rF) ("1=) Pre~sur!.> (p!'i) (p!'i) ........~.......__..__...- ~- p'i,)led, 10120/2001 6:01:03 AM ,~ 10/21/01 10:S9P P.0Ø4 ~ BP EXPLORATION Cementing Report Legal Well Name: L-115 Common Well Name: L-115 Event Name: DRILL+COMPLETE ..".......,.....-..... _.._....~.. ..-.--.............,. ...... Report #: Start: 1 10/6/2001 Stage No: 1 Slurry No: 1 of 2 . Additives '. .n.. .............--.-.....-.-..--- -.-----"T.---..---.----.-....... .....- __.._,_.__.__._.._,__..,.,nad.e,~ame. "., Type I Concentration Barite 031 7,702.0C Anti Foam Olio 48.0( Disperse TIC065 72.0C Retard 0110 5,OC Cal Chlof 120.00 Uniflac 0167 96.0C - ... ........_.__.._......... .._n........ ." ,.. Slurry Data Fluid Type: CEMENT Slurry IntéNa1: :2 ,047 ,0 (ft) To: Water Source: Lake Test Data Thickening Time: Free Water: (%) Flul<l Loss: (cc) Fluid Loss Pressure: ("F) .. ..... .. Type: Mudpush XL Volume Excess %: Mess. FrOm: Time Circ Prior To Cementing: 3,50 Mud Circ: Rate: 200 (gpm) Mud Clrc Press: (psi) .......__......... __no Units _.....__.._-_._.......,......"~,..,.,._.~.,,...__.., ....... ....~.. Stage No: 1 Slurry No: 2 of 2 '" '. . Description: TAIL SLURRY 2,735.0 (It) Cmt Vol: 249 (sk) Density: 15.8 (ppg) Slurry VOI:52,O (bbl) Water Vol: 30.12 (bbl) Page 2 of 3 Spud Date: 10/7/2001 Report Date: 10110/2001 End: ..-.. ..'. ......-..... ... ...-..---..---- ... ··1" ...--.. I.iquid Cone, Units ........... .................- .-... ..".._.." .I. .. .,~. . _·....n.__.·._.·_·__·___n Class: G·CLASS Yield: 1.17 (frIsk) Other Vol: (bbl) Purpose; FH..l"ER SI..Ur. Mix Water: 0 Foam Job: N Temperature: (OF) Temperature: (OF) Temp.rature: (OF) Tlm@ Compressive Strength 1: Compressive Strength 2: ..__.__...._--~_..- ........ ... ,. .. ..' . ... ..... Start Mix Cmt: ,Start Slurry Displ: : Start Displ: : End Pumping: End Pump Date: Top Plug: N Bottom Plug: N Stage No: 2 of2 I . Dlsp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: (bbl/mln) (bbl/min) N (ft) (pSi) (mln) N .. ~ .... '" .'.'--" ...-...-....-"... .",.... "", .". .".... .. .. Mud Data ___..___..___.. .._... ..._....._.......__. __.__..._.________.._.__._.______._.___._____._... ._._.... _...". ........... .n .. .- .... Type: Density: (ppg) VIse: (s/qt) Bottom Hole Circulating Temperature: rF) Displacement Fluid Type: Temp ('F) ('F) Pre~sur!l (psi) (psi) .. "" ." Returns: Total Mud Los!: (bbl) Cmt Vol to Sur(; (bbl) Ann Flow After; N Mixing Method: Density Meas By: ~. . _.w .. _, . .-.. .. ....~~._._.~._. PV/YP: (ep)1 (tb/100ftJ) Gels 10 see: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: ("F) Density: (ppg Volume: (bbl) ..__________..._._.___.._M_._..____..__.____._~_._..... .....__.._.........~. _~_ _.__~. .._._.......__._._...... .__.. .~... . .. ..... -.-. Prinlnd: 1':)IÎ.OI?:J01 A:(H'03 AM 10/21/01 10;59P P.005 ~ .~ BP EXPLORATION Cementing Report Page 3 of :\ I I legal Well Name: L-115 Common Well Name: L-116 Event Name: DRILL +COMPLETE Report #: Start: 1 10/6/2001 Spud Date: 10/7/2001 Report Date: 10/10/2001 End: -.-------..-.---.----.--.--, ...--.... " ,...... .. ...... ",,,.......,, ".~.._"..."-..."... . ...... Casing Test Shoe Test Liner Top Test --.--...-........... ..-.-.......-...-........-,..--.....-. .---...- ... . ".. Pressure: (ppge) i Liner lap: Toot: N Pos Test: (ppge) Open Hole: (ft) Neg Test: (ppge) Hrs Before Test: Hrs Before Test: ¡ Cement F'~~n~~~..~~.?I:. .~___.._. ........ .._ .......... ..._......_.._.... .__.._ ... ........ Test Press: 4,000 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Tool: N Tool: N ,.----.,..,"....-.,.,.... ,.,. Log/Survey Evaluation ........... ... .................... ·-·-·········..·..r;······· ..... ........... ... . . ... ement To!): 26 (ft) How Determined: Visual check TOe Sufficient: Y !JOb Rating: Excellent 'If Unsuccessful Detection Indicator: Remedisl Cementing Required: Number of Remedial Squeezes: Interpretation Summary CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: 1'1 Hrs Prior to log: N N ..._.._.__~__. . . _, _ ._. M_' ~... . ,".. , . . --. -.." --.".. -,-.-- .. Prinl~d: 1017017001 ~·O.:O:! AM 10/21/01 10159P P.00S ~ ,~ BP EXPLORA rlON Daily Operations Report Page 1 of 3 Operator. BP EXPLORATION Rig: NABORS 9ES ~!'\port: 5 Well: L·115 Event: DFtILL +COMPLETE Date: 10/1012001 Field: L -Fad Well Type: DEVELOPMENT - Current Well Status Depth MO: 2,756.0 (ft) Casing Size: 9.625 (In.) Costs in: USD Rig Accept: 00:00 10'6/2001 Est TVD: 2.619.9 (ft) Casing (MD): 2,735.06 (ft) AFE No: 6M402i Rig Release: Progress: (ft) Next Casing Size: 7,000 (In) AFE Cost: 2,370,000 Spud Date: 10/7/2001 A uth Depth: 8,479.Q (ft) Next Casing (MD): 8,485.0 (ft) Daily Mud; 7,093 Elev Ref: SEA LEVEL Hole Size: 12,250 (in) Next Casing (TVD):6,972.0 (ft) Cum. Mud: 55,706 DOUDFSlTarget: 4.5013.13/16,10 Liner (MD): Daily Well; 293,213 KB Elev: 2B.50 (fi) Geologist: ST£A~N$I BICKE Liner Top (MD): Cum,Well: 732,001 Englnoor: MAGEE I ODE NTH Tot. F'ersonnel: 38 Supervisor: ANGLEN J MORRIS Program: Cost Ahead -76,000 USD, Days Ahead 1.00 CûrièñiStatus: Nipple up csg /tbg·ha:---··-··-..·-··..· . ' .. ~... , .., ,.-.".- ..,.~. .......- .. _"M" ......., 24hr Summary: R.un holè opener, lay dn bha, run! cmt 9 5/8 0$9. 24hr Forecast: Nipple up bop, test, rih 8 3/4 Þha. test csg. Comments: No Accidents, No Inoldents, No SJ)ills.. Weather: Wind NE @ 0 mph. 17 degrees wi CF of 17 degrees, HSE & Well Control Days Since Last DAFWC: 1056 All Free Days: 4 .. ...___M.·.......... . . L"ii&t"ë;g-TesfPress,: -¡pSl)--··" Läst enŸii:-'ncldëñi:--'3"Ï1"6i:fo'ó'--- ..- - . last BOP Press. Test: Next BOP Press. Test: last Safety Meeting: 10/10/2001 last Divertor Drill (D3): 10/8/2001 Last Spin Drill: 10/10/2001 No. Stop Cards: 7 Regulatory Agency Insp: N Non-compliance Issued: N Fire: .. ._"....__._... ...._.__!~1 012_~0:....... ... .. Pump SlóW'Pümj)'Raies(Ö'ir¿f"'- -. SlowPump Rates (Choke) Slow Pump R~ï¡i$(K'i¡"ii'-'-- TVD: (ft) Stroke Rate Pr':!~l!.~~(L Stroke Rate Pre$sure() Stroke Rata PressureO ____._._0._.".. ._____.~_..,....'-M _._, H,..M·. .. . .. -l~-~~~ EMW: (ppg) I MAASSP; (psi) .. .... ·0·-·--_-·-- ---'--'-'~". .... ....-,. .. Test Pressure: (psi) Kick Toler;ll'loe: (ppg) i Kick Volume: (bbl) Operational Parameters ROP Daily: (ftIh r) Rotating Weight: (Ibs) Daily Bit Hrs: 20,00 (hr) Pllmp Status - Drilling and Riser ROP Cllm.: (ftIhr) Pick Up wt,: (Ibs) Daily Sliding Hrs:O.OO (hr) . p'ümp'Typën E·ff. Strökë;; Iinèï' Size ¡ Circ, Ratë' WOB (min): 51al:k OffWt,: (Ibs) Cum. Bit Hrs: 20.00 (hr) (%) (spm) (In) : (gpm) WOB (max); Cire. Rate Riser: f "''''-0-':'''96- - -1Ö2' -. ·--5'.500 302 RÞM et Surf¡¡oe: Cire. Rate Hole; 604 (gpm) Ann. Vel, Riser: (f1/niin) 2 D : 96 102 5.500 1 302 I RPM at Bottom: Circ. Off Bottom: (psi) Ann. Vel. DC: (ftImin) 1 , , Torq. on Bottom: (ft-Ibl) Cire. On Bottom: (psi) Ann, Vel. OF': (ft/mln) Torq. off Bottom: (ft-Ibf) Jar Hrs since Inspect: 139 (hr) Bits . .~;I ~i ..~~ ~'rej\Y-- Ma¿",-,_+_ T,,,, ~ SMJ," J . No"'''.. .J- T~A(;"~)_I~"lh ''''')-1. D.'pl"""'" 3 12.250 Smith Porcupine 155488$11 '1.2/'1.2/2'1.1'1.0//1 1,420 2,756.0 2,756.0 -'èum p'r()gJ~)I.R£'·~~~!.ñ/M¡¡X ¡WOB ~in/Max: "D~i~~rs ._=~~~o~r~. fcum ROP-l--;-;-~"'''; ~;'~~'nditi~ñ""-"I . T ÑO'T".tt)T~ BHA No Type , Weight Wt Below Depth Out Description , (Ibs) .~ar (lbs) (ft) -'3" -dÜ::AN··ODT----'r·-· -... . 0 2.756,0 HOLE OPENER. Xd:FCdÄT..S\.ÌB~-Ñr:iORICCCOLLÄR: XÓ: '''iM-STRINCi STAB; XO, INM DRILL COLLAR, XO, HWDP, JAR, HWDP, XO, 21 x HWDP, ..---- Drillin J Fluid Type: SPUD MUD 10 5ec gel$; 10 (IÞ/100W) Ca: 60 (mg/L) , ES: (rnV) Tlme/Loc: 20:00/F'IT 10 min gels: 20 (lb/10OO") K+: (mg/L) I Solids: (%) Depth; 2.756.0 (ft) Fluid Loss: ß,S (CCf30min) CaCI2; (%) OU; (%) Temp: (OF) HTHP Temp: (OF) NaCI: (%) Water: 91.5 (%) Density: 9.50 (ppg) HTHP WL; (Oc/30rnin) CI-: 800 (rng/L) : OillVVater; I Funnel Vise.: 60 (s/qt) Cake; 2 (132") Sand: 0.10 ('Yo) Daily Cuttings: (bbl) ECD: 9.80 (ppg) MBT: 22,00 (ppb) HGS: 0.20 (pPb) Cum. CuWngs: (bhl) PV: :)0 (cp) Lime: (ppb) LGS: 74.71 (ppb) Lost Downhole: (hbl) yp; 26 (lbI10OO2) PM; (mL) Pf/Mf; 10.40 (mLlmL) Lost Surface: (bbl) pH: $.2 Prinlcd: 10/2C!/20Q1 B:12.25 AM BP EXPLORATION Daily Operations Report Rig: NA80RS 9ES Event: DRlll+COMPLETE Well Type: DEVELOPMENT Survey Data Vertical Section Definition == 328.16 Incl. I Azimuth TVD +N/-S +EI-W Section OLS Tool n i (') (ft) (It) (ft) (ft) ('f100ft) .. .... ·3:990-·-----:f:2·ßfj· '-"-'-"(039:45 -14.81 7,57 -16,67 . . :Ù;'¡""'" 5,834 334.53 1,132.93 -7.91 3.54 -6.59 2.24 6.848 340.54 1.225,44 1.59 -0.35 1.541.30 6,421 343.95 1,316.70 13.25 -4.04 13,39 1.78, 11.512 345.04 1.408,75 28.841 -6,34 28.90 3.31: 13,780 349.12 1,500.67 48.951 -12,89 48,38 2.59! 16.155 348.78 1.589,28 72.20; -17.43, 70.53 2.591 17.697 350,02 1.680,47 99.47 i -22.521 96.39 1.66 17,337 344.09 1,797.34 135.38' -30.761 131.23 1.491 17.141 338.78 1.858,74 153.42 -36.81, 149.76 2.47: 19.041 338.02 1.947,60 160,.41 -47.51: 178.32 2.05 i 21,052 340.03 2,034.23 209.93 -58.801 209.36 2.311 23.446 339.51 2.120.32 242,97' -70,98: 243.86 2.581 25.585 338.71 2,202.25 271,88: -M.32\ 280.54 2.401 27,914 336.94 2,285.92 316.91: -100.26 322,12 2.631 31.40B 333.06 .... 2,365.67 358.02 -119.51 367.19 4.34 34,951 331,06 2,443.83 403.14 -143.49 418.16 3.97 36.409 326.25 2,518.63 450,63 -17;a.~3 .473,64 11.82 42.235 325.54 2.575,75 490.76 -199.72 522.28 5.14 Operations Summary From-To ; Hrs Phase J Task Activity COde I NPT Operation hh:mm I (hr) I '..._ .._. -Öõ:"OO-02T30Ti]O- -SÜRF'TDRILL HOPEN"- - P--:-- Make UP bha #37IÏõlè-õpeñér:-Lä~ïouf2 galled DCs. 02:30-06:00 i 3,50 SÙRF- ORiCe -H"OP-E·Ñ--P·--·-·- -. Flow check, rih hole öpener ašsY"tò 'zeo.ffC....··· .;-. . ... .......-. . I I . 06:'ÒO:66:3<f!""0:50 . . SURF DRILL -Óif'3-0:07:3(r~'TÒ(fI-ŠORF -DRILL ~ 10/21/01 10:59P P.007 .~ Operator: BP EXPLORATION Well: L-115 Field: L-Pad Report: 5 Date: 10/10/2001 Page 2 of 3 MD I (It) .~ I . 1.039.98! 1.133,811 1,226.891 1,318,97 1.412.44 1.506,65 1 ,598.38 1,693.70 1,816,24 1,880,53 1,974.01 2,066,23 2,159,26 2.249.31 2,343.01 2,434.79 2.528.19 2,621.45 2,696.38 HOPEN- ·-·p--------·-Ream"150· ft: 'tå btm. HOPEN ..-p----.-.----- Prt!pare ãñëf~õ¡;"fõr9 5Jaï.:sg ·run. EMS IAK EMSIAK EIVI$IAK EMSIAK EMSIAK EMSIAK EMSIAK EMSIAI< EMSIAK EM$IAK eM$IAK EMSIAK EM$IAK EMStAK EMSIAK eM$!AI< J!'MSIAI< EMSIAK EMSIAK ---.-----.-. .,. '-". ..-,. 07:30:09:30 : 2.00 SURF .¡jRïC~-BHÃCr¡- -P--'-'-" . .. layout BHA #3. clear rig floor, . - .. .-.. '.... .-.. ".-..-.... 'Og':3'Q:f2:30 .~. 3:0'0· "SURF 'CASE RTIH .. .....þ..-----.----...-. 'pjSM;"'pläëa -9'5 'fB running equip'on floor, rig up same. . _·___u· , Perform dummy run 9 5/8 hgr, reoord strap. "12:3'0':"17:00-;-;C50--'SÙRF CASE I RTfH' .-. --P-:·---- ~Iow c;:hê¿i<;-t'v1äkÌ!l-upšhõë track, thread lock criUcal connectiQiÙõ: . .-... J : J Check float equip. Commence rih 9 5/8, 40#. LSO, BTC 059, : 1 : Make up hgr, land at :2735 ft. -1·t:oo~io:30T3.50 SURF CASE i -·-ëll~--·· -p¡------ 'Mãke ü'p¿nït"hi(ciiëJ cond mud, reci~ pipe at all times.'··'··-·-·· 1 I -20:3Ö::-ÕO:ÖÕ-;-:ßO- -SURF CASE: CMT' ...---p-...-1----------- ·PumpfÖ-bbCÖl'nbO~-Tèsfliñeš-to3500psi. Test good. Drop btm plug, pump 75 bÞls Mudpush XL spacer. Commence emt 9 5/8 C$9 as follows: Pl,lmp 382 bbls 10.7 lead slurry @ 6 bpm. Pump 52 bbls 15.8 ppg tail slurry, Drop top plug, chase with 10 bblS H2o. Change over rig pumps, displace at 8 bpm, 201 bbls drill mud. ICP 490 psi at 8 bpm, FCP 700 psi at 3 bpm, Bump plug wtl11500 p5i. Hold 5 min. 61eed, check (Io$t$, no flowback. Flow check 30 min. Pipe reciprocated constantly during cmt. Stop at !;t11it of flush, Circ 30 bbls cement to surface. PlUg bumped at 2326 hrs. 06;00 Uptlate: Layout cmt equip. nipple dn diverter, nipple up csg I tbg hds. , -- ...-- Prlnled; 10/2012001 8:12'25 AM . /'~ 10/21/01 10:58P P.008 ~, BP EXPLORATION Daily Operations Report Page 3 of 3 Operator. BP EXPL.ORATION Rig: NABORS 9ES Reþort: 5 Well: L-115 Event: DRILL+COMPLETE Data: 10/1012001 Field; I.-Pad Well Typo: DEVELOPMENT Materials 1 Consumption Item ·----+GAr.units - uS~~~il.9r1 H6~~~ I Item .,... .1 ' ... - ~n,it~.. .. ··f·..·~gag~... 'I'?~ !j!'l.~.~.. ·ÕIESËl. Personnel ".,. ..,...~~~paI!Y______L.!'i~... Houl'$ Company . No, ,Hours Company No. Hours BP I 2 --Œöö -ép----·- -·'-----,·-·....--2; -12:00 NABORS , 213 12.00 BAROID 2 12,00 ANADRII.I. SCHI.UMBERGER I 21 ANADRILL SCHLUMBER.GER 2 Anchoring I Marine . .::ñ~~~~J_._, 1 , 2 -I~~I"-~I- 6 I 6+~7J819.1 10 I 11 12 ____ _._...._._._ _.. H' .. , I I .. " . .. Rig Hëiiïie:..·..···- ......--.-.-... ....-. ""'~f$ër'T¡';';sion;' " ,. -,. .......-.... Rig HeadÎng; Sea Height: VDL: Sea Olr.: Rig Roll: Riser Anglo/Dir.: / Swell Height: Sea Period: Rig Pitch: Current: Current Oirection; Comments: Cumulatiye Phase Breakdown PlannÐd . .... Chilngeof Scope Total T (Ita I Cost Phase Prod % Total NPT % Total; WOW % Total .. proif' % Totär '-'NPT"- iI¡';'Tõtãï . WOVÎI '"%Totäf Hours USO 'PRE :is-:-ÖÖ-'¡OÖ-:-Ol>;¡ --..--.-...."..." .... ..-... .....'..-. -... '-"'28:00 ...........-..--..... SURF 86.00 100.0% 86.00 'TOTALŠ--' . ',',;Ùo", oo:o·j'c;' ,,,... , . , " . .- 0.00 ..-.. .. .._n_ _.. .n.._ - . ,~ "-114;00 ..._......:-~ 0,00 0,0% 0,00 0.0% 0.00 0.0% 0.0% 0.00 0.0% Window' Coiled Tubina Drlllina Wi'1dol/V Top; (ft) CTOD: (in) CT Daily Ftg: (It) CT Strength: (psi) Mud Sys Ftg: (it) CTID: (In) cr Cum Ftg: (It) CT Length: (ft) Window Desc: ", Remarks .. '" Print.d 10120/2001 B,12,25 ^M . .-.>. '.',' , .'. ->.. ". .~', . '::>!';' ~> .:.:.~~'.:;.;: -> .->' "'..'>' ->: '~i:' ...~. '. .>::... ..'>. '. . ':.->.' ,.' . .~~. .>.:~> ' ','r ,·1 '\. . :.-;>. ", ~,. , '''~' :. . .~ , , 10/21/01 10:5SP P.00S .~ ~ASING AND LEAK-OFF FRAcn = TESTS Well Name: L·115 Date: 10/11/2001 Supervisor: Anglen/Morris 2604 TVD Leakoff pressure == 525 psi Hole Depth := 2775 md Volume Back := 0.5 bbls 0.071 Barrels/Stroke CASING TEST DATA o 1 2 3 4 5 10 15 20 - ......-_.... . ..... ,,,. -> . 25 '0:>.';;>". 30 . (1'-""'" "-'.' --..... "...." Csg Size/Wt/Grade: 9 5/8 40# L-80 Csg Setting Depth: 2735 TMD Mud Weight: 9.3 ppg LOT= 13.18 ppg Fluid Pumped= 1.0 BblS Estimated Pump Output: LEAK-OFF DATA Enter Strokes HQrø Enter" Pressure Horq ~ o 8 :-"'~';::::..'....... 1~~" ... . '> \O~ .:: .-m···..·(3 » :> 290 \ 4'" .> ··--å..~··')·.. . .....4"3"3". '> p,\ \ -~. ....g. ~. r" ... 500..·· ). cÞ "1 ".> 16 >-"r"'--- . ... - 536 ~ .............~> 1. <.-.. . . ~> . . . u.__ --"'11 >- l ... - -·-.----··583 . ..- > '" ""'\ ... .> .. ····..·..-12ï}.-·l-· . '--612---"'-" '> ~ ~ .','. .>.:..,,> ... f3~----" . (33-0---- > \ ~.. ":;'," . "fi;i'): Y"'-' .-.... .. ......-..-.- ->.. .:> ..' . .>. .0 ..,.... ..__..... .> . ->.. . -> , .. .."..........-...-...... Enter Holding Enter Holding Time Here Pressure Here 1 340 . .." --.... .. 2 280 ". ···..·---··-""'·3 ' .. ......- ····2..52 ... 4 ........-..... . 2"3"4' . .."........ ...__ ... .....no , 5 221 6 210 7 201 " _0' "_. 'N' .... ... . 8 190 . .-. -.---...--....-. ....- ".. ,.--...-...-.... 9 186 ..__.._ __. __.._..... '" ".". .... _........ o. ._...._ ... 10 184 ,,:~:><' .> . .>. "'N "".N"_.... . ...-------.- --. .".----- - -..,-- --..------..-. . '--0" _._____"N..·. '":11;' . .. .--.----....---............ ,., - "."........... ..... . . .. _n...._. ""'M ->. Enteï:~Strokes Hore T J Enter Pressure Hore .... I. I I "> o 5 10 15 20 25 30 .. N"'"'''' . 35 . ~fõ-··---.._··_--·· .. '4'5 ........ ...... 50 55 60 65 Enter" ¡:·iolding-··· Time Here Enter Holdii,g . Pressure Here 4000 3985 3985 3985 3985 3985 3985 3985 3985 3985 .",...... _H" _.... 3985 25 333 740 1080 1449 1858 .~. --. .........-.. .. . 2277 . ...-...------... 2719 3165--" 3508 .> -> .' .> .> .> ~> .> .>' . .> .> ..-..---.. -,. ..., ... ....-............ .> . .>. . \ o-Ç. ~ 1700 1600 1500· 1400 1300 1200 . 1100 1000 900 800 700 600 500 400 300 200 100 o o .~ 10/21/01 10:59P P.010 ~ I ~i~~~:?~.~~ÄTÃ·~.9-~~~~S? :r~~ I DÄ.i~.1 ¡ I 1 I , I I I.. . .. í ·1..····· I 1 I I ; .1._._______._. . r' . ..._....... .... . ;................_... ¡, -. ...-- ....,- .-.. . ....- -....----..... . I .-.. ..... ......--._ . . . __=~=~ ~:=_~=__I --.-==:~:_ .____m_ ¡ , I I ···..···-····1·..···· I ,....... I ... ._"'~ . ....~- .,. "...-,...-.,... ... . .---- -... 4000 3900· ....... ...-..... -... .. .......... . 3800 . .-..----.--... .. . . .-...--------..... .. --.-... .... -..- .. . 3700 .. -.-----.. ....------,- ... 3600 . ......--...--....... 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 2400·..·-..· 2300 2200· .... 'iii .s. 2100 . ------.. cÞ !5 2000 1/1 ë 1900 0.. 1 800 '''....--.-.......-............ . .....--..."...-.... .. ........... ...-- -........-.-- .-.- ~. ......----..- . .--.--- --.-...., ..1. ! ! __'H"__' '" . .1. I i ....... .. ··-·1 ··..1· ·1 , .... ......... .. ,........--..---- .----., ... . .. ,.....-. ...- ... ....__._..._...... N" 10 20 30 40 Strokes (# of) I. i ..-----"... _._- 1. 1 1 ·1 i i I _ L... "-1 ! . " ,. ""... ......... .- . .. ...---."--..- " ...... ...-....--. .....'. .. .... '~HH .__,.. ,,_._, . , i .. ·r·..·--···· I .. ... ..... 1 I ! .1 ... ,.._.. '.,. R·..., , 'R.·_ .__, .____ ... ... __ H ._. ... -·-r·---·-------.. I ." '" .... " 50 60 70 ;} ~~ ~ ~ lØ/21/Øl lØ:5SP P.Øll /-~ -: ¡ . I I r . ... "-'"_.''-'-'~--''-''' ..,_.....,--~_.._.. noon . ...~ " w.o'... .._ .._., . ...~.._l.E~K.?FF D~i~·_.:-œ-~Ä~iÑG-iË~.,. .~~~~] 4000 3900 3800 . .------.....-.. 3700 3600 3500 3400 3300 ¡ 3200 . .. .--..-...-. I I 3100 +..-..... 3000 .j' 2900 2800 ....... ...... ......... I . I 2700 .... ... ---.--......-. .. ..__ ..... . .1__ . 2600· -.-.----.-. . ...-.....-..- .. ....... _.....__.__........ .... 2500 ..-......-..-..-..--...-...... .....-. .._.._...... ....... .... ... .. ___ 2400·· ....-..-....,.-....-.......... .. ......._..... 2300 ......-......---.-. .... .... ............ _... 2200 ! 2100 ~ 2000 1/1 1ß 1900 ~ 1800 1700 ...n...n...._. .... 1600 1500 ... ...... .... 1400 1300 .¡ 1200 . ..- .. I ......1. I I 1100 ..... ..·····_·.._____..··1· .. ... ...--.. 1000 '-"'---'-'" I ......---..--t-..... I 900 .. ...._..n ---..-...........-__. ..1 ......_._..... ...... 800 ...-..-...-...... . ........_........ .......... .... ..j. 700 ..........--..--......- ....._.____...... .___............__......_....... 600 . ..... .......... -........... .... .. . ....... ... .. _...... ... 500 . .n.. ........-... ..... .... ..-.......... -_...... f... .. . ......... I . ··r·~· . "1-- ..-.................. i I ..-.--..-..-...-... ... .... '......H·. , I,. I , I I I I ! ...-.. .' ,,·..·...._·....N.. ,.. -.00. ....__.____.......__". . . ....-...... ....... ............ I . .i.-... I I I ! 400 300 í 200 I 100· . 1· 0 0 ......---.,.........."... ..... '0' ",,,.. ; I .! .. ..... ·-----1.... I I 5 10 15 Time (Minutos) 20 ...~ .-----.- .-..... .. ·"--"'-'-1 ¡ ¡ _.. ø ... ...... .. ......M__....·_....~... .._.._. . ....···1 i ...... ..1 . . ·1·..· ! I I ..........._1... ! .....·....._.ø.... . .. ....,.... .-... -.-. 25 30 ~ Qi ~ /~ 10/21/01 10:6SP P.012 .~ to( o.f Go 10;58P 10/21/01 P.018 ~~-..'\ , .. 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Y~ ,_~__ __ .~_ ~ _ ~='l'~ //.o''': ~s:::-' _. _~:::::'"':___ __ _ ... :+.~ - - -:.---:::;.,:;;..-::-::.- ~ ~ 'i Ì\' :::--:::~~"':::___ --...::.-==- ~-::3..:-::;.---:-%.:Ç~~~/ s;¡ __;'<:'" _ __. -_ _.__---.....__----..:::-t.--..------'~X---~V ' __ ';~ . . '," . ,:c-~~-=--p~. ---- - -_...-.-::::¡:.:.-- .-_..¡..--.:.,.-:_.~ /. _. .= .==:.7.. _ ~:~::ñ:'S'::T~---:=--"-' :- ",'1\ S., . . --...::::::.:::. :1'1 0 E - .- ~H.,l. . \ ~ - . . lÞOf' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: 0 Abandon ~~ 0 Plugging 0 Time Extension 0 Perforate o Alter Casing 0 Repair Well 0 Pull Tubing 0 Variance 0 Other o Change Approved Program ~ eration Shutdown 0 Re-Enter Suspended Well 0 Stimulate 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. 0 Development Plan RKB = 77' o Exploratory 7. Unit or Property Name o Stratigraphic Prudhoe Bay Unit 181 Service r-, ~ Jt'^~o' \Ot ø~ ./Q ,j ?..s- J:tÐ/ /;}'d- 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 8. Well Number L-115i 9. Permit Number 201-140 10. API Number . 50- 029-23035-00 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 4. Location of well at surface 2543' NSL, 3801' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 512' NSL, 522' WEL, SEC. 28, T12N, R11 E, UM (As Planned) At effective depth At total depth 873' NSL, 734' WEL, SEC. 28, T12N, R11 E, UM (As Planned) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8435 feet 7014 feet 8335' feet 6920 feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 107' 107' 2735' 2735' 8417' 6925' 80' 2709' 20" 9-5/8" 260 sx Arctic Set (Approx.) 483 sx Articset Lite, 250 sx Class 'G' 8389' 7" 209 sx CemCrete, 346 sx LARC Perforation depth: measured None RECEIVED true vertical None OCT 1 9 2001 Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Alaska Oil & Gas Cons. Commission Anchorage 13. Attachments 181 Description Summary of Proposal o Detailed Operations Program 15. Status of well classifications as: o Oil 0 Gas 0 Suspended Service Injector o BOP Sketch 14. Estimated date for commencing operation October 19, 2001 16. If proposal was verbally approved~ Qlrl'<\n Tom Maunder RJ:j..-'1\" " 8/19/2001 Name of approver Date Approved Contact Engineer Name/Number: Robert Odenthal, 564-4387 17. I hereby certify that the fo going is true and correct to the best of my knowledge Signed L II C Title Senior Drilling Engineer owe ran Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of Approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- l..{C) ~ Original Sìgned By ammy 1\ G \ N A L L-1j~Suspension plan ~ ~ Subject: L·115 Suspension plan Date: Fri, 19 Oct 2001 12:41:40 -0500 From: "Odenthal, Robert S" <OdenthRS@BP.com> To: "'tom_maunder@admin.state.ak.us'" <tom_maunder@admin.state.ak.us> Due to the questions that about the spacing and not having a pool rules in place. We are suspending drilling operations on L-115. We will finish the completion after the issues in questions are resolved. «L-115 Suspension Plan.doc» Robert S. Odenthal BP Exploration Alaska Drilling Engineer Work #: 907-564-4387 Cell #: 907-440-0185 E-mail: odenthrs@bp.com Name: L-115 Suspension Plan.doc lliJL-115 Suspension Plan. doc Type: WINWORD File (application/msword) Encoding: base64 1 of 1 10/19/01 10:53 AM ~, ~. BPXA-NABORS9ES-PBU Well: L-115 7" Suspension Plan 1. Run 7" casing and set at the depth of 8416' 2. Cement casing in place 3. Rig down cementing equipment. 4. Pull and lay down landing jt. Pick up pack-off running tool. 5. Set pack-off and RILDS. Test pack-off fl above to 4000 psi wI 7" x 9 5/8" annulus open. 6. RIH wI 6 1/8" bit on 4" DP. 7. Confirm annulus injectivity as follows. · Rig up kill line to the 11" 5M Wellhead casing valve. · Test line against the closed wing valve to 4000 psi. · Open wing valve. Line up rig pumps on active pits. · After OK from Dowell that UCA Test 500 psi compressive strenath has been attained: Initiate injection of 85 bbl of 10.3 ppg mud down the 7" x 95/8" casing annulus. Record the formation break- down pressure as an equivalent mud weight ( LOT ). · Once complete check annulus pressure & close casing valve. Disconnect Kill line. 8. Freeze Protect 7" x 9 5/8" annulus as follows: · Rig up Hot Oil line to the 11" 5M casing valve. Test to 3500 psi. · Bullhead 60 bbl (2000' of annular volume) of dead crude oil down 7" x 9 5/8" casing annulus not to exceed 3500 psi. Once complete check annulus pressure & close casing valve. · Bleed off pressure on hot oil line & disconnect it. Catch all oil residues from hose. Follow BP & Nabors spill prevention procedures & take all precautions necessary to avoid a spill. · Release Hot Oil Truck. 9. Close Blind rams & test 7" casing to 4000 psi for 30 minutes. Record on chart. 10. After LDDP, RIH wI 3000' 4.5" tbg wI WLEG. 11. Set BPV. 12. Land tbg. ND BOPE. NU & test tree. 13. Freeze protect well by circulating diesel around. 14. Secure well and release rig. "Ii' ., ~ .. .~" /""""'\ Borealis L-115i: Proposed Completion TREE: 4-1/16"-SMCIW Carbon WELLHEAD: 11" - SM FMC GS Cellar Elevation = ±47' RKB-MSL = ±77' 9-518",40 #/ft, L-BO, BTC 2735' 4-1/2" 12.6# L-80, Premium Connection Tubing 41/2" WLEG Plug Back Depth 8334' 7",26 #Ift, L-BO, BTC-Mod 8416' Date 9-30-01 Rev By Comments NM Proposed Completion (P6) Borealis WELL: L-115 API NO: 50-029-23035 BP Alaska Drilling & Wells ~ /~ BPXA-NABORS9ES-PBU Well: L-115 7" Suspension Plan 1. Run 7" casing and set at the depth of 8416' 2. Cement casing in place 3. Rig down cementing equipment. 4. Pull and lay down landing jt. Pick up pack-off running tool. 5. Set pack-off and RILDS. Test pack-off fl above to 4000 psi wI 7" x 9 5/8" annulus open. 6. RIH w/6 1/8" bit on 4" DP. 7. Confirm annulus injectivity as follows. · Rig up kill line to the 11" 5M Wellhead casing valve. · Test line against the closed wing valve to 4000 psi . · Open wing valve. Line up rig pumps on active pits. · After OK from Dowell that UCA Test 500 psi compressive strenath has been attained: Initiate injection of 85 bbl of 10.3 ppg mud down the 7" x 9 5/8" casing annulus. Record the formation break- down pressure as an equivalent mud weight ( LOT ). · Once complete check annulus pressure & close casing valve. Disconnect Kill line. 8. Freeze Protect 7" x 9 5/8" annulus as follows: · Rig up Hot Oil line to the 11" 5M casing valve. Test to 3500 psi. · Bullhead 60 bbl (2000' of annular volume) of dead crude oil down 7" x 9 5/8" casing annulus not to exceed 3500 psi. Once complete check annulus pressure & close casing valve. · Bleed off pressure on hot oil line & disconnect it. Catch all oil residues from hose. Follow BP & Nabors spill prevention procedures & take all precautions necessary to avoid a spill. · Release Hot Oil Truck. 9. Close Blind rams & test 7" casing to 4000 psi for 30 minutes. Record on chart. 10. After LOOP, RIH wI 3000' 4.5" tbg wI WLEG. 11. Set BPV. 12. Land tbg. ND BOPE. NU & test tree. 13. Freeze protect well by circulating diesel around. 14. Secure well and release rig. ,~ ,-, aOJ-J'-/O RECEIVED .,. bp ."'.'11. -...~ ~~-- ~...- ~...~ *~ ~.. ·I'+jl\' ". SEP 1 4 toØ] Alaska Oil & Gas Cons. Commission Anchorage To: Tom Maunder, AOGCC Date: September 14, 2001 From: Neil Magee Subject: Dispensation for 20 AA C 25.035 (c) on L-115 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale for the request. To date, none of the 5 Borealis/Ivishak wells at L-pad, nor the two NWE wells 1-01 and 1-02 drilled in 1998 experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. All four of the surface holes for the Borealis Development (L-116, L-ll 0, L-114 and L-l 07) and the first Ivishak well (L-O 1) were drilled to the shale underlying the SV -1 sands. The shale underlying the SVl is the deepest planned surface casing setting depth for future pad development wells. This casing point is ±300' TVD above the U gnu horizon. RFT's from NWE 1-02 recorded pore pressures of 1,275 psi at 2782' TVDss (8.8 ppg EMW) and 1387 psi at 3059' TVDss (8.7 ppg EMW) in the Ugnu. L-115 is planned to reach 9.6 ppg mud weight before TD at 2,500' TVDss. This request is being made based on the previously submitted mud weight and RFT data for L-Pad, (Permit # 201-167 well L-117.) Your consideration of the waiver is appreciated. Sincerely, '-IJ. ~o~ Neil Magee ADW Engineer 564-5119 ~ --... ~V~VŒ lill~ ~~~~æ~ AI.ASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W, 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit L-115i BP Exploration (Alaska) Inc. Permit No: 201-140 Sur Loc: 2349' NSL, 3801' WEL, SEC. 34, Tl2N, RIlE, UM Btmho1e Loc. 873' NSL, 734' WEL, SEe. 28, Tl2N, RIlE, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Q Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit L-115i. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (M!) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~«, ~ Julie M. Heusser Commissioner BY ORDER OF THE WMMISSION DATED this 6 ..... day of August, 2001 jjc/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · . ~ STATE OF ALASKA ~ ALA~ .A OIL AND GAS CONSERVATION C~ .II1ISSION PERMIT TO DRILL 20 MC 25.005 ~b-~ ." Revised Surface Location: 08/27/01 12. Distance to nearest property line 13. Distance to nearest well ADL 047447,4406' MD L-110 is 29' away at 575' 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casinf) Program Specifications Ize Casin Grade Cou lin 20" H-40 Weld 9-5/8" L-80 BTC 7" L-80 BTC-M o Exploratory 0 Stratigraphic Test 0 Development Oil II Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan RKB = 77' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028239 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number L-115i 9. Approximate spud date 10/01/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 8448' MD / 6955' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 39.5 0 Maximum surface 2787 psig, At total depth (TVD) 6379' / 3425 psig Setting Depth To Bott m MD TVD MD TVD Surface Surface 110' 110' Surface Surface 2776' 2577' Surface Surface 8448' 6955' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2543' NSL, 3801' WEL, SEC. 34, T12N, R11E, UM At top of productive interval 512' NSL, 522' WEL, SEC. 28, T12N, R11E, UM At total depth 873' NSL, 734'WEL, SEC. 28, T12N, R11E, UM 1 b. Type of well Number 2S100302630-277 Hole 30" 12-1/4" 8-3/4" 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD RECEIVED Perforation depth: measured AUG 2 8 2001 true vertical Alaska Oil & Gas Cons. Commission Anchorage 20. Attachments II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherriff, 564-5204 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone ~__~.~ Title Senior Drilling Engineer Permit Number API Number See cover letter 201-140 50- 029-23035-00 for other re uirements Conditions of Approval: Samples Required 0 Yes 0 No Mud Log Required 0 Yes 0 No Hydrogen Sulfide Measures 0 Yes 0 No Directional Survey Required 0 Yes 0 No Required Wor~g Pressure fOmE 9,2K ~ ~ 4K D5K D10K D15K 0 3.5K psi for CTU dIfíÎNAlM¿,àN~f~tþt ~(fttt. tty ~ by order of <t:>_Q_ /). ( J. M. ~ commission Date 0 0 U Rev. 12-01-85 Submit In Triplicate r--, .~\ bp To: Tom lIIIaunder, AOGCC Date: August 27,2001 From: AII4:!n Sherritt Subject: Surface Location chanae on Borealis L·115 Permit #201·140 Mr. Maunder, As per our conversation on 8-27-01, the following is a written notification changing the surface location of Borealis well, L-115, (Permit #201-140, API # 50-029-23035.) This change does not significantly affect the design criteria previously submitted for permitting. The BHL location, directional plan, casing and cement designs am unchanged. The move is required for optimizing the drilling and facilities construction programs. This well is scheduled to spud 10..01-01. If there is any other additional information or questions you may have, don't hesitate to call. - Allen Sherr-itt Operations Drilling Engineer 564-5204 240-8070 .~ .~ I Well Name: I L -115i Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Injector Surface Location: X = 583,115.89' Y = 5,978,078.15' As-Built 2357' FSL (2922' FNL), 3801' FEL (1478' FWL), Sec. 34, T12N, R11 E Target Location: X = 581,070' Y = 5,981,490' Top Kuparuk 512' FSL (4767' FNL), 522' FEL (4756' FWL), Sec. 28, T12N, R11 E Bottom Hole Location: X = 580,853' Y = 5,981,849' 873' FSL (4406' FNU, 734' FEL (4544' FWU, Sec. 28, T12N, R11E I Rig: I Nabors 9ES 1 Operating days to complete: 113.3 I AFE Number: 15M4027 I Estimated Start Date: 18/9/2001 I TVD: 16955' I I ~ 8448' I BF/MS: 130' I RKB: 177.0' I Well Design (conventional, slim hole, etc.): I Ultra Slim hole (Iongstring) I Objective: I Kuparuk Formation (Target zones C sands) Mud Program: 12 %"" Surface Hole 0-2776' : Initial below Permafrost interval TD Fresh Water Surface Hole Mud PH 8.5- 9.5 8.5-9.5 8.5- 9.5 8 %" Intermediate I Production Hole (2776' - 8448'): Fresh Water LSND Interval Density Tau 0 YP PV pH API HTHP (ppg) Filtrate Filtrate Upper 9.3 4-7 20-25 8-12 8.5-9.5 4-6 Interval Top of HRZ 10.8 5-8 20-25 8-14 8.5-9.5 3-5 <10 by toTD HRZ L-115i Permit to Drill Page 1 .~ ~ Directional: Ver. Sperry WP-02 KOP: 300' Maximum Hole Angle: 39.50 at 2389' MD Close Approach Wells: All wells pass major risk criteria. L-110 - 29' @ 575' MD L-116 - 61' @ 750' MD L-114 - 49' @ 650' MD L-01 - 148' @ 575' MD Intermediate/Production Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Den / Neut Open Hole: Cuttings samples Cased Hole: USIT cement evaluation Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, PPG SV5 1560 1465 SV4 1715 1610 Base Permafrost 1895 1775 SV3 2087 1950 SV2 2287 2120 SV1 2698 2440 UG4A 3087 2700 Not hydrocarbon bearina UG3 3586 3085 UG1 4266 3525 Ma 4588 3905 WS2 (N sands) 4750 4055 Not hydrocarbon bearina WS1 (0 sands) 4964 4188 Hydrocarbon bearing 1850 psi, 8.5 PPQ Obf Base 5476 4585 CM2 (Colville) 5827 4855 THRZ 7378 6025 BHRZ (Kalubik) 7632 6246 K-1 7692 6294 TKUP 7787 6368 3425 psi, 10.3 ppg TMLV (Miluveach) 8298 6781 TD Criteria 8448 6878 150' below Miluveach top L-115i Permit to Drill Page 2 /"'-, ~ c IT b- p aSlnCJ, U Ing rogram: Hole Csgl WtlFt Grade Conn Length Top Btm Size Tbg O.D. MDrrVD MDrrVD bkb 30" 20" 91.5# H-40 WLD 80' GL 110/110 12 %" 9 5/8" 40# L-80 BTC 2776' GL 2776'/2577' 8%" 7" 26# L-80 BTC-m 8448' GL 8448'/6955' Tubing 4 Y2"1I 12.6# L-80 NSCT 7788' GL 7788'/6445' I nte rit Test Point Surface Casing Shoe Testin : Depth 20' min from surface shoe Test Type LOT EMW 13.5 ppg EMW Target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casin Size 9-5/8" Surface Basis: Lead: Based on 1895' of annulus in the permafrost @ 175% excess and 239' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2134' MD 2077' TVDbkb . Total Cement Volume: Lead 315 bbl I 1769ft 1398 sks of Dowell ARTICSET Lite at 10.7 and 4.44 cf/sk. Tail 52 bbl I 292 ft 1249 sks of Dowell Premium 'G' at 15.8 and 1 .17 cf/sk. Casin Size 7" Production Longstring Basis: Lead: Based on TOC 500' above top of Schrader formation & 30% excess above shoe. Lead TOC: 4057' MD, 3566' TVDbkb Tail: NA Total Cement Volume: Lead 141 bbls I 792 ft I 331 sks of Dowell LiteCrete at 12.0 and 2.39 cf/sk. NA Tail L-115i Permit to Drill Page 3 ,~ ,~ Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 3425 psi @ 6379' TVDss - Kuparuk Sands 2787 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4000 psi (The casing and tubing will be tested to 4000 psi.) 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. L-115i Permit to Drill Page 4 /", .~ DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and I or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. 3. MU 12 %" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2776' MD I 2577' TVD. The actual surface hole TD will be +1-100' TVD below the top of the SV1 sand. 4. Run and cement the 9-5/8", 40# surface casing back to surface. A port collar or stage tool will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4" drilling assembly with MWD/GR/RES/DEN/NEU and RIH to float collar. Test the 9-5/8" casing to 4000 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for running 7" 26# longstring. POOH laying down excess 4" DP. 9. Run and cement the 7" production casing as required from TD to 500' above the Schrader Bluff. Displace the casing with seawater during cementing operations and freeze protect the 7" x 9-5/8" annulus as required. 10. RU Schlumberger and run USIT log on eline from the 7" landing collar to the 9 5/8" surface shoe. RD Schlumberger. 11. Test the casing to 4000 psi for 30 min. 12. Run the 4-1/2", 12.6#, L-80 gas lift completion assembly. Set packer and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes. 13. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 14. Freeze protect the well to -2200' and secure the well. 15. Rig down and move off. Estimated Spud Date: 8-9-2001 L-115i Permit to Drill Page 5 ~ /'""'., L-115i Hazards and Contingencies Job 1: MIRU Hazards and Contingencies )0> L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. (Confirmed per J. Copen.) As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. >- The closest surface locations are L-110 and L 114. No surface shut-in's will be required as these wells are not on production. Reference RPs .:. Operaüona/Specifics · Job 2: Drillina Surface Hole Hazards and Contingencies )0> No faults are expected to be penetrated by L-115i in the surface interval. )0> There are no close approach issues in the surface hole. All wells pass major risk criteria. The closest existing well, L-11 0, is at roughly 29' center-center at approximately 575' MD. A Gyro survey will be used to steer while drilling the surface hole · Gas hydrates were observed by the NWE1-01and NWE1-02 wells. These were encountered near the base of the Permafrost at 1795' and 1730' TVD. L-01 surface interval encountered hydrates from the base of permafrost to TD in the SV1 sand. Expect to encounter hydrates from the base of permafrost to the surface shoe setting depth. Hydrates will be treated at surface with appropriate mud products. Refer to Saroid mud recommendation. )0> Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RPs .:. Operaüona/Specifics · Job 3: Install surface Casina Hazards and Conüngencies )0> It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 9-5/8" port collar will be positioned at ±1 OOO'MD to allow a secondary circulation as required. Reference RPs .:. L-115i Permit to Drill Page 6 ~ ~ Operational Specifics · Job 7: Drillina Intermediate I Production Hole Hazards and Contingencies > L-115i will cross a fault in the base of Shcrader top of Collvile, @-5860' MD/4957' TVD. The estimated throw of the NW-SE fault is approximately 160'. The well will be -390 when crossing the fault. Loss circulation is not considered to be a risk. > KICK TOLERANCE: In the worst case scenario of 10.3 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.5 ppg at the surface casing shoe, 10.8 ppg mud in the hole, kick tolerance is 48 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 13.5 ppg. Reference RPs .:. OperaUonalSpecifics · Job 9: Case & Cement Production Hole Hazards and Contingencies > The Ugnu 4A is not expected to be oil bearing. For this reason the 7" casing will be cemented to 500' above the Schrader sand. The top of the hydrocarbon interval should be verified with LWD resistivity log. > After freeze protecting the 7" x 9-5/8" casing outer annulus with 56 bbls of dead crude, the hydrostatic pressure will be less than the formation pressure, (10.1 EMW.) Ensure a double- barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Expect trapped annulus pressure after pumping the dead crude. > This is the first injection well on L-pad. The casing design is an Ultra-Slim hole and is a divergence from the first three "Microbore" wells drilled to the Borealis target. Thorough pre-job planning meetings will help ensure success. > A cement bond log (USIT) will be run to confirm the TOC. This will be done with the rig prior to running the completion. Reference RPs .:. Operational Specifics · Job 12: Run Completion Hazards and Contingencies > No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. L-115i Permit to Drill Page 7 ~ ".........." OperaffonalSpecifics . Job 13: ND/NUlRelease RiÇl Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operational Specifics . L-115i Permit to Drill Page 8 ~ ~ Borealis L-115i: Proposed Completion TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 9-518",40 #/ft, L-BO, BTC 2776' I Plug Back Depth 8368' Cellar Elevation = ±47' RKB-M8L = ±77' 4-1/2" 'X' Landing Nipple with 3.813" seal bore. I 2200' I 4-1/2" x 1" Gas Lift Mandrels with handling pups installed. # 1 2 GAS LIFT MANDRELS MD Size I --------¡ Valve Type DV DV TBD TBD 1 " 1" I _oj 4-1/2" 12.6# L-80, Premium CDnnection Tubing 4-1/2" 'X' Landing Nipple with 3.813" seal bDre. 4-1/2" 'XN' Landing Nipple with 3.813" seal bDre and 3.725" No-Go ID. 4-1/2" WireLine Entry Guide set at +1-150' above the Kuparuk Formation 4-1/2" 'X' Landing Nipple with 3.813" seal bDre. 7"x 4-1/2" Baker '8-3' ProductiDn Packer 7",26 #/ft, L-BO, BTC-Mod 8448' Date 7-10-01 Rev By Comments JAS Proposed Completion WP2 Boreal is WELL: L-115i API NO: 50-029-????? BP Alaska Drilling & Wells ~ ~ L-115i Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates were observed in both NWE offset wells and L-01. These are expected to be encountered near the base of the Permafrost at 1800' and near the TD hole section as well. · 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. Production Hole Section: · A majority of the L-Pad development wells will have "kick tolerances" in the 25 bbl range or less. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. · The production section will be drilled with a recommended mud weight of 10.8 ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 10.3 pore pressure. Read the Shale Drilling Recommended Practice. · 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. · One fault will be crossed while drilling the Schrader/Colville interval at -5860' MD, (±.4957' TVD). Losses are not anticipated. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells NEW 1-01 and NEW 1-02 did not report H2S as being present. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE L-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 Plan L-115!Plan L Date: Date: Date: Plan: L-I 15 WPO Created By: Authorised User Checked: Reviewed: T. CB-MAG-..<;S MWD SURVEY PROGRAM Swv,*,lPlan Planned:L-1 Planned:L-1 DepÙl Fm Deplh To 17.00 500.00 REFERENCE INFORMA nON Co-ordinate (NÆ) Reference: Well Centre: Plan L·115, True North Vertical (1VD) Ref=: Temp Plan elevation 77 77.0 Section (VS) Reference: SIoI- S-F (0.00,0.00) Measurz~ufa~io~~~~ ~~:n~:=77 77.1 COMPANY DETAILS BP Amoco Calclllation Method: Minimum Curvat\lre Error System: ISCWSA Scan Method: Hi¡#! Side + Az.ìmuth El!Or Surface: Elhptical ~ Casing Wmmng Mctbod: Rilles Based VI VI WP02 WP02 500.00 8448.36 Sl. S-F Shape Circ1e(Rad.ius:300) Longitude 149" [9'JO.704W """"s 581069.9 Latitude 70'-'2I'OO.28IN TARGET DETAILS +EJ_W Northing -2008.40 5981489.97 'WELL DETAIL Eastin 583 Northing 5978077.29 +N/-, 3435.4' +EI-W 17.59 TV!) 6445.00 +-N/-S N~ Nmno IN3,3 FORMATION TOP DETAILS No. TVDPath MDPath Formation SV5 SV4 Base Permafrost SV3 SV2 SV1 UG4A UG3 UG1 CM3 (Colville Shales THRZ Kaluhik TKUP TMLV(M 1560.06 1714.81 1894.66 2087.41 2286.75 2698.44 3087.15 3585.98 4266.2 I 5613.72 7378.43 7632.38 7787.86 8298.36 1542.00 1687.00 1852.00 2027.00 2197.00 2517.00 2817.00 3202.00 3727.00 4767.00 6129.00 6325.00 6445.00 6839.00 I 2 3 4 5 6 7 8 9 10 11 12 13 14 ANNOTATIONS Annotation Start Dir 1"11 00' : 300' MD, 300'TVD Start Dir 1.5"/1 00' : 700' MD, 699.68'TVD Start Dir 2"1100' : iIl5.63' MD, 11 12.05'TVD EndDir : 1815.63'MD, 1779.8'TVD Start Dir4"/JOO': 2001.93' MD, 1950'TVD End Dir : 2389.04' MD, 2278.21' TVD Total Depth: 8448.36' MD, 6954.77' TVD MD 300.00 700.00 I I 15.63 18i5.63 2001.93 2389.04 8448.35 TVD 300.00 699.68 1112.05 1779.80 1950.00 2278.20 6954.76 No. 1 2 3 4 5 6 7 ) ) Target IN_L_ 4 All TVD depths are ssTVD plus 77' for RKBE., VSec 0.00 0.00 i3.46 63.58 267.72 343.50 546.55 3979.47 4304.09 4399.46 TFace 0.00 326.66 345.00 334.84 0.00 0.00 0.00 0.00 0.00 0.00 DLeg 0.00 0.00 1.00 1.50 2.00 0.00 4.00 0.00 0.00 0.00 SECTION DETAILS E/W 0.00 0.00 -3.61 -25.66 -129.02 -167.39 -270.20 -2008.40 -2172.76 -2221.05 NIS 0.00 0.00 13.48 58.65 234.69 300.04 475.13 3435.48 3715.41 3797.66 TVD 77.00 300.00 699.68 1112.05 1779.80 1950.00 2278.21 6445.00 6839.00 6954.77 Azi 326.66 326.66 345.00 329.58 329.58 329.58 329.58 329.58 329.58 329.58 Inc 0.00 0.00 4.00 10.00 24.00 24.00 39.48 39.48 39.48 39.48 MD 77.00 300.00 700.00 i115.63 1815.63 2001.93 2389.04 7787.86 8298.36 8448.36 Sec I 2 3 4 5 6 7 8 9 10 Size 9.62 7.00 ;luveach) CASING DETAILS Name 95/8' 7" MD TVD No. ./A- 1000 140 2800 560 420' :s ¢: 0:> 0:> ; oS ¡¡. ¡:¡ '" u t:: ~ 2 ..... 2600 200 9800 8400 7000 Vertical Section at 329.68" [1400ft/in] fMiluveach) 5600 ~ 4200 7' 2800 1400 700 Plan: L-IIS WP02 (pian L-II5IPlan L- Created B)': Authorised Uirer Checked: To, CB-MAG-SS MWD REfERENCE INFORMATION SURVEY PROGRAM Co-ordinate (NÆ) Reference: Well Centre: Plan L..[I:;, True North Deplh Fm Deplh To SurveytPIan VertÎcal (TVDJ Ref~nœ; Temp Plan elevation 77 77.0 Section (VS) Referen<:e: Slol - S-F (O.OO,O.OO) 77.00 500.00 Planncd:I..ll:; WP02 VI M~u~~~o~'t~:; ~=~:=77 77.0 500.00 8448.36 P\a!lned:L-115\VP02VI - FORMATION TOP DETAILS No. TVDPath MDPath Fonnation COMPANY DETAILS BP Amoco Calculation Method: Minimum (ÙJval\lYC Error System: ISCWSA &an Method: HI~1 Side + Azimuth Error Surfaœ: Elliptical + Casing Warning Method: Rules Based - ANNOTATIONS Date: WELL DETAILS Nmre +N/-S -<-Ei·W Northing Basting Loti'"'" Ù)ngitude 5101 PlanL-l15- 117.:;9 5978077.29 583116.14 70"2I'OO.28IN 14<r19'30,704W 50F - T ARGBT DETAILS N= TVD +N/-S '1-Fl_W Northin Easting Shape IR.k4 6445,00 3435.48 -2008.40 5981489.9' :;81069.95 Circle (Radius: 300) Reviewed: SV5 SV4 Base Perrnafrosl SV3 SV2 SVI UG4A UG3 UGI CM3 (Colville Shales THRZ Kalubik TKUP TML V (Miluveaeh) 1560.06 1714.82 1894.66 2087.41 2286.75 2698.45 3087.15 3585.99 4266.22 5613.72 7378.43 7632.38 7787.86 8298.36 1542.00 1687.00 1852.00 2027.00 2197.00 2517.00 2817.00 3202.00 3727.00 4767.00 6129.00 6325.00 6445.00 6839.00 I 2 3 4 5 6 7 8 9 10 II 12 13 14 Annotation Start Dir I '/I 00' : 300' MD, 300'TVD Start Dir 1.5'/100' : 700' MD, 699.68'TVD Start Dir 2"/100': 1115.63' MD, 1 I 12.05'TVD EndDir : 1815.63'MD,I779.8'TVD Start Dir 4'/100' : 2001.93' MD, 1950'TVD End Dir : 2389.04' MD, 2278.21' TVD Total Depth: 8448.36' MD, 6954.77' TVD MD 300.00 700.00 I I 15.63 1815.63 2001.93 2389.04 8448.35 TVD 300.00 699.68 I I 12.05 1779.80 1949.99 2278.20 6954.76 No. 1 2 3 4 5 6 7 ) Target IN_L_ 4 VSec 0.00 0.00 13.46 63.58 267.73 343.5 1 546.55 3979.47 4304.08 4399.46 TFace 0.00 326.66 345.00 334.84 0.00 0.00 0.00 0.00 0.00 0.00 DLeg 0.00 0.00 1.00 1.50 2.00 0.00 4.00 0.00 0.00 0.00 SECTION DETAILS EIW 0.00 0.00 -3.61 -25.66 -129.03 -167.40 -270.20 -2008.40 -2172.76 -2221.05 NIS 0.00 0.00 i3.48 58.65 234.69 300.04 475.13 3435.48 3715.41 3797.66 TVD 77.00 300.00 699.68 1112.05 1779.80 1950.00 2278.21 6445.00 6839.00 6954.77 Azi 326.66 326.66 345.00 329.58 329.58 329.58 329.58 329.58 329.58 329.58 Ine 0.00 0.00 4.00 10.00 24.00 24.00 39.48 39.48 39.48 39.48 MD 77.00 300.00 700.00 1 I 15.63 i815.63 2001.94 2389.05 7787.86 8298.36 8448.36 See 1 2 3 4 5 6 7 8 9 10 Size 9.62 7.00 ) All TVD depths are ssTVD plus 77' for RKBE 6000 5000 4000 3000 1000 2000 West(-)/East(+) [1000ftJin] CASING DETAILS r= MD Name 2577.00 2776.19 9518" 6954.76 8448.35 7" ~ --r---I" 000 500, 7' 400' 2000 300 c äi '" '" Ë +' ~ ~ :c- g '" 000 -2000 -3000 ~ ~ BP Amoco Anticollision Report SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There ardU'8iitè8fells in thB'~al Plan & PLANNED Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 29.10 to 8447.76 ft Scan Method: Trav Cylinder North Maximum Radius: 1041.87 ft Error Surface: + ~surveY Program for Definitive Wellpath Date: 1/10/2001 Validated: No Planned From To Survey ft ft 77.00 500.00 Planned: L-115 WP02 V1 ~~~447.76 Planned: L-115 WP02 V1 Version: 6 Toolcode Tool Name .------ ! .... j CB-GYRO-SS MWD Camera based gyro single shots MWD - Standard Casing Points Summary EX NWE#1 delete me NWE1-01ANWE1-01A V4 503.93 500.00 219.53 10.29 209.27 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01 V3 503.93 500.00 219.63 10.29 209.38 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01A VO 503.93 500.00 219.63 10.29 209.38 Pass: Major Risk EX NWE#1 NWE1-02 NWE1-02 V2 1149.19 1125.00 169.05 20.92 148.81 Pass: Major Risk PB L Pad L-01 L-01 V12 574.51 575.00 147.71 11.42 136.29 Pass: Major Risk PB L Pad L-02 Plan L-02 V1 Plan: L-O 2359.51 2300.00 81.72 66.66 21.25 Pass: Major Risk PB L Pad L-104 Plan L-104 V3 Plan: L- 648.46 650.00 281.19 13.00 268.20 Pass: Major Risk PB L Pad L-105 Plan L-105 V5 Plan: L- 698.43 700.00 236.41 14.45 221.96 Pass: Major Risk PB L Pad L-106 Plan L-106 V7 Plan: PI 821.25 825.00 250.92 16.03 234.90 Pass: Major Risk PB L Pad L-107 Plan L-107 V6 Plan: L- 474.76 475.00 176.61 10.86 165.75 Pass: Major Risk PB L Pad L-108 Plan L-108 V3 Plan: L- 797.26 800.00 220.65 14.92 205.74 Pass: Major Risk PB L Pad L-109 Plan L-109 V3 Plan: L- 599.17 600.00 75.03 12.57 62.46 Pass: Major Risk PB L Pad L-110 Plan L-110 V5 Plan: PI 574.41 575.00 29.06 12.21 16.85 Pass: Major Risk PB L Pad L-111 Plan L-111 V11 Plan: L 699.29 700.00 91.08 14.63 76.45 Pass: Major Risk PB L Pad L-112 Plan L-112 V2 Plan: L- 1657.23 1625.00 85.63 33.33 54.40 Pass: Major Risk PB L Pad L-113 Plan L-113 V3 Plan: L- 1359.99 1350.00 64.90 24.50 40.40 Pass: Major Risk PB L Pad L-114 Plan L-114 V8 Plan: PI 650.31 650.00 46.25 14.05 32.21 Pass: Major Risk PB L Pad L-116 Plan L-116 V5 Plan: PI 749.07 750.00 61.22 15.15 46.08 Pass: Major Risk PB L Pad L-117 Plan L-117 V4 Plan: L- 763.57 750.00 274.89 19.57 255.37 Pass: Major Risk PB L Pad L-118 Plan L-118 V5 Plan: L- 557.95 550.00 297.88 12.80 285.10 Pass: Major Risk , _~~_.__._...______~______-----1 Site: EX NWE#1 Well: delete me NWE1-01A Rule Assigned: Major Risk Wellpath: NWE1-01A V4 Inter-Site Error: 0.00 ft 99.99 124.99 149.99 149.99 150.00 150.00 0.33 0.07 289.51 289.51 215.57 3.34 212.22 Pass 174.99 174.99 175.00 175.00 0.42 0.08 289.50 289.50 215.64 3.87 211.77 Pass 199.99 199.99 200.00 200.00 0.50 0.10 289.49 289.49 215.74 4.44 211.30 Pass 224.99 224.99 225.00 225.00 0.56 0.13 289.46 289.46 215.85 4.93 210.92 Pass 249.99 249.99 250.00 250.00 0.61 0.16 289.42 289.42 216.03 5.43 210.60 Pass 274.99 274.99 275.00 275.00 0.67 0.18 289.35 289.35 216.27 5.92 210.35 Pass i 300.03 300.03 300.05 300.04 0.72 0.20 289.25 289.25 216.59 6.40 210.19 Pass i I 325.52 325.52 325.00 324.98 0.77 0.24 289.12 304.12 216.94 6.90 210.04 Pass I . ~_._--_.__... ~__ _____-1 Tool CB-GYRO-SS MWD SURVEY PROGRAM SurveyIPlan PIanned:L-115WP02VI Planned; L-115 WP02 VI Depth Fm Depth T, 29.10 500,00 500.00 8447,76 COMPANY DETAILS BP Amoco Calculation Melhod: Minimum Curvature Enor System: ISCWSA Scan Method: Trav Cylinder North EITOI'Surface: Elliptical';' Casing Warning Method: Rules Based ANTI-COLLISION SETTINGS Interval: 25.00 To: 8447.76 Reference: PLan: L-115 Interpolation MethodMD Depth Range From: 29.10 Maximum Range: i04i.87 Slol S·F Longitude 149°19'30.7IlW Latitude 70021'OO,290N WELL DETAILS Easting 583115,89 Northing 5978078.15 ,·E¡-W [\7.35 ~NI-S -155.90 Næœ L-115 ) ) WELLPA TH DETAILS PlanL-IIS Temp Plan eJevation77 77.00fI Origin Origin Starting +N/-S +EI-W From TVD OJ)() 0.00 29.10 LEGEND cklete me NWEI-OIA (NWEI-OIA), Major Risk NWEI-OI (NWEI-OI), Major Risk NWEI-OI (NWEi-OIA), Major Risk NWEI-02 (NWEI-02), Major Risk L-OI (L-OI), Major Risk L-02 (plan L-(2), Major Risk l-l04 (Plan L-I04), Major Risk L-I05 (plan L-105), Major Risk L-I06 (plan L-I(6), Major Risk L-to7 (Plan L-107). Major Risk L-I08 (plan L-108),Major Risk L-I09 (plan L-109), Major Risk L-II0 (plan L-IIO), Major Risk L-lll (Plan L-III), Major Risk L-l 12 (PiaD L-I 12),Major Risk L-113 (plan L-113), Major Risk L-114 (plan L-114), Major Risk L-I 16 (plan L-II6), Major Risk L-117 (pW¡ L-117), Major Risk L-118(p1anL-118),MajorRisk PIanL-ItS L-1l5 WP02 Target IN_.L._4 VSœ 0.00 0.00 13,46 6358 t67.73 ~43.51 ;46.43 3978.61 4303,13 439850 TFace 0.00 0.00 345.00 334.84 0.00 0.00 0.00 0.00 0.00 0.00 Rig: Ref. Datum: V.Section AnsI< 329.68° DLeg 0.00 0.00 1.00 1.50 2.00 0.00 4.00 0.00 0.00 0.00 - SECTION DETAILS ~NI-S +E!-W 0.00 0.00 0,00 0.00 13.48 -3.61 58.65 -25.66 234.69 -129.03 300.04 -167AO 475.03 ·270.15 3434,62 ·2008.16 3714.46 -2172.50 3796.69 -2220.79 TVD 29.10 300.00 699.68 1112.05 1779.80 1950.00 2278.07 6445.00 6839.00 6954.78 ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4500 5500 An 0.00 0.00 345.00 329.58 329.58 329.58 329.58 329.58 329.58 329.58 loc 0.00 0.00 4.00 10.00 24.00 24.00 39.48 39.48 39.48 39.48 o MD 29.10 300.00 700.00 1115.63 1815.63 2001.94 2388.87 7787.31 8297.76 8447.76 Colour o 120 Se< I 2 3 4 5 6 7 8 9 10 WP02 21 ~/ ~ . 50 -;/:;./ '110 (þ, %¿I/. OJ % /- ;;;. ~ -. ~ ~ -~ ~ -- . , , 24( 64 0 50 40 30 20 10 0 2701 10 20 30 40 Íl ... vs Centre -. 8<r 1 ,..Jing Cylinder Azimuth /""'.. /'., BP Amoco Planning Report - Geographic Prudhoe Bay North Slope UNITED STATES System:US State Plane Coordinate System 1927 Datum: NAD27 (Clarke 1866) Datum: Mean Sea Level I Site: PB L Pad l! UNITED STATES: North Slope Site Position: Northing: From: Map Easting: ~;~;~;::I:~nty:_____~J~ ~ _ Well: Plan L-115 5978232.73 ft 582996.83 ft Surface Position: +N/-S +E/-W Position Uncertainty: Reference Point: +N/-S +E/-W -156.77 ft 117.59 ft 0.00 ft -156.77 ft 117.59 ft Northing: 5978077.29 ft Easting: 583116.14 ft Measured Depth: 77.00 ft Vertical Depth: 77.00 ft Northing: Easting : 5978077.29 ft 583116.14 ft I 1____. [w;iïp;th: Plan L-115 i I Current Datum: Temp Plan elevation 77 ~MagnetiC Data: 1/10/2001 Field Strength: 57446 nT Vertical Section: Depth :rom (TVD) ____:;~~~__ 0.00 0.00 1______________________.__ _~______~____.__________ Height 77.00 ft I-pi;~~- .. L-115 WP02 I I ! Principal: Yes L_____________._________.______....___ Plan Section Information Map Zone: Coordinate System: Model: Alaska, Zone 4 Well Centre BGGM2000 Latitude: 70 21 1.823 N Longitude: 149 19 34.141 W North Reference: True Grid Convergence: 0.63 deg Slot Name: S-F Latitude: 70 21 0.281 N Longitude: 149 19 30.704 W Latitude: 70 21 0.281 N Longitude: 149 19 30.704 W Inclination: 0.00 deg Azimuth: 0.00 deg Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Above System Datum: Mean Sea Level Declination: 26.46 deg Mag Dip Angle: 80.74 deg +E/-W Direction ft deg 0.00 329.68 I I I -----~ I I I I I --.J I I Date Composed: Version: Tied-to: 1/10/2001 1 From Well Ref. Point I I I __________J 0.00 326.66 77.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 326.66 300.00 0.00 0.00 0.00 0.00 0.00 326.66 700.00 4.00 345.00 699.68 13.48 -3.61 1.00 1.00 0.00 345.00 1115.63 10.00 329.58 1112.05 58.65 -25.66 1.50 1.44 -3.71 334.84 1815.63 24.00 329.58 1779.80 234.69 -129.03 2.00 2.00 0.00 0.00 2001.94 24.00 329.58 1950.00 300.04 -167.40 0.00 0.00 0.00 0.00 2389.05 39.48 329.58 2278.21 475.13 -270.20 4.00 4.00 0.00 0.00 7787.86 39.48 329.58 6445.00 3435.48 -2008.40 0.00 0.00 0.00 0.00 IN_L_4 8298.36 39.48 329.58 6839.00 3715.41 -2172.76 0.00 0.00 0.00 0.00 8448.36 39.48 329.58 6954.77 3797.66 -2221.05 0.00 0.00 0.00 0.00 Section 1 ; Start 200.00 300.00 ~ '---... BP Amoco Planning Report - Geographic Azim deg 345.00 345.00 345.00 345.00 IP~ Page: 2 5. True North on 77 77.0 ,329.68Azi) 399.99 499.96 599.86 699.68 0.84 3.37 7.58 13.48 -0.23 -0.90 -2.03 -3.61 0.84 3.37 7.57 13.46 1.00 1.00 1.00 1.00 Turn deg/100ft 0.00 0.00 0.00 0.00 I Company: BP Amoco ~ield: Prudhoe Bay Site: PB Well: PI 15 Wellpatb: Plan L·115 Section 2: Start [ ~D~ ~~ I 400.00 1.00 I 500.00 2.00 L ~~~~~_____J:~~ Section 3: Start I ~D~~l: 'I 800.00 5.40 900.00 6.84 1000.00 8.30 '1100.00 9.77 I_~ 115.63 _1()'00_ Section 4: Start ì MD Incl Azim TVD +N/-S ¡ ft deg deg ft ft L---- ! 1200.00 11.69 329.58 1194.91 72.34 I 1300.00 13.69 329.58 1292.46 91.28 I! 1400.00 15.69 329.58 1389.19 113.14 1500.00 17.69 329.58 1484.97 137.90 1600.00 19.69 329.58 1579.70 165.53 I 1700.00 21.69 329.58 1673.25 195.99 I 1800.00 23.69 329.58 1765.50 229.25 L~8.1~.63~~~__ 329.58 _177~:~~_____~34.69 1.00 1.00 1.00 1.00 338.20 334.22 331.63 329.82 329.58 Section 5: Start Ir-- MD-----in~~----Azim ft deg deg hooo.oo 24.00 329.58 I 2001.94 24.00 329.58 , ----.------~-----._------~-~--~----------- Section 6: Start 799.34 898.77 997.90 1096.66 1112.05 TVD ft 1856.88 1950.00 21.21 30.94 42.65 56.33 58.65 -6.26 -10.59 -16.61 -24.30 -25.66 Turn deg/1000 -6.80 -3.98 -2.59 -1.82 -1.51 1.50 1.50 1.50 1.50 1.50 1.40 1.44 1.46 1.47 1.48 +N/-S ft 264.28 300.04 ,---- I MD Incl Azim TVD i ft deg deg ft 1-2100.oo-----v:-92u 329.58--2'038.15 I 2200.00 31.92 329.58 2124.80 ,2300.00 35.92 329.58 2207.76 I 2389.05 39.48 329.58 2278.21 L __._.. .~_._._ ___~____,_______.__________~___.______~__.______~~__ Section 7: Start r----mMD----- Incl -- Azim- ft deg deg 2400.00 39.48 329.58 2500.00 39.48 329.58 2600.00 39.48 329.58 2700.00 39.48 329.58 2800.00 39.48 329.58 2900.00 39.48 329.58 3000.00 39.48 329.58 3100.00 39.48 329.58 3200.00 39.48 329.58 3300.00 39.48 329.58 3400.00 39.48 329.58 3500.00 39.48 329.58 3600.00 39.48 329.58 3700.00 39.48 329.58 3800.00 39.48 329.58 I 3900.00 39.48 329.58 '----- - TVD ft 2286.66 2363.85 2441.03 2518.22 2595.40 2672.59 2749.77 2826.95 2904.14 2981.32 3058.51 3135.69 3212.88 3290.06 3367.25 3444.43 +N/-S ft 337.05 380.06 428.17 475.13 +N/-S ft 481.13 535.96 590.79 645.62 700.45 755.27 810.10 864.93 919.76 974.59 1029.42 1084.24 1139.07 1193.90 1248.73 1303.56 +E/-W ft -33.70 -44.82 -57.65 -72.19 -88.41 -106.30 -125.83 -129.03 79.45 101.42 126.77 155.48 187.52 222.85 261.41 267.73 DLS Build Turn c\egl100ft deg/100ft deg/1000 2.00 2.00 0.00 2.00 2.00 0.00 2.00 2.00 0.00 2.00 2.00 0.00 2.00 2.00 0.00 2.00 2.00 0.00 2.00 2.00 0.00 2.00 2.00 0.00 -146.41 -167.40 +E/-W ft -189.13 -214.38 -242.63 -270.20 +E/-W ft -273.73 -305.92 -338.11 -370.30 -402.50 -434.69 -466.88 -499.08 -531.27 -563.46 -595.66 -627.85 -660.04 -692.24 -724.43 -756.62 vs ft 386.43 436.30 492.10 546.55 Bund Turn deg/1000 deg/100ft 0.00 0.00 0.00 0.00 .---------------- DLS Build Turn degl100ft deg/10Oft deg/1000 4.00 4.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 VS ft 553.51 617.09 680.67 744.25 807.83 871.41 934.99 998.57 1062.15 1125.74 1189.32 1252.90 1316.48 1380.06 1443.64 1507.22 TFO deg 0.00 0.00 0.00 0.00 TFO deg -25.16 -18.38 -14.43 -11.86 -10.10 - TFO deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TFO deg 0.00 0.00 TFO deg 0.00 0.00 0.00 0.00 TFO deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~ i _.--1 Pl j ------n I l I u_____~ ~ I I I 'I ___~J u -~ I I ì I ~ ~. ..--", BP Amoco Planning Report - Geographic Section 7 : Start 4000.00 39.48 329.58 3521.62 1358.38 -788.82 1570.80 0.00 0.00 0.00 0.00 4100.00 39.48 329.58 3598.80 1413.21 -821.01 1634.38 0.00 0.00 0.00 0.00 4200.00 39.48 329.58 3675.99 1468.04 -853.20 1697.96 0.00 0.00 0.00 0.00 4300.00 39.48 329.58 3753.17 1522.87 -885.40 1761.54 0.00 0.00 0.00 0.00 4400.00 39.48 329.58 3830.35 1577.70 -917.59 1825.12 0.00 0.00 0.00 0.00 4500.00 39.48 329.58 3907.54 1632.52 -949.78 1888.70 0.00 0.00 0.00 0.00 4600.00 39.48 329.58 3984.72 1687.35 -981.98 1952.29 0.00 0.00 0.00 0.00 4700.00 39.48 329.58 4061.91 1742.18 -1014.17 2015.87 0.00 0.00 0.00 0.00 4800.00 39.48 329.58 4139.09 1797.01 -1046.36 2079.45 0.00 0.00 0.00 0.00 4900.00 39.48 329.58 4216.28 1851.84 -1078.56 2143.03 0.00 0.00 0.00 0.00 5000.00 39.48 329.58 4293.46 1906.67 -1110.75 2206.61 0.00 0.00 0.00 0.00 5100.00 39.48 329.58 4370.65 1961.49 -1142.94 2270.19 0.00 0.00 0.00 0.00 5200.00 39.48 329.58 4447.83 2016.32 -1175.14 2333.77 0.00 0.00 0.00 0.00 5300.00 39.48 329.58 4525.02 2071.15 -1207.33 2397.35 0.00 0.00 0.00 0.00 5400.00 39.48 329.58 4602.20 2125.98 -1239.52 2460.93 0.00 0.00 0.00 0.00 5500.00 39.48 329.58 4679.39 2180.81 -1271.71 2524.51 0.00 0.00 0.00 0.00 5600.00 39.48 329.58 4756.57 2235.63 -1303.91 2588.09 0.00 0.00 0.00 0.00 5700.00 39.48 329.58 4833.76 2290.46 -1336.10 2651.67 0.00 0.00 0.00 0.00 5800.00 39.48 329.58 4910.94 2345.29 -1368.29 2715.25 0.00 0.00 0.00 0.00 5900.00 39.48 329.58 4988.12 2400.12 -1400.49 2778.84 0.00 0.00 0.00 0.00 6000.00 39.48 329.58 5065.31 2454.95 -1432.68 2842.42 0.00 0.00 0.00 0.00 6100.00 39.48 329.58 5142.49 2509.78 -1464.87 2906.00 0.00 0.00 0.00 0.00 6200.00 39.48 329.58 5219.68 2564.60 -1497.07 2969.58 0.00 0.00 0.00 0.00 6300.00 39.48 329.58 5296.86 2619.43 -1529.26 3033.16 0.00 0.00 0.00 0.00 6400.00 39.48 329.58 5374.05 2674.26 -1561.45 3096.74 0.00 0.00 0.00 0.00 6500.00 39.48 329.58 5451.23 2729.09 -1593.65 3160.32 0.00 0.00 0.00 0.00 6600.00 39.48 329.58 5528.42 2783.92 -1625.84 3223.90 0.00 0.00 0.00 0.00 6700.00 39.48 329.58 5605.60 2838.74 -1658.03 3287.48 0.00 0.00 0.00 0.00 6800.00 39.48 329.58 5682.79 2893.57 -1690.23 3351.06 0.00 0.00 0.00 0.00 6900.00 39.48 329.58 5759.97 2948.40 -1722.42 3414.64 0.00 0.00 0.00 0.00 7000.00 39.48 329.58 5837.16 3003.23 -1754.61 3478.22 0.00 0.00 0.00 0.00 7100.00 39.48 329.58 5914.34 3058.06 -1786.81 3541.81 0.00 0.00 0.00 0.00 7200.00 39.48 329.58 5991.53 3112.88 -1819.00 3605.39 0.00 0.00 0.00 0.00 7300.00 39.48 329.58 6068.71 3167.71 -1851.19 3668.97 0.00 0.00 0.00 0.00 7400.00 39.48 329.58 6145.89 3222.54 -1883.39 3732.55 0.00 0.00 0.00 0.00 i 7500.00 39.48 329.58 6223.08 3277.37 -1915.58 3796.13 0.00 0.00 0.00 0.00 j 7600.00 39.48 329.58 6300.26 3332.20 -1947.77 3859.71 0.00 0.00 0.00 0.00 I I 7700.00 39.48 329.58 6377.45 3387.03 -1979.97 3923.29 0.00 0.00 0.00 0.00 I I 7787.86 39.48 329.58 6445.00 3435.48 -2008.40 3979.47 0.00 0.00 0.00 0.00 ~_l ----~._-,--_._--------_.~_._._-- Section 8 : Start 7900.00 8000.00 8100.00 8200.00 8298.36 Section 9: Start 8300.00 8400.00 8448.36 39.48 39.48 39.48 329.58 329.58 329.58 6840.27 6917.45 6954.77 3716.31 -2173.29 3771.14 -2205.48 3797.66 -2221.05 4305.13 4368.71 4399.46 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ~, BP Amoco Planning Report - Geographic .~ 77.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1115.63 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1815.63 1900.00 2001.94 2100.00 2200.00 2300.00 2389.05 2400.00 2500.00 2600.00 2700.00 2800.00 2900.00 3000.00 3100.00 3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.00 4300.00 4400.00 4500.00 4600.00 I I 4700.00 4800.00 L 4900.00 0.00 0.00 0.00 0.00 1.00 2.00 3.00 4.00 5.40 6.84 8.30 9.77 10.00 11.69 13.69 15.69 17.69 19.69 21.69 23.69 24.00 24.00 24.00 27.92 31.92 35.92 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 39.48 326.66 326.66 326.66 326.66 345.00 345.00 345.00 345.00 338.20 334.22 331.63 329.82 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 329.58 77.00 100.00 200.00 300.00 399.99 499.96 599.86 699.68 799.34 898.77 997.90 1096.66 1112.05 1194.91 1292.46 1389.19 1484.97 1579.70 1673.25 1765.50 1779.80 1856.88 1950.00 2038.15 2124.80 2207.76 2278.21 2286.66 2363.85 2441.03 2518.22 2595.40 2672.59 2749.77 2826.95 2904.14 2981.32 3058.51 3135.69 3212.88 3290.06 3367.25 3444.43 3521.62 3598.80 3675.99 3753.17 3830.35 3907.54 3984.72 4061.91 4139.09 4216.28 0.00 0.00 0.00 0.00 0.84 3.37 7.58 13.48 21.21 30.94 42.65 56.33 58.65 72.34 91.28 113.14 137.90 165.53 195.99 229.25 234.69 264.28 300.04 337.05 380.06 428.17 475.13 481.13 535.96 590.79 645.62 700.45 755.27 810.10 864.93 919.76 974.59 1029.42 1084.24 1139.07 1193.90 1248.73 1303.56 1358.38 1413.21 1468.04 1522.87 1577.70 1632.52 1687.35 0.00 0.00 0.00 0.00 -0.23 -0.90 -2.03 -3.61 -6.26 -10.59 -16.61 -24.30 -25.66 -33.70 -44.82 -57.65 -72.19 -88.41 -106.30 -125.83 -129.03 -146.41 -167.40 -189.13 -214.38 -242.63 -270.20 -273.73 -305.92 -338.11 -370.30 -402.50 -434.69 -466.88 -499.08 -531.27 -563.46 -595.66 -627.85 -660.04 -692.24 -724.43 -756.62 -788.82 -821.01 -853.20 -885.40 -917.59 -949.78 -981.98 1742.18 -1014.17 1797.01 -1046.36 1851.84 -1078.56 5978077.29 5978077.29 5978077.29 5978077.29 5978078.13 5978080.65 5978084.85 5978090.72 5978098.43 5978108.10 5978119.74 5978133.34 5978135.64 5978149.24 5978168.05 5978189.77 5978214.36 5978241.81 5978272.07 5978305.10 5978310.51 5978339.90 5978375.42 5978412.19 5978454.91 5978502.70 5978549.35 5978555.31 5978609.77 5978664.24 5978718.70 5978773.16 5978827.62 5978882.09 5978936.55 5978991.01 5979045.47 5979099.94 5979154.40 5979208.86 5979263.33 5979317.79 5979372.25 5979426.71 5979481.18 5979535.64 5979590.10 5979644.56 5979699.03 5979753.49 5979807.95 5979862.41 5979916.88 583116.14 583116.14 583116.14 583116.14 583115.90 583115.20 583114.02 583112.38 583109.65 583105.20 583099.06 583091.22 583089.83 583081.64 583070.32 583057.24 583042.43 583025.90 583007.68 582987.79 582984.53 582966.82 582945.44 582923.30 582897.57 582868.79 582840.71 582837.12 582804.32 582771.53 582738.73 582705.93 582673.14 582640.34 582607.54 582574.75 582541.95 582509.16 582476.36 582443.56 582410.77 582377.97 582345.17 582312.38 582279.58 582246.78 582213.99 582181.19 582148.40 582115.60 582082.80 582050.01 582017.21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 70 21 0.281 N 149 19 30.704 W 0.281 N 149 19 30.704 W 0.281 N 149 19 30.704 W 0.281 N 149 19 30.704 W 0.290N 14919 30.711W 0.314 N 149 19 30.731 W 0.356 N 149 19 30.764 W 0.414 N 149 19 30.810 W 0.490 N 149 19 30.887 W 0.586 N 149 19 31.014 W 0.701 N 149 19 31.190 W 0.835 N 149 19 31.414 W 0.858 N 149 19 31.454 W 0.993 N 149 19 31.689 W 1.179 N 149 19 32.014 W 1.394 N 149 19 32.389 W 1.637 N 149 19 32.814 W 1.909 N 149 19 33.288 W 2.209 N 149 19 33.811 W 2.536 N 149 19 34.382 W 2.589 N 149 19 34.475 W 2.880 N 149 19 34.983 W 3.232 N 149 19 35.597 W 3.596 N 149 19 36.232 W 4.019 N 149 19 36.970 W 4.492 N 149 19 37.795 W 4.954 N 149 19 38.601 W 5.013 N 149 19 38.704 W 5.552 N 149 19 39.645 W 6.092 N 149 19 40.586 W 6.631 N 149 19 41.527 W 7.170 N 149 19 42.468 W 7.709 N 149 19 43.409 W 8.248 N 149 19 44.350 W 8.788 N 149 19 45.291 W 9.327 N 149 19 46.232 W 9.866N 14919 47.173W 10.405N 14919 48.114W 10.944 N 149 19 49.055 W 11.484N 14919 49.996W 12.023 N 149 19 50.938 W 12.562 N 149 19 51.879 W 13.101 N 149 19 52.820 W 13.640 N 149 19 53.761 W 14.180 N 149 19 54.702 W 70 21 14.719 N 149 19 55.643 W 70 21 15.258 N 149 19 56.585 W 70 21 15.797 N 149 19 57.526 W 70 21 16.336 N 149 19 58.467 W 70 21 16.876 N 149 19 59.408 W 70 21 17.415 N 149 20 70 21 17.954 N 149 20 70 21 18.493 N 149 20 0.350 W 1.291 W 2.232 W /' /~ BP Amoco Planning Report - Geographic 5000.00 39.48 329.58 4293.46 1906.67 -1110.75 5979971.34 581984.41 70 21 19.032 N 149 20 3.173 W 5100.00 39.48 329.58 4370.65 1961.49 -1142.94 5980025.80 581951.62 70 21 19.571 N 149 20 4.115 W 5200.00 39.48 329.58 4447.83 2016.32 -1175.14 5980080.27 581918.82 70 21 20.111 N 149 20 5.056 W 5300.00 39.48 329.58 4525.02 2071.15 -1207.33 5980134.73 581886.02 70 21 20.650 N 149 20 5.997 W 5400.00 39.48 329.58 4602.20 2125.98 -1239.52 5980189.19 581853.23 70 21 21.189N 149 20 6.939 W 5500.00 39.48 329.58 4679.39 2180.81 -1271.71 5980243.65 581820.43 70 21 21.728 N 149 20 7.880 W 5600.00 39.48 329.58 4756.57 2235.63 -1303.91 5980298.12 581787.64 70 21 22.267 N 149 20 8.821 W 5700.00 39.48 329.58 4833.76 2290.46 -1336.10 5980352.58 581754.84 70 21 22.807 N 149 20 9.763 W 5800.00 39.48 329.58 4910.94 2345.29 -1368.29 5980407.04 581722.04 70 21 23.346 N 149 20 10.704 W 5900.00 39.48 329.58 4988.12 2400.12 -1400.49 5980461.50 581689.25 70 21 23.885 N 149 20 11.646 W 6000.00 39.48 329.58 5065.31 2454.95 -1432.68 5980515.97 581656.45 70 21 24.424 N 149 20 12.587 W 6100.00 39.48 329.58 5142.49 2509.78 -1464.87 5980570.43 581623.65 70 21 24.963 N 149 20 13.528 W 6200.00 39.48 329.58 5219.68 2564.60 -1497.07 5980624.89 581590.86 70 21 25.502 N 149 20 14.470 W 6300.00 39.48 329.58 5296.86 2619.43 -1529.26 5980679.35 581558.06 70 21 26.042 N 149 20 15.411 W 6400.00 39.48 329.58 5374.05 2674.26 -1561.45 5980733.82 581525.26 70 21 26.581 N 149 20 16.353 W 6500.00 39.48 329.58 5451.23 2729.09 -1593.65 5980788.28 581492.47 70 21 27.120 N 149 20 17.294 W 6600.00 39.48 329.58 5528.42 2783.92 -1625.84 5980842.74 581459.67 70 21 27.659 N 149 20 18.236 W 6700.00 39.48 329.58 5605.60 2838.74 -1658.03 5980897.21 581426.88 70 21 28.198 N 149 20 19.177 W 6800.00 39.48 329.58 5682.79 2893.57 -1690.23 5980951.67 581394.08 70 21 28.737 N 149 20 20.119 W 6900.00 39.48 329.58 5759.97 2948.40 -1722.42 5981006.13 581361.28 70 21 29.276 N 149 20 21.061 W 7000.00 39.48 329.58 5837.16 3003.23 -1754.61 5981060.59 581328.49 70 21 29.816 N 149 20 22.002 W 7100.00 39.48 329.58 5914.34 3058.06 -1786.81 5981115.06 581295.69 70 21 30.355 N 149 20 22.944 W 7200.00 39.48 329.58 5991.53 3112.88 -1819.00 5981169.52 581262.89 70 21 30.894 N 149 20 23.885 W 7300.00 39.48 329.58 6068.71 3167.71 -1851.19 5981223.98 581230.10 70 21 31.433 N 149 20 24.827 W 7400.00 39.48 329.58 6145.89 3222.54 -1883.39 5981278.44 581197.30 70 21 31.972 N 149 20 25.769 W 7500.00 39.48 329.58 6223.08 3277.37 -1915.58 5981332.91 581164.51 70 21 32.511 N 149 20 26.710 W 7600.00 39.48 329.58 6300.26 3332.20 -1947.77 5981387.37 581131.71 70 21 33.051 N 149 20 27.652 W 7700.00 39.48 329.58 6377.45 3387.03 -1979.97 5981441.83 581098.91 70 21 33.590 N 149 20 28.593 W 7787.86 39.48 329.58 6445.00 3435.48 -2008.40 5981489.96 581069.94 70 21 34.066 N 149 20 29.425 W 7800.00 39.48 329.58 6454.37 3442.14 -2012.31 5981496.58 581065.96 70 21 34.132 N 149 20 29.540 W 7900.00 39.48 329.58 6531.55 3496.96 -2044.50 5981551.04 581033.17 70 21 34.671 N 149 20 30.481 W 8000.00 39.48 329.58 6608.74 3551.79 -2076.69 5981605.50 581000.37 70 21 35.210 N 149 20 31.423 W i 8100.00 39.48 329.58 6685.92 3606.62 -2108.89 5981659.96 580967.57 70 21 35.749 N 149 20 32.365 W I I 8200.00 39.48 329.58 6763.11 3661.45 -2141.08 5981714.43 580934.78 70 21 36.288 N 149 20 33.306 W ¡ 8298.36 39.48 329.58 6839.00 3715.41 -2172.76 5981768.03 580902.51 70 21 36.819 N 149 20 34.233 W I l8~OO 39.48 329.58 6840.27 3716.31 -2173.29 5981768.92 580901.97 70 21 36.828 N 149 20 34.249 W 8400.00 39.48 329.58 6917.45 3771.14 -2205.48 5981823.38 580869.17 70 21 37.367 N 149 20 35.190 W I 8448.36 39.48 329.58 6954.77 3797.66 -2221.05 5981849.73 580853.31 70 21 37.628 N 149 20 35.646~~ Targets 6445.00 3435.48 -2008.40 5981489.97 581069.95 70 21 34.066 N 149 20 29.425 IN_L_ 4 -Circle (Radius: 300) -Plan hit target ~ ~ H 193313 DATE 07/06/01 CHECK NO. 00193313 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT 070201 CK070201 PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it to Drill 8tH Terrie Hub Sondra Ste X4628 or X4750 L..\\S; fHE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. p.o. BOX 196612 ANCHORAGE, ALASKA 99519·6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 193313 CONSOLIDATED COMMERCIAL ACCOUNT 56·389 ~ 00193313 PAY :::>,>:.:,::,:;=.:...--/..:: . . " '.. - . .:; "- - ::\":'-:'--';:".;.". :>:.-:r '." :t",; _> __ __ _ __ _ _ _ __»,._,::.: _ '::::"',._'.- .:::!':':::" OI\1E·HUNDRED 8< OOt10Q~****************"'*~!ifit***i}*********** U$ DJjjLLAR ·l~LAa~A q~L~~~Q~S .. .··Ç()~§~RV,?T Iq~~OM"I SS10N1 .. 333>WEST 7TH l\VENUE SUITE lOP ANCHORAGE AK 99501 . :X.- : DATE... 07/06/0111 AMOUNT ~10~:...···~~····1 To The ORDER Of' NOTVALlD AFTER 120 DAYS -,'-" ....:'::--..:',. " . .... ...... -,. "';.;,', ;-,'-'- :." ";' .. ............-...'.;.-........... ......... '-... .............. ....:.....-. . ..... ....'...'--.: '-.-.-': ", ," ': ,-, . '; .... .'...... . "-', .. . ..- ~...... ... ...... ......... .- .. . . -.-.- ..-.- --.- .,. ""- ,,'.','" -'--'.. .... .................................................... ..................................................................................................................... ...................---....-...................:--....................................'.: '-"-"-' ....- ---..-'.. ....'-..". .;" ......:. ., .', .... '-'_'_",0, ... . . ".,.,...~ . .. .>..... ....... ,.... ... ..... .·..··~..fl)J}/1tt· .... .:.:' . ,-MI'. . .42 . ". . ..... .', .,-.,-..,- ".. . ....,. .'. III ¡. I:i ~ ~ ¡. ~ III I: 0 l. ¡. 2 0 ~ B I:i 5 I: 0 0 B l. l. ¡. I:i III ~~_--.... ~--- - TRANSMITAL LETTER CHECK ....1ST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER L- \LS"'; WELL NAME CHECK 1 CHECK WHAT APPLIES STANDARD LETTER ADD-ONS (OPTIONS) "CLUE" DEVELOPMENT MULTI LATERAL The permit is for a new wellbore segment of existing well ---J Permit No, API No. (If api number last· two (2) Production should continue to be reported as a function of digits are between 60-69) the original API number stated above. DEVELOPMENT PILOT HOLE (PH) In accordance with 20 AAC 25.005(f), all records, data and REDRlLL logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logS acquired for well (name on permit). / EXPLORATION ANNULAR D~SAL Annular disposal has not been requested. . . (, 0 V INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . V '<- .<- <-> YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved. . . REDRILL THIS WELL DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <-> YES + SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. The. permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (ComDanv Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates ) ) c o z o -4 :E ;.0 - -4 m - z -I J: - en :Þ ;.0 m :Þ _ serv ~ wellbore seg _ann. disposal para req _ UNIT# Lf c;£ð ONIOFF SHORE (1..,) redrll _dev o exp GEOL AREA N N N. N N N N N N COMPANY Permit fee attached. . . . . . . Lease number appropriate. " Unique well name and number. . Well located in a defined pool.. . . . . . . . . . . . Well located proper distance from drilling unit boundary. Well located proper distance from other wells.. . . . Sufficient acreage available in drilling unit.. . . . . . If deviated, is wellbore plat included.. . . . . . . . . Operator only affected party.. . . . . . . . . . . . . Operator has appropriate bond in force. . . . . . . . Permit can be issued without conservation order. . . Permit can·be issued without administrative approval Can permit be approved before 15-day wait. . WELL PERMIT CHECKLIST FIELD & POOL_ ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 4roÐ ~<¡:l"'1. .. . . sig. Conductor string provided . . . . . . . . Surface casing protects all known USDWs. . . . . . CMT vol adequate to circulate on conductor & surf csg. CMT vol adequate totia-in long string to surf csg. . . . CMT will cover all known productive horizons. . . . . . Casing designs adequate for C, T, B & permafrost. . . Adequate tankage or reserve pit.. . . . . . . . . . . . . If a re-drill, has a 10-403 for abandonment been approved. Adequate wellbore separation proposed.. . . . . . . If diverter required, does it meet regulations . . . . . Drilling fluid program schematic & equip list adequate BOPEs, do they meet regulation . . . . . . BOPE press rating appropriate; test to _ Choke manifold complies w/API RP-53 (May Work will occur without operation shutdown. Is presence of H2S gas probable.. . . . 84) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. ~~ ...,.9t-TJ 33. ~ 34. ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; (B) will not contaminate freshwater; or cause drilling waste to surface; (C) will not impair mechanical integrity of the well used for disposal (0) will not damage producing formation or impair recovery from a pool; and E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ENGINEERING: UI Permit can be issued w/o hydrogen sulfide measures. Data presented on potential overpressure zones . . . Seismic analysis of shallow gas zones. . . . . . . . Seabed condition survey (if off-shore). . . . . . . . . . . . . Contact name/phone for weekly progress reports [exploratory only, GEOLOGY Commentsllnstructions: Y N Y N Y N Y N N Y COMMISSION: 8~s c>~/o ( JMI1 11/01/100) GEOLOGY: ~þ~è c:\msoffice\wordian\diana\checklist (rev. DATE APPR