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Home My WebLink About201-167Nolan 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-117 50029230390000 201167 5/30/2025 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.06.18 12:03:53 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU L-117 Isolate Colville Interval Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-167 50-029-23039-00-00 9189 Conductor Surface Intermediate Production Liner 7056 80 3084 9145 8436 20" 9-5/8" 7" 6344 28 - 108 27 - 3111 24 - 9169 28 - 108 27 - 2605 24 - 7037 8460 470 3090 5410 8436 1490 5750 7240 5930 - 8790 4-1/2" 12.6# x 3-1/2" 9.2# L80 22 - 8448 4226 - 6680 Structural 4-1/2" Baker Premier Packer 8390, 6300 5905, 8390 4209, 6300 Torin Roschinger Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY, SCHRADER BLUFF OIL, ORION Dev Area / PRUDHOE Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028239 22 - 6355 6188' - 8385' MD in IA. 37-bbls of 15.8-ppg Class G cement. Final treating pressure = 3756-psi. 2854 2003 700 650 2450 2029 322-623 13b. Pools active after work:SCHRADER BLUFF OIL, ORION Dev Area / PRUDHOE BAY, BOREALIS OIL 4-1/2" Baker S3 Packer 5905, 4209 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Kayla Junke at 3:49 pm, Apr 17, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.04.13 18:47:43 -08'00' Torin Roschinger (4662) RBDMS JSB 042023 DSR-4/17/23WCB 12-27-2023 ACTIVITY DATE SUMMARY 1/18/2023 ****WELL S/I ON ARRIVAL**** HES UNIT 759 R/U DRIFT/ TAG FILL @ 8802' SLM, SAMPLE OF THICK SCHMOO OBTAINED. T-BIRD LOAD WELL W/ 180BBLS OF DIESEL. BRUSH & FLUSH NIPPLES @ 8436' MD & 8415' MD ****CONT, WSR ON 1/19/2023**** 1/18/2023 T/I/O= 2350/450/350 (Assist Slickline) TFS U-3, Pumped 170 bbls DSL for TBG load and 10 bbls DSL for B&F. ***Job Continued on 1-19-23*** 1/19/2023 ***Job Continued from 1-18-23*** (Assist Slickline) TFS U-3, Pumped 1.2 bbls DSL to bring TBG up to Max test pressure of 3750 for MIT-T ***PASS*** Tubing lost 125 psi in 1st 15 min. and lost 35 psi in 2nd 15 min. Total pressure loss on TBG for 30 min. test was 160 psi. TBG pressure was bleed to 1700 psi. FWHP= 1700/400/300 SL still on well upon departue. 1/19/2023 ****CONT, WSR FROM 1/18/2023**** SET 3-1/2" PX PLUG BODY IN X-NIPPLE @ 8,436' MD SET P-PRONG IN PX PLUG BODY IN X-NIPPLE @ 8,436' MD TBIRD PERFORM PASSING MIT-T TO 3500# (see t-bird awgers for details) PULL P-PRONG FROM PX IN X-NIPPLE @ 8,436' MD PULL 3-1/2" PX FROM X-NIPPLE @ 8,436' MD DRIFT TO 3,100' SLM W/ 20' x 3.7" DMY WHIPSTOCK ***WELL LEFT S/I ON DEPARTURE PAD OP NOTIFIED ON WELL STATUS*** **DRIFT FOR SUBSIDENCE W/ 20' x 3.70" WHIPSTOCK TO 3,100' SLM** 2/12/2023 ***WELL FLOWING ON ARRIVAL*** PT PCE 250LP-3000HP T-BIRD LOADS TUBING WITH 152 BBLS OF DIESEL. SET NS 2.63" MAGNUM COMBOSITE BRIDGE PLUG AT 8386.5' ME(8386' TOP) CCL S/D=8376.7', CCL TO ME=9.8' CORRELATED TO TUBING TALLY DATED:10-3-2001 T-BIRD PRESSURES UP TUBING TO 2500# WITH .7 BBLS OF DIESEL FOR 5 MINS(good) ***CONTINUED ON 2-13-2023 WSR*** 2/12/2023 T/I/O=2200/850/350 Temp= SI Assis ELine as directed Pumped 153 bbls DSL down TBG to load All CV's= OTG Tag Hung Well left in Alaska ELine control 2/13/2023 ***CONTINUED FROM 2-12-2023 WSR*** PT PCE 250LP-3000HP(good) TAGGED COMPOSITE AND PUNCH HOLES FROM 8382.8' MD TO 8384.8' MD, TIED INTO TUBING TALLY DATED 10-3-2001 T-BIRD PERFORMS INJECTIVITY TEST INTO COLVILLE AND SHRADER FORMATION. 1 BPM=1479 PSI 2 BPM=1578 PSI 3 BPM=1575 PSI T-BIRD PUMPS 55 BBLS OF DIESEL TOTAL FOR INJECTIVITY TEST. TAGGED CBP AT 8386' MD AND PICKED UP 5' TO SET RETAINER ME SET DEPTH AT 8380.2' MD. TOP OF RETAINER AT 8379.3' MD. ***WELL LEFT S/I, READY FOR COIL*** Daily Report of Well Operations PBU L-117 TAGGED CBP AT 8386' MD AND PICKED UP 5' TO SET RETAINER ME SET DEPTH AT 8380.2' MD. TOP OF RETAINER AT 8379.3' MD. SET NS 2.63" MAGNUM COMBOSITE BRIDGE PLUG AT 8386.5' ME(8386' TOP) (g ) TAGGED COMPOSITE AND PUNCH HOLES FROM 8382.8' MD TO 8384.8' MD SET 3-1/2" PX PLUG BODY IN X-NIPPLE @ 8,436' MD@ SET P-PRONG IN PX PLUG BODY IN X-NIPPLE @ 8,436' MD@ TBIRD PERFORM PASSING MIT-T TO 3500# (see t-bird awgers for details)( PULL P-PRONG FROM PX IN X-NIPPLE @ 8,436' MD@ PULL 3-1/2" PX FROM X-NIPPLE @ 8,436' MD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 10, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC L-117 PRUDHOE BAY UN BORE L-117 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/10/2023 L-117 50-029-23039-00-00 201-167-0 W SPT 4209 2011670 1500 2080 2083 2081 2083 422 443 440 440 4YRTST P Austin McLeod 7/7/2023 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE L-117 Inspection Date: Tubing OA Packer Depth 132 2847 2705 2692IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230708163858 BBL Pumped:3.8 BBL Returned:2.5 Thursday, August 10, 2023 Page 1 of 1            Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 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: 06/14/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230418 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# KU 12-17 50133205770000 208089 4/19/2023 YELLOW JACKET PERF MPU C-42 50029231960000 204028 3/22/2023 YELLOW JACKET PERF MPU E-19 50029227460000 197037 4/11/2023 YELLOW JACKET SCBL-CALIPER MPU H-15 50029232840000 205159 3/8/2023 YELLOW JACKET PERF MPU L-12 50029223340000 193011 4/2/2023 YELLOW JACKET CUT PBU 01-31 50029216260000 186132 5/1/2023 YELLOW JACKET SCBL PBU L-117 50029230390000 201167 3/5/2023 YELLOW JACKET SCBL PBU V-02 50029232090000 204077 3/27/2023 YELLOW JACKET SCBL SRU 231-33 50133101630100 223008 3/31/2023 YELLOW JACKET GPT-PERF SRU 231-33 50133101630100 223008 4/14/2023 YELLOW JACKET GPT-PLUG-PERF Please include current contact information if different from above. T37746 T37747 T37748 T37749 T37750 T37751 T37752 T37753 T37754 T37754 PBU L-117 50029230390000 201167 3/5/2023 YELLOW JACKET SCBL Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.14 14:53:01 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Rixse, Melvin G (OGC) To:Brodie Wages Cc:Davies, Stephen F (OGC); Wallace, Chris D (OGC) Subject:20230307 1100 PTD201-167 PBU 322-623 L-117 CBL Log Date:Tuesday, March 7, 2023 10:57:09 AM Attachments:image007.png image008.png image010.png Brodie, AOGCC agrees that you have cement isolation of the Colville perforations. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Chris Wallace, Steve Davies From: Brodie Wages <David.Wages@hilcorp.com> Sent: Monday, March 6, 2023 3:25 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: PBU 322-623 L-117 CBL Log Hello Mel, Please see attached CBL for L-117. With TOC @ 6188’, this cement job went just about perfect. The objective of the cement job was to isolate the perforations at 6514’ – 6524’. We may have covered some of the OBd but it appears as though we have good isolation over the Coville. David “Brodie” Wages Ops Engineer C: 713.380.9836 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Stefan Reed <Stefan.Reed@hilcorp.com> Sent: Monday, March 6, 2023 5:17 AM To: Brodie Wages <David.Wages@hilcorp.com> Subject: FW: [EXTERNAL] RE: L-117 CBL Log Stefan Reed Well Site Supervisor Hilcorp Wells Group, GPB Hmy#2491 / Cell: 206-518-0400 From: Sanders Bonin <sbonin@yjosllc.com> Sent: Sunday, March 5, 2023 10:20 PM To: pbaqueiro (yjos llc) <pbaqueiro@yjosllc.com> Cc: Stefan Reed <Stefan.Reed@hilcorp.com> Subject: [EXTERNAL] RE: L-117 CBL Log Stefan, Please see the attached log revision and the interpretation for the L-117 well. Thanks Sanders Bonin Operations Supervisor Mobile.337.380.9077 Main 337.541.2690 Web.www.yjosllc.com Addr.1098 Forum Drive Broussard, LA 70518 This message contains confidential information and is intended only for the individual named. If you are not the named addressee you should not isseminate, distribute or copy this e-mail. Please notify the sender immediately by e-mail if you have received this e-mail by mistake and delete this e-mail from your system. E-mail transmission cannot be guaranteed to be secure or error-free as information could be intercepted, corrupted, lost, destroyed, arrive late or incomplete, or contain viruses. The sender therefore does not accept liability for any errors or omissions in the contents of this message, which arise as a result of e-mail transmission. If verification is required please request a hard-copy version. From: Pedro Gonzalez Baqueiro <pbaqueiro@yjosllc.com> Sent: Sunday, March 05, 2023 9:35 PM To: Sanders Bonin <sbonin@yjosllc.com> Cc: Stefan Reed - (C) <Stefan.Reed@hilcorp.com> Subject: RE: L-117 CBL Log You can send the result to Stefan Reed Stefan Reed - (C) Stefan.Reed@hilcorp.com Thank you!!! From: Pedro Gonzalez Baqueiro Sent: Sunday, March 5, 2023 5:11 PM To: Sanders Bonin <sbonin@yjosllc.com> Subject: FW: L-117 CBL Log Hi Sanders Hilcorp want a final process for this CBL job we ran in to 3.5’’ tbg and 4.5’’ tbg look the tbg tally into the docx file it will be for state of Alaska requirements, It will be MAIN 1 AND REPEAT 1 Loaded the db in to the share folder!! Thank you From: Tim Atkinson <Tim.Atkinson@hilcorp.com> Sent: Tuesday, February 28, 2023 1:39 PM To: Pedro Gonzalez Baqueiro <pbaqueiro@yjosllc.com> Subject: L-117 CBL Log Pedro, Can you run a CBL in this well ? Log CBL from ~ 8430’ to 5500’. Looking where TOC is behind the Tbg. Tbg is both 3-1/2” and 4- 1/2”. If you can do this, what size is your CBL tool ? Thanks, Tim 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. 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. 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Chmielowski Digitally signed by Jessie L. 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&KDQJHVWRDQDSSURYHGVXQGU\ZLOOEHFRPPXQLFDWHGWRWKH$2*&&E\WKHZRUNRYHU:2³ILUVWFDOO´HQJLQHHU$2*&&ZULWWHQDSSURYDORIWKHFKDQJHLVUHTXLUHGEHIRUHLPSOHPHQWLQJWKHFKDQJH6WHS3DJH'DWH 3URFHGXUH&KDQJH+163UHSDUHG%\,QLWLDOV+16$SSURYHG%\,QLWLDOV$2*&&:ULWWHQ$SSURYDO5HFHLYHG3HUVRQDQG'DWH$SSURYDO$VVHW7HDP2SHUDWLRQV0DQDJHU 'DWH3UHSDUHG)LUVW&DOO 2SHUDWLRQV (QJLQHHU 'DWH MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re �j DATE: Thursday, July 18, 2019 P.I. Supervisor � �1'I ��e.9 SUBJECT: Mechanical Integrity Tests f BP Exploration (Alaska) Inc. L -I 17 FROM: Guy Cook PRUDHOE BAY UN BORE L-117 Petroleum Inspector Sire: Inspector Reviewed By: P.I. sup" J -rP__ NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-117 API Well Number 50-029-23039-00-00 Inspector Name: Guy Cook IBSp Num: mi[GDC]90718133437 Permit Number: 201-167-0 Inspection Date: 7/18/2019 ' Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I L-117 "'Type Inj �� -TVD -coo Tubing 2127 2124 �e� - 2129 Well -I --_--..----- PTD 2011670 Type Test S1'I Test psi ISoo - IA 418 2796 —Is 3711 BBL Pumped 2.6 - BBL Returned: - OA 241 361 ss 356 Interval 4YRTST P/p r , Notes: Testing was completed with a triplex pump, calibrated gauges and a bleed trailer. Thursday, July 18, 2019 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re � DATE: Tuesday,August 25,2015 gg K4�1 P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L-117 FROM: Bob Noble PRUDHOE BAY UN BORE L-117 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J) — NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-117 API Well Number 50-029-23039-00-00 Inspector Name: Bob Noble Permit Number: 201-167-0 Inspection Date: 7/20/2015 Insp Num: mitRCN150723115746 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type J g 2011670 Type SPT psi1500 289 1800 2959 2960 Well L 117 T e In' G 'TVD b 4209 Tutn 2955 2958 PTDT e Test Test IA 1723 - 1716 - Interval 4YRTST P/F P ,/ OA 391 397 - 397 - 398 - Notes: SCANNED 1 RY , r Tuesday,August 25,2015 Page 1 of 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, July 12, 2015 1:39 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Well Pad LV;Wallace, Chris D (DOA); Regg, James B (DOA); Shrider, James Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Morrison, Spencer Subject: UNDER EVALUATION:Injector L-117 (PTD #2011670) Place on Injection for Compliance testing Attachments: image001.jpg; image002.png All, Injector L-117 (PTD#2011670) was due for its AOGCC witnessed MIT-IA in January of 2015 and is now ready to be placed on injection. At this time the well has been reclassified as Under Evaluation to facilitate compliance testing. Please use caution when bringing the well online as the annuli are fluid packed. Plan Forward: 1. Operations: Place well on injection 2. Downhole Diagnostics: Once thermally stable, perform AOGCC witnessed MIT-IA Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska -Well Integrity Coordinator same) JUL 1 3 2015 WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com m: AK, D&C Well Integrity Coordinator Sent: I- u. January 06, 2015 11:29 PM To: AK, OPS GC2 0 ' , • •PS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C ' - Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB Eas - I•t Engr; AK, OPS Well Pad LV; 'chris.wallace@alaska.gov'; Oshiro, Joleen; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Inte • ngineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R Subject: NOT OPERABLE: Injector L-117 (PTD #2011670) Due for Regulatory Co •ante Testing All, 1 WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. ¿J-o J / ¡, 7 Well History File # Digital Data Added to LaserFiche File 0 CD's - # 0 DVD's - # - 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # - 0 Mud Logs # - 0 Other # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. STATE OF ALASKA RECEIVED A. .KA OIL AND GAS CONSERVATION COMM. _ION APR 2 g 2014 • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well Li Plug Perforations U Perforate Lt.] Other ti lAC)GCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time ExtensionD Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Development El Exploratory ❑ • 201-167-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑✓ 6.API Number: Anchorage,AK 99519-6612 + 50-029-23039-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028239 . BRLS L-117 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: Total Depth measured • 9189 feet Plugs measured None feet true vertical 7055.53 feet Junk measured None feet Effective Depth measured . 9085 feet Packer measured See Attachment feet true vertical 6957.47 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 28-108 28-108 1490 470 Surface 3084 9-5/8"40#L-80 27-3111 27-2604.97 5750 3090 Intermediate None None None None None None Production 9145 7"26#L-80 24-9169 24-7036.66 7240 5410 Liner None None None None None None Perforation depth Measured depth 5930-5970 feet 6013-6040 feet 6073-6087 feet 6142-6182 feet 6242-6280 feet 6514-6524 feet 8655-8706 feet 8719-8724 feet 8775-8790 feet True Vertical depth 4225.56-4253.38 feet 4284.04-4303.63 feet 4327.86-4338.15 feet 4378.48-4407.71 feet 4451.43-4479.02 feet 4646.9-4654.01 feet 6552.03-6600.33 feet 6612.62-6617.35 feet 6665.5-6679.65 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): scANNEDUN. 1 1 2014. Treatment descriptions including volumes used and final pressure: RBDMS� Y 15 2014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1051 0 2360 Subsequent to operation: 0 0 2512 0 2191 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratori❑ Development❑ Service❑✓ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPLU GSTOR El WINJ ❑ WAGE ❑✓ GINJ ❑ SUSP ❑ SPLUGEI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.SummerhaysCa)_bp.com Printed Name Nita Summerhays Title Data Coordinator Sign a jj - -of.../AP Phone 564-4035 Date 4/28/2014 ✓Lr 5/zz-7 1- ,A f-41// Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028239 sum ° T , ', iw,w,f,,rx 3/26/2014 Road to location. Continued on 03-27-14 WSR T/I/0=1900/720/320 Freeze protect. FL w/ 10 bbls 60/40/ Freeze protect Tbg. w/3 bbls 3/27/2014 neat, 22 bbls 60/40 FWHP=2200/720/320 SV,WV,SSV shut MV,IA,OA open ***WELL S/I ON ARRIVAL***(perforating) EQUALIZED & PULLED 4.5" MCX (SER#M-26B) FROM 2,120' SLM/2,138'MD. DRIFTED W/ 10'x 2.0" DUMMY GUN, 5' x 2-1/8" STEM, TEL, 1.75" S. BAILER. (recovered 1/2 cup schmoo) LOC TT @ 8,417' SLM/8,432' ELMD (15' CORR). TAGGED STKY BTM @ 8,826'ELMD (102' OF RATHOLE) 3/27/2014 ***WELL S/I ON DEPARTURE, PAD OP NOTIFIED*** ***WELL INJECTING ON ARRIVAL*** SSV= OPEN, INITIAL T/I/O = 2200/940/325 PERFORATED 8775'-8790'WITH 2" HSD 6SPF 60 DEGREE PHASED PJ NOVA GUN. DID NOT TAG TD. DEPTH CORRECTED TO SLB JEWELRY LOG DATED 3- MAR-02. CONFIRMED ALL SHOTS FIRED. RETURNED WELL TO INJECTION AFTER PERFORATING WAS COMPLETED. HAND OVER WITH DSO PRIOR TO DEPARTURE. FINAL T/I/O = 2200/940/325. 4/6/2014 ***JOB COMPLETE*** FLUIDS PUMPED BBLS 3 DIESEL 32 60/40 METH 7 METH 42 TOTAL a) o o O o o co g„) Lo LO CY) Lo 0 0 Lo M1,-6" U y 0 0 0 0 0 0 0 L O NT LO CO CO 7 V" N N- - V m ti Ln CO CO O ti CO N LO N- CO O) V Co co N co M O N N- LO O CO N Lo N M N V V CO CO I I I I I H CO N Ln V co co co V N 06 N N N V N Lo N V C co O '- co co CO co O O CO CO V N- a- 0) co CO NI- a) O co Lo CO co co V (130) ° i . i i i*..+ C") 2 N C0 (0 NNC9N- CD Q N N N N N O) CO CO =Q X � J ~ Q CD 0 O coacoa Q p c J J J J J *k CO M O Itk M .N N Lo * N O N f/) Cfl U OCVNCN (N r s O CO -' M L LO 0O 00 N O N a0 X 0 0 0 CO CI) O M Lo J Z O m » 0 0 0 0 U O O LLZ Z_ Z Z_ Z O (Ym 000003 OCYDDDDD UdU) HHI- I- Packers and SSV's Attachment ADL0028239 SW Name Type MD TVD Depscription L-117 PACKER 5905 4131.51 4-1/2" Baker Premier Packer L-117 PACKER 8390 6223.05 4-1/2" Baker S-3 Perm Packer TREE= . 4-1/16'CNV W t' `D -117 SAL AVERAGE 125 ppm WI-ENONMI WELLREQES: H2S �ES A SSSV WHEN ON AGTUATOR= BAKER C MI„• OKB.ELEV- 77.1' I BF.ELEV= 54.8' KOP= 1000' "CONDUCTOR - 1019' 9-5/8"TAM PORT COLLAR - - Max Angle - 59"©4187' ? Datum MD= 8787' - , 2138' -14-1/2-HES X NP,ID=3.813' Datum"ND= 6600'SS ID= 9-5/8"CSG,40#,L-80 BTC,D=8.835" -{ 3111' GAS LIFT MANDREIS ST MD TVD DEV TYFE VLV LATCH FORT DATE 4 4715 3501 57 KBG-2 DIY BK 0 06/08/02 3 5845 4169 50 KBG-2 DMY BK 0 06/08/02 Minimum ID = 2.813" cc 8377' 5862' j4-1/2'12.6#X 20'PUP JT W/RA TAG 3-1/2" HES X NIPPLE 5847'BMD LOGGED ON 03/08/02 I 5892' -14-1/2"F5ES X NP,D=3.813" 6904' -J5"LH ACME X 4-1/2"NSCT XO PN,D=3.560" 2 C6906' _Ir X 4-1/2'BKR PREMIER PKR,ID=3.875" 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958' -{ 6962' 69sz {4-1i2'X 3-1l2•TBG X0,D=2.937' WATBZFLOOD MANDRILS _ ST MD TVD DEV TYPE VLV LATCH FORT DATE 2 5973 4256 45 MMG-W DMY RK 0 07/19/05 1 6354 4533 44 MMG-W DMY RK 0 01/29/07 3-1/2"TBG,9.2#,L-80 NSCT,.0087 bpf,D=2.992" --{ 6374' I-- 6374' -13-1/2"X 4-1/2'XO,D=2.992' U 4-1/2"TBG,12.6#,L-80 NSCT, -I 8366' - 8366' --14-112"X 3-1/2'X0,D=2.937' .0152 bpf,0=3.958' 8377' -13-1/2"HES X NP,ID=2.813' 3-1/2"TBG,9.2#,L-80 PLSCT,.0087 bpf,D=2.992" -{ 8389' 3-1/2"TBG,9.2#,L-80 NSCT, --4 8447' 8389' -13-1/2"X 4-112"XO,13=2.992" .0087 bpf,ID=2.992" 4 8390' .4 T'X2:4)(1-1/2"BKR 5 -3 PKR,D=3.875" PERFORATION SUTARY -' 8394' H. _73:11/2/ 112371:82m 1/2"XO,D=2.937" F LOG: SWS CDR/RESISTNITY LOG ON 09/23/01 8416' -{3 11 s- X ice,D=2.813' ANGLE AT TOP F .W: 47"@ 5930' Note:Refer to Ptoduction DB for historical pert data SIZE SW 04TB�VAL Opn/Sqz SHOT SQZ 8436' H3-1/2"HES X NP,D=2.813' 4-5/8"IP 5 5930-5970 0 10/03/01 4-5/8" r 5 6013-6040 0 10/03/01 1 4-5/8" r 5 6073-6087 0 10/03101 8' � -13-1/2"WLEG,D=2.875' 4-5/8" r 5 6142-6182 0 10/03/01 8432' --IBM)io TT LOGGED 03/08/02 4-5/8" r 5 6242-6280 0 10/03/01 8598' 7'26#X 20'PUP ST W/RA TAG 4-5/8" r 5 6514-6524 0 10/03/01 2-1/2" r 4 8655-8706 O 003/08/028587'amp LOGGED 03108102) 2-112" r 4 8719-8724 0 03/08/02 111H 8907 -7'26#X 20'PUP.IT W/RA TAG 2' r 6 8775-8790 0 04/06/14 / 8893'BMD LOGGED 03/08/02) 1�1�1� tIVIIrff1' 1...11111111..111.111 9085' -{ MID 7'CSG,26#,L-80 BTC-BTC-M,.0383 bpf, D=6.276' -I 9169' 1'1'1'1'1'1'1'1'1'1.1 DATE REV BY COMMENTS DATE REV BY COP4,U4rS BOREALIS UNIT 10/06/01 CHIKAK ORIGINAL COMPLETION 01/17/12 MB/JMD ADDED H2S SAFETY NOTE WILL: L-117 04/18/06 KSB/PJC GLV C/O 04/08/14 GW/PJC PERFORATIONS PERMIT No:'2011670 06/13/06 BSE/PJC C/O MCX VALVE @ 8435' 04/08/14 PJC FORMAT CANVAS AR No: 50-029-23039-00 01/14/07 DAV/PAG CIO WTR FLOW REG,P-15 SEC 34,T12N,R11E,2546'FSL&1493'PM_ 02/06/07 KS6/TLH GLV C/O&MCX RUB) 02/15/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) i . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 05, 2011 TO: Jim Regg 1 /¢ P.I. Supervisor i t f (// SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L -117 FROM: Bob Noble PRUDHOE BAY UN BORE L -117 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -:Ti- NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN BORE L - 117 API Well Number: 50 029 - 23039 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110101163206 Permit Number: 201 - 167 - Inspection Date: 1/1/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-117 " Type Inj. W' T\• I 4209 - IA 1 500 1 3980 - 3880 3860 P.T.D 2011670 " TypeTest SPT Test psi I 3980 . OA 260 610 540 530 Interval 4YRTST PM P ' Tubing 2700 2700 2700 2700 Notes: 4MONED FEB 0 7 2UV1 Wednesday, January 05, 2011 Page 1 of 1 Maunder, Thomas E (DOA) From: Rixse, Mel G [Mel.Rixse @bp.com) Sent: Tuesday, September 01, 2009 9:26 AM To: Maunder, Thomas E (DOA) Subject: L -117Ai Tom, I want to inform you that BP Exploration (Alaska) Inc. is expected to abandon perforations aWwWp"V the approved Sundry Number 308 -354 and will then drill L -117Ai under the approver) Drilling Permit 208 -155 by the end of January 2010. 1 do not believe anything else needs to be done. We expected to do this work last year, but because of higher than expected reservoir pressure the work was delayed. This is informative only. Thanks, Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564 -5620 - Office (907, - Hell 12/2/2009 ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 ~ ~~ ~.OC£ r ~.~~~~:~~ ~ ' ; ~ ~`? ~/ `" ..~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, ~ bp ~~~~~~~~ 0 C T 0 5 2009 ~18sk~ ~il Re Gas Con~. Gonunni~~ion Anchorage a~~~ ~~'~ ~-~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) o~P L pad an ~nnna Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion mhibitor/ sealant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L•101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6l27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-177 2071670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 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 6l26/2009 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 325 NA 31.4 5/5/2009 1-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 1-214A 2060270 50029232580100 NA 025 NA 102 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late blockin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2Q71480 50029233760000 surface NA NA L420 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6l25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 1-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 • I ~- ~ -~ , ,- ~---~ COI~SER~A ATip C 1rII~nDSS I~H John McMullen Engineering Team Leader BP Exploration Alaska Inc ~ ~ f ~~, k`, ~ ~I ~ ~ ~ PO Box 196612 ~~~' Anchorage, AK 99519-6612 Re: Prudhoe Bay FYeld, Borealis Pool, PBU U 117 Sundry Number: 308-354 Dear Mr. McMullen: SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ao~- I~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Cotnrrussion to witness any required test, contact the Commission's petroleum field inspector at (90~ 659-360? (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. moo/ Chair DATED this ~ day of October, 2008 Encl. • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ®Abandon e ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: BP Exploration (Alaska) Inc. 4. Current Well Class: ®Development . ^ Exploratory 5. Permit To Drill Number 201-167 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 ^ Service ^ Stratigraphic 6. API Number: 50-029-23039-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? ^ Yes ®No 8. Well Name and Number: PBU L-117 - 9. Property Designation: ADL 028239- 10. KB Elevation (ft): 77.1' - 11. Field /Pool(s): _ Prudhoe Bay Field /Borealis Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): 9189'- Total Depth TVD (ft): 7056'• Effective Depth MD (ft): 9085' Effective Depth TVD (ft): 6957 Plugs (measured): None Junk (measured): None i I / " 11' 2 7 Perforation Depth MD (ft): 5930' - 8724' Perforation Depth TVD (ft): 4226' -6617' Tubing Size: 41/2", 12.6# x 3-1/2", 9.2# Tubing Grade: L-80 Tubing MD (ft): 8448' Packers and SSSV Type: 7" x 4-1/2" Baker Premier packer; 7" x 4-1/2" Baker'S-3' packer Packers and SSSV MD (ft): 5905 ; 8390' 13. Attachments: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Pro ram 14. Well Class after proposed work: ^ Exploratory ®Development ^ Service 15. Estimated Date for Commencin O rations: October 15, 2008 16. Well Status after proposed work: ^ Oil ^ Gas ^ Plugged ®Abandoned 17. Verbal Approval: Date: Commission Representative: ^ WAG ^ GINJ ^ WINJ ^ WDSPL 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Mel Rixse, 564-5620 Printed Name Joh AcMu I Title Engineering Team Leader arepared By N~rialrAxr~er: Signature Phone 564-4711 Date i'Q Z~~ Terrie Hubble, 564-4628 Commission Use On Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ~OP Test ^ Mechanical Integrity Test ^ Location Clearance Other: '~ c~~ Subsequent Form Required: 1.~~~ APPROVED BY ~0 ~ 3 l X A roved B ~ COMMISSIONER THE COMMISSION Date l v Form 10-403 ROGised06/2006 4.~~ ~~ ~L Submit In Duplicate /"~~? ~~~ ~' ~JM ' ~ • To: Tom Maunder Petroleum Engineer ~~ Alaska Oil & Gas Conservation Commission From: Mel Rixse CTD Engineer Date: September 29, 2008 Re: Borealis L-117Ai Perforation Abandonment and new CTD Sidetrack Sundry Approval Request Sundry approval is requested for Borealis L-117Ai. Isolation of the existing Kuparuk C sand perforations (8724' -8655' ELMD) with a cement plug followed by a new coil tubing drilling sidetrack is proposed. The Orion perforations will remain unaltered. The CTD side track will target the Kuparuk C3 reservoir sands to the north. A slotted/solid liner is planned for completion in the new CTD lateral. HISTORY: L-117 was drilled as an injector in September to October, 2001. The well has serviced as produced water injector for the Schrader Bluff (Orion) interval, and a WAG injector for the Kuparuk (Borealis) interval. The Schrader Bluff zone is currently isolated and not being injected, due to shut-in wells in the pattern. L-117 has a 7" longstring casing (to TD). The well has 4.5" tubing down to the Schrader, then 3.5" tubing below that, to accommodate the water flow regulator (WFR) mandrels used for injection control in the Schrader. During 2005 and 2006, a great deal of step-rate testing and injection profile logging was done in this well to better understand the flow splits among the Schrader Bluff intervals. The Kuparuk was isolated by tubing plug during these logging periods. L-117 went on Kuparuk-only MI injection in January, 2007 through February, 2008. The Schrader was isolated during this time, via dummy valves in the WFR mandrels and remains so. REASON FOR SUNDRY AND SIDETRACK: To drill a sidetrack north of parent wellbore to increase exposure to Kuparuk C3 reservoir and improve recovery in producers L-118 to east and L-101 to south. NOTE: Because this well is already an injector, we will utilize the existing cement bond log for L-117. The CTD sidetrack will exit the existing casing in the Kuparuk C sand and remain in the reservoir over the entire lateral length. Pre-Rig Work: 1. O PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi 2. O MIT-OA to 2000 psi 3. O MIT-IA to 4000 psi 4. O PPPOT-T 5. 6. O S Bullhead tubing with schmoo removal treatment. Perform SBHP survey. ~ ~~ v ~ o ~ 7. S ~ ~~ ~ , , Run PDS calliper log from 8800' to surface. 8. C Set and squeeze cement abandonment plug across Kuparuk C sand perforations 9. O MIT -Tubing to 3000 psi 10. S Drift tubing/ tag top of cement plug 11. O Function test LDS. 12. O Bleed production flow lines and GL lines down to zero and blind flange 13. O Remove wellhouse, level pad, drill mouse hole. Co,Sb~l~ ~~~ t~f,~ • Rig Sidetrack Operations: (Sch~ed to begin on December 15, 2008) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high z. ivnu ~.uu poor Hole ana ramp rot i casing exit 3. Mill 2.80" window from cement ramp. 4. Drill build/turn section with 3" bicenter bit, and land well. 5. Drill lateral section to 12,400' MD w/ resistivity log. 6. Run SLB open hole density-neutron-calliper-gamma ray log (if hole conditions allow) 7. Run 2-3/8" slotted liner from TD to ~9055'MD. 8. Run 2-3/8" solid liner from 9055' to 8434' MD. 9. Set liner top packer, test to 2000 psi. 10. Freeze protect well from 2500' with diesel. 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 12. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. c .%~~~ Mel Rixse CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble = d-1H6 O]N UiEAD ~ _ CiUATOR._.__ lcs~ aev = - FMC _..- - - --- .._ _. ----- n-1. BF. ELE11= 54.0' KOP~ 1000' Max An = 58 ®4282' Datum MD = 878T DatunTVD = 6000' 3S L-117 ~ s.ss• cso. 4os, L-e0. D= B.~• H 3111' r N~ti~rlum ID = 2813' ~ 887T 3.4I?' HES X NIPPLE 4112' 92.Bi X 20' PUPJT W RA TAO 5862' EiMD RA TA6 LOGCi®05108l02 SM7' 49x2' TBG, 92.88, ~-eo, .olst~f. D=S.asa• ss6z' ~4.911't9iMXN8! D=5.873' I S• LH AC.MEX 4-9R' NBCf XO, D = 5.580' r x a.~rr sro ~aav ace ~o: s am r-r`-~. I--, 6374' I PERFORATION SUMIMRY REF LOCI: 59MS CDRIRE51SfNftY 1OC30N 08/23/09 ANCILEATTOPPERF: 48 ®5830' Nate: Refer to Ptrod~atiai D8 fa h'eitorinl pert data E ffi NTERVAI 0117E 4-'Sl8' S 5030-5870 0 08/9SA4 4.518' S 8093-8040 O 08/151D4 4.518" S 8073-8087 O 08115104 4518' z 69az-6982 0 081151D4 4.518' S 6242 - ~ O Oifl 5104 4518' S 8514 - 6521 O 0811 SA4 b1/2• 4 8865- 87~ O 03A0A2 2~f12' 4 8718-8724 0 038M102 ~ r 2es x 20' PUP Jt W RI- rAt: I'i SS96' ~ E~MO RA TAO; LOOOi®OSIOBID2 8587' r 2W X 20' PUP JT W RA TAO 8181' Bl4D RA TAO LO01080 OSASl02 889:1' _ 9Ar9~r9rlnorts: ours 8 sTA1r9 a4r2 ARB 3-712" X t-1/2" MtiaW 1, MYwdf Alit WATtRPL000 MAND11ds (OMY 40R9RM} 3-1/1" CNROMETtO 3 cue i icr ~uwtum s MD TVD OE1f TYPE VlV LATCM PORT DI1TE 4 5 479 s045 5424 4002 u KBQ>2 K8Ci2 DIIr BK DMY Bu 0 o 0810W2 of1WIQz MD TVD TrPE vw uTai PDRr out7E 1 OMi4 4178 44'!A 46 44 MMO~ M 0991' C84Y RK RK 0 0 OBM5104 01/28907 ~ 6374' f-{s•1rr x 4.9rr rea xq D a 2.u2• ~ 83Bi' 4-1/2' TBQ 12.88, 48D, D= 5.988• 8387' 4912' X 3.9R' 780 XO, D = 2A3r 8377' HS-t7!•FI~XNIP,D=2.e93' I 8388 1112' X4.9/2• TBti XO; D = 2J182' 8380' 1 T X 4~ 1R' 8KR SS PKR D = 9.876' XNP D=2.895' 6432' aMD Tr t.cx;ta®a~r9E142 TE REI/ Br 10!08101 K88fPJC V 08ft YAI. TV091~ OORIOXrT10Ni 09/94107 D1IVIPYI t 5104 IC18fKAK ALLNJVIVNXXN K881TU9 V i l 0819 P' tWiF ODRRBC'tDNB MCX VAIY 80R6M.Bt tJtiNf 9N0.1: 4997 PEltltBf Ne: 2099674 AR Na: 5402-250W 00 Y ti4, Ri 9Q 2848' NBt, i 5786' ~ (A~kM . ~ Borealis L-117Ai -Coiled Tubii~rilling r ~,,,~ WELLHEAD= - AI;RIATIDR = 8. ELCi/ = FAC _-_ --- 77.1' BF. ELEV = SI.B' KOP = 1000' Mcc Anna = 58 ®4282' Datu m MD = 8787' DatumND= 8600'SS Minimum ID = 2.813" ~ 837T 3-1/2" HES X NIPPLE L-117Ai Proposed CTD Sidetrack 4.1/2' TBCi, 12.81, L-80, .0152 t+p1, ID = 3.958' 5967 !/1F1FTY NOTEB: alA'! ~ BTA 81 i 82 ARE 3-1r!" X 1-112" MM6W 9, WFNdi ARE WATERFLOOD MANDRELi (OMY 10/8101 ~ 3-112" CHROMETBO "173a" -1aln-ntsxnr, u=~.uia' GAS LFT AAANDRELS ST AAD ND DEV TYPE VLV LATCH PORT DOTE 4 4715 3424 57 KBG2 DRAY BK 0 08108102 3 5845 4092 48 I(BG2 DAAY 9K 0 08108ID2 5892' 4-111' HES X NIP, 10 = 3.813' tNlTt~liLOOO M1NOAiB! MO NO DE1/ TYPE VLV LATCH PORT DATE 2 1 5975 8354 4179 4455 45 44 MMC-Ylt MMO-W DRAY DMY RK RK 0 0 08/15104 0128107 8475' -{31r!'HESXNIP,ID=2.819' Bt7r KB Lner Top Paeker 8428' ~~, Top f _3.~^" sto[tatl I~nar 2 70" D = 2.992' cement for crnent I ELMD RA TAG LGGG®03/08/02 I 8655' KICK OFF PONT 2-319' L-~ solid liner w! Swell Poker 9055' 2-3/8" L-80 slotted liner - Low ar Segment -~ 12400' DATE REV 9Y COMAABYTS DATE REV BY COAAMBNTS 10106101 CWKAK ORIGINAL COMPLETION 04/18108 KS8IPJC GLV CIO 03A8AJ2 TMNRLH ADO PERFS i RA TAG ELAN D8/13/08 BSEIPJC CIO MCX VALVE ®8435' 041081D3 DRS/rP NDIMD ODRRECfKJNS D1/14I07 OAVIP/1 CJO WiR FLOW R~3, P15 06/15104 KSBlKAK NSTALL NJ VLV N XXN 02/D8A7 KS9/TLH GLV CIO i AACX KILLED 08MSA4 GRC/TLP PERFCORRBCTKxVS 08/17108 MSE PRDPOS®CTD LATERAL 08x14105 TWIPJC MCJ(VALVESET 227A5 BORB/1LI3 WR WELL: L-117Ai P9>511fi No: AR No: 50.029.23099.01 12N, R118 2548 NSL i 3788' Wa d E~Ieretlon (AlNkel September 29, 2008 02/16/2007 Schlumberger NO. 4146 Schlumberger-OCS 2525 Gambell St, Suite 400 Anchorage AK 99503~2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Borealis Orion Well Job# log Description Date BL Color CD L-117 11626466 IPROF/WFL 01/18/07 1 S-124 11485868 CH EDIT US IT PDC-GR) 11/08106 1 Z-103 40011520 OH EDIT MWDILWD 02118/05 2 1 Z-103 PB1 40011520 OH EDIT MWDILWD 02106/05 2 1 L-212 PB2 40011670 OH EDIT MWD/LWD {REVISED DATA 04/06/05 2 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Petrotechnical Data Center LR2-1 900 E Benson Blvd Anchorage AK 99508-4254 Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage, AK 99503-2838 A TTN: Belh Date Delivered Received by . ~FEB 2020Q1 u;:r c- {)61 --, ~ ':J- --- 6 MEMORANDUM . . State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 'r::J q¿;. / P.I. Supervisor ì <\ e r1 J , ( -, ...., I( \ I:t () / DATE: Wednesday, January 17,2007 SlIBJECT: Mechanical Integrity Tests BP EXPLOR/\TION (ALASKA) INC L·117 PRUDHOE BA Y UN BORE L·117 QO I - I IP7 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv f:BZ- Comm Well Name: PRUDHOE BAY UN BORE L-I 17 API Well Number 50-029-23039-00-00 Inspector Name: John Crisp Insp Num: mitJCr070 117074422 Permit Number: 201-167-0 Inspection Date: 1/8/2007 Rei Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~-~--"---'---~--"- -- --'-,- ,-.-..._- .------- Well L-117 ¡Type Inj. , w TVD 4209 IA 1120 ! 4000 3920 3910 , --"----_f__ _.-- ---~--_.. --~.__.~-_. .--,------------~-;--._-----,--._--~- P.T. 2011670 TypeTest . SPT ¡ Test psi 1500 OA 325 370 380 380 __L... ..- ' ---- .-- -----~'-------- . , Interval REQVAR P/F P ,/ Tubing 2250 2250 2250 2250 -- --_.._----~_._. Notes 3.6 bbl's pumped for test. 2007 5CANNED JAN 2 5 NON-CONFIDENTIAL Wednesday, January 17,2007 Page 1 of 1 MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg Re'4Q 1f zS'/O (.;, P.I. Supervisor ( DATE: Wednesday, July 19,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L-1I7 PRUDHOE BAY UN BORE L-117 ~b\- \~1 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: -g¡-. P.I. Suprv \ JC-- Comm Well Name: PRUDHOE BAY UN BORE L-117 API Well Number 50-029-23039-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060714063 120 Permit Number: 201-167-0 Inspection Date: 7/13/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L-ll7 !Type Inj. i W I TVD ! 5905 I IA 1140 I 2000 I 2000 2000 ! I I P.T. 2011670 !TypeTest i SPT I Test psi i 1500 ! OA ! 400 420 i 420 420 Tubing ! i I 2600 I 2550 2550 2550 Interval 4YRTST PIF P ! , I Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. NON-CONFIDENTIAL -, (~' ,C'·, Wednesday, July 19,2006 Page I of I . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marker.doc ') ) ¿po I - /01 ids C!\L~I" WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC Atten: Robin Deason 333 W. 7th Street Suite # 100 Anchorage, Alaska 99501 RE : Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Bur'ton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska], Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 WELL DATE LOG TYPE Electronic Data Images 1 BLUE LINE PRINT(S] REPORT OR COLOR Open Hole 1 L-117 10-17-04 Res. Eva!. CH 1 1 . ... .~ I ~ í "- - ¡\ P n'l ,. '7 n 0 ¡- SC;i·\I>t4H,EL} H n, J. tj L_U .J Signed: --/ ¡; I / ..(1 é/){dh, ! - W~~- Print Name: ¡'JÞ--AJ(\:7~ /Cbrl11(Á III Date: ~6~ ',-, PI{u^uivl DiAlINU~,k Su{Vill~, INC., PO Bux I ~69 S'Affultd lX 77477 Phonc:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Wcbsitc: \V\\'w.mcmorylog.COlll ) ) AT¡ASKA. OIL AND GAS CONSERVATION COMMISSION aOI-I'1 FRANK H. MURKOWSKI. GOVERNOR ~~!Æ~'E ::} !Æ~!Æ~~!Æ 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bruce Smith Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-117 Sundry Number: 304-405 Dear Mr. Smith: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been request. . ~1! 'K. NO~ Chairman BY ORDER OF T.H,j.£OMMISSION DATED this~ day of November, 2004 Encl. - ¿ ~ ')Onr! CA.' t..i..!À.'. E"!.~..\ 1\\0\1 I '- t. ...h S -, J~'''I » !'U.. ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Development D Exploratory D Stratigraphic D Service Œ] / 9. Well Name and Nu~r: L-117 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9085 6880.4 MD TVD ~.. 1. Type of Request: Abandon D Alter Casing D Change Approved Program D 2. Operator Name: Suspend D RepairWell D Pull Tubing D BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 77.10 KB 8. Property Designation: ADL-0028239 11. Total Depth MD (ft): 9189 Casing Total Depth TVD (ft): 7055.5 Length Conductor 80 Production 9145 Surface 3084 Perforation Depth MD (ft): 5930 - 5970 6013 - 6040 6073 - 6087 6142 - 6182 6242 - 6280 6514 - 6524 8655 - 8706 8719 - 8724 Packers and SSSV Type: 4-1/2" Baker Premier Packer 4-1/2" Baker S-3 Perm Packer 12. Attachments: Description Summary of Proposal D Size 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 4225.56 4253.4 4284.04 4303.6 4327.86 4338.2 4378.48 4407.7 4451.43 4479.0 4646.9 4654.0 6552.03 6600.3 6612.62 6617.4 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: November 16, 2004 Date: 2004 Operation Shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Perforate D waiver~.:t:t£¡[rt~üfãr Disposal D StimulateD Time ExtensionD OtherŒ] Re-enter Suspended WellD Convert to WAG Inj 5. Permit to Drill Number: 201-1670 ,/ 6. API Number / 50-029-23039-00-00 Plugs (md): Junk (md): None None Burst Collapse top bottom top bottom 28 108 28.0 108.0 1490 470 24 9169 24.0 7036.7 7240 5410 27 3111 27.0 2605.0 5750 3090 Tubing Size: Tubing Grade: Tubing MD (ft): 3.5 " 9.3 # L-80 5963 6375 3.5 " 9.3 # L-80 8366 8448 4.5 " 12.6 # L-80 22 5963 4.5 " 12.6 # L-80 6375 8366 S GANNED f\OV 1 {) ?nn!l Packers and SSSV MD (ft): 5905 8390 13. Well Class after proposed work: ExploratoryD DevelopmentD Service ŒI 15. Well Status after proposed work: Oil D GasD PluggedD AbandonedD WAG [!] GINJD WINJD WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Bruce Smith ~. fj /) J . . "':>,Ji.. ~~ -v . ~~..~" Contact Bruce Smith Title Phone Petroleum Engineer 564-5093 11/2104 Commission Use Only Sundry Number: .3 [)l{ -l/o5" BOP TestD Conditions of approval: Notify Commission so that a representative may witness Location Clearance D Form 10-403 Revised 06/2004 Mechanciallntegrity Test D RBDMS BFL NOV 1 6 2DD4 BY ORDER OF ,,/,'" ~c.£ THE COMMISSION Date: II¡ I ~ / () I SUBMIT IN DUPLICATE ~ . -~) '1Ii"-fJ'J. TREE = 4-1/16" CJN WELLI-EAD = FMC ÄCfÙATOR ~"- ^ì<Ef'"ËlBïu.;;umum m .7rfi BF. ELEV = 54.8' ~^~~~-~-^^=^^^^^ KOP = 1000' - -- Max Angle = 59 @ 4282' 'tfatÙrí1"rvfö' .;;...m..".."""m".'Ë~787ï (5atum"'i\To";;.""",,....m66õ'iVS's 9-5/8" CSG, 40#, L-80, 10 = 8.835" H 3111' Minimum ID = 2.813" @ 8377' 3-1/2" HES X NIPPLE I 4-1/2" 12.6#X20'PUPJTW/RA TAG H 5862' I ELM) RA TAG LOGGID 03/08/02 H 5847 4-1/2" lBG, 12.6#, L-BO, .0152 bpf, D = 3.958" H 5962' 3-1/2" TBG, 9.2#, L-BO, .0087 bpf, 10 = 2.992" H 6374' PERFORATION SUtvMARY REF LOG: SWS CDR/RESISTtJ \TY LOG ON 09/23/01 ANGLEA TTOPPERF: 46 @ 5930' f\bte: Refer to A'oduction OB for historical perf data SIZE SPF INfERV AL Opn/Sqz DA TE 4-5/8" 5 5930 - 5970 0 06/15/04 4-5/8" 5 6013 - 6040 0 06/15/04 4-5/8" 5 6073 - 6087 0 06/15/04 4-5/8" 5 6142 -6182 0 06/15/04 4-5/8" 5 6242 - 6280 0 06/15/04 4-5/8" 5 6514 - 6524 0 06/15/04 2-1/2" 4 8655- 8706 0 03/08/02 2-1/2" 4 8719- 8724 0 03/08/02 I 3-1/2" lEG, 9.2#, 13-CR, .0087 bpf, 10 = 2.992" H 8447 I 7"26#X20'PUPJTW/RA TAG H I ELM) RA TAG LOGGID 03/08/02 H I 7"26#X20'PUPJTW/RA TAG H I ELM) RA TAG LOGGID 03/08/02 H 1 PBTO H 8598' 8587 8902' 8893' 9085' I 7" CSG, 26#, L-BO, D = 6.276" H 9169' L-117 ) SAFETY NOTES: GLM'S @ STA #1 & #2 ARE 3-1/2" X 1-1/2" MMG-W'S, WHICH ARE WATERFLOOD MANDRELS (DMY 10/6/01) 3-1/2" CHROM E TBG ~ 1019' 1--1 9-5/8" TAM PORf COLLAR 1 1 2138' H 4-1/2" HES X NIP, 10 = 3.813" I ~ ~ 5892' 5904' 5905' 5963' OA TE REV BY COMrÆNfS 06/15104 KSB/KAK INSTALL INJVLV INXXN 06/15104 GRC/fLP PERF CORRECllONS DAlE 10106101 10/01/0 1 10/29/0 1 03108/02 06108/02 04108/03 RBI BY COM\Aß\JTS CIi'KAK ORIGINAL COMPLErION BSlKAK FIELO CORRECTION OAC/KK MANOREL CORRECllONS TrvT-J/Uh AOO ÆRFS & RA TAG ELM) RUth GLV LPOATE ORS/TP TVO/tJ[) CORRECfIONS GAS LFT MA.NORELS ST MO TVO OBI TYPE VL V LATCH PORf OA TE L - 4 4715 3424 57 KBG-2 O\AY BK-5 0 06/08/02 3 5845 4092 49 KBG-2 O\AY BK-5 0 06/08/02 MO TVO 2 5973 4179 1 6354 4455 ** ST 2 FLOW SLV ~ ** ST 1 P-15 WTR ROW REG lJ "i 6374' 1-1 3-1/2" X4-1/2"TBG XO, D =2.992" 1 8366' U 4-1/2" 1BG, 12.6#, L-80, 10 = 3.958" I 8367 H 4-1/2" X3-1/2"TBG XO, D =2.937" I 8377 H 3-1/2" HES X NIP, 10 = 2.813" 1 8389' H 8390' U 8394' H 8415' H 8436' 8436' 8448' 8432' h z I ~ ~ I 1: I .... L ;' .... ~ v 1 CI I ~ H 4-1/2" HES X NIP, 10 = 3.813" 1 U 5" LH ACrÆ X 4-1/2" NSCf XO, 10 = 3.560" 1 U T' X4-1/2" BKR PREMERPKR, 10=3.875" 1 H 4-1/2" X3-1/2"TBG XO, D =2.937" 1 WA lERFL 00 0 MANDRELS OEV TYÆ VLV LATCH PORT OAlE 45 I\ifv1G-W "" RKP 0 06/15/04 44 I\ifv1G-W "" RKP 22 06/15/04 3-1/2" X4-1/2"TBG XO, D =2.992" 1 Till X 4-1 /2" BKR S-3 A<R, 10 = 3.875" 1 4-1/2" X3-1/2"TBG XO, D =2.937" I 3-1/2" HESX NIP, 10 =2.813" I 3-1/2" HESX NIP, 10 =2.813" I - 4-1/2" MCX RAPPER INJ VL V I H 3-1/2" WLEG, 10 = 2.875" 1 H ELM) TT LOGGEO 03108/02 1 SCANNED NOV 1 6 2004 BOREALIS UNrr WELL: L-117 PERMT f\b: 2011670 API f\b: 50-029-23039-00 SEC34, T12N, R11E, 2546' NSL & 3786'WEL BP Exploration (Alaska) 1. Operations Performed: Abandon D Alter Casing 0 Change Approved Program 0 2. Operator Name: 3. Address: r--, ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS kEZCi IVcEQle Inj Repair Well 0 Pull TubingO Operation Shutdown 0 PluQ PerforationsD Perforate New Pool 0 Perforate 0 Stimulate D WaiverD Time E~~n!J3 2004 Re-enter Suspended Well 0 Alð4.~~tgNilP~O~QP:~ìon ExploratoryD 201-16MChorane 6. API Number 50-029-23039~~ BP Exploration (Alaska), Inc. 4. Current Well Class: Development 0 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 77.10 8. Property Designation: ADL-028239 11. Present Well Condition Summary: Total Depth measured 9189 feet true vertical 7055.5 feet Effective Depth measured 9085 feet true vertical 6957.5 feet Casing Conductor Production Surface Length 80 9145 3084 Perforation deDth: Stratigraphic 0 9. Well Name and Number: L-117 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool ServiceŒ Plugs (measured) Junk (measured) None None Size 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 MD TVD 28 108 28.0 - 108.0 24 - 9169 24.0 - 7036.7 27 - 3111 27.0 - 2605.0 Burst 1490 7240 5750 Collapse 470 5410 3090 Measured depth: 5930 - 5970,6013 - 6040,6073 - 6087,6142 - 6182,6242 - 6280,6514 - 6524,8655 - 8706,8719 - 8724 True vertical depth: 4225.56 - 4253.38, 4284.04 - 4303.63, 4327.86 - 4338.15, 4378.48 - 4407.71, 4451.43 - 4479.02, 4646.9 - 4654.01 6552.03 - 6600.33,6612.62 - 6617.35 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 Packers & SSSV (type & measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: ¡RBDMS BFL SEP ~ j ReDresentative Dailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure o -15750 810 o -2995 425 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations. 4-1/2" Baker Premier Packer 4-1/2" Baker S-3 Perm Packer @ 22 @ 5963 @ 6375 @ 8366 @ @ 5905 8390 5963 6375 8366 8448 ')11,' I, Oil-Bbl o o Tubing Pressure 1885 2226 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD WAG 0 GINJD WINJ[! WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 304-106 Contact Printed Name Garry Catron Garry Catron ßao Signature Form 10-404 Revised 4/2004 DevelopmentD Service ŒJ Title Production Technical Assistant ~ Phone 564-4657 Date 9/20/04 OR ¡: 1 \! 1\ \ ,-<,. í i ~ ~ ~- ~ ~ L-117 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/15/04 Change out waterflood mandrel stations 1,2: Set flowsleeve in station 1, memory gauge in station 2. 06/16/04 *** JOB CONTINUED FROM 6-15-04 *** (DfT & GAS LIFT). RIH WI 31/2" Ea. PRONG TO 8409' SlM.. PULLED 31/2" XX PLUG @ 8409' SLM.. TAGGED T.T @ 8422' SLM +10' CORA. TO 8432' ELM. T.D @ 8925' ELM. 201' RAT HOLE.. SET 31/2" MCX 2.75 WI .50 BEAN (SEA. #339) @ 8,408' SLM.. ***CALLED DSO AND HE WilL BRING WELL BACK ON INJECTION AT FULL OPEN CHOKE*** 06/17/04 Start Commingled injection. FLUIDS PUMPED BBLS : TOTAL No Fluids Pumped 0 Page 1 r", TREE = 4-1/16" aw WEi.U-EAD = FMC ACruATOR = KB. ELEV = 77.1' BF. ELEV = 54.8' KOP= 1000' Max Angle = 59 @ 4282' Datum MD = 8787' Datum TVD = 6600' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" Minimum ID = 2.813" @ 8377' 3-1/2" HES X NIPPLE 4-112' 12.6#X20'PUPJTW/RA TAG I Ei.rvD RA TAG LOGGED 03/08/02 H 5862' 5847 4-112' TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 3-1/2" TBG, 9,2#, L-80, .0087 bpf, ID = 2.992" 6374' 0 0 3-1/2" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992' 8447' I 7" 26#X20'PUPJTW/RA TAG H I Ei.rvD RA TAG LOGGED 03/08/02 H I 7"26#X20'PUPJTW/RA TAG H I Ei.rvD RA TAG LOGGED 03/08/02 H 8598' 8587 8902' 8893' 9085' 7" CSG, 26#, L-80, D = 6.276" 9169' ~ L-117 SÞFETY NOTES: GLM'S @ STA#1 & #2 ARE 3-1/2" X 1-1/2" MMG-WS, VllHICH ARE WATERFLOOD MANDRELS (DMY 10/6101) -i 9-5/8" TAM PORI" OOLLAR I 4-1/2" I-ESX NP, ID =3.813" GAS LFT fl.¥.f\DRELS ST MD TVD DEV TYPE VLV LATOI PORI" DATE 4 4715 3424 57 KBG-2 ~Y BK-5 0 06/08/02 3 5845 4092 49 KBG-2 ~Y BK-5 0 06/08/02 5963' 4-1/2" I-ESX NP,ID =3.813" 5" LH ACM: X 4-1/2" NSGr XO,ID = 3.560" 7' X 4-1/2" BKR PREWIER PKR, ID = 3.875" 4-1/2" X3-1/2"TBG XO, D =2.937" WA TERFLOOD MANDRELS DEV TYÆ VLV LATCH PORT DATE 45 rvtJIG-W" RKP 0 06115/04 44 rvtJIG-W .. RKP 22 06115/04 ST MD TVD 2 5973 4179 1 6354 4455 * ST 2 FLOW SLV ** ST 1 P-15 WTR FLOI/V REG bl\5/o~ 8389' 8390' 8394' 8415' 8436' 8436' 8448' 8432' Oð. TE REV BY COrvtJlENTS DATE REV BY COMWENTS 10106101 CWKAK ORIGINAL COM PLErION 06/15/04 KSB/KA K INSTALLINJVLV INXXN 10101,Q1 BSiKAK FIEi.D OORRB::TION 10129,Q1 DAC/KK MANDREL CORRB::1l0NS 03l08,Q2 TWN/Uh Am ÆRFS & RA TAG Ei.rvD 06l08,Q2 RUth GLV UPDATE 04l08,Q3 DRS/TP TVD/rvD OORREGrIONS 3-1/2" X4-1/2"TBG XO, D =2,992" 4-1/2" TBG, 12.6#, L-80, ID = 3.958" 4-1/2" X3-1/2"TBG XO, D =2.937" 3-1/2" I-ESX NP, ID =2.813" 3-1/2" X 4-1/2" TBG XO, D = 2.992" 7'" X 4-1/2" BKR 5-3 A<R. ID= 3.875" 3-1/2" I-ESX NP, ID =2.813" 3-1/2" I-ESX NP, ID =2,813" 4-1/2' MCX FLAPPER INJ VLV 3-1/2" WLEG, ID = 2.875" H Ei.rvD IT LOGGED 03l08,Q2 I BOREALIS UNrr WELL: L-117 PERWIT f'.b: 2011670 API f'.b: 50-029-23039-00 SEC 34, T12N, R11E, 2546' NSL & 3786' WEi. BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 lI--fl71, "'P"-"-"", 07i 1-/, I f- '" 1. Type of Request: D Suspend D Operation Shutdown D Abandon PerforateD waiverD Annular Disposal 0 Alter CasinQ 0 RepairWeli 0 PluQ Perforations D StimulateD Time Extension 0 OtherŒ) Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 Commingle Injection 2. Operator Name: 4. Current Well Class: BP Exploration (Alaska), Inc. Development D Exploratory 0 5. Permit to Drill Nuf!)ber: 201-1670 ,/' P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 77.10 KB 8. Property Designation: ADL-0028239 11. Total Depth MD (ft): 9189 Casing StratigraphicD Service ŒJ 9. Well Name and Number: L-117 / 10. Field/Pool(s): Prudhoe Bay Field / Borealis Oil Pool PRESENT WELL CONDITION SUMMARY I Total Depth TVD (ft): IEffective Depth MD (ft): IEffective Depth TVD (ft): 7055.5 9085 6880.4 Length Size MD TVD 6. API Number / 50-029-23039-00-00 3. Address: Plugs (md): None Burst Junk (md): None Collapse Conductor 80 Production 9145 Surface 3084 Perforation Depth MD (ft): I 8655 - 8706 8719 - 8724 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 Perforation Depth TVD (ft): 6552 6600.3 6613 6617.4 top bottom top bottom 28 108 28.0 108.0 1490 470 24 9169 24.0 7036.7 7240 5410 27 3111 27.0 2605.0 5750 3090 Tubing Size: Tubing Grade: Tubing MD (ft): 3.5" 9.3 # L-80 5963 6375 3.5" 9.3 # L-80 8366 8448 4.5 " 12.6 # L-80 22 5963 4.5 " 12.6 # L-80 6375 8366 Packers and SSSV MD (ft): 5905 8390 Packers and SSSV Type: 4-1/2" Baker Premier Packer 4-1/2" Baker S-3 Perm Packer 12. Attachments: Description Summary of Proposal D 13. Well Class after proposed work: Detailed Operations Program 00 BOP Sketch D ExploratoryD DevelopmentD Serviceoo ,./ Date: 15. Well Status after proposed work: Oil 0 GasO WAG D GINJD PluggedO AbandonedO WINJŒ / WDSPLD Prepared by Garry Catron 564-4657. 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. April 20, 2004 Contact Bruce Smith Printed Name Signature Bruce Smith ~ ).u ;L)J Title Phone Petroleum Engineer 564-5093 4/5/04 Commission Use Only I Sundry 3õií. /ð ¿, Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test 0 Location Clearance D Form 1 0-403 Revised 12/2003 Ie? - '-/-04- (/ "-t1R \ G\ NAL R8DMS Sf L ~E.CE.\\IrO 1)0 .... \\ -m?~RDER Ç>F ~ - THE COMMrðJmON Date: 1~/ðf Other: þ". , ,;" -....-"";; h"~' APR8' 288~ SUBMIT IN DUPLICATE L-117i Program Note: Possible Simops with onQoinQ construction and driliinQ. 1- 2. 3. 4. 5. Rig up slickline. Drift and tag to TD with well on injection. SI well, set an X plug in the TT to isolate the open Kuparuk interval. /' ~""-- Perform MIT-T to confirm tubing / plug integrity. If there is a leak, locate ans;trépair Pull dummys from injection mandrels at 5973' md and 6354' md. ~- Install a 90-day memory pressure/temperature gauge in the top injection mandrel at 5973'md. Program gauge to take data at 20 sec. intervals for 5 days then 1 data point per minute for the duration. Memorv QaUQe should be confiQured to measure pressure in the 7"cSQ x 3.5" tubinQ annulus. Install a flow sleeve (full open) in the bottom injection mandrel at 6354' md. Do not / run a check valve in the flow sleeve. Using the produced water injection system, choke, flow meter and WHP gauge, perform the following breakdown and Step Rate Test (SRT): i. Open well to injection, and over - 5 minutes open to FOe. Allow to flow at FOe for - 5 minutes to breakdown formation. Return well to minimum choke. ii. Begin the SRT by opening the choke at about 200 psi increments at 3 minute steps until the choke is either full open or 8000 bwpd, whichever comes first. The size of the step increments is not critical. The time /' between steps and not adjusting the choke between steps is critical. Record surface rate, pressure and time at the beginning and end of each step. Record all information in the WSR. iii. SI water injection for 30 minutes for PFOT. Shut in as Quickly as possible. RIH and pull the flow sleeve. RIH with a 1.5" Schlumberger P-15 Waterflood Flow Regulator ported for maximum injection rate, and set in the Injection Mandrel #1 at 6354' md. / Pull the TT plug. RIH with 3.5" MCX valve with a 1/2" bean, and set in the X nipple @8436' md. Return well to injection at full open choke. RDMO. 6. 7. 8. 9. 10. 11. 12. Note: If at all possible, perform all the above steps in one slickline rigup to minimize injection downtime into the Kuparuk. -" bp .,. ,"f."'. .-;.,~ ~#.... ~..- a'7' '*~ ~~.. ~"I'.~'\. ". Memorandum To: J. SmarVD. Cismoski Date: April 5, 2004 GPB Well Ops Team Leaders PECT: BRLPDWL 17-C From: Taylor West 1 Bruce Smith CAP SUST_GL GPB Satellite Production Engineers DESIGN lOR ~ Subject: L-117i ComminQled Kup./ SB Injection Est. Cost: ~ooo 11. Is I Install memo Gauge, injection valve work, SRT Current Status: Current Rate: Max. Deviation: Deviation at Inj. Mandrels: Minimum ID: Last Tag: Last Downhole OP: Latest H2S Value: on PW injection into the Kuparuk formation ~ -1000 bwpd @ 2200 psi 59 deg @ 4282' md 44 deg 2.813" @ 8377' md X-Nipple 8928' md - 4/14/03 - 4/14/03 - WL tag. NIA - offsets <10ppm L-117 is currently a Borealis (Kuparuk formation) injector that is configured to allow commingled / Kuparuk/Schrader Bluff injection. The purpose of this program is to open the straddled Schrader Bluff interval to injection and acquire information on the intervals' injectivity via a memory gauge and a step rate test. Injection into this well will support production from new Multi-lateral L-200. Approximately 2 weeks after the Schrader interval is opened, an IPROF will be run to confirm that the./ waterflood flow regulator is working as designed. Taylor West Bruce Smith cc: w/a: Well File Taylor West Bruce Smith 564-4647 564-5093 242-2310 (weekend only) 440-8008 337-2028 345-2948 " .. TREE = 4-1/16" CIW WELLHEAD = FMC ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TV D = 77.1' 54.8' 1000' 59@ 4282' 8787' 6600'SS L-117 / - - =---1 I 1019' 2138' 9-518" CSG, 40#, L-80, ID = 8.835" 1-1 3111' r- Minimum ID = 2,813" @ 8377' 3-1/2" HES X NIPPLE I 4-1/2" 12.6# X 20' PUPJT W/ RA TAG H 5862' . I ELMD RA TAG LOGGED 03/08/02 H 5847' 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf,ID= 3.958" 1-1 5962' 1 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" H 6374' PERFORA1l0N SUMMARY REF LOG: SWS CDRlRESISllVITY LOG ON 09123/01 ANGLE AT TOP PERF: 46 @ 5930' Note: Refer to Production DB for historical perfdata SIZE SPF INlERVAL OpnlSqz DATE 4-5/8" 5 5930 - 5970 C 10/03/01 4-5/8" 5 6013 - 6040 C 10/03/01 4-5/8" 5 6073 - 6087 C 10/03/01 4-5/8" 5 6142 -6182 C 10/03/01 4-5/8" 5 6242 - 6280 C 10/03/01 4-5/8" 5 6514 - 6524 C 10/03/01 2-1/2" 4 8655 - 8706 0 03/08/02 2-1/2" 4 8719 - 8724 0 03/08/02 3-1/2" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" H 8447' I 7"26#X20'PUPJTW/RA TAG 1-1 I ELMD RA TAG LOGGED 03/08/02 1-1 I 7"26#X20'PUPJTW/RATAG 1-1 I ELMD RA TAG LOGGED 03/08/02 1-1 1 PBTD H 8598' 8587' 8902' 8893' 9085' 17" CSG, 26#, L-80, ID = 6.276" 1-1 9169' DATE 10/06/01 10/01/01 10/29/01 03/08/02 06/08/02 04/08/03 REV BY COMMENTS CHiKAK ORIGINAL COMPLETION BS/KA K FIELD CORRECTK:>N DACIKK MANDREL CORRECTK:>NS TMNltlh ADD ÆRFS & RA TAG ELMD RL/tlh GLV UPDA TE DRSfTP TV DIMD CORRECTIONS DATE SAFETY NOTES: GLM'S@STA#1 &#2 ARE 3-1/2" X 1-1/2" MMG-WS, WHICH ARE WATERFLOOD MANDRELS (DMY 10/6101) H 9-5/8" TAM PORT COLLAR I 1-1 4-1/2" HES X NIP, Ð = 3.813" I GAS LIFT MANDRELS ST MD TVD DEV lYÆ VLV LATCH PORT DATE L - 4 4715 3424 57 KBG-2 DMY BK-5 0 06/08/02 3 5845 4092 49 KBG-2 DMY BK-5 0 06/08/02 8 1 ~ ~ 5892' 5904' 5905' H 4-112" HESX NIP, Ð = 3.813" 1 1-1 5" LH ACMEX 4-1/2" NSCTXO, ID = 3.560" 1 L.J 7"X4-112"BKRPREMIERPKR,ID=3.875" 1 ~" JJ----, 5963' 1-14-1/2"X3-1/2"TBGXO,ID=2.937" n -- . WA TERFLOOD MANDRELS ST ~ TVD DEV lYÆ VLV LATCH PORT DATE ~ 2 ~4 4179 45 MMG-W RKED RKP 0 10/06/01 I 1 Ô 54 4455 44 MMG-W RKED RKP 0 10/06/01 ~ , 6374' H 3-1/2"X4-1/2"TBGXO,ID=2.992" I U 8366' " "'- I 8367' 1 8377' ~ N 8389' 8390' 1 8394' I 8415' 1 8436' I 7 , I 8448' 1-" I 8432' ~¡ I ~ REV BY COMMENTS IJ H 4-1/2" X 3-1/2" TBG XO, ID = 2.937" H 3-112" HES X NIP, D = 2.813" I H IJ 1-1 H H 1-1 l-i 4-1/2"TBG, 12.6#, L-80, ID=3.958" 1 I 3-1/2" X 4-1/2" TBG XO, ID = 2.992" 1 7"" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 4-1/2" X 3-1/2" TBG XO, ID = 2.937" 1 3-1/2" HESX NIP, D = 2.813" I 3-1/2" HES X NIP, D = 2.813" 1 3-1/2" WLEG, ID = 2.875" 1 ELMD TT LOGGED 03/08/02 I BOREALIS UNIT WELL: L-117 ÆRMrr No: 2011670 API No: 50-029-23039-00 SEC 34, T12N, R11E, 2546' NSL & 3786' WEL BP Exploration (Alaska) Permit to Drill 2011670 MD 9189 ,.-- No REQUIRED INFORMATION to fV 1 if ~Ö t) !. DATA SUBMITTAL COMPLIANCE REPORT 10/22/2003 Well Name/No. PRUDHOE BAY UN BORE L-117 Operator BP EXPLORATION (ALASKA) INC TVD 7056 ,- Completion Date 10/6/2001 ..-- Completion Status Mud Log No Samples No WAGIN r Current Status WAGIN Sp~J 16 1ii~) API No. 50-029-23039-00-00 UIC Y ----"--- Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Electr Digital Dataset ed/Frmt Number I~' ~~ I~ f;: /D ~ I V ~ ~ æD C ~16 lAiM14 ---- - __I Name Log Log Run Scale Media No FINAL . dional Survey ~nisotrOpy Processing çJwo.~~r- ELAN Global Solver >c.h.."è.u' 2 DSI Anisotropy Processing Kl4.f~ v.,k- '."..'.'.'.'.'. Temperature Log I t:I\J[ )10~)1 ~Ie Sonic Imager 2/5 MD Resistivity ---- 2/5 Best DT 5 ~R DMRP Processing 2 Combinable Magnetic .tr.. ¥ÅØO12/5 ~sonance Mechanical Properties !)d-¡.t..J w 2 ELAN Global Solver l{tIfClt"v.k MD Den I Neu .....--- 2 2/5 Directional Survey / TVD Den / Neli --- 2/5 Mechanical Properties 1{ f/¡f/CJY,,",'--2 TVD Resistivity ~ 2/5 FINAL FINAL FINAL FINAL FINAL 1-3 FINAL FINAL FINAL FINAL 1 FINAL 1-3 FINAL 1-3 FINAL 1-3 1 (data taken from Logs Portion of Master Well Data Maint) Interval Start Stop 4900 6750 3900 4660 8350 9150 0 9073 3106 9126 100 9189 2990 9150 3990 9010 3106 9012 .--~ OHI CH Received Comments Open 10/15/2001 Directional Survey Paper Copy Case 10/30/2001 4900-6750 Color Print Case 10/30/2001 3900-4660 Color Print Case 10/30/2001 8350-9150 Color print Open 10/16/2001 0-9073 BL, Sepia Case 10/30/2001 3106-9126 BL, Sepia Case 10/30/2001 100-9189 BL, Sepia Case 10/30/2001 2990-9150 Color Print Case 10/26/2001 3990-9010 Color Print Case 10/30/2001 3106-9012 BL, Sepia 3900 4650 Case 10/30/2001 102 9189 Open 6540 6880 Case 1 0/30/2001 100 9189 Case 10/30/2001 Open 10/15/2001 100 9189 Case 10/30/2001 6550 7050 Case 10/30/2001 100 9189 Case 10/30/2001 3000 9156 Open .-'. 3900-4650 Color Print 6540-6880 Color print 100-9189 BL, Sepia Directional Survey Digital Data 100-9189 BL, Sepia 6550-7050 Color Print 100-9189 BL, Sepia DATA SUBMITTAL COMPLIANCE REPORT 10/22/2003 Permit to Drill 2011670 Well Name/No. PRUDHOE BAY UN BORE L-117 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23039-00-00 MD 9189 TVD 7056 Completion Date 10/6/2001 Completion Status WAGIN Current Status WAGIN UIC Y Well Cores/Samples Information: S\I¿~~eli ~~ Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION ~ ~ Well Cored? c!)~ ò..'-~~{)f.I\~ Chips Received? Y I&) ;~ Daily History Received? 0N (]/N .--- Formation Tops Analysis Received? ---~-------- Comments: v M , I" H ð.-- I" 1- y? ~t.I ) (ì-v.y 0 ""-- ....d\" '----. =ccc' .'.' . e.. \31- "HJ- ""O\') \ ~J,. ~~k, 1 0 !J, v' Â. ù-<'J3, . ~~: Compliance Reviewed By: -IL ----. (' ( 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 - 2733' FNL, 3786' FEL, Sec. 34, T12N, R11 E, UM At top of productive interval 3178' FNL, 3387' FEL, Sec. 27, T12N, R11E, UM At effective depth 3067'FNL,3295'FEL,Sec.27,T12N, R11E, UM At total depth 3041' FNL, 3272' FEL, Sec. 27, T12N, R11E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Length 102' 3084' Size 20" Surface 9-5/8" Production 9144' 7" Perforation depth: Prior to well operation Shut-In Stimulate - Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service X (asp's 583128, 5978267) (asp's 583464, 5983106) (asp's 583555, 5983218) (asp's 583577, 5983245) 9189 feet 7056 feet Plugs (measured) 9085 feet 6957 feet Junk (measured) Plugging - Perforate - Repair well - Other _X 6. Datum elevation (DF or KB feet) RKB 77 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number L-117 9. Permit number / approval number 201-167/302-181 10. API number 50-029-23039-00 11. Field / Pool Prudhoe Bay Field / - .. ~<l1 \ I U- f"'\. ~\. L. \"., L ~ V L tl JUL - fiOO2 \) t... Alaska on & Gas Gons, Commjsß~Qr' Anchoraoe Cemented Measured Depth 260 sx Arctic Set (Approx 129' 491 sx AS Lite, 425 sx Class 'G' 420 sx LiteCrete Subsequent to operation 06/28/2002 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations Oil Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. kJ~ ~ J ~ Title: Technical Assistan1 DeWavne R. Schnorf measured Open Perfs 5930'-5970',6013'-6040',6073'-6087', 6142'-6182', 6242'-6280', 6514'-6524', 8655'-8706', 8719'.8724' true vertical Open Perfs 4226'-4253',4284'-4304',4328'-4338', 4378'-4408', 4451'-4479', 4647'-4654', 6552'-6600',6613'-6617' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 5962'.4-1/2" XO 3-1/2" TBG @ 5962'.3-1/2" 9.2# L-80 TBG @ 6374' 3-1/2" XO 4-1/2" TBG @ 6374'.4-1/2" 12.6# L-80 TBG @ 8366'.4-1/2" XO 3-1/2"TBG @ 8366'. 3-1/2" 9.2# L-80 TBG @ 8389'.3-1/2" XO 4-1/2" TBG @ 8389'.4-1/2" 12.6# L-80 TBG @ 8394. 4-1/2" XO 3-1/2" TBG @ 8394'. 3-1/2" 9.2# L-80 TBG @ 8448'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 5905' MD. 7" x 4-1/2" Baker S-3 Packer @ 8390' MD. 4-1/2" HES 'X' Nipple @ 2138'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Recresentative Dailv Average Production or Injection Data Oil-Bbl Gas-Mct Water-Bbl Form 10-404 Rev 06/15/88 . True Vertical Depth 129' 2605' 3111' 9169' 7037' Casinç¡ Pressure Tubinç¡ Pressure 798 1810 16. Status of well classification as: Suspended Service WAG Injector Date Julv 02.2002 Prepared bv DeWavne R. Schnorr 564.5174 SUBMIT IN DUPLICATE ~ 06/08/2002 06/09/2002 06/09/2002 06/1 012002 06/13/2002 06/08/02 06/09/02 06/09/02 06/10102 06/13/02 ( f \ L-117 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FRACTURING: DRIFTjTAG; GAS LIFT--TO DUMMY VALVES; STATIC BOTTOM HOLE PRESSURE SURVEY; BRUSH / BROACH; HOT OIL TREATMENT FRACTURING: GAS LIFT--TO DUMMY VALVES; HOT OIL TREATMENT; MIT- IA FRACTURING: FRACTURING STARTED WATER INJECITON ANN-COMM (UIC PROGRAM): AC-MITIA EVENT SUMMARY ( WELL SHUT IN ON ARRIVAL) TAG TO @ 89571 CORR TO ELM. RAN SBHPS WI DUAL MRrs. PULL 111 SIO GLV STA 3 - PULL 111 LGLV STA 4 - SET DGLV STA 4. LOAD IA WITH 105 BBLS OF DIESEL. RAN INTO PARAFFIN PROBLEMS AFTER PUMPING DOWN fA. BRUSHED & FLUSHED TBG WITH 70 BBLS OF 190* F 01 ESEL. COMPLETED HOT DIESEL CLEAN UP OF TUBING, SET A DGLV (BK) IN GLM # 3. PUMPED 3 BBLS OF DIESEL TO MITIIA TO 4000 PSI. PASSED TEST. BLEED IA DOWN TO 1000 PSI. PULLED CATCHER SUB - WELL LEFT SHUT IN. «< NOTIFY DSO OF WELL STATUS »>. MIRU DOWELL FRAC EQUIPMENT. PT TREATING IRON TO 8200 PSI. SET TREE-SAVER. LRS PRESSURED IA TO 3400 PSI. PUMP HPBD PER PROCEDURE. STROKED OUT TREE SAVER --- LOST HALF OF THE BOTTOM RUBBER. TURNED WELL OVER TO PAD OPERATOR TO PUT WELL ON WATER INJECTION. STARTED WATER INJECTION. MIT-IA PASSED TO 2280 PSI (AOGCC Witnessed). FLUIDS PUMPED BBLS 1 PRESSURE TEST LUBRICATOR WI 1 BBL OF DIESEL, (1 TESTS) 187 DIESEL 61 GELLED DIESEL 1694 SLICK FRESH WATER (W/2% EQUIVALENT KCL ---> L-64). ROCK SALT (2100# TOTAL) 16x20 CARBOLITE (6034# TOTAL) 1943 TOTAL Page 1 (" 1REE = 4-1/16" CrN WELLHEAD = FWC ACnJA TOR = KB. 8...BI = 77.1' BF. 8...EV = 54.8' KOP= 1000' tv'ax Angle = 59 @ 4282' D3tum ~ = D3tum lV D = 8800' SS tð-5/8" CSG, 40#, L-80, ID = 8.835' 3111' Minimum ID = 2.813" @ 8377' 3-1/2" HES X NIPPLE 4-1/2" 12.6#X20'PUPJTW/RA TAG I 8...tvD RA TAG LOGGED 03/08/02 H 5862' 584T 4-1/2"ll3G, 12.6#, L-80, .0152 bpf, D =3.958" 5962' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 6374' PERFORA TlON SlJv1rv\A. RY RB= LOG: SWS COR/RESISTIVITY LOG of 09/23/01 ANGLE AT TOP PERF: 46 @ 5930' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTER\! AL Opn/Sqz DATE 4-5/8" 5 5930 - 5970 C 10/03/01 4-518" 5 6013 - 6040 C 10/03/01 4-5/8" 5 6073 - 6087 C 10/03/01 4-5/8" 5 6142 -6182 C 10/03/01 4-5/8" 5 6242 - 6280 C 10/03/01 4-5/8" 5 6514 - 6524 C 10/03/01 2-1/2" 4 8655 - 8706 0 03/08/02 2-1/2" 4 8719 - 8724 0 03/08/02 3-1/2" 113G, 9.2#, 13-CR, .0087 bpf, ID = 2.992" 8447' 7" 26#X 20' PUPJTW/ RA TAG ELMD RA TAG LOGGED 03/08/02 8598' 8587' 8902' 8893' 9085' 7" 26#X 20' PUPJTW/ RA TAG I 8...tvD RA TAG LOGGED 03/08/02 H 7" CSG, 26#, L-80, D = 6.276" 9169' L-117 ST tvD 2 5973 1 6354 1019' 2138' ("' SAFETY NOTES: GLM'S @ ST A #1 & #2 ARE 3- 1/2"X 1-1/2" MMG-WS, WHCHARE WATERFLOODMANæa.S (DMY 10/6101) 9-518" TA M PORT COLLAR 4-1/2" I-ES X NP, ID = 3.813" GAS LIFT MANDRELS ND DBI TYPE V LV LATCH 3424 57 KBG-2 D'v1Y BK-5 4092 49 KBG-2 D'v1Y BK-5 WA TERR.-Ooo rv\A.f\ÐRELS ND DBI TYPE VLV LATCH 4179 45 Mrvx3-W RKED RKP 4455 44 Mrvx3-W RKED RKP 5892' 5904' 5905' 5963' 6374' 8366' 8367' 8377' 8389' 8390' 8394' 8415' 8436' 8448' 8432' DAlE RBI BY C 0 tv'M 13\1 TS DATE REV BY COMrvENTS 10/06/01 CI-VKAK ORlGINA.L COMPLETON 1 % 1/0 1 BSIKAK FI8...D CORRECTION 10/29/01 DAC/KK MANDREL CORRECTIONS 03/08/02 Trl/N/tih ADD ÆRFS & RA TAG 8...tvD 06/08/02 RUth GLV LPDATE PORT DAlE 0 06l08¡{)2 0 06l08¡{)2 PORT DAlE 0 1 0/06¡{) 1 0 1 0/06¡{) 1 4-1/2" HES X NP, ID = 3.813" 5' LHAOV1EX 4-112" NSCT XC, ID = 3.560" 7" X 4-1/2" BKR PREMER PKR, 10 = 3.875" 4-1/2" X3-1/2"TBGXO, ID= 2.937" 3-1/2" X 4-1/2" TBG XC, ID = 2.992" 4-112" 113G, 12.6#, L-80, D = 3.958" 4-1/2" X 3-1/2"TBG XO, ID= 2.937" 3-1/2" HES X NP, ID= 2.813" 3-1/2" X4-1/2"TBGXO, ID= 2.992" Till X 4-1/2" BKR S-3 A<R, ID = 3.875" --i 4-1/2" X3-1/2"TBGXO, ID= 2.937" I -i 3-1/2"HESXNP,ID=2.813" I 3-1/2" HES X NP, ID= 2.813" 3-1/2" WLEG, ID= 2.875" 8...MD TT LOGGED 03/08/02 GPB BOREALIS WELL: L-117 PERMT t-b: 201-1670 AA No: 50-029-23039-00 2546' NSL & 3786' WEL, SEC 34, T12N, R11 E BP Exploration (Alas ka) {' MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 TaYlof\ý~ Chairman ~ f\ ~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~\(cl «{ ~ \11 BPX P.L Supervisor {)dY' L Pad ~( )C~ PBU FROM: Chuck Scheve . :P Borealis Petroleum Inspector NON- CONFIDENTIAL DATE: June 13, 2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well L-111 Type Inj. S T.v.D. 4015 Tubing 1550 1550 1550 1550 Interval I P.T.D. 202-030 Type test P Test psi 1004 Casing 1350 2480 2480 2480 P/F P Notes: Well L-115 Type Inj. S TV.D. 3860 Tubing 1600 1600 1600 1600 Interval I P.T.D. 201-140 Type test P Test psi 965 Casing 1640 2480 2460 2460 P/F P Notes: Well L-117 Type Inj. S TV.D. 4209 Tubing 1600 1600 1600 1600 Interval I P.T.D. 201-167 Type test P Test psi 1052 Casing 680 2280 2160 2160 P/F P Notes: Well Type Inj. T.V.D. Tubing Interval P.TD. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G=GASINJ. S = SALTWATER INJ. N = NOT INJECTING 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-III ,L-115and L-117. 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.LT's performed: ~ Attachments: Number of Failures: Q Total Time during tests: 3 hours cc: MIT report form 5/12/00 LG. MIT PBU L Pad 6-13-02 CS1.xls 6/20/2002 Ú?/7/DL kiG;A- ~ D7:S APPLICATION FOR SUNDRY APPROVALS ( ( . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 9189 feet 7056 feet 9085 feet Junk (measured) 6957 feet Alaska Oil & Gas Cons. GommtSSiOf Cemented Measured Depth AnchoraOfiue vertical Depth 260 sx ArcticSet (Approx) 129' 129' 491 sx AS Lite, 425 sx Class 'G' 420 sx LiteCrete measured Open Perfs 5930'-5970',6013'-6040',6073'-6087', 6142'-6182', 6242'-6280', 6514'-6524' 8655'-8706',8719'-8724' true vertical Open Perfs 4226'-4253',4284'-4304',4328'-4338', 4378'-4408', 4451'-4479', 4647'-4654', 6552'-6600',6613'-6617' 4-1/2" 12.6# L-80 TBG @ 5962'.4-1/2" XO 3-1/2" TBG @ 5962'.3-1/2" 9.2# L-80 TBG @ 6374'. 3-1/2" XO 4-1/2" tbg @ 6374'. 4-1/2" 12.6# L-80 TBG @ 8366'. 4-1/2" XO 3-1/2" TBG @ 8366'. 3-1/2" 9.2# L-80 TBG @ 8389'.3-1/2" XO 4-1/2" TBG @ 8389'.4-1/2" 12.6# L-80 TBG @ 8394. 4-1/2" XO 3-1/2" TBG @ 8394'. 3-1/2" 9.2# L-80 TBG @ 8448'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 5905' MD. 7" x 4-1/2" Baker S-3 Packer @ 8390' MD. 4-1/2" HES 'X' Nipple @ 2138'. 13. Attachments Description summary of proposal _X Detailed operations program - 14. Estimated date for commencing operation 15. Status of well classification as: June 4, 2002 1 6. If proposal was verbally approved Tom Maunder 31-May-O2 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. Borea!;. Development Petroleum Engineer Date June 03, 2002 Bruce W. Smith Pre Bred b DeWa ne A. Schnorr 564.5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity - ",~P Test - Location clearance - ; J I Mechanical Integrity Test A I S .......1 &Jþsequent form required 10- ~ 0 Co . 009108 ..' ,Igna:i\l fT1 çwnmy OechsU Tay'œ Approved by order of the Commission ' 1. Type of request: Pre-Producer Converted to Inject 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora e, AK 99519-6612 4. Location of well at surface Abandon- Suspend- Alter casing - Repair well - Change approved program - 273~FNL,3786'FEL,Sec.34,T12N,R11E, UM At top of productive interval 3178' FNL, 3387' FEL, SEC 27, T12N, R11E, UM At effective depth 3067'FNL,3295'FEL,Sec.27,T12N, R11E,UM At total depth 3041' FNL, 3272' FEL, Sec 27 T12N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 102' 20" Surface 3084' 9-5/8" Production 9144' 7" Perforation depth: Tubing (size, grade, and measured depth Form 10-403 Rev 06/15/88 . Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development - Exploratory - Stratigraphic - Service_X (asp's 583128, 5978267) (asp's 583464, 5983106) (asp's 583555, 5983218) (asp's 583577, 5983245) Plugs (measured) Oil- ORIGINAL bIll Re-enter suspended well - Pre-Producer Converted Time extension - Stimulate - to Injector Variance - Perforate - Other _X 6. Datum elevation (DF or KB feet) RKB 77.1 feet 7. Unit or Property name Prudhoe Ba Unit 8. Well number L-117 9. Permit number 1 approval number 201-167 10. API number 50-029-23039-00 11. Field 1 Pool Prudhoe Ba JUN 0 6 2002 3111' 9169' BOP sketch - Gas- Suspended - Approval no. 3 Ð '2- - l ~ Commissioner Date CO) ~ SUBMIT IN TRIPLICATE bp ( ( ,\t~'I. ....~.... ,.~~.. :!IIi.- ~4i.: ..~ .¡:..-. .J'~\" 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 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for L-117 Conversion from Pre-Producer to WAG Injector BP Exploration Alaska, Inc. proposes to convert well L-117 from a pre-produced injection well to an active inject,or (both water and MI (WAG flood)) as part of the Borealis Pool Flood Development project. The procedure includes the following major steps: S DfT, Dummy off GL Design, Run Static Survey. MITIA to 4000 psig. Stim Pump HPBD Slickline Work: 1. Drift and tag to at least 8900' MD, to verify access to perfs. 2. DGLVs 3. Obtain SBHPS stop counts at: 8893' - 40-min, 8787' - 20/30min, 8681' - 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. AU the tree-saver/isolation tool for 4% "- 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 PAV 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 BPM U( J 20/40 at 1 ppa. Flush with water/di( shut down for ISIP, monitor for closure time. 4. Pump stage two Diversion 1 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 1 HPBD#3 and scour stage. Pump rocksalt and spacers as per attached schedule. Flush as per schedule and shut 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: 4/29/02266 BFPD, 253 BOPD 63.6° @ 3204' MD 16° @ 9930' MD 2.813" SSSV Nipples @ 2314' MD 9960 ELM SCMT and bailer cleanout 0 ppm at time of shut-in 4/02 Freeze protected tubing & IA to 2200' with diesel. 158°F & 2800 psia @ 6600' TVDSS Schlumberger Vision 1/30102 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, ~ ~~ Bruce W. Smith GPB Borealis Development Engineer ( "TREE = 4-1/16" CrN . WEllHEAD = FWC AC1UA TOR = KB. RBI = 77.1' BF. REV = 54.8' KOP= 1000' Max Angle = 59 @ 4282' D3tum W = D3tum lVD = 8800' SS g.5/8" CSG, 40#, L-80, ID = 8.835" 3111' Minimum ID = 2.813" @ 8377' 3-1/2" HES X NIPPLE 4-1/2" 12.6# X 20' PUPJTW/ RA TAG I RW RA TAG LOGGED 03/08/02 H 5862' 5847 4-1/2"lBG, 12.6#,L-80, .0152 bpf, 0=3.958" 5962' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 6374' PERF ORA llON SU'v1MA. RY REF LOG: SWS COR/RESISTIVITY LOG of 09/23/01 ANGLE AT TOP PERF: 46 @ 5930' Note: Refer to A'oduction DB for historical perf data SIZE SPF INfER\! AL Opn/Sqz DATE 4-5/8" 5 5930 - 5970 C 10/03/01 4-5/8" 5 6013 - 6040 C 10/03/01 4-5/8" 5 6073 - 6087 C 10/03/01 4-5/8" 5 6142 -6182 C 10/03/01 4-5/8" 5 6242 - 6280 C 10/03/01 4-5/8" 5 6514 - 6524 C 10/03/01 2-1/2" 4 8655 - 8706 0 03/08/02 2-1/2" 4 8719 - 8724 0 03/08/02 3-1/2" lBG, 9.2#, 13-CR, .0087 bpf,lD = 2.992" 8447' 7" 26# X 20' PUPJTW/ RA TAG ELMD RA TAG LOGGED 03/08/02 8598' 8587' 8902' 8893' 9085' 7"26#X20'PUPJTW/RA TAG I RMD RA TAG LOGGED 03/08/02 H 7" CSG, 26#, L-80, 0 = 6.276" 9169' L-117 GPo. S LIFT MA. ~RELS TVD DEV TYPE VL V LA TO; 3424 57 KBG-2 OPEN BK-5 4092 49 KBG-2 rN BK-5 WATERFLOOD MA.NDRRS TVD DEV TYPE VL V LA TO; 4179 45 rvJv1G-W RKED RKP 4455 44 rvJv1G-W RKED RKP 1019' 2138' ST MD 4 4715 3 5845 ST MD 2 5973 16354 5892' 5904' 5905' 5963' 6374' 8366' 8367' 8377' 8389' 8390' 8394' 8415' 8436' 8448' 8432' DAlE RBI BY CO rvJv18'JTS DATE REV BY COMrvENfS 10/06/01 CH'KAK ORIGINAL COMPLETON 10/01/01 BSIKAK FIRD CORRECTION 10/29/01 DAC/KK MANDREL CORRECllONS 03/08/02 Tfv'f\J/tih ADD ÆRFS & RA TAG RW ,'- SAFETY NOTES: GLM'S@STA#1 &#2ARE3- 1/2" X 1-1/2" MM G-WS, WHCH ARE WA TERFLOOD MANtRaS (DMY 1016101) 9-518" TA M PORT COLLAR 4-1/2" I-ES X NIP, ID = 3.813" PORT DATE 0 1 0/05/01 0 1 0/06/01 PORT DATE 0 1 0/06/01 0 1 0/06/01 4-112" HES X NP, ID = 3.813" 5" LH AOV1EX 4-1{2" NSCT XC, ID = 3.560" 7' X 4-1/2" BKR PREMER PKR 10 = 3.875" -1 4-1/2" X 3-1/2"TBG XO, ID= 2.937" I -1 3-1/2"X4-1/2"TBGXO,ID=2.992" I 4-1 {2" lBG, 12.6#, L-80, 0 = 3.958" -1 4-1/2" X 3-1/2" TBG XO, 10= 2.937" I 3-1/2" HES X NP, ID= 2.813" 3-1/2" X4-1/2"TBGXO, ID= 2.992" 7'" X 4-1/2" BKR S-3 A<R, ID = 3.875" -1 4-1/2" X3-1/2"TBGXO, 10= 2.937" I -i 3-1/2" HES X NP, ID= 2.813" I - 3-1/2" HES X NP, ID= 2.813" I 3-1/2" WLEG, 10= 2.875" RMD TT LOGGED 03/08/02 GPB BOREALIS WELL: L-117 PERMT f\b: 201-1670 AA No: 50-029-23039-00 2546' NSL & 3786' WEL, SEC 34, T12N, R11 E BP Exploration (Alaska) ,( c- MEeHAN I eAL INTEGRITY REPORT' '- , . '-~UD ""'.....~' : ~ 'iJ:'.':':': OPER & FIELD ~p,~ PI6t1... wTIL NUMBER L.. t/7 ¡ := ï G ~ t:'i ~,' ~ -=. . .'- 1\......._r'_-~. :~""ELL DATA TI>: ~}ffi.. JOS(PTVD; ?BTD: ~MI? (¡,&fS1 TVD Casing: 7'1 - Shoe: '11,,'1 MD TVD; DV: -- MD .TVD -- Shoe: . II J., II :~bi~g: ~~~3~acker ~ole Size -3.11,," MD ~ LIt.{ t HI) .,... UT". ': n l' , - 'I U J - '-'..I. . HD ..." -D ~ ,¡ I ;...:"':1e~: TVD; Set ë.,t S'lOS'; -9~'?O I stt ! c. (pSït¡i. , ; Perfs 3Cø55" to ~7 2.'1 I ".'. . ana , - tSCP"þ'1~IC;'..L INTEGRITY, - P ..4..RI #1 . ., Annulus 'Press Test £ . :.p " ; '15 min ."" 0 . 'j ',' ~ mJ.n ,. . ; ";". -: ,:, ".. - '- .. , -. . Comments: .l!JjÞT ~.2~dfH'()LJ() ~~ii...-... '. ~ ",. ~CHJÜIIC~.L INTEGRITY - PART 12 11~bbJ! . ; Csg '1~ ~ 1/." j , , ,kh1 ~ 1Ð--.. ~,.(¿t' 'P¡~f DV ¥'2P.¡I t \" . Cement: Volumes:' .Amt. Liner i i j ~ t !: C~t ~ol to cover Der£s 130 . ç <00' . ~ ~ ~ Clì, Q.f...l:Rs«:,... L/~ 2 t' ,k(. eJ. ¡) tW ~t;- ~ ~ ' f!A.? w., ~. - l 10 () , ~ ,.J) 1~ Theoretical Toe Cement Bond Log (Yes or No) "1 , .; In AOGCC File' ~ ~ þ~d{ -§ :; 1 ¡; ,- i ~ CBL .!:.valuation, ::onë above ,~,cU~1z'l Q.b(J~1.le.. euL. Prociuc.tion Log: i Evå.luation Type ,. . I i i , ¡ . ; ¡ \ i i I -.. , . -" --' CONG~LUSIONS : ,: :'. '. ? ar; : 1: /tit r.' T ~'~.,J4 vlf},,/ to 11v' $~~ ? ar:: : 2: CßL ~ ....,~~~,-" ~t ~k" L ;~~ fb.-c, ~ fì w" .J. - I}..f c. Æ- {p (? (I) ~ r'VLJ/I.ß.':b. tJŒ.. " . ' -. -- "," STATE OF ALASKA ALASKA 01 L AN D GAS CONSERVATION COMM ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 04/25/02, Put on Line ( (' 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned ~ Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 -- -- 4. Location of well at surface " ',I: ,- 2547' NSL, 3787' WEL, SEC. 34, T12N, R11 E, UM' " At top of productive interval : IIJ ~~t~ l;)_i..: 2102' NSL, 3387' WEL, SEC. 27, T12N, R11E, UM -, " At total depth : ,___~A-~~.:--,"-' 2238' NSL, 3272' WEL, SEC. 27, T12N, R11E, UM :, ",,--.-, ,.""---,,.- 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 77.10' ADL 028239 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 9/13/2001 9/23/2001 10/6/2001 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9189 7056 FT 9085 6957 FT ~ Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, CMR, MDT, USTI 123. CASING. LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 91.5# H-40 Surface 102' 30" 260 sx Arctic Set lADDrox.) 9-5/8" 40# L-80 27' 3111' 12-1/4" 491 sx AS Lite 425 Class 'G' 7" 26# L-80 25' 9169' 8-3/4" 420 sx LiteCrete Classification of Service Well Water & Gas Injector 7. Permit Number 201-167 8. API Number . .~ 50-029-23039-00 -- I-m~' 9. Unit or Lease Name f Prudhoe Bay Unit :51 ",...., , : \( !~~:-~'- ..".:.~-:~ 1 O. Well Number L-117 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2138' MD 1900' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 spf 2-1/2" Gun Diameter, 4 spf MD TVD MD TVD 5930' - 5970' 4226' - 4253' 8655' - 8706' 6552' - 6600' 6013' - 6040' 4284' - 4304' 8719' - 8724' 6613' - 6617' 6073' - 6087' 4328' - 4338' 6142' - 6182' 4378' - 4408' 6242' - 6280' 4451' - 4479' 6514' - 6524' 4647' - 4654' 25. SIZE 4-1/2", 12.6#, L-80 x 3-1/2",9.2#, L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 190 Bbls of Diesel & 10 Bbls of MeOH TUBING RECORD DEPTH SET (MD) 8448' PACKER SET (MD) 5905' 27. Date First Production 04/16/02 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Lift PRODUCTION FOR TEST PERIOD Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE Oll-BBL GAs-McF WATER-BBl CHOKE SIZE GAS-Oil RATIO Oil -BBl GAs-MCF WATER-BBl Oil GRAVITy-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ro,~ if'" [/"" ~,.." ~ ì\ ~ 1,;- ~""~I ,:-",;0" ~I'~'-r, ,"'I .1 ;1, ," ~, ,1,1) , ii ,\, K.."" ,;. ~~/ ~~ ;\ ~¡ No core samples were taken. '" '"." "" ,.,." L II :' r'ì ,:, r:" i', ¡ì ('. t) /-¡ ;,'-' rï: ,'~ -J ~:: li U t.:, '-" .-. Æ\¡':J""~"-"~O:\ßG""-'--"'" - ,.'1.11:\,;::>,'\..:;.( U (51 . ä:;; U)'O::í" ~):mmHSSHJj f'i(1J"!'O' "";\[1'1 !, .~.,., A '.1\.\",1:> Form 10-407 Rev. 07-01-80 I.'.. II ...J r ( "I.: I. ",~<i. /(¡;):~\I\ fl..,_, \, : 1\ I,: . I :1 C,r- Submit In Duplicate Summary of Post-Rig Work. Previously Submitted: Summary of Daily Drilling Reports, Surveys, Leak-Off Test, Sidewall Core Summary 32. I ~erebY certify that the f~oin: is true and correct to the best of my knowledge Signed Terrie Hubble '11A Title Technical Assistant Date Ó . ~.Ó L-117 201-167 Well Number Permit No. / A roval No. '- -- (' 29. Geologic Markers Marker Name Measured True Vertical Depth Depth Schrader Bluff M 5348' 3858' Schrader Bluff N 5783' 4129' Schrader Bluff 0 5930' 4226' Colville Mudstone 6424' 4583' CM1 7601' 5551' HAl 8254' 6171' Kalubik 8495' 6400' Kuparuk C 8653' 6550' LCU / Kuparuk B 8789' 6679' Kuparuk A 8929' 6811' Base Kuparuk / Top Miluveach 9017' 6893' 31. List of Attachments: INSTRUCTIONS (' 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. MDT was ran, log supplied for detail. ", ¡: '~, :ì' I: "." ,,' ;~) [: ;": {I> /:. :~; ~.:': ~-_. 'F- '" :i'->,oiI ' Prepared By Name/Number: Terrie Hubble, 564-4628 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 (OF, 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 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 i'¡ I: 1- , I;; . ' (' ( Well: Field: API: Permit: L-117 Prudhoe Bay Field / Borealis Pool 50-029- 23039-00 201-167 Rig Accept: Rig Spud: Rig Release: DriliingBlg: 09/12/01 09/13/01 10/06/01 Nabors 9ES - - - - - - - - -- ----- ---- --- ------ ----- --- - ---. ---.-- --------- ---.--------------- -- ----- --- -- ---- - -- --- - ---- -- -- ----- ---- -------------- ----------- --- --- ---- - -, -- - --- -- - - - -- POST RIG WORK 10/24/01 PULL B&R @ 8417' SLM. SET 1" DGLV @ 4707' SLM. 10/25/01 SET 1" DGLV @ 4707' SLM. PULL 31/2" RHC PLUG BODY @ 8421' SLM. DRIFTTBG W/2.5" DG. LOCATE TTL @ 8430' SLM + 18' = 8448' CORR MD. TAG BOTTOM @ 9015' SLM + 18' = 9033' CORR MD. BAILER FULL OF SAND. RDMO. 10/27/01 COMPLETED JEWELRyrrEMP LOG; SCMT & MIT. CEMENT IS FAIR FROM 9012' TO 8650' AND GOOD FROM 8650' TO 8436', MIT WAS GOOD. 03/02/02 SET CATCHER SUB, SET GLV DESIGN IN STA # 4 AND 3, PULL CATCHER, DRIFT WI 2.5 DUMMY GUN. TAGGED TO @ 8975' SLM. RDMO I LEFT WELL SHUT IN. 03/08/02 RUN BASELINE TEMP I JEWELRY LOG FROM 9015' (TO TAG) TO 4600'. PERF 8719'-8724' & 8655' - 8706' IN THREE RUNS (ALL SHOTS FIRED). GUNS: 2.5" POWERJET, 4 SPF, 180 PHASING, ORIENTED 10 DEG OFF BOTTOM. WHP REMAINED CONS TAl NT AT 0 PSI THROUGHOUT OPERATION (NOT ON VA C). NOTIFY PAD OPERATOR OF WELL STATUS: DO NOT INJECT, NEXT UP ARE GAUGES AND STEP RATE TEST. 03/19/02 SET DUAL GAUGES IN 2.813" X NIPPLE @ 8423' WLMD. TOTAL LENGTH OF SHUT IN TOOL= 8' 03/20/02 SET GAUGES IN X NIPPLE @ 8423' WLMD -- RUN CHECK SET TO 2.813 LOCK, GOOD SET -- RDMO -- (GAUGES SET @ 2300 ON 3/19102) -- 8' LONG WI 2.813 X LOCK. WELL TO REMAIN SHUT IN. 03/21/02 PUMP L-117 INJECTION TEST, 0.5 bpm @ 2200 psi. 04/01/02 - ATTEMPT TO PULL GAUGES ON FLOW THROUGH SUB SET AT 8436' MD (UNSUCCESFULL) DUE TO TBG OBSTRUCTION BEGINNING AT 5732' SLM - RETRIEVED HYDRATES FROM 5782' SLM WI 2.50" PUMP BAILER. 04/02/02 PUMP 10 BBLS MEOH AND 190 BBLS HOT DSL DOWN TBG. PULL FLOW THROUGH SUB WI PANEX GAUGES FROM BOTTOM X- NIPPLE @ 8436' MD. WELL READY TO POP. 4/412002 SchlllDbepgep NO. 1955 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora ~~'-"""'- Well Job# Log Description Date Color Sepia BL CD "'- L-117 ---;::¡¡)) - J lJJ 7 PRODUCTION LOG 03/08/02 1 1 L-120 ~~ -00(0 PRESSITEMP LOG 03/17/02 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Sherrie Received ~'ïYJ. ~ Date Delivered: F r"'n 0 0 "002 ¡.. :";-: J . { . Alaska Oil & Gas Cons. Commisston Arri'lnrMA '.-- ;20'- n~1 - 12/11 /2001 ScbllD_epUlr NO. 1676 Alaska Data and Consulting Services 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Well Job# Log Description Date Color Sepia CD BL L-117 21499 SCMT 10/27/01 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEI\JED Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received b~ l& fk ..J DEC 2 1 2001 Date Delivered: Alaska Oil & Gas Cons. Gomm!ßSion Anchorage Qo7- / to 1 ," ,{ { ~' 1- ~V~VŒ (DJ~ ~~~~l}{~ I , / ¡ / TONY KNOWLES, GOVERNOR / ALAS KA OIL AND GAS / I 333 W. "JTH AVENUE. SUITE 100 CONSERVATI ON COMMISSION I' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 November 20,2001 Gil Beuhler Satellite Resource Manager BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Borealis Well L-117i Dear Mr. Beuhler: On August 7, 2001, BP Exploration Alaska, Inc., ("BPXA") submitted an application to the Commission for approval to drill and complete PBU well L-117i as a Kuparuk Fonnation injection well in the as yet undefined Borealis Pool. This BPXA L-117i application identified only one target and specified a conventional completion (4-Y2" tubing and isolation packer) with perforations only in the Kuparuk River fonnation. The Commission approved the pennit to drill for PBU well L-117i on August 13, 2001. On October 10, 2001 ,BPXA submitted a pennit to drill application for PBU Borealis well L- 109i. The L-109i application specified a straddle packer completion to allow targets in both the Schrader Bluff and Kuparuk fonnations to be developed. To aid in the !eview of L-109i application, on October 17,2001, AOGCC staff requested directional survey and completion infonnation that had not yet been submitted on well L-117i. Review of the L- 117i infonnation indicated 169 feet of Schrader Bluff perforations as well as a straddle packer completion. A phone call to BPXA staff verified that the L-117i perforation and completion infonnation was indeed correct. It appears that these operations represent substantive changes from the approved pennit to drill PBU well L-117i. An operator is required to seek commission approval for changes to a program approved in a Pennit to Drill. 20 AAC 25.015. AOGCC regulations allow for the option of requesting oral approval where prompt approval is needed. The AOGCC On-Call Engineer or Field Inspector is available 24 hours a day at (907) 244-1567 or (907) 659- 3607, respectively, to discuss drilling and completion issues and to request oral approval under the regulations. In this case it appears that BPXA failed to obtain Commission approval prior to the perforation of the Schrader Bluff fonnation and the installation of a straddle packer completion across this perforated interval. . (' Borealis Well L-117i November 20,2001 Page 2 of 2 l' ( The Commission is requesting that you provide an explanation for this failure. We find the situation to be particularly puzzling in light of the fact that BPXA Shared Services Drilling previously developed training materials that include a checklist showing when it is necessary to submit an Application for Sundry Approvals to the Commission. You may also wish to review the enclosed copy of the guidelines developed by BPXA. We would appreciate receiving your response no later than December 3, 2001. Should you have any questions, please do not hesitate to contact Tom Maunder at 793-1250. Sincerely, Ck/~ ()\Æ"twL . ~'-f/' Cammy bechsli Taylor Chair COT\jjc ---- ClJ Shared Services Drilling Well Permitting Leadership - . expectations made clear to all Drilling Staff Awareness - . Drilling Staff must know the Regulations, . Drilling Staff must know where to go to find out for interpretation (seek internal clarification before asking AOGCC) Training - . Mandatory training for all Drilling Staff and new starts Compliance - ; . Internal System to :e,nsure we comply. and provide early warning of potential breaches (check list) . . Apprqval of Supervisor for quality control . Rigorous with Recörd Keeping/Documentation " . J . ~ ~~- -... 19 AOGCC ReQuired DrillinQ Permit Content Please refer to AOGCC Regulations (Alaska Administrative Code, Title 20, Chapter 25, April 2. 1986) for clarification and/or details. Also, refer to any local Pool Rules which may supersede some requirements. Minimum Requirements for Dril!ina I Sidetrack Permits (Translation. or how it applies to SSD. provided in italics) (1 ) S1 00 filing fee; Plat identifying property and showing coordinates of surface location, top of the objective formation and bottom hole location referenced to governmental section lines; Translation: As built diagram (for surface location); top of objective formation and BHL can be derived from directional plan; (2) (3) Diagram and description of BOP equipment to be used, as required in 20 AAC 25.035(a)(1), and the pressure information required in 20 AAC 25.035(d){2); Translation: BOP diagrams for most all North Slope operating rigs are on file with the AOGGG; a short description of the BOP configuration, working pressures and maximum anticipated bottom hole pressure should suffice; (4) A complete proposed casing and Qementing program as required in 20 AAC .25.030; Translation: Provide details of the proposed casing program [hólé size, casing size, grade, weight, connection, length and setting depths (MD and TVD)]; provide details of proposed cementing program for each casing size (volume in sacks and cubic feet, density, yield, percent excess, proposed TOC, liner lap and proposed placement method for all cement sluriies); (5) - -.. A diagram and description of the diverter system to be-. used as specified in 20 ACC 25.035(b), unless this requirement is waived by the AOGCC; Translation: Diverter diagrams for most all North Slope operating rigs are on file with. the AOGGC; a short description of the diverted configuration and maximum anticipated bottom hole pressure should suffice; check Pad Data Sheets for opportunities to waive diverter requirements; (6) A drilling- fluid program, a schematic diagram and description of the drilling fluid system to be used, and the informatiqn -required in 20 AAC 25.033(e); Translation: Schematics for the drilling fluid systems of most North Slope operating rigs are on file with the AOGCC; include a description of each drilling fluid system to be utilized ... including details such as density, viscosity, gel strengths, pH and filtrate loss; . On exploratory and stratigraphic test wells, provide a tabulation setting out the depths of predicted overpressured strata as required by 20 AAC 25.016(a); Translation: Provide names and depths of known and/or predicted overpressured formations for all exploratory wells; (7) (8) On exploratory and stratigraphic test wells, provide a seismic refraction or reflection analysis as required by 20 MC 25.061 (a); Translation: Provide analysis of all potential shallow hazards, namely shallow hydrocarbons, within 2, ODD' of the proposed surface location; On offshore wells drilled from a mobile bottom founded, jack-up or floating unit, provide an analysis of the seabed conditions as required by 20 AAC 25.061 (b); Translation: Provide analysis and documentation of seabed surveys (i.e. sidescan sonar) to ascertain potential hazards on seabed in the vicinity of the proposed location; (10) A copy of the proposed drilling progråm; Translation: Provide scope of work for anticipated operations; (9) (11) Proposed directional program (which meets the requirements of 20 AAC 25.0S0(b); Translation: A workable directional plan showing surface location, top of target interval and BHL with continuous surveys no further than 100' apart; additionally, vertical section and plan views should be provided; " .. , \ . . -------, - \¿) IïPic-al SSD DrillinQ/Sidetrack Permit Content Type of well: Surface Location: Target Location: Bottom Hole Location: AFE: Rig: Estimated Start Date: Days to complete: Depths: Well Design: Objective;:- ~ ' > Formation Markers: CasingfTubing Program: Cementing Program: Drilling Fluid Program: Directional Program: Logging Program: Well Control: Hazards: Disposal: Operations Summary: Producer or Injector is sufficient description, although many engineers use this opportunity to describe the generic well type (i.e. USH Extended Horizontal, etc); Surface location coordinates must be provided in both ASP (X, Y) and TRS (Section, Township, Range) coordinates; Target location coordinates must be provided in both ASP (X,Y) and TRS (Section, Township, Range) coordinates; Bottom Hole location (BHL) coordinates must be provided in both ASP (X, Y) and TRS (Section, Township, Range) coordinates; Usually included for our own benefit, but not required; Since AOGCC has rig layout, BOP and drilling fluid system configurations on file for all north slope operating rigs, this information should be provided; Two purposes for this date - (1) signifies our intent, and; (2) provides the AOGCC with a ~arget start date for planning purposes; Provides an estimated duration of operations; . '\ Total depth of the proposed wellbore should be provided in Measured Depth (MD) and ,Total Vertical Depth (~D); we often include TVDss (subsea) depths as provided by geoscience; an estimated RKB elevation ~hould also be provided; Description of generic well type (i.e. Conventional UgH high angie well, etc); A short description of the purpose of the well (will sidetrack existing well and drill a horizontal wellbore in Zone 4 to drain two separate fault blocks, determine PWOC and access reserves east of previous bottom hole location); Provide depths (MD, TVD) key formation tops that are utilized to plan casing points, cement volumes, directional work, drilling fluid density, etc, etc; Provide details of proposed casing and tubing program; include hole size, tubular size, grade, weight, connections, depths (MD and TVD), etc; Provide details of proposed cementing program to include method of placement (single stage, two stage, DV collar, inner string, etc) and cement composition [must include volume (sacks and cubic feet), density and yield]; critical information includes proposed top of cement (TOC) for each casing string (surface casing must be cemented to surface); Provide details of all drilling fluid systems for each hole size to include mud type, density rànge, viscosity, yield point, gel strength, pH and filtrate loss; Provide a brief summary of the proposed directional profile, namely kick-off point(s), maximum hole angle, departure, close approach issues, etc; a copy of the proposed detailed directional profile (MD, TVD, inclination, azimuth, bottom hole location, etc) along with section and plan views must be included with every permit; Provide details of proposed formation evaluation methods (MWD, LWD, open hole and/or cased hole logs, etc) for each hole section; Provide a brief description of the proposed well control equipment to be utilized (most north slope rigs have well control equipment schematics on file with the AOGCC); provide proposed configuration of BOP stack and rated working pressure; provide descriptions of known overpressured intervals. estimated bottom hole pressure and maximum anticipated surface pressure; any requests for variances (i.e. no diverter) should be first addressed here; if variances are not obtained in the original drilling permit, a follow-up sundry application will be required; Provide details of any known drilling hazards and how they will be addressed (shallow overpressure - higher MW; 50' fault at start of horizontal interval - lost circulation measures will be in place; close approach in surface interval - will gyro while drilling; H2S pad - no camp on location, H2S detection, drills, etc, ete); Provide details of how wastes will be handled (cuttings to CC-2A Ball Mill; drilling fluids and other Class II wastes to CC-2A Ball Mill; Class I wastes to Pad 3, etc); Always a good idea to include a brief summary of the proposed scope of operations to be undertaken; " FÓO ,~-- ~ ~ When is a Sundry Notice Required? Sundrv Application Menu D Abandon D Alter Casing D Change Approved Program D Suspend D Repair Well D Operation Shutdown D Plugging D Pull Tubing D Re-Emer;Suspended W~ll D Time Extension D Variance '. ~ D StilI!ul~te -;- D -'} Perforate D Other Examole/Comments Abandoning a well bore or interval (usually includes a top cement plug) A change in the proposed or approved casing program (size, depth, etc) Any change in the approved (pennitted) program Cessation of drilling operations - intent to return is an unknown Required for injectOrs; may be exempted by local Pool Rules for producers Cessation of drilling operations - intent to return is known Plug (and possibly abandon) in preparation for other work (sidetrack, reperf, etc) Self explanatory; maibe exempted by local Pool Rules Conunencernent of drilling operations in a well previously suspended Required for extending previously estimated tirneline - Waiver to exempt use of divener is best example Acid work, frac job. etc To add perforations (excluding perforations in original drilling permit) Verbal approvals for any of the above work can be obtained through the AOGCC over the telephone in most cases but written documentation MUST follow on the AOGCC's next working day. When in doubt. ask and/or file. T. Burns T. Hubble 4/27/98 4/27/98 ,ø r -~ . Change to Approved Operation Required ODE I SDE Discusses Change and Proposed Forward Operations with AOGCC Yes ODE Generates Follow- up Written Documentation TA Check Numbers; Complete Permit Yes , 'r T A Processes; Routes to AOGCC,ODE AOGCC Receives/Processes Yes Approved Permit Received by TA T A Routes Permit (ODE, Rig, POC, Asset TA, File) Revised Operations can continue ,~~, Questions -. No Questions Permit Process MaR. ~ Changes? Changes? No --. Change Request & Verbal Approval Key Point AOGCC Verbal Approval for necessary changes can be obtained to avoid delays and/or shutdown of operations. Written confirmation (fax, e-mail) of verbal approval is recommended. Sundry Application Kevhlnt Written Sundry Application must be submitted within 1 working day of AOGCC Verbal Approval. Documentation to include name of AOGCC contact granting verbal approval and date of same. Revised Operations Approved Key Point Ongoing Operations can proceed without interruption if permitting process observed. Rig Operations personnel should confirm receipt of permit. (2) Burns/Hubble 4/28/98 , . ~ f ODE check Requirements and Generate Permit Documentation TA Check Numbers; Complete Permit Yes .. T A Processes; Routes to . AOGCè,ODE ",AOGCC Receives/Processes .... '" .. '- '-- . Yes Yes Approved Permit Received byTA ~. TA Routes Permit (ODE, Rig. PDC, Asset TA. File) . Permitted Work Can Commence ..-..... ---- (JV Permit Process Mag. {Routinel Changes? Planning Phase No . Key Point Confirm surface location and set conductor. Directional plan should be close to final. Plan and permit any necessary pre-rig work. AOGCC requests 5 working days to approve Sundry Applications and 10 working days to approve Drilling Permits. Accelerated approvals can be requested on an as- needed basis, but should be the exception. Questions No -- Action Phase Key -.P---.Oln1 Rig Operations personnel should confirm receipt 01 permit. Burns/Hubble 4/28/98 r \. . ~-. , ~ ,-., -- General Permitting Knowledge Test (with Answers \ 1. How long before a Drilling Permit expires? 2. Two years per AAG 25.005 (h). Asset desires to sidetrack an existing shut-in well to a new BHL. How many permits, if any, are required? Which permits should be filed? What is minimum required TOC for abandoning existing perforations? Two permits. An Application for Sundry Approval to abandon the original well bore must be obtained. The actual abandonment can be done prior to drilling rig arrival (i.e. pre-rig work) if desired, but the Sundry permit must be approved prior to commencing abandonment operations. A full Drilling Permit to sidetrack to the new BHL is also required. By displacement method, TOG must be a minimum of 100' above the uppermost perforation per AAG 25.105 (h) (1). Alternative cement placement methods may allow for variations on the actual coverage height. These variances can be granted under AAG 25.105 (m). 3. A well reaches it's, proposed BHL and the target is deemed a "dry hole". Asset requests we P&A and move on to next location. What permits, if any, are required? One permit. An Application for Sundry Approval to abandon the original well bore. - ~ 4. A well reaches it's proposed BHL and the target rs deemed a "dry hole". Asset requests we plug back and sidetrack to an alternate BHL. What permits, if any, are required? -Two permits. A verbal approval can be obtained to plug back without delay, but an Application for Sundry Approval to abandon the original well bore must be submitted on the AOGGC's next working Gay. A Drilling Permit to sidetrack to the alternate BHL is also required. See AAC 25.025 (b) (2). ~ -, 5. Tr~e or False. AOGCC does not require the details of how drilling wastes (cuttings, fluids, etc) will be handled in the permit application. False. See AAG 25.047 (b). 6. After drilling a few hundred feet into the horizontal target, Geoscience determines wellbore is in the proper formation but too high (TVD) and in the wrong sand body, Asset requests that we move the wellbore vertically down but does not want to forfeit the section already drilled. SSD decides to move back to the beginning of the horizontal interval and perform a low side, open hole sidetrack to reposition the wellbore down to the desired TVD depth. Although the final TVD depth will be revised slightly deeper, the ultimate BHL coordinates will remain unchanged. What permits, if any. are required? No permits are required (as long as well bore remains in same target interval). If the first horizontal section drilled is to be plugged back, verbal apprÇJval can be obtained but an Application for Sundry Approval must be submitted pn the AOGGG's next working day. See AAC 25.015 (b) (2). 7. Horizontal drilling in the target interval is going extremely well and Asset desires to extend the wellbore 399' in the pay zone. What permits, if any, are required? An Application lor Sundry Approval is required. See AAC 25.015 (b) (1) and (2). 8. True or False. A variance (Le. no diverter) can only be received from the AOGCC via an approved Sundry Application. False. A variance can be granted in the original Permit Application. 9. Are casing setting regulations the same across the North Slope? Are there any field specific regulations? Casing setting regulations vary from area to area depending primarily on local geology and are governed by field specific "Pool Rules". Field and Pool Regulations can be set up for specific areas under AAC 25.520 (a-b). 10. A change in the proposed drilling permit is verbally approved by the AOGCC. What happens next? An Application for Sundry Approval must be submitted on the AOGCC's next working day. See AAC 25.015 (b) (2). .-- ." -,. 11. --... ~ --- After drilling the intermediate section to proposed casing point, intermediate casing becomes stuck 500' off bottom and is cemented in place. The bottom hole target remains the same, but the mud program and forward casing program will be altered slightly to meet the objective. What permits, if any, are required? A verbal approval can be obtained to proceed without delay, but an Application for Sundry Approval to alter the forward casing, cementing and drilling fluids program must be submitted on the ADaCC's next working day. SeeAAC 25.015 (b) (2). 12. While cementing the surface casing, the hole packs off (zero returns) and cement is not circulated to surface. Should the AOGCC be notified? Do we need to file any permits? 13. A tough judgment call. We usually notify the ADGCC if the requirements of AAC 25.030 (d) (2) (8) are not met. Remedial operations may require AOGCC consent. See also AAC 25.030 (h) and Conservation Orders identifying any field specific Pool Rules (i.e. Conservation Order #341, Rule 3c for Prudhoe Bay). . A conventional rig workover (tubing swap) of a production well is proposed. What permits, if any, are required? What if the well is an injector? 14. No permits are required for workovers on producing wells. An application for Sundry Approval is required on all injection we/ls. See MC 25.280 (a) (1-5). Most North Slope areas waive the permit requirement for workovers on producing wells via Conservation Orders (i.e. Conservation Order #341, Rule 14 for Prudhoe Bay). . How long does the AO~CC require to process/approve a Sundry Application? A Drilling Permit? Can accelerated approvals be obtained? - 15. ADGCC has verbally requested 5 working days for Sundry Applications and 10 working days for Dri//ing Permits. Accelerated written approvals are fairly common but should be the exception ifls-tead of the norm. Alt~'r drilling and logging a well, the Asset decides to increase the tubing size based on logging data and~ new estimated production rates. Miraculously, the larger tubing size is in stock. Do we need a permit to run the larger tubing size? J 16. A verbal approval can be obtained to alter the tubing size without delay, but an Application for Sundry Approval must be submitted on the AOGCC's next working day. See AAC 25.015 (b) (2). Half way through the drilling of the intermediate hole section, the OS decides it's finally time to try our newest proposed experimental drilling fluid for the upcoming horizontal section. Are any permits required? A judgment caJ/. If the dri/ling fluid density and basic properties remain the same, probably not. If significant changes are required, then a verbal approval can be obtained to alter the forward drilling fluids program without delay, but an Application for Sundry Approval must be submitted on the ADGCC's next working day. See AAC 25.015 (b) (2). 17. seD plans to drill on a pad proven to be absent of shallow hazards and desires to drill surface hole without a diverter. Can this be done? How? A variance can be obtained in the original drilling permit or via an Application for Sundry Approval. See MC 25.035 (c) (2). 18. SSD plans to cease operations on a well with seasonal access. Originally permitted operations will recommence next season. Is this allowable and if so, how should this process be permitted? 19. An Application for Sundry Approval to shutdown operations is a/lowable under MC 25.072 (a). What are the critical timing issues involved with permitting wells near Unit boundaries? If there are affected owners in the nearby Unit, the permit application can be held for an additional 15 days (comment period). If any affected owner raises objections within the 15 day period, a public hearing wi/l be held and an order concerning the permit application would then be issued within 30 _days of the close of the public hearing. See AAC 25.050 (d) (1-3). See also AAC 25.540 for guidelines on hearings. 20. For directional wells, what is the maximum permitted distance between directional surveys? For intentionally deviated wells, a continuous directional survey at intervals of not more than 100 feet apart is required, beginning within 100 feet of surface. The ADGCC can, at it's own discretion, waive or amend this requirement as long as alternate methods of determining the location of the bore hole are approved. See MC 25.050 (e) (I). A- . - . /~- -- æ Bonus During drilling operations, a small influx into the wellbore is observed and subsequently circulated to surface during well control operations. At surface, the influx ("dry gas") is vented to the atmosphere. No spills occur and well control is regained allowing drilling operations to continue. The potential for slight overpressure was highlighted in the Drilling Hazards section of the original drilling permit. Is AOGCC notification required? The waste of any oil & gas in the state of Alaska is prohibited under Alaska Statutes, Title 31, Chapter 5, Article 2, Sec. 31.005.095. -... . ~ 0_. -::O) 11/8/2001 Sc_lumbel'ger NO. 1601 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Aftn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Well Job # Log Description Date Color Sepia BL CD L-115 éhOI- IL}a- ... 21467 USIT 10/22/01 2/ L-117 dOf-/l£,7' 21465 USIT 10/02/01 2"'" -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: RECEIVED NOV 1- J 2001 AJæka..Oil.& Gas Co1l5. CommiSSion ArrchDrage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Received ~ 6Jo~ 10/30/2001 SC-_blpgIP NO. 1576 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis --,--- Well Job # Log Description Date Color Sepia BL CD L-101 ./ / 9 'i( -{)~:J. TEMPERATURE LOG ~ 10/08/01 1 1 L-117 21425 GR,CDR,DIN 1/ 09/23/01 1 L-117 21425 MD CDR-RESISTIVITY v 09/23/01 1 1 L-117 21425 TVD-CDR-RESISTIVITY v 09/23/01 1 1 L-117 21425 MD VISION DEN/NEUTRON v.. 09/23/01 1 1 L-117 -. 21425 TVD VISION DEN/NEUTRON v 09/23/01 1 1 L-117 1 21406 BEST DT v 09/25/01 2 L-117 ~ 21406 DSI ANISTROPHY (S.B.SECTION) fI" / 09/25/01 2 L-117 -- 21406 MECH PROPERTIES (S.B. SECTIONV 09/25/01 2 L-117 " 21406 ELAN (S.B. SECTION) if 09/25/01 2 L-117 ~ 21406 DSI ANISTROPHY (KUP.SECTlON) V 09/25/01 2 L-117 \ () 21406 MECH PROPERTIES (KUP. SECTION) t/" 09/25/01 2 L-117 -- 21406 ELAN (KUP. SECTION) \I 09/25/01 2 r""-""-,- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED OCT 30 2001 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Receive~ - (ß Q rv- / - I Date Delivered: Alaska Oil & GaS Cons. CommissiOn Anchorage 10/24/2001 5e_l.be,ger NO. 1562 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora --~c Well Job# Log Description Date Color Sepia BL CD S-101 é:ÀOf\-IIS 21428 RST-SIGMA'/ 09/01/01 1 1 1 L-117 ~,,'-'tb Î 21407 DSI/CMR ""- 09/25/01 1 L-117 21407 DSI a/' . 09/25/01 1 1 L-117 21407 CMR t/ . 09/25/01 1 1 -~~-- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received ~ 6. 0 ¥. ) BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2- 1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED OCT 30 2001 ~Cons. Commission Allchorage S£~lumbeIlDep NO. 1535 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Well Job# Log Description Date Color Sepia BL CD S-108 dD/-/()n 21405 SCMT v' 09/08/01 2 L-117 A()- Un; 21407 CMR ~ 09/25/01 2 L-114 - 21374 BHC,CMR / 08/13101 1 L-114 -.:::J.OJ-/3lo 21374 BHC V 08/13/01 1 1 L-114 21374 CMR .tV 08/13101 1 1 L-1 07 21420 PP,D/N, IMPULSE (PDC) v 08/27/01 1 L-107 c9. OJ - /6/ 21420 MD VISION RES v 08/27/01 1 1 L-1 07 21420 TVD VISION RES V 08/27/01 1 1 L-1 07 21420 MD VISION D/N-QUAD V 08/27/01 1 1 L-1 07 21420 TVD VISION D/N-QUAD v 08/27/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 A TIN: Sherrie Date Delivered: RECEIVED OCT 262001 AIaska.QiJ 3 Gas Cons. Commission Anchorage Receive~ [JlggpJ 10/16/2001 ~""-~. ./-~. ~ ,:- (' STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1, Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned 181 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P,O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface ; 2546' NSL, 3786' WEL, SEC. 34, T12N, R11 E, UM \, .__/f-_"), -,--t'- -', (:,1_1'- At top of productive interval ~ Ie:> - 2102' NSL, 3387' WEL, SEC. 27, T12N, R11E, UM 1 ", .:'; .' I At total depth \ ----..ß1.------- " 2238' NSL, 3272' WEL, SEC, 27, T12N, R11 E, UM -'~ ,-,c.,._~,~ --." '. 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. KBE = 77,10' ADL 028239 12, Date Spudded 13, Date T.D, Reached 14. Date Comp., Susp., or Aband. 9/13/2001 9/23/2001 10/6/2001 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9189 7056 FT 9085 6957 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, RES, DEN, NEU, CMR, MDT, USTI 2 . CASING LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT, GRADE Top BOTTOM SIZE 20" 91.5# H-40 Surface 102' 30" 9-5/8" 40# L-80 27' 3111' 12-1/4" 7" 26# L-80 25' 9169' 8-3/4" Classification of Service Well Water & Gas Injector 7. Permit Number 201-167 8. API Number 50- 029-23039-00 9. Unit or Lease Name Prudhoe Bay Unit Smi ,'" IU ~ \:),'p. , ~_.,-",."':.~. ",""--'-' .' 10. Well Number L-117 11. Field and Pool Prudhoe Bay Field / Borealis Pool (Undefined) 15, Water depth, if offshore 16. No. of Completions N/ A MSL One 20, Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2138' MD 1900' (Approx.) AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-5/8" Gun Diameter, 5 spf MD TVD 5930' - 5970' 4226' - 4253' 6013' - 6040' 4284' - 4304' 6073' - 6087' 4328' - 4338' 6142' - 6182' 4378' - 4408' 6242' - 6280' 4451' - 4479' 6514' - 6524' 4647' - 4654' 25. 26. SIZE 4-1/2", ,12.6#, L-80 x 3-1/2",9.2#, L-80 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect wI 85 Bbls of Diesel TUBING RECORD DEPTH SET (MD) 8448' PACKER SET (MD) 59051 MD TVD 27. Date First Production Not on Production Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) N/A PRODUCTION FOR TEST PERIOD Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL -BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL-BBL GAs-McF WATER-BBL OIL GRAVITy-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED OCT 2 5 2001 Alaska Oil & Gas Cons. Commission Form 10-407 Rev. 07-01-80 Su mit In Duplicate (' ( 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. Schrader Bluff M 5348' 3858' Schrader Bluff N 57831 4129' Schrader Bluff 0 5930' 4226' Colville Mudstone 6424' 4583' CM1 7601' 5551' HRZ 8254' 6171' Kalubik 8495' 6400' Base Kuparuk / Top Miluveach 9017' 6893' ~SCSIVSD OCr ;: t... 4~SkaOi/& iJ 2001 GasQ Anc/¡Q Dna. Co,n. . rage "'111'$.(1; vlOf!¡ Kuparuk C 8653' 6550' LCU / Kuparuk B 8789' 6679' Kuparuk A 89291 6811' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test, Sidewall Core Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ Title Technical Assistant Date l"{). %5-01 L-117 Well Number 201-167 Permit No. / Approval No. Prepared By Name/Number: Terrie Hubble, 564-4628 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 (OF, 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'. Form 1 0-407 Rev. 07-01-80 nR,r,'~J,^r (" L-117i Sidewall Core5 Shot: 45 ( Recovered: 44 98% Rec Sample # Depth Fm Recovery Condition Lithology Comments 1 6521 Colville No Rec lost 2 6517 Colville 11/4" Intact Sand mod consol Oil Odor 3 6513 Colville 11/4" Intact Sand mod consol Oil Odor 4 6311 OBe 11/2" Intact Coal and Sand Oil Odor 5 6276 OBd 11/2" Intact Sand mod conso! Oil Odor 6 6264 OBd 11/2" Intact Sand mod con sol Oil Odor 7 6252 OBd 11/2" Intact Sand mod consol Oil Odor 8 6243 OBd 11/2" Intact Sand mod consol Oil Odor 9 6233 Obd-FI spl 11/2" Intact Sand mod con sol Oil Odor 10 6230 OBd 11/4" Intact Sand mod con sol Oil Odor 11 6222 OBd 11/2" Intact Sand mod con sol Oil Odor 12 6157 OBc 11/4" Intact Sand mod consol Oil Odor 13 6145 OBc 1" Intact Sand and Coal Oil Odor 14 6083 OBb 11/2" Intact Sand mod consol Oil Odor 15 6078 OBb 11/4" Intact Sand mod consol Oil Odor 16 6076 OBb 11/4" Intact Sand mod consol Oil Odor 17 6040 OBa 11/2" Intact Sand mod con sol Oil Odor 18 6028 OBa 11/2" Intact Sand mod consol Oil Odor 19 6022 OBa 11/2" Intact Sand mod con sol Oil Odor 20 6019 OBa 11/2" Intact Sand mod con sol Oil Odor 21 6013 OBa 11/2" Intact Sand mod con sol Oil Odor 22 5968 OA 11/2" Intact Sand mod con sol Oil Odor 23 5961 OA-FI spl 11/2" Intact Sand mod con sol Oil Odor 24 5960 OA-FI spl 1 3/4" Intact Sand mod con sol Oil Odor 25 5951 OA 1 3/8" Intact Sand mod consol Oil Odor 26 5948 OA 1 3/8" Intact Sand mod con sol Oil Odor 27 5943 OA 1 1/4" Intact Sand mod consol Oil Odor 28 5935 OA 11/4" Intact Sand mod consol Oil Odor 29 5932 OA 11/4" Intact Sand mod con sol Oil Odor 30 5785 Nb 1" Intact Sand mod con sol Questionable oil odor 31 5766 Mc 1 1/2" Intact Sand mod con sol Questionable oil odor 32 5748 Mc 1 3/8" Intact Sand mod consol Questionable oil odor 33 5668 Mc 11/2" Intact Sand mod con sol Questionable oil odor 34 5643 Mc 1" Crumbly Sand poor consol No oil odor 35 5603 Mb2 11/4" Intact Sand mod consol Questionable oil odor 36 5589 Mb2 11/2" Intact Sand mod consol Questionable oil odor 37 5580 Mb2 11/2" Intact Sand mod consol Questionable oil odor 38 5566 Mb2 1 1/4" Intact Sand mod consol Questionable oil odor 39 5540 Mb2 11/4" Intact Sand mod consol Questionable oil odor 40 5480 Mb1 11/2" Intact Sand mod consol Questionable oil odor 41 5461 Mb1 11/2" Intact Sand mod con sol Questionable oil odor 42 5448 Mb1 1 1/4" Intact Sand mod consol Questionable oil odor 43 5428 Mb1 1" Intact Sand mod consol Questionable oil odor 44 3563 Ugnu 4A 1 3/8" Intact Sand mod consol Sli oil odor 45 3525 Ugnu 4A 11/2" Intact Sand mod consol Blk oil stain 9/18/2001 LOT 3,110.0 (ft) 2,605.0 (ft) 9.30 (ppg) Surface Pressure 500 (psi) Leak Off Pressure (BHP) 1,759 (psi) Page 1 of 1 EMW 12.99 (ppg) ---- ;.- Printed: 10/8/2001 1:35:38 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/11/2001 9/12/2001 9/13/2001 9/14/2001 9/15/2001 9/16/2001 ( ( BP AMOCO Operations Summary Report L-117 L-117 DRILL +COMPLETE NABORS NABORS 9ES 19:00 - 00:00 From - To Hours Activity Code NPT PRE 00:00 - 01 :30 01 :30 - 06:00 06:00 - 10:30 10:30 - 19:30 19:30 - 20:30 20:30 - 21 :00 21 :00 - 00:00 00:00 - 01 :30 01 :30 - 02:00 02:00 - 00:00 00:00 - 02:30 02:30 - 03:30 03:30 - 07:00 07:00 - 10:00 10:00 - 12:00 12:00 -13:00 13:00 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 09:30 09:30 - 12:00 12:00 - 13:00 13:00 -15:30 15:30 -18:30 18:30 - 21 :00 21 :00 - 00:00 00:00 - 06:00 Phase 5.00 MOB P 1.50 MOB P 4.50 BOPSUF P 4.50 DRILL P PRE SURF SURF 9.00 DRILL P SURF 1.00 DRILL 0.50 DRILL P P SURF SURF 3.00 DRILL P SURF 1.50 DRILL 0.50 DRILL 22.00 DRILL P P P SURF SURF SURF 2.50 DRILL P SURF 1.00 DRILL P SURF 3.50 DRILL 3.00 DRILL 2.00 DRILL 1.00 DRILL P P P P SURF SURF SURF SURF 9.50 DRILL P SURF 1.50 DRILL 2.50 DRILL 7.00 DRILL P P P SURF SURF SURF 2.50 DRILL 1.00 DRILL P P SURF SURF 2.50 DRILL 3.00 DRILL p P SURF SURF 2.50 DRILL 3.00 CASE P P SURF SURF 6.00 CASE P SURF Page 1 of 8 Start: 9/11/2001 Rig Release: 10/6/2001 Rig Number: Spud Date: 9/13/2001 End: 10/6/2001 Description of Operations Move Rig From Summer Maintenance Location to L-117.Spot Sub base. Spot Camp. Spot & Connect Pit Module. Torque and clamp top drive. Nipple up diverter system, all related plumbing and controls. Load pipe shed with tubulars while take on water to pits. Test pit system connections. Prep floor. Begin pick up 4" dp sgls, stand back in stds. Pick up hwdp, stand back in stds. PJSM, commence make up bha. Stand back in mast. Function, test bop diverter system. Witness test waived by AOGCC Resume make bha #1, 12 1/4 drctnl assy. Note: Rig 9-ES accepted this date 00:00 hrs MIU BHA# 1. Tag @ 102". Fill Conductor. Spud Meeting with Rig Team Directional Drill 12 1/4" Hole from 102' to 1558'. @ 1158: 600 GPM - 2040 psi. PIU = 84K SIC = 80K ROT = 80K WeB = 25 to 35K TO = 4 to 5K AST = 11.9 Hrs. ART = 4.1 Hrs. Cont drill ahead 12 1/4 hole 1558 - 1836 ft. No abnormal hole problems. ART .5 hr, AST 1. 25 hrs. Flow check, circ hi - vis sweep, slight increase cuttings return, shakers clean. Poh for bit, make up bit #2, rih motor assy. Service top drive Rih bha #2, flow check. Follow bha with 4" dp to 1747 ft, precautionary wash to btm, 1836 ft. No fill. Flow check, resume drill 12 1/4 hole 1836 - 3130 ft TD. Up 93, Dn 75, Rot 81 Press 2250, Rpm 60, Wob 35, Gpm 600 at 200 spm Art 3.1 hrs, Ast 3 hrs Survey, cond mud, 630 gpm at 2830 psi Circ I cond mud. Pump hi-vis sweep, note shakers clean. Flow check, poh wiper trip, tight hole at 2964,2787,2715, 2556, 2500,2463,2300 and 2160 ft. 30 - 35 K overpull. Pump out of hole 2160 - 930 ft. Make up bha #3, hole opener assy, rih same. Flow check, follow bha with 4" dp to 3040 ft. Precautionary wash 3040 - 3130 to btm. 5 ft fill. 20 - 30 K WOB 1820 - 2320 ft. '" Circ hole clean, pump hi-vis sweep, returns clean. Flow check, poh for 9 5/8 csg. Slight swabbing 2320 - 1870. Recip pipe this interval, swabbing eliminated. Flow check, layout bha #3. Clear floor. Flow check, make dummy run 9 5/8 csg hgr. Place csg run tools on rig floor, rig up same. MU Franks tool. Make up shoe track assy, guide shoe, float shoe, thread lock all connections to float. Check floats, follow with 9 5/8 40#, Printed: 10/8/2001 1:16:35 PM (' ( BP AMOCO Page 2 of 8 Operations Summary Report Legal Well Name: L-117 Common Well Name: L-117 Spud Date: 9/13/2001 Event Name: DRILL +COMPLETE Start: 9/11/2001 End: 1 0/6/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/16/2001 00:00 - 06:00 6.00 CASE P SURF L80 BTC csg to landing point at 3111 ft. Make up mandrel hgr. 06:00 - 11 :30 5.50 CASE P SURF Make up cmt head. Circ I stage pumps to 100% returns while recip csg. Up 145, On 100. 11:30-12:00 0.50 CASE P SURF Test cmt lines 4000 psi. Test good. 12:00 - 14:00 2.00 CEMT P SURF Commence cmt 9 5/8 csg as follows: Pump 10 bbls CW100, Drop btm plug, pump 75 bbls Mudpush XL spacer. Mix and pump 388 bb110.7 ppg ASIII Lite slurry 6 bpm Mix and pump 88 bbls 15.8 ppg G Tail slurry. Drop top plug, flush lines 10 bbls H2O. Continued reciprocation till started getting sticky(-60 bbls cement out of shoe.) Begin displace wth rig pump 219 bbls mud 12 bpm. Bump plug with 1062 psi. at 1329 hrs. Hold 10 min, no leak dn. Circ -50 bbls good cement to surface. 14:00 - 14:30 0.50 CEMT P SURF Bleed press, no back flow. 14:30 - 15:00 0.50 CEMT P SURF Rig dn csg tools, layout, clear floor. Prepare for Nipple dn. 15:00 -18:00 3.00 CEMT P SURF Nipple dn diverter system, layout same. 18:00 - 20:00 2.00 CEMT P SURF Flange up 9 5/8 I tbg hd assy. Test to 1000 psi 15 min. Test successful. 20:00 - 00:00 4.00 CEMT P SURF Nipple up bope. All related plumbing I hydraulics. Press up Koomey unit. 9/17/2001 00:00 - 06:30 6.50 BOPSUR P SURF Prepare test bope, test bope all related equip BP I AOGCC specs as follows: Rams, kill, choke lines, choke mnfld, floor valves 250/4000 psi Floor safety valves 250 I 4000 psi Annular 250 I 3500 psi Accumulator unit as per specs. All tests successful and witnessed by C Sheve AOGCC. 06:30 - 07:30 1.00 DRILL P SURF Slip I cut drlg line. 07:30 - 08:30 1.00 DRILL P SURF Service top drive 08:30 - 11 :00 2.50 DRILL P SURF Pick up 4" dp in singles. 11 :00 - 00:00 13.00 DRILL N RREP SURF Repair E Magco elect brake, dwks. 9/18/2001 00:00 - 02:30 2.50 DRILL N RREP SURF Complete repairs on drawworks brake bearing and seal replacement. 02:30 - 07:30 5.00 DRILL P SURF PJSM. Pick up drill pipe, drift, and stand back in derrick. 07:30 - 11 :30 4.00 DRILL P SURF Make up BHA #4. 11 :30 - 12:00 0.50 DRILL P SURF Pick up drill pipe and RIH. 12:00 -12:30 0.50 DRILL P SURF Perform shallow function test of MWD and mud motor. OK. 12:30 -15:30 3.00 DRILL P SURF Pick up drill pipe and RIH to 2596'. 15:30 - 16:30 1.00 DRILL P SURF Break circ. Fill pipe and lines. PT csg to 4000 psi for 30 min. OK. 16:30 - 17:30 1.00 DRILL P SURF Conduct 0-1 and stripping drills. Strip in with TIW in string. 17:30 - 18:00 0.50 DRILL P SURF POH to TIW, break out, and lay down same. Blow down choke and kill lines. 18:00 -18:30 0.50 DRILL P SURF RIH. Wash last stand. Tag FC at 3025'. 18:30 - 19:30 1.00 DRILL P PROD1 Drl. FC, shoe track, FS, and rat hole to 3130'. Tag FS at 3109'. Firm cmt in shoe track. 19:30 - 20:00 0.50 DRILL P PROD1 Drill new hole from 3130' to 3150'. 20:00 - 21 :00 1.00 DRILL P PROD1 Displace spud mud with new 9.3 ppg KCL-LSND mud. Record Printed: 10/8/2001 1:16:35 PM (" (' BP AMOCO Page 3 of 8 Operations Summary Report Legal Well Name: L-117 Common Well Name: L-117 Spud Date: 9/13/2001 Event Name: DRILL +COMPLETE Start: 9/11/2001 End: 10/6/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/18/2001 20:00 - 21 :00 1.00 DRILL P PROD1 SPR. 21 :00 - 22:00 1.00 DRILL P PROD1 POH to shoe. Conduct LOT. Closed rams and slowly pressured up to 569 psi pumping at about 0.45 bpm. Recorded Leak-off pressure at 500 psi. Calc. EMW of 12.99 ppg at csg shoe. SI and bled off to 252 psi in 15 min. Pumped in 2.1 bbls and bled back 1 bbl. 22:00 - 00:00 2.00 DRILL P PROD1 Dir. drill from 3150' to 3530'. AST = 0.5 hrs; ART = 0.5 hrs; ADT = 1 hr. 9/19/2001 00:00 - 09:00 9.00 DRILL P PROD1 Dir. drill from 3530' to 4836'. AST = 0.75 hrs. ART = 5.25 hrs. ADT = 6 hrs. 09:00 - 09:30 0.50 DRILL P PROD1 Circ. Pump hi-visc sweep. 09:30 - 17:00 7.50 DRILL P PROD1 POOH for short trip to shoe. Hole tight from 4500'. Back ream intermittant sections to 3400'. Began packing off. No returns and hole tight. Work pipe free and rotate. POH to shoe filling hole through DP. Unable to circ at shoe. Continue POH. Establish circ at 2969'. (Lost est. 120 bbls on trip out.) 17:00 -18:30 1.50 DRILL N DPRB PROD1 Circ. and condo mud at 2969'. Pump sweep. 18:30 - 19:00 0.50 DRILL P PROD1 Service top drive, blocks, and crown-o-matic. 19:00 - 00:00 5.00 DRILL P PROD1 RIH. Tight at 3180'. Wash and back ream 3418' to 3500'; 3820'-3903'; 3950'-4025'; and 4380'-4835'. 9/20/2001 00:00 - 00:30 0.50 DRILL P PROD1 Circ and pump hi-visc sweep. 00:30 - 06:30 6.00 DRILL P PROD1 Dir drill from 4836' to 5581'. 06:30 - 07:30 1.00 DRILL P PROD1 Circ and pump weighted sweep. 07:30 - 09:30 2.00 DRILL P PROD1 Flow check, OK. POOH for short trip to shoe. Started swabbing at 3450'. Back ream to 3109'. Flow check, OK. 09:30 - 10:00 0.50 DRILL P PROD1 Service top drive and blocks. 10:00 - 11 :30 1.50 DRILL P PROD1 RIH to 5489'. Hole condition good. 11:30 -12:00 0.50 DRILL P PROD1 Break circ. Fill pipe and stage pump rate up. Precautionary wash to 5581'. 12:00 - 00:00 12.00 DRILL P PROD1 Dir drill from 5581' to 6517'. Pump weighted sweeps every 300'. Some sweeps bring moderate cuttings increase to surface. 9/21/2001 00:00 - 08:30 8.50 DRILL P PROD1 Drl from 6517' to 7078'. AST = 2 hrs; ART = 4.25 hrs; ADT = 6.25 hrs. 08:30 - 10:00 1.50 DRILL P PROD1 Circ. and pump weighted sweep. Flow check, OK. Pump dry job. 10:00 - 11 :30 1.50 DRILL P PROD1 POOH for short trip. Trip out to 5350'. Few tight spots. Pulled through OK. 11:30 -12:30 1.00 DRILL P PROD1 Flow check, OK. RIH to 6985'. 12:30 - 13:00 0.50 DRILL P PROD1 Fill pipe. Break circ. Precautionary wash of last stand to bottom. No fill. 13:00 - 00:00 11.00 DRILL P PROD1 Dir. drill from 7078' to 7648'. AST = 5 hrs; ART = 4.75 hrs; ADT = 9.75 hrs. 9/22/2001 00:00 - 07:30 7.50 DRILL P PROD1 Dir. drill from 7648' to 7915'. Bringing mud wt. up to 10.3 ppg. AST = 1.5 hrs; ART = 3 hrs. 07:30 - 10:30 3.00 DRILL P PROD1 Pump sweep. Circ. and condo mud bringing to uniform mwt of 10.3 ppg. Flow check, OK. 10:30 - 11 :30 1.00 DRILL P PROD1 POOH on short trip to 6890'. Intermittant drag from 5K to 25K overpull. Flow check, OK. 11 :30 - 12:00 0.50 DRILL P PROD1 RIH to 7822'. Fill pipe and break circ. Precautionary wash last stand to TO. Hole condition good. 12:00 - 00:00 12.00 DRILL P PROD1 Dir. drill from 7915' to 8474'. AST = 0 hrs; ART = 9.75 hrs. 9/23/2001 00:00 - 15:00 15.00 DRILL P PROD1 Dir. drill from 8474' to well TO of 9189'. ART = 12.25 hrs; ADT ,/ Printed: 10/8/2001 1:16:35 PM ( ("i- I BP AMOCO Page 4 of 8 Operations Summary Report Legal Well Name: L-117 Common Well Name: L-117 Spud Date: 9/13/2001 Event Name: DRILL +COMPLETE Start: 9/11/2001 End: 10/6/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/23/2001 00:00 - 15:00 15.00 DRILL P PROD1 = 12.25 hrs. 15:00 - 16:30 1.50 DRILL P PROD1 Circ. and condo mud. Pump hi-visc sweep surface-to-surface. Hole clean. 16:30 - 00:00 7.50 DRILL P PROD1 Flow check, OK. POOH for short trip to shoe. Pulled tight between 6700' and 5900' w/15K to 75K overpull. Work pipe and wipe tight spots without pump. Pulled tight between 5100' and 4900' w/15K to 20K overpull. Pulled tight at 4850' and put pump on to back ream. Began packing off and loosing mud at 4850'. 9/24/2001 00:00 - 05:00 5.00 DRILL P PROD1 POOH, back reaming from 4900' to 4700'. Attempt to POH w/o pump but hole swabbing. POH filling hole through drill pipe. Pulled tight at 3780'. Back reamed to 3340'. Packing off and hole taking fluid. POH to shoe. Total fluid lost on trip to shoe = 188 bbls. 05:00 - 06:30 1.50 DRILL P PROD1 Flow check, well flowing back. Rate declining with time. Break circ. at shoe with full returns. Circ bottoms up at 560 gpm. Considerable filter-cake like (soft & without form) material over shakers. 06:30 - 08:00 1.50 DRILL P PROD1 POOH to BHA. Flow check, OK. 08:00 - 10:30 2.50 DRILL P PROD1 PJSM. Download MWD and remove RA sources. Lay down BHA. 10:30 - 11 :00 0.50 DRILL P PROD1 Pull wear bushing and set BOP test plug. 11 :00 - 13:30 2.50 DRILL P PROD1 Test BOPE. Test rams, choke manifold, floor valves, and kelly valves to 250 psi then 4000 psi for 10 minutes. Annular tested to 250 psi then 3500 psi for 10 minutes. Witnessing of BOP test waived by John Spaulding, AOGCC rep. 13:30 - 14:00 0.50 DRILL P PROD1 Pull test plug and run wear bushing. 14:00 - 16:00 2.00 DRILL P PROD1 Make up BHA No.5 for cleanout run. 16:00 - 18:00 2.00 DRILL P PROD1 RIH to shoe. 18:00 - 20:00 2.00 DRILL P PROD1 PJSM. Slip and cut drilling line. Service and inspect crown. Adjust drawworks brakes, linkage, and rollers. Service and inspect top drive. 20:00 - 00:00 4.00 DRILL P PROD1 RIH. String took weight at 3350'. Break circ. Ream with porcupine hole opener from 3350' to 3980' at 24:00 hrs. 9/25/2001 00:00 - 04:30 4.50 DRILL P PROD1 RIH. Ream to 4300'. RIH from 4300' to TO wlo reaming. Broke circ. every 500' to 6000', then every 1000' to TO. No fill atTD. 04:30 - 07:30 3.00 DRILL P PROD1 Circ. & condo mud. Pump lo-visc sweep followed by hi-visc sweep. Considerable cuttings with lo-visc sweep to surface. Spot lube pill for logging from TO to 5000'. Flow check, OK. 07:30 - 13:00 5.50 DRILL P PROD1 POOH. Occasional tight spots to 7900' with 5K-25K overpull. From 7900' to shoe, occasional5K-10K over pull. SLM with no correction. 13:00 -14:00 1.00 DRILL P PROD1 POH with BHA and stand back. 14:00 - 15:00 1.00 EVAL P PROD1 Rig up SWS wireline equipment. 15:00 - 21 :00 6.00 EVAL P PROD1 Run SWS Dipole Sonic/GR/Caliper log from 9156' (WLM-TD) to csg. shoe. Hole taking about 1 bbllhr while logging. 21:00-21:30 0.50 EVAL P PROD1 Rig down E-line equipment. 21 :30 - 22:00 0.50 EVAL P PROD1 PJSM for DPC logging. 22:00 - 00:00 2.00 EVAL P PROD1 Pick up SWS DPC open-hole logging tools (CMRlGRlMDT). 9/26/2001 00:00 - 01 :00 1.00 EVAL P PROD1 Pick up SWS DPC logging tools (CMRlMDT). Test, OK. 01 :00 - 02:30 1.50 EVAL P PROD1 RIH wI logging tools on DP to 3027'. Controlling running speed to 90 fpm. Printed: 10/8/2001 1 :16.35 PM (' ( - BP AMOCO Page 5 of 8 Operations Summary Report Legal Well Name: L-117 Common Well Name: L-117 Spud Date: 9/13/2001 Event Name: DRILL +COMPLETE Start: 9/11/2001 End: 1 0/6/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/26/2001 02:30 - 03:00 0.50 EVAL P PROD1 Circ. DP vol. RIU wireline sheave in derrick. 03:00 - 04:30 1.50 EVAL P PROD1 RIH. Broke circ. every 10 stands. Hole displ. vol. deviated from calc at 5919'. Flow check, hole flowing back slowly. 04:30 - 05:00 0.50 EVAL P PROD1 Circ. and pump DP vol. Flow check, OK. 05:00 - 08:00 3.00 EVAL P PROD1 RIH with a 90 fpm running speed. 08:00 - 09:30 1.50 EVAL P PROD1 Make up XO's and Cable Side Entry Sub. RIH with wireline. Pump down and latch in to DWCH. Pull test, OK. Secure cable wlCSES clamp. 09:30 - 14:00 4.50 EVAL P PROD1 RIH to 9100'. Orient CMR pad. Log at 200 fph. Ran repeat section. 14:00 - 18:00 4.00 EVAL P PROD1 Log MDT taking pressure samples. Took 15 pressure stations. 18:00 - 19:30 1.50 EVAL P PROD1 Take MDT fluid samples (1 gallon + 450 ml). 19:30 - 21 :30 2.00 EVAL P PROD1 POH to CSES. Pull wireline loose from latch and POH. LD CSES and XO's. 21 :30 - 00:00 2.50 EVAL P PROD1 POH wI DP to new CSES location. Break CÎrc. every 10 stands at 3 bpm and 200 psi. 9/27/2001 00:00 - 01 :30 1.50 EVAL P PROD1 POH to second CSES entry point. 01 :30 - 03:00 1.50 EVAL P PROD1 Make up XC's and CSES. RIH with wireline. Pump down and latch in to DWCH. Check connection. Pull test, OK. Secure CSES wireline clamp. 03:00 - 05:30 2.50 EVAL P PROD1 RIH with DP to new CMR logging section. Run repeat log. RIH to the base of new logging section. 05:30 - 11 :00 5.50 EVAL P PROD1 Log up with CMR at 200 fph. Pulled into tight spot @ 5954'. Attempt to work tools by tight spot without success. Pulling 20K over. 11:00 -15:30 4.50 EVAL P PROD1 Run MDT log for pressures, logging down. PU = 136K; SO = 93K. 15:30 - 21:00 5.50 EVAL P PROD1 Run MDT fluid sampling logging up. 21 :00 - 21 :30 0.50 EVAL N DPRB PROD1 Attempt to work tools past tight spot @ 5954' pulling 1 OK to 20 K over. Work several times without success. Pulls tight but tools will move down OK. 21 :30 - 23:00 1.50 EVAL N DPRB PROD1 RIH 130' to put circ ports at tight spot. Break circ and pump DP vol. at 3 BPM and 325 psi. SD pumping and attempt to pull past tight spot without success. 23:00 - 00:00 1.00 EVAL N DPRB PROD1 Repeat working past tight spot with pumps on at 3 BPM and 340 psi. Unable to pull through tight spot. Tools will still move down OK. 9/28/2001 00:00 - 00:30 0.50 EVAL N DPRB PROD1 Pull into tight spot at 5954' while pumping at 3 BPM. Work 90 degrees of torque down hole to reposition tools. Unable to come up. RIH back to 6186'. 00:30 - 01 :30 1.00 EVAL N DPRB PROD1 Pump 25 bbl bead pill and spot around tools at 3 BPM. 01 :30 - 02:30 1.00 EVAL N DPRB PROD1 Attempt to pull past tight spot at 5954' with no success. Inflate MDT packers in at attempt to work past tight spot. 02:30 - 04:30 2.00 EVAL N DPRB PROD1 Circ and wash at maximum recommendede rates (5.5 BPM and 800 psi) for tools with circ ports opposite tight spot. Pull up while circ and attempt to work tight spot without success. 04:30 - 05:00 0.50 EVAL N DPRB PROD1 RIH and spot 25 bbllube (10%) pill across tools. 05:00 - 06:30 1.50 EVAL N DPRB PROD1 Pull back up to tight spot at 5954'. Increase overpull on tools slowly. Tools came free at 40K overpull. 06:30 - 08:00 1.50 EVAL P PROD1 POH. Pulled tight at 5888'. Slowly increase overpull. Tools came free with 42K overpull. 08:00 - 10:00 2.00 EVAL P PROD1 Run CMR log over upper interval. Log at 200 fph. 10:00 - 11 :30 1.50 EVAL P PROD1 POH to CSES point. Break out and lay down XO's and CSES. Printed: 10/8/2001 1:16:35PM ('" (' BP AMOCO Page 6 of 8 Operations Summary Report Legal Well Name: L-117 Common Well Name: L-117 Spud Date: 9/13/2001 Event Name: DRILL +COMPLETE Start: 9/11/2001 End: 10/6/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/28/2001 11:30-16:30 5.00 EVAL P PROD1 POOH with DPC logging tools. Flow check at shoe, OK. 16:30 -19:30 3.00 EVAL P PROD1 PJSM. Break out and lay down CMRlGRlMDT DPC logging tools. All tools and packers look OK. No evidence of tool damage from tight hole. Clear tools from floor. 19:30 - 22:00 2.50 EVAL P PROD1 PJSM. Pick up and rig up SWS wireline equipment and SWC guns. Establish radio silence safety zone on Pad while handling SWC guns. 22:00 - 00:00 2.00 EVAL P PROD1 RIH with SWC guns on E-line. 9/29/2001 00:00 - 03:30 3.50 EVAL P PROD1 Correlate and shot SWC guns. POH wI SWC. PJSM when 200' from surface. Establish radio safe zone on Pad. POH to surface. Shot 45, recovered 44 (lost bottom core carrier). 03:30 - 06:00 2.50 EVAL P PROD1 Lay down and handle SWC guns. RD wireline equipment. 06:00 - 09:00 3.00 DRILL P PROD1 Pick up BHA #5 (rerun) and RIH to csg shoe. Circ. btms up. 09:00 - 09:30 0.50 DRILL P PROD1 Service top drive. 09:30 - 12:30 3.00 DRILL P PROD1 RIH to 5883'. Circ & ream from 5883' to 6000' through tight section when logging. Torque and tight at 5970'. 12:30 - 16:00 3.50 DRILL P PROD1 RIH. Tight at 6540'. Wash and ream to 7500'. RIH to 9095'. 16:00 - 20:30 4.50 DRILL P PROD1 Break circ. Stage pumps up. Wash and ream to 9189'. Condo mud. Pump lo-visc and hi-visc sweeps surface to surface. Spot lube pill for running casing. Flow check, OK. Pump dry job. 20:30 - 00:00 3.50 DRILL P PROD1 POOH to run casing. Pulled tight at 8980' and 8945'. Work through OK. Pulled tight at 8890'. Make up top drive and back ream to 8600'. Pulling tight and packing off. 9/30/2001 00:00 - 03:00 3.00 DRILL P PROD1 POOH. Pumped out of hole from 8600' to 8183' without rotating. Packing off occasionally. 03:00 - 07:30 4.50 DRILL N DPRB PROD1 RIH. Reaming from 8183' to 9189'. Weight up mud to 10.6 ppg to aid in controlling running shales. Rotating at 100 rpm with 170 spm and 2800 psi on pumps. Tight and considerable torque from 8820' to 8890'. 07:30 - 09:00 1.50 DRILL N DPRB PROD1 Circ. Pump lo-visclhi-visc sweeps. Rotate and reciprocate while circulating. 09:00 - 17:00 8.00 DRILL P PROD1 POOH. Tight to 9025'. Backreamed to 8650'. Pulled OK to 8307'. Work thru tight spot at 8307',6570', and 5950' without rotation or pumps. 15K to 60K overpull. Flow check at shoe, OK. 17:00 -18:00 1.00 DRILL P PROD1 PJSM. Lay down BHA below 4" HWDP. Porcupine holeopener and string stabilizer balled up with clay and shale. Holeopener in gauge. 18:00 -18:30 0.50 DRILL P PROD1 Clear floor and dtrain stack. 18:30 -19:00 0.50 WHSUR P COMP Pull wear bushing and make dummy run with 7" landing joint and mark. 19:00 - 20:30 1.50 BOPSUF P CaMP PJSM. Changeout rams blocks in upper rams. Install?" variables. Test door seals to 3500 psi, OK. 20:30 - 22:30 2.00 CASE P COMP Pick up 7" casing tools. Change over to long bales. Pick up Franks fill-up tool. 22:30 - 00:00 1.50 CASE P CaMP PJSM. Run 7',26#, L-80, BTC-M casing. Baker lock shoe, and float collar joints. Check floats, OK 1 0/1/2001 00:00 - 03:00 3.00 CASE P COMP Continue running 7" Csg to 9 5/8" casing shoe @ 3100'. 03:00 - 03:30 0.50 CASE P COMP Engage Franks tool & circulate 1.5 times casing capacity. 03:30 - 12:30 9.00 CASE P COMP Continue running 7" Prod. Csg. M/U Hanger and landing Jt. land casing at setting depth of 9169'. PIU = 285K SIO = 120K. 12:30 -13:00 0.50 CEMT P COMP UD Franks tool. MIU Cement head and lines. Printed: 10/8/2001 1 :16:35 PM ( (" BP AMOCO Page 7 of 8 Operations Summary Report Legal Well Name: L-117 Common Well Name: L-117 Spud Date: 9/13/2001 Event Name: DRILL +COMPLETE Start: 9/11/2001 End: 10/6/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/1/2001 13:00 - 14:00 1.00 CEMT P CaMP Break circ. & stage pumps up to 5 bpm @ 630 psi. 100% returns.CBU - sand & clay returns - no Shale!. Cleaned up good. 14:00 - 17:00 3.00 CEMT P COMP PJSM wlDowell, Crew and Svc Co. personnel. Pump 10 bbls CW100. Test Cmt lines to 4000 psi. Pump 10 bbls CW1 00. Drop Btm plug and pump 50 bbls MudPush XL viscosified spacer @ 11.2 ppg. Mix & pump 179 bbls 12 ppg CemCRETE Lite cement. Drop top plug. Switch to rig pumps and displace wI 82 bbls 9.2 ppg brine, followed by 80 bbls 9.2ppg Perf Pill, followed by 186 bbls 9.2 ppg. brine. Displace @ 5 bbm. slowing to 3 bbm for last 30 bbls. Bumped plug wI 4000 psi. Floats OK 100% Returns throughout Job. 17:00 - 18:00 1.00 CEMT P COMP RID Cmt. head & lines. Break out & LID landing Jt. 18:00 - 19:30 1.50 WHSUR P COMP M/U & run pack-off. RILDS, Test pack-off to 5000 psi. OK 19:30 - 22:30 3.00 EVAL P COMP PJSM RlU SWS Run Temp. log on E-line. No discernale TOC and no warming above 8600'. ( Test Choke manifold while logging.) POH and Rig down SWS sheave. Leave E-line run to floor. 22:30 - 00:00 1.50 BOPSU~ P CaMP pull wear bushing - Run test plug Test BOPE. 10/2/2001 00:00 - 00:30 0.50 BOPSUF P COMP Change out long bails, RIU test Jt., Run test plug. 00:30 - 03:30 3.00 BOPSUF P COMP Prepare test bope, test bope all related equip BP I AOGCC specs as follows: Rams, kill, choke lines, floor valves 250 I 4000 psi Floor safety valves 250 I 4000 psi Annular 250 I 3500 psi Accumulator unit as per specs. All tests successful and witness waived by John Spalding AOGCC 03:30 - 07:30 4.00 EVAL P COMP Rih wireline, log temperature - Some improvement. Simultaneously inject 93 bbl1 0.3 ppg mud dn 7 X 9 5/8 annulus. LOT = 12.54 ppg, 263 psi. Injection Rates & Pressures: 1 BPM @ 435,2 BPM @ 516,3 BPM @ 625, 4 BPM @ 755, 5 BPM @ 840. Final Circ press = 630 psi 07:30 - 09:00 1.50 EVAL P COMP Rehead SWS E-line for USIT tool. Simultaneously Freeze protect - inject 56 bbl dead crude I hot oil dn 7 X 9 5/8 annulus.FCP 600psi. 09:00 - 18:00 9.00 EVAL P CaMP Rih USIT, perform log, poh, lay down US IT tool. Good Cement seen @ 4000' - appears to be setting up. ODE informed - instructed to go ahead with perforating plan. PJSM with HOWCO Perforating Hands. 18:00 - 18:30 0.50 CASE P CaMP Test 7" csg to 4000 psi I 30 min. Test successful. 18:30 - 21 :00 2.50 PERF P COMP Make up perf assy, as per program. Total length 594'. 21 :00 - 00:00 3.00 PERF P CaMP RIH wI perf. assy. on 4" HWDP & DP. 10/3/2001 00:00 - 01 :00 1.00 PERF P CaMP Cont rih perf assy DPC. 01 :00 - 02:30 1.50 PERF P COMP PJSM, place Schlum equip on floor, rig up same. Perform correllation GR I CCL. Confirm depth. 4 ft correction. Rig dn Schlum, release unit. 02:30 - 03:30 1.00 PERF P CaMP Adjust depth, test lines 3000 psi. Fire guns, confirm shot with Printed: 10/8/2001 1:16:35 PM (' f ( BP AMOCO Page 8 of 8 Operations Summary Report Legal Well Name: L-117 Common Well Name: L-117 Spud Date: 9/13/2001 Event Name: DRILL +COMPLETE Start: 9/11/2001 End: 10/6/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/3/2001 02:30 - 03:30 1.00 PERF P COMP sound recorder. 03:30 - 04:00 0.50 PERF P CaMP Monitor well. No losses I gains. Circ out gun gases. Flow check. 04:00 - 06:30 2.50 PERF P COMP Poh 4" dp for scraper run. 06:30 - 07:00 0.50 PERF P COMP Circ btms up due to back flow dp. 07:00 - 08:30 1.50 PERF P COMP Flow check, poh 4" dp. 08:30 - 11 :00 2.50 PERF P COMP PJSM, clear area, layout spent guns. All shots fired, no misfire. No debris in well. 11 :00 - 13:30 2.50 CLEAN P COMP Flow check, make up 7" scraper bha #6. 13:30 - 18:00 4.50 CLEAN P CaMP Follow bha with 4" dp to 8850 ft. Losses 3 bph. 18:00 - 21:00 3.00 CLEAN P COMP Circ well clean, cont displace with clean 9.2 ppg brine. Pump wt pill. Monitor well. Dynamic losses 4 bph. 21 :00 - 00:00 3.00 CLEAN P COMP Flow check, poh 4"dp laying dn. 10/4/2001 00:00 - 03:30 3.50 CLEAN P CaMP Cont poh 4" dp laying dn. 03:30 - 04:00 0.50 CLEAN P COMP Rih 12 stds from mast. 04:00 - 05:30 1.50 CLEAN P COMP Slip I cut drlg line, service top drive. 05:30 - 08:30 3.00 CLEAN N RREP CaMP Repair dwks brake bands. 08:30 - 09:00 0.50 CLEAN P COMP Poh laying dn 4" dp. 09:00 - 10:30 1.50 CLEAN P COMP Lay dn 7" scraper bha #6. 10:30 - 22:30 12.00 RUNCO~ P COMP Make dry run with tbg hgr, record measurements. Make 4" dual pkr bha. Follow with 4112 X 3 1/2 L80, 12.6/9.2# nsct to setting depth as per program. 22:30 - 23:30 1.00 RUNCO~ P COMP Install tbg hgr. Make up Idg joint. Land hgr, run in lock dn screws. 23:30 - 00:00 0.50 RUNCO~ f' COMP Rev circ filtered corrosion inhibited brine. 10/5/2001 00:00 - 02:00 2.00 CHEM P COMP Cont reverse circ corrosion inhibitor, displace well. 02:00 - 04:30 2.50 RUNCO~ f' COMP Drop ball, press up to 2800 psi to set lower pkr. Bleed. Press to 4200 psi, to set upper pkr. Attempt hold press for tbg test. Failed test. Note communication to annulus. 04:30 - 06:30 2.00 RUNCO~ IN DFAL COMP Rig dn test equip, back out Idg jt. 06:30 - 12:00 5.50 RUNCO~ IN DFAL CaMP Place slickline equip on rig floor, rig up same, PJSM, Pu II RP shear install dummy valve. 12:00 - 14:30 2.50 RUNCO~ IN DFAL COMP Re-test tbg to 4000 psi 130 min. Bleed tbg to 500 psi, build tbg annulus to 4000 psi I 30 min. Bleed tbg and annulus. All tests successful. 14:30 - 16:30 2.00 RUNCO~ IN DFAL CaMP Rih slickline, pull dummy valve. Layout slickline equip, release unit. 16:30 - 17:00 0.50 BOPSUF P COMP Install twc, test to 2800 psi. 17:00 - 21:00 4.00 BOPSUF P CaMP Nipple dn bope I all related plumbing. 21 :00 - 00:00 3.00 BOPSUF P CaMP Nipple up prod tree, test metal seal 5000 psi. Test good. 10/6/2001 00:00 - 00:30 0.50 WHSUR P COMP Test Adaptor Flange & Tree to 5000 psi. - OK 00:30 - 01 :00 0.50 WHSUR P COMP RIU DSM Lubricator - Pull TWC 01 :00 - 03:30 2.50 CHEM P CaMP PJSM with & RIU Little Red. Test lines to 3000 psi,. Freeze Protect tubing and annulus, pump 85 bbls diesel. allow to U-Tube 03:30 - 04:30 1.00 WHSUR P COMP Install BPV. Test to 1000 psi 04:30 - 06:00 1.50 RIGD P CaMP RID Little Red, RID lubricator, Clean Pits pump cellar Secure Well RELEASE RIG @ 06:00 HRS. Printed: 10/8/2001 1:16::35 PM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field....................: L-pad, WOA Well.....................: L-117i API number...............: 50-029-23039-00 Engineer.................: Corriveau COUNTY:..................: Nabors 9ES STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 48.60 ft KB above permanent.......: N/A DF above permanent.......: 77.10 ft ----- vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 5.89 degrees [(c)2001 Anadrill IDEAL ID6_1C_10J 24-Sep-200117:37:41 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 13-Sep-01 24-Sep-01 101 0.00 ft 9189.00 ft --..~ ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2000 Magnetic date............: 12-Sep-2001 Magnetic field strength..: 1149.01 HCNT Magnetic dec (+E/W-).....: 26.24 degrees Magnetic dip.............: 80.74 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G.............. : H.............. : Dip............ : of G.. . .. . . . . . . : of H...........: of Dip.........: Criteria --------- 1002.68 mGal 1149.01 HCNT 80.74 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ,-=-- ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.24 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.24 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report Seq # -------- -------- Measured depth eft) -------- -------- 1 2 3 4 5 0.00 118.13 197.12 290.15 381.83 ------ ------ Incl angle (deg) ------ ------ 0.00 0.24 0.30 0.17 0.31 0.60 0.65 1.06 2.55 4.57 7.31 11.44 15.02 19.02 20.90 23.82 27.47 29.43 31.29 32.73 36.11 40.02 42.11 43.96 44.63 46.60 48.62 49.98 51.21 53.83 ------- ------- Azimuth angle (deg) ------- ------- 0.00 357.85 323.01 337.36 314.12 288.87 311.75 324.81 356.29 358.07 355.98 358.38 0.70 1.82 1.39 1.61 1.24 0.40 358.11 357.71 357.39 357.51 359.19 0.08 359.96 359.55 1.22 2.58 1.94 1.51 ------ ------ Course length eft) ------ ------ 0.00 118.13 78.99 93.03 91.68 92.20 93.61 82.82 99.16 92.46 92.59 93.08 94.15 89.21 97.84 94.76 93.33 92.02 94.49 91.63 93.09 92.92 94.53 92.54 93.29 93.75 94.66 92.36 93.74 94.99 [{c)2001 Anadrill IDEAL ID6_1C_I0J 6 7 8 9 10 474.03 567.64 650.46 749.62 842.08 11 12 13 14 15 934.67 1027.75 1121.90 1211.11 1308.95 16 17 18 19 20 1403.71 1497.04 1589.06 1683.55 1775.18 21 22 23 24 25 1868.27 1961.19 2055.72 2148.26 2241.55 26 27 28 29 30 2335.30 2429.96 2522.32 2616.06 2711.05 -------- -------- TVD depth ( f t) -------- -------- 0.00 118.13 197.12 290.15 381.83 474.02 567.63 650.44 749.55 841.83 933.91 1025.73 1117.36 1202.65 1294.61 1382.23 1466.36 1547.26 1628.79 1706.49 1783.27 1856.41 1927.68 1995.32 2062.09 2127.67 2191.48 2251.71 2311.21 2369.01 24-Sep-200117:37:41 -------- -------- Vertical section eft) -------- -------- 0.00 0.24 0.56 0.86 1.13 1.40 1.82 2.67 5.54 11.21 20.67 35.66 57.08 83.10 116.40 152.34 192.61 236.27 283.69 331.79 383.85 440.51 502.06 564.84 629.64 696.25 765.84 835.69 907.97 983.14 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ---------------- ---------------- 0.00 0.25 0.58 0.90 1.20 1.53 2.04 2.98 5.93 11.66 21.23 36.37 57.91 84.01 117.39 153.42 193.80 237.63 285.37 333.91 386.47 443.69 505.76 568.91 634.06 701.05 770.95 840.93 913.30 988.64 0.00 -0.01 -0.14 -0.34 -0.57 -1.21 -2.07 -2.86 -3.53 -3.79 -4.32 -5.00 -5.11 -4.51 -3.58 -2.63 -1.64 -1.02 -1.67 -3.44 -5.70 -8.24 -10.01 -10.41 -10.38 -10.68 -10.19 -7.86 -5.01 -2.74 --------------- Page --------------- Total displ (ft) At Azim (deg) --------------- --------------- 0.00 0.25 0.59 0.96 1.33 1.95 2.90 4.13 6.90 12.26 21.66 36.71 58.13 84.13 117.45 153.45 193.80 237.63 285.38 333.93 386.51 443.77 505.86 569.00 634.14 701.13 771.02 840.97 913.32 988.65 0.00 357.85 346.39 339.32 334.55 321.71 314.64 316.19 329.24 342.02 348.49 352.17 354.95 356.93 358.25 359.02 359.52 359.75 359.67 359.41 359.16 358.94 358.87 358.95 359.06 359.13 359.24 359.46 359.69 359.84 2 of 5 ----- ----- DLS (deg/ 100f) ----- ----- 0.00 0.20 0.22 0.15 0.18 0.38 0.27 0.55 1.75 2.19 2.97 4.46 3.84 4.50 1.93 3.08 3.91 2.17 2.32 1.59 3.64 4.21 2.50 2.10 0.72 2.12 2.50 1.85 1.41 2.78 ----- ----- Srvy tool type ----- ----- TIP IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA ------ ------ Tool qual type ------ ------ --.- --, ANADRILL SCHLUMBERGER Survey Report Seq # -------- -------- Measured depth (it) -------- -------- 31 32 33 34 35 2804.07 2897.09 2990.48 3068.69 3131.88 ------ ------ Incl angle (deg) ------ ------ 53.71 54.86 53.94 52.68 52.99 53.43 55.92 55.76 56.21 54.82 53.93 53.17 53.42 53.24 54.40 58.03 59.11 59.22 58.56 58.35 57.74 57.47 56.77 56.23 55.80 55.55 55.33 55.58 54.68 53.07 ------- ------- Azimuth angle (deg) ------- ------- 1.38 2.35 1.86 1.71 3.32 2.63 1.31 1.34 1.39 0.43 0.03 0.63 359.57 359.44 359.78 0.01 359.74 359.89 359.88 359.99 359.71 0.22 0.18 359.69 359.85 359.78 359.91 0.08 0.50 0.85 ------ ------ Course length (it) ------ ------ 93.02 93.02 93.39 78.21 63.19 32.64 94.01 92.72 85.93 101.02 93.58 93.56 93.50 92.13 90.20 96.77 88.92 95.28 94.45 91.59 94.96 93.65 93.40 91.44 93.79 93.39 92.70 92.64 93.99 94.38 [(c)2001 Anadrill IDEAL ID6_1C_10J 36 37 38 39 40 3164.52 3258.53 3351.25 3437.18 3538.20 41 42 43 44 45 3631.78 3725.34 3818.84 3910.97 4001.17 46 47 48 49 50 4097.94 4186.86 4282.14 4376.59 4468.18 51 52 53 54 55 4563.14 4656.79 4750.19 4841.63 4935.42 56 57 58 59 60 5028.81 5121.51 5214.15 5308.14 5402.52 -------- -------- TVD depth (it) -------- -------- 2423.99 2478.29 2532.65 2579.38 2617.56 2637.10 2691.46 2743.52 2791.59 2848.79 2903.30 2958.88 3014.77 3069.79 3123.03 3176.84 3223.20 3272.04 3320.84 3368.76 3419.02 3469.19 3519.89 3570.36 3622.79 3675.45 3728.04 3780.57 3834.30 3889.94 24-Sep-200117:37:41 -------- -------- Vertical section (ft) -------- -------- 1057.95 1133.29 1209.06 1271.61 1321.88 1347.98 1424.49 1500.97 1571.98 1654.93 1730.62 1805.53 1880.10 1953.54 2025.91 2105.88 2181.34 2262.69 2343.11 2420.75 2500.87 2579.52 2657.57 2733.41 2810.74 2887.43 2963.35 3039.25 3115.99 3191.91 ---------------- --------------- Page --------------- ---------------- Displ +N/S- (ft) Displ +E/W- ( f t) Total displ (ft) At Azim (deg) ---------------- --------------- --------------- ---------------- 1063.65 1139.14 1215.02 1277.70 1328.01 1354.11 1430.76 1507.46 1578.67 1661.92 1737.99 1813.24 1888.20 1962.09 2034.90 2115.31 2191.19 2273.00 2353.86 2431.92 2512.49 2591.56 2670.00 2746.25 2824.02 2901.14 2977.48 3053.79 3130.90 3207.13 -0.85 1.61 4.40 6.36 8.57 9.92 12.55 14.32 16.02 17.35 17.65 18.08 18.21 17.58 17.08 16.94 16.77 16.51 16.35 16.26 16.05 16.00 16.27 16.19 15.87 15.62 15.42 15.41 15.80 16.70 1063.66 1139.14 1215.03 1277.72 1328.04 1354.15 1430.81 1507.53 1578.75 1662.01 1738.08 1813.33 1888.29 1962.17 2034.97 2115.38 2191.25 2273.06 2353.92 2431.97 2512.54 2591.61 2670.05 2746.30 2824.06 2901.19 2977.52 3053.83 3130.94 3207.17 359.95 0.08 0.21 0.29 0.37 0.42 0.50 0.54 0.58 0.60 0.58 0.57 0.55 0.51 0.48 0.46 0.44 0.42 0.40 0.38 0.37 0.35 0.35 0.34 0.32 0.31 0.30 0.29 0.29 0.30 3 of 5 ----- ----- DLS (deg/ 100f) ----- ----- 0.17 1.50 1.07 1.62 2.09 2.16 2.89 0.17 0.53 1.58 1.01 0.96 0.95 0.23 1. 32 3.76 1.24 0.18 0.70 0.25 0.69 0.54 0.75 0.74 0.48 0.27 0.26 0.31 1.03 1.73 ----- ----- Srvy tool type ----- ----- IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA ------ ------ Tool qual type ------ ------ .-.. '-'-., ANADRILL SCHLUMBERGER Survey Report Seq # -------- -------- Measured depth (ft) -------- -------- 61 62 63 64 65 5496.42 5588.99 5682.43 5776.62 5870.52 ------ ------ Incl angle (deg) ------ ------ 51.41 50.42 50.27 50.62 49.33 45.34 42.60 43.00 43.35 43.80 44.46 44.62 43.07 41.37 38.99 36.71 34.95 32.94 30.08 27.28 25.14 23.52 22.65 19.65 17.49 17.66 18.23 18.19 18.36 18.48 ------- ------- Azimuth angle (deg) ------- ------- 1.20 2.37 2.09 1.95 1.89 2.79 4.20 3.95 3.53 3.63 3.36 1.94 3.22 4.57 5.77 9.00 11.02 13.82 15.89 15.86 20.49 26.19 31.59 35.72 41.60 40.79 41.55 41.64 41.48 40.87 ------ ------ Course length (ft) ------ ------ 93.90 92.57 93.44 94.19 93.90 92.98 93.67 92.95 93.74 92.76 94.64 94.13 92.99 92.25 94.42 94.38 91.01 95.98 93.48 91.95 93.11 92.65 92.92 93.65 93.73 92.48 90.18 94.33 93.41 93.41 [(c)2001 Anadrill IDEAL ID6_1C_10J 66 67 68 69 70 5963.50 6057.17 6150.12 6243.86 6336.62 71 72 73 74 75 6431.26 6525.39 6618.38 6710.63 6805.05 76 77 78 79 80 6899.43 6990.44 7086.42 7179.90 7271.85 81 82 83 84 85 7364.96 7457.61 7550.53 7644.18 7737.91 86 87 88 89 90 7830.39 7920.57 8014.90 8108.31 8201.72 -------- -------- TVD depth (ft) -------- -------- 3947.44 4005.80 4065.43 4125.42 4185.80 4248.81 4316.22 4384.42 4452.78 4519.98 4587.91 4655.00 4722.07 4790.38 4862.52 4937.04 5010.83 5090.46 5170.15 5250.81 5334.35 5418.78 5504.27 5591.60 5680.46 5768.62 5854.41 5944.02 6032.72 6121.34 24-Sep-200117:37:41 -------- -------- vertical section (ft) -------- -------- 3265.88 3337.54 3409.33 3481.79 3553.52 3621.74 3686.71 3749.83 3813.93 3877.81 3943.65 4009.57 4073.87 4135.82 4196.72 4254.60 4307.73 4360.96 4409.22 4452.67 4492.84 4529.23 4562.74 4592.66 4617.77 4640.56 4663.24 4687.18 4710.97 4735.07 ================ Displ +N/S- (ft) Displ +E/W- (ft) ================ 3281.35 3353.17 3425.05 3497.63 3569.49 3637.79 3702.69 3765.69 3829.69 3893.50 3959.28 4025.23 4089.57 4151.42 4212.08 4269.50 4321.96 4374.29 4421.51 4463.95 4503.01 4538.04 4569.93 4598.08 4621.41 4642.42 4663.34 4685.38 4707.30 4729.52 18.02 20.25 23.05 25.61 28.02 30.80 34.74 39.23 43.41 47.40 51.42 54.47 57.36 61.56 67.03 74.43 83.67 95.16 107.65 119.72 132.48 147.53 165.09 183.73 202.29 220.68 238.97 258.54 277.97 297.40 --------------- Page --------------- Total displ (ft) At Azim (deg) --------------- --------------- 3281.40 3353.23 3425.13 3497.72 3569.60 3637.92 3702.86 3765.89 3829.94 3893.79 3959.61 4025.60 4089.98 4151.87 4212.61 4270.15 4322.77 4375.32 4422.82 4465.56 4504.96 4540.44 4572.91 4601.75 4625.84 4647.67 4669.46 4692.51 4715.50 4738.86 0.31 0.35 0.39 0.42 0.45 0.49 0.54 0.60 0.65 0.70 0.74 0.78 0.80 0.85 0.91 1.00 1.11 1.25 1.39 1.54 1.69 1.86 2.07 2.29 2.51 2.72 2.93 3.16 3.38 3.60 4 of 5 ----- ----- DLS (deg/ 100f) ----- ----- 1. 79 1.45 0.28 0.39 1.37 4.35 3.11 0.47 0.48 0.49 0.73 1.07 1.92 2.09 2.65 3.20 2.33 2.65 3.27 3.05 3.18 3.08 2.46 3.57 3.05 0.32 0.68 0.05 0.19 0.24 ----- ----- Srvy tool type ----- ----- IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA ------ ------ Tool qual type ------ ------ -~~ ---" ANADRILL SCHLUMBERGER Survey Report Seq # 96 97 98 99 100 -------- -------- Measured depth (ft) -------- -------- 91 92 93 94 95 8295.62 8388.83 8481.88 8576.58 8669.10 ------ ------ Incl angle (deg) ------ ------ 18.17 18.18 17.99 18.00 18.64 19.33 19.65 19.73 19.67 19.54 Final Projected Survey: 101 9189.00 19.36 8762.73 8856.01 8950.83 9042.28 9104.44 ------- ------- Azimuth angle (deg) ------- ------- 41.05 41.20 41.33 40.36 40.45 40.33 39.45 40.26 39.82 40.00 40.25 ------ ------ Course length (ft) ------ ------ 93.90 93.21 93.05 94.70 92.52 93.63 93.28 94.82 91.45 62.16 84.56 [(c)2001 Anadrill IDEAL ID6_1C_10J -------- -------- TVD depth (ft) -------- -------- 6210.48 6299.04 6387.49 6477.56 6565.39 6653.93 6741.86 6831.14 6917.23 6975.79 7055.52 24-Sep-200117:37:41 -------- -------- Vertical section (ft) -------- -------- 4759.23 4782.98 4806.53 4830.51 4854.47 4879.57 4905.37 4931.87 4957.38 4974.67 4997.95 ---------------- ---------------- Displ +N/S- (ft) Displ +E/W- (ft) ================ 4751.81 4773.71 4795.42 4817.55 4839.70 4862.90 4886.78 4911.30 4934.90 4950.90 4972.43 316.75 335.88 354.93 374.06 392.91 412.65 432.60 453.08 472.91 486.29 504.44 --------------- Page --------------- Total displ ( f t) At Azim (deg) --------------- --------------- 4762.36 4785.51 4808.54 4832.05 4855.62 4880.38 4905.89 4932.16 4957.51 4974.73 4997.95 3.81 4.02 4.23 4.44 4.64 4.85 5.06 5.27 5.47 5.61 5.79 5 of 5 ----- ----- DLS (deg/ 100f) ----- ----- 0.34 0.05 0.21 0.32 0.69 0.74 0.47 0.30 0.17 0.23 0.23 ----- ----- Srvy tool type ----- ----- IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA IFR_MSA Projected ? ------ ------ Tool qual type ------ ------ -- ....=- - 10/15/2001 Schlumbel'ger NO. 1526 Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis c- Well Job# Log Description Date BL Sepia CD -" --- L-117 l~nl-f{O 7 TEMPERATURE LOG 10/01/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 RECEIVED OCT 1 6 2001 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Received ~ c.J) 0 L{' -- Date Delivered: Alaska OU & Gas Cons. Commission Anchorage TREE = ( 4-1/16M CIW WElLHE"AD= F~ ACruA IDR= KB. ElEV = 77.1' BF. ElEV = 54.8' KOP= 1000' Wax Angle = 59 @ 4282' 1:8 bin M) = I:8tl.Jn ND = 8800' SS 9-5/a-M CSG, 40#, L-80, ID = 8.835M 3111' Minimu m ID = 2.813" @ 8377' 3-112" HES X NIPPLE 4-1/2M 12.6#X20'PUPJTW/RA TAG 5862' 4-1/2" TBG, 12.6#, L-80, .0152 bpf. ID = 3.958" 5962' 3-112" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992M H 6374' FERFORA TIONSUMMARY REF LOG: SWS œRlRESISTIV ITY LOG of 0 9fl 3'{) 1 ANGLE A T TOP PERF: 46 @ 5930' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz Ot\TE 4-SJ8" 5 5930 - 5970 0 10103,U1 4-SI8" S 6013 - 6040 0 1 OIO3,U 1 4-518" 5 6073 - 6087 0 HV03,U 1 4-518" S 6142-6182 0 1 0I03,U 1 4-SI8" 5 6242 - 6280 0 10103,U1 4-SI8" 5 6S14 - 6524 0 10103,U1 3-112" TTP, 9.2#, 13CR, .0087 bpf, ID = 2.992" H 8447' 7"26#X20'PUPJTW/RA TAG 8598' 7"26#X20'PUPJTW/RA TAG 890~ 9085' 7" CSG, 26#, L-80, D = 6.276" 9169' L-117 1019' 2138' (" 5892' 5904' 5905' 5963' 6374' 8366' 8367' 8377' Ø389' 8390' 8394' 8415' 8436' 8448' DATE REVBY COMM:NlS DATE REV BY COMMENTS 10/06/01 CWKA K ORIGINAL COMPLETION SAFETY NOTES: GLM'S @ STA #1 & #2 ARE 3-1/2" X 1-1/2" MMG-WS, WHICH ARE W A TERFLOOO ~ I'oI)RElS. 9-518" TAM PORT COLLAR 4-1/2- ÆS X NlP,ID = 3.813- GAS LIFT MANrRELS ST M) N D DEV 1Y PE V LV L lCH PORT DA TE 4 4715 3424 õl KBG-2 OFEN BK-5 0 1 OIOS,{) 1 3 5845 4092 49 KBG-2 OJ BK-5 0 1 OIO6,{) 1 2 5973 4179 45 MM3-W OJ RKP 0 1 OIO6,{) 1 1 6354 4455 44 MM3-W OJ RKP 0 1 0/06,{) 1 -i 4-1/2"HE5XNP,ID=3.813" -f 5" LHACMEX 4-1fl" NSCT XO,ID =3.560" I 7" X 4-1/2" BKR PREMER PKR, D = 3.875" -I 4-112" X 3-1/2" TBG XO, ID = 2.937" I -i 3-1/2"X4-1/2"TBGXO,ID=2.992" I 4-1fl" TBG, 12.6#, L-80, D =3.958" I 4-1/2" X 3-1/2" TBG XO, ID = 2.937" 3-112" HES X NP, 10 = 2.813- -i 3-112" X 4-1/2" TBG XO, ID = 2.992" -I 7"" X 4-1/2" BKR S-3 A<R, ID = 3.8 7S" I 4-1/2" X 3-1/2" TBG XO, ID = 2.937" -J 3-1/2" HES X NP, ID = 2.813" I -i 3-112" HES X NP, ID = 2.813" I 3-1/2" WLEG, ID= 2.875" I, ElMDrTNOT LOGGED I RECEIVED OCT 1 8 2001 Alaska Oil & Gas Cons. Commission Anchorage POIUf ItJeIlfl""RIii I'~I~ WELL: L-117 PERMIT No: 201-1670 API No: 50-029-23039.QO 2546' NSL & 3786'Wa, SEC34, T12N, R11E SP exploration (Alaska) (\ (J Date: 10-12-2001 Transmittal Number:92283 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Date 09-22-2001 10-01-2001 09-24-2001 Media itle HARDCOPY/DISKETTE SURVEY REPORT; HARDCOPY/DISKETTE SURVEY REPORT; HARDCOPY/DISKETTE SURVEY REPORT; ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center AOGCC Attn: Lisa Weepie RECE IVED OCT 1 5 2001 Alaska Oil & Gas Cons, Commission Anchorage Phillips Alaska Inc. Attn: Sandy Lemke Exxon Mobil Production Co. Attn: Susan Nisbet Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 \: fi ~1f~1fŒ lill~ !A\~!A\~[K(!A\ t AlAS IiA. 0 IL AND GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 W. TH AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit L-117 BP Exploration (Alaska) Inc. Permit No: 201-167 Sur Loc: 2546' NSL, 3786' WEL, SEC. 34, T12N, RIlE, UM Btmhole Loc. 2123' NSL, 3392' WEL, SEC. 27, T12N, 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. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit L-117. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test 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, ~ .1\;1., H-eu/~ Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this I~ day of August, 2001. jj c/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ( STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~(~ ,f)7f o/h II Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Neil Magee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that, tho/!e. t th , oregoi~~ is, true and c~ect to the best of my knowledge Signed Dan Stone'~jl4.1 ~«<C'"---S I~ÐS Title Senior Drilling Engineer Date 8 - b'-o~ ", ,:'",' ",""";',':',.:;.""":.:,':r",:..,,.;,;:".",'; <" !:/',' ;::::,:I:./::i;:::,:::::::.i::;~ê)mltt~$~i,QÓ,;Ø~i:.t)~ly¡:;::,.::;"",',:,:(:,,": :',':::"',':",:,:::: "':,.,,': .':.:"".','...,.';:.: ':' ,': "':""" Permit Number API Number ~ Approval Date See cover letter Z 0 ) - / If(; ;> 50- o.z.. '9- Z :;f' ð 3' 7 for other requirements Conditions of Approval: Samples Required D Yes IS No Mud Log Required DYes 1!SI No Hydrogen Sulfide Measures DYes B No Directional Survey Required ~ Yes D No Required Working Pressure for BOPE ,P 2K D 3K ~K D 5K D 10K D 15K D 3.5K psi for CTU Other: ~ \\~ c..C(~-\f\... ~ c.~t\.\\'~ \~~~ ORIGiNAl ~ ~u-=r I rv I I ^ - by order of Approved By 9 U . y-, 'DI"'1~ ~ ~ t\ I Commissioner the commission Form 10-401 Rev. 12-01-85 '\.,;,.j 1\ U t , 'J f\ L 1 a. Type of work aD Drill 0 Redrill 0 Re-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 2546' NSL, 3786' WEL, SEC. 34, T12N, R11 E, UM At top of productive interval 2095' NSL, 3401' WEL, SEC. 27, T12N, R11E, UM At total depth 2123' NSL, 3392' WEL, SEC. 27, T12N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL047447, 3156' MD NWE1-02is44'awayat1375'MD 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casing Program Specifications C¡ize , 1_'- -. . . . . ,,- ..... - - ,. . - nol~ L":l~IIIU C ;nllnllnn 30" 20" 91.5# H-40 Weld 12-1/4" 9-5/8" 40# L-80 BTC 8-3/4" 7" 26# L-80 BTC-M 1 b. Type of well I ønnth 80' 3002' 9215' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical feet feet feet feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Perforation depth: measured true vertical 20. Attachments 0 Exploratory 0 Stratigraphic Test 0 Development Oil aD Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Plan RKB = 76.2' Prudhoe Bay Field / Borealis 6. Property Designation Pool (Undefined) ADL 028239 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number L-117 9. Approximate spud date 09/10/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 9214' MD /7064' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 56 Maximum surface 2818 psig, At total depth (TVD) 6422' / 3460 psig Setting Depth T( 10 ... MD TVD MD Surface Surface 110' Surface Surface 3002' Surface Surface 9215' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 TVD 110' 2577' 7063' r of- (i"ll"h IrI~ st;:¡nA rJ;:¡t;:¡) 260 sx Arctic Set (Approx.) 85 sx AS Lite. 268 sx Class 'G' 388 sx LiteCrete Plugs (measured) Junk (measured) Cemented MD TVD RECEIVED AUG 0 7 2001 Alaska Oil & Gas Cons. Commission Anchorage Date Submit In Triplicate ( ( I Well Name: I L-117 Drill and Complete Plan Summary l.!ïPe of Well (service I producer I injector}~ector Surface Location: X = 583,127.24' Y = 5,978,267.69' As-Built 25461 FSL (27321 FNL), 37861 FEL (14921 FWL), Sec. 34, T12N, R11 E Target Location: X = 583,449.92' Y = 5,983,100.01' Too Kuparuk 20951 FSL (31831 FNL), 34011 FEL (18781 FWL), Sec. 27, T12N, R11E Bottom Hole Location: X = 583,458.06' Y = 5,983,127.59' 21231 FSL (31561 FNL), 33921 FEL (18861 FWL), Sec. 27, T12N, R11 E I AFE Number: 15M4029 1 Estimated Start Date: 19/10/2001 I I MD: 19214' 1 TVD: 17064' 1 l£!!9:J Nabors 9ES l.Qperatin~s to complete: 121.6 1 BF/MS: 126.9' 1 1 RKB: 176.2' I Well Desi~(conventional, slim hole, etc.}.J Ultra Slimhole (Iongstring) ~ective: 1 Kuparuk Formation Mud Program: 12 %"" Surface Hole 0-3002' : Initial below Permafrost interval TD 8.5 - 8.6 9.0 - 9.5 9.6 max Fresh Water Surface Hole Mud API FL PH mls/30min 15 - 20 <10 <10 8.5 - 9.5 8.5 - 9.5 8.5- 9.5 8 3,4" Intermediate I Production Hole (3002' - 9215'): Fresh Water LSND Interval Density Tau 0 YP PV pH API HTHP (ppg) Filtrate Fi Itrate Upper 9.3 4-7 20-25 8-12 8.5-9.5 4-6 Interval Top of HRl 10.8 5-8 20-25 8-14 8.5-9.5 3-5 < 1 0 by to TO HRl L-117 Permit to Drill Page 1 { "- ( Di rectional: Ver. Sperry WP-03 KOP: 300' Maximum Hole Angle: 55.5° at 2554' MD Close Approach Wells: All wells pass major risk criteria. NWE 1-01 - 247' @ 247' MD NWE 1-02 - 44' @ 1375' MD L01 - 200' @ 325' MD Lo I ntermed i ate/Prod ucti on Hole Drilling: MWD / GR Open Hole: None Cased Hole: None Drilling: MWD / GR / Res / Den / Neut Open Hole: CMR/MDT, SWC's, Cuttings Cased Hole: US IT cement evaluation Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, PPG SV5 1465 SV4 1610 Base Permafrost 1775 SV3 1950 SV2 2120 SV1 2440 UG4A 2730 UG3 3063 UG1 3525 Ma 3795 Na 3950 Oa 4135 Hydrocarbon bearing 2000 psi, 9.3 ppg Obf Base 4550 CM2 Colville 5097 CM1 Colville 5675 THRZ 6125 BHRZ (Kalubik) 6310 K-1 6365 TKUP 6442 Hydrocarbon Bearing 34260psi, 10.3 ppg Kuparuk C 6446 LCU (Kuparuk B) Kuparuk A TMLV (Miluveach) 6872 TD Criteria 150' below Miluveach top L-117 Permit to Drill Page 2 (' { C 8 IT b8 p aSln51j u Ing rogram: Hole Csg! Wt/Ft Grade Conn Length Top 8tm Size Tbg 0.0. MDrrVD MDrrVD bkb 30" 20" 91.5# H-40 WLD 80' GL 110/110 12 %" 9 5/8" 40# L-80 BTC 3002' GL 3002'/2577' 8 3.4" 7" 26# L-80 BTC-m 9215' GL 9215'/7063' Tubing 4 Y2"1I 12.6# L-80 NSCT 8400' GL 8400'/6253' Inte rit Testin : Test Point Depth Surface Casing Shoe 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 1843' of annulus in the permafrost @ 250% excess and 329' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOG: To surface Tail: Based on 750' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOG: At -2252' MD Total Cement Volume: Lead 375 bbl 121 03ft 1474 sks of Dowell ARTIGSET Lite at 10.7 and 4.44 dIsk. 56 bbl I 314 ft I 268 sks of Dowell Premium 'G' at 15.8 and 1 .17 disk. Tail Casin Size 7" Production Longstring Basis: Lead: Based on TOG 500' above top of Schrader formation + 30% excess + 80' shoe track volume. Lead TOG: 4550' MD Total Cement Volume: Lead Tail 165 bbls I 925 ft I 388 sks of Dowell LiteGrete at 12.0 and 2.39 dIsk. NA L-117 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: 3460 psi @ 6422' TVDss - Kuparuk Sands 2818 psi @ surface (based on BHP and a full column of gas from TO @ 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-117 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 lor 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 3002' MD I 2577' TVD. An intermediate wiper trip to surface will be performed prior to exiting the Permafrost. 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. NO 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 to +1-100' above the HRl, ensure mud is in condition to 10.8 ppg and perform short trip as needed. During this time hold the Pre-Reservoir meeting highlighting kick tolerance and detection. 9. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for logging and POOH. (Make wiper trip as dictated by hole conditions.) 10. Perform open hole logging program. Run CMR and MDT logs DPC. E-line SWC's. 11. Condition hole for running 7" 26# longstring with HO run. POOH laying down excess 4" DP. 12. Run and cement the 7" production casing as required from TO to 500' above the Schrader Bluff if indicated oil bearing otherwise 500' above uppermost oil bearing reservoir. Displace the casing with seawater during cementing operations and freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on Morning Report. 13. Test the casing to 4000 psi for 30 minutes. 14. RU Schlumberger and run USIT log on e-line from the 7" landing collar to the 9 5/8" surface shoe. 15. Test the casing to 4000 psi for 30 min. 16. 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. Shear RP valve and install TWC. Test below to 2800 psi. 17. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 18. Freeze protect the well to -2200' TVD. Allow diesel to U-tube from the annulus to tubing and equalize at 2000' TVD. 19. Rig down and move off. Estimated Spud Date: 9-10-2001 L-117 Permit to Drill Page 5 ( ( L-117 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies );;> L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ~ The closest surface locations are wells on the SW quadrant of the pad. No surface shut-in's will be required as these wells are not on production. ~ Due to the elevated landing ring height on L-Pad, the BOP stack will need to be run with a l' double flange adapter spool on bottom (13-5/8" x11") Reference RPs .:. Operational Specifics . .....-.-- ,,--- .. --",....... .",-.." , -,,-.. '" .._..__...._.._,..........,.,-""..."~'" Job 2: Drilling Surface Hole Hazards and Contingencies );;> No faults are expected to be penetrated by L-117 in the surface interval. );;> There are no close approach issues in the surface hole. All wells pass major risk criteria. The closest existing well, L-110, 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 TO 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 Baroid mud recommendation );;> 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 .:. Operational Specifics . ..._--,-,--_...~ , '" " ..-.." ...---..., "L , ...........-,.--..."'.-.------."-".--...,..,, Job 3: Install Surface Casing Hazards and Contingencies );;> 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. Based on cement returns on prior wells on L-Pad this may be increased to ensure cement to surface. As a contingency, a 9- 5/8" port collar will be positioned at :1:1 OOO'MD to allow a secondary circulation as required. L-117 Permit to Drill Page 6 {' ( » "Annular Pumping Away" criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV-1 sand. Reference RPs .:. Operational Specifics . Job 7: Drillin Intermediate I Production Hole Hazards and Contingencies » L-117i will cross a fault in the base of Ugnu and Top Schrader @-3785'TVDss. The estimated throw of the E-W fault is approximately 165'. The well will be -550 when crossing the fault. Loss circulation is not considered to be a risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. » KICK TOLERANCE: In the worst case scenario of 1 0.3 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.2 ppg at the surface casing shoe, 10.8 ppg mud in the hole the kick tolerance is 25 bbls. LOT's of 13.5ppg (L-01) 15.4ppg (L-116) and 13.7ppg (L-110) have been recorded in offset L-Pad wells. An accurate lOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 12.2 ppg. » A majority of the l-Pad development 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. » There are no "close approach" issues with the production hole interval of L-117. Reference RPs .:. Operational Specifics . "."."~,~.,....."""..._.,,........._.._...,,_._...,,--_... ..... . -,.", , -- "..-.~ ~---.."--_.._"--_......-...._.._'....,,'-,,.....,,-"'._,_..,.._....,,'.,,"'"....' Job 8: Log Prod~ction Hole Hazards and Contingencies » Ensure the hole is in very good condition to avoid a stuck tool string » If logging time is excessive or hole conditions dictate, perform an intermediate clean out run between logging runs. Reference RPs .:. Operational Specifics . "....---.--.." ,.- , -- ...-..."'.--......,-..., L-117 Permit to Drill Page 7 ( ( 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, (10.3 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: Rldn ComPletion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operational Specifics . ---.........-..."...--........,-..".....-..-,.......-...,-..."'.----.-..-..---.........-,.....- ~,.._-_.._"_........,._....."-".~...."...,""'~..",...",....."".,,-,-,,,,.,..."",.......""""'""",, Job 13: ND/NU/Release Rig Hazards and Contingencies . ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Operational Specifics . ,-,_._,-"., ,,'w, ,...w, ,--_. ~ -",-" -..- ---, ..-" ,..,,'. "'......--.-----, L-117 Permit to Drill Page 8 ;g lun_n 8 3000- =. J-c-_u ..c:: õ.. '" (:) <ii .:! 1:: '" > '" '" '-0 I- COMPANY DETAILS BP Amoco a1lculotioo Method: Minimum am"""" Error System: ISCWSA ScanMelbod: T!3\'C)'Iind.:rNorth Enor Surfuce: Elliplical -;- Casing Wamin>< Method: Rules Based -1500- I- -j 15°" ~... I-~--_u I~-_nn 4500- 600 750v- 1 -fA- ! ( 0 ;----'-- , .,,::. -- I u Start Dir 1°/100' : 300' MD, 300'TVD Start Dir 2°/100' : 700' MD, 699.68'TVD REFERENCE INFORMA nON SURVEY PROGRAM Depth Fm Depth To Sum:ylPIao Co-onlina'" (NŒ) Referenœ: Well Centre: L-117, True North VeJtica) (IVD) Referenœ: Temp Plan e!e\"tioo 77 77.00 Section (VS) Refurenœ: Slot - N-l (O_OON,O_OOE) Measured Depth Reference: Temp Plao ele",tioo 77 77_00 Calculation Method: Minimum C"",.rure 77.00 1300-00 PliUIœŒ L-117 WPO3 VI 1300_00 9214_98 PIaoœd: L-117 WPO3 VI All TVD depths are ssTVD plus 77' for RKBE. Start Dir 2.5°/1 00' : 1000' MD, 997.3'TVD "" 2000 .. ,-, IT., End Dir : 1800' MD, 1745.25' TVD Start Dir 5°/100': 2036.43' MD, 1950'TVD End Dir : 2554.55' MD, 2325.99' TVD , 5i'ii~VJ~4A- -- ";.: - "',;~'._, T T'--'~ , '" -', 1500 NO LUGl <" 'u StartPir2°/l00':5262.08'MD,3843.72'TVD -, - "'-, 6000 ~""-- '. c'"' "'- ------- ~-c-G~p (('olville Shales) '\ ' 7000. ~<!I (n . End Dir : 8365.36' MD, 6218.75' TVD _/ End Dir j: 9074.' unn,_n .LmRz _n__- --Kalubik _.=~~~u ~ MD,6923.95" I VI) 1 . Start Dir 2°/100': 8668-66' MD, 6519'TVD 9:1:;0 !tr.~TML V (Miluveach) . -~"- --- Total Depth: 9214.98' MD, 7063.95' TVD 3000 I 6000 -;"1)0 Vertical Section at 4.53° [I 500ft/in] See MD 77.00 300.00 700.00 1000.00 1800-00 2036.43 2554.55 5262.08 6021.68 8365.36 8668.66 9074.98 9214.98 I 2 3 4 5 6 7 8 9 10 II 12 13 I 7500 N:uœ ~N'-S L-111 Name IN L I L-ïI8-inI. Inc 0.00 0.00 4.00 10.00 30.00 30.00 55.91 55.91 55.00 8.13 8-13 0.00 0.00 Tool CB-DYRO.SS MWD 33.52 +FJ-W 130_80 1VD 6519_00 4828_88 4271.00 3647_72 Azi TVD 77.00 300.00 699.68 997.30 1745.25 1950.00 2325.99 3843.72 4277.00 6218.75 6519.00 6923.95 7063.95 0.00 0.00 358.65 358.65 358.65 358.65 358.65 358.65 17.09 17.09 17.09 197.09 197.09 I 9000 Nmlúng 59711267.69 ~N'-S SECTIO l'lan: 1.-117 WI'O) (1..I17man 1..117) C,,-atC<! Uy: Ken Allen Chcch..J: Dale: 7/1 6/2(XI I Dale: Re"¡CWl..J: Date: WELL DETAILS EaslÍUB I,'ngitld: Slot L"tilloJo: 583127.24 7rr2r02-153N 149"19'.IOJI8W N-! TARGET DETAILS .FJ.W Ntorthing E"-<~ng Shape 376JO 13.16 58.1449,92 n,l;!.; (H:uh",: .100) 58.1O'J9_94 Poiot 598J(XJ.OI 5981915,00 N DETAILS +FJ-W DLeg TFace VSec Target 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 -0.33 1.00 358.65 13.88 -1.19 2.00 0.00 50.24 -7.60 2.50 0.00 321.03 -10.39 0.00 0.00 438.63 -18.63 5.00 0.00 786.83 -71.36 0.00 0.00 3017.21 13.16 2.00 98.64 3637.37 L-118 int. 363.70 2.00 -180.00 4801.67 376.30 0.00 0.00 4843.52 IN_L_I 384.75 2.00 180.00 4871.59 384.75 0.00 197.09 4871.59 +N/-S ì~- 0.00 0.00 13.95 50.49 322.64 440.82 790.77 3032.31 3647.72 4787.90 4828.88 4856.38 4856.38 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I 1542.00 1571.50 SV5 2 1687.00 1733.29 SV4 3 1852.00 1923.27 Base Pennafrost 4 2027.00 2127.53 SV3 5 2197.00 2350.19 SV2 6 2517.00 2895.29 SVI 7 2847,00 3483,99 UG4A 8 3202.00 4117.29 UG3 9 3727.00 5053.86 UGI 10 4767.00 6751.72 CM3 (Colville Shales) II 6203.00 8349.45 THRZ 12 6399.00 8547.45 Kalubik 13 6519.00 8668.66 TKUP 14 6912.00 9063.03 TMLV (Miluveach) CASING DETAILS I '~~-- No. TVD Size MD 3002.33 9214.97 Name I 2 2577.00 7063.94 95/8" 7" 9.625 7.000 I 10500 600 500 400 :s ~ g 300 <=> ;- :g 5 ~ :c :; 0 en 200 100 COMPANY DETAILS REFERENCE INFO¡u,fAllON BP Amoco Co-ordinate (NIE) Ref""""",: Well Centre: L-111, True North Vertical (IVD) Refen:nœ: T<mp Plan ele".tioo 17 71.00 Section (VS) Ref<retJ<:Ç: Slot - N-) (O.lXJN,O.ooE) Measured Deplh Reference: T<mp Plane1e\~tioo 17 17_00 Calculation Method: Minimum CUI'~,"", Calculatioo Method: Minimum am~ture Error System: ISCWSA SeaoMethod: Toa\"CyIin<I....-North Error Surlàce: Elliplical + Casing Wamíng Method; Rules Based 95% eonf. 7" ¡ IN_L,J /a~,v Total Depth: 9214.98' MD, 7063.95' TVD - -.-.-.. ,----.--,;<,----~'\.---.....---..,/, '.... ../......'..[....;"./.'..~.\.' ,/".. '; " End Dir : 9074.98' MD, 6923.95' TVD ,! f Y- " ¡ , , I \,.'¥\......\...,". \)/) Start Dir 2°/100' : 8668.66' MD, 65 I 9'TVD : . ----V' :. EndDir:8365.36'MD,6218.75'TVD 15000, 18 into 4oo0ý I . nrv SJIDiDi<2"!10W , 52~.08' MD, 384372TVll 35000 : .,. --100°It::::!')t¡ut--~ir5°/100' : 2036.43' MD, 1950'TVD : [~ End Dlr : 1800' MD, 1745.25' TVD ¡SOO .-------omm 1000 Start Dlr 2.5"/100' : 1000' MD, 997.3'TVD --$00--- : < Sfart.Dir--2°1I 00' : 700' MD, 699.68'TVD Start pir 1"/100' : 300' MD, 300'TVD ...... -1000 0 1000 West(-)/East(+) [IOOOft/in] 2000 SURVEY PROGRAM Deplh Fm Depth T" SUI"eylPlan l'Ian: 1.-117 WPO3(L-11711'Ian 1.-117) Tool Date: 71161l00 I Crl'alOO By: Ken Nil" Checkl-d: 71.00 1300_00 P!anœd: L-111 \VPO3 VI 1300.00 9214_98 Planœd: L-111 WPO3 VI CB-GYRO-SS MWD Dale: Re\.il"Wl-d: Date: WELL DETAILS N:nœ +NI-S "Ef-W Nor1hing Ea'linp '-"lit,.)" tooBit,.)" Sin' L-111 33.52 130.80 597!i261.69 5~_112724 70"21'02.15JN 149^1'Y1031~W N-) TARGET IJETAII_~ Name IN L I L-ïI8-j¡¡t 'EI-W l'a>ting Shape TVD +N!-S N<,rthínB 5983100.01 5981915.00 581449.92 ('ud, (1!a<11U<: 100) 58_1D99.94 I'"inl 6519.00 4828.88 4277.00 3647_72 176JO 13.16 SECTION DETAILS See MD Ine Azi TVD +N/-S +Ef-W Dug TFaee VSee Target F----~. I 71.00 0.00 0-00 77.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 700.00 4.00 358.65 699.68 13.95 -0.33 1.00 358.65 13.88 4 1000.00 10.00 358.65 997.30 50.49 -I.] 9 2.00 0.00 50.24 5 1800.00 30.00 358.65 1745.25 322_64 -7.60 2.50 0.00 321.03 6 2036.43 30.00 358.65 1950.00 440.82 -10.39 0.00 0.00 438.63 7 2554.55 55.91 358.65 2325.99 790- 77 -18.63 5.00 0.00 786.83 8 5262.08 55.91 358.65 3843.72 3032.3] -71.36 0.00 0.00 3017.21 9 6021.68 55.00 17.09 4277.00 3647.72 13.]6 2.00 98.64 3637.37 L-] 18 int. 10 8365.36 8.13 17.09 6218.75 4787.90 363.70 2.00 -180.00 4801.67 II 8668.66 8.13 17.09 6519.00 4828.88 376.30 0.00 0.00 4843.52 IN_L_l 12 9074.98 0.00 197_09 6923-95 4856.38 384.75 2.00 180.00 4871.59 13 9214.98 0.00 197.09 7063.95 4856.38 384.75 0.00 197.09 4871.59 All TVD depths are ssTVD plus 77' for RKBE. CASING DETAILS No. TVD MD Name Size I 2577.00 3002.33 95/8" 9.625 2 7063.94 92] 4.97 7" 7.000 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation I ] 542.00 1571.50 SV5 2 ]687.00 ] 733-29 SV4 3 ] 852.00 ] 923.27 Base Pennafrost 4 2027.00 2127.53 SV3 5 2197.00 2350.19 SV2 6 25] 7.00 2895.29 SV] 7 2847.00 3483.99 UG4A 8 3202.00 4117.29 UG3 9 3727.00 5053.86 UOI 10 4767.00 6751.72 CM3 (Colville Shales) 11 6203.00 8349.45 THRZ 12 6399.00 8547.45 Kalubik 13 6519.00 8668.66 TKUP 14 69]2.00 9063.03 TMLV (Miluveaeh) .-< ~. / 3000 -( ( BP Amoco Planning Report - Geographic r-- - ----- ------- i Company: BP Amoco Date: 7/16/2001 Time: 13:58:59 I : Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: L-117, True North ! Site: PB L Pad Vertical (fVD) Reference: Temp Plan elevation 77 77.0 i Well: L-117 Section (VS) Reference: Well (0.00N,O.00E,4.53Azi) I Wellpath: Plan L-117 Plan: L-117 WP03 '--------- -- - --- -------- - - ..----- -------....- -..- - ---------- ------ -- -..-- - ---- -- - - ---- ---- --- -- - - - -- ------ - ---- - - -- ---- - ---- ------- --- - - --------- - - - -- -- - --- -- ------ ------- ---- -- ----- - -- --- -------- - --- ------ - - --- ------- -- - - ----- ----- - Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Geo Datum: NAD27 (Clarke 1866) Coordinate System: ¡ Sys Datum: Mean Sea Level Geomagnetic Model: L______-------------- --------------------------- -- ------------------------------------ ___on - - ------ ----------- - -- ---------- ------- --------- ---- -- -------- ---- ~--------------~--------------------------------- ----- I Site: PB L Pad ¡ I UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5978232.73 ft 582996.83 ft ---~------ Page: 1 Alaska, Zone 4 Well Centre BGGM2001 ------------------------------------------- _. ------------ - , Latitude: 70 21 1.823 N Longitude: 149 19 34.141 W North Reference: True Grid Convergence: 0.63 deg ------------------------------- ------------------------ ----------------------------------------------- -- --------------------------------------------------.----------- -- n- _n ------------ N-J Well: L-117 Surface Position: +N/-S 33.52 ft Northing: 5978267.69 ft +E/-W 130.80 ft Easting: 583127.24 ft Position Uncertainty: 0.00 ft Reference Point: +N/-S 33.52 ft Northing: 5978267.69 ft +E/-W 130.80 ft Easting: 583127.24 ft Measured Depth: 77.00 ft Vertical Depth: 77.00 ft ------------------------------------- - _. ------- --- Slot Name: Latitude: Longitude: 70 21 2.153 N 149 19 30.318 W 70 21 2.153 N 149 19 30.318 W 0.00 deg 0.00 deg Latitude: Longitude: Inclination: Azimuth: Wellpath: Plan L-117 ----------------------------------------------------------------------------------------------- ------------- --- - ----- ---------------------- -------- ------------------ ---- ----------------------______n___---__------------------- --------------------------- ----- -- -- --- -------------------------- ----------------------------------- ------------------------------- ---------------- --- ----------------- ------------------------- - --- ----- - --------- -------------------------- Current Datum: Magnetic Data: Field Strength: Vertical Section: Temp Plan elevation 77 12/26/2000 57446 nT Depth From (TVD) ft - ------------------- ------------------ - --- -- - 0.00 Height 77.00 ft +N/-S ft ----------------------------------- --- --- 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft - ---- ----______n______----------- ------ 0.00 Well Ref. Point 0.00 ft Mean Sea Level 26.47 deg 80.74 deg Direction deg ---------------------------------------- 4.53 ---------------__--___n__- --------------------- - --- Plan: L-117 WP03 n______-- ---------------------- ------------------------------------------------ ----------- --_--____n_____n______------______n--_____--------------------"------------------__-_-n__- ------------------______n - ---------- ------..------------ ------_.- ----------------------------..------------------------------- ------------- -------"----------------------..--------.._------_.._------------------------------------------- ---- -------------------------------- ---------------------------------------.. ----------------..---------..---------------------------------------------- - n_____- ------ Principal: Yes ---- -------------------------------- ------------------------------------------------------------------ -------------------"----------------"------------------------------- --..------- --- --..---------.. -- ----------------"------------------------------------------- --------------- ------ ---- - --- -------------------------------------------------, Plan Section Information Date Composed: Version: Tied-to: 7/16/2001 1 From Well Ref. Point ,-- - --- ------------ --..- --- .......... ------------- -- -- - --..-----....---- ----- --------------..--------..--..-..- -- - -- - ---- --- -------------.. ..---- ---..- -------- ----------- -- - -----------..--.. --------------- ---- ---- - ------ - --..--- -..- - - .. -_..-------- - -----..-- - - -----------.. - - - - n- ---- - - ----..---------- - - -- -.. -- ---- ---- ------..---- - -"---"_____n___- --- ------ - ------ - -----.. !l\1D Ind . Azim TVD +N/-S +E/~W... DLS J3üild . Turn . TFO Target ftdeg . de!;) ft ftft deg/100ft degl100ft deg/100ftdeg . -------------------------..---------- ---- -------------..-.. ---------------- ------ ------------..-------- ------"------------------------------------_____n_____------------- ---------------------------- ---- -- -- --------- -- -------------- -----..---------..-------------------------------- ----------- --------------------------------- --------______n______--------------------------------....------------------------------------- - --..--------------- 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0_00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 4.00 358.65 699.68 13.95 -0.33 1.00 1.00 0.00 358.65 1000.00 10.00 358.65 997.30 50.49 -1.19 2.00 2.00 0.00 0.00 1800_00 30_00 358.65 1745.25 322.64 -7.60 2.50 2.50 0.00 0.00 2036.43 30.00 358.65 1950.00 440.82 -10.39 0.00 0.00 0.00 0.00 2554.55 55.91 358.65 2325.99 790.77 -18.63 5.00 5.00 0.00 0.00 5262.08 55.91 358.65 3843.72 3032.31 -71.36 0.00 0.00 0.00 0.00 6021.68 55.00 17.09 4277.00 3647.72 13.16 2.00 -0.12 2.43 98.64 L-118 int. 8365.36 8.13 17.09 6218.75 4787.90 363.70 2.00 -2.00 0.00 -180.00 8668.66 8.13 17.09 6519.00 4828.88 376.30 0.00 0.00 0.00 0.00 IN_L_1 9074.98 0.00 197.09 6923.95 4856.38 384.75 2.00 -2.00 0.00 180.00 9214.98 0.00 197.09 7063.95 4856.38 384.75 0.00 0.00 0.00 197.09 ------------------- ------ --------- -- -- --- -- --------- ------------ - -------- -------- ------ - - -------------- -- - - - -- -- -- - - ------ - --- ---- ----- - ------- --- Section 1: Start --------,------c------- ------ ---------------------------------- --------------~ MD . Incl Azim TVD+N/-S+E/-W VS DLS Build Turn TFO ftdeg degft . ft ft ft deg/100ftdeg/100ft deg/1O0ftdeg . . . ---------..------ - - ------ -- --------..---- ---------- --------------------- -.... -- --------- -- -------------- - -- - ----- ---- ---------- --------- ---- ------------------- ---- ---- ------- -------------------- ---- ----- ----..-..-- ----------- -- -------------- -------- --- -- ----- - ------- 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0_00 0_00 0.00 ------------- -----------------------------------------------..-------- ------------------------ ---------------------- ------------ ------------------------------------~---------- ( ( BP Amoco Planning Report - Geographic i-C~~pany: BP Amoco -'-----------D;;~:---'7Î1-6/2-001--'----'--Ti~~:- 13:58:59------'------------- Pa;~----;----- Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: L-117, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: L-117 Section (VS) Reference: Well (0.00N.0.00E,4.53Azi) l__~!_~!~a t ~~ I a n__,==.~!!_--------_._---------------- ------.--------.---.! I~ n: .-------- -.----. _._------__~.~_1_~_.~--~~-~--_._--------- ---- --.-.-------.-- ------.--.--...-J Section 2: Start [~:::~ ~- ~~._~; f==::.;~~-=:. ::-- -- _:~ -. - ._--~:~~ -.-.-.- - ---+ F) ~::_-_:=:~s---=-~; ~!~ ~ d ~~~f ~~- ~ ~~_?_~ :_--_:;~-=-=_::== ::=:::::_:: j . 400.00 1.00 358.65 399.99 0.87 -0.02 0.87 1.00 1.00 0.00 0.00 i 500.00 2.00 358.65 499.96 3.49 -0.08 3.47 1.00 1.00 0.00 0.00 I 600.00 3.00 358.65 599.86 7.85 -0.18 7.81 1.00 1.00 0.00 0.00 ; 700.00 4.00 358.65 699.68 13.95 -0.33 13.88 1.00 1.00 0.00 0.00 " ._-------_._~-_..-_._---------- ,,---------------------------------------- --------- - -------------------------.- - .--- Section 3: Start I--~D--'~~~ -- ~~';;-----~~D----+N~S------'-+E/ft W -----'~~-------:~~1S~~ft d~~~~dOOft -- ~~~~-'------TJ:~------'--------------I ,.---,.---...---- --'-'---- ,.--.---... --.--" - -- -----.- --.- --------... .-.- ----.- - --' ----- .-----...--...- ,---,-_._------ --,-, ----.....--.- "-.-----.--- --.- -- --,...-- -- -------------------- ,--.-- -.,-., -- "'--'--- -------.--.----.-- -.---- ,---- --- -- ------..--- -. ----------- -- --------'----'-----' - ,-... .,- ---- ------.---- ,- --, --._- ,----.-----.-- 800.00 6.00 358.65 799.29 22.66 -0.54 22.55 2.00 2.00 0.00 0.00 900.00 8.00 358.65 898.54 34.85 -0.82 34.67 2.00 2.00 0.00 0.00 1000.00 10.00 358.65 997.30 50.49 -1.19 50.24 2.00 2.00 0.00 0.00 ----------- - --..----.---.----- -.------------------.----,---------- ---.- ---------- ---------------- ------------ ------------- -' .,--- -----,------ ---- - -- ---- ----- --- '-----'--'---'------'- ---------...---- - -------- -------------------------- _m______-------------------.------- Section 4: Start ...-- ------------------- :\'11) Incl Azim TVD ft deg deg ft - --- --- _.. 1100.00 12.50 358.65 1095.37 1200.00 15.00 358.65 1192.50 1300.00 17.50 358.65 1288.49 1400.00 20.00 358.65 1383.18 1500.00 22.50 358.65 1476.37 1600.00 25.00 358.65 1567.90 1700.00 27.50 358.65 1657.58 1800.00 30.00 358.65 1745.25 +:'\/-S ft 69.99 93.75 121.73 153.86 190.09 230.35 274.56 322.64 +E/-W ft -1.65 -2.21 -2.87 -3.63 -4.48 -5.43 -6.47 -7.60 VS ft 69.64 93.29 121.12 153.09 189. 14 229.20 273.19 321.03 DLS Build Turn deg/100ft deg/100ft deg/10Oft 2.50 2.50 0.00 2.50 2.50 0.00 2.50 2.50 0.00 2.50 2.50 0.00 2.50 2.50 0.00 2.50 2.50 0.00 2.50 2.50 0.00 2.50 2.50 0.00 TFO deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ----- --------------------------.--------.--,----..-------------------" --,-------------.---------,-------.-.-------- ----------_._-,-- ---------- -----.---.--------,------ --- -------------.--- -_.-----------------.._---------- ------- .--------" ._------------------,--- --------------- - - .--- Section 5: Start - ---- - -- --- ------ ---- - --_.. --_..--- _.. - - ----- ---- - ..- ---- '-ID Incl Azim T\'D +:\'/-S +E/-\V ft deg deg ft ft ft 1900.00 30.00 358.65 1831.85 372.63 -8.78 2000.00 30.00 358.65 1918.46 422.61 -9.96 2036.43 30.00 358.65 1950.00 440.82 -10.39 - -- ----- - ---- - -- - -- - - - -- _..- \'8 DLS Build Turn TFO ft deg/100ft deg/100ft deg/100ft deg 370.77 0.00 0.00 0.00 0.00 420.51 0.00 0.00 0.00 0.00 438.62 0.00 0.00 0.00 0.00 Section 6: Start ---_u_---------------- -----------------------.--------------------.-,----------.-------..---,----------.--------.--,-----..------- -----.--------.-...---------,---------------------------,---,--------_.- ,,------------ ---------------- -- -- --,-----------,---.._--.- - ----.--_.,---- ,-- - ------- --------,--._---,.._-----------------------------------_.._-",-------------_-m---_____---",----------,-----,--,,----------------------------------.--------'-----------..-------------.-__"'___m______---"'---------------------------------- -------------------------"'------------------------'-'----------..---------,--.-.--..------.-------------------------..---------------------------------.-------,------------------- -----.._---------_..------,-- - - MD ft 2100.00 2200.00 2300.00 2400.00 2500.00 2554.55 Incl Azjm . TVD +N/-S .. deg. deg ft . ft - - - - - -- ------ ------------ -.---------------- 33.18 358.65 2004.14 474.11 38.18 358.65 2085.35 532.40 43.18 358.65 2161.16 597.54 48.18 358.65 2231.01 669.04 53.18 358.65 2294.36 746.35 55.91 358.65 2325.99 790.77 +E/-W VS DLS Build Turn TFO -~!_--~~-,--,--_~~;~!2?Oft- dê~~ 00!~~egI1 O~ft --~~--'-'----~--~------'- -11.17 471.74 5.00 5.00 0.00 0.00 -12.55 529.74 5.00 5.00 0.00 0.00 -14.08 594.56 5.00 5.00 0.00 0.00 -15.77 665.70 5.00 5.00 0.00 0.00 -17.59 742.63 5.00 5.00 0.00 0.00 -18.63 786.83 5.01 5.01 0.00 0.00 ---------- ---------------,--- ._---~-------_._---------_.._----- ------ --,--- ------------------------- ---- .-- ----- Section 7: Start ----'-------,---:-----c-----------"'---------------------c--------------:-------:---------~--~--_._----~------":'---------_.__._------------~~-----'--'~------:-------:------l i .. MDlncl AzjmTVD. +N/-S +E/~WVS, ,.. DLS. ,BuildTurnTFO . . :--.- -. ._-_!~--- -. -. ----- -----. ..~:g,----~- -.- ---"-- -~~~, ,-.- - ..- ----- --- ---...- --.-'-. -_!~ ---- ,-~_._--- ---._c-_.---- .~...: --,_. -- -----------. _...__!~ --------. -~-,.. -.- ~:,f:_____--_... --- _.: __?:~!I9~~__~:_~~-~.~-~~~ ~~_:~~- ~~.~~_. __m~- ...'. ~_:.~-- ------. --- ----- .-.- -- ----- ------ c_---.--.-. -.-. . : 2600.00 55.91 358.65 2351.46 828.40 -19.52 824.27 0.00 0.00 0.00 0.00 2700.00 55.91 358.65 2407.51 911.19 -21.47 906.65 0.00 0.00 0.00 0.00 2800.00 55.91 358.65 2463.56 993.98 -23.42 989.03 0.00 0.00 0.00 0.00 2900.00 55.91 358.65 2519.61 1076.78 -25.37 1071.41 0.00 0.00 0.00 0.00 3000.00 55.91 358.65 2575.66 1159.57 -27.32 1153.79 0.00 0.00 0.00 0.00 3100.00 55.91 358.65 2631.71 1242.36 -29.27 1236.17 0.00 0.00 0.00 0.00 3200.00 55.91 358.65 2687.76 1325.16 -31.22 1318.55 0.00 0.00 0.00 0.00 3300.00 55.91 358.65 2743.81 1407.95 -33.17 1400.93 0.00 0.00 0.00 0.00 3400.00 55.91 358.65 2799.86 1490.74 -35.13 1483.31 0.00 0.00 0.00 0.00 3500.00 55.91 358.65 2855.91 1573.53 -37.08 1565.70 0.00 0.00 0.00 0.00 3600.00 55.91 358.65 2911.96 1656.33 -39.03 1648.08 0.00 0.00 0.00 0.00 3700.00 55.91 358.65 2968.01 1739.12 -40.98 1730.46 0.00 0.00 0.00 0.00 3800.00 55.91 358.65 3024.06 1821.91 -42.93 1812.84 0.00 0.00 0.00 0.00 3900.00 55.91 358.65 3080.11 1904.71 -44.88 1895.22 0.00 0.00 0.00 0.00 4000.00 55.91 358.65 3136.16 1987.50 -46.83 1977.60 0.00 0.00 0.00 0.00 --_._---------------,-----------,- -,-'--'-----"---------------------------'-----,,------'-----,- ----- ------------------,---------------------------------- - -_._------,---------,,-- ------- -- ---------------------'-'--'--'----------------------'--------.----- ( ( BP Amoco Planning Report - Geographic r-- - ¡ Company: BP Amoco Date: 7/16/2001 Time: 13:58:59 ! Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: L-117, True North I Site: PB L Pad Vertical (fVD) Reference: Temp Plan elevation 77 77.0 : Well: L-117 Section (VS) Reference: Well (0.00N.0.00E,4.53Azi) L_._~~~~? a t h: .__~_I~~~--~- ~L -------- ------_.._-----_._----_._-----------------_.~ I a.~:___._-------------_._-------_._-----~= ~~- W~? 3 -------'------------'-------'-- ----- .-----.---.--------J - ---- ----- - - -- ------ - - ---. Page: 3 Section 7: Start ,------------------ ------ ---- ----------- ----------------------~--------------_._--- -.---------- ------------------------- -------'-------------, I MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO I I ' i ft deg deg ft ft ft ft deg/10OO deg/10OO deg/10OO deg : c.--. - ------- -- - - -- ---- - ---- -- -. -------- - ---- ---- ---- - - -.----.- - --- -. .----.---.- -- .-- -----" -.--- -- ---- m"__- ---- - -.. ----.-.- - -- ------- - -- - -- -- ------.- - .--- .-.- -- --- -----------'-'- --- -...--.----.-- - ---- -----.-..- --- - - - - - -- -- ---- . --- '--- -' - - --- ----' '4100.00 55.91 358.65 3192.21 2070.29 -48.78 2059.98 0.00 0.00 0.00 0.00 ' ,4200.00 55.91 358.65 3248.26 2153.08 -50.73 2142.36 0.00 0.00 0.00 0.00 ,4300.00 55.91 358.65 3304.31 2235.88 -52.69 2224.74 0.00 0.00 0.00 0.00 I 4400.00 55.91 358.65 3360.35 2318.67 -54.64 2307.12 0.00 0.00 0.00 0.00 I 4500.00 55.91 358.65 3416.40 2401.46 -56.59 2389.50 0.00 0.00 0.00 0.00 I 4600.00 55.91 358.65 3472.45 2484.26 -58.54 2471.88 0.00 0.00 0.00 0.00 ¡ 4700.00 55.91 358.65 3528.50 2567.05 -60.49 2554.26 0.00 0.00 0.00 0.00 4800.00 55.91 358.65 3584.55 2649.84 -62.44 2636.64 0.00 0.00 0.00 0.00 4900.00 55.91 358.65 3640.60 2732.63 -64.39 2719.02 0.00 0.00 0.00 0.00 5000.00 55.91 358.65 3696.65 2815.43 -66.34 2801.40 0.00 0.00 0.00 0.00 5100.00 55.91 358.65 3752.70 2898.22 -68.29 2883.78 0.00 0.00 0.00 0.00 5200.00 55.91 358.65 3808.75 2981.01 -70.25 2966.16 0.00 0.00 0.00 0.00 5262.08 55.91 358.65 3843.72 3032.31 -71.36 3017.21 0.00 0.00 0.00 0.00 ------------------------ ------------- --- ------------ ----------------'- ---- ------ - ----- ----- - ----------- ------ -- ----- -------- Section 8: Start m _m... - - - - ---- ------ ---- - - -- - _m___-- ----.. -- --- ---------- - ----- - - ------ --- --- --, - - ------------------- - _____m______-------- __m______------------ -_.----- \ID Incl Azim TVD +:\/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/10OO deg 5300.00 55.80 359.56 3865.00 3063.69 - 71.85 3048.45 2.00 -0.29 2.39 98.64 5400.00 55.54 1.96 3921.41 3146.25 -70.76 3130.84 2.00 -0.26 2.40 98.13 5500.00 55.33 4.37 3978.15 3228.46 -66.22 3213.16 2.00 -0.21 2.42 96.78 5600.00 55.16 6.80 4035.16 3310.22 -58.22 3295.29 2.00 -0.16 2.43 95.41 5700.00 55.05 9.23 4092.37 3391.43 -46.79 3377.15 2.00 -0.12 2.43 94.02 5800.00 54.98 11.67 4149.72 3471.99 -31.93 3458.63 2.00 -0.07 2.44 92.63 5900.00 54.96 14.12 4207.12 3551.80 -13.65 3539.64 2.00 -0.02 2.44 91.23 6000.00 54.99 16.56 4264.52 3630.77 8.00 3620.06 2.00 0.03 2.44 89.83 6021.68 55.00 17.09 4277.00 3647.72 13.16 3637.37 2.01 0.04 2.45 89.06 ---------..----------- - ----- ---------------- -- ----_-----m______- ---------- ____n______---------------- ---------- ------ --------- ------------------------------------ ----- ---------------------- - - --------- ------------- --------------------- ---------- -..-- -------- Section 9: Start m --- -- '--M D - --- --- - -- - - --I ~ -~ï" ,-- - - ..' - - ___.om ¡; i ~- -- --.. -....-.. - - ,- ---.. - T :V'-i): --- - -, - - - ... --¡Nt:s -- - - -..... - - - .. - - + Ii" ï ~ w- - - -- - - - --.- - -- m -': vs""" - .. - - --- - -_... - --r; L -S - - - m.- ---li~-iï d - - .....__m- -i ~;-~- - --- - - - - --- TFO--- --- ---_... ---.-._.-...., ..._- -- - - - -- - , - - - - - --1 ft -- deg deg ft - ft ftft deg/100ft deg/100ft deg/10OO deg I 1----,----- --- -- --- .----- -- ---_C_-----------~---_.._----'- --_._------ ---m___- ------..-- __00__--_- --------- ----' -------------------' ---- ---------_u -- - -- -- ------- - -.- -- ------. 6100.00 53.43 17.09 4322.79 3708.45 31.83 3699.38 2.00 -2.00 0.00 -180.00 6200.00 51.43 17.09 4383.76 3784.21 55.12 3776.75 2.00 -2.00 0.00 -180.00 6300.00 49.43 17.09 4447.45 3857.89 77.78 3851.99 2.00 -2.00 0,00 -180.00 6400.00 47.43 17.09 4513.80 3929.40 99.76 3925.01 2.00 -2.00 0.00 -180.00 6500.00 45.43 17.09 4582.71 3998.66 121.06 3995.73 2.00 -2.00 0.00 -180.00 6600.00 43.43 17.09 4654.12 4065.57 141.63 4064.06 2.00 -2.00 0.00 -180.00 6700.00 41.43 17.09 4727.92 4130.06 161.46 4129.92 2.00 -2.00 0.00 -180.00 6800.00 39.43 17.09 4804.03 4192.05 180.51 4193.22 2.00 -2.00 0.00 -180.00 6900.00 37.43 17.09 4882.36 4251.46 198.78 4253.89 2.00 -2.00 0.00 -180.00 7000.00 35.43 17.09 4962.81 4308.23 216.23 4311.85 2.00 -2.00 0.00 -180.00 7100.00 33.43 17.09 5045.28 4362.27 232.85 4367.04 2.00 -2.00 0.00 -180.00 7200.00 31.43 17.09 5129.68 4413.53 248.61 4419.39 2.00 -2.00 0.00 -180.00 7300.00 29.43 17.09 5215.90 4461.95 263.49 4468.82 2.00 -2.00 0.00 -180.00 7400.00 27.43 17.09 5303.83 4507.46 277.49 4515.30 2.00 -2.00 0.00 -180.00 7500.00 25.43 17.09 5393.37 4550.01 290.57 4558.74 2.00 -2.00 0.00 -180.00 7600.00 23.43 17.09 5484.41 4589.54 302.72 4599.12 2.00 -2.00 0.00 -180.00 7700.00 21.43 17.09 5576.84 4626.02 313.94 4636.36 2.00 -2.00 0.00 -180.00 7800.00 19.43 17.09 5670.54 4659.39 324.20 4670.44 2.00 -2.00 0.00 -180.00 7900.00 17.43 17.09 5765.41 4689.61 333.49 4701.30 2.00 -2.00 0.00 -180.00 8000.00 15.43 17.09 5861.32 4716.65 341.80 4728.91 2.00 -2.00 0.00 -180.00 8100.00 13.43 17.09 5958.15 4740.47 349.13 4753.24 2.00 -2.00 0.00 -180.00 8200.00 11.43 17.09 6055.80 4761.05 355.45 4774.25 2.00 -2.00 0.00 -180.00 8300.00 9.43 17.09 6154.15 4778.36 360.77 4791.93 2.00 -2.00 0.00 -180.00 8365.36 8.13 17.09 6218.75 4787.90 363.70 4801.67 1.99 -1.99 0.00 180.00 ------------------------------ - -------------------------------------------- -------------______00______---------- Section 10: Start ------- ------------ -- ------ ---------:-- -- --------- ---------,----- --- -- --------------...,------------------------------------------ --------------- ------ ----------------------------------------------,-------------------------- -- ------------------c-- --------------------~----_.. ----- -------- -------cl MD Incl Azim TVD ' +N/-S +E/~W VS DLS Build, Turn TFO ft deg deg ft ft ft ft deg/100ft deg/tOOft deg/10OO ' deg ! ----.----.----------.----------------.--------- --- .---- .------------------------------------______m______------_h______---- ------------_____m__.___-------.---------,-------- ---- --------------.------ -------------- -------__m_- -.-------------------------- ------------------------------..--------------.-----------------------'---------------------:-___--'__h_'____----------------- !--------------------------------:---.---------------------- 8400.00 8.13 17.09 6253.04 4792.58 365.14 4806.45 0.00 0.00 0.00 180.00 8500.00 8.13 17.09 6352.04 4806.10 369.30 4820.25 0.00 0.00 0.00 180.00 8600.00 8.13 17.09 6451.03 4819.62 373.45 4834.06 0.00 0.00 0.00 180.00 ---- ------------------------- --------- ---------------- --------- ------------ --------------------------------------------------- -------------------------- -------------______n___- ------------------------------------------------------------ ------------- ----.----------------------------------- -------- '~ ( BP Amoco Planning Report - Geographic i ------------- ----- -------------- -- -- : Company: BP Amoco Date: 7/16/2001 Time: 13:58:59 i Field: Prudhoe Bay Co-ordinate{NE) Reference: Well: L-117. True North ; Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 ! Well: L-117 Section (VS) Reference: Well (0.00N.0.00E,4.53Azi) , : Wellpath: Plan L-117 Plan: L-117WP03 ¡ ,-------------- --------- -- --------- -- - ---- --- - ---- --- - ---- -- - -- -- - ---------- --- ----- --- --- --- -- -- --- - --- -- - ---- --------------- ------- ------- ------------ --------- ---- ------------ --- ------------' Page: 4 Section 10 : Start ,-- ---- ---- ------------------- ---- -- --------------------- ---------------------- ..-------------- --- -- -- ----- l____n__~:- ---------;;~-- ----- ------;~:_- ---------- _~r______-- + ~~~----- - ---~~~ ~--------~~--------___~;!f~_~!!__-~~~!_~~~--~ ~1_~~__n____~;~~--- - -------- ------------- -----< ~668.66 8.13 17.0~__.!~~9.0~__- 4828.88___376.:~~843~52______- 0.00 O_~~~----~.:.~--~~.O~--------- Section 11 : Start r--- MD----ï~~I-------Aziß1- ----TVD -------+N/-S------+Ê¡::\V--------VS-----------DLS-----B~iÎd--- -T~-;'~--- ----T-FO -------------------l - --870-~oë)--------- _00 -~~~o--- - - -- -- --- ----? ;i:og- -- _00- --65š¡OS----- ------:iS3-2;-i;---- --- --0037-7;5--_00.. ---- -4Ëi4~68-- -.. ..m~_~:~ ~~-~~ -~~2~~~~-~ --~-~~~~~---1-ã~~6o- ___n--m___- ------- ------1 8800.00 5.50 17.09 6649.40 4843.78 380.88 4858.73 2.00 -2.00 0.00 180.00 8900.00 3.50 17.09 6749.09 4851.28 383.19 4866.39 2.00 -2.00 0.00 180.00 9000.00 1_50 17.09 6848.99 4855.46 384.47 4870.66 2.00 -2.00 0.00 180.00 9074.98 0.00 197.09 6923.95 4856.38 384.75 4871.60 2.00 -2.00 0.00 180.00 --------------------- -------- ----------------------- --- ---------- ---- ------ ---- -- ---------------------- ---------------- Section 12 : Start -- - -- - -- 00_- - - ---- - 00'- 00 - - -- - - - ---- - - -m- -.- -- 00- -- -- --- -- - - ----- - - - ---- -- --- -- - - --- - - -- _00- - --_00 ------- 00__- --- - ----- -- --- -- --- - ------- - - - - - ---- -- ---- -- ------- ---- -- -- - - - - - - ..---- ------ - --- -- - - - - -- - -- - - --- ---00__- - - --- ---- 00 - -- MDInCi Azim TVD +N/-S +E/,;W VS DLS. Build Turn TFO. . ft dég deg ft.. ft ft ft. degl100ftideg/1O0ftdég/10Oft deg. ----------------.--..---_c....,---,---- -----------------..;-,~..._-- - --.....--..-..--.....--______0__.___--------- -."----""-"".----"--"--""------'----"--.-------'-- ...' ".._----_.____'__n..-_.-~_.._-"'."---------- ..--....--....---.-.. _..---- -.... ------"-.---..---..----....---, --""----"------..---..--- 9100.00 0.00 197.09 6948.97 4856.38 384.75 4871.60 0.00 0.00 0.00 197.09 9200.00 0.00 197.09 7048.97 4856.38 384.75 4871.60 0.00 0.00 0.00 197.09 9214.98 0.00 197.09 7063.95 4856.38 384.75 4871.60 0.00 0.00 0.00 197.09 -------------__-___00___--_--------------------- ------,- ,-------------- -------.-..--------------------- ---------------------- ----- ---------------------------------..----- ------- -------------------,--..----------------------- ------------ Survey ---- -- ......- -.. - ---- --_...-------- - ---_"____00...__-- ----..... ---..--- - ---..- -- -..-..-- -..---- -..-..._-_..- ......m_m___"'-- --- -- - ....------; __m_- --"""-"---- - ------_... ___mm -- ~i~p"'-- --- _....._-.._- ----_nï\i~p--_m____- -- --~~~~~-i ~Ù t~ d~ - -=~:.; ____m_~~~=_"'L~~-gi-t~d~-- -==~;---1 MD lucl Aiim TVD' +N/-S +E/~W :Northing Easting Deg Min Sec Deg Min See: ft ,deg deg ft ft ft ft ft - - - - - -- - -- - --- -- ------- -- ..--- --- --------- ----_..--- ------- ------- --- -----------------.. --------- ------ -----..--------.._- -.----- - mO--____----------_.. -.. ------...----..- - --- --- ----- --- ---------. ------ ---- -------- -- - -- -- -- -.- -- -------- - ---- ----- ----------------.--- -----------------------_..- 77.00 0.00 0.00 77.00 0.00 0.00 5978267.69 583127.24 70 21 2.153 N 149 19 30.318 W 100.00 0.00 0.00 100.00 0.00 0.00 5978267.69 583127.24 70 21 2.153 N 149 19 30.318 W 200.00 0.00 0.00 200.00 0.00 0.00 5978267.69 583127.24 70 21 2.153 N 149 19 30.318 W 300.00 0.00 0.00 300.00 0.00 0.00 5978267.69 583127.24 70 21 2.153 N 149 19 30.318 W 400.00 1.00 358.65 399.99 0.87 -0.02 5978268.57 583127.21 70 21 2.161 N 149 19 30.319 W 500.00 2.00 358.65 499.96 3.49 -0.08 5978271.18 583127.12 70 21 2.187 N 149 19 30.320 W 600.00 3.00 358.65 599.86 7.85 -0.18 5978275.54 583126.97 70 21 2.230 N 149 19 30.324 W 700.00 4.00 358.65 699.68 13.95 -0.33 5978281.64 583126.75 70 21 2.290 N 149 19 30.328 W 800.00 6.00 358.65 799.29 22.66 -0.54 5978290.35 583126.45 70 21 2.376 N 149 19 30.334 W 900.00 8.00 358.65 898.54 34.85 -0.82 5978302.52 583126.03 70 21 2.495 N 149 19 30.342 W 1000.00 10.00 358.65 997.30 50.49 -1.19 5978318.16 583125.49 70 21 2.649 N 149 19 30.353 W 1100.00 12.50 358.65 1095.37 69.99 -1.65 5978337.66 583124.81 70 21 2.841 N 149 19 30.366 W 1200.00 15.00 358.65 1192.50 93.75 -2.21 5978361.41 583123.99 70 21 3.075 N 149 19 30.383 W 1300.00 17.50 358.65 1288.49 121.73 -2.87 5978389.37 583123.02 70 21 3.350 N 149 19 30.402 W 1400.00 20.00 358.65 1383.18 153.86 -3.63 5978421.49 583121.91 70 21 3.666 N 149 19 30.424 W 1500.00 22.50 358.65 1476.37 190.09 -4.48 5978457.70 583120.65 70 21 4.022 N 149 19 30.449 W 1600.00 25.00 358.65 1567.90 230.35 -5.43 5978497.95 583119.26 70 21 4.418 N 149 19 30.477 W 1700.00 27.50 358.65 1657.58 274.56 -6.47 5978542.14 583117.72 70 21 4.853 N 149 19 30.507 W 1800.00 30.00 358.65 1745.25 322.64 -7.60 5978590.20 583116.06 70 21 5.326 N 149 19 30.540 W 1900.00 30.00 358.65 1831.85 372.63 -8.78 5978640.16 583114.33 70 21 5.817 N 149 19 30.575 W 2000.00 30.00 358.65 1918.46 422.61 -9.96 5978690.13 583112.60 70 21 6.309 N 149 19 30.609 W 2036.43 30.00 358.65 1950.00 440.82 -10.39 5978708.33 583111.96 70 21 6.488 N 149 19 30.622 W 2100.00 33.18 358.65 2004.14 474.11 -11.17 5978741.60 583110.81 70 21 6.816 N 149 19 30.645 W 2200.00 38.18 358.65 2085.35 532.40 -12.55 5978799.87 583108.79 70 21 7.389 N 149 19 30.685 W 2300.00 43.18 358.65 2161.16 597.54 -14.08 5978864.98 583106.53 70 21 8.029 N 149 19 30.730 W 2400.00 48.18 358.65 2231.01 669.04 -15.77 5978936.45 583104.05 70 21 8.733 N 149 19 30.779 W 2500.00 53.18 358.65 2294.36 746.35 -17.59 5979013.74 583101.37 70 21 9.493 N 149 19 30.832 W 2554.55 55.91 358.65 2325.99 790.77 -18.63 5979058.14 583099.84 70 21 9.930 N 149 19 30.863 W 2600.00 55.91 358.65 2351.46 828.40 -19.52 5979095.75 583098.54 70 21 10.300 N 149 19 30.889 W 2700.00 55.91 358.65 2407.51 911.19 -21.47 5979178.51 583095.67 70 21 11.114 N 149 19 30.946 W 2800.00 55.91 358.65 2463.56 993.98 -23.42 5979261.27 583092.80 70 21 11.928 N 149 19 31.003 W 2900.00 55.91 358.65 2519.61 1076.78 -25.37 5979344.02 583089.93 70 21 12.743 N 149 19 31.060 W 3000.00 55.91 358.65 2575.66 1159.57 -27.32 5979426.78 583087.06 70 21 13.557 N 149 19 31.117 W ----------------.- ------------------- --------------- .--.-, - ---- -----------..-.------------- -- '---------.------ -- -,------- --------------- ------------------------------------------- --___00___---------------------------------------------------- ( ( BP Amoco Planning Report - Geographic ¡--------- --------------------------- ----------- ------------------------- ---------------- -- ---- --- -- --------------- I Company: BP Amoco Date: 7/16/2001 Time: 13:58:59 Page: 5 I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: L-117. True North - Site: PB L Pad Vertical (fVD) Reference: Temp Plan elevation 77 77.0 ; ¡Well: L-117 Section (VS) Reference: Well (0.00N,0.00E,4.53Azi) ! I Well path: Plan L-117 Plan: L-117 WP03 i L- --- ------- -------- ------- - m --- --------- ----------- -----, -- -- m - ---- --------- - - ----- ------ -, .o- - --- ---- -------- --- ------ ---- m_- - -- ------ -- -- - ------__-___m --- -- - ----- ----- ---- - --- ,--- -- - m___- ------~ Survey ,-- ------------------- ---- - --------------- - -,-------------------- ---------- --- ------------- ------- -- ---------------- <- Latitude --> ; ! Map Map <- Longitude -> I I ! MD Incl Azim TVD +N/-S +EI-W Northing Easting Deg Min Sec Deg Min See ! I ; ft deg deg ft ft ft ft ft ! t.o-------------'-----___.__m-.m._____-----.------.------- -- ---.--- -.._--- _.__m_.' ,-- -----.- ------ - --.-.- --- -.--.- ..-- ,----- ---------------------- ------- ----- --------- ------------ ---, ---- --- ------- ----.---.----- ----------.- ----- -- ----- -------- --.-'---"-'-- -.-.--------.------.-.------------ --------- _n ------- --- ---- -.-.--- -- ,-..-------..-.-------.---1 I 3100.00 55.91 358.65 2631.71 1242.36 -29.27 5979509.54 583084.19 70 21 14.371 N 149 19 31.174 W I I 3200.00 55.91 358.65 2687.76 1325.16 -31.22 5979592.30 583081.32 70 21 15.185 N 149 19 31.231 W 3300.00 55.91 358.65 2743.81 1407.95 -33.17 5979675.06 583078.45 70 21 16.000 N 149 19 31.288 W 3400.00 55.91 358.65 2799.86 1490.74 -35.13 5979757.82 583075.58 70 21 16.814 N 149 19 31.345 W 3500.00 55.91 358.65 2855.91 1573.53 -37.08 5979840.58 583072.71 70 21 17.628 N 149 19 31.402 W 3600.00 55.91 358.65 2911.96 1656.33 -39.03 5979923.33 583069.84 70 21 18.443 N 149 19 31.459 W 3700.00 55.91 358.65 2968.01 1739.12 -40.98 5980006.09 583066.97 70 21 19.257 N 149 19 31.516 W 3800.00 55.91 358.65 3024.06 1821.91 -42.93 5980088.85 583064.11 70 21 20.071 N 149 19 31.573 W 3900.00 55.91 358.65 3080.11 1904.71 -44.88 5980171.61 583061.24 70 21 20.885 N 149 19 31.630 W 4000.00 55.91 358.65 3136.16 1987.50 -46.83 5980254.37 583058.37 70 21 21.700 N 149 19 31.687 W 4100.00 55.91 358.65 3192.21 2070.29 -48.78 5980337.13 583055.50 70 21 22.514 N 149 19 31.744 W 4200.00 55.91 358.65 3248.26 2153.08 -50.73 5980419.88 583052.63 70 21 23.328 N 149 19 31.801 W 4300.00 55.91 358.65 3304.31 2235.88 -52.69 5980502.64 583049.76 70 21 24.142 N 149 19 31.858 W 4400.00 55.91 358.65 3360.35 2318.67 -54.64 5980585.40 583046.89 70 21 24.957 N 149 19 31.915 W 4500.00 55.91 358.65 3416.40 2401.46 -56.59 5980668.16 583044.02 70 21 25.771 N 149 19 31.972 W 4600.00 55.91 358.65 3472.45 2484.26 -58.54 5980750.92 583041 .15 70 21 26.585 N 149 19 32.029 W 4700.00 55.91 358.65 3528.50 2567.05 -60.49 5980833.68 583038.28 70 21 27.399 N 149 19 32.087 W 4800.00 55.91 358.65 3584.55 2649.84 -62.44 5980916.44 583035.41 70 21 28.214 N 149 19 32.144 W 4900.00 55.91 358.65 3640.60 2732.63 -64.39 5980999.19 583032.54 70 21 29.028 N 149 19 32.201 W 5000.00 55.91 358.65 3696.65 2815.43 -66.34 5981081.95 583029.67 70 21 29.842 N 149 19 32.258 W 5100.00 55.91 358.65 3752.70 2898.22 -68.29 5981164.71 583026.81 70 21 30.656 N 149 19 32.315 W 5200.00 55.91 358.65 3808.75 2981.01 -70.25 5981247.47 583023.94 70 21 31.471 N 149 19 32.372 W 5262.08 55.91 358.65 3843.72 3032.31 - 71.36 5981298.75 583022.25 70 21 31.975 N 149 19 32.404 W 5300.00 55.80 359.56 3865.00 3063.69 - 71.85 5981330.11 583021.41 70 21 32.284 N 149 19 32.419 W 5400.00 55.54 1.96 3921.41 3146.25 -70.76 5981412.68 583021.59 70 21 33.096 N 149 19 32.387 W 5500.00 55.33 4.37 3978.15 3228.46 -66.22 5981494.93 583025.22 70 21 33.904 N 149 19 32.254 W 5600.00 55.16 6.80 4035.16 3310.22 -58.22 5981576.76 583032.31 70 21 34.708 N 149 19 32.020 W 5700.00 55.05 9.23 4092.37 3391.43 -46.79 5981658.09 583042.84 70 21 35.507 N 149 19 31.686 W 5800.00 54.98 11.67 4149.72 3471.99 -31.93 5981738.80 583056.81 70 21 36.299 N 149 19 31.252 W 5900.00 54.96 14.12 4207.12 3551.80 -13.65 5981818.80 583074.19 70 21 37.084 N 149 19 30.717 W 6000.00 54.99 16.56 4264.52 3630.77 8.00 5981897.99 583094.97 70 21 37.861 N 149 19 30.084 W 6021.68 55.00 17.09 4277.00 3647.72 13.16 5981915.00 583099.93 70 21 38.028 N 149 19 29.933 W 6100.00 53.43 17.09 4322.79 3708.45 31.83 5981975.93 583117.93 70 21 38.625 N 149 19 29.387 W 6200.00 51.43 17.09 4383.76 3784.21 55.12 5982051.93 583140.38 70 21 39.370 N 149 19 28.706 W 6300.00 49.43 17.09 4447.45 3857.89 77.78 5982125.85 583162.21 70 21 40.095 N 149 19 28.044 W 6400.00 47.43 17.09 4513.80 3929.40 99.76 5982197.60 583183.40 70 21 40.798 N 149 19 27.401 W 6500.00 45.43 17.09 4582.71 3998.66 121.06 5982267.08 583203.92 70 21 41.479N 149 19 26.778 W 6600.00 43.43 17.09 4654.12 4065.57 141.63 5982334.21 583223.75 70 21 42.137 N 149 19 26.177 W 6700.00 41.43 17.09 4727.92 4130.06 161.46 5982398.91 583242.86 70 21 42.771 N 149 19 25.597 W 6800.00 39.43 17.09 4804.03 4192.05 180.51 5982461.10 583261.22 70 21 43.381 N 149 19 25.040 W 6900.00 37.43 17.09 4882.36 4251.46 198.78 5982520.71 583278.83 70 21 43.965 N 149 19 24.505 W 7000.00 35.43 17.09 4962.81 4308.23 216.23 5982577.66 583295.65 70 21 44.524 N 149 19 23.995 W 7100.00 33.43 17.09 5045.28 4362.27 232.85 5982631.88 583311.66 70 21 45.055 N 149 19 23.509 W 7200.00 31.43 17.09 5129.68 4413.53 248.61 5982683.31 583326.85 70 21 45.559 N 149 19 23.048 W 7300.00 29.43 17.09 5215.90 4461.95 263.49 5982731.88 583341.20 70 21 46.035 N 149 19 22.613 W 7400.00 27.43 17.09 5303.83 4507.46 277.49 5982777.54 583354.68 70 21 46.483 N 149 19 22.204 W 7500.00 25.43 17.09 5393.37 4550.01 290.57 5982820.22 583367.29 70 21 46.901 N 149 19 21.821 W 7600.00 23.43 17.09 5484.41 4589.54 302.72 5982859.89 583379.01 70 21 47.290 N 149 19 21.466 W 7700.00 21.43 17.09 5576.84 4626.02 313.94 5982896.48 583389.81 70 21 47.649 N 149 19 21.138 W 7800.00 19.43 17.09 5670.54 4659.39 324.20 5982929.96 583399.70 70 21 47.977 N 149 19 20.838 W 7900.00 17.43 17.09 5765.41 4689.61 333.49 5982960.28 583408.66 70 21 48.274 N 149 19 20.566 W 8000.00 15.43 17.09 5861.32 4716.65 341.80 5982987.41 583416.67 70 21 48.540 N 149 19 20.323 W -----------------_____--n__-_--'--'----'---------------- ,n--_____------------------.------ ,--------------- - - ----------.------------.------------- ------.----- -----,----,---- ---- ¡' ,( (' BP Amoco Planning Report - Geographic ----------- -- - - _____m______- Company: BP Amoco Date: 7/16/2001 Time: 13:58:59 Field: Prudhoe Bay Co...()rdinate(NE) Reference: Well: L-117. True North Site: PB L Pad Vertical (fVD) Reference: Temp Plan elevation 77 77.0 I Well: L-117 Section (VS) Reference: Well (0.00N,O.00E,4.53Azi) : Well path: PlanL-117 Plan: L-117WP03 , l_____- -------- -- -- --- ----- - - - ---- -- ---- - - -- --- -- - ... - - - ------ ----- ------------ -- - ---- - ---- ---... -- - --- --- ------ --- ...-... ------ ---- --- --- ------ ------ ----- - ----- -..--- ------- - ---- - -- -- -...-- ---- .--. ----- - - ---- -------- -- __m_____- - -- ~ - - -- - ----- - Page: 6 Survey ,---------------.- ------ -- __-__m- ------ -- --- --- -- --- -------- -------- ---------------- - - ----------- --------------------------- ---------- ---..--.. -- -------- ----, I Map Map <- Latitude --> <- Longitude -> ¡ i MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min See i ! ft deg deg ft ft ft ft ft : '-------------- ------------- - ---..------- ----- ------n_--- - - ___m______---- h--__h__--- ---------------- -- - ----- - -..---..---- ___n_- - - ---_..-- --------..--..----...--------------- ---.. - ___m_- ------ -oo------------ -.. ---..----- _h- ------------------------ - -- ------- -- ____nn__- ------ -----...------------------ _..-- ------- __m____- oo------.._-- - - ---_J 8100.00 13.43 17.09 5958.15 4740.47 349.13 5983011.31 583423.73 70 21 48.775 N 149 19 20.108 W I 8200.00 11.43 17.09 6055.80 4761.05 355.45 5983031.96 583429.82 70 21 48.977 N 149 19 19.923 W I 8300.00 9.43 17.09 6154.15 4778.36 360.77 5983049.32 583434.95 70 21 49.147 N 149 19 19.768 W 8365.36 8.13 17.09 6218.75 4787.90 363.70 5983058.89 583437.77 70 21 49.241 N 149 19 19.682 W 8400.00 8.13 17.09 6253.04 4792.58 365.14 5983063.59 583439.16 70 21 49.287 N 149 19 19.640 W 8500.00 8.13 17.09 6352.04 4806.10 369.30 5983077.15 583443.17 70 21 49.420 N 149 19 19.518 W 8600.00 8.13 17.09 6451.03 4819.62 373.45 5983090.71 583447.17 70 21 49.553 N 149 19 19.397 W 8668.66 8.13 17.09 6519.00 4828.88 376.30 5983100.01 583449.92 70 21 49.644 N 149 19 19.314 W 8700.00 7.50 17.09 6550.05 4832.95 377.55 5983104.09 583451.12 70 21 49.684 N 149 19 19.277 W 8800.00 5.50 17.09 6649.40 4843.78 380.88 5983114.95 583454.33 70 21 49.791 N 149 19 19.180 W 8900.00 3.50 17.09 6749.09 4851.28 383.19 5983122.48 583456.55 70 21 49.864 N 149 19 19.112 W 9000.00 1.50 17.09 6848.99 4855.46 384.47 5983126.67 583457.79 70 21 49.905 N 149 19 19.075 W 9074.98 0.00 197.09 6923.95 4856.38 384.75 5983127.59 583458.06 70 21 49.915 N 149 19 19.066 W 9100.00 0.00 197.09 6948.97 4856.38 384.75 5983127.59 583458.06 70 21 49.915 N 149 19 19.066 W 9200.00 0.00 197.09 7048.97 4856.38 384.75 5983127.59 583458.06 70 21 49.915 N 149 19 19.066 W 9214.98 0.00 197.09 7063.95 4856.38 384.75 5983127.59 583458.06 70 21 49.915 N 149 19 19.066 W ------ ------------------------- --------------------..------------------------oo------- ------- ----- -------- -- ------- ----- -_-m-___------------------ - --------------------------- From Colour ToMD 0 300 300 600 600 900 900 1200 1200 ~ 1500 1500 2000 2000 2500 2500 3000 00 ""^'--.-. 3500 ..3~ 4500 5500 WEll DErAIlS COMPANY DETAIlS BP Amoco ANTI-COLLISION SEITINGS N""", +N/-5 33.52 +EI-W Interpolation Method:MD Depth Range From: 77.00 Maximum Range: 1113_80 Latitude longitude Slot Nonhing 5978267.69 Easting 58312724 Interval: 25.00 To: 9214.98 Reference: Plan: L-II? WP03 Calculation Method: MinimWl Cwvdtun: EnurS)-st<m: ISCWSA S= Method: T ",v Cylinder Nor1h Error Surf a",,: EThJ'Û<'>l + G.sing Warning Method: Rules Bosed 70"21'02.153N 149"']9'30318W N-J l-117 130_80 64 0 0 40 10 0 10 20 0 0 64 ..- ..- nder SURVEY I'R()(iRAM D"pth I'm D'l'th Tn SUIW)-¡j'lan 77.00 1100_00 1100_00 9214_91! PIaMc<I:I_-117W1'03VI "lannul: 1.-117 WI'û3 VI Rig: Re[ f)atwn: V.s,-ctÍ<'n An¡¡Ic 4.53" T..,I CU.{õYIW.SS MWI> WELloP^lll)ETAIJ_~ Plan 1.-117 T"mp Plan d,~~tí"l17 77.00 ft Origin (~in ~:;1'V) IN/.S ;¡;I.W 0_00 0_00 0_00 U,(;!:ND - .. ".~ 11A).MojnrRisk , . jsk , ,. . Risk , . .isk , -.. - '.-. .-. -. '- . -. - ,. . -. -> . , . "., '-0 ,- , .. , . . -. .. .,-, - .. . .. , . ,. . .. . .' . -. SECTION DETAILS S«: MD h¡c Azi 1'01) -W.S '!;I-W )(~1! 1 Face VSc< lar¡;cI 1 77.00 0.00 0_00 77.00 0_00 0_00 0_00 0_00 0_00 2 300-00 0_00 0_00 300_00 0_00 0_00 0-00 0_00 0_00 3 700-00 4_00 358.1>5 699.1>8 11.95 -'JJ3 1.00 358.65 IJ.!Ø! 4 1000.00 10_00 358_65 99UO 50_49 -1.19 2_00 0_00 50_24 5 1800_00 30_00 358_65 174525 322.1>4 -7_W 2.50 0-00 321.0) 6 2036.43 30.00 358_r.s 1950_00 440_82 .1039 0.00 0_00 4.1K_I,_1 7 2554.55 55_91 358.65 2325-99 790_77 .18.6.1 5-00 O.OD 786Xl 8 5262-08 55_91 358_65 31!43_72 _103231 .71.J6 0_00 O_OD 3017_21 9 6021-68 55_00 17_09 4277.00 31>47_72 13_11. 2.OD 98.1>4 3(,)U7 1.-118 inl 10 836536 8-13 17_09 1.218_75 4787_90 3(,).70 2.00 .ISO_OD 4801.1,7 II 8668_66 8_13 17_09 1>519_00 482SjiS 371,_30 0_00 O_00 41!4.!.52 IN.I..I 12 9O74-9S 0_00 197_09 (,<)23_95 485638 31!4_75 2_00 180,00 41<71.59 13 9214-98 0_00 197_09 701ù.95 485638 384_75 0_00 197,09 41<71.59 f ,(' BP Amoco Anticollision Report - ----- -- -- - --- -- --- --- --- - - - 1 : ¡ i Company: BP Amoco : Field: Prudhoe Bay i Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: L-117, True North : Reference Well: L-117 Vertical (fVD) Reference: Temp Plan elevation 77 77.0 L_~~~ ~~~ n c~~~_!~~~~-~!'.!~~---~ - ~~~------ -------------:=--====--==~==c---:----------------------"------- .--. -- "-----"------- ----- ----------- :~=~~,,=,_._--- ---- --- --------_.E_~ ~-c--~;~9.1 ~=:-! GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There arfRH8iÐèl'fells in thi'~al Plan & PLANNED PROGRAM : Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 77.00 to 9214.98 ft Scan Method: Trav Cylinder North I Maximum Radius: 1113.80 ft Error Surface: Ellipse + Casing Date: 7/16/2001 Time: 13:38:00 Page: ------------______m______------ ----------------- moo- ------ n -- :----------------- ------------------- ----- --- -- ~--- - --------------------------- ----------------- ---- ---- ------ -----_-__n__--___---- -----1 : Survey Program for Definitive Well path - I Date: 12/26/2000 Validated: No Version: 6 'II : Planned From To Survey Toolcode Tool Name I ft ft I ~~~~~~--~~~~=_J Casing Points r~~~~-=i~i~=-jÞT~'3~¡-=~~~:~~-:==::====:==~=-==::'-=--~=--==:==--l Summary ----- -- ------,-- -, -, ,-------,--- - - ---- -- - ------~--'--- -'--,-- ,----- ---------,--,-- --- ---- ------------,----------------, --,------- om"~ --- ------------------ -,,--- --- -- ---- ----------- - 'm --------,--,- - ----- -- - --- -- -- - -----'---- -------- -,----- --------- - ----, <------------------ Offset Well path -----------------> Reference Offset Ctr-Ctr No-Go Allowable ! Site Well Wellpath MD MD Distance Area Deviation Warning -- - ft ft ft ft ft - ------------- 300.00 300.05 247.82 5.83 242.00 Pass: Major Risk 299.98 300.00 247.82 5.83 241.99 Pass: Major Risk 299.98 300.00 247.82 5.83 241.99 Pass: Major Risk 1353.59 1375.00 44.51 28.03 19.04 Pass: Major Risk 324.62 325.00 200.17 6.38 193.79 Pass: Major Risk 649.57 650.00 32.59 13.85 18.74 Pass: Major Risk 883.42 900.00 298.35 18.28 280.14 Pass: Major Risk 422.06 425.00 252.61 9.88 242.73 Pass: Major Risk 953.50 975.00 258.35 19.27 239.33 Pass: Major Risk 348.72 350.00 214.87 8.07 206.81 Pass: Major Risk 762.10 775.00 238.89 15.02 223.95 Pass: Major Risk 348.54 350.00 180.78 8.16 172.62 Pass: Major Risk 348.46 350.00 182.92 8.17 174.75 Pass: Major Risk 421.41 425.00 183.72 10.01 173.71 Pass: Major Risk 548.96 550.00 91.40 12.27 79.13 Pass: Major Risk 498.82 500.00 121.85 10.84 111.02 Pass: Major Risk 421.46 425.00 209.85 9.96 199.89 Pass: Major Risk 781.38 800.00 190.87 16.34 174.70 Pass: Major Risk 712.56 725.00 184.58 12.46 172.28 Pass: Major Risk 650.17 650.00 18.37 14.45 3.93 Pass: Major Risk 602.44 600.00 221.15 13.28 207.87 Pass: Major Risk 451.45 450.00 251.56 9.94 241.62 Pass: Major Risk ------ EX NWE#1 EX NWE#1 EX NWE#1 EX NWE#1 PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad PB L Pad delete me NWE1-01ANWE1-01A V4 NWE1-01 NWE1-01 V3 NWE1-01 NWE1-01A VO NWE1-02 NWE1-02 V2 L-01 L-01 V12 L-02 Plan L-02 V1 Plan: L-O L-103 Plan L-103 V1 Plan: L- L-105 Plan L-105 V5 Plan: L- L-106 Plan L-106 V7 Plan: PI L-107 Plan L-107 V6 Plan: L- L-108 Plan L-108 V3 Plan: L- L-109 Plan L-109 V3 Plan: L- L-110 Plan L-110V5 Plan: PI L-111 Plan L-111 V11 Plan: L L-112 Plan L-112V2 Plan: L- L-113 Plan L-113 V3 Plan: L- L-114 Plan L-114 V8 Plan: PI L-115 Plan L-115 V6 Plan: L- L-116 L-116V7 L-118 Plan L-118 V6 Plan: L- L-119 Plan L-119 V5 Plan: L- L-120 Plan L-120 V4 Plan: L- --- ---- -- --------------- --- ----------------------- ------------------- -------------------- -- --- ------------ ------------------ -- - --- -------,------.--- - ----.- - -- ----------- ----, -----n_- ----- Site: EX NWE#1 Well: delete me NWE1-01A Wellpath: NWE1-01A V4 Rule Assigned: Inter-Site Error: Major Risk 0.00 ft ,-- - ------,--,--' ---"'---, -- ~-~,-: ...----- -...---- --, -- -- -" ---" ---- - --- ~~-,- -"-' .,.--,-------.,.- ~ ----: -~c--- - --,' --, .---c- ,...--- -~ -, ~- ---~ ---- -- -- -- - - - ~ -- - ""---'-' -~c---,- --,---:- ,-- ------ - ----:--~. - - ---,---- - . .. - -- -, -,~-- --- -, ,-, ---:--' ---"" --- -~ - - - -,.. - - -- ----, , , Reference, .. Offset,.' . >SeÜ1i-l\1;aj()r Axis ... .. .... .. ... . Ctr-Ctr No~Go . Allowa~le . .... . .. ,'.. .. i .l\'ID . .TVD , MD , >TVD .', ..Ref .. Offset. TFO+AZI TFO-'HS Ca~ing.. DištaitceArea . .. Deviation Warning ... .1' ------ --- -. --.- ..- ~~ ,.'----------. ---.. ,_no' ..~------------------ ----,----_.~--_-C-_- ---!!_-.. ---~--~--_!!_- ----.--------_f!.- ----~:~-----..___,._d..:_~___-----_.,. ,--~-~------------_.- -.-,-_!!_--- -- -----.. - ---~----~------_._---_.._----,,--~---------_. ---. --- -.---:------ ------------". -----.- ,~..-_.-- ------_c--- 99.99 99.99 100.00 100.00 0.05 0.06 241.52 241.52 246.33 1.47 244.86 Pass 124.99 124.99 125.00 125.00 0.16 0.07 241.53 241.53 246.37 2.06 244.31 Pass 149.99 149.99 150.00 150.00 0.26 0.07 241.54 241.54 246.43 2.65 243.78 Pass 174.99 174.99 175.00 175.00 0.36 0.08 241.55 241.55 246.50 3.23 243.27 Pass 199.99 199.99 200.00 200.00 0.47 0.10 241.56 241.56 246.59 3.86 242.74 Pass 224.99 224.99 225.00 225.00 0.52 0.13 241.56 241.56 246.74 4.35 242.39 Pass 249.99 249.99 250.00 250.00 0.58 0.16 241.56 241.56 246.99 4.86 242.14 Pass 274.99 274.99 275.00 275.00 0.63 0.18 241.57 241.57 247.35 5.35 242.01 Pass 300.00 300.00 300.05 300.04 0.69 0.20 241.56 241.56 247.82 5.83 242.00 Pass 324.49 324.49 325.00 324.98 0.74 0.24 241.55 242.90 248.44 6.31 242.14 Pass 348.99 348.99 350.00 349.97 0.78 0.27 241.50 242.85 249.25 6.79 242.47 Pass -..------------------------------------------______m_____-,___,_m_'_n______---------_____n--__- -- -- -- ------------------------------- ---------------------------------'---------------_..-_..--- -- --------------..-------- (' ( Borealis L-117i: Proposed Completion TREE: 4-1/16" - 5M CIW Carbon WELLHEAD: 11" - 5M FMC G5 9-5/8",40 lIft, L-80, BTC 3002' Plug Back Depth 9135' 7",26 lIft, L-80, BTC-Mod 92151 Date 7-30-01 Rev By NM Cellar Elevation = %47' RKB-MSL = :1:.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. r-------------------------------------------------------------- - ------- - # GAS LIFT MANDRELS ---------_m_-- ___n-- -----------------------_-__n MD Size Valve Type --------.---- ------------_.------------------------------- ---------------------.--------- 1 2 TBD TBD DV DV 1 " 1" ------- ------------------------------- ---------------------------------- 4-1/2" 12.6# L-80, Premium Connection Tubing 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker '8-3' Production Packer 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 4-1/2" 'XN' Landing Nipple with 3.813" seal bore and 3.725" No-Go 10. 4-1/2" WireLine Entry Guide set at +/-150' above the Kuparuk Formation Comments Borealis WELL: L-117 API NO: 50-029-????1 Proposed Completion WP3 BP Alaska Drilling & Wells ( ( L-117 Well Summary of Drillinq Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: . Gas hydrates were observed in all offset wells. These are expected to be encountered near the base of the Permafrost at 1850' 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: . The production section will be drilled with a recommended mud weight of 10.8 ppg to ensure shale stability in the HRZ shale. 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. . FAULTS: The well trajectory is expected to intersect a fault while drilling L-117, in the base of the Ugnu/Top Schrader @ -3785' TVDss. The throw is estimated @ -165' and is not considered a high risk for loss circulation. Consult Lost Circulation Decision Tree for recommended LCM treatments. . KICK TOLERANCE: With 10.3 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 12.2 ppg at the surface casing shoe, 10.8 ppg mud in the hole, kick tolerance is 25 bbls. (Offset wells have shown fracture gradient of 13.5 ppg to 14.7 at the surface shoe depth. ) . A majority of the L-Pad development will have "kick tolerances" in the 25-35 bbl range or less. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S . This drill-site not designated as an H2S drill site. Recent wells NWE 1-01 and NWE 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 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page 1 of 1 H 193331 DATE INVOICE I CREDIT MEMO 070201 CK070201R PYMT OMMENTS: HANDL NG I NST: DESCRIPTION GROSS 100.00 Per it to Drill ee S/H - Terrie Hub Ie X4628 or Sandra Ste man X4750 \:;'~O"';'~i~:;:~:Jj:~';:(: >111,,1', ,',II:\"'::,~~il'.'I, "",', ,-- -':'" -',' ",,":',- -,'^ ,,:::' rHE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE, (' ~Á--l QA l~4 L-\ll DATE 07/06/01 ~ CHECK NO- 100 193331 VENDOR DISCOUNT NET 100. 00 ----- --.--- ----_.------ 100 0 193331 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY To The ORDER Of No.H FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. m-lio 56-389 -m- CONSOLIDATED COMMERCIAL ACCOUNT 00193331 ONE HUNDRED & 00/100************************************* US DOLLAR DATE AMOUNT 07/06/0C] [= $iOO_'O~ NOT VALID AFrEH 120 DAYS ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE III ~ 9 j j j . III AI-<. 99501 I:O~ ~ 20 jB9 51: OOB~~ .9111 Ç( /1:'. ~; ¡.;,,", . ;:7 .t-" (I ¡ / 1; ç;. n 1.'./ / ')/ \,~. ~~. \.. . ---.....""<.)1' ~ø !1 ", ~ ,......------------- / CHECK 1 STANDARD LETTER D EVELO PMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL v INJECTION WELL RED RILL (' (1 rtANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSNUTTALLETTER WELLNAME-t. --\ \~ CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LA TERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULA~ DI~. SAL . ~NO ANNULAR DISPOSAL <--> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well . Permit No, API No. . Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and 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). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L.-> YES + SPACING EXCEPTION Templates are located m drive\jody\templates 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 peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY WELL NAME ¿ -- # ? PROGRAM: exp - dev - redrll FIELD & POOL C Clr?/ ) 0 INIT CLASS' GEOL AREA K 7~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y 2. Lease number appropriate. .. . . . . . . . . . . . . . . . . Y 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y 4. Well located in a defined pool.. . . . . . . . . . . . . . . .' ~ Y 5. Well located proper distance from drilling unit boundary. . . . Y 6. Well located proper distance from other wells.. . . . . . . . . Y 7. Sufficient acreage available- in drilling unit.. . . . . . . . . . . Y 8. If deviated, is wellbore plat included.. . . . . . . . . . . .'. . Y 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y 11. Permit can be issued without conservation order. . . . . . . . Y 12. Pennit can.be issued without administrative approval.. . . . . Y 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y 14. Conductor string provided. . . . . . . . .. . . . . . . . . . 15. Surface casing protects all known USDWs. . .. . . . . . . . 16. CMT vol adequate to circulate on conductor & suñ csg. . . . . 17. CMT vol adequate totia-in long string to surf csg. . . . . . . . 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate weilbore separation proposed.. . . . . . . . . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . ~ . . 25. 80PEs, do they meet regulation. . . . . '.' . . . . . . . . . 26. SOPE press rating appropriate; test to '-CeO Dsig. - 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30. Permit can be issued wlo hydrogen sulfide measures. . . . .. 31. Data presented on potential overpressure zones. . . . . . . 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . AEJ:~ ~~T1 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N Lf/!5;::,..... ~ 34. Contact name/phone for weekly progress reports [exploratory on/~ Y N ANNULAR DISPOSAL35. With proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; . . . . . (C) will not impair mechanical integrity 9f the well used for disposal; Y N (D) will not damage producing fonnation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOL Y: ENGINEERING:.' UIC/Annular COMMISSION: ~þ WM ----=-~ . 8~s r)/o I ~ JMH ' 0 { GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) \ " serv wellbore seg _ann. disposal para req - /? b S::-J ON/OFF SHORE ðrJ . UNIT# c 0 Z ( 0 -t ~ ::0 - -to m - z -t J:' - en ). ::0 ( m » N : ~ < /S ,.. ~ ~¿/ "'- y ~ e~dAc:;or-7' -Ø-é. I<ID . . N N . ~ N ~<'<;. ~ (~~~~ ~) T H ~ ~ ~ . ~ co \c:,,¡.<,t 0. t-?~&c, ~ . N . ~ "'C>b~ ~~~ ~ ;)15\. "6 ~ l , '-\~\ ~6~-~~ ~ Y~ . =<~. ~. 4<:'£0&-1/1- Y N Y N ..."--'.- ,.; Com mentsllnstructions: Daily Report of Well Operations PBU L-117 2/13/2023 T/IA/OA= 1050/700/300 Assist Eline (Injectivity test). TFS U4. Pumped 0.3 BBLS of DSL down the TBG, pressured up to 1500psi for perf guns to be fired. Pumped 2 BBLS of 60/40 followed by 55 BBLS of DSL down the TBG for step rate injectivity test. 1BPM @1479 psi, 2BPM @1578 psi, 3BPM @1575 psi. Pumped 2.5 BBLs of DSL to pressure up to 2500 psi against the cement retainer. Bleed back 2.5 BBLS. Final T/IA/OA= 209/700/300. Well left in control of Eline upon departure. 2/26/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: Cement Colville Perfs, Mill Retainer and CBP MIRU CTU. Perform weekly BOP test. Make up NS Cementing BHA & RIH. ***Continued on 2/27/23*** 2/27/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: Cement Colville Perfs, Mill Retainer and CBP RIH with NS Cementing BHA. Sting in to retainer at 8341' ctm. Verify circulation into the IA. Circulate 5 bbls of Fresh water, 38 bbls of Class G cement. Circulate 37 bbls into IA, unsting with 1 bbl left in coil. Reverse out excess cement. Est TOC in IA at ~6404'. WOC. Make up milling BHA with 2.80" Bow Junk Mill and RIH. Tag high 8283' ctm. Mill easy through stringers/contaminated cement. Encounter retainer at 8362' ctm (+17' correction). Mill through retainer and cement. Pump 20 bbls gel pill and circulate bottoms up. ***Continued on 2/28/23*** 2/28/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: Cement Colville Perfs, Mill Retainer and CBP Circulate gel pill bottoms up. MIT T Passed to 3704 applied pressure Attempt to mill CBP however encounter muliple stalls and heavy overpulls. POOH and make up Venturi/ Junk Basket BHA with 2.30" mule shoe. Nothing recovered in venturi. Make up milling BHA w/ 2.79" 3-bld junk mill. Mil CBP at 8386'. ***Continued on 3/1/23*** 3/1/2023 LRS CTU #2 - 1.50" Blue Coil Job Objective: Cement Colville Perfs, Mill Retainer and CBP Mill through CBP and push out tubing tail at 8460' ctm. POOH. Flushed the wellbore with 270 bbls of kcl at 5 bpm at 1450 psi. Freeze protect to 3000' TVD with diesel. RDMO ***Job Complete*** 3/4/2023 *** WELL S/I ON RRIVAL*** (STANDBY FOR WEATHER) STANBY FOR WEATHER ***JOB CONTINUE ON 3/5/2023*** 3/5/2023 *** JOB CONTINUED FROM 3/4/2023*** ( CEMENT BOND LOG ) PT 300L/3000H RIH W/CH,WB,CET,CBL,CENT, TO 8430' MD AND PERFORM REAT AND MAIN PASS FROM 8430' MD TO 5500' MD SEND DATA TO TOWN FOR FINAL ANALISYS CEMENT BOND LOG COMPLETE *** WELL S/I ON DEPARTURE*** RIH W/CH,WB,CET,CBL,CENT, TO 8430' MD AND PERFORM REAT AND MAIN PASS FROM 8430' MD TO 5500' MD Circulate gel pill bottoms up. MIT T Passed to 3704 applied pressure Attempt to mill g CBP however encounter muliple stalls and heavy overpulls. POOH and make upy Venturi/ Junk Basket BHA with 2.30" mule shoe. Nothing recovered in venturi. Make g up milling BHA w/ 2.79" 3-bld junk mill. Mil CBP at 8386'. CEMENT BOND LOG COMPLETE Mill through CBP and push out tubing tail at 8460' ctm. POOH. Flushed the wellbore gg with 270 bbls of kcl at 5 bpm at 1450 psi. Freeze protect to 3000' TVD with diesel RIH with NS Cementing BHA. Sting in to retainer at 8341' ctm. Verify circulation into gg y the IA. Circulate 5 bbls of Fresh water, 38 bbls of Class G cement. Circulate 37 bbls into IA, unsting with 1 bbl left in coil. Reverse out excess cement. Est TOC in IA at ~6404'.Make up milling BHA with 2.80" Bow Junk Mill and RIH. Tag highggg 8283' ctm. Mill easy through stringers/contaminated cement. Encounter retainer atygg 8362' ctm (+17' correction). Mill through retainer and cement. Pump 20 bbls gel pill ( and circulate bottoms up. ***Continued on 2/28/23*** Daily Report of Well Operations PBU L-117 3/28/2023 ***WELL S/I ON ARRIVAL*** (profile modification) PERFORMED B&F TO 8,450' SLM W/ LRS PUMPING HOT DIESEL SET 2.81" PX PLUG IN NIP AT 8,436' MD (lrs performed pt) PULLED RK-DGLV AT ST# 1 (6,354' md) & ST# 2 (5,973' md) SET RK-WFR IN STA # 2 AT 5,973' MD SET RK-DGLV IN STA # 1 AT 6,354' MD ***WELL S/I ON DEPARTURE*** 3/28/2023 T/I/O=950/570/300 Assist S-Line (Brush N Flush) Pump down Tbg. w/ 3 bbls 60/40, 135 bbls 180* Diesel while S-Line brushed. S-Line set plug, pumped 2.1 bbls diesel down Tbg. to test plug to 2500. Pump additional 15 bbls Diesel down Tbg. to assist S- Line to set WFR Establish injection rate of 0.4 BPM @ 1600 psi. FWHP= 600/580/330 S-Line on location upon departure. Sundry 322-623 required a CBL be submitted to the AOGCC prior to the well being POI. A CBL was submitted, and an email was sent to Hilcorp, agreeing that the Colville was isolated. -WCB