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Home My WebLink About203-163Nolan 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: 2/4/2026 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20260204 Well API # PTD # Log Date Log Company Log Type AOGCC E-Set# BRU 223-34T 50283202060000 225059 12/31/2025 AK E-LINE Perf T41308 BRU 244-27 50283201850000 222038 1/2/2026 AK E-LINE Perf T41309 CLU 11RD 50133205590000 225013 1/2/2026 YELLOWJACKET SCBL T41310 CLU 11RD 50133205590000 225013 12/19/2025 YELLOWJACKET SCBL T41310 END 1-25A 50029217220100 197075 11/7/2025 HALLIBURTON COILFLAG T41311 END 1-25A 50029217220100 197075 12/26/2025 READ PressTempSurvey T41311 END 2-40 50029225270000 194152 12/18/2025 READ PressTempSurvey T41312 END 2-52 50029217500000 187092 12/24/2025 HALLIBURTON MFC40 T41313 END 2-56A 50029228630100 198058 1/1/2026 HALLIBURTON COILFLAG T41314 END 2-56A 50029228630100 198058 1/19/2026 READ CaliperSurvey T41314 KALOTSA 3 50133206610000 217028 1/14/2026 YELLOWJACKET PERF T41315 KALOTSA 3 50133206610000 217028 1/9/2026 YELLOWJACKET PERF T41315 KALOTSA 8 50133207050000 222003 12/18/2025 YELLOWJACKET PERF T41316 KBU 44-06 50133204980000 200179 12/22/2026 YELLOWJACKET CBL T41317 KBU 44-06 50133204980000 200179 11/12/2025 YELLOWJACKET PLUG T41317 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE CBL T41318 KU 24-07RD 50133203520100 205099 1/6/2026 AK E-LINE Plug/Cement T41318 KU 24-07RD 50133203520100 205099 1/1/2026 AK E-LINE Plug/Cement/TubingPunch T41318 MPI-36 50029236770000 220047 1/19/2026 READ CaliperSurvey T41319 MPI-36 50029236770000 220047 1/19/2026 READ LeakDetectLog T41319 NCIU A-19 50883201940000 224026 1/7/2025 AK E-LINE Perf T41320 NFU 42-35 50231200460000 214170 1/8/2026 YELLOWJACKET PERF T41321 NIK OI24-08 50029234570000 211130 1/19/2026 HALLIBURTON COILFLAG T41322 ODSN-04 50703206700000 213037 1/20/2026 HALLIBURTON LDL T41323 ODSN-22 50703207080000 215054 12/20/2025 READ LeakDetection T41324 PBU 15-11D 50029206530400 225112 1/18/2026 HALLIBURTON RBT-COILFLAG T41325 PBU 15-43 50029226760000 196083 12/21/2025 HALLIBURTON RBT T41326 PBU B-30B 50029215420200 225009 1/24/2026 HALLIBURTON RBT-COILFLAG T41327 PBU C-33B 50029223730200 225096 12/16/2025 HALLIBURTON RBT-COILFLAG T41328 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:10:43 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: PBU D-26B 50029215300200 206098 12/20/2025 HALLIBURTON ISAT T41329 PBU D-26B 50029215300200 206098 12/19/2025 BAKER SPN T41329 PBU F-21A 50029219490100 225019 1/18/2026 HALLIBURTON RBT-COILFLAG T41330 PBU J-21A 50029217050100 225106 1/21/2026 HALLIBURTON RBT-COILFLAG T41331 PBU L-291 50029237790000 224002 12/26/2025 HALLIBURTON RBT T41332 PBU L-291 50029237790000 224002 12/9/2025 YELLOWJACKET RCBL T41332 PBU S-107A 50029220440200 225083 12/8/2025 HALLIBURTON RBT-COILFLAG T41333 PBU S-201A 50029229870100 219092 1/21/2026 HALLIBURTON WFL-TMD3D T41335 PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT T41334 PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D T41334 SRU 223-15 50133207410000 225123 1/29/2026 YELLOWJACKET GPT-PERF T41336 SRU 223-15 50133207410000 225123 1/20/2026 YELLOWJACKET SCBL T41336 SRU 233-10 50133207400000 225113 12/30/2026 AK E-LINE CBL T41337 SRU 233-10 50133207400000 225113 1/10/2026 YELLOWJACKET SCBL T41337 SRU 233-10 50133207400000 225113 1/6/2026 YELLOWJACKET SCBL T41337 SRU 34-28 50133101580000 163007 1/7/2026 YELLOWJACKET Gamma Ray T41338 SU 32-16 50133207380000 225095 1/17/2026 YELLOWJACKET GPT-PLUG-PERF T41339 SU 32-16 50133207380000 225095 11/22/2025 YELLOWJACKET SCBL T41339 SU 43-10 50133207390000 225107 12/10/2025 YELLOWJACKET SCBL T41340 TBU A-12RD 50883200320100 171029 1/2/2026 AK E-LINE StripGun T41341 TBU D-24A 50733202240100 174064 12/4/2025 AK E-LINE TubingPunch T41342 Please include current contact information if different from above. T41334PBU S-24B 50029220440200 203163 12/22/2025 HALLIBURTON RBT PBU S-24B 50029230230100 203163 12/23/2025 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2026.02.05 09:11:00 -09'00' 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:Lau, Jack J (OGC) To:Abbie Barker; Hunter Gates; Oliver Sternicki Subject:RE: Clarification Needed: Completed Sundry 325-721 PBU S-24B (PTD 203-163) Date:Thursday, January 8, 2026 3:07:43 PM Hi Abbie. Yes, you are correct since the wells class and status is not changing the subsequent form should be a 10-404. Thanks for catching that. Also, just a reminder that per the Conditions of Approval “Unable to suspend well without addressing PC leak at 2650' leak. PC Leak at 2650' shall be repaired or P&A'd by 12/31/26 and a sundry application submitted for the repair or P&A by 9/30/26.” Thanks! Jack From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, January 8, 2026 2:56 PM To: Hunter Gates <Hunter.Gates@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: Clarification Needed: Completed Sundry 325-721 PBU S-24B Importance: High Hello Jack, I was reviewing this sundry # 326-721 (attached for reference) in preparation for reporting and need some clarification. Originally, the 10-403 was for Suspending S-24A but based on the AOGCC’s updates to the form & program, the work approved was “Reservoir Abandonment”. Traditionally, that work would not require a 10-407; but the approved 10-403 identifies the form 10-407 as the “Subsequent Form Required” for this work. I believe this is an error and the correct form to submit is a 10-404. Please confirm the correct Subsequent form to be submitted once the work approved by Sundry 325-271 is completed. Thank you, Abbie CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Wednesday, November 26, 2025 10:28 AM To: Abbie Barker <Abbie.Barker@hilcorp.com>; Carrie Janowski <Carrie.Janowski@hilcorp.com>; Cody Dinger <cdinger@hilcorp.com>; Daniel Taylor <dtaylor@hilcorp.com>; Darci Horner <dhorner@hilcorp.com>; Donna Ambruz <dambruz@hilcorp.com>; Gordon Piltz - (C) <Gordon.Piltz@hilcorp.com>; Abhijeet Tambe - (C) <abhijeet.tambe@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com>; Josh Allely - (C) <josh.allely@hilcorp.com>; Juanita Lovett <jlovett@hilcorp.com>; Tom Fouts <tfouts@hilcorp.com> Subject: [EXTERNAL] Completed Sundry 325-721 PBU S-24B Importance: High Hello, Attached is the completed Sundry for PBU S-24B. Thank you, Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 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 Grace Christianson at (907-793-1230) or (grace.christianson@alaska.gov). The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/22/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251222 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# END 1-35 50029216720000 186184 12/3/2025 READ PressTempSurvey T41215 END 2-36 50029220140000 190024 10/20/2025 YELLOWJACKET PLUG-PERF T41216 END 2-38 50029220900000 190129 11/14/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/15/2025 HALLIBURTON WFL-TMD3D T41217 END 2-38 50029220900000 190129 11/22/2025 HALLIBURTON WFL-TMD3D T41217 END 2-48 50029226120000 195166 12/4/2025 READ PressTempSurvey T41218 END 2-60 50029223750000 193083 12/2/2025 READ PressTempSurvey T41219 MPU C-22A 50029224890100 195198 10/13/2025 YELLOWJACKET PERF T41220 MPU I-14 50029232140000 204119 10/15/2025 YELLOWJACKET CUT T41221 MPU R-111 50029238270000 225097 12/3/2025 YELLOWJACKET SCBL T41222 PBU 15-43 50029226760000 196083 11/25/2025 HALLIBURTON TMD3D-SiAct T41223 PBU 15-43 50029226760000 196083 11/23/2025 YELLOWJACKET CBL T41223 PBU C-32E 50029215590500 225102 11/20/2025 HALLIBURTON RBT T41224 PBU F-42A 50029221080100 207093 10/27/2025 YELLOWJACKET CBL T41225 PBU L-202 50029232290000 204196 10/23/2025 YELLOWJACKET RCBL T41226 PBU L-202 50029232290000 204196 10/30/2025 YELLOWJACKET RCBL T41226 PBU S-110C 50029230300300 225086 12/1/2025 HALLIBURTON RBT T41227 PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D T41228 Please include current contact information if different from above. PBU S-24B 50029220440200 203163 11/19/2025 HALLIBURTON WFL-TMD3D Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.12.23 08:27:35 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector S-24B (PTD #2031630) Reservoir P&A complete Date:Thursday, December 11, 2025 11:17:01 AM Attachments:MIT PBU S-24B 12-09-25.xlsx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, December 11, 2025 10:33 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector S-24B (PTD #2031630) Reservoir P&A complete Mr. Wallace, Injector S-24B (PTD #2031630) reservoir P&A was completed on 12/04. An AOGCC witnessed cement tag and MIT-T was performed on 12/09. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity Sent: Sunday, November 16, 2025 2:49 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector S-24B (PTD #2031630) Sustained casing pressure over NOL OA Mr. Wallace, Injector S-24B (PTD #2031630) is a not operable PWI well that is secured with a tubing plug with known PC / packer leak and IAxOA communication. Operations reported a rapid increase in IA & OA casing pressure on 11/16. The IA/OA was bled to production all liquid to ~700 psi however casing pressure climbed to 1393 psi when the bleed was shut in. Injector S-210 (PTD# 219057) operates under AA AIO 25A.021 and requires monitoring and notification to AOGCC with any changes in casing pressure in S-24B. S-210 was shut in and we are now monitoring casing pressure on S-24B. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 12, 2024 12:27 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector S-24B (PTD #2031630) Failed AOGCC MIT-IA Mr. Wallace, The Injector S-24B (PTD #2031630) under eval period has concluded, slickline is scheduled to secure the well with a tubing tail plug in the next 24 hrs. The well is now classified as NOT OPERABLE and remain shut in until tubing integrity is restored. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 14, 2024 3:58 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector S-24B (PTD #2031630) failed AOGCC MIT-IA Mr. Wallace, Injector S-24B (PTD #2031630) failed it’s 4-year AOGCC MIT-IA on 06/14/24. The well has been shut- in, freeze protected and will now be classified as UNDER EVALUATION to secure with a TTP and perform diagnostics. Plan forward: 1. DHD: PPPOT-T/PPPOT-IC 2. SL: Set TTP 3. Fullbore. MIT-T/CMIT-TxIA and establish LLR if fails 4. Elline (Pending): LDL Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 2031630 Type Inj N Tubing 286 2760 2694 2678 Type Test P Packer TVD 8520 BBL Pump 1.3 IA 180 246 247 245 Interval O Test psi 2500 BBL Return 1.2 OA 334 400 398 398 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Hilcorp North Slope LLC Prudhoe Bay / PBU / S Pad Kam St.John Jon Coon 12/09/25 Notes:AOGCC MIT-T to 2500 psi per sundry 325-721 Notes: Notes: Notes: S-24B Form 10-426 (Revised 01/2017)MIT PBU S-24B 12-09-25 From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: S-24B Sundry Program (203-163) Date:Tuesday, December 2, 2025 1:32:59 PM From: Lau, Jack J (OGC) Sent: Tuesday, December 2, 2025 10:42 AM To: 'Hunter Gates' <hunter.gates@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-24B Sundry Program Thanks Hunter. Your change is approved. Jack From: Hunter Gates <hunter.gates@hilcorp.com> Sent: Tuesday, December 2, 2025 10:03 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: S-24B Sundry Program Jack, As discussed, I have updated the procedure with the steps we discussed in red in the attached document. Updated schematic included on the last page. We will split the IA cement squeeze into 2 stages with 2 retainers as opposed to 1 due to the recently discovered leak at 7,900’ MD in the 4.5” tubing. Proposed TOC on the IA will remain unchanged as per the original proposal. TOC in the tubing will now be brought up to 7800’ MD instead of 7900’ MD. Please let me know when we are good to proceed with this plan forward and if you have any questions or comments. Hunter Gates Operations Engineer I M/S/W/Z Pads I Prudhoe Bay West Hilcorp Alaska, LLC Email: hunter.gates@hilcorp.com Cell: (215) 498-7274 Office: (907) 777-8326 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Sent: Monday, December 1, 2025 8:40 AM To: Hunter Gates <hunter.gates@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-24B Sundry Program Thanks for the update. Jack From: Hunter Gates <hunter.gates@hilcorp.com> Sent: Monday, December 1, 2025 8:02 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: S-24B Sundry Program Morning Jack, Quick update on our plan. We will conduct the witnessed tag this morning and then we have a BOP test. Once both of these are completed, we’ll be running in with a hydraulic set test packer to see where the TxIA might be originating from to make sure we don’t get bit on our cement job. Hunter Gates Operations Engineer I M/S/W/Z Pads I Prudhoe Bay West Hilcorp Alaska, LLC Email: hunter.gates@hilcorp.com Cell: (215) 498-7274 Office: (907) 777-8326 From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Sunday, November 30, 2025 4:07 PM To: Hunter Gates <hunter.gates@hilcorp.com> Subject: RE: [EXTERNAL] RE: S-24B Sundry Program Hunter, An AOGCC witnessed tag of TOC will be adequate in place of the failing MITT. Is Hilcorp concerned about the TxIA communication and how it might impact the upcoming IA cement job? Jack From: Hunter Gates <hunter.gates@hilcorp.com> Sent: Sunday, November 30, 2025 12:13 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: Re: [EXTERNAL] RE: S-24B Sundry Program Jack, Our abandonment of the Ivishak was completed last night, all went well on the cementing front. However, our MIT-T is still failing with a LLR of about 1 BPM at ~1000 psi with the IA tracking the whole way. We ran in with a 2" drift BHA and tagged at 9,922' MD. We decided not to go deeper than this to avoid getting stuck so this could be a stringer and not a hard top. I wanted to get in contact with you as we discussed yesterday following the MIT-T. Feel free to call me on my cell 215-498-7274. Get Outlook for iOS From: Hunter Gates <hunter.gates@hilcorp.com> Sent: Saturday, November 29, 2025 12:21:14 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: Re: [EXTERNAL] RE: S-24B Sundry Program Yes sir, that plan works for me. We will move forward with this and try to be as accurate as possible leaving our TOC between 9945' and 9952', conduct the MIT-T and notify you at that point. Thanks for looking into this and getting back to me on a weekend. Get Outlook for iOS From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Saturday, November 29, 2025 12:13:55 PM To: Hunter Gates <hunter.gates@hilcorp.com> Subject: [EXTERNAL] RE: S-24B Sundry Program CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. You approved to bring the reservoir plug cement up in the tubing above the packer (keep TOC below proposed tubing punches at 9945’MD. Still attempt the MITT and notify me if it fails. That work for you? Jack From: Hunter Gates <hunter.gates@hilcorp.com> Sent: Saturday, November 29, 2025 10:46 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: S-24B Sundry Program Jack, See attached. As mentioned on the phone, the packer at 9952’ MD is likely the culprit as the tubing has integrity when a plug is set at 9941’ MD. Hunter Gates Operations Engineer I M/S/W/Z Pads I Prudhoe Bay West Hilcorp Alaska, LLC Email: hunter.gates@hilcorp.com Cell: (215) 498-7274 Office: (907) 777-8326 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 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. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-24B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 203-163 50-029-22044-02-00 ADL 028257, 028258 14155 Conductor Surface Intermediate Liner Liner 8950 80 2640 10154 2684 3078 9975 20" x 30" 13-3/8" 7" 4-1/2" 3-1/2" x 3-1/4" x 2-7/8" 8541 29 - 109 28 - 2668 26 - 10180 10003 - 12687 11077 - 14155 2361 29 - 109 28 - 2668 26 - 8722 8565 - 8919 8923 - 8950 None 2260 5410 7500 10530 9975 5020 7240 8430 10160 10480 - 14060 4-1/2" 12.6# L-80 25 - 100088879 - 8961 Structural 4-1/2" Baker S-3 Perm Packer No SSSV Installed 9952, 8521 Date: Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com 907-777-8326 PRUDHOE BAY 11/22/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.11.21 16:06:59 - 09'00' Torin Roschinger (4662) 325-721 By Grace Christianson at 4:19 pm, Nov 21, 2025 Reservoir Abandonment X 10-407 X DSR-11/24/25J.Lau 11/24/25 A.Dewhurst 25NOV25 *AOGCC witnessed MITT to 500 psi of Ivashak plug TOC. *AOGCC witnessed tag TOC and MITT to 2500 psi of second cement plug. *Send CBL of IA remedial cement to the AOGCC. *Unable to suspend well without addressing PC leak at 2650' leak. PC Leak at 2650' shall be repaired or P&A'd by 12/31/26 and a sundry application submitted for the repair or P&A by 9/30/26. 11/26/25 Secure Well & Reservoir P&A Well: S-24B PTD: 203-163 API: 50-029-22044-02 Well Name:S-24B Permit to Drill:203-163 Current Status:Under Eval, PWI API Number:50-029-22044-02 Estimated Start Date:11/22/2025 Estimated Duration:5 days Regulatory Contact:Abbie Barker Service Lines:SL/CT/EL/FB First Call Engineer:Hunter Gates (215) 498-7274 (M) (907) 777-8326 (O) Second Call Engineer:Tyson Shriver (406) 690-6385 (M) Current Bottom Hole Pressure:Max of 3,500 psi at 8,800 TVDss Expected 3,100 psi at leak point of 6,500 TVDss Last SI WHP:207 psi August 6 th, 2025 Min ID:2.441 @ 12,830 MD XO to 2-7/8 Max Angle:70+ deg starts @ 10,383 MD Last Tag:9,975 XX Plug Brief Well Summary: S-24B is a shut-in Ivishak injector that was planned to be sidetracked to become a Kuparuk injector. Upon screening the well, it was determined that the tubing had integrity, but the production casing did not after failing a CMIT-TxIA. The initial LDL showed two production casing anomalies at 7800 MD (correlates to the top of Kuparuk) and 2650 MD (correlates to old kick off point from S-24A). On 11/16/2025, the IA and OA pressure spiked on S-24B and pressure was attempted to have been bled down but constant returns were noted. The well was then subsequently killed w/ 295 bbls of 9.8 brine. Current pressures on IA and OA are under MOASP. Another LDL was run on 11/19-20/2025 and confirmed leak points in the 7 production asing at 7470 MD and 2650 MD. We plan to perform a reservoir abandonment on the current Ivishak perforations. From here we will perforate the 4.5 tubing right above the production packer and circulate KWF brine to surface in the IA prior to cementing. We will then set a retainer in the tubing and pump cement through the tubing punch, taking returns up the IA, bringing cement top up to 5,000 MD. Then we will unsting from retainer and lay-in cement in the tubing up to 7,900 MD. Current Status/Recent Integrity Tests: Shut-In Not Operable Injector, temp log shows production casing leak. 7/22/2024 MIT-T passed to 2500 psi 7/22/2024 CMIT-TxIA failed to 2500 psi, unable to get up to pressure 8/14/2025 LDL showed IAxOA communications w/ anomalies at ~2700 MD and ~7800 MD 11/19-20/2025 WFL confirmed anomalies at 2650 MD and 7470 MD Facts/Depths About Reservoir: 10,180 MD (8,658 TVDss) is the base of the confining layer above the Ivishak 7,801 MD (6,617 TVDss) is the top of Kuparuk 7,568 MD (6,430 TVDss) is the top of the confining layer above the Kuparuk (HRZ shale) 7,470 MD(lower leak) (6,354 TVDss) is within the Colville 6,349 MD (5,511 TVDss) is the calculated TOC on the backside of the 7 casing 2,650 MD (upper leak) (2,586 TVDss) correlates with the depth of the surface casing shoe 9/6/1999 drilling report states log of 4.5 liner in S-24A shows good to fair cement in liner lap Secure Well & Reservoir P&A Well: S-24B PTD: 203-163 API: 50-029-22044-02 Objective: Plan is to set a cement retainer at 10,000 MD and perform a reservoir abandonment on the Ivishak completion. From here, we will punch holes and circ out to 9.8 ppg br ine right above the packer at 9,950 MD. Then we will set a retainer at 9,940 MD and perform an IA squeeze up to 5,000 MD on the IA. Then we will unsting from the retainer and lay in cement up to 7,800 MD. We will wrap up by pulling a CBL. Request for Suspension: Post repair the well will be mechanically sound with a pressure test of the reservoir plug to 2500 psi. We will be unable to PT the PC leak repair at 7470 MD due to IAxOA leak at 2650 MD. The well will not allow the migration of fluid and will not damage fresh water or producing or potentially producing formations. Will not impair the recovery of oil or gas. Is secure, safe and not a threat to public health. Future utility of the well is as a RWO/ sidetrack candidate. Procedure Slickline 1. MIRU SL. 2. RIH w/ GS and pull XX plug at 9975. 3. RDMO SL. Coil Tubing 1. MIRU service CT. 2. POOH and establish injection rate by pumping into well. MU drift/logging run to 10,200 MD. BHA to include GR/CCL for correlation log to set CICR. 3. POOH and MU cementing BHA and one trip retainer. 4. RIH and set CICR at10,100 MD inside the 4.5 liner. 5. Once set, establish injection rate down CT. w/ FW spacer and once obtained, swap to cement and pump 37 bbls of 15.3 ppg Class G cement or until we see lock up. Unsting from the retainer and lay in 2 bbls of cement bringing cement top inside 4.5 tubing to ~9,970 MD. 6. POOH and BD cementing BHA. 7. MU and RIH w/ 5 perf gun for tubing punch. RIH and perforate at 9,945 MD (above production packer). POOH and LD perf guns. 8. Establish circulation through squeeze holes and circulating out KWF down the tubing taking returns up the IA (9.8 ppg should suffice). 9. POOH and MU cementing BHA and one trip retainer. 10. RIH and set CICR at ~9,935 MD. 11. Once set, establish injection rate w/ FW spacer and once obtained, swap to cement and pump 95 bbls of 15.3 ppg Class G cement (brings cement top to ~5000 MD in the IA) to isolate hole at 7,470 MD. 12. Unsting from CICR and lay-in 31 bbls of 15.3 ppg Class G cement (brings our TOC in the tubing to 7900 MD). Once laid in, swap to KCl and pump pipe displacement while POOH. Pump freeze protect cap from 2500 TVD to surface (39 bbls). Bullhead 50 bbls of FP down IA. 13. Finish POOH & BD cementing BHA. 14. RDMO CT. Cement Volumes for Coil Tubing Pumping: 2-7/8 x 3-3/16 x 3-1/2 x 4.5 (below CICR @ 10,100 MD(8,587 TVDss)) = 37 bbls of cement ~130 of cement on top of CICR at 10,100 MD up to ~9,970 MD (8,473 TVDss) = 2 bbls of cement 4-1/2 x 7 annulus from punch holes at 9,945MD (8,451 TVDss) up to 5,000 MD (4,494 TVDss) = 92 bbls of cement *AOGCC Witnessed MITT of TOC to 500 psi. - JJL Secure Well & Reservoir P&A Well: S-24B PTD: 203-163 API: 50-029-22044-02 4-1/2 tubing from CICR at 9,935 MD (8,442 TVDss) up to 7,900 MD (6,698 TVDss) = 31 bbls of cement Cement Type/Weight: Class G 14-16 ppg Bottomhole Static Temp (Ivishak): 190-200 F Bottomhole Static Temp (Kuparuk): 130 F Fluid Loss: 20-200 cc/30 min Thickening Time:Minimum 6 hours Slickline 1. AOGCC witnessed TOC tag. MIRU SL. RIH to drift and tag TOC in 4.5 tubing. E-line/Fullbore 1. AOGCC witnessed MIT-T to 2500 psi max applied pressure. 2. MIRU EL. RIH w/ GR/CCL/CBL and pull from TOC to 4,500 MD to log TOC in the IA. Attachments: Current Wellbore Schematic Proposed Wellbore Schematic Sundry Change Form Secure Well & Reservoir P&A Well: S-24B PTD: 203-163 API: 50-029-22044-02 Current Wellbore Schematic: Secure Well & Reservoir P&A Well: S-24B PTD: 203-163 API: 50-029-22044-02 Proposed Wellbore Schematic: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: November 21, 2025Subject: Changes to Approved Sundry Procedure for Well S-24BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) first call engineer. AOGCC written approval of the change is required before implementing the change.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector S-24B (PTD #2031630) Sustained casing pressure over NOL OA Date:Tuesday, November 18, 2025 2:36:06 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Sunday, November 16, 2025 2:49 PM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector S-24B (PTD #2031630) Sustained casing pressure over NOL OA Mr. Wallace, Injector S-24B (PTD #2031630) is a not operable PWI well that is secured with a tubing plug with known PC / packer leak and IAxOA communication. Operations reported a rapid increase in IA & OA casing pressure on 11/16. The IA/OA was bled to production all liquid to ~700 psi however casing pressure climbed to 1393 psi when the bleed was shut in. Injector S-210 (PTD# 219057) operates under AA AIO 25A.021 and requires monitoring and notification to AOGCC with any changes in casing pressure in S-24B. S-210 was shut in and we are now monitoring casing pressure on S-24B. The well is now classified as UNDER EVALUATION and on a 28 day clock to be resolved. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 12, 2024 12:27 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector S-24B (PTD #2031630) Failed AOGCC MIT-IA Mr. Wallace, The Injector S-24B (PTD #2031630) under eval period has concluded, slickline is scheduled to secure the well with a tubing tail plug in the next 24 hrs. The well is now classified as NOT OPERABLE and remain shut in until tubing integrity is restored. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 14, 2024 3:58 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector S-24B (PTD #2031630) failed AOGCC MIT-IA Mr. Wallace, Injector S-24B (PTD #2031630) failed it’s 4-year AOGCC MIT-IA on 06/14/24. The well has been shut- in, freeze protected and will now be classified as UNDER EVALUATION to secure with a TTP and perform diagnostics. Plan forward: 1. DHD: PPPOT-T/PPPOT-IC 2. SL: Set TTP 3. Fullbore. MIT-T/CMIT-TxIA and establish LLR if fails 4. Elline (Pending): LDL Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Christianson, Grace K (OGC) To:Brooks, James S (OGC); Gluyas, Gavin R (OGC) Subject:This 403 Sundry application has not been approved Date:Thursday, October 9, 2025 3:22:06 PM Attachments:Sundry_325-493_NTAVP_100925.pdf Importance:High This sundry application for PBU S-24B has not been approved. Attached is the paperwork for this and has been added to the wells folder. Thank you, Grace Grace Christianson Executive Assistant, Alaska Oil & Gas Conservation Commission (907) 793-1230 By Grace Christianson at 1:32 pm, Aug 20, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.08.20 10:56:51 - 08'00' Sean McLaughlin (4311) 325-493 JJL 9/5/25 DSR-9/10/25 Approved to set whipstock. Approval of the S-24B reservoir abandonment will be addressed on a separate sundry. 10-407 NOT APPROVED 10/09/25 NOT APPROVED 10/09/25 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: August 20, 2025 Re:S-24B Sundry Request Sundry approval is requested to set a whipstock in the S-24B wellbore as part of the drilling and completion of the proposed S-24C CTD lateral. Proposed plan: Prior to drilling activities, Ivishak perforations will be abandoned and the 4-1/2x7" annulus will be cemented above the production packer (see separate sundry). Following abandonment work, screening will then be conducted to drift for whipstock, caliper, CBL and MIT. E-line will set a 4-1/2" packer whipstock. If unable to set the whipstock pre-rig, the rig will perform that work. See S-24C PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to pre-rig, the rig will set the 4-1/2" packer whipstock and mill a dual string 3.80" window + 10' of formation. The well will kick off drilling and lands in the Kuparuk C. The lateral will continue in Kuparuk C, B and A to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8 L-80 solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This pre-rig abandonment (separate sundry) will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in September 2025) 1. P&A : Ivishak abandonment and cement 4-1/2"x7" IA (see separate sundry) 2. Slickline : Dummy WS drift, CBL and caliper if needed. 3. E-Line : Set 4-1/2" Packer Whipstock* at 7,805 MD at 0 degrees ROHS 4. Fullbore : MIT-IA and/or MIT-T to 2,500 psi (min) 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. *P&A Not approved on this sundry -JJL 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job,( ) q p q p g g p packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. Rig Work: Reference S-24C Permit submitted in concert with this request for full details. 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,361 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80 Dual String 4-1/2"x7" Window 3. Drill build section: 4.25" OH, ~172' (35 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,967' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2 x 3-1/4 x 2-7/8 L-80 solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job*: 38 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL. Set LTP*. If high losses are encountered during cement job and it is deemed necessary, a cement down squeeze from TOL to loss zone will be performed with the rig or service coil (if performed by service coil see future sundry). 7. Only if not able to do with service coil extended perf post rig Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Alternate plug placement variance request per 20 AAC 25.112(i) Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : Contingent set LTP*. 3. Fullbore : MIT-IA to 2500 psi Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3"or 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 24, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC S-24B PRUDHOE BAY UNIT S-24B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2024 S-24B 50-029-22044-02-00 203-163-0 W SPT 8521 2031630 2130 1181 540 4YRTST F Kam StJohn 6/14/2024 4 Year. Could not get IA up to test pressure so well was shut in.No change in Tubing ar OA pressures. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT S-24B Inspection Date: Tubing OA Packer Depth 52IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS240614111518 BBL Pumped:10 BBL Returned: Wednesday, July 24, 2024 Page 1 of 1 9 9 9 9 9 9 99 9 9 9 9 9 Could not get IA up to test pressure so well was shut in F 10 James B. Regg Digitally signed by James B. Regg Date: 2024.07.24 14:34:28 -08'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: Injector S-24B (PTD #2031630) Failed AOGCC MIT-IA Date:Monday, July 15, 2024 10:03:03 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, July 12, 2024 12:27 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: NOT OPERABLE: Injector S-24B (PTD #2031630) Failed AOGCC MIT-IA Mr. Wallace, The Injector S-24B (PTD #2031630) under eval period has concluded, slickline is scheduled to secure the well with a tubing tail plug in the next 24 hrs. The well is now classified as NOT OPERABLE and remain shut in until tubing integrity is restored. Please call with any questions or concerns. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 14, 2024 3:58 PM To: chris.wallace@alaska.gov Cc: jim.regg <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector S-24B (PTD #2031630) failed AOGCC MIT-IA Mr. Wallace, Injector S-24B (PTD #2031630) failed it’s 4-year AOGCC MIT-IA on 06/14/24. The well has been shut- in, freeze protected and will now be classified as UNDER EVALUATION to secure with a TTP and perform diagnostics. Plan forward: 1. DHD: PPPOT-T/PPPOT-IC 2. SL: Set TTP 3. Fullbore. MIT-T/CMIT-TxIA and establish LLR if fails 4. Elline (Pending): LDL Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector S-24B (PTD #2031630) failed AOGCC MIT-IA Date:Tuesday, June 18, 2024 8:13:47 AM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, June 14, 2024 3:58 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UNDER EVALUATION: Injector S-24B (PTD #2031630) failed AOGCC MIT-IA Mr. Wallace, Injector S-24B (PTD #2031630) failed it’s 4-year AOGCC MIT-IA on 06/14/24. The well has been shut- in, freeze protected and will now be classified as UNDER EVALUATION to secure with a TTP and perform diagnostics. Plan forward: 1. DHD: PPPOT-T/PPPOT-IC 2. SL: Set TTP 3. Fullbore. MIT-T/CMIT-TxIA and establish LLR if fails 4. Elline (Pending): LDL Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Permit Number: 203-163-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday, June 15, 2020 P.I. Supervisor (�JLj �I jG1 SUBJECT: Mechanical Integrity Tests ozew -L l 15 Min 30 Min 45 Min 60 Min Well S-2413 Type jnI K' 'TVD 8�ITubing 692 BP Exploration (Alaska) Inc. 694 - S -24B FROM: Bob Noble 2031630 Type Test SPT Test psi PRUDHOE BAY UNIT S -24B Petroleum Inspector 34 2so6 Ste; Inspector 2460 Reviewed By: P.L Supry �lz NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S -24B API Well Number 50-029-22044-02-00 Inspector Name: Bob Noble Permit Number: 203-163-0 Inspection Date: 6/6/2020 i Insp Num: mitRCN200606170348 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-2413 Type jnI K' 'TVD 8�ITubing 692 694 - 693 693PT)� 2031630 Type Test SPT Test psi 2 34 2so6 2470 ' 2460 BBL Pumped: 2.1 BBL Returned: 2.1 OA 552 - 553 ' 554 555 Interval 4YRTST Phi --- — — Notes: Monday, June 15, 2020 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Regg f DATE: Monday,June 13,2016 P.I.Supervisor I .e Z �`i3�I SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. S-24B FROM: Jeff Jones PRUDHOE BAY UNIT S-24B Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S-24B API Well Number 50-029-22044-02-00 Inspector Name: Jeff Jones Permit Number: 203-163-0 Inspection Date: 6/4/2016 Insp Num: mitJJ160608085657 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-24B Type Inj W'TVD 8521 Tubing I 748 748 - 748 - 750 - PTD 2031630 ' Type Test SPT'Test psi 2130 - IA 126 2479 - 2477 2478 . Interval I4YRTST P/F P '/ OA 636 636 - 639 640 - Notes: 1 well inspected,no exceptions noted. - SCANNED DEC 2 9 2016 Monday,June 13,2016 Page 1 of 1 STATE OF ALASKA htt..tiVED - A. AKA OIL AND GAS CONSERVATION COMM. .,ION MAR 0 2 2015 • REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon CI Repair Well CIPlug Perforations El Perforate El Other ❑ AOGCC Performed: Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4 Well Class Before Work: 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory❑ 203-163-0 3 Address P O Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-22044-02-00 7.Property Designation(Lease Number) 8 Well Name and Number: ADL0028258 PBU S-24B 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: Total Depth measured 14155 feet Plugs measured None feet true vertical 5949 82 feet Junk measured None feet Effective Depth measured 14121 feet Packer measured See Attachment feet true vertical 8953 95 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 29-109 29-109 0 0 Surface 2636 9 13-3/8"68#L-80 28 5-2665 4 28 5-2665.25 5020 2260 Intermediate 10145 89 7"26#L-80 26 72-10172 61 26 72-8715 34 7240 5410 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10480-10510 feet 10620-10650 feet 10670-10700 feet 10890-10920 feet 13475-13500 feet 13725-13750 feet 13945-13965 feet 14010-14023 feet 14023-14048 feet 14048-14060 feet True Vertical depth 8879 43-8884 97 feet 8894 89-8896 33 feet 8897 27-8898 72 feet 8909 22-8911.22 feet 8961 89-8959.2 feet 8968 1-8971 feet 8975 46-8973 22 feet 8967 57-8965 95 feet 8965 95-8962 85 feet 8962 85-8961 34 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#L-80 24 53-10007 73 24 53-8569 54 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) CANNED (_1,, Treatment descnptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 930 40 1082 Subsequent to operation 0 0 1082 60 1602 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil ❑ Gas ❑ WDSPL El GSTOR ❑ WINJ 0 WAG ❑ GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.CatronBP.Com Printed Name Garry Catron Title PDC PE Signature r _- Phone 564-4424 Date 2/27/2015 I viz, 3 /ii/1,� RBDMS MAR - 5 2015 �'"_ / Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028258 SW Name Type MD TVD Depscription S-24B PACKER 9951.67 8520.53 4-1/2" Baker S-3 Perm Packer S-24B PACKER 10003.11 8565.49 5" Baker ZXP Top Packer w � 0ocn C0 CO0 C (0 N N V co 0 0 Lo CD M N M 7 N c O ct m co O do U) N M U) co co co,� O N LO O O 0 0 v N O CO N- 0 CO 0 0 0 1 ) O 00 CO CO N CO H N O N .7 O M M Ln O'N 00 • O N co co N N N N N O CO CO O N CO CO CO CO M 1� O O 000 O O O O N M O C O N N N coCU CO 2 o I� Q N o � OMN- Cv) 00 �CO N N O 00 O ' N N CV C O _ • 0 � J 9 0 . 02 p 0 Q aoaoa000ppao O C N co co .41x0 0 *kN 0 0 N •� N O N _ _ O 00 ♦� N CV o (V \ M N VM M 4 N M M r' 4 r O H O 0N- C) O Nr CO N N O co 00 B co N Cv) O r N 00) w =0a 5 H I-1-1 � � � QC zwwwww'wm U Z J J J J O 8 -. . a e 60 C co , \ fE � fC 0 a (N w = m . / o-� # (0 0 £ A U 0kz � f © PCZ cC 2 t » / m 3 § ƒ @9 % � I [ — Qyp \ § 02 U) e _ $ ° c 0 0 0 E/ . 2 = 7 0 2 I P $ ~ � z.,,,, ca 2bo I_ k \ , _c f c 7 f 22t &/ # 0)'O IO 7 / 2 \ E / n- . Cr) /$ § 7 O m # b \ q = 1 0 ea \ N. # & - ■ E (0 / ± c § - / c E § "-§ / oCC °- �ƒ m A =_ Q \ •- -I .- 0 cti k � �2 \ 00 0 % 2 f0CU0D k2 = cm 2 % § / \ / a)a = O & « O -.-C, ® CL 0q / � ± \ / 7k � � f / # o 3 % _0 \ c @ b I ( S + (aoolr � Om .c2 _ / D ® � f ' / / O e - c .t a 5 & \ 2 c 0_A 2 a — 0 o J o < f c o . , g . / 2 b 0) cn f - / / � E / % § mom / ocK rb / § m � Eal > tEE % > c D -cc - > a, 0Ef9 & v/ / f © // ® / / ¢ - / 9 '� -0E29 @ = 2 't2 � oa28 p »H = = e H E 9 « f e E \ R Q p . © % Oco- c \ » _ 0 7 § _ E _ % 7a_ t 4, 0 c ® b E \ % _ 1 \ ® b ® W / % i. \ cv' @b _= % 0 ? \ ' f / c .c ) g % & - � � � / / � a \\ / E E % \ 6 a o E \ 6 0 a® j ✓ 2 w s- D M 2 D - _ 4 - g r 2 D U E ® t = 27 ® f « $ ca / % # pa) 475 o22 / / _0- \ 0 / \ 2ggdo/ 0G0 f 002 = 0 000uJ H000a. E - - n r r G \ 7 g m & CO & CD C 9 9 TTS= 4-1/16"CNV — s. Y NOTES: WELL ABITUA OR McEVOY S m2 B H2S ,READINGS AVERAGE 125 ppm WHEN ON MI AC�TIIJATOR= UNCNOVVN KB.BEV= 66.25' I ***MAX DOGLEG:28.8°(off 12899'*** BF.ELEV= 37.05' KOP= 2650' Max Angle= 97°@ 14076' ' ' 2195' H4-1/2"HES X NP,ID=3.813" Datum MD= 10430' Datum TVD= 8800'SS 13-3/8"CSG,68#,L-80 BUTT,D=12.415" H 2668' _ , 2669' H9-5/8*TOC RI[9-5/8-MLLE)OUT CSG STUB �-r 2739' I . F3SV(08/09199) —{ 3020' 444 9-5/8"MLLOUT WINDOW(S-24A)2669'--2745' 1 V, Minimum ID =2.387" @ 12830' 1 I 9941' H4-1/2"FES X N ,D=3.813" 3-3/16" X 2-7/8" XO z X 9952' -f7"X 4-1/2"BKR S-3 PKI.D=3.875" I I 9975' —14-1/2"FE.S X NP,D=3.813" ' ' 9996' 4-1/2"FES XN NP,D=3.80"-MLLED(10/18/03) 10003' H 'X 5"BKRZXP PKR w/I-MAC HGR,ID=4.375" 4-1/2'TBG,12.6#,L-80 NSCT, H 10006' 7 1-4 10008' —14-112"W/LEG,D=4.00" .0152 bpf,13=3.958" 10004' —ELND TT LOGGED 09/24/99 10024' --I5"X 4-1/2"XO,D=3.958' 4--.-I L-� 11077' H3.70"BKR DECOY SLV,D=3.0" 3-1/2"LIR,8.81#,L-80 STL, — 11129' 1 11097' —13-1/2-HES X NIP,D=2.813" .0087 bpf,13=2.992" 7-CSG,26#,L-80 BTC-M,.0383 bpf,D=6.276" -{ 10180' 7 11129' —13-1/2"X 3-3/16"XO,13=2.786" I 4-1/2"LNR --I12.6#,L 80 BT-M - 12687' f .0152 bpf,ID=3.958" 0 f , 4 PERFORATION SUW*AAR1 f MLLOUT WINDOW(S-248)T 12U 4-1/2"SHOE @ 12687' RIEF LOG: SFERRY MVVD EWR ANGLE AT TOP PERE:76°@ 10480' Itikeltp:titcr. Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT Sol 2.88" 6 10480- 10510 0 01/30/15 434444, "-N. 12830' _-13-3/16"X 2-7/8"X0,D=2.387" 2.88' 6 10620-10650 0 10/29/15 1►e 2.88" 6 10670-10700 0 10/29/15 'i 2.88" 6 10890- 10920 0 10/29/15 3-3/16"LNR, 12830' ' ''.', 2" 6 13475- 13500 0 07/10/04 6.2#,L-80 TCN, 6r 2' 6 13725- 13750 0 07/09/04 'a' ' .0076 bpf,D=2.80" '� 2" 6 13945- 13965 0 04/27/04 PBTD -4 14121' 2' 6 14010- 14060 0 11/12/03 .1t 2" 6 14023- 14028 0 11/12/03 2-7/8"LNR,6.16#,L-80 STL, —I 14155' .0058 bpf,113=2.441" DATE REV BY COMVBJTS (ATE REV BY COMMENTS PRUDHOE BAY MIT 05/12/90 N18E INITIAL COMPLETION 01/30/15 BLS/PJC ADPERFS(01/29-01/30/15) WELL: S-24B 09/07/99 N9ES SIDETRACK(S-24A) 02/02/15 PJC CORRECTIONS-CSG,TBG,SET NOTE PU MT No: `2031630 11/13/03 NORDIC 1 CTD SDTRACK(S-24B) AFI No: 50-029-22044-02 02/28/12 PJC MLLOUT WINDOW CORRECTION SEC 35,T12N,T12E, 1633'FNL&1050'FWL 11/20/12 PJC S-24B MLLLOUT WINDOW 01/30/15 BLS/PJC ADPERFS(01/29-01/30/15) BP Exploration(Alaska) Image p'ect Well History File co!r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q3 - J b3 Well History File Identifier Organizing (done) ~o-sided 1111111111111111111 D Rescan Needed 11111111111" 111111 RES CAN DIGITAL DATA OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Color Items: D Greyscale Items: D Diskettes, No. D Other, NolType: D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date I J-j'1 Ios- I D Other:: BY: ~ /5/ VltP Project Proofing 1111111111111' "III BY: Date: /5/ BY: Date: + :3 = TOTAL PAGES b3 (Count does not include cover sheet) /5/ Scanning Preparation c2. Production Scanning 11111111I11I11 "III Stage 1 Page Count from Scanned File: (P LJ- (Count does include cover sheet) Stage 1 Page Count Matches Number in Scanning Preparation: ~~~ Date Ja.-/ ttj Ios- If NO in stage 1, page(s) discrepancies were found: V YES NO YES /5/ Wi P NO BY: BY: Maria Date: /5/ 11111111111111" III Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 "III BY: Maria Date: /5/ Comments about this file: Quality Checked 11111111111111111/1 1 0/6/2005 Well History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday June 26 2012 TO: Jim Regg P.I. Supervisor s L (( v SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -24B FROM: Lou Grimaldi PRUDHOE BAY UNIT S -24B Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv NON CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT S - 24B API Well Number 50 029 - 22044 - 02 - 00 Inspector Name: Lou Grimaldi Permit Number: 203 - 163 - Inspection Date: 6/8/2012 Insp Num: mitLG120608134700 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-24B ' Type Inj W ' TVD 8521 IA 1 255 2508 ' 2474 2468 . PTD 2031630 ' Type Test SPT Test psi 2130 OA 598 597 597 597 . Interval 4YRTST P/F P ' Tubing 1568 - 1565 1567 1578 Notes: 2.0 bbl's pumped, 1.8. Returned. Good stable test. SulltiMED JUU 2 3 'D 1 Tuesday, June 26, 2012 Page 1 of 1 . • ~ BP Exploration (Alaska) Inc. ~ Attn: Well Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 9 ~ Enclosed piease find a spreadsheet with a list of wells from S-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, 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, . rg~Y~° ~~ Y ~ W ~ ~ ~ c ;, ;~~,~~,~+-'~ ~ ~ ~" ~.. i;,,r Torin Roschinger BPXA, Well Integrity Coordinator • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Oparetions (10-404) Spad ~ IlA}A fi/25/2009 Well Name PTD # initial top of cement Vol. of cement um ed Final top of cement Cament top off date Conosion inhibitor Corrosion inhibitoA sealant date f[ bbis it na al S-O18 1952020 025 NA 0.25 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 5-03 1811900 1325 NA 1325 NA 92.&5 5/20/2009 S-04 1830790 0 NA 0 NA O.s 5/25/2009 S-OSA 1951890 0 NA 0 NA O.s 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26I2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA ~9.4 5/31/2009 S-10A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/7/2009 S-t3 1827350 8 NA 8 NA 55.3 6/1/2009 5-75 1840170 025 NA O25 NA 3 6/2/2009 S-17C 2020070 025 NA 0.25 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 5-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 0.25 NA 025 NA 1.3 5/79/2009 S-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 -248 2031630 0.5 NA 0.5 NA 2.8 5/ZS/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 S-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29A1t 1960120 0 NA 0 NA 0.85 5/27/2009 S-30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1927020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1927360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 NA .BSin 5/31/2009 S36 1921160 075 NA 075 NA 425 5/27/2009 S37 1920990 125 NA 125 NA 11.9 5/27/2009 S38 1921270 025 NA 025 NA 102 5/27/2009 S-4t 1960240 1.5 NA 1.5 NA it.t 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 025 NA 1.7 5/28/2009 S-100 2000780 2 NA 2 NA 21.3 5/29/2009 S-101 2001750 125 NA 125 NA 71,9 5/29/2009 5-102L1 2031560 125 NA 125 NA 71.1 5/31/2009 5-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-704 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-~o5 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2010120 16.25 NA 1625 NA 174.3 6/2/2009 5-107 2011130 2.25 NA 225 NA 28.9 5/18/2009 S-7oe 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-10s 2022450 2 NA 2 NA 21.3 5/30/2009 S-110 2017290 11.75 NA 11.75 NA 98.8 5/30/2009 5-11~ 2050510 2 NA 2 NA 19.6 5/30/2009 S-172 2021350 0 NA 0 NA o.5 5/30/2009 S-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 5-114A 2021980 1.25 NA 125 NA 10.2 5/30/2009 5-715 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-776 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-119 2032000 5 NA 5 NA 76.5 5/29~2009 S-tts 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-121 2060410 4.5 NA 4.5 NA 53.8 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 S-723 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-t24 2061360 175 NA 1.75 NA v.9 5/26/2009 S-t25 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 125 NA 15.3 6/1/2009 S-200 1972390 125 NA 125 NA 14.5 5/28/2009 5-201 2001840 0 NA 0 NA 0.85 6/19I2009 5-213A 2042130 2 NA 2 NA 13.6 ~ 5/29l2009 5-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-277 2070950 025 NA 025 NA 1.7 6/1/2009 5-400 2070740 2 NA 2 NA 9.a 5/28/2009 5-401 2060780 16 NA i6 NA 99.5 6/2/2009 S-50a 0 NA 0 NA 0.85 5/28/2009 C~ J ~® ~~~ • TO: / Pim RPgg isor 1 ~ ~ ~ 7( 5t 1~~ FROM: Jeff Jones Petroleum Inspector State ®f Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 30, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-24B PRUDHOE BAY UNIT 5-24$ Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. SuprvJ`~?~-- Comm Well Name: PRUDHOE BAY UNIT S-24B IIISp Num: mitJJ08 0623 1 7 1 0 50 Rel Insp Num: API Well Number 50-029-22044-02-00 Permit Number: 203-163-0 Inspector Name• Jeff Jones Inspection Date: 6~23~2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ S-24B Type Inj. ~ W ~ TVD ~ 8520 ~ IA i 690 j 2350 ~ 2325 ~ 2325 P.T. ~ 2031630 TypeTCSt SPT Test psi II 2130 ~ OA I, 660 660 660 660 'I Interval 4YRTST Pte, P / Tubing I 1410 ii 1410 i 1410 i 1410 Notes: 1.4 BBLS methanol pumped, no exceptions noted. '~filf~ AllG ~ ~ 208 Monday, June 30, 2008 Page I of 1 • • ~. ~- ~. F~~ MICROFILMED 03!01 /2008 DD NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_Inserts~R~ficrofilm Marker.doc e e WELL LOG TRANSMITTAL VIe; d D 3; - IÚJ!J To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 fÔLcU6 RE: MWD Fonnation Evaluation Logs S-24B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 S-24B: LAS Data & Digital Log Images: 50-029-22044-02 1 CD Rom ~ )3 ~ DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 _.~^_._-~._-------~~ Current Status 1WINJ Jf1~ 7 1Jo.. ^~~ 1- API No. 50-029-22044-02-00 ~..... Permit to Drill 2031630 Well Name/No. PRUDHOE BAY UNIT S-24B Operator BP EXPLORATION (ALASKA) INC MD 14155 /TVD 8950 ..--- Completion Date 11/13/2003"'- -~-_...- REQUIRED INFORMATION Mud Log No Samples No Directiona~y ~.~ ~~-------------------'--'-----------'-~-- ..- -_._-------------_._-~----~-~--_.~--------~-------_._-- ~---_.._._---------- -_._~- DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR, MGR CCL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH / Start Stop CH . Received Comments - i ~~t Directional Survey 12643 14155 Open 12/8/2003 ED D Las 12402 I nd uction/Resistivity 1-5 12493 14128 Open 2/12/2004 GR, EWR4, ROP ED D Las 12402 Rate of Penetration I)..,,: f.i ~~,.. I,J/f· 1-5 12493 14128 Open 2/12/2004 GR, EWR4, ROP ! ~ A..t I nQl.I~tie R,'R¿~;;;,L;~ ity 1..1 oS 1-5 12493 14128 Open 2/12/2004 GR, EWR4, ROP i 1-49 Q,:,!<¡> Qf DIji- stl'8tion 1--i 1~Aa~ 1.ð.1?A r\p'iR J'. ')170Q4 CR, i"IRA, ~Q~ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ì I - ADDITIONAL INFORM&ION Well Cored? Y ~ Daily History Received? G)N ~ . Chips Received? ~ Formation Tops Analysis Received? ~ Comments: ~ Date: ~~ ~ ) "'-- '"' Compliance Reviewed By: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS . . ..... 1. Operations Performed: Abandon D Repair WellD PluQ PerforationsD Stimulate ŒJ OtherD Alter Casing D Pull TubingD Perforate New Pool D WaiverD Time ExtensionD Change Approved Program D Operation ShutdownD Perforate IKJ Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development D ExploratoryD 203-1630 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic D ServiceŒ 50-029-22044-02-00 7. KB Elevation (ft): 9. Well Name and Number: 63.77 S-24B 8. Property Designation: 10. Field/Pool(s): ADL-028258 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 14155 feet true vertical 8949.8 feet Plugs (measured) None Effective Depth measured 14121 feet Junk (measured) None true vertical 8954.0 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 27 - 107 27.0 - 107.0 1490 470 Liner 2684 4-1/2" 12.6# L-80 10003 - 12687 8565.4 - 8919.4 8430 7500 Liner 52 3-1/2" 9.3# L-80 11077 - 11129 8922.7 - 8928.3 10160 10530 Liner 1701 3-3/16" 6.2# L-80 11129 - 12830 8928.3 - 8920.5 Liner 1325 2-7/8" 6.16# L-80 12830 - 14155 8920.5 - 8949.8 13450 13890 Production 10153 7" 26# L-80 25 - 10178 25.0 - 8720.1 7240 5410 Surface 2640 13-3/8" 68# N-80 26 - 2666 26.0 - 2665.9 4930 2270 Perforation depth: Measured depth: 13475 -13500,13725 -13750,13945 -13965,14010 -14023,14023 -14048,14048 -14060 True vertical depth: 8961.89 - 8959.2, 8968.1 - 8971, 8975.46 - 8973.22, 8967.57 - 8965.95, 8965.95 . 8962.85, 8962.85 - 8961.34 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 25 - 10008 RECEIVED Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer @ 9952 SEP 1 5 2004 5" Baker ZXP Liner Top Packer @ 10003 lU"..I,,, na 11. r..... ('I....... ~ 12. Stimulation or cement squeeze summary: Anchorage Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl I Gas-Mcf I Water-Bbl CasinQ Pressure Tubing Pressure Prior to well operation: Never Injected or Produced 780 Subsequent to operation: 0 I 0 I -1012 700 1648 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD Service 00 Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations. ! OilD GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact Garry Catron 304-200 Printed Name Garry Catron Title Production Technical Assistant Signature j-ihA ~. ("'~:;f-;- _ Phone 564-4657 Date 9/10/04 fI - . 1\ , Form 10-404 Revised 4/2004 \' GY\\l}\ t:- . ..' ". ~~ øtï.. SEP 15 luü\ ~~ t1tIJUrJ . . S-248 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/09/04 CTU 9; PERF BREAKDOWN. MURU. MU BOT 2.25" OD MHA W/PDS IN 2.2" OD CARRIER W/2.0" OD JSN AND RIH. LOG FROM 13,875' CTM TO 13,250' CTM W/STOPS AT 13,700' CTM AND 13451' TO FLAG COIL. LAY IN FLO PRO W/LUBTEX AND SWAP WELL TO DIESEL WHILE POOH TO SLICK UP AND UNDERBALANCE WELL FOR PERFORATING. MU 25' OF 2" 2006 PJ HMX 6 SPF AND RIH. SHOOT GUN # 1 INTERVAL FROM 13,725'- 13,750'. GOOD INDICATION SHOTS FIRED. POOH. CONTINUE ON 07-10-04 WSR,. 07/10104 CTU # 9. PERFORATINGI BREAKDOWN. CONTINUE FROM 07-09-04 WSR. SURFACE WITH GUN # 1. ALL SHOTS FIRED. MU BOT 2.25" OD MHA AND GUN # 2,25', 2.0" OD, 6 SPF, 2006 PJ HMX PERF GUNS. PERFORATE FROM 13,475' TO 13,500' AND POOH. ALL SHOTS FIRED. MU 2.0" OD JSN AND RIH. CLEAN OUT LINER FROM 14,080' CTM W/FLO PRO SWEEP AND CIRCULATE OUT. RECOVERED FIND SAND AND PERF GUN DEBRIS. PERFORM INJECTIVITY TEST WITH FILTERED SW, INITIAL RATE WAS .5 BPM @ 1912 PSI. INCREASED INJECTION PRESSURE. CONTINUE ON 07-11-04 WSR. 07/11/04 CTU # 9. BREAKDOWN/INJECTIVITY TEST. CONTINUE FROM 07-10-04 WSR. PERFORM INJECTIVITY TEST AFTER PERFORATING AND FCO.COMPLETED BREAKDOWN. INITIAL INJECTIVITYWITH FILTERED SW AFTER PERFORATING WAS.5 BPM @ 1912 PSI. SAW GOOD BREAKOVER AT APPROXIMATELY 2350 PSI W/5 BPM. FINAL INJECTIVITY AT SUSTAINED TARGET RATE OF 2000 PSI WAS 2.7 BPM. FREEZE PROTECT TUBING TO 2500' PER PAD OPERATORS REQUEST DUE TO GC-2 SHUT DOWN WORK. PERFORM WEEKLY CHAIN INSPECTION.«< JOB COMPLETE »> FLUIDS PUMPED BBLS 10 50/50 Methonal 762 Filtered SeaWater 73 FloPro 24 FloPro with 3% Lubtex 351 Diesel 1220 TOTAL Page 1 TREE = WELLHEAD = AcrLIA TOR= KB. 8.EV - BF. 8.EV = KOP- Max Angle = Datum MD = DatumTVD - 4-1/8" CIW M:;BlOY AXELSON 64.77' 35.43' 2782' 97 @ 14076' 10430' 8800'SS 13-318" CSG, 68#, N-80, ID = 12.415" Minimum ID = 2.377" @ 12830' TOP OF 2-7/8" LINER 8-248 SAFETY NOTES: 9·5/8" CSG CUT, PUllED & MILLS) FROM SURFACE TO STUB@ 2739' HORIZONTAL LNR 70° @ 10383' & 900@ 11758'. ORIGINAL WELlBORE NOT SHOWN ON DIAGRAM. TOP OF 4-1/2" LNR 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID -3.958" 3-3116" LNR, 6.2#, L-80, ..0075 bpf, ID = 2.786" 11131' 7" LNR, 26#, L-80 MOO, .0383 bpf, ID = 6276" 10180' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 12687' 1 ÆRFORA TlON SLMMARY REF LOG: SÆRRY MoND EWR ANGLE AT TOP PERF: 95 @ 13475' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2" 6 13475 - 13500 0 07/10/04 2" 6 13725- 13750 0 07/10/04 2" 6 13945 - 13965 0 04/28/04 2" 6 14010-14060 0 11/13/03 . 2195' 4-1/2" HES SSSV NIP, ID = 3.813" 9941' 9952' 9975' 9996' 4-1/2" X NP, D = 3.813" 10004' ELM) TT LOGG8) 09/24/99 10008' H4-1/2"W/LEG, ID= 4.00" 1107T 3.70" BKRDEPLOYrv£NTSLV, ID =3.0" 1109T 11129' 3-1/2" HES X NIP,ID = 2.813" 3-1/2" X 3-3/16" XO, ID = 2.786" 12830' 3-3116" X 2-7/8" XO, ID = 2.440" 2-7/8"LNR, 6.16#, L-80, .0058 bpf, ID =2.441" )t>, TE RBI BY COMrv£NTS 05112/90 ORGINAL COMPLETION 09107/99 SIDETRACK COMPLETION 11/13/03 TMN/TL CTD SIDETRACK 04/28104 JLG/KAK AŒ'ERFS& CORREcrlONS 07/10/04 KEY/KAK AŒ'ERFS DATE REV BY COMrv£NTS PRUDI-OE BAY lJ'.J1T WELL: S-24B PERMT lib: 2031630 API lib: 50-029-22044-02 SEC35, T12N, T12E, 1633' SNL & 1050'EWL BP Expbration (Alaska) .' . STATE OF ALASKA . ALASKA"'elL AND GAS CONSERVATION COMr\1I!SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 08/10/04, Put on Injection 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 o Development o Exploratory DGINJ IBI WINJ o WDSPL No. of Completions One Other o Stratigraphic IBI Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 11/13/2003 '203-163 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 11/7/2003 50- 029-22044-02-00 4a. Location of Well (Governmental Section): 7. Date ToO. Reached 14. Well Name and Number: Surface: 11/10/2003 PBU 5-24B 1633' SNL, 1050' EWL, SEC. 35, T12N, R12E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2627' NSL, 4113'WEL, SEC. 27, T12N, R12E, UM KBE = 63.77' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+TVD) 3311' NSL, 4867'WEL, SEC. 27, T12N, R12E, UM 14121 + 8954 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 619212 y- 5979855 Zone- ASP4 14155 + 8950 Ft ADL 028258 TPI: x- 613976 y- 5984034 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 613211 y- 5984706 Zone- ASP4 (Nipple) 2195' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IBI Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR, MGR, CCL 2. CASING, LINER AND (;EMENTING RECORD :'!(§ìZË~ ......../.~~g~/ SETTINQ' ..~~:> > .i>2 > /........ ./..'//.. ···WT. PE~FT. lOP I::SOTTOM lOP ¡ I::SOTTOM ·····PuLLED 20" Insulated Conductor Surface 110' Surface 110' 8 cu vds Concrete 13-3/8" 68# L-80 Surface 2668' Surface 2668' 17-1/2" 2580 cu ft Arcticset II & III 7" 26# L-80 34' 10180' 34' 8722' 8-1/2" 1403 cu ft Class 'G' 4-1/2" 12.6# L-80 10003' 12687' 8565' 8919' 6" 1432 cu ft Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 8.81# /6.2# /6.16# L-80 11077' 14155' 8923' 8950' 4-1/8" x 3-3/4" 158 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 124. ./>/.............. . ../ ··il.» .i Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 2" Gun Diameter, 6spf 4-1/2", 12.6#, L-80 10008' 9952' MD TVD MD TVD 14010' - 14060' 8968' - 8961' 13475' -13500' 8962' - 8959' 125. ······A~ln "". @.,j.¡ .... 13725' - 13750' 8968' - 8971' >.'.">. ..:-._' 13945' - 13965' 8975' - 8973' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protected with 28 Bbls of MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): July 13, 2004 Water Injection Date of Test Hours Tested PRODUCTION FOR Oll-BSl GAs-McF WATER-Bsl CHOKE SIZE GAS-Oil RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... Oll-Bsl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None R8DMS 8Fl ~611 ?nO~ . . . ~ç Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE OR\G\\\JAL 287 GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sadlerochit 12872' 8926' None Sadlerochit 14118' 8954' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date PBU S-24B Well Number Prepared By Name/Number: Drilling Engineer: Te"ie Hubble, 564-4628 Mark Johnson, 564-5666 203-163 Permit No. I A roval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only e e Well: Field: API: Permit: S-24B Prudhoe Bay Unit 50-029-22044-02 203-163 Accept: Spud: Release: Rig: 11/05/03 11/07/03 11/13/03 Nordic #1 .. .. . .. . . "'"h'm""=,^",=,=·' .,=.....,. 'Y="'''' '·='..'~NY" . POST RIG WORK 01/03/04 RIH. DISPLACE COIL WITH KCL. PUMP 10 BBLS 7% HCL. RECIP ACROSS PERFS AND HESTITATE TWICE. FINAL INJECTIVITY WITH HCL IS 0.15 BIM AT 2252 PSI. INITIAL INJECTIVITY WITH MUD ACID IS 0.2 B/M AT 2278 PSI. FINAL INJECTIVITY WITH MUD ACID IS 1978 PSI. POH I FP WELL TO 2500'. WELL LEFT SHUT IN, NOTIFY PO I PCC. 04/26/04 MU I BOT & PDS MHAlMEMORY TOOLS AND RIH. TAG BTM AT 14132'. LOG UP AT 40 FPM FROM 14132' TO 13700. FLAG PIPE AT 13900. LAY IN LUBTEX MIXTURE AND DIESEL TO SLICK AND UNDERBALANCE WELL. OOH. VERIFY LOG DATA. GOOD DATA. 04/27/04 MU AND RIH WITH GUN #1 (25'). TIE IN WITH FLAG. POSITION AND SHOOT GUN #1 (14023-14048) WITH 2" GUNS WITH PJ 2006 CHARGES LOADED AT 6 SPF WITH RANDOM ORIENTATION AND 60 DEG. PHASING. POH.ALL SHOTS FIRED. MU AND RIH WITH GUN # 2.- TIE IN AND FIRE GUN # 2 ON PERF INT 13945'- 13965'. POH, ALL SHOTS FIRED. MU AND RIH WITH 2" JSN TO 12000. CIRCULATE IN KCL. POH AND STOP AT 2000 FT. PERFORM STEP RATE TEST. UNABLE TO ESTABLISH INJECTIVITY. FREEZE PROTECT COIL AND WELL WITH 50/50 MEOH. 07/09/04 MURU. MU BOT 2.25" OD MHA WIPDS IN 2.2" OD CARRIER W/2.0" OD JSN AND RIH. LOG FROM 13,875' CTM TO 13,250' CTM WISTOPS AT 13,700' CTM AND 13451' TO FLAG COIL. LAY IN FLO PRO W/LUBTEX AND SWAP WELL TO DIESEL WHILE POOH TO SLICK UP AND UNDERBALANCE WELL FOR PERFORATING. MU 25' OF 2" 2006 PJ HMX 6 SPF AND RIH. SHOOT GUN # 1 INTERVAL FROM 13,725'- 13,750'. GOOD INDICATION SHOTS FIRED. POOH. 07/10/04 SURFACE WITH GUN # 1. ALL SHOTS FIRED. MU BOT 2.25" OD MHA AND GUN # 2,25',2.0" OD, 6 SPF, 2006 PJ HMX PERF GUNS. PERFORATE FROM 13,475' TO 13,500' AND POOH. ALL SHOTS FIRED. MU 2.0" OD JSN AND RIH. CLEAN OUT LINER FROM 14,080' CTM WIFLO PRO SWEEP AND CIRCULATE OUT. RECOVERED FINE SAND AND PERF GUN DEBRIS. PERFORM INJECTIVITY TEST WITH FILTERED SW, INITIAL RATE WAS.5 BPM @ 1912 PSI. INCREASED INJECTION PRESSURE. 07/11/04 PERFORM INJECTIVITY TEST AFTER PERFORATING AND FCO.COMPLETED BREAKDOWN. INITIAL INJECTIVITYWITH FILTERED SW AFTER PERFORATING WAS.5 BPM @ 1912 PSI. SAW GOOD BREAKOVER AT APPROXIMATELY 2350 PSI W/5 BPM. FINAL INJECTIVITY AT SUSTAINED TARGET RATE OF 2000 PSI WAS 2.7 BPM. FREEZE PROTECT TUBING TO 2500' PER PAD OPERATORS REQUEST DUE TO GC-2 SHUT DOWN WORK. . TREE = WELLHEAD = A CTUA. TOR = KB. 8..EV = BF. 8..EV = KOP= Max Angle - Datum MD = DatumTVD = 4-1/8" CIW f>lcBlOY AXELSON 64.77' 35.43' 2782' 97 @ 14076' 10430' 8800' SS 13-3/8" CSG, 68#, N-80, ID = 12.415" Minimum ID = 2.377" @ 12830' TOP OF 2-7/8" LINER 8-248 SAFETY NOTES: 9-5/8" CSG CUT, PULLED & MILLED FROM SURFACE TO STUB@ 2739' HORIZONTAL LNR 70° @ 10383' & 90° @ 11758'. ORIGINAL WELLBORE NOT SHOWN ON DIAGRAM. TOP OF 4-1/2" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 3-3116" LNR, 6.2#, L-80, ..0075 bpf, ID = 2.786" 11131' 7" LNR, 26#, L-80 MOD, .0383 bpf, ID = 6276" 10180' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 12687' I . 2195' 4-1/2" HES SSSV NIP, ID = 3.813" 9941' 9952' 9975' 9996' 4-1/2" X NIP, D - 3.813" 10004' ELI'vD TT LOGGID 09/24/99 10008' H4-1/2"W/LEG, ID=4.00" I ÆRFORA llON SU'v1MARY REF LOG: SÆRRY rvwD EWR ANGLE AT TOP PERF: 95 @ 13475' Note: Refer to Production DB for historical perf data SIZ E SPF INTERV AL Opn/Sqz DATE 2" 6 13475 - 13500 0 07/10/04 2" 6 13725 - 13750 0 07/10/04 2" 6 13945 - 13965 0 04/28/04 2" 6 14010- 14060 0 11/13/03 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" 1107T 1109T 11129' COMfvENTS 3.70" BKR DEPLOYfvENT SLY ,ID = 3.0" C\A. TE RBI BY COMfvENTS 05112/90 ORGINAL COMPlETION 09/07/99 SIŒTRACKCOMPLETION 11/13/03 TMN/TL CTDSlDETRACK 04/28/04 JLG/KAK ACPERFS & CORRECTIONS 07/10/04 KEY /KA K A CPERFS DATE REV BY 3-1/2" HES X NIP, ID - 2.813" 3-1/2" X 3-3/16" XO, ID = 2.786" 12830' 3-3116" X 2-7/8" XO,ID =2.440" PRUDHOE BAY UNIT WELL: S-24B PERMT i'b: 2031630 API i'b: 50-029-22044-02 SEC 35, T12N, T12E. 1633' SNL & 1050' EWL BP Expbration (Alaska) e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD 2. Operator Suspend 0 RepairWellD Pull TubingD Operation Shutdown 0 Plug PerforationsD Perforate New Pool D 4. Current Well Class: Perforate ŒI WaiverD Stimulate D Time ExtensionD Re-enter Suspended WellD 5. Permit to Drill Number: 203-1630 OtherD Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development D ExploratoryD 63.77 8. Property Designation: ADL-028258 11. Present Well Condition Summary: StratigraphicD ServiceŒ 9. Well Name and Number: S-24B 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool 6. API Number 50-029-22044-02-00 Total Depth measured 14155 feet true vertical 8949.8 feet Effective Depth measured 14121 feet true vertical 8954.0 feet Plugs (measured) Junk (measured) J , . 7 {, ?n()· 4 Alastca 011 & Gas . ,.' t ~~n None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 27 107 27.0 - 107.0 1490 470 Liner 2684 4-1/2" 12.6# L-80 10003 - 12687 8565.4 - 8919.4 8430 7500 Liner 52 3-1/2" 9.3# L-80 11077 - 11129 8922.7 - 8928.3 10160 10530 Liner 1701 3-3/16" 6.2# L-80 11129 - 12830 8928.3 - 8920.5 Liner 1325 2-7/8" 6.16# L-80 12830 - 14155 8920.5 - 8949.8 13450 13890 Production 10153 7" 26# L-80 25 - 10178 25.0 - 8720.1 7240 5410 Surface 2640 13-3/8" 68# N-80 26 . 2666 26.0 - 2665.9 4930 2270 Perforation depth: Measured depth: 13945 - 13965, 14010 -14023,14023 -14048,14048 - 14060 True vertical depth: 8975.46 - 8973.22,8967.57 - 8965.95, 8965.95 - 8962.85,8962.85 - 8961.34 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 25 10008 @ 9952 @ 10003 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 5" Baker ZXP Liner Top Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Representative Dailv Averaae Production or Iniection Data Gas-Me! Water-Bbl Never Injected Still Shut-In Casing Pressure 1439 1034 Tubing Pressure o 87 Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ] Copies of Logs and Surveys run _ 16. Well Status after proposed work: Operational Shutdown D OilD GasD WAG D GINJD WINJŒ WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or NIA if C.O. Exempt: 304·152 Daily Report of Well Operations. X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Signature Title Production Technical Assistant ¡ð ~one 564-4657 Date 6/15/04 e e 5-248 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 04/26/04 MIRU CTU # 9- MU / BOT & PDS MHA/MEMORY TOOLS AND RIH. TAG BTM AT 14132'. LOG UP AT 40 FPM FROM 14132' TO 13700. FLAG PIPE AT 13900. LAY IN LUBTEX MIXTURE AND DIESEL TO SLICK AND UNDERBALANCE WELL. OOH. VERIFY LOG DATA. GOOD DATA. JOB IN PROGRESS. 04/27/04 Perforate 13945'-13965' 6 SPF, 14023'-14048' 6 SPF FLUIDS PUMPED BBLS 183 Methonal 245 1 % KCL 23 FloPro with Lubtex at 12% 189 Diesel 640 TOTAL Page 1 TREE = WELLHEAD - A GrUð. TOR = KB. 8.EV = BF. 8.EV - KOP= Max Angle = Datum MD = DatumTVD - 4-1/8" CIW Iv'c BI OY AXELSON 64.77' 35.43' 2782' 97 @ 14076' 10430' 8800'SS 8-248 13-318" CSG, 68#, N-80, ID = 12.415" Minimum ID = 2.377" @ 12830' TOP OF 2-7/8" LINER TOP OF 4-1/2" LNR 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID =3.958" 3-3116" Lf\R, 6.2#, L-80, ..OO75bpf, ID= 2.786" 11131' 7" LNR, 26#, L-80 MOD, .0383 bpf, ID = 6.276" 10180' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 12687' 1 ÆRFORA liON SU\1MARY REF LOG: SÆRRY MND EWR ANGLE AT TOP PERF: 95 @ 13945' Note: Refer to Production DB for historical perf data SIZE SPF INfERV AL Opn/Sqz DATE 2" 6 13945 - 13965 0 04/28/04 2" 6 14010-14060 0 11/13/03 . SAFETY NOTES: 9-5/8" CSGCUT, PULLED & MLLED FROM SURFACE TO SruB@2739'HORIZONTAL LNR 70° @ 10383' & 90° @ 11758'. ORIGINAL WELLBORE NOT SHOWN ON DIAGRAM. 2195' 4-1/2" HES SSSV NIP, ID = 3.813" 9941' 9952' 9975' 9996' 4-1/2" X NP, D = 3.813" 4-1/2" X NP, D = 3.813" 4-1/2" XN NIP, ID = 3.80" - MLLIÐ our FROM 3.725' 10/18/03 10004' ELI\,{) TT LOGGIÐ 09124/99 10008' H4-1/2"W/LEG, ID= 4.00" 1 1107T 1109T 11129' 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID =2.441" Oð.1E RBI BY COMI'vENTS 05112/90 OR3INAL COM PlETION 09107/99 SIŒTRACKCOMPLETION 11/13103 TMNITL cm SIDETRACK 04/28/04 JLG/KA K A [PERFS & CORREGrIONS DATE REV BY COMI'vENfS 3.70" BKR DIPLOYI'vENT SLV, ID = 3.0" 3-1/2" HES X NIP, ID = 2.813" 3-1/2" X 3-3/16" XO, ID = 2.786" 12830' 3-3116" X 2-7/8" XO, ID = 2.440" PRUDHOE BAY U\JIT WELL: S-24B PERMT I\b: 2031630 APII\b: 50-029-22044-02 SEe 35, T12N, T12E, 1633' SNL & 1050'EWL BP B<pbration (Alaska) e STATE OF ALASKA e ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1¡.J6A;- lP f / 1 2-D 04- OJY 6// /1- 1. Type of Request: 0 0 D Perforate X] WaiverD Annular Disposal 0 Abandon Suspend Operation Shutdown Alter Casing 0 Repair Well 0 Plug Perforations D StimulateŒ Time Extension 0 OtherD Change Approved Program 0 Pull Tubing 0 Perforate New Pool D Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill N~er: Name: BP Exploration (Alaska), Inc. 203-1630 Development D Exploratory D 3. Address: P.O. Box 196612 / 6. API Number ./ Anchorage, Ak 99519-6612 Stratigraphic D Service ŒJ 50-029-22044-02-00 7. KB Elevation (ft): 9. Well Name and Numb.:?"" 63.77 KB 5-24B 8. Property Designation: 10. Field/Pool(s): ADL-028258 Prudhoe Bav Field / Prudhoe Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): I Total Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD (ft): Plugs (md): Junk (md): 14155 8949.8 14121 8890.2 None None Casing Length Size MD TVD Burst Collapse too bottom too bottom Conductor 80 20" 91.5# H-40 27 - 107 27.0 - 107.0 1490 470 Liner 2684 4-1/2" 12.6# L-80 10003 - 12687 8565.4 - 8919.4 8430 7500 Liner 52 3-1/2" 9.3# L-80 11077 - 11129 8922.7 - 8928.3 10160 10530 Li ner 1701 3-3/16" 6.2# L-80 11129 - 12830 8928.3 - 8920.5 Liner 1325 2-7/8" 6.16# L-80 12830 - 14155 8920.5 - 8949.8 13450 13890 Production 10153 7" 26# L-80 25 - 10178 25.0 - 8720.1 7240 5410 Surface 2640 13-3/8" 68# N-80 26 - 2666 26.0 - 2665.9 4930 2270 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 13945 - 13965 8975.5 - 8973.2 4.5 " 12.6 # L-8RE CEfVED 10008 14010 - 14023 8967.6 - 8966.0 14023 - 14048 8966 - 8962.9 14048 - 14060 8962.9 - 8961.3 Mt y?i ~) Packers and SSSV Type: Packers and SSSV MD (ft): ~a GIs ConS. Commieoion 4-1/2" Baker S-3 Perm Packer 5" Baker ZXP Liner Top Packer 10003" . Description Summary of Proposal 0 -.... 12. Attachments: 13. Well Class after proposed work: Detailed Operations Program ŒI BOP Sketch 0 ExploratoryD Development 0 Service ŒI / 14. Estimated Date for June 8, 2004 / 15. Well Status after proposed work: Commencino Ooeration: Oil D GasO PluggedO Abandoned 0 16. Verbal Approval: Date: WAGD GINJD WINJ[! / WDSPLD Commission Representative: Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jim Youna Printed Name Jim Youna I Title Petroleum Enaineer Signature :. \íNf) \i\~ <: ....2R. -/"r;;:1' 1 Phone 564-5754 5/25/04 f-/ I I Commission Use Onlv Conditions of approval: Notify Commission so that a representative may witness Sundry N~"e4. zoO Plug Integrity 0 BOP TestO Mechanciallntegrity Test D Location Clearance 0 Other: Subsequent Form Required: _iPc 4-P 4· ""1 RIØJS Bfl JJN 0, "~,f;~' BY ORDER OF Date: (P ///ó <j Approved by: THE COMMISSION Form 10-403 Revised 12/2003 [l R ! CJ! r~ A 1 SUBMIT IN DUPLICATE bp e e Memorandum To: G ANC Wellwork Program Date: 3 December 2003 From: Jim Young, PE, GPB Waterflood AFE: lOR: Est. Cost: Pbd4P2150 500 BOPD $5,000 Subject: S-24B Perf. Flowback. Breakdown OBJECTIVE/COMMENTS: S-24Bi was sidetracked by Nordic1 in November, 2003 with a 50' interval perforated in bleach using 2" guns. Since three interventions to breakdown, aeidize and reperf have failed to establish minimum injectivity, a review of similar well types determined that either significantly/" underbalanced perforating or a flowback is required to relieve stresses around the wellbore so that a fracture can be initiated. Due to the well trajectory, significantly underbalanced perforating is not an option, so a flowback with N2 is requested prior to a perf breakdown. S-24B DETAILS: Completion: 4-1/2" tubing and 4-1/2" x 2-7/8" cemented liner, tested to 3000# wi rig Min restriction: 2-7/8" (2.44" ID) TD Tag History: 14119' post perforating Injectivity: 0.3 bpm at 3500psi Expect: 0.5 bpm @ 2000# WHP post-BD Displacement bbls: 200 BBLS to top perf Fluids: 350 bbl filtered Seawater & 100 MCF N2 Static: 3490# @ TVDSS taken 9/24/99 Wellhead Pressure tested t si on /7 . / Burst on tub in pre-Job Planning: 1. Have lubricants as necessary to reach proposed perf depth and N2 pumper available as soon as 2nd perf gun fired and at surface. Jum er t~.!E:ES?E'.'l:!:Y_"~"'~""""E~P.i~g to§_~~"!J_I.<?.:Y.!~!1:~ (k~ll fla~ge)."_______________________ osed Steps: 1. Perforate 2x25' intervals with CTU per attached perf form. POOH to unload guns. 2. Open well to S-21 flowline, eirc N2 while RIH to 9500' MD at -300 SCF/MIN 6-hours (can reduce N2 rate if FBHP drops <1500psi, well could initially flow -lmbd, but drop off to -300 bid after a 1-2 hours). Bleed IA if above 2000psi to stay under 7500psi tbg colla se rating at acker. 3. Blow-down N2 and eirc-out tubing wlcold (60F) filtered KCI or seawater. Once N2 is out of tubing, pump-down CT & tu~~ni nd attempt to breakdown by increasing treating pressure to a maximum o(~?Ò psi. If the perfs are not breaking down (ie >3 b m) under the 4500 si limit," r e to flowline & re eat breakdown. 4. Ramp up to the maximum injection rate available with 1 truck, and displace remaining seawater, holding approximately 2000 psi WHIP for the last 20 bbls. 5. Noti ad operator to start open well to in'ection at maximum rate. Cc: Jim Young GPB Wells Tech Aide (4) Well File e e S-24B Historv 4/27/2004 MU and RIH with gun #1 (25'). Tie in with flag. Position and shoot gun #1 (14023-14048) with 2" guns with PJ 2006 charges loaded at 6 spf with random orientation and 60 deg. phasing. POH.all shots fired. MU and RIH with gun # 2.- Tie in and fire gun # 2 on perf int 13945' - 13965'. POH, all shots fired. MU and RIH with 2" JSN to 12000. Circulate in KCL. POH and stop at 2000 ft. Perform step rate test. Unable to establish injectivity. (see log portion for details). Freeze protect coil and well with 50/50 MEOH. Job in progress. 4/26/2004 MIRU CTU # 9- MU / BOT & PDS MHA/Memory Tools and RIH. Tag btm at 14132'. Log up at 40 fpm from 14132' to 13700. Flag pipe at 13900. Lay in lubtex mixture and diesel to slick and underbalance well. OOH. Verify log data. Good data. Job in progress. 1/3/2004 Continue RIH. Displace coil with KCL. Pump 10 bbls 7% HCL. Recip across perfs and hestitate twice. Final injectivity with HCL is 0.15 b/m at 2252 psi. Initial injectivity with mud acid is 0.2 b/m at 2278 psi. Final injectivity with mud acid is 1978 psi. POH / FP well to 2500' **** Well Left Shut In - Notify PO / PCC **** 1/2/2004 MIRU unit #9. RIH with 2" JSN. Problems getting past 5519. POH and check out stripper lube, Remove ice build-up due to weather conditions. RBIH. Job in progress. 12/23/2003 T/I/O=50/40/420 (Well SI) Attempt tbng step rate test @ 3500 i, Pressure IA up to 1050 psi, Pump 7.2 bbls to pressure tbng up to 3500 psi max, TP dropped 2100 ps' In 1. min, Bumped up to 3500 psi w/2.4 bbls 60/40, TP dropped 1750 psi in 15 min, Try to establish injection @ OOQ,psi, Pressure IA to 1500 psi, Bump up tbng to 4000 psi, TP droppe~21 ()O psi in 15 min., Pressure tbng bacp to 4000 psi w/ 2.5 bbls 60/40, Injection rate appx. 7 GPM @ OO{Ypsi, Bleed Tbng & IA Final WHP's=200/40/420 "'" 12/2/2003 TIO=0/50/400---Pump Step Rate Injectivity Test on TBG/ Establised rate of 0.2 bpm @ 2500 psi ---Final WHP's=500/50/400 Cc: Jim Young GPB Wells Tech Aide (4) Well File e e PERFORATING PROCEDURE Ver 4.006/04/01 Well: Date: S-24B 4/8/03 API #: 50-029-22044-02 Prod Engr .~.i.'!.!...Y.~lJ!'.9.......... Office Ph: 564-5754 ..............----.-----.......----- Home Ph: 248-0133 Cell/Pager: 440-8007 9335-070-770 ...............--.-...................... ...................-..--.--..... CC or AFC: Pbd4P2150 Detail Code: . ..-...................................... Description: DRLG / COMPLETION / PERF lOR 200 Type C WBL Entries Work Desciption Perforate 50', flowback w/ N2, breakdown ad Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Log: MWD GRlCCL Date: 11/10/2003 11/12/2003 Company: SLB SLB Depths (from-to) 13,725 13,750 Add 0 to the tie-in log to be on depth with the reference log. feet Depths (from-to) 13,725' 13,750' Feet 25' SPF 6 Phasing 60° Zone 4b Ad/Rellperf Iperf 13,475' 13,500' 13,475' 13,500' 25' 6 60° 4b Iperf Gas Jetting Expected? No Requested Gun Size: mmmmm....?.::.................. Charge: Desired Penetration: At what Depth? N/A 2006PJ HMX ....H....................H._..____ >15" MAX Swell=2.16" in liq Entry Hole Diam: .........._ 0.2 _.__ Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check wI Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) Tie in to Jewelry @ Minimum ID: Tail Depth: Tie in using: Min ID Type: Casing Size: Est Res. Pres. @ DCCL XO @ 12,838 'MD 2-7/8 in 14,999m MD is m:??99 psi Last Tag: 14,119 ft MD on Well: S-24B Date: API#: float collar Perforation Summary 50-029-22044-02 Prod Engr: Summary Dist Town: Anch Prod Engr P.D. Center PBTD General Comments: Balance O/B/U O/B/U O/B/U O/B/U O/B/U Depths Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone Aperf/Reperf 00 00 O· ~~~~. ~,~ --- w.__~_~~~~ TREE = WELLHEAD - A CTUð. TOR- KB. 8...EV = BF. 8...EV = KOP= Max Angle - Datum MD- DatumTVD = 4-1/8"CIW M:EVOY AXELSON 64.77' 35.43' 2782' 97 @ 14076' 1 0430' 8800' SS 13-318" CSG, 68#, N-80, ID = 12.415" Minimum ID = 2,377" @ 12830' TOP OF 2-7/8" LINER TOP OF 4-1/2" LNR 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 3-3116" Lf\R, 6.2#, L-80, ..0075 bpf, ID = 2.786" 7" LNR, 26#, L-80 MOD, .0383 bpf, ID = 6.276" 10180' 14-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" H 12687' I ÆRFORA llON SlJv1MARY REF LOG: SÆRRY MND EWR ANGLE AT TOP PERF: 95 @ 13945' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 13945 - 13965 0 04/28/04 2" 6 14010-14060 0 11/13/03 8-248 . SAFETY NOTES: 9·5/8" CSGCUT, PULLED & MLLED FROM SURFACE TO SruB @ 2739' HORIZONTAL LNR 70° @ 10383'& 900@ 11758'. ORIGINAL WELLBORE NOT SHOWN ON DIAGRAM. 2195' 4-1/2" HES SSSV NIP, ID = 3.813" 9941' 9952' 4-1/2" X NIP, D = 3.813" 9975' 9996' 10004' ELMHT LOGGED 09/24/99 10008' H4-1/2"W/LEG, ID= 4.00'" 1107T 3.70" BKRDEPLOYWENTSLV, ID -3.0" 1109T 11129' 3-1/2" HES X NIP, ID = 2.813" 3-1/2" X 3-3/16" XO, ID = 2.786" COMWENTS 12830' 3-3116" X 2-7/8" XO, ID = 2.440" 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" )l\ 1E REV BY COMWENTS 05112/90 ORGINAL COMPLETION 09107/99 SIŒTRACK COMPLETION 11/13103 TMNITL CTDSlDETRACK 04/28/04 JLG/KA K A [PERFS & CORRECTIONS DATE REV BY PRUDI-OEBAY U'JIT WELL: S-24B PERMT i'b: 2031630 API N:J: 50-029-22044-02 SEC35, T12N, T12E, 1633' SNL & 1050'EWL BP Expbration (Alaska) lNúA +/ 2. ~(ZOO 4- IJClf ~k;a~ . STATE OF ALASKA . ALAS~OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 StratigraphicD Service ŒJ ¡ 9. Well Name and Number/: . S-24B 10. Field/Pool(s): Prudhoe Bav Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Total Depth TVD (ft): 'Effective Depth MD (ft): 'Effective Depth TVD (ft): 8949.8 14121 8890.2 S~ MD nD 1. Type of Request: Abandon 0 Alter Casing 0 Change Approved Program 0 Suspend 0 RepairWell 0 Pull Tubing 0 2. Operator Name: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 63.77 KB 8. Property Designation: ADL-028258 3. Address: 11. Total Depth MD (ft): 14155 Casing Length Conductor Liner Liner Liner Liner Production Surface 80 20" 91.5# H-40 2684 4-1/2" 12.6# L-80 52 3-1/2" 9.3# L-80 1701 3-3/16" 6.2# L-80 1325 2-7/8" 6.16# L-80 10153 7" 26# L-80 2640 13-3/8" 68# N-80 I Perforation Depth TVD (ft): 8968 - 8961.3 Perforation Depth MD (ft): 14010 - 14060 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer 5" Baker ZXP Liner Top Packer 12. Attachments: Description Summary of Proposal Œ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for CommencinQ Operation: 16. Verbal Approval: Commission Representative: May 4, 2004 Date: Operation Shutdown Plug Perforations Perforate New Pool D D D Perforate!!] / WaiverO StimulateD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 203-1630 ~ Annular DisposalD OtherD 4. Current Well Class: Development D Exploratory D / 6. API Number ./ 50-029-22044-02-00 Plugs (md): None Burst Junk (md): None Collapse top 27 10003 11077 11129 12830 25 26 bottom top bottom 107 27.0 - 107.0 - 12687 8565.4 - 8919.4 - 11129 8922.7 - 8928.3 12830 8928.3 - 8920.5 14155 8920.5 - 8949.8 13450 10178 25.0 - 8720.1 7240 2666 26.0 - 2665.9 4930 Tubing Size: I Tubing Grade: rTUbing MD (ft): 4.5 " 12.6 # L-80 25- Packers and SSSV MD (ft): 1490 8430 10160 470 7500 10530 - 13890 5410 2270 10008 9952 10003 13. Well Class after proposed work: ExploratoryD ServiceŒ /' Development 0 15. Well Status after proposed work: Oil D GasO PluggedO WAG D GINJD WINJ[! Abandoned 0 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 Jim Young i ) " \'.!'¥fA. , I I I Contact Jim Young Title Phone Petroleum Engineer 564-5754 4/26/04 Commission Use Only I Sundry Number: 30~ I~~ Plug Integrity 0 Conditions of approval: Notify Commission 50 that a representative may witness Location Clearance D BOP Tesrz Other: - S"bs~~Æ - 404- Approved BY: 7'--7 of j / /h A L/ 1/ Y" ~ \. Mechanciallntegrity Test D RECEIVED . !' .,! APR~~DiJ4 BY ORDER OF . ~ THE COMMISSIO~'a~&PI' & ~ 6Zrs:t()4~0!1 fill choragi , ~'a.r¿ Form 10-403 Revised 12/2003 OR\G~t~AL SUBMIT IN DUPLICATE Well: Date: I Attachment: 8-24B ....................--..........--....---..-- .~(FI~~:~1~L CC or AFC: Pbd4P2150 Descrlptlon:ºf.í.~~iªQM~Ç§ti9~z:~~BË=__.. lOR B e . PERFORATING PROCEDURE API II: 50-029-22044-02 ....___.._....______m.__ Prod Engr~ill1.'f()U"11.. Office Ph: 564-5754 Home Ph: 248-0133 Cell/Pager: ... . .. .......~~IJ(I!. H2S Level: r~i¡¡ppml Detail Code: 000.000000000.000000..000.........000000000000000.............000000.......................~~:º?º'!!º.... Type C ···············..·...._·..·..wËiii··E"ñïriïts ............. ........................ Work Desciption ¡Perforate 50' underbalance with 1'12 ,., , .....................-..---........-......... .....................-..-...... Wit v nd Looolno Notes: adDerf/reoerf section where current Darts not connected to reservoir """ tie-in with memory CCLJfIag-pipe 1'12 lift off top (no GLMs). surge to system alter perforating eire-out 1'12 & oerform in'activity test at 0.2. 0.5. 1.2. and 4 bom w/liltered KCI water. Max WHIP: 3000Dsi. contact APE if no breakdown. Reference log WIth proposed perfs annotated, 5'/100' scale Reference Log Log: MWD Date: -1i7911999 Compeny: SlB Depths (from~iojOOO'OOO .!,~",º.!.8_. _...:1..4..048. ..~..~!.!!4...s.~.. Gas Jetting Expected? TIe In Log GR/CCl 1111- SLB Add 0 to the tie-In log toi;.""··- depth with the reference log, feet ....~_~,965·.. ...~.ª-!.~?:.. Depths (from-to) .!±:-º.~.I!... ....~.~.048·._ 60° 13968 MD :[[¡;gilimmln ._1.Q9Q!I...... It MD .1.~,.!~ It MD on 8-24B API II: Depths Referenced to BHCS Feet 30' Phasing 60° Zone AdlRellperf 4b lperf Requasted Gun Size: 2' SPF 6 ...~.~.~65' . ---~~.__...Ip~ .1'10 At what Depth? Charge: Desired Penetration: MAX Swell-2.16- in IIq Entry Hole Dlam: (1.2 /' Is Drawdown NecessarylDeslred!Unnecessary During Perforating Describe bøIuN how to achi9ve Gtawdown (check wi Pad 0peIat0r to see if necessæy piping is insrBlfed) (e.g. N2 Lift. HarrJJne Uft Gas, Gas Uft, FkNf Well, BackfIow Through Drain or Harrline) Tie In to Jewelry @ Minimum ID: Tall Depth: Last Tag: ÇF'1II!çA!,::m.M!\I!:f.r.:!\I.t:I..!!.'::IF.'.~!§Q(?~.I:i.lhg.F.'.§.'3f.9RAI1.t:I.(3_.._.. .çirc N2 i=~M9~.l..QlJ(l~.!P~'!!!~,..!Q..§.:.?.!.!i.n......p.rior to firin..l!:_ Tie in using: Mln ID Type: Casing Size: Est Ras. Pres. @ .~~!".".II!,r... DCCl ·····················)!9.::::::ooooooooo........@ OOOOOOOOOOOOOOOiii;@!;MD OOO.OOO2:¡ïij·OOO·ïiï :::::i~,ooo _ MD Is ~ psi Perforation Summary Well: Date: General Comments: Balance O/B/U O/B/U O/B/U O/B/U O/B/U ..~~~~C):!ooo Prod Engr: PBTD Gun Dla. Orient. SPF Phasing Zone AperflReperf 00 00 O· ....-.....-..................................... ..m..mm....................._. . . (~o3-)L03 WELL LOG TRANSMTITAL To: State of Alaska Alaska Oil and Gas Conservation Cornm. Attn.: Howard Okland 333 West "ft Avenue, Suite 100 Anchorage, Alaska January 26, 2004 RE: MWD Formation Evaluation Logs S-24B, AK-MW-2762907 1 WWG formatted Disc with verification listing. API#: 50-029-22044-02 '::f!: J ~ >--\ ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMI1TAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro- Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 -~.'"~ ~."".... Signed: ""'Ç')\...." IV"' ~\P~~""'- Date: RECEIVED r:r~r; 1 r 0'Ou~4 I ~...LJ .i... L ÞJa.~801 & Gas Cons. Camm_ Ancíiorage ~~~\\\~ .. . STATE OF ALASKA . RECEIVED ALAS~ AND GAS CONSERVATION COM' ION ' WELL COMPLETION OR RECOMPLETION REPORT AND LOG DEC 2 92003 AII~h nil [l,¡ r::2~ rnM ~ 1a. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well c'a~b 20AAC 25.105 20AAC 25.110 o Devel Rfa~ Exploratory DGINJ 1m WINJ o WDSPL No. of Completions One Other o Stratigraphic 1m Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit Number BP Exploration (Alaska) Inc. 11/13/2003 ./ 203-163 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 11/7/2003 50- 029-22044-02-00 4a. Location of Well (Governmental Section): 7. Date ToO. Reached 14. Well Number Surface: 11/10/2003 PBU 5-24B 1633' SNL, 1050' EWL, SEC. 35, T12N, R12E, UM 8. Elevation in feet (indicate KB, DF, etc.) 15. Field and Pool Top of Productive Horizon: 2627' NSL, 4113' WEL, SEC. 27, T12N, R12E, UM KBE = 63.77' Prudhoe Bay Field I Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 3311' NSL, 4867' WEL, SEC. 27, T12N, R12E, UM 14121 + 8954 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Lease Designation and Serial No. Surface: x- 619212 y- 5979855 Zone- ASP4 14155 + 8950 Ft ADL 028258 TPI: x- 613976 y- 5984034 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 613211 y- 5984706 Zone- ASP4 (Nipple) 2195' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 1m Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR, MGR, CCL n. CASING, LINER AND CEMENT~ ~~fi~G ~ETTINGDEptH >I§?~ i> > ;,6,' iiiiiiiii"i W,..PE~FT.i GkÃDE TOP' BOiTOM .' RECC>R[) 20" Insulated Conductor Surface 110' 8 cu vds Concrete 13-3/8" 68# L-80 Surface 2668' 17-1/2" 2580 cu ft Arcticset II & III 7" 26# L-80 34' 10180' 8-1/2" 1403 cu ft Class 'G' 4-1/2" 12.6# L-80 10003' 12687' 6" 1432 cu ft Class 'G' . 8.81# /6.2# /6.16# L-80 11077' 14155' 4-1/8" x 3-3/4" 158 cu ft Class 'G' . 3-1/2" x 3-3/16" x 2-7/8" 23. Perforations open to Production (MD + TVD of To,e and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 10008' 9952' MD TVD MD TVD 14010' - 14060' 8968' - 8961' I?$· þ,cu:>,. I,;iEMENT ,i~ç; f-ëÖr:,~j~TÊŸ: GÑl DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED -¡ i.:l&TF i 111 (ll>rJ..c'{)~ 2500' Freeze Protected with 28 Bbls of MeOH ¡ , ; \!r~~u ¡ ; ! 1=:--- . ,- '--~---.-J-- ,) 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection Yet N/A Date of Test Hours Tested PRODUCTION FOR Oil -BBl GAs-McF W A TER-BBl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-BBl GAs-McF WATER-Bsl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None IiØ)MS;Bfl ÐK !.. --- ls 1-::: , .;1." 1<;1 .>. _" Form 10-407 Revised 2/2003 CONTINUED ON REVERSE SIDE ,~ 28. ... GEOLOGIC MARKERS 29. 'ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sadlerochit 12872' 8926' None Sadlerochit 14118' 8954' 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the fOr~ng is true and correct to the best of my knowledge. Signed Terrie Hubble /[~ tt, !n{11o Title Technical Assistant Date \;{,;;(.. 9· Q..3 PBU S-24B 203-163 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mark Johnson, 564-5666 Permit No. I Approval No. 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 ..,. a Page 1 of 9 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date S-24A S-24A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To I Hours Task ¡ Code I NPT ---.....-...------ -...- .......-... - --.-- .. .....-.-- 17:00 - 17:30 0.50 MOB P PRE 17:30 - 18:30 1.00 MOB P PRE 18:30 -19:00 0.50 MOB P PRE 19:00 - 19:30 0.50 MOB P PRE 19:30 - 21:30 2.00 RIGU P PRE 11/5/2003 Start: Rig Release: Rig Number: Phase I ! 21 :30 - 00:00 2.50 BOPSUF P PRE 11/6/2003 00:00 - 02:00 2.00 BOPSUF P PRE 02:00 - 02:40 0.67 STMILL P WEXIT 02:40 - 03:10 0.50 STMILL P WEXIT 03: 1 0 - 05:25 2.25 STMILL P WEXIT 05:25 - 05:35 0.17 STMILL P 05:35 - 05:50 0.25 STMILL P 11/5/2003 11/13/2003 N1 Spud Date: 4/24/1990 End: 11/13/2003 Description of Operations "."-..-- Safety meeting prior to moving off of S-1 02L 1. Move rig from S-102 L 1 to S-24 B. Safety meeting prior to moving over well s-24B. Move rig in over S-24 B. Set rig down over S-24. Begin nippling down swab cap, and NU BOP stack. Call for berm crew to set tiger tank and cuttings box. Spot KCL vac truck to on load water for displacing freeze protect. Accept rig at 19:30 hours. Weekly BOP pressure test. Witness waived by State of Alaska, AOGCC, John Crisp. Continue with weekly BOP test. All items passed, no failures. Pre spud meeting with rig crew to discuss well plan. Also discuss plan forward for milling float equipment. Check WHP. Well dead. Make up milling BHA as per proceedure. RIH with BHA #1; 3.80 DSM, 3.80 string reamer, Baker Extreme motor, PH6 MHA. Start mud downhole when at 9500'. WEXIT Tagged up at 12507'. PBTD should be equal to 12599'. Last tag by service coil unit was at 12576'. PU, @ 44 klbs. Finish circulating mud to bit. Pumping at 2.6/2.42/2050 psi. 93% returns at this pump rate and pressure. Check mechanical vs electrical depth counters to confirm accuracy. Both counters agree. Assume that tag is CaC03 fill in hole. WEXIT Mud to bit. Begin milling on suspected fill. Pit vol=empty, taking on mud thru coil. IAP=10 psi, OAP=81 psi. Tag up and begin milling at 12506'. Seems to drill off reasonably easily. It does not look to be the liner wiper plug. Broke thru after 3'. Tag up again at 12606'. MAke a -7' correction to get on depth to PBTD. Note, the correction used on the last well was -6', so depths are consistent. Begin milling liner wiper plug and landing collar. Mill landing collar and float collar. Mill to 12,604'. Back ream float collar and landing collar. Pull up hole out of horizontal section to clean hole. RIH from 10,250'. Continue milling cement at 90 fph to 12,685'. Back ream float equipment area at 12,600'. Mill float shoe. Bust through shoe at 12,687.2'. RIH and tag up at 12,700'. Drill formation to 12,701'. Start hi vise. sweep down coil. Ream from 12,700' to 12,500'. Drift from 12,480' to 12,701' with pump off. Pump sweep out coil. POOH pumping at 2.5 bpm. Hold pre spud meeting. Review well plan hazards and mitigations with rig crew. OOH. Stand back injector. Lay down motor and mills. DSM 3.80 in the hole, 3.78" OOH. String mill 3.80" in the hole, 3.79" OOH. MU BHA #2, 3.125" Venturi basket. 05:50 - 10:45 4.92 STMILL P WEXIT 10:45 - 10:50 0.08 STMILL P WEXIT 10:50 - 12:00 1.17 STMILL P WEXIT 12:00 - 12:30 0.50 STMILL P WEXIT 12:30 - 13:45 1.25 STMILL P WEXIT 13:45 -14:00 0.25 STMILL P WEXIT 14:00 - 14:50 0.83 STMILL P WEXIT 14:50 - 15:20 0.50 STMILL P WEXIT 15:20 - 16:00 0.67 STMILL P WEXIT 16:00 - 18:15 2.25 STMILL P WEXIT 18:15 -18:35 0.33 STMILL P WEXIT 18:35 - 19:10 0.58 STMILL P WEXIT Printed: 11/17/2003 8:40:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To -....- 11/6/2003 11/7/2003 11/8/2003 19:10 - 21:10 21:10 - 21:30 21 :30 - 23:00 23:00 - 23:40 23:40 - 00:00 00:00-01:15 01:15 - 03:30 03:30 - 04:20 04:20 - 04:45 04:45 - 05:30 05:30 - 08:40 08:40 - 08:50 08:50 - 12:40 12:40 -15:00 15:00 - 17:30 17:30 - 19:55 19:55 - 22:10 22:10 - 22:20 22:20 - 00:00 00:00 - 00:45 00:45 - 00:50 00:50 - 01 :25 ..... .. Page 2 of 9 BP EXPLORATION Operations Summary Report S-24A S-24A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours I Task I Code! NPT , ¡i' -- ...--- ____.__n____. . ... _ _... 2.00 STMILL P 0.33 STMILL P 1.50 STMILL P 0.67 STMILL P 0.33 DRILL P 1.25 DRILL P 2.25 DRILL P 0.83 DRILL P 0.42 DRILL P 0.75 DRILL P 3.17 DRILL P 0.17 DRILL P 3.83 DRILL P 2.33 DRILL P 2.50 DRILL P 2.42 DRILL P 2.25 DRILL P 0.17 DRILL P 1.67 DRILL P 0.75 DRILL P 0.08 DRILL P 0.58 DRILL P Start: Rig Release: Rig Number: Phase Spud Date: 4/24/1990 End: 11/13/2003 11/5/2003 11/13/2003 N1 Description of Operations - . WEXIT RIH with BHA #2 to run venturi junk basket accross milled area. Pumps down while RIH. WEXIT 12590'. Kick on the pumps to 2.34 bpm, 3800 psi to activate junk basket. Work down to TD at 30 fpm. No weight loss or bobbles observed. Pull back up to 12590'. Repeat a second time. WEXIT POOH, continuing to circulate to pick up any heavier debris that has been strung up the hole. WEXIT Tag up at surface. Send derrick hand up to stabbing boards to confirm we are not icing up. Stand back injector. Dump the venturi basket. Found very few pieces of debris. About 1/4 cup of small aluminum and formation pieces. Rig down Venturi basket BHA. PROD1 Safety meeting prior to picking up first drilling BHA. PROD1 Make up BHA #3, first OH lateral section BHA. 4.125" Hycalog bicenter bit, 1.2 deg Baker motor, Directional-GR, MHA. Also rehead coil tubing. Pull test CTC to 35 klbs, PT to 4000 psi. Stab on injector. PROD1 RIH with first drilling BHA. Shallow hole test of orienter at 2770' passed ok, continue to bottom. PROD1 Log tie in pass up from 12590'. Make -21' correction. PROD1 Orient straight down. Attempt to orient in hole below shoe. Can't get clicks. PU into casing and try to orient, no success. RIH to bottom to stall motor and see what happens. Finally managed to get orienter to work. PROD1 12693', Free spin 3250 psi at 2.6 bpm. Drill ahead from 12693'. Drilling at 2.6/2.15/3400 psi. ROP=40 fph. Taking on new mud. IAP=15 psi, OAP=107 psi. PROD1 Returns have improved as we get away from the old perfs. 2.50/2.45/3325 psi. Continuing to drill ahead to 12,772'. PROD1 Pull BHA into casing to make sure it does not hang up on float equipment. No problems. PROD1 Drill at 2.6/2.6 3,300 psi, 140 L TF. 20 to 30 fph in shublik. Drill to 12,865'. ROP increasing, drilling in Z4. PROD1 12865', POOH to PU resistivity tool. Pump at 2.5 bpm while POOH. PROD1 Stand back injector. Change out MWD probe and pulser. Change motor bend to 1.5 degree. Change bit to 3.75" DS 49 H+GJNU. PU resistivity tool. Confidence test MWD tools. PROD1 RIH with BHA #4, RES tool, DS49 bit. 1.5 deg motor. PROD1 Tag bottom. Set depth to last tagged depth of 12865'. Made a -19' correction. Make a MAD pass for missing RES data and tie in to previous run. Make a +6' correction. PROD1 Orient to 11 OL. PROD1 12871', Resume drilling at 2.5/2.4/3260 psi. Free spin 2800 psi at 2.5 bpm. IAP=43 psi, OAP=126 psi. Pit vol=325 bbls. ROP=50 fph. PROD1 12947', Drilling ahead as per geo. 2.65/2.55/3450 psi. Pit vol=313 bbls. IAP=51 psi, OAP=129 psi. PROD1 13005', Take a couple of clicks. PROD1 Resume drilling. Printed: 11/17/2003 8:40:18 AM ..., a Page 3 of 9 BP EXPLORATION Operations Summary Report Legal Well Name: S-24A Common Well Name: S-24A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To Hours: Task Code NPT I I .._ .____... ou._..._ 19:15-21:25 21 :25 - 21:40 21:40-22:15 Start: Rig Release: Rig Number: Phase 11/5/2003 11/13/2003 N1 Spud Date: 4/24/1990 End: 11/13/2003 0.33 DRILL P 0.25 DRILL P 1.00 DRILL P PROD1 PROD1 PROD1 .--. -.- ---.. 11/812003 01 :25 - 01 :45 01 :45 - 02:00 02:00 - 03:00 03:00 - 03:35 03:35 - 03:50 03:50 - 04:35 04:35 - 06:00 06:00 - 07:25 07:25 - 07:45 07:45 - 10:30 10:30 -11:15 11:15-13:35 13:35 - 14:30 14:30 - 15:05 15:05 - 15:50 15:50 - 16:00 16:00 -16:15 16:15 -17:30 17:30 - 18:30 18:30 - 19:15 0.58 DRILL P PROD1 0.25 DRILL P PROD1 0.75 DRILL P PROD1 1.42 DRILL P PROD1 1.42 DRILL P PROD1 0.33 DRILL P PROD1 2.75 DRILL P PROD1 0.75 DRILL P PROD1 2.33 DRILL P PROD1 0.92 DRILL P PROD1 0.58 DRILL P PROD1 0.75 DRILL P PROD1 0.17 DRILL P PROD1 0.25 DRILL P PROD1 1.25 DRILL P PROD1 1.00 DRILL P PROD1 0.75 DRILL P PROD1 Description of Operations _____.____._________... __.. .... _.._ ......____. _0... _..._...... no m_.__.__ 13050', wiper trip to shoe. Orient to 80R. Resume drilling. Losses have increased a bit. May have broken something down by orienting. Now drilling at 2.5/2.2/3620 psi. ROP=90 fph. Pit vol=292 bbls. 13109', continue drilling. 2.53/2.27/3190 psi. Losses have improved a bit. Pit level=260 bbls. 13145', Orient to 70R. Resume drilling. 2.5/2.2/3220 psi. 13186', Long wiper trip up to 10300'. (Less than 60 degrees inclination.) Orient to high side. Drill at 2.5 12.21 3,350 psi. Orient to 50L. Drill to 13,220'. Orient to 70R. Pit volume 167 bbls. Drill at 70 - 90R TF, 2.5 I 2.1 I 3,430 psi. Start pumping new mud down coil to add volume. Drill to 13,321'. Wiper trip to 12,695'. RIH. Drill from 13,321' to 13,450' at 60 - 80 RTF. Wiper trip to window. Drill from 13,450' to 13,490' at 85 RTF. Get two clicks and drill from 13,490' to 13,546' at 115R TF. Losing 0.6 bpm. Orient TF to 90L. Drill from 13,546' to 13,547' at 90L TF. Stacking weight. Wiper trip to shoe. RIH. Hanging up at 12,912'. This is revert entry back into Z4 from shublik. Orient to 1 OOL to get by 12,912'. RIH. Orient to 119L. Pit volume 156 bbls. Start new mud down coil to add volume. Drill at 2.6/1.9/3,670 psi, 104 L TF. 13598', Drilling ahead. Able to make acceptable ROP in sands, with surface weight of + 6klbs. Have to snub to -10k Ibs when we hit little shale stringers. Taking on new mud from vac truck. Current mud lubricant is lubetex at 3%. Adding the 3 drums of Flo-Iube that we have on location to bring the concentration up to 1 % Flo-Iube. Getting more lubricant out to raise it to maximum. Will shoot for 4% Lubetex and 1.5% Flo-Iube. IAP=O, OAP=142 psi. Free spin is 3100 psi at 2.55 bpm. Drilling at 2.53/2.04/3440 psi. Loosing about 1/2 bbl/min, 30 bbl/hour. ROP=116 fph. PROD1 13674', Start long wiper trip up to 10300'. Had overpulls and motor work from 13000-12850'. Possibly cuttings beds? Had packing off and overpulls as we pulled into the liner. Worked thru it slow. Continue pulling to vertical section of the hole. 2.17 DRILL P 0.25 DRILL P 0.58 DRILL P Ran back down, made it thru sticky spots without setting down, or with any problems. Made it to bottom easily PROD1 Orient 70R. PROD1 Resume drilling. 2.55/1.84/3600 psi. String wt=-2000 Ibs. Pit vol=295 bbls, truck is currently round tripping for more mud. IAP=0,OAP=144. Returns are slightly improving as we drill. Printed: 11/1712003 8:40:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To __moo .. _. __ ___00 _..._. 11/8/2003 21:40-22:15 22:15 - 23:15 23:15 - 00:00 11/9/2003 00:00 - 00:50 00:50 - 01 :45 01:45-02:15 02:15 - 03:00 .... a Page 4 of 9 BP EXPLORATION Operations Summary Report S-24A S-24A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours I Task ---.-- - 0.58 DRILL P 1.00 DRILL P 0.75 DRILL P 0.83 DRILL P 0.92 DRILL P 0.50 DRILL P 0.75 DRILL P Start: Rig Release: Rig Number: Phase I 11/5/2003 11/13/2003 N1 Spud Date: 4/24/1990 End: 11/13/2003 ! Code I NPT . ì .--..--. .. PROD1 PROD1 PROD1 PROD1 PROD1 Description of Operations n..__ _____... .. ....... -........ ...-.. -- .-.--.-.... ---.-- .. .... . -.. - ..-.-------.------ -.-.. . .. ROP=110fph. 13737', PU to orient. Resume drilling. 2.53/1.79/3500 psi. At 13774', seem to be getting some more reactive torque. About 90-180 degrees. Continuing to add lubetex and flolube to bring the concentrations in the mud to 4% lubetex and 1.5% flolube. 13782', Drilling ahead. Pit level =220 bls. Truck with new mud in route from MI. IAP=20, OAP=146, Good weight transfer at this time. Drilling with +6000 Ibs string wt. 13803', Wiper trip to shoe. PU off bottom clean. Pulled into something at 13705'. Motor stalled, SD pumps, worked it up and down and popped free. Kick pumps back on, continue with wiper trip. Probably cuttings. Continue trip to shoe. No problems thru interval at 12912'. PROD1 12585', Log tie in pass up. Make +3' correction. May have broken down the CaC03 in the perfs. During logging pass losses went up to 2.5/0.75 Oops. PROD1 Run back in the hole to resume drilling. Will try to drill a bit and see if cuttings will seal off our losses. Call for another vac truck to join the round trips from MI. Set down at 13675' on run back in the hole, stalled motor. Worked back thru after 5 trys. 13803', Resume drilling. 2.6/0.6/3700 psi. Loosing 2 bpm. Hopefully some cuttings in the liner will slow losses. Loss zone is suspected to be in the previously perforated interval. 13818', Orient to 45R. Not going to help our losses any. Resume drilling. Slow ROP. Have been in a shale since 13750'. 13833', Can't make any ROP in this shale we are stuck in. Make a short wiper trip up to 13500'. Resume drilling. 2.53/0.91/3800 psi. Pit vol=193 bbls. Peak vac truck broke down. Need to wait for Veco truck that just left location. Returns have improved slightly. 13840', Returns have improved to 2.53 in, 2.1 out. Don't want to make any more tie in passes, or disturb the perfs any more than we have to. 13857', Drilling ahead and had CT pressure up. Pickup off bottom clean and are pumping 1.010.7614000 psi. Something is plugged off down hole. Suspect a stator rubber chunk plugging off the bit. PUH, cycle the pumps to try to blow the bit clean unsuccessfully. Take pump pressure to 5000 psi 2 x with no success. PUH, pumping 1.010.72, need to come out and fix the BHA problem. DFAL PROD1 POOH. DFAL PROD1 PJSM for LD BHA. Discuss potential for trapped pressure. Pull to bit and found Xtreme motor unscrewed at adjustable bend threads and adjustment retainer rings were left in hole. Discuss plan forward with Anchorage while LD BHA. Break bit, download MWD, LD tools. DFAL PROD1 Wait on fishing tools. DFAL PROD1 PU Baker venturi junk basket, equilizer sub, orienter, Baker circ sub, Baker disconnect, 2 joints PH6, Dowell disconnect, check 03:00 - 03:20 0.33 DRILL P PROD1 03:20 - 03:35 0.25 DRILL P PROD1 03:35 - 04:20 0.75 DRILL P PROD1 04:20 - 04:35 0.25 DRILL P PROD1 04:35 - 04:50 0.25 DRILL P PROD1 04:50 - 05:45 0.92 DRILL P PROD1 05:45 - 06:00 0.25 DRILL N DFAL PROD1 06:00 - 08:30 08:30 - 10:30 10:30 - 12:30 12:30 - 13:45 2.50 DRILL N 2.00 DRILL N 2.00 DRILL N 1.25 FISH N Printed: 11/17/2003 8:40:18 AM ,.,. .. Page 5 of 9 BP EXPLORATION Operations Summary Report Legal Well Name: S-24A Common Well Name: S-24A Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To I Hours i Task Code NPT !_...... ....... I 12:30 - 13:45 1.25 FISH 13:45 - 16:35 2.83 FISH 11/9/2003 16:35 - 17:10 0.58 FISH N 17:10 -19:30 2.33 FISH N 19:30 - 20:30 1.00 FISH N 20:30 - 22:00 22:00 - 00:00 1.50 DRILL N 2.00 DRILL N Start: Rig Release: Rig Number: Phase I Spud Date: 4/24/1990 End: 11/13/2003 11/5/2003 11/13/2003 N1 Description of Operations . - ----.-..-- ... ._n u_. -- _....,------ ...- .........-----. n____... N N DFAL PROD1 DFAL PROD1 valves, NRJ. RIH at 100 fpm pumping at 1.5 bpm. At 11,550' slow running speed to 50 fpm and increase pump to 2.2 bpm. Slow running speed to 30 fpm in OH. Losing at 0.5 bpm. SO= 12,500 Ibs at 13,300' SO= 11,500 Ibs at 13,750' Tag bottom at 13,857'. PROD1 PU to 13,800'. Orient 5 clicks and RIH 30 fpm pumping 1.5 bpm. Tag at 13,873'. Increase rate to 2.5 bpm, 3,640 psi. PU=39,000 Ibs. PU to 13,850'. RIH and tag at 13,873'. PU to 13,825' and orient 5 clicks. RIH. Tag at 13,873'. PU and orient 5 clicks. RIH. Tag at 13,873'. Poke around on bottom. PROD1 POOH pumping at 1.5 bpm until 12,600'. Shut down pump and POOH filling across the top. DFAL PROD1 Tag up at surface, stand back fishing BHA dump Venturi Basket. Found 1/2 cup of formation cuttings, several 2"x1"x1/4" pieces of cement, and 1 large 6"x3"x1" chunk of cement jammed into the mule shoe. Discuss with down the best plan forward. Plan is to lay down fishing eq, and go to drilling with a reduced BHA. Lay down fishing BHA. DFAL PROD1 Make up drilling BHA. DFAL PROD1 RIH with BHA #6, DS49, Baker HP motor, Sperry GR-DIR, No RES tool in this BHA. Shallow pulse test at 500'. Orienter and Agitator test at 3100'. Got good indication of agitator activation. Orienter worked fine. Continue RIH. Continue RIH to resume drilling. Kick on pumps to full rate at 12800'. TF=120L. RIH at 40 fpm, 2.57/1.98/4142 psi. Tag bottom, make a -4' correction to last tagged depth of 13857'. PUH 200' to see if the fish is going to stick us. No problem. 13857', Orient to 30R. After orienting, Free spin =2.57/1.99/4000 psi. Pressure gain after laying out RES tool and picking up Agitator tool is 550 psi. Hard to determine real actual pressure gain due to the Agitator, because the RES tool normally has a significant effect on pump pressure. I'd guess 950 psi. DFAL PROD1 When we tagged bottom to begin drilling the Sperry pulser quit. Tried cycling the pumps several times, and it wouldn't come back on. POOH to fix Sperry's equipment. Pulling into the casing shoe it started working again for a short period, then shut off. POOH. Keep pumps on to watch the Sperry signal. Worked intermittantly a few times on the way OOH, but definately is not functioning properly. DFAL PROD1 Tag up stand back injector, hold PJSM about plan forward, and best way to check out BHA. DFAL PROD1 Check orienter, agitator, motor. All seemed tight and in good condition. Change out MWD probe. Change out Agitator. Replace Baker float with Baker dual check valve. No obvious problems found with anything. DFAL PROD1 RIH with BHA #7. DS49 bit, Baker HP mud motor, Sperry DIR-GR, Baker Dual Checks, Agitator #312. Shallow hole 11/10/2003 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 01 :00 - 01 :15 0.25 DRILL P PROD1 01 :15 - 01 :35 0.33 DRILL P PROD1 01 :35 - 01 :50 0.25 DRILL P PROD1 01 :50 - 04:40 2.83 DRILL N 04:40 - 05:00 0.33 DRILL N 05:00 - 05:50 0.83 DRILL N 05:50 - 08:00 2.17 DRILL N Printed: 11/1712003 8:40:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To / "' ..., - ........ Page 6 of 9 BP EXPLORATION Operations Summary Report S-24A S-24A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours I Task ; Code NPT Start: Rig Release: Rig Number: Phase 11/5/2003 11/13/2003 N1 Spud Date: 4/24/1990 End: 11/13/2003 -- ____no ...... -- 11/10/2003 05:50 - 08:00 2.17 DRILL N DFAL PROD1 08:00 - 08:30 0.50 DRILL P PROD1 08:30 - 09:00 0.50 DRILL N DFAL PROD1 09:00 - 09:30 0.50 DRILL N DFAL PROD1 09:30 - 12:40 3.17 DRILL P PROD1 12:40 - 14:00 1.33 DRILL P PROD1 14:00 - 16:30 2.50 DRILL P PROD1 16:30 - 18:00 1.50 DRILL P PROD1 18:00 - 18:30 0.50 DRILL P PROD1 18:30 - 18:50 0.33 DRILL P PROD1 18:50 - 21 :50 3.00 DRILL P PROD1 21 :50 - 22: 15 0.42 DRILL P PROD1 22:15 - 23:45 1.50 EVAL P PROD1 23:45 - 00:00 0.25 EVAL P PROD1 11/11/2003 00:00 - 02:00 2.00 EVAL P PROD1 02:00 - 02:30 0.50 EVAL P PROD1 02:30 - 03:00 0.50 EVAL P PROD1 03:00 - 03:45 03:45 - 03:55 03:55 - 04:25 04:25 - 06:50 06:50 - 08:50 08:50 - 09:15 09:15 -13:50 0.75 EVAL P 0.17 EVAL P PROD1 PROD1 0.50 EVAL P PROD1 2.42 EVAL P PROD1 2.00 EVAL P 0.42 CASE P 4.58 CASE P PROD1 COMP COMP Description of Operations .- --.--- ......---....--------. ..------------ check. RIH to 12,500'. Rig evacuation drill. RIH. No hole problems. Tag bottom. Correct depth to 13,857'. MAD pass GR to get data gap from difference in BHA length wlo resistivity tool. Drill at 2.451 2.27 I 4,150 psi 45R TF. Pit volume=176 bbls. Start new mud down coil to add volume. Drill to 14,000'. Wiper trip to window. Drill to 14,128'. Wiper trip to 12,600'. Drill at 2.3 12.3 14,000 psi, 90L TF 14140', Continue drilling. 2.37/2.17/4000 psi. Hard drilling and GR is wrapped around to 200 + API. IAP=57 psi, OAP=200 psi. Pit vol=220 bbls" 140 bbls on Vac truck. 14145'. Geologist thinks we are in the Shublik. Does not want to drill excess hole in the shublik. Make a wiper trip to the shoe while we wait for a bottoms up sample to confirm. Got bottoms up sample, confirming that we are in the Shublik by 40'. We have enough rathole to bury our float eq. POOH to run MAD pass with RES tool. Tag up, stand back injector. Hold PJSM re BHA swap, and plan forward. Lay down Agitator, Baker Check valves. PU SWS check valves in BHA above the Disconnect. PU sperry RES tool. Program RES tool. Check Bit. Scribe MWD. RIH with BHA #8 to MAD pass for missing RES data. RIH with BHA #8. Shallow hole test passes ok for MWD and orienter @ 3000'. Log tie in pass up from 12590' @60fph. Make -17' correction. RIH to TD. Weight bobbled at 12915' when running in with pumps down, but then fell thru. RIH and tag up at 14155'. Repeat to confirm. RIH weight with pumps on is 17 klbs. Pickup weight is 34 klbs. Log MAD pass up for RES data at 10 fpm to 13800'. RIH dry from 13800 to simulate running liner to bottom. Depth String Weight 13800 15000# 13900 15900# 14000 15600# 14100 15300# 14150 15000# Make pickup weight dry off of bottom, = 38500 Ibs. Pump 70 bbls of new mud to bit. Circulation rate 2.5/2.2/3200 psi. Having 12% losses, 88% returns while yo-yoing pipe and circulating at TD. POOH laying in 70 bbls of new mud with 4% lubetex and 1.5% flolube. PUH slick in open hole. No problems at any of the shales, the spot at 12915', or the shoe. Pump all the way out at 2.5 bpm to clean hole. Stand back injector. Download MWD data. LD BHA. PJSM for running liner. Run 2 7/8" x 3 3/16" liner. Printed: 11/17/2003 8:40:18 AM / .. ..... BP EXPLORATION Page 7 of 9 Operations Summary Report Legal Well Name: S-24A Common Well Name: S-24A Spud Date: 4/24/1990 Event Name: REENTER+COMPLETE Start: 11/5/2003 End: 11/13/2003 Contractor Name: NORDIC CALISTA Rig Release: 11/13/2003 Rig Name: NORDIC 1 Rig Number: N1 ; ¡ Date From - To Hours Task Code NPT Phase Description of Operations ---- . -.... .-. un_n_ ...... ....-...-.. 11/11/2003 13:50 - 14:30 0.67 CASE P COMP Remove Schlumberger CTC. Install Baker CTC. Pressure test to 3,300 psi, pull test to 30,000 Ibs. 14:30 -16:20 1.83 CASE P COMP RIH wI liner on coil. Catch flag #1 at 12577' CTM. Made a -24' correction, which is consistent with what we have seen on previous runs. Weight check up =35klbs. Continue RIH pumping 0.6 bpm. slight weight bobble at the shoe, significant weight bobbles below 12915', Set down at 13000, then fell thru. RIH weight at 13150'=14 klbs, 13500'=11000#, 13900'=6000#, Checked flag at 13978', and were 3' shallow. Weight at 14000'=3000#, Set down at 14010', PU at 35 klbs, worked it down from there. Weight at 141 00'=4000Ibs, 14150'=3000Ibs. Made it to 14155'. Life is good! 16:20 - 16:50 0.50 CASE P COMP Drop 5/8" ball to release from CTLRT. Coil tubing volume=61.1 bbls. Pumping mud at 2.76 bpm, Returns are 1.3 bpm. Returns are 2.78/1.75 at 20 bbls away. 2.7711.86 at 30 bbls away. 2.77/1.97 at 40 bbls away. Ball on seat at 51 bbls away. Good indication of shear at 4500 psi. PU 2' at 30 klbs. Confirmed released from CTLRT. 16:50 - 21 :00 4.17 CEMT P COMP Circulate the well to 2% KCL. Pumping mud 2.75/2.02/2800 psi. Returns at 75% at 3.0 bpm. Clean rig pits. Fill with 2% KCL water. Mix Biozan pill in pill pit. 21 :00 - 21 :30 0.50 CEMT P COMP Batch up Cement. Cement at wt. at 2130 hrs. 21 :30 - 21 :45 0.25 CEMT P COMP SAFETY MEETING. Review procedure, hazards and mitigation to pump liner cement job. 21 :45 - 22:25 0.67 CEMT P COMP Pressure test cement line. Stage 28.1 BBL, 15.8 PPG, G Cement, 2.0/1.60 bpm, 1600 psi, Insert dart, close reel valve. clean cement line. 22:25 - 23:00 0.58 CEMT P COMP Displace Dart with Biozan water. 2.7/2.3 bpm, 2000 psi, Zero out total with cement at shoe. Slow rate to 1.5 bpm at 54 bbls. Dart on LWP at 61.4 bbL LWP sheared at 3600 psi, Displace LWP at 3.0 12.3 bpm. 2800 psi, Returns dropped from 2.3 to 1.8 bpm with 10 bbls out. Slow rate to 2.5 bpm I 1.8 bpm, 2400 psi. Slow rate to 1.0 bpm at 79 bbls, Bump plug with 1300 psi at 81.9 bbls. [0.2 bbls early]. Check floats. OK. 24 bbl cement returns from out totalizer. 23:00 - 00:00 1.00 CEMT P COMP Sting out of top of liner. 29K up wt. POH while contaminate with Biozan. Replace CT volume only. Cement job went well. 11/12/2003 00:00 - 01 :00 1.00 CEMT P COMP POH with BKR CTLRT. 01 :00 - 01 :30 0.50 CEMT P COMP UO BHA. Recover all tools. 01 :30 - 02:30 1.00 EVAL P COMP MIU 2.30" mill, motor, SWS memory GR I CCL in carrier, BKR circ sub and hyd disc. 02:30 - 05:45 3.25 EVAL P COMP PIU 102 jts of 1-1/4" CSH workstring and SWS MHA. BHA total length = 3,192.5 ft. 05:45 - 06:45 1.00 EVAL P COMP RIH with cleanout I GR I CCL logging BHA. Circ. in 25 bbls Bleach at 0.3 bpm, 150 psi pump press. Circ. 2% KCL water behind bleach. 06:45 - 12:30 5.75 EVAL P COMP Stop at 9000 ft. Wait on cement compressive strength. 12:30 - 12:40 0.17 EVAL P COMP Cement at 500psi, displace bleach out of coil, continue running in hole 12:40 - 13:35 0.92 EVAL P COMP Stop at 9900ft, log down at 60 FPM to PBTD. 13:35 - 13:42 0.12 EVAL P COMP Stop at 13180 backside line frozen, sending 1st bleach pill Printed: 11/17/2003 8:40:18 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I Date i From - To 11/12/2003 13:35-13:42 13:42 - 14:00 14:00 - 15:40 15:40 - 17:00 17:00 - 17:55 17:55 - 19:00 19:00 - 20:45 20:45 - 21 :45 21:45 - 22:15 22:15 - 22:30 22:30 - 00:00 11/13/2003 00:00 - 00:15 00:15 - 02:15 02:15 - 04:00 Page 8 of 9 BP EXPLORATION Operations Summary Report S-24A S-24A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours Task Code NPT Phase --..-.----.- .--. COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP ----------.--- ----." 0.12 EVAL P 0.30 EVAL P 1.67 EVAL P 1.33 EVAL P 0.92 EVAL P 1.08 EVAL P 1.75 EVAL P 1.00 CEMT P 0.50 PERF P 0.25 PERF P 1.50 PERF P 0.25 PERF P 2.00 PERF P 1.75 PERF P COMP 04:00 - 06:00 2.00 PERF P COMP 06:00 - 06:30 0.50 PERF P COMP 06:30 - 06:45 0.25 PERF P COMP 06:45 - 10:00 3.25 PERF P COMP 10:00 - 10:15 0.25 PERF P COMP 10:15 - 10:45 0.50 PERF P COMP 10:45 - 12:00 1.25 WHSUR P COMP 12:00 - 13:00 1.00 WHSUR P COMP 13:00 -14:00 1.00 RIGD P POST 14:00 - 15:00 1.00 RIGD P POST Start: Rig Release: Rig Number: Spud Date: 4/24/1990 End: 11/13/2003 11/5/2003 11/13/2003 N1 Description of Operations outside. Continue logging @ 60 fpm, started pumping bleach at 13,000 ft. Tag bottom at 14132, pick-up to 14128 circulate bleach to bit at 0.5 bpm. Start logging up @ 60 fpm, laying in bleach. Stop the log at 9900', POOH with coil tubing, pumping at 0.5 bpm to keep the hole full. (SWS is using 0.5 bpm as max safe rate to prevent damaging their equipment.) Stand back injector, drop a 5/8" ball to open the circ sub. Open circ sub. Circ until fluids balanced. Stand back 51 stds of CSH workstring. UO SWS logging tools and motor and mill. Pressure test liner lap with 3000 psi, Chart test. 30 min. test. 3080 psi at start, 2980 psi at end. 100 psi drop in 30 min. Good Test. Load perf guns in pipe shed. SAFETY MEETING. Review procedure, hazards and mitigation for MIU SWS 2" Perf guns. MIU SWS 2" perf guns, total of 50 ft of charges at 6 SPF. MIU Hyd Disc, XO and 51 stds of CSH workstring. M/U 2" SWS Perforating BHA with 51 stds of CSH and SWS MHA. Total length = 3,234'. RIH with perforating BHA. Circ at 0.4 bpm, 220 psi. Tag PBTD at 14,126', Correct depth to GRICCL PBTD of 14,119'. [-7 ft CTD]. Pull bottom perf charge up to 14,060'. Circ. in 26 bbl bleach ahead of perf ball. 1.2 bpm, 1420 psi, Insert 5/8" Aluminum ball. Displace with new 2% KCL water. 1.7 bpm, 3100 psi. Bottom perf charge located at 14,060 ft. Ball on seat at 63 bbls, Firing head sheared at 3000 psi. PERFORATED INTERVAL: 14,010 - 14,060 FT. 50 FT AT 6 SPF. POH. Circ in new clean 2% KCL water at 10,500 ft. Bleach in hole from 10,500-14,119'. Clean rig pits. Tag up at surface. Standby for crew change. Safety meeting with day tour reguarding laying down CS Hydril work string. Lay down 102 joints of CS Hydril work string. Hold safety meeting prior to laying guns down. Lay down 3 SWS perf guns. All guns fired, all shots fired. Stab on injector, Jet out stack. Swap to methanol, RIH. Lay in methanol from 2200' to surface. PUmp a total of 28 bbls. The last 500' was neat methanol. Left neat meth in the tree. Tag up at surface. Close the swap valve. Blow down the reel with N2. Unstab injector. Unstab coil. Stab injector in stabbing box. NIU Tree cap and pressure test. RELEASED RIG AT 1500 HRS, 11-13-2003. TOTAL TIME ON WELL WAS 7 DAYS, 19.5 HOURS. Printed: 11/17/2003 8:40:18AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/13/2003 15:00 - 21 :00 21 :00 - 21 :30 21 :30 - 00:00 Page 9 of 9 BP EXPLORATION Operations Summary Report S-24A S-24A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 6.00 RIGD P 0.50 RIGD P POST POST Start: Rig Release: Rig Number: From - To Hours Task Code I NPT Phase I 2.50 RIGD P POST 11/5/2003 11/13/2003 N1 Spud Date: 4/24/1990 End: 11/13/2003 Description of Operations --.-"-------- Pull off well. Lay down wind walls. Lay down derrick. Held pre-rig move safety meeting with Security, tool service, CPS, Nordic and SWS personnel. Reviewed rig move plan and all safety concerns. Move Nordic 1 to H pad. Printed: 11/17/2003 8:40:18 AM . AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well S-24 B Dear Dear Sir/Madam: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 12,643.81' MD 12,687.00' MD 14,155.00' MD . (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~~~,,'-~~ Bð3~} 0Jð 26-Nov-03 ECEIVED DEC 082003 ,j" (Ù !j8S Cor&Gømmileion AnchOfSl' Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA S Pad S-24B Job No. AKMW0002762907, Surveyed: 10 November, 2003 Survey Report 24 November, 2003 Your Ref: API 500292204402 Surface Coordinates: 5979855.00 N, 619213.00 E (70' 21'12.9713" N, 149' 01' 55.0091" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 979855.00 N, 119213.00 E (Grid) Surface Coordinates relative to Structure Reference: 1021.73 S, 1280.19 E (True) Kelly Bushing Elevation: 63. 77ft above Mean Sea Level Kelly Bushing Elevation: 63. 77ft above Project V Reference Kelly Bushing Elevation: 63. 77ft above Structure Reference speararaY-SUI! DRILL.ING se.R\lIc:es A Halliburton Company EFt N ITIVE . . . Survey Ref: svy4125 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-24B Your Ref: API 500292204402 Job No. AKMW0002762907, Surveyed: 10 November, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12643.81 95.530 288.540 8859.74 8923.51 4199.90 N 4953.50 W 5983975.55 N 614193.30 E 6494.24 Tie On Point 12687.00 95.530 288.540 8855.58 8919.35 4213.57 N 4994.26 W 5983988.57 N 614152.33 E 0.000 6534.25 Window Point 12697.13 95.150 288.540 8854.64 8918.41 4216.78 N 5003.82 W 5983991.62 N 614142.72 E 3.751 6543.64 12732.19 91.810 287.500 8852.51 8916.28 4227.60 N 5037.09 W 5984001.92 N 614109.28 E 9.976 6576.08 12767.85 88.520 286.240 8852.41 8916.18 4237.95 N 5071.21 W 5984011.72 N 614075.00 E 9.879 6608.87 12802.72 85.460 284.370 8854.24 8918.01 4247.14 N 5104.79 W 5984020.37 N 614041.27 E 10.280 6640.51 . 12834.74 83.960 281.550 8857.19 8920.96 4254.29 N 5135.86 W 5984027.03 N 614010.10 E 9.942 6668.90 12866.94 81.410 279.440 8861.29 8925.06 4260.11 N 5167.26 W 5984032.35 N 613978.61 E 10.245 6696.69 12899.18 78.060 270.630 8867.05 8930.82 4262.90 N 5198.82 W 5984034.64 N 613947.01 E 28.822 6722.67 12931.49 76.650 268.160 8874.12 8937.89 4262.57 N 5230.34 W 5984033.81 N 613915.49 E 8.642 6746.60 12964.57 76.650 261.640 8881.77 8945.54 4259.71 N 5262.38 W 5984030.44 N 613883.50 E 19.177 6769.31 12996.05 77.530 256.180 8888.80 8952.57 4253.81 N 5292.48 W 5984024.06 N 613853.50 E 17.135 6788.57 13027.08 80.090 251.600 8894.83 8958.60 4245.36 N 5321.71 W 5984015.14 N 613824.41 E 16.663 6805.53 13065.17 82.470 249.830 8900.60 8964.37 4232.92 N 5357.25 W 5984002.14 N 613789.08 E 7.755 6824.76 13108.92 83.260 258.470 8906.05 8969.82 4221.08 N 5398.97 W 5983989.64 N 613747.55 E 19.678 6849.11 13141.30 82.640 265.520 8910.03 8973.80 4216.61 N 5430.77 W 5983984.66 N 613715.83 E 21.692 6870.59 13169.48 83.960 268.690 8913.31 8977.08 4215.20 N 5458.71 W 5983982.80 N 613687.91 E 12.114 6891.09 13201.96 88.280 272.920 8915.51 8979.28 4215.65 N 5491.10W 5983982.75 N 613655.52 E 18.592 6916.20 13232.00 91.190 274.330 8915.65 8979.42 4217.55 N 5521.08 W 5983984.17 N 613625.51 E 10.764 6940.38 13262.81 92.160 282.430 8914.75 8978.52 4222.04 N 5551.52 W 5983988.17 N 613595.00 E 26.467 6966.58 13296.25 93.220 287.370 8913.18 8976.95 4230.62 N 5583.79 W 5983996.24 N 613562.60 E 15.093 6996.82 13324.11 93.740 292.480 8911.49 8975.26 4240.10 N 5609.92 W 5984005.30 N 613536.32 E 18.403 7022.93 . 13359.00 93.660 298.290 8909.23 8973.00 4255.02 N 5641.37 W 5984019.71 N 613504.64 E 16.619 7056.61 13404.39 95.240 307.980 8905.70 8969.47 4279.72 N 5679.22 W 5984043.81 N 613466.41 E 21.566 7101.48 13429.31 96.040 313.800 8903.25 8967.02 4295.94 N 5697.96 W 5984059.74 N 613447.41 E 23.462 7126.27 13464.44 96.740 322.960 8899.33 8963.10 4322.01 N 5721.12 W 5984085.43 N 613423.83 E 25.989 7160.77 13497.03 95.950 329.130 8895.73 8959.50 4348.87 N 5739.20 W 5984112.00 N 613405.33 E 18.971 7191.88 13530.46 92.160 335.120 8893.36 8957.13 4378.33 N 5754.78 W 5984141.20 N 613389.28 E 21.163 7222.75 13573.65 87.590 329.270 8893.46 8957.23 4416.50 N 5774.91 W 5984179.06 N 613368.55 E 17.185 7262.71 13612.14 85.110 323.840 8895.91 8959.68 4448.54 N 5796.07 W 5984210.75 N 613346.88 E 15.482 7299.51 13643.78 84.930 317.850 8898.66 8962.43 4472.97 N 5815.96 W 5984234.87 N 613326.60 E 18.869 7330.46 13679.82 87.310 316.270 8901.10 8964.87 4499.29 N 5840.46 W 5984260.79 N 613301.69 E 7.921 7366.14 13713.14 85.290 322.430 8903.25 8967.02 4524.51 N 5862.11 W 5984285.66 N 613279.64 E 19.418 7398.93 13745.04 82.640 327.010 8906.61 8970.38 4550.39 N 5880.42 W 5984311.25 N 613260.92 E 16.517 7429.60 13779.09 84.140 332.830 8910.53 8974.30 4579.65 N 5897.37 W 5984340.23 N 613243.51 E 17.540 7461.39 24 November, 2003 - 17:25 Page 2 of 4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-24B Your Ref: API 500292204402 Job No. AKMW0002762907, Surveyed: 10 November, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 13815.64 83.260 337.060 8914.54 8978.31 4612.55 N 5912.75 W 5984372.88 N 613227.61 E 11.752 7494.32 13844.73 88.720 343.230 8916.58 8980.35 4639.82 N 5922.59 W 5984400.00 N 613217.33 E 28.277 7519.39 13874.08 91.280 346.040 8916.58 8980.35 4668.12 N 5930.37 W 5984428.16 N 613209.11 E 12.951 7543.53 13908.78 94.270 349.570 8914.90 8978.67 4701.98 N 5937.69 W 5984461.91 N 613201.25 E 13.322 7570.91 13936.56 95.510 352.040 8912.53 8976.30 4729.31 N 5942.11 W 5984489.16 N 613196.39 E 9.920 7591.86 13972.31 97.270 357.500 8908.55 8972.32 4764.67 N 5945.35 W 5984524.47 N 613192.59 E 15.956 7617.07 . 14012.00 97.180 0.670 8903.55 8967.32 4804.03 N 5945.98 W 5984563.82 N 613191.33 E 7.927 7642.86 14046.72 97.090 3.310 8899.24 8963.01 4838.46 N 5944.78 W 5984598.26 N 613191.98 E 7.549 7664.07 14076.87 97.710 10.890 8895.35 8959.12 4868.11 N 5941.09 W 5984627.96 N 613195.20 E 25.016 7680.30 14107.23 96.040 11 .240 8891.72 8955.49 4897.69 N 5935.31 W 5984657.63 N 613200.51 E 5.618 7694.88 14125.49 97.000 9.300 8889.64 8953.41 4915.54 N 5932.07 W 5984675.53 N 613203.46 E 11 .792 7703.88 14155.00 97.000 9.300 8886.05 8949.82 4944.44 N 5927.34 W 5984704.50 N 613207.74 E 0.000 7718.83 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 310.000° (True). Magnetic Declination at Surface is 25.339° (06-Nov-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 14155.00ft., The Bottom Hole Displacement is 7718.87ft., in the Direction of 309.834° (True). . 24 November, 2003 - 17:25 Page 3 of 4 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_WOA S Pad - S-24B Your Ref: API 500292204402 Job No. AKMW0002762907, Surveyed: 10 November, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 12643.81 12687.00 14155.00 8923.51 8919.35 8949.82 4199.90 N 4213.57 N 4944.44 N 4953.50 W 4994.26 W 5927.34 W Tie On Point Window Point Projected Survey . Survey tool proøram for S-24B From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 2665.65 0.00 2665.65 2665.50 14155.00 2665.50 BP High Accuracy Gyro (S-24) 8949.82 MWD Magnetic (S-24A) . 24 November, 2003 - 17:25 Page 4 of4 DrillQuest 3.03.05.005 . (ffi~ ~~~~æ~ AI/ASIiA. OIL AND GAS CONSERVATION COMMISSION Mark O. Johnson CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519-6612 . FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe bay Unit S-24B BP Exploration (Alaska), Inc. Permit No: 203-163 Surface Location: 1633' SNL, 1050' EWL, Sec. 35, TI2N, RI2E, UM Bottomhole Location: 3408' NSL, 4885' WEL, Sec.27, TI2N, RI2E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~.".,_.,.. ¿/ ~~L Commissioner BY ORDER OF THE COMMISSION DATED this~ day of September, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section /~-') l í" ~// (J ;- '. ....\j C^-./~ W41\- q/'l..7) IZOO~ 1a. Type of work o Drill II Redrill rb. Current Well Class o Exploratory o Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test II Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and Number: / BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU $-24B 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 14250' TVD 8862'55 Prudhoe Bay Field I Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028258 1633' SNL, 1050' EWL, SEC. 35, T12N, R12E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: September 30, 2003 ./ 1843' NSL, 1826' WEL, SEC. 27, T12N, R12E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 3408' NSL, 4885' WEL, SEC. 27, T12N, R12E, UM 2560 4603' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation KBE= 15. ~tance to Nearest Well Within Pool Surface: x-619212 y-5979855 Zone-ASP4 (Height above GL): 63.77' feet S-03 is 744' away at 12750' MD 16. Deviated Wells: 17. Anticipated pressure (see 20 AAC 25.035) fl-~f" ./ Kickoff Depth 12687 ft Maximum Hole Angle 104 0 Max. Downhole Pressure: 4000 psig. Max. Surface Pressure: 3115 psig 18. Casing Program §þecificØtions TI ¡p"''''lUII\: ...."'..."'801 tom . l&f.c ~rsacks) Size Hole Casina Weiaht Grade Couolina Lenath MD TVD MD TVD (includinc staae data) 4-118" x 3-3/4" 3-3/16" x 2-7/8" 6.2# /6.16# L-80 CIII STL 3150' 11100' 8861' 14250' 8862' 146 cu ft Class 'G' ,. 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft): I Junk (measured): 12700' 8918' None 12599' 8928' None ~".,i'"'"" ) ...., Si:ze ....j/? 1:// ..../, .., /)l·t...., j·/·······iMQ /' ,'TVQ)' ..' t Conductor 110' 20" 8 cu yds Concrete 110' 110' ~ r 2668' 13-3/8" 2580 cu ft Arcticset II & III 2668' 2668' Inter 10146' 7" 1403 cu ft Class 'G' ., .1D180r . X'" ~722' Prnrhlr.tinn " '. .... Liner 2684' 4-1/2" 432 cu ft Class 'G' 10OQ~....1~6W' ,.S565' - 8919' n:-· ~ \J ,-'., '. .' .'. Perforation Depth MD (ft): 12377' - 12597' IPerfOration Depth TVD (ft): 8950' - 8928' , .",,"', 20. Attachments 181 Filing Fee 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Johnson, 564-5666 Printed Name Mark Johnson () Title CT Drilling Engineer /n"" L 0, (fA. 9 J¡~/o 3 Prepared By Name/Number: Sianature '/f7 A.., Phone 564-5666 Date Terrie Hubble, 564-4628 ...... ..'·....¥f;/.'!'tt' './ i... ·.·.···..i/ iti ........' .. ......... , " .!..! Permit To Drill I API ~~ber: Permit APprovt )oJ.a. £.'\, ~ I ,see cover letter for Number: 2G~? -/£"3 50- 029-22044-02-00 Date: '"'i fI/ .2, R r other requirements Conditions of Approval: Samples Required DYes l8J No Mud Log Requir 9d , DYes 181 No Hydrogen Sulfide Measures g:¡ Yes DNo Directional Survey Required '":8J Yes DNo Other: T.e s t ßO~E to ~50o C'>I, MIl r~"ve:N. A. Original Signed By BY ORDER OF Date qla~h0 Sarah Palin Annroved Bv: COMMISSIONER THE COMMISSION Form 10-401 Revised 3/2003 ORIGINAL Silbmit In Duplicate _ STATE OF ALASKA _ ALASKA CW'AND GAS CONSERVATION CO~SION PERMIT TO DRILL 20 MC 25.005 e e BP S-24B Sidetrack Summary of ODerations: Well S-24A is scheduled for a through tubing sidetrack with the SLB/Nordic I Coiled Tubing Drilling rig on 9/30/03. This sidetrack, S-24B (injection well), will exit-ðtlt«the existing 4 W' liner float shoe and target Zone 4 sands to the Northwest. The existing injection perforations will be abandoned by liner cement from this ",.- S-24B liner (P&A sundry fonn already submitted). The following describes the planned sidetrack. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (Dhase 1) 1) Slickline -Drift tubing. Pressure test IA to 3000 psi. 2) CT - Cleanout liner to PBID. Drift with 3.8" mill to landing collar at 12599'. CTD Sidetrack Summary (Dhase 2) 1) MIRV CTD rig. 2) Mill out shoe track with 3.80" OD diamond speed mill. 3) Drill 4 lI8" x 3.75" bicenter bit openhole sidetrack to -14250' TD with MWD/gamma ray/resistivity. 4) Run 3 3/16" x 2 7/8" solid liner completion and cement. 5) Perforate 6) RDMO. Mud Program: · Phase I: 8.4 - 8.9 ppg brine , /" · Phase 2: 8.5 - 8.9 ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 33/16" x 2 7/8" solid cemented liner completion from 11100' to ID at 14250'. The 33/16" will run from 11100' to ~3 the 27/8" will run from 13325' to TD at 14250'. The liner cement volume is planned to be 26 bb of 15.8 ppg class G. / Well Control: · BOP diagram is attached. t' · Pipe rams, blind rams and the CT pack ofIwill be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 104 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD directional and Gamma Ray will be run over all of the open hole section. · Resistivity is optional. e e Hazards · S pad is not designated as an illS pad. Maximum recorded illS on the pad was 100 ppm from S-21 ./ 2/13/00. S-24A is an injector, so illS levels are not monitored. Based on high WC producers on S Pad, illS for S-24A is likely 60 ppm and will be assumed to be a high illS level well by the drilling team. All illS monitoring equipment will be operational. · No fault crossings are anticipated. Lost circulation risk is considered "low", but LCM material will be on location as a contingency. Reservoir Pressure · Res. press. is estimated to be 4000 psi at 8855'ss (8.7 ppg EMW). Reservoir pressure is expected to ./ decline as injection will be shut off prior to sidetracking. Max. surface pressure with gas (0.10 psi/ft) to surface is 3115 psi. Distance to nearest property · S-24B is 4603' from the PBU unit boundary line at TD of 14250' md. Distance to nearest well within pool · S-03 is 744' away at 12750' md in the S-24B directional plan. CasimúLiner Information 13 3/8", N-80, 68#, Burst 5020 psi; collapse 2270 psi 7", L-80, 26#, Burst 7240 psi; collapse 5410 psi 4 W' L-80 NSCT, 12.6#, Burst 8440 psi; collapse 7500 psi 3 3/16" L-80 TCII, 6.2#, Burst 8520 psi; collapse 7660 psi (connection same as body rating) 27/8" L-80 STL 6.16#, Burst 10570 psi; collapse 11170 psi (connection same as body rating) MOl 9/17/03 lREE = WELLHEAD = AClUA TOR = KB. 8.EV = BF. 8.EV = KOP= lltax Angle = C6tum M:> = C6tum 1V 0 = 4-1/8" CIN McEVOY AX 8. SON 64.77' 35.43' 2782' 97 @ 12411' 10430' 88(()' 55 TOP OF CevlßIT S-24A SAFEr OTe;: 9-518" CSG cur, Pl1.LB> & MILLED FROM SU~ACE TO srœ @ 2739' HORIZONTAL LNR. 70· @ 10383' AND 90" @ 11758' 2195' 4-1/Z'I-ESSSSV NIP, 10 =3.813" . I OLD 9-5/8" CSG -- 9941' 9952' 4-112" X NIP, 10 = 3.813" 13-318" CSG, 68#, N-80, 10 = 12.415" Minimum ID = 3.725" @ 9996' 4-1/2" XN NIPPLE 3020' 9975' 4-1/2"WILEG,ID=4.00" TOPOF 4-1/2" LfooR 10003' 4-1/2" lBG, 12.6#, L-BO, 0.0152 bpf,lD = 3.958" 7" LfooR, 26#, L-BO M)o, 0.0383 bpf, D = 6.276" 10180' PERFORA llON SLMMð.RY RB= LOG: ANGLEAT TOP PERF: 97 @ 12377' /lbte: Refer to R"oductbn œ for historical perf data SIZE SPF INTERVAL 0 ISqz DATE 2-7/8" 4 12377 - 12597 0 09199 4-1/2" LNR, 12.6#, L-BO, 0.0152 bpf, 10 = 3.~8" 12687' 12599' e.~;sh it $ QA,TE REV BY (X)M\¡ßITS QA,lE REV BY COMWENTS PRLDI-OE BA Y LNrr 05/12/90 ORGlNAL (X)fl.R.EllON WB.L: S-24A 09,U7/99 SIDETRACK COMRETION PERMIT No: 198-2450 03/14/01 SIS- M-I COIWERTIÐ TO CAIW AS AA No: 50-029-22044-01 03/15/01 SIS-M:> FINAL SEe 35, T12N. T12E 03,U2/02 R/'¥TP CORRB::TIONS BP Exploratbn (Alaska) · "TREE = , WB.LHE'AD = ACTUATOR = KB. B.EV = BF. B.EV = KOP= Max Angle = Datum MD = Datum TVD = 4-1/8" CIVV McEVOY AXB.SON 64.77' 35.43' 2782' 97 @ 12411' 10430' 8800' SS e S~AFf .OTES: 9_518" CSG CUT, PULLED & MILLED :'U'ACE TO STUB @ 2739' HORIZONTAL LNR Proposed CTD Sidetrack 70o@ 0383' AND90o@ 11758' 8-248 . 2195' -14-1/2" HES SSSV NIP, ID = 3.813" I 13-3/8" CSG, 68#, N-80, D = 12.415" 2669' Minimum ID = 3.725" @ 9996" 4-112'" XN NIPPLE (milled to 3.8") 9952' 7" BAKER S-3 A<R. D = 3.875" TOP OF 4-1/2" LNR 4-112" TBG, 12.6#, L-80, 0.0152 bpf, D = 3.958" 9941' 9975' 9996" H4-1/2" X NIP, D = 3.813"1 4-1/2" x NIP, D = 3.813" -14-1/2" XN NP, D = 3.725" I OLD 9-5/8" CSG B.M:> TT LOGGED 09/24/99 4-1/2" WILEG, ID = 4.00" 17" L~ 26#,l-80 MOD, 0.0383 bpf, D = 6.276" H 10180' I PERFORA TION SUMMARY REF LOG: ANGLE AT TOP PERF: 97 @ 12377' Note: Refer to A"oduction DB for historical perf data SIZE SPF MERV AL Opn/Sqz DATE 2-718" 4 12377 - 12597 isolated proposed 12599' 1268T 11100' HTOP of 3-3/16" Liner 11110' -J3-1/2" X NIP, ID = 3.813" I PrOfOSeJ. 3-3/16 x 2-7/8 X-over 3-3116" X 2-7/8" cnt'ed and perfed DATE 05112190 09107/99 03114101 03115101 03102/02 SIS-M-I SIS-M:> RNITP COMMENTS ORGIllAL COMPlETION SIDETRACK COMPLETION CONVERTED TO CANVAS FIlIAL CORRECTIONS DATE REV BY COMMENTS PRUDHOE BAY UNIT WB.L: S-24A PERMIT No: 198-2450 API No: 50-029-22044-01 SEe 35, T12N, T12E BP Exploration (Alaska) REV BY BP Amoco waLMftI......... -.... - ~:t&l: =.u ......::: Mota ...". v--= '= = ~ It....· .... .... ...., REFERENCE INFORMATION CO-GnInOIe,~ _: _ C«mt: $024. TNO_ VOltk:ol(TVQ __: : _ Soo L_ _ (Vs -...co: ~4 (O.OOII.O.OOE) _ _: $o24A 83.77 C__: _eur.an --- e. _ .. All ftIIi .... ................. .... 'hftM I :=: ~ == :::u: ==:::: 1: t: == iæ! e Ii !!fI !EiHI!S 1m IE! ==u=:: =.:: :I::ft=:l :tI.=:: II : ~=:tJ It: === == == == :t:: tit: III .. ...."....0 ..... ...... .....,. ....... ..... ..... "'& U ............... ....7. ..... ........ ....... ........,.,.. AzImuths 10 True North PIon: Pion N (S-2011Pt_ $0248) MIgnetIc North: 25.41· C_od By: ~ p_ Dllo: 91212003 S~~~ Contact Information Öiix;;¡¡,;;~.85· Dirac! (907) 267-6613 Date: 912/2003 E·maM: b<lj.potniS@inteq.com Model: bggm2OO3 INTEO: (907) 267-ð600 T l U!_ m -PlMN ObP e e Baker Hughes ¡ I l2/f'l r· .1+î" I· I I I ' I : I : ' ¡ If·-¡/.t...--.j_.~.- :~\.,...t-.:.. I ; f ;"-1 ..! ¡··_J1__'·I. "+"--'~-"--' ~'r~-I-~~ .-.l,-.J¡__I.'ï¡:···+-·-l¡'-·r·j.· : i',: ' I 1 ¡ !' f:'¡:": .. ¡::!: :~:J:'::II':~ ;~~r~"f: .tf·::.:¡t..-·t::: ¡":'!"'j "':¡::T"'! . .., ,...J n\ -- ...... . .. .. 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INTI!.Q Company: BP Amoco Date: 91212003 Time: 15:21:23 Page: I FIeld: Prudhoe Bay Co-ordlaate(NE) Referenee: Well: 5-24, True North Site: PB S Pad Vertleal (fVD) Reference: System: Mean Sea Level Well: 5-24 SectIon (VS) Reference: Well (0.OON,O.ooE,310.ooAzi) Wellpatb: Plan#4 5-24B Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre S15 Datum: Mean Sea Level Geomagnetic Model: bggm2oo3 Site: PB S Pad TR-12-12 UNITED STATES: North Slope Site Positloa: Northing: 5980854.54 ft Latitude: 70 21 23.002 N From: Map Eastlng: 617919.92 ft Longitude: 149 2 32.343 W Position Uncertainty: 0.00 ft North Reference: True Grouad Level: 0.00 ft Grid Convergenee: 0.90 deg Well: 5-24 Slot Name: 24 5-24 Well PosIdoa: +NI-S -1019.86 ft Northing: 5979855.00 ft Latitude: 70 21 12.971 N +FJ-W 1277.29 ft Eastlng : 619213.00 ft Loøgltucle: 149 1 55.009 W Position Uncertalaty: 0.00 ft Wellpath: Plan#4 5-24B Drilled From: 5-24A 500292204402 TIe-on Depth: 12643.81 ft Curreat Datum: 5-24A Height 63.77 ft Above System Datum: Mean Sea Level Magnetic: Data: 91212003 Declination: 25.41 deg FIeld Strength: 57558 nT Mag Dip Angle: 80.85 deg Vertical SectIon: Depth From (fVD) +N/-S +FJ-W Direction ft ft ft deg 28.27 0.00 0.00 310.00 Targets Map Map <- Latitude --> <-- Longitude -> Name DescrIption TVD +N/-S +Fl-W Northing Eastlng Beg Mia See Beg Mia See Dip. Dlr. ft ft ft ft ft 5-24B PoIyg0n4.1 0.00 4280.92 -4965.93 5984056.01 614180.00 70 21 55.057 N 149 4 20.243 W -Polygon 1 0.00 4280.92 -4965.93 5984056.01 614180.00 70 21 55.057 N 149 4 20.243 W -Polygon 2 0.00 4376.27 -5740.58 5984139.01 613404.00 70 21 55.990 N 149 442.900 W -Polygon 3 0.00 5380.02 -5837.63 5985141.01 613291.00 70 22 5.861 N 149 445.762 W -Polygon 4 0.00 5302.83 -6140.92 5985059.01 612989.00 70 22 5.099 N 149 4 54.631 W -Polygon 5 0.00 5059.33 -5986.76 5984818.01 613147.00 70 22 2.706 N 149 450.116 W -Polygon 6 0.00 4230.30 ~.96 5983988.01 613088.00 70 21 54.552 N 149 4 52.209 W -Polygon 7 0.00 4057.17 -5738.65 5983820.01 613411.00 70 21 52.851 N 149 4 42.837 W -Polygon 8 0.00 4160.98 -5410.93 5983929.01 613737.00 70 21 53.875 N 149 4 33.255 W -Polygon 9 0.00 4144.10 -4979.11 5983919.01 614169.00 70 21 53.712 N 149 4 20.626 W 5-24B T4.1 8854.00 4218.53 -5004.93 5983993.01 614142.00 70 21 54.444 N 149 421.382 W S-24B T4.5 8862.00 5042.63 -5943.02 5984802.01 613191.00 70 22 2.542 N 149 4 48.836 W 5-248 T4.3 8885.00 4413.30 -5805.00 5984175.01 613339.00 70 21 56.353 N 149 4 44.785 W 5-24B T4.2 8920.00 4266.14 -5608.30 5984031.01 613538.00 70 21 54.908 N 149 4 39.029 W 5-24B T4.4 8920.00 4663.49 -5939.05 5984423.01 613201.00 70 21 58.813 N 149 4 48.712 W Annotation MD TVD ft ft 12643.81 8859.74 TIP 12687.00 8855.58 KOP 12737.00 8853.81 3 12997.00 8886.03 4 13322.00 8920.72 5 13422.00 8908.15 6 ObP BP-GDB Baker Hughes INTEQ Planning Report e e ... ...... INTRQ Compaay: BP Amoco Date: 9/2/2003 TIme: 15:21:23 Pap: 2 FIeld: PNdhoe Bay Co-ord....te(NE) Reference: Well: 5-24. True North Site: PB S Pad Vertical (TVD) Reference: System: Mean Sea Level WeD: 5-24 SectIoa (VS) Refereace: Well (0.OON.0.00E.310.00Azi) WeDpada: PIan#4 5-248 Survey Calculatloll Method: Minimum Curvature Db: Oracle Annotation MD TVD It It 13572.00 8887.91 7 13697.82 8901.04 8 13861.17 8920.50 9 14061.17 8899.58 10 14250.00 8862.22 TD Plan: Plan #4 Date Composed: 912/2003 Identical to Lamar's Plan #4 Venlon: 2 Prinelpal: Yes TIecI-to: From: Definitive Path Plan Section Information MD lad AzIm TVD +NJ-8 +FJ-W DLS BaUd TvD TFO Tar¡et It deg deg It It It degl1ÐOft deg/100ft deg/100ft deg 12643.81 95.53 288.54 8859.74 4199.94 -4953.66 0.00 0.00 0.00 0.00 12687.00 95.53 288.54 8855.58 4213.61 -4994.42 0.00 0.00 0.00 0.00 12737.00 88.53 288.54 8853.81 4229.49 -5041.76 14.00 -14.00 0.00 180.00 12997.00 77.66 253.48 8886.03 4234.90 -5295.32 14.00 -4.18 -13.48 251.00 13322.00 90.67 297.42 8920.72 4266.27 -5608.37 14.00 4.00 13.52 76.60 13422.00 103.80 302.31 8908.15 4315.50 -5694.21 14.00 13.14 4.89 20.00 13572.00 91.61 319.60 8887.91 4412.61 -5805.61 14.00 -8.13 11.53 124.00 13697.82 76.40 328.56 8901.04 4513.46 -5878.84 14.00 -12.09 7.12 150.00 13861.17 90.00 347.12 8920.50 4662.80 -5939.26 14.00 8.33 11.36 55.00 14061.17 101.83 12.68 8899.58 4859.70 -5940.08 14.00 5.92 12.78 64.10 14250.00 100.58 345.75 8862.22 5043.08 -5942.69 14.00 -0.66 -14.26 270.00 Survey MD Ind ADm Sys TVD NIS EIW MapN MapE VS DLS TFO Tool It deg deg It It ft ft ft ft deg/100ft deg 12643.81 95.53 288.54 8859.74 4199.94 -4953.66 5983975.24 614193.56 6494.40 0.00 0.00 TIP 12650.00 95.53 288.54 8859.15 4201.90 -4959.50 5983977.11 614187.69 6500.13 0.00 0.00 MWD 12675.00 95.53 288.54 8856.74 4209.82 -4983.09 5983984.64 614163.97 6523.29 0.00 0.00 MWD 12687.00 95.53 288.54 8855.58 4213.61 -4994.42 5983988.26 614152.59 6534.40 0.00 0.00 KOP 12700.00 93.71 288.54 8854.53 4217.73 -5006.70 5983992.18 614140.24 6546.46 14.00 180.00 MWD 12725.00 90.21 288.54 8853.68 4225.68 -5030.39 5983999.75 614116.44 6569.71 14.00 180.00 MWD 12737.00 88.53 288.54 8853.81 4229.49 -5041.76 5984003.38 614105.00 6580.88 14.00 180.00 3 12750.00 87.94 288.82 8854.21 4233.44 -5054.14 5984007.13 614092.56 6592.90 14.00 251.00 MWD 12775.00 86.81 283.50 8855.36 4239.97 -5078.24 5984013.27 614068.36 6615.56 14.00 251.05 MWD 12800.00 85.68 280.18 8857.00 4245.09 -5102.66 5984018.00 614043.88 6637.55 14.00 251.21 MWD 12825.00 84.58 276.85 8859.12 4248.77 -5127.29 5984021.30 614019.19 6658.79 14.00 251.42 MWD 12850.00 83.49 273.50 8861.72 4251.02 -5152.05 5984023.15 613994.40 6679.20 14.00 251.71 MWD 12875.00 82.42 270.14 8864.78 4251.81 -5176.84 5984023.54 613969.60 6698.70 14.00 252.05 MWD 12900.00 81.38 266.77 8868.31 4251.14 -5201.58 5984022.48 613944.88 6717.22 14.00 252.47 MWD 12925.00 80.37 263.38 8872.27 4249.02 -5226.17 5984019.97 613920.33 6734.70 14.00 252.94 MWD 12950.00 79.39 259.96 8876.67 4245.46 -5250.51 5984016.02 613896.04 6751.06 14.00 253.48 MWD 12975.00 78.45 256.53 8881.47 4240.46 -5274.53 5984010.65 613872.11 6766.24 14.00 254.08 MWD 12992.16 77.83 254.16 8885.00 . 4236.21 -5290.77 5984006.14 613855.94 6775.95 14.00 254.74 5-24B T 12997.00 77.66 253.48 8886.03 4234.90 -5295.32 5984004.75 613851.42 6778.59 14.00 255.23 4 13000.00 77. 75 253.90 8886.67 4234.07 -5298.13 5984003.88 613848.62 6780.21 14.00 76.60 MWD 13025.00 78.59 257.37 8891.79 4228.01 -5321.83 5983997.44 613825.02 6794.47 14.00 76.51 MWD 13050.00 79.47 260.83 8896.55 4223.37 -5345.93 5983992.42 613801.00 6809.95 14.00 75.80 MWD 13075.00 80.39 264.26 8900.92 4220.17 -5370.33 5983988.84 613776.65 6826.59 14.00 75.14 MWD 13100.00 81.33 267.67 8904.90 4218.44 -5394.95 5983986.71 613752.07 6844.33 14.00 74.54 MWD 13125.00 82.31 271.06 8908.45 4218.16 -5419.69 5983986.04 613727.34 6863.11 14.00 74.00 MWD 13150.00 83.32 274.44 8911.58 4219.36 -5444.46 5983986.84 613702.55 6882.85 14.00 73.52 MWD 13175.00 84.35 277.81 8914.27 4222.01 -5469.17 5983989.10 613677.81 6903.48 14.00 73.09 MWD 13200.00 85.40 281.16 8916.50 4226.11 -5493.72 5983992.81 613653.19 6924.93 14.00 72.73 MWD 13225.00 86.46 284.50 8918.28 4231.65 -5518.03 5983997.96 613628.80 6947.11 14.00 72.43 MWD ObP e BP-GDB e Baker Hughes INTEQ Planning Report 8.. ..... INTRQ Compaay: BP Amoco Date: 912/2003 Time: 15:21:23 Page: 3 FIeld: Prudhoe Bay Co-ordlaate(NE) Reference: Well: $-24. True North Site: PB S Pad Vertical (fVD) Reference: System: Mean Sea Level Well: $-24 SeetIoa (VS) Reference: Well (0.OON,O.ooE.310.00Azi) Wellpatb: Plan#4 8-24B Survey Cakulation Method: Minimum Curvature Db: Oracle Survey MD lad ADm Sys TVD NIS FJW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft degl100ft deg 13250.00 87.53 287.84 8919.59 4238.60 -5542.01 5984004.53 613604.72 6969.95 14.00 72.20 MWD 13275.00 88.62 291.17 8920.43 4246.94 -5565.56 5984012.49 613581.04 6993.35 14.00 72.02 MWD 13300.00 89.71 294.50 8920.79 4256.64 -5588.59 5984021.82 613557.86 7017.23 14.00 71.91 MWD 13322.00 90.67 297.42 8920.72 4266.27 -5608.37 5984031.14 613537.93 7038.57 14.00 71.86 5 13325.00 91.06 297.57 8920.68 4267.66 -5611.03 5984032.48 613535.25 7041.49 14.00 20.00 MWD 13350.00 94.35 298.77 8919.50 4279.44 -5633.04 5984043.91 613513.05 7065.93 14.00 20.00 MWD 13375.00 97.64 299.98 8916.89 4291.63 -5654.71 5984055.76 613491.20 7090.36 14.00 20.06 MWD 13400.00 100.92 301.21 8912.86 4304.19 -5675.94 5984067.97 613469.77 7114.70 14.00 20.19 MWD 13422.00 103.80 302.31 8908.15 4315.50 -5694.21 5984078.98 613451.32 7135.97 14.00 20.38 6 13425.00 103.57 302.67 8907.44 4317.06 -5696.67 5984080.51 613448.84 7138.86 14.00 124.00 MWD 13450.00 101.59 305.63 8901.99 4330.76 -5716.86 5984093.88 613428.44 7163.13 14.00 124.08 MWD 13475.00 99.58 308.54 8897.40 4345.57 -5736.46 5984108.39 613408.61 7187.66 14.00 124.73 MWD 13500.00 97.55 311.43 8893.67 4361.46 -5755.40 5984123.97 613389.42 7212.38 14.00 125.27 MWD 13525.00 95.50 314.28 8890.83 4378.35 -5773.60 5984140.56 613370.95 7237.18 14.00 125.69 MWD 13550.00 93.44 317.12 8888.88 4396.19 -5791.01 5984158.12 613353.27 7261.98 14.00 126.02 MWD 13572.00 91.61 319.60 8887.91 4412.61 -5805.61 5984174.3~ 613338.41 7283.72 14.00 126.24 7 13575.00 91.25 319.81 8887.84 4414.90 -5807.55 5984176.56 613336.43 7286.68 14.00 150.00 MWD 13600.00 88.22 321.56 8887.95 4434.23 -5823.38 5984195.64 613320.29 7311.24 14.00 150.01 MWD 13625.00 85.19 323.32 8889.39 4454.02 -5838.60 5984215.18 613304.76 7335.61 14.00 150.00 MWD 13650.00 82.16 325.09 8892.15 4474.17 -5853.13 5984235.09 613289.91 7359.70 14.00 149.90 MWD 13675.00 79.15 326.88 8896.21 4494.61 -5866.93 5984255.31 613275.79 7383.41 14.00 149.70 MWD 13697.82 76.40 328.56 8901.04 4513.46 -5878.84 5984273.97 613263.59 7404.65 14.00 149.41 8 13700.00 76.58 328.81 8901.55 4515.27 -5879.94 5984275.76 613262.46 7406.66 14.00 55.00 MWD 13725.00 78.60 331.74 8906.92 4536.47 -5892.04 5984296.77 613250.02 7429.56 14.00 54.94 MWD 13750.00 80.66 334.62 8911.42 4558.42 -5903.14 5984318.53 613238.58 7452.16 14.00 54.31 MWD 13775.00 82.74 337.46 8915.03 4581.02 -5913.18 5984340.97 613228.18 7474.38 14.00 53.79 MWD 13800.00 84.83 340.28 8917.74 4604.20 -5922.14 5984364.00 613218.86 7496.14 14.00 53.38 MWD 13825.00 86.94 343.08 8919.54 4627.87 -5929.97 5984387.54 613210.65 7517.36 14.00 53.08 MWD 13850.00 89.05 345.87 8920.41 4651.94 -5936.65 5984411.50 613203.58 7537.95 14.00 52.88 MWD 13861.17 90.00 347.12 8920.50 4662.80 -5939.26 5984422.32 613200.80 7546.93 14.00 52.78 9 13875.00 90.85 348.86 8920.40 4676.32 -5942.14 5984435.79 613197.71 7557.83 14.00 64.10 MWD 13900.00 92.37 352.01 8919.70 4700.96 -5946.29 5984460.36 613193.17 7576.84 14.00 64.11 MWD 13925.00 93.89 355.17 8918.33 4725.77 -5949.08 5984485.11 613189.98 7594.92 14.00 64.20 MWD 13950.00 95.40 358.34 8916.31 4750.64 -5950.49 5984509.96 613188.18 7611.99 14.00 64.37 MWD 13975.00 96.89 1.53 8913.63 4775.49 -5950.52 5984534.81 613187.75 7627.99 14.00 64.63 MWD 14000.00 98.36 4.73 8910.32 4800.23 -5949.17 5984559.56 613188.71 7642.85 14.00 64.97 MWD 14025.00 99.80 7.96 8906.37 4824.76 -5946.44 5984584.13 613191.05 7656.53 14.00 65.40 MWD 14050.00 101.21 11.22 8901.81 4849.00 -5942.35 5984608.42 613194.75 7668.98 14.00 65.91 MWD 14061.17 101.83 12.68 8899.58 4859.70 -5940.08 5984619.17 613196.85 7674.12 14.00 66.50 10 14075.00 101.83 10.70 8896.74 4872.96 -5937.34 5984632.46 613199.38 7680.54 14.00 270.00 MWD 14100.00 101.78 7.13 8891.63 4897.13 -5933.55 5984656.69 613202.78 7693.18 14.00 269.59 MWD 14125.00 101.69 3.55 8886.54 4921.50 -5931.27 5984681.09 613204.67 7707.09 14.00 266.86 MWD 14150.00 101.55 359.98 8881.51 4945.97 -5930,51 5984705.56 613205.04 7722.24 14.00 268.14 MWD 14175.00 101.37 356.42 8876.54 4970.45 -5931.28 5984730.03 613203.88 7738.57 14.00 267.42 MWD 14200.00 101.15 352.86 8871.85 4994.86 -5933.57 5984754.40 613201.20 7756.02 14.00 266.71 MWD 14225.00 100.89 349.30 8866.87 5019.10 -5937.38 5984778.57 613197.01 7774.51 14.00 266.01 MWD 14250.00 100.58 345.75 8862.22 5043.08 -5942.69 5984802.46 613191.33 7793.99 14.00 265.33 TO ObP e BP-GDB Anticollision Report e BíiW ..... INTHQ Company: BP Amoco Date: 91212003 Time: 15:00:28 Page: 1 field: Prudhoe Bay Reference Site: PB S Pad Co-ordlnate(NE) Reference: Well: S-24, True North Reference Well: 5-24 Vertical (fVD) Reference: 5-24A 63.8 Reference Wellpath: Plan#4 S-24B Db: Oracle GLOBAL SCAN APPLIED: All _lIpaths within 200'+ 100/1000 of reference - There ar~ells In th~lan #4 & NOT PLANNED PROOf; It1 Interpolation Method: MD... Stations Interval: 10.00 ft Error Model: ISCWSA Ellipse Depth Range: 12687.00 to 14250.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1622.17 ft Error Suñaee: Ellipse'" Casing Casing Points MD TVD DIameter Hole Size Name ft ft in in 2668.00 2667.85 13.375 17 .500 13318" 10180.00 8721.84 7.000 8.500 r 12687.00 8919.35 4.500 6.000 4 1/2" 14250.00 8925.99 2.875 3.750 2 718" PIa.: Plan #4 Date Composed: 91212003 Identical to Lamar's Plan #4 Version: 2 Prladpal: Yes Tied-to: From: Definitive Path Summary -< Offset WdIpatIa ,.. Reference Offset Ctr-Ctr No-Go Allowable She Well Wellpath MD MD DIstaDce Area Dmatloa Warning ft ft ft ft ft PB S Pad S-03 S-03 Vi 12750.00 11700.00 743.73 411.96 331.77 Pass: Major Risk PB S Pad 5-24 S-24A Vi 12690.00 12690.00 0.01 0.00 0.01 Pass: NOERRORS Site: PB S Pad Well: 5-03 Rule Assigned: Major Risk WeUpath: S-03 Vi Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingIH!Ðlstanee Area Deviation ~ing ft ft ft ft ft ft deg deg in ft ft ft 12687.00 8919.35 11400.00 8402.43 93.93 42.54 335.72 47.18 768.56 353.83 414.73 Pass 12690.64 8919.02 11410.00 8409.76 93.97 42.57 336.35 47.81 766.16 355.86 410.30 Pass 12692.82 8918.83 11420.00 8417.11 94.00 42.60 336.98 48.44 763.86 358.18 405.69 Pass 12695.03 8918.65 11430.00 8424.47 94.03 42.63 337.61 49.07 761.67 360.48 401.19 Pass 12700.00 8918.30 11440.00 8431.85 94.09 42.65 338.25 49.71 759.58 362.23 397.36 Pass 12700.00 8918.30 11450.00 8439.24 94.09 42.69 338.88 50.34 757.58 364.93 392.65 Pass 12700.00 8918.30 11460.00 8446.64 94.09 42.73 339.52 50.98 755.70 367.46 388.24 Pass 12700.00 8918.30 11470.00 8454.06 94.09 42.77 340.17 51.63 753.93 370.12 383.81 Pass 12700.00 8918.30 11480.00 8461.49 94.09 42.80 340.82 52.28 752.29 372.77 379.52 Pass 12708.94 8917.82 11490.00 8468.94 94.21 42.82 341.46 52.92 750.65 373.72 376.93 Pass 12711.38 8917.73 11500.00 8476.40 94.24 42.85 342.10 53.56 749.18 375.88 373.30 Pass 12713.85 8917.64 11510.00 8483.87 94.27 42.88 342.75 54.21 747.82 378.01 369.81 Pass 12716.36 8917.57 11520.00 8491.34 94.31 42.92 343.40 54.86 746.57 380.11 366.46 Pass 12725.00 8917.45 11530.00 8498.82 94.42 42.94 344.06 55.52 745.49 381.16 364.33 Pass 12725.00 8917.45 11540.00 8506.31 94.42 42.97 344.70 56.16 744.44 383.64 360.80 Pass 12725.00 8917.45 11550.00 8513.80 94.42 . 43.01 345.35 56.81 743.52 386.09 357.43 Pass 12725.00 8917.45 11560.00 8521.30 94.42 43.05 346.00 57.46 742.73 388.50 354.23 Pass 12729.54 8917.46 11570.00 8528.80 94.49 43.08 346.65 58.11 742.06 390.17 351.89 Pass 12732.31 8917.49 _11580.00 8536.31 94.53 43.11 347.30 58.76 741.50 392.09 349.41 Pass 12737.00 8917.58 11590.00 8543.82 94.61 43.15 347.95 59.41 741.05 393.7<¿ 347.36 Pass 12737.00 8917.58 11600.00 8551.34 94.61 43.18 348.60 60.06 740.72 395.97 344.75 Pass 12737.00 8917.58 11610.00 8558.87 94.61 43.22 349.24 60.70 740.52 398.21 342.31 Pass 12741.60 8917.71 11620.00 8566.41 94.30 43.03 349.30 61.37 740.40 398.84 341.56 Pass 12743.55 8917.77 11630.00 8573.97 94.17 42.97 349.70 62.03 740.41 400.33 340.08 Pass 12745.48 8917.83 11640.00 8581.54 94.05 42.92 350.10 62.69 740.53 401.77 338.76 Pass 12750.00 8917.98 11650.00 8589.12 93.75 42.73 350.18 63.36 740.78 402.27 338.51 Pass 12750.00 8917.98 11660.00 8596.72 93.75 42.76 350.83 64.01 741.11 404.29 336.82 Pass 12750.00 8917.98 11670.00 8604.33 93.75 42.80 351.48 64.67 741.58 406.28 335.30 Pass 12750.00 8917.98 11680.00 8611.95 93.75 42.83 352.14 65.32 742.17 408.22 333.95 Pass 4 S-Z/fÂ P¿.,A - ßb/s L'I1~r ce...,t;>~1 lIo/v#44-t '(0% rEI'( ~r;s 1 "I.- ::. /1, 0 0/1 ' c<ZS' Y.I25 - 'Z.~7S ~ 7.~x/. '-f Ilfz~o -1:J3Z~ ~ 1 x !oz.9 , I 7- 'I.- e 0# /332>- IZ6'g7 .: b38 x 'f,ns ... 3./~ ~ "'I, 3~/.' = ~,O /0 Z-, , I ~ iB,S LfÄf 12. GS7- 1/1100 : L- Jl. 151,7 )( $.'$'i -1· , -:::- ,?,S /(>2-5 shoe fv<oc/c.; (;) I '- '3 ~6Y¿' ?~ Xo - ~ 2~.7 ßbl.~ , 111°0 , ~ 1"2S , /Zb87 2.% (~ , 11Z50 - - 3Y~/ - -- - lo"oo~ - 7 'I , r'2 371 - n)9 7 If ff> ðH e rrlvn. 4bl"l$ t>f $- 2 'fA ! ~ ~ 1M t ", ó ó z z w W IL ..J ~ ¡¡: t¡j CJ Q ::I to w !ci: Q ..J > Q. 0. 0( ..,: 0. W Q f10J c¡ ~7 /63 I- Z a: o 0 w W Q W ..., W 3!: to en CJ ::I 0( Z en to W I IL o I ó Z I- W W :x: en = iC a a z - II: 1&1 1&1 Z - a z 1&1 c.. .c ~~$~ '7IW~ _ e Nordic 2 CTD BOP Detail - CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ - 7" Riser Methanol Injection Otis 7" WLA Quick Connect - 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Flanged Fire Resistant Kelly Hose to Dual Choke Manifold Fire resistant Kelly Hose to Flange by Hammer up 1/4 Tur~ Valve on OS Hardline to StandpipE manifold Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure EJ I Blind/Shear I I 12 3/8 .. Combi PipelSIi~ Kill One check valve or HCR 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE I TOT I Manual over Hydraulic MOJ 9/15/02 2 3/8" X 3 1/2" VBRs 23/8" Combi Pipe/Slip XO Spool as necessary 2 flanged gate valves Full production christmas tree Inner Annulus Outer Annulus I I p055139 e e DATE 8/22/2003 CHECK NO. 055139 DATE INVOICE / CREDIT MEMO DESCRIPTION GRbss VENDOR DISCOUNT NET' 8/22/2003 INV# PR082003B PERMIT TO DRILL EE I- SI~Yß TOTAL ~ HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE:. AK99519-6612 NATIONAL CITY BANK Ashland, Ohio 56-389 412 No. P 05513 9 .CONSOLlDATED COMMEACIAlACCOUNT TO THE ORDER OF: ALASKA OIL & GAS 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 AMOUNT PAY: *******$100.00****** :\:'·~;t~>IlFf.:sg,~ ··.·:;':;f~ gS:~,;,:~:ç~~:';:i;fi III 0 5 5 ¡. ~ Ii III ¡ : 0 La ¡. 2 0 ~ 8 Ii 5 I: 0 ¡. 2 7 8 Ii b III . - TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ~ Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function' of tbe original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for tbe 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). . SPACING The permit is approved subject to full EXCEPTION .' compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to the spacing . exception tbat may occur. DRY DITCH All dry ditch sample sets submitted to tbe SAMPLE Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals througb target zones. Rev: 07/10/02 C\jody\templates WELL PERMIT. CHECKLIST Company BP EXPLORATIONLALASKA) INC Well Name: PRUDHOE BAY UNIT S-24B Program SER Well bore seg D PTD#: 2031630 Field & Pool PRUDHOE BAY PRUDHOE OIL - 640150 Initial ClasslType SER 11WINJ GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal D Administration 1 Pß(mit fee attacheø _Yßs 2 _Leasßnumber _approprißte Yßs 3 _U-"ique well_n_arnß_a[1d oumb_er _Yßs 4 WelllQcatßd in_a_d_efine_dppol Yes 5 WeJIJQcatßd pr_oper _dista[1ce_ from driJling urÜtb_oundalY_ Yßs 6 WeJllQcatßd proper distance_ from Qther wel!s Yßs 7 _S_utficient <lcreag.e_aYaiIßble indrilli09 unjt Yes 8 Ifdßviated, js_weJlbQre platincJuded Yßs 90-perator only affected party _ Yßs 10 _Qpecator has_apprppriate_bond inJorce _ Yßs_ 11 Pß(mit c_a[1 Þe issueø wjthQut co_nservaJion order _Yßs Appr Date 12 Pß(mit ca[1 Þe issued wjthQut ad_minist(atille_a-pprpval Yßs RPC 9/23/2003 13 Can permit be approved before 15-day wait Yes 14 WeJIJQcated within area and_strata _authorized by_l[1jectipo Ordß( # (puUOtl in_ cprnrn_e[1ts) (For Yes AIOj#.3 e 15 _AJI WßlJs_withinJl4JlJile_area_of (eyiß"" idßtltified (Fp( !¡ervjCßw.ellonly) _ _ _Yßs $-03 __ 16 Pre-produ_cec! i[1jeçtor; øur<ltiQnof pre--proøuction les!¡ than 3 months_ (For service well QnJy) NA 17 ACMPJ:ïndjng_ofConsi$te[1cyhas Þee_nj!¡sued_forthis project_ _NA _ _ _ Engineering Appr Date WGA 9/23/2003 Geology Appr RPC Date 9/23/2003 18 _C9[1du.ctor st(ingprQvidßdNA 19 _S_u!:facßca!¡ing protect!¡ all_known USDWsNA 20 _CMTvoladequ_ateto circ_ulateon_cpnd_uc!pr& SUJf~g NA 21 _CMT vol adequateto tie-inlQngstring tosu!:f ~g_NA 22 _CMTwil! coyer_aJl know-"pro_ductiye hQrizons_ Yes 23 _C_asitlg de_sig[1s ac!eQuaJe fpc C,_T" B _& Rerruafcost _Yßs 24 _Mequ<ltetan_kage_oJ re_serye pit Yßs CTDU._ 25 JtaJe-ø(iIL has_a t0c403 fQr <lbandonme_nt beßtl apPJoved Yßs 9/19/03_. 26 Aøequ<ltewellbore !¡eparatjo_npro-pp!¡ed _ _ _ _ _ Yßs _ _ 27 JtdNerter req_uired, does it meet regulations NA $idet(ack. 28 _Dri[litlg fluid_Rrogram schematic_& eq_uiplistadequate_ Yßs Max MW_8, 9. RP9.- 29 _BOPEs,_dj)jhey meet regulation Yßs 30 _BOPE_press raJitlg ap-prop(iate; _test to (put psig in _comments)_ _YßS 31 _CMke_ruanifold complies w/APIRfJ-53 (May 64)_ Yßs 32 WQrk will OCCU( ""ithoutoperatjo-" _shutdown_ Yßs 33 Is presence Qf H2$ gas_ RrQbaÞle _ Yßs 34 MechanicalcPtldJtio[1 p{ wells within AOR yerifiec! (for_selVice wßIJ only) Yßs - e Testto_3500Rsi. MSfJ 3115 psi._ $-03: drlgJec_o(d$ jn_dicateadeq_uate ceruent {or mech<ltlica.1 integrity._ 35 Pß(mit ca[1 Þe issued w/o hydcogen sulfide meas_ures 36 _D_ata_presentec! on Rote-"tial pveJpressure _Zone$_ 37 _Sßismic_a-"alysJs_ of shallow 9aS_ZPtles_ 38 _Sßªbeøconditiotl survey Jif off-shore} 39 _ CQnta_ct namelphonefor_wee~ly progre!¡S_reRorts [e1<ploratolY 9nlYl No_ NA NA NA NA - -- Geologic Commissioner: Date: Engineering Commissioner: Public ð;1 . Commissioner 9./ Date çd---5' DT~ Date 7 ) GJj J e e Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Doô~ILçð . . Sperry-Sun Drilling Services LIS Scan Utility # JJv"1~Î-- $Revision: 3 $ LlsLlb $Revision: 4 $ Thu Jan 22 15:17:39 2004 Reel Header Service name.............LISTPE Date.....................04/0l/22 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNh~OWN Cont.inuati on Number...... 01 Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/01/22 Origin...................STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA S-24B 500292204402 BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 22-JAN-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002762907 S. LATZ SARBER/KOLST MWD RUN 2 MW0002762907 S. LATZ SARBER/KOLST MWD RUN 4 MW0002762907 S. LATZ SARBER/KOLST JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW00027 62 907 S. LATZ SARBER/KOLST # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 35 12N 12E 1633 RECEIVED 1050 63.77 .00 .00 Fi"; 1 r t)r\{\4 ~ :-~-~u :.. ~ i..vv 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 12687.0 pi .. !\"!" r.: Co C ~.... ,,¿~8!\8 \dE (1¡ ~ ns. OmmlØOM! PJitA1«age # WELL CASING RECORD # REMARKS: ~"~~DN\~ . . 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. MWD RUNS 1 AND 4 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (8M). 4. MWD RUNS 2 AND 5 COMPRISED DIRECTIONAL WITH GM; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 5 WAS A MAD PASS OVER THE RUN 4 INTERVAL TO ACQUIRE RESISTIVITY DATA - NO SEPARATE MAD PASS IS PRESENTED. NO SGRC DATA ARE PRESENTED FOR RUN 5 DUE TO POOR DATA QUALITY. SRAT DATA (TOOL RUNNING SPEED) FOR RUN 5 ARE INCLUDED. 5. NO PROGRESS WAS MADE ON RUN 3 DUE TO A PULSER FAILURE. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A GAMMA RAY RUN IN S-24A ON 9/3/99. THESE DATA WERE PROVIDED TO SSDS BY KURT COONEY, SIS, ON 1/7/04. LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1 - 5 REPRESENT WELL S-24B WITH API#: 50-029-22044-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14155'MD/8886'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ SHIFT-DERIVED RESISTIVITY ( SHALLOW SHI FT- DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/22 Maximum Physical Record..65535 File Ty-pe................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 12493.5 12669.5 12669.5 12669.5 12669.5 12669.5 12694.0 STOP DEPTH 14128.0 14127.5 14127.5 14127.5 14127.5 14127.5 14154.5 . . $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 12493.5 12488.0 12508.0 12502.5 12510.0 12505.0 12512.0 12509.0 12521.0 12517.5 12523.5 12520.0 12528.0 12525.0 12530.5 12527.0 12532.0 12528.0 12532.5 12529.0 12543.0 12541. 0 12560.0 12561. 0 12588.0 12588.5 12589.0 12590.0 12600.0 12599.5 12606.5 12607.0 12609.5 12611. 5 12614.5 12616.5 12619.0 12621. 5 12621.0 12623.0 12627.5 12630.0 12631.0 12631. 5 12633.5 12634.5 12638.0 12638.5 14154.5 14155.0 $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 12488.0 12870.5 MWD 2 12870.5 13857.5 MWD 4 13857.5 14155.0 MWD 5 13801. 5 14155.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value......................-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT F'I' 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Uni t. Min Max Mean Nsam Reading Reading DEPT FT 12493.5 14154.5 13324 3323 12493.5 14154.5 ROP MWD FT/H 0.43 757.04 69.6073 2922 12694 14154.5 GR MWD API 21.16 486.93 65.4275 3240 12493.5 14128 RPX MWD OHMM 0.73 2000 17.8774 2917 12669.5 14127.5 RPS MWD OHMM 0.94 2000 30.9466 2917 12669.5 14127.5 . . RPM MWD OHMM 1. 31 2000 37.2966 2917 12669.5 14127.5 RPD MWD OHMM 0.51 2000 113.427 2917 12669.5 14127.5 FET MWD HOUR 0.3 47.62 6.05221 2917 12669.5 14127.5 First Reading For Entire File..........12493.5 Last Reading For Entire File...........14154.5 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/22 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.002 Physical EOF File Header Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/22 Maximum Physical Record..65535 Fil e Type................ LO Previous File Name.......STSLIB.OOI Comment Record FILE HE:ADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 12488.0 12694.5 STOP DEPTH 12842.5 12870.5 # LOG HE:ADE:R DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 07-NOV-03 Insite 4.3 Memory 12865.0 12694.0 12865.0 81. 4 95.5 # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR TOOL NUMBER 93091 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.125 12687.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): F10 Pro 8.70 65.0 9.0 30000 9.6 . . RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 .0 155.5 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. __...............0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .IIN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name DEPT ROP GR Code Offset o 4 8 Channel 1 2 3 Service Order Units FT FT!H API Size 4 4 4 Nsam 1 1 1 Rep 68 68 68 MWD010 MWD010 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12488 12870.5 12679.3 766 12488 12870.5 ROP MWD010 FT!H 1.19 63.42 28.2327 353 12694.5 12870.5 GR MWD010 API 29.96 378.91 99.9898 675 12488 12842.5 First Reading For Entire File..........12488 Last Reading For Entire File...........12870.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04!01!22 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.003 Physical EOF File Header Service name.............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04!01!22 Maximum Physical Record..65535 File Type............... .LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 3 header data for each bit run in separate files. 2 . DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ .5000 START DEPTH 12670.0 12670.0 12670.0 12670.0 12670.0 12843.0 12871.0 STOP DEPTH 13825.0 13825.0 13825.0 13825.0 13825.0 13812.0 13857.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEfu~PERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O . 09-NOV-03 Insite 4.3 Memory 13857.0 12865.0 13857.0 76.7 96.7 TOOL NUMBER 82758 126589 3.750 12687.0 Flo Pro 8.70 65.0 8.5 29000 7.0 .120 .050 .140 .160 69.0 162.0 69.0 69.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 . . ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12670 13857.5 13263.8 2376 12670 13857.5 ROP MWD020 FT/H 0.43 757.04 77.7749 1974 12871 13857.5 GR MWD020 API 21.91 486.93 54.3002 1939 12843 13812 RPX MWD020 OHMM 0.73 2000 21.7193 2311 12670 13825 RPS MWD020 OHMM 0.94 2000 38.1596 2311 12670 13825 RPM MWD020 OHMM 1.31 2000 46.1346 2311 12670 13825 RPD MWD020 OHMM 2.04 2000 142.136 2311 12670 13825 FET MWD020 HOUR 0.3 16.57 2.96305 2311 12670 13825 First Reading For Entire File..........12670 Last Reading For Entire File...........13857.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/01/22 Maximum Physical Record..65535 File Type............... .LO Next File Name...........STSLIB.004 Physical EOF File Header Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1. 0.0 Date of Generation.......04/01/22 Maximum Physical Record..65535 File Type.............. ..LO Previous File Name...... . STSLIB. 003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 13812.5 13858.0 STOP DEPTH 14128.5 14155.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10-NOV-03 Insite 4.3 Memory 14155.0 13857.0 14155.0 88.7 97.3 . # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...... .....Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code TOOL NUMBER 82758 3.750 12687.0 F10 Pro 8.70 65.0 9.0 21 000 8.6 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 .0 173.2 .0 .0 . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13812.5 14155 13983.8 686 13812.5 14155 ROP MWD040 FT/H 1.02 280.53 67.0567 595 13858 14155 GR MWD040 API 21.16 447.1 62.9725 633 13812.5 14128.5 First Reading For Entire Fi1e..........13812.5 Last Reading For Entire File...........14155 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/01/22 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 . Physical EOF File Header Service name..... ........STSLIB.005 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/01/22 Maximum Physical Record..65535 File Type................ 1.0 Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RAT RPD RPM RPS RPX FET $ 5 . header data for each bit run in separate files. 5 .5000 START DEPTH 13801.5 13825.5 13825.5 13825.5 13825.5 13825.5 STOP DEPTH 14155.0 14128.0 14128.0 14128.0 14128.0 14128.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: Il-NOV-03 Insite 4.3 Memory 14155.0 13801.0 14155.0 88.7 97.3 TOOL NUMBER 78012 126589 4.125 12687.0 Flo Pro 8.70 65.0 9.0 21000 8.6 .120 .050 .140 .160 69.0 173.0 69.0 69.0 . . $ # Data Format Specification Record Data Record Type.................. C Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...ü Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 W\T MWD050 FT/H 4 1 68 4 2 RPX MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPM MWD050 OHMM 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 FET MWD050 HOUR 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13801. 5 14155 13978.3 708 13801. 5 14155 RAT MWD050 FT/H 34.42 598.03 575.029 708 13801.5 14155 RPX MWD050 OHMM 1.03 35.16 3.22606 606 13825.5 14128 RPS MWD050 OHMM 1.23 6.71 3.43992 606 13825.5 14128 RPM MWD050 OHMM 1.68 8.25 3.59238 606 13825.5 14128 RPD MWD050 OHMM 0.51 53.66 3.94652 606 13825.5 14128 FET MWD050 HOUR 10.85 47.62 17.8328 606 13825.5 14128 First Read~ng For Entire File..........13801.5 Last Reading For Entire File...........14155 File Trailer Service name.............STSLIB.005 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/01/22 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name.............LISTPE Date.................... .04/01/22 Origin...................STS Tape Name............... . UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date...... ...............04/01/22 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................ UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File . .