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Home My WebLink About188-1597. 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 Z-25 Acid Wash Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 188-159 50-029-21902-00-00 ADL 0028262 11800 Conductor Surface Intermediate Production Liner 9210 80 2611 10950 1072 10759 20" 13-3/8" 9-5/8" 7" 8431 39 - 119 38 - 2649 36 - 10986 10728 - 11800 2000 38 - 118 38 - 2649 36 - 8598 8408 - 9210 11730 2260 4760 5410 10759 5020 6870 7240 7874 - 11508 4-1/2" 12.6# L-80 35 - 107866590 - 8984 Structural 4-1/2" HES TNT Perm Packers (3) 4-1/2" MCX SSSV 7830, 6561 / 8123, 6750 / 10551, 8282 2203, 2203 Date: Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 PRUDHOE BAY 2/2/2026 Current Pools: PRUDHOE OIL, Borealis Oil Proposed Pools: PRUDHOE OIL, Borealis 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: 2026.01.12 12:25:26 - 09'00' Torin Roschinger (4662) 326-023 By Grace Christianson at 2:03 pm, Jan 12, 2026 JJL 1/23/26 TS 1/13/26 CDW 01/12/2026 10-404 DSR-1/22/26 01/23/26 Acid Stimulation Well: Z-25 PTD: 188-159 API: 50-029-21902-00 Well Name:Z-25 Permit to Drill:188-159 Current Status:Operable, WAG API Number:50-029-21902-00 Estimated Start Date:2/2/2026 Estimated Duration:1 day Regulatory Contact:Abbie Barker Service Lines: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:2,849 psi at 6,700 TVDss Maximum Potential Surface Pressure:2,000 psi Min ID:3.813 @ 2,203 MD X-Nipple Max Angle:52 deg @ 9,869 MD Last Tag:10,729 SLM Brief Well Summary: Z-25 is an operable Kuparuk WAGinjector that supports Z-20, Z-100, and Z-113. After swapping to PWI in early 2025, injection rate seemed quite poor, so the decision was made to swap back to MI. It was here that MI had deteriorated as well. An IPROF was ran, SBG pumped, perforations were reshot, and a HPBD was attempted. Nothing seemed to help our injectivity. We recently ran a SBHPS and an overpressured reservoir is not our problem either. The next thing we would like to attempt is a fullbore acid job to hopefully help our injectivity into the Kuparuk. The well is taking 2.2-2.3 MMCFD where it has historically injected 6+ MMCFD at 300 psi lower header pressure. Current Status: Active Operable WAG Injector Objective: Fullbore acid stimulation to improve injectivity in the current Kuparuk perforations. Acid treatment targets: Type Top Bottom Net perf Footage Perforations 7,874 7,890 16 Perforations 7,912 7,9166 Total 22 Procedure DHD 1. TIFL. Fullbore 1. MIRU LRS pump truck and SLB acid transport. a. Ensure a shower trailer is on location and properly functioning prior to opening the well and pumping any fluids. b. Please have SLB test the load water to confirm iron content is <100 ppm and all water is filtered to 5 microns. c. Order out brine between 100 120 deg F. d. No sludge emulsion testing is required. Acid Stimulation Well: Z-25 PTD: 188-159 API: 50-029-21902-00 e. Verify acid strength via titration testing prior to leaving SLB yard. f. Document all test results on load out sheets and have present at the wellsite. g. Ensure wing valve is shut prior to bringing pumps online. May be a good idea to have WPO isolate the flowline via the lateral valve or inlet valve at the manifold as well. 2. Begin job as designed in the schedule below: a. Displace acid down tubing and flush away into perfs. b. Well is an injector so now flowback will be required and acid is fine to be pushed away near wellbore. 3. Pump 5 bbl 50/50 meth/water spear. 4. Swap to pumping 20 bbls of hot diesel. 5. Swap to 1% KCl for fluid pack/pre-flush. 6. Obtain injectivity test w/ 1% KCl working up to max rate on pump truck if pressure will allow. Pump 1x WBV w/ 1% KCl (130 bbls). 7. Swap to 90:10 DAD Acid. Blend and pump the following mixture. a. 50 bbls (2100 gal) of 15% HCL b. 9 gal of corrosion inhibitor c. 40 lbs of iron control d. 11 gal of anti-emulsifier e. 210 gal of xylene f. 32 gal of emulsifier 8. Swap to 1% KCl and pump 130 bbls for overflush displacing acid into formation. Obtain injectivity rate when acid is cleared. 9. Have operations put well on injection immediately. No need for freeze protect. FB HCl Acid Pump Schedule Stage Description Step Fluid Type Volume (bbls) Cum. Volume (bbls) Pump Rate (bpm) WHP Pressure (psi) Comment 50/50 Spear 1 50/50 MEOH/H2O 5 5 Max 2000 See details above Diesel Perf Wash 2 Diesel 20 25 Max 2000 Clean up perfs Fluid pack/Pre- flush/Injectivity Test 3 1% KCl 130 155 Max 2000 Well was on MI Acid Stage 4 90:10 DAD Acid 50 205 Max 2000 See details above Overflush 5 1% KCl 130 335 Max 2000 See details above Displacement / Injectivity Test 6 1% KCl 10 345 Max 2000 See details above Attachments: Current Wellbore Schematic Sundry Change Form Acid Stimulation Well: Z-25 PTD: 188-159 API: 50-029-21902-00 Current Wellbore Schematic: Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Work Over Sundry ProcedureDate: January 12, 2026Subject: Changes to Approved Sundry Procedure for Well Z-25Sundry #: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 ChangeHAK PreparedBy (Initials)HAKApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 Starns, Ted C (OGC) From:Starns, Ted C (OGC) Sent:Tuesday, January 13, 2026 1:25 PM To:'Hunter Gates' Cc:Lau, Jack J (OGC); Wallace, Chris D (OGC); Davies, Stephen F (OGC); Dewhurst, Andrew D (OGC) Subject:RE: [EXTERNAL] PBU Z-25 (PTD 188-159) sundry 326-023 data request Thank you sir. Have a good afternoon Ted From: Hunter Gates <hunter.gates@hilcorp.com> Sent: Tuesday, January 13, 2026 12:20 PM To: Starns, Ted C (OGC) <ted.starns@alaska.gov> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] PBU Z-25 (PTD 188-159) sundry 326-023 data request Good Morning Ted, Attached is a USIT ran after the tubing was pulled for the Kuparuk UHRC in 2019 on the 9-5/8. It shows good bond across the Kuparuk interval. As for OH logs, no luck. We have cased hole GR only across the Kuparuk. Please let me know if there is anything else I can assist with. 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: Starns, Ted C (OGC) <ted.starns@alaska.gov> Sent: Tuesday, January 13, 2026 10:59 AM To: Hunter Gates <hunter.gates@hilcorp.com> Cc: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] PBU Z-25 (PTD 188-159) sundry 326-023 data request 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. 2 Hello Hunter, Im reviewing the acid job sundry for PBU Z-25 and would appreciate your help locating some log data to expedite my review. I see from the well records that the 9 5/8 cementing job had a calculated TOC of 6401 MD (1,471 above top Kuparuk), do have a CBL which evaluates this cement job? We also dont have OH logs across the Kuparuk interval, do you have those? Thanks Ted Ted Starns Petroleum Geologist AOGCC 907-793-1225 (o ce) The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 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: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, January 10, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-25 PRUDHOE BAY UNIT Z-25 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/10/2025 Z-25 50-029-21902-00-00 188-159-0 G SPT 6561 1881590 3280 1785 1799 1792 1791 174 196 197 197 REQVAR P Austin McLeod 11/2/2024 Two year to MAIP. AIO 24C.001. WAG approved. 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 Z-25 Inspection Date: Tubing OA Packer Depth 458 3500 3423 3404IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM241102183544 BBL Pumped:8 BBL Returned:8.6 Friday, January 10, 2025 Page 1 of 1 9 9 9 9 9999 9 9 9 9 99 9 9 9 AIO 24C.001 James B. Regg Digitally signed by James B. Regg Date: 2025.01.10 14:29:40 -09'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/02/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230415 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# END 2-20 50029220480000 190060 4/12/2023 BAKER SPN PBU 01-10 50029201690000 175043 4/15/2023 BAKER SPN PBU 01-13 50029202700000 177059 4/13/2023 BAKER SPN PBU 15-05B 50029207310200 211057 4/24/2023 BAKER RPM PBU 15-09B 50029212010200 212024 4/26/2023 BAKER RPM PBU D-01A 50029200540100 197078 4/15/2023 BAKER SPN PBU D-10 50029203890000 179053 4/17/2023 BAKER SPN PBU E-26B 50029217810200 221084 4/9/2023 BAKER MRPM PBU F-33A 50029226400100 208163 4/20/2023 BAKER SPN PBU J-12 50029204450000 180017 4/17/2022 BAKER SPN PBU J-19 50029216290000 186135 4/18/2023 BAKER SPN PBU N-15 50029206070000 181079 4/20/2023 BAKER SPN PBU R-04 50029203740000 179038 4/21/2023 BAKER SPN PBU R-27 50029215570000 186051 4/22/2023 BAKER SPN PBU Z-25 50029219020000 188159 4/23/2023 BAKER SPN Please include current contact information if different from above. T37696 T37697 T37698 T37699 T37700 T37701 T37702 T37703 T37704 T37705 T37706 T37707 T37708 T37709 T37710PBU Z-25 50029219020000 188159 4/23/2023 BAKER SPN Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.05 11:18:47 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, January 3, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-25 PRUDHOE BAY UNIT Z-25 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/03/2023 Z-25 50-029-21902-00-00 188-159-0 G SPT 6561 1881590 1640 2348 2354 2350 2348 141 211 214 214 OTHER P Adam Earl 11/22/2022 MIT-IA to Max ant.inj, Psi. For AA request 30 MinPretest Initial 15 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 Z-25 Inspection Date: Tubing OA Packer Depth 975 3621 3554 3534IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE221123204318 BBL Pumped:5.8 BBL Returned:7 Tuesday, January 3, 2023 Page 1 of 1 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector Z-25 (PTD #1881590) slow IA re-pressurization Date:Tuesday, November 22, 2022 9:40:04 AM Attachments:image002.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, November 18, 2022 4:55 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-25 (PTD #1881590) slow IA re-pressurization Mr. Wallace, WAG Injector Z-25 (PTD #1881590) has been found to have a slow IA re-pressurization trend after a bleed was performed on 10/19/22. The increasing trend does not appear to be related to thermals effects. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for diagnostics. Plan forward: 1. Fullbore: AOGCC witnessed MIT-IA 2. Well Integrity: Pursue AA application Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Injector Z-25 (PTD #1881590) no evidence of TxIA communication Date:Wednesday, October 5, 2022 10:23:25 AM Attachments:image005.pngimage006.pngimage007.pngimage008.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, September 30, 2022 8:13 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: OPERABLE: Injector Z-25 (PTD #1881590) no evidence of TxIA communication Mr. Wallace, A PPPOT-T was performed on 08/13/22 and passed to 5000 psi. After the IA bleed on 08/09/22, follow up monitors have not indicated the presence of TxIA communication. The well will now be classified back to OPERABLE. Please respond with any question. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 From: PB Wells Integrity Sent: Tuesday, September 6, 2022 11:34 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: UNDER EVALUATION: Injector Z-25 (PTD #1881590) possible TxIA communication- UE clock extension Mr. Wallace, Per our discussion last Friday (9/2), we plan to roll the Under Evaluation clock on Z-25 (PTD #1881590) an additional 28 days to allow more time to monitor the well for possible TxIA repressurization. The IA pressure has stabilized and is not exhibiting increasing trends currently. Please respond with any questions or concerns. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, August 10, 2022 1:59 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-25 (PTD #1881590) possible TxIA communication Mr. Wallace, WAG Injector Z-25 (PTD #1881590) was identified as having an increasing IA pressure trend and an IA bleed was performed on 08/09/22. The bleed started at 860 psi and when the pressure reached 140 psi the returns switched from fluid to gas. The increasing pressure trend and presence of gas in the IA bleed indicate possible TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Well Integrity: Monitor for re-pressurization 3. Fullbore (pending): MIT-IA 4. Well Integrity: Further diagnostics as needed/apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector Z-25 (PTD #1881590) possible TxIA communication- UE clock extension Date:Tuesday, September 6, 2022 3:23:09 PM Attachments:image001.pngimage004.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Tuesday, September 6, 2022 11:34 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> Subject: RE: UNDER EVALUATION: Injector Z-25 (PTD #1881590) possible TxIA communication- UE clock extension Mr. Wallace, Per our discussion last Friday (9/2), we plan to roll the Under Evaluation clock on Z-25 (PTD #1881590) an additional 28 days to allow more time to monitor the well for possible TxIA repressurization. The IA pressure has stabilized and is not exhibiting increasing trends currently. Please respond with any questions or concerns. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, August 10, 2022 1:59 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-25 (PTD #1881590) possible TxIA communication Mr. Wallace, WAG Injector Z-25 (PTD #1881590) was identified as having an increasing IA pressure trend and an IA bleed was performed on 08/09/22. The bleed started at 860 psi and when the pressure reached 140 psi the returns switched from fluid to gas. The increasing pressure trend and presence of gas in the IA bleed indicate possible TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Well Integrity: Monitor for re-pressurization 3. Fullbore (pending): MIT-IA 4. Well Integrity: Further diagnostics as needed/apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UNDER EVALUATION: Injector Z-25 (PTD #1881590) possible TxIA communication Date:Wednesday, August 10, 2022 2:44:48 PM Attachments:image002.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, August 10, 2022 1:59 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: Injector Z-25 (PTD #1881590) possible TxIA communication Mr. Wallace, WAG Injector Z-25 (PTD #1881590) was identified as having an increasing IA pressure trend and an IA bleed was performed on 08/09/22. The bleed started at 860 psi and when the pressure reached 140 psi the returns switched from fluid to gas. The increasing pressure trend and presence of gas in the IA bleed indicate possible TxIA communication. The well will now be classified as UNDER EVALUATION and is on the 28-day clock for further diagnostics. Plan Forward: 1. DHD: PPPOT-T 2. Well Integrity: Monitor for re-pressurization 3. Fullbore (pending): MIT-IA 4. Well Integrity: Further diagnostics as needed/apply for AA Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone numberis listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Permit Number: 188-159-0 Inspection Date: 12/8/2019 1/ Alaska Oil and Gas Conservation Commission To: Jim Regg )� DATE: Tuesday, December 10, 2019 P.I. Supervisor l I Z.1tp/1 II SUBJECT: Mechanical Integrity Tests 15 Min 30 Min 45 Min 60 Min BP Exploration (Alaska) Inc. Z-25 Z-25 FROM: Adam Earl PRUDHOE BAY UNIT Z-25 Petroleum Inspector Tubing 3077 Src: Inspector 3073 Reviewed By: P.I. Supry 1— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Z-25 API Well Number 50-029-21902-00-00 Inspector Name: Adam Earl Permit Number: 188-159-0 Inspection Date: 12/8/2019 1/ Insp Num: mitAGE191208184215 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z-25 'Type Inj c TVD 6561 Tubing 3077 3070 3073 3084 PTD 1881590 Type Test SPT Test psi 3400 - IA 503 3600 - 3549 � 3535 BBL Pumped: 75 ' BBL Returned: 7..1 OA 356 198 - 180 ' 172 Interval OTHER p F P Notes: MIT IA tested as per sundry 319-133 Requires MIT -IA to 3400 Tuesday, December 10, 2019 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 188-159-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg� </ I DATE: Monday, December 9, 2019 P.I. Supervisor T/ SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial BP Exploration (Alaska) Inc. Well Z-25 FROM: Austin McLeod PRUDHOE BAY UNIT Z-25 Petroleum Inspector as6t Src: Inspector Reviewed By: P.I. Supry 19.9p--- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Z-25 API Well Number 50-029-21902-00-00 Inspector Name: Austin McLeod Permit Number: 188-159-0 Inspection Date: 11/30/2019 Insp Num: mi[SAM19113018I237 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well z-zs Type Inj N TVD as6t Tubing 968 976 976 - 976 - PTD 1881590 - Type Test SPT Test psi 3400 IA 442 3588 3541 - 3521 ' BBL Pumped: s BBL Returned: 7.7 OA 43 sz s2 83 - Interval OTHER p/F I P / Notes: Pre-Inj. Post workover. Sundry 319-133. 3400psi target test. Monday, December 9, 2019 Page I of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 6. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed ')01,(1 Abandon 0 Plug Perforations 11 Fracture Stimulate 0 Pull Tubing Q Operations shutdown JJ ❑ Suspend ❑ Perforate 0 Other Stimulate 0 Alter Casing ❑ Cham d. o r0, ❑ Plug for Rednll ❑ Perforate New Pool Q Repair Well 0 Re-enter Susp Well 0 Other: Commingle Pools J Q 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ❑ Exploratory ❑ 5. Permit to Drill Number 188-159 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service Q 6. API Number: 50-029-21902-00-00 7 Property Designation (Lease Number): ADL 028262 8. Well Name and Number: PBU Z-25 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Fieltl/Pools: Cement Evaluation PRUDHOE BAY, PRUDHOE OIL PRUDH DE BAY, BOREALIS OIL 11. Present Well Condition Summary: Total Depth: measured 11800 feet Plugs measured 10759 feet true vertical 9210 feet Junk measured None feet Effective Depth: measured 10759 feet Packer measured 7830, 8123, 10555 feet true vertical 8431 feet Packer true vertical 6561, 6750, 8285 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20" 39-119 39-119 0 0 Surface 2611 13-3/8" 38-2649 38-2649 5020 2260 Intermediate 10950 9-5/8" 36-10986 36-8598 6870 4750 Production Liner 1072 7" 10728 - 11800 8408-9210 7240 5410 Perforation Depth: Measured depth: 7874-11508 feet True vertical depth: 6590-8984 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 34-10766 34-8451 4-1/2" HES TNT Perm Packer 7830 6561 Packers and SSSV (type, measured and 4-1/2" HES TNT Perm Packer 8123 6750 true vertical depth) 4-1/2" HES TNT Perm Packer 10555 8285 4-1/2" HES MCX SSSV 2203 2203 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 7970 525 2550 Subsequent to operation: 0 500 200 14. Attachments: (required per 20 nnc 25.070,25071, &26 283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development 0 Service Q Stratigraphic 0 Copies of Logs and Surveys Run 0 16. Well Status after work: Oil ❑ Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR 0 WINJ ❑ WAG Q GINJ ❑ SUSP 0 SPLUG 0 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-133 Authorized Name: Lastufka, Joseph N Contact Name: Hartley, Josephine Authorized Title: SIM Specialist Contact Email: Josephine. Hartley@bp.com Authorized Signature: Date: 215/ I Contact Phone: +1 9075644570 Form 10-404 Revised 04/2017X1'0//� r �{g.��'�1�,� RBDMS L�DEC 0 6 2019 6ubmit Original Only T/1/0=2500/350/100, Temp=118*. PPPOT-T (PASS), PPPOT-IC (FAIL), Pre pulling unit. PPPOT-T: Stung into test port (500 psi), bled void to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi), bled void to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 1200 psi in 15 min, lost 500 psi in second 15 min (FAIL). LDS torqued to 600 Ib/ft. Re-pressured void to 3500 psi, lost 1200 4/28/2019 psi in 15 min, lost 500 psi in second 15 min. Bled void to 0 psi. T/I/O = 2380/380/60. Temp = 1140. WHPs (UIC). On MI. 5/3/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:30 ***WELL FLOWING ON ARRIVAL*** (rwo) RIG UP SWCP 4521 5/16/2019 ***WSR CONTINUED ON 5/17/19*** 5/17/2019 Road to location, standby with SL for wind. **Job postponed** LRS Released ***WSR CONTINUED FROM 5/16/19*** (rwo) RAN 3.84" NO-GO TO MCX @ 2,081' MD. PULLED 4-1/2" MCX FROM 2,081' MD. 5/17/2019 ***WSR CONTINUED ON 5/18/19*** T/1/0= 2090/280/40. Assist slickline with load and test. Pumped 10 bbls 60/40, followed by 274 bbls of I% kcl down tbg to load. Freeze protect tbg with 20 bbls 60/40 and 30 bbls diesel. Slickline to set plug. Pumped 8.25 bbls DSL down TBG to check plug set. MIT-T completed on following day 5/18/2019 *** WSR continued on 05/19/19*** ***WSR CONTINUED FROM 5/17/19*** (rwo) LRS LOADED TBG w/ 274 bbls 1% KCL, 25 bbls DIESEL. RAN 3.80" G-RING & 4-1/2" BRUSH TO XN-NIP @ 10,759' MD. SET 4-1/2" PXN-PLUG @ 10,759' MD. LRS BEGINS 3,400 psi MIT-T 5/18/2019 ***WSR CONTINUED ON 5/19/19*** ***WELL SHUT !NON ARRIVAL*** (SLB E-LINE TUBING PUNCH AND RCT) INTIAL T/I/O = 950/75/200 PSI RIG UP, PT LUBRICATOR TO 350/3600 PSI RIH W1.56" X 5' TUBING PUNCHER, 4 SPF, 0 DEG PHASE. OAL = 31', CAW = 225 LBS, MAX OD = 1.69". PUNCHER INTERVAL = 8216'- 8221'. CCL TO TOP SHOT = 5.6', CCL STOP DEPTH = 8210.4'. RIH W/ RCT CUTTER. CAL = 33', CAW = 225 LBS, MAX OD = 2.5". CUTTING DEPTH = 8224' CCL TO TOP SHOT= 14', CCL STOP DEPTH =8210'. FINAL T/l/O = 650/300/200 PSI 5/19/2019 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** ***WSR CONTINUED FROM 5/18/19*** (rwo) LRS OBTAINS PASSING 3,400 psi MIT-T. LRS OBTAINS PASSING 3,400 psi CMIT TAX 5/19/2019 ***JOB COMPLETED, WELL LEFT S/I*** Daily Report of Well Operations PBU Z-25 *** WSR continued from 05/18/19***MIT-T PASSED to 3612 psi. Max Applied Pressure=3650 target Pressure=3400. Pressured TBG to 3628 psi with 2.2 bbls of DSL. MIT-T lost 12 psi the 1st 15 minutes and 4 psi in the 2nd 15 minutes for a total of 16 psi during a 30 minute test. (Test started on previous day) U-tube TxIA for CMIT-TxIA. CMIT-TxIA PASSED to 3593/3616 psi. Max Applied Pressure= 3650 psi Target Pressure= 3400 psi. Pressured T/IA to 3617/3637 psi with 10.5 bbls DSL. T/IA lost 16/16 psi in the 1st 15 min and 8/5 psi in the 2nd 15 min for a total of 24/21 psi during a 30 minute test Bled TxIA to 500/0 psi. recovering —10.77 bbls Pumped 2.8 bbls diesel down OA for MIT-OA. Failed to achieve test pressure. See log for details SV/WV/SSV= C MV=O CV's= OTG. Tags hung. DSO/WSL notified of well status. 5/19/2019 1FWHP,s 850/25/215. T/1/0=721/532/165 Temp= S/I (LRS UNIT 42 CMIT-TxIA and CIRC OUT) MIT-TxIA PASSED to 3634/3479 Max applied pressure=3650 psi, Target pressure= 3400 psi. Pressure TxIA to 3634/3479 with 10.5 bbls of 40* F Crude CMIT TxIA lost 26/29 1st 15 min and 17/17 2nd 15 min. for a total loss of 43/46 psi in a 30 min test. bled TxIA to 1500 psi 6 bbls returned. Pumped 862 bbls of fresh water down TBG and up IA taking returns down Z-22 F/L. Further pumped 172 bbls of DSL down IA and up TBG taking returns down Z-25 F/L. U-Tube TxIA for 17 min to ensure TxIA freeze protect. Pumped 7 6/10/2019 1 bbls of 50/50 down Z-22 F/L for freeze protect. Final T/1/0=456/457/41 T/1/0=250/250/0 Set 4" CIW "H" TWC #430. R/D upper tree, R/U Dryhole tree Tag #108. Torqued to API specs. R/U lubricator, PT'd against TWC 300/low..5000/high.. Pass. see "Field Charted Tests" Pulled 4" CIW "H" TWC #430. Installed tree cap with new O-ring. PT'd 500 psi. pass. Installed integrals on IA & OA working sides. Torqued to specs, installed block valves with cap and jewelry on integrals. PT'd 300/low..3500/high.. pass. see "Field Charted Tests" Bled working side OA to 0 psi., monitored, removed blind from non working side OA. Verified VR plug. Installed blind with bleeder plug. PT'd against VR 6/18/2019 plug 300/low..3500/high.. pass. see "Filed Charted Tests". FWP's 250/250/0 see log for T/I/O=N/A/360/150, Temp=S1. Perform LPE-IC, post failed PPPOT-IC (Pre pulling unit.) DHD bled IAP & OAP to 0 psi. Stung into IC test void (200 psi), bled to 0 psi. DHD pressured OAP to 1000 psi, IC test void increased to 100 psi, IAP increased to 38 psi. Monitored for 15 min, OAP decreased to 420 psi, test void unchanged, IAP decreased to 20 psi.. Bled OAP to 0 psi. DHD pressured IAP to 1330 psi, IC test void remained at 0+ psi. Monitored for 15 min, test void unchanged, OAP at 7 psi. 7/27/2019 PPPOT-IC: Pressured test void to 3500 psi, lost 1000 psi in 15 min, lost 150 psi in second T/l/O = SV/320/160. Temp = SI. Assist Cameron (LPE-IC). No AL, wellhouse or flowline. Dry hole tree. IA & OA FL @ surface. Bled IAP to BT from 320 psi to 0 psi (Fluid, 1/2 bbl). OAP decreased 30 psi. Increased OAP w/ gas from 130 psi to 1000 psi. IAP increased 40 psi. Monitored for 30 min. IAP decreased 20 psi, OAP decreased 480 psi. Bled OAP to BT from 520 psi to 0 psi (Gas). Increased IAP w/ gas from 10 psi to 1330 psi. OAP increased 5 psi. Bled IAP to 20 psi. Final WHPs = SV/20/10. 7/27/2019 SV = C. MV = O. IA, OA = OTG. 16:30 INITIAL T/1/0= 10/10/0. PRE CDR-2. RU LUB & PT TO 350/3500. (PASS). PUMMPED UP TUBING TO 20OPSI RD & SET 4" CIWHP-BPV #HP4-1 @ 90" THRU DRY HOLE. RD LUB. REMOVE TEMP #108. INSTALL TEMP #112. TORQ TO API SPECS. PT TO 350/5000. (PASS) PT TOP SIDE MV GATE TO 350/3500 (PASS) PT TOP SIDE SV GATE TO 350/3500 (PASS) RDMO ***JOB COMPLETE*** SEE LOG FOR DETAILS. 10/8/2019 BPV SIGN HUNG ON MV. FINAL T/I/O = BPV/30/0 Daily Report of Well Operations PBU Z-25 TWO = BPV/20/160. Temp = SI. Bleed WHPs (Pre Rig). No Flowlines or wellhouse. Dry hole tree. OA FL @ surface. Bled OAP to BT from 160 psi to 0+ psi in 1 hr (Fluid/gas, 1/2 bbl). Monitored for 30 min. OAP increased 70 psi. Bled OAP from 70 psi to 0+ psi and held open OA bleed for 5 hrs. OAP increased 50 psi in 30 min. Final WHPs = BPV/20/50. 10/19/2019 SV = C. MV = O. IA, OA = OTG. 16:10 TWO = BPV/20/160. Temp = SI. IA FL (Pre RWO). No Wellhouse, flowline or AL. Dryhole tree installed. IA FL @ Near Surface. OA FL @ Surface. The IAP remained unchanged and the OAP increased 110 psi in -5 days. 10/25/2019 SV, MV = C. IA, = OTC. OA casing valve could not be reached. 11:30 North America -ALASKA - BP Page I of 6 Operation Summary Report Common Well Name. Z-25- _ - - AFE No Event Type. WORKOVER (WO) Start Date: 10/26/2019 End Date. H-S4DW00195D-EX-D1-WO- (1,491,129.00) Project: PBU - Site: Z -- — -- - -- Rig Name/No.: CDR -2 Spud Date/time: 2/6/1989 12:00 OOAM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000084 Active datum: KB @91.45usft (above Mean Sea Level) Date From - To I Hrs Task Code NPT Total Depth Phase Description of Operations �.. (hr) _ (usft) 10/26/2019 '20:00 - 21:00 1.00 MOB P PRE PREP TO MOVE '.-INSTALL STOP SILL, JACK UP RIG MODULE, -FINISH SECURING BOP IN CELLAR 'INSTALL JEEPS -HOLD PJSM WITH CREWS FOR MOVE MOB P— PRE IRIG MOVE TO Z-25 -CHECK PRESSURES ON IAAND OA BOTH AT j O PSI AND ALL VALVES ON WELLHEAD ARE ROAD IN FRONT OF TARMAC CAMP. 21:00 - 22:30 1.50 _._CLOSED _ MOB P PRE MOVE RIG OFF 11 -071 P PRE -JACK UP, MOVE PIT MODULE TO CENTER 22:30 - 00:00 10/27/2019 00:00 10:30 10:30 - 16:00 16'00 22:30 22:30 - 00:00 10/28/2019 00:00 - 04:00 04:00 - 06:00 06:00 - 0930 09:30 - 12:00 11:02:32AM **All depths reported in Drillers Depths" OF PAD AND INSTALL JEEPS li '.-INSTALL STOP SILL, JACK UP RIG MODULE, MOVE OFF WELL TO CENTER OF PAD AND 'INSTALL JEEPS 1.50 MOB P— PRE IRIG MOVE TO Z-25 -MOVE RIG FROM DS 11 TO EAST DOCK ROAD IN FRONT OF TARMAC CAMP. 10.50RIGU P PRE RIG MOVE TO Z-25 -MOVE RIG FROM EAST DOCK ROAD IN FRONT OF TARMAC CAMP.TO SPINE ROAD IN FRONT OF CROWS NEST T 5.50 RIGU N PRE STANDBY FOR PRODUCTION PIGGING -._—! OPERATION ACCESS ON W PAD 6.50--T RIGU r P PRE RIG MOVE TO Z -25 -MOVE RIG FROM SPINE ROAD IN FRONT OF _ - CROWS NEST TO Z PAD 1.50 RIGU I P f PRE MOVE RIG OVER Z-25 I -REMOVE JEEPS FROM SUB AND PIT j MODULE j -MOVE DRILLING SUB ONTO MATS AND JOCKEY IN TO POSITION 4 00 r RIGU P iT_ ! PRE MOVE RIG OVER Z-25 -MOVE DRILLINGSUBONTO MATSAND !, 'JOCKEY IN TO POSITION j i. -SPOT DRILLING SUB OVER WELL WITH FOOT. ;WALKING - SPOT PIT MODULE NEXT TO DRILLING SUB AND SET DOWN. "ACCEPT RIGAT 0400 2.00 RIGU P j PRE RIG UP WORK ON RIG UP CHECKLISTS. F I 3 50 BOPSUR P PRE NIPPLE UP BOPS 2.50 T BOPSUR P -. PRE PREPARE TO TEST BOPE ;- BRING XO AND HANDLING EQUIPMENT TO ail RIG FLOOR. !i - GREASE STACKAND CHOKE, I- INSTALL RISER. '- INSTALLMIR BOOT ON RISER AND _ ENERGIZE. -GET IRKS MEASUREMENT -FLUID PACK LINES 11:02:32AM **All depths reported in Drillers Depths" Printed 12/5/2019 11:02:32AM **All depths reported in Drillers Depths" North America -ALASKA - BP Page 2 of 6 Operation Summary Report Common Well Name: Z-25 AFE No Event Type: WORKOVER(WO) Start Date: 10/26/2019 End Date: H-S4DW00195D-EX-DI-WO-(1,491,129.00) _ _ Project: PBU Site: Z Rig Name/No.: CDR-2 Spud Date/Time: 2/6/1989 12:00:OOAM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. �BPUOI: USA00000084 Active datum: KB Q91.45usR (above Mean Sea Level) Date From - To His Task ICode NET Total Depth Phase Description of Operations (hi) (usft) _ 2:00 - 20:00 8.00 BOPSUR P ail PRE 'INITIAL BOPETESTPER BPANDAOGCC STANDARD. TEST WITNESS WAIVED BY ' AOGCC JEFF JONES - PJSM AND REVIEW PRESSURE CROSSCHECK LIST - i-13-5/8" ANNULAR, BLIND, MUDX,4-1/2"x7" VARIABLE. -ANNULAR PREVENTER AND VBRs TESTED WITH 4-1/2" TEST JOINT ANNULARTESTEDTO 25OPSILOW/3500 j PSI HIGH FOR 5 MIN EACH '- RAMS/ VALVES TESTED 250 PSI LOW/ 5000 PSI HIGH FOR 5 MIN EACH - PERFORM ACCUMULATOR DRAWDOWN 3000 PSI START, 18 SEC TO 200 PSI / 43 SEC TO FULL RECHARGE -ALL TEST PASSED 20:00 - 00'.00 4.00 BOPSUR P PRE ROCK OUT DIESEL FROM WELL BORE -UD TEST JOINT- -CLEAR FLOOR, PREP TO CIRC OUT DIESEL. -EVACUATE STACK. -VERIFY 0 PSI / FLOW AT IA. ! -SPOTAND HOOK UP DOYON EQUIPMENT. -MAKE UP LANDING JOINT XO. -HOLD PRE SPUD MEETING AND H2S/RIG EVACUATION DRILL WITH RICK ROYS CREW. -PULL HE DART FROM BPV WITH DRY ROD, PULL HE BPV WITH DRY ROD -TEST SURFACE LINES TO 250/3500 PSI j-GOOD -CHECK LINE UPS WITH WSLAND RIG MANAGER -PUMP 45 BBLS HEATED 8 6 PPG 1% KCL BBLS DOWN IA TAKING RETURNS UP TUBING '.. TO TIGER TANKAT4 BPM AT B50 PSI -CHECK LINE UPS WITH WSLAND RIG MANAGER -PUMP 195 BBLS HEATED 8.6 PPG 1% KCL BBLS DOWN TUBING TAKING RETURNS OUT IA TO TIGER TANK AT 4 BPM AT 120 PSI 10/29/2019 0000 - 01:00 1.00 BOPSUR P PRE ROCK OUT DIESEL FROM WELL BORE -PUMP 185 BBLS HEATED 8.4 PPG 1% KCL BRINE DOWN TUBING TAKING RETURNS OUT IATO TIGER TANKAT4 BPMAT 120 PSI -VERIFY O PSI AND ZERO FLOW. -EMPTY TIGER TANK AND SEND DIESEL TO RECYCLE NOTE: BLEED OA PRESSURE FROM 730 PSI 01:00 - 03:00 1 2.00 _,. TO 420 PSI PULL P 8,200.00 DECOMP PULL HANGER -HOLD PRE SPUD MEETING AND H2S/RIG EVACUATION DRILL WITH MICAH BUSHES CREW. - -MAKE UP LANDING JOINT -PULL ROTARY BUSHINGS -MAKE UP LANDING JOINT TO HANGER -MAKE UP TOP DRIVE TO LANDING JOINT. -PULL HANGER OFF SEATAT 123K, P/U WEIGHT 133K Printed 12/5/2019 11:02:32AM **All depths reported in Drillers Depths" Common Well Name. Z-25 Event Type: WORKOVER (WO) North America - ALASKA - BP Operation Summary Report Start Date: 10/26/2019 End Date: Z Page 3 of 6 AFE No H-S4DW00195D-EX-DI-WO- (1.491,129o0) Rig Name/No.: CDR -2 i Spud Date/i1me: 2f6/1989 12:00:00AM Rig Release: Active datum: KB @91.45usft (above Mean Sea Level) Date,From - To Hrs Task I Code NPT Total Depth Phase Description of Operations 103:0 I hr) _ ___ (usft) -PULL 3.50 P 8,200.00 _ �,r DECOMP -CIRCULATE -LINE UP DOWN TUBING TAKING RETURNS THROUGH THE CHOKE TO THE TIGER TANK WITH THE ANNULAR CLOSED -PUMP 40 BBL H2S SCAVENGER PILL AT 5 BPM AT 950 PSI. -PUMP 300 HEATED 8.4 PPG 1% KCL BRINE 5 BPM AT 950 PSI. -SHUT DOWN AND TAKE 290 BBLS OUT OF 'TIGER TANK -PUMP HEATED 8.4 PPG 1% KCL BRINE 5 ''. BPM AT 1000 PSI. UNTIL SCAVENGER PILL RETURNED TO TIGER TANK -SHUT DOWN PUMP AND BLEED PUMP LINE 'OFF -OPEN ANNULAR PREVENTER AND MONITOR WELL, GOOD NO FLOW CHECK I -BLOW DOWN TIGER TANKAND CHOKE TRAILER LINES. 06:30 - 15:00 I 6.50 PULL P 8,200.00 r..---- � DEGOMP ._._. POOH AND LAY DOWN 41/2", L-80, 12.6PPF, RANGE III TCII TUBING F/ 8175' MD T/ 2743' MD ! -BREAKOUT LANDING JOINT FROM TOP 'DRIVE '-BREAKOUT TUBING HANGER, PROTECT FLANGE AND TREE SEALS, SET OFF TO SIDE FOR RE-RUN -BLOWDOWN TOP DRIVE TURN ON HOLE FILLAND OBTAIN BASELINE -PUW 130KAT 8175', LAY DOWN SINGLES TO PIPE SHED WHILE INSTALLING THREAD ''.PROTECTORS -MONITOR HOLE FILL ON TRIP TANK WITH '. PROPER DISPLACEMENT OBSERVED 'STOP THE JOB AFTER RIGGING UP POWER iTONGS *KICK WHILE TRIPPING DRILL WITH CREW j RESPONSE IN 2MINUTES 30 SECONDS FOR WELL TO BE SECURED 15:00 - 1700 2.00 PULL N 8,200.00 DECOMP SWAP POWER TONGS -TONG OPERATOR OBSERVED WELD BROKE ON THE INTEGRAL BACK-UPS OF THE POWER TONGS AND NOTIFIED WSL -INSTALL FOSV IN TUBING STRING -BRING CARRIER TO RIG FLOORAND REMOVE TONGS FROM FLOOR -BRING IN BACKUP TONGS INSTALLAND FUNCTION TEST 'TONG OPERATOR STOPPED THE JOB DUE TO UNEXPECTED EQUIPMENT FAILURE (NOT - - -.. - - LOAD BEARING) Printed 12/5/2019 11:02:32AM `*All depths reported in Drillers Depths" North America - ALASKA- Blo Page 4 of 6 Operation Summary Report Common Well Name. Z-25 AFE No Event Type: WORKOVER(WO) Start Date: 10/26/2019 End Date H-S4DW00195D-EX-DI-WO-(1,491,129.00) �- — Project: PBU Site: Z Rig Name/No.: CDR-2 Spud Date/Time: 2/6/1989 12:00:00AM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. I BPU01: USA00000084 Active datum: KB @91.45usft (above Mean Sea Level) Date From -To - His Task Code NPT Total Depth I Phase Description of Operations (hr) (usft) �— PULL +� 117:00 - 2030 3.50 P 8,200.00 DECOMP POOHAND LAY DOWN 4-1/2", L-80, 12.6PPF, '.! RANGE III TCI! TUBING F/ 2743' MD T/ !SURFACE RECOVERED - 191 JTS OF 4-1/2", L-80, 12.6PPF, RANGE III TCII TUBING '- 1 JT OF 4-1/2", L-80, 12.6PPF, RANGE III TCII TUBING WITH TUBING PUNCHES '1 '-1 CUT JOINT OF 4.5"4-1/2",L-80,12.6PPF, RANGE III TCII TUBING 6.02' TO CUT-NO - 'FLARE AT CUT - XNIPPLE ASSEMBLY WITH 2 TC II PUPS ASSEMBLY LENGTH 40.84' '-CAMERON SSH I3"X4.5"TC II HANGER WITH 4.5" TC II PUP TO BE RE RUN CLEAN RIG FLOOR 1, 20:30 - 21:30 1.00 EVAL P ! 8,200.00 OTHCMP I INSTALL WEAR RING WITH 4 LOCKDOWNS --� - _—,__.UNIN. ,21:30 - 00:00 1 2.50 EVAL P $200.00 1I OTHCMP E LINE OPERATONS -BRING ELINE EQUIPMENT TO RIG FLOOR .-HOLD PJSM WITH CREW -RIG UP ELINE SHEAVES j -MAKE UP ELINE BHA#1 -GAMMA, CCL, 8.3" 1 GAUGE RING, JUNK BASKET -RIH WITH ELINE BHA#1 AT 2300 HOURS 10/30/2019 ' 00:00 - 05:00 'I 5.00 i EVAL P 8,200.00 ! OTHCMP E LINE OPERATONS '- RIH WITH ELINEBHA#1 TAGAT8220'ELMD 1 -POOH AT 0015 1 -LD ELINE BHA# 1 @ 0100 HOURS -MU ELINE BHA#2-CCL, GAMMAAND USIT -RIH WITH ELINE BHA#2 AT 0145 HRS !-PERFORM USIT LOG FROM 8190' ELMD AT 0300 HRS 05.00 - 05:30 0.50 EVAL P 8,200.00 OTHCMP RIG DOWN LOGGING TOOLS -BREAK OUTAND LAY DOWN LOGGING TOOL STRING -REMOVE SHEAVES AND WIRELINE FROM RIG FLOOR - .0530_06:00 0.50- I WHSUR i P 8,200.00 OTHCMP REMOVE WEAR RING } _ _ 06:00 08:00 2.00 WHSUR P 1 8,200.00 OTHCMP RIG UP EQUIPMENT FOR RUNNING 4-1/2" 'COMPLETION 1 -INSTALL PROPER CROSSOVER ON FOSV -RIG UP POWER TONGS -INSPECT, MEASURE AND CONFIRM -', ELEVATORS, HAND SLIPS, AIR SLIPS AND DOG COLLAR -COUNT PIPE IN PIPE SHED, CONFIRMED BY 1 WSL, TOOLPUSHER, DRILLER AND HALIBURTON COMPLETION SPECIALISTS '.. -ARRANGE STACKER PACKER ASSEMBLY IN CORRECT ORDER AND MARK JOINTS FOR JEWELRY -CLEAN ALL CONNECTIONS FOR BAKER-LOK -CONFIRM WITH ODE ON CEMENT VALUATION AND DRAFT TALLY Printed 12/5/2019 11:02:32AM **All depths reported in Drillers Depths** North America - ALASKA - BP Operation Summary Report Common Well Name: Z-25 Event Type: WORKOVER (WO) Start Date: 10/26/2019 End Date: Rig Contractor: N Active datum: KB Date 21:00 10/31/2019 00:00 2/6/1989 AFE No BPUOI: USA00000084 -WO- (1,491,129.00) .45usft (above Mean Sea Level) From - To iIHrs Task Code NPT Total Depth Phase Description of Operations - -�-- (hr) - 21:00 13,00 RUNCOM P 8,238.00 OTHCMP PICK UPAND RIH WITH 4-1/2" RANGE 3,12,6# L-80 VAMTOP STACKER PACKER j COMPLETION ASSEMBLY -CONFIRM SHEAR PINS ON OVERSHOT ASSEMBLYARE AT 4'AND 12'FROM GUIDE SHOE -BAKER-LOKALL CONNECTIONS ON STACKER PACKER ASSEMBLY TO LOWER HALF OF UPPER PACKER '-CONTINUE RIH PICKING UP PIPE AND JEWELRY FROM PIPE SHED AS PER APPROVED TALLY -DRIFT TUBING WITH 3.833" DRIFT WHILE '.. PICKING UP FROM PIPE SKATE ''.-JET LUBE SEAL GUARD USED ON ALL CONNECTIONS THAT WEREN'T ASSEMBLED WITH BAKER-LOK -TORQUE—TURN ALL CONNECTIONS TO 4400 FT/ LBS -PUW=136K, SOW =115K AT 8200'MD -OBSERVE 2K BOBBLE AT 8224' MD (TOP OF STUB) -OBSERVE 5K BOBBLE AT 8228'MD(FIRST . SET OF SHEAR PINS) '-OBSERVE 5K BOBBLE AT 8236 MID (SECOND SET OF SHEAR PINS) -OBSERVE SET DOWN 10K AT 8238' MD (NO GO ON OVERSHOT) - 0000 j 3.00 RUNCOM P 8,238.00 OTHCMP SPACE OUT -LAY DOWN JOINTS 185,184 AND 183 -PICK UP 12.6#, L-80 VAMTOP SPACE OUT JOINTS (9.81', 7.80, 7.80, 3.79') AND RIH -PICK UP JOINT NUMBER 183 AND RIH -INSTALL 15'X OVER PUP TCII BOX X VAMTOP PIN -INSTALL TUBING HANGER AND LANDING JOINT -EVACUATE STACK DOWN TO IA - 01:15 1.25 RUNCOM P ' 8,233.00 OTHCMP LAND COMPLETIONS -LAND TUBING STRING IN 8.4 PPG 1% KCL -FINAL PUW =136K, SOW = 115K WITH 8APPG SEAWATER -RILDS AFTER WELLHEAD REP CONFIRM MARK ON PUP BELOW HANGER THROUGH IA VALVES � I -FINAL DEPTH OF END OF GUIDE SHOE ON �nvvocunr nr c��oo n -LAY Printed 12/5/2019 11:02:32AM "All depths reported in Drillers Depths" 5 Of Common Well Name'. Z-25 Event Type: WORKOVER(WO) Rig Name/No.: CDR -2 Rig Contractor: NABORSALASKA DRILLING IN( Active datum. KB Qa 91.45usft (above Mean Sea Date From- To HIM (hr)_ 61:15 - 0600 4.75 North America - ALASKA- Bld Operation Summary Report Start Date. 10/26/2019 End Date: Spud Daterime: 2/6/1989 AFE No H-S4DW00195D-EX-D1-WO- (1,491,129,00) BPUOI: USA00000084 Task I Code I NPT I Total Depth I Phase Description of Operations 06:00 - 07:30 1.50 WHSUR P I i I I � 0730 - 09:00 ? 1.50 WHSUR P _ (usft) 8,233.0O PST FREEZE PROTECT P_.�i 0900--13:00 i 4.00 WHSUR III _ (usft) 8,233.0O PST FREEZE PROTECT -RIG UP LITTLE RED SERVICES -HOLD PJSM WITH CREWS -PRESSURE TEST LRS TO 3500 PSI -GOOD TEST -PUMP 150 BBLS OF DIESEL DOWN IA TAKING RETURNS THROUGH TUBING HANGER AGAINST CLOSED BLINDS TO RIG CHOKE BACK TO PITS PUMPING AT 4 BPM AT 680 PSI. -SHUT IN IAAND EVACUATE LRS LINES. -FLOW CHECKTUBING SIDE FOR 5 MINUTES STATIC -RIG UP LANDING JOINT WITH PUMP IN SUB AND RIG UP TO U TUBE -U TUBE FROM 0400HRS TO 0500 HRS -CONFIRM NO PRESSURE ON IAANDTUBING -BLOW DOWN U -TUBE LINES TO TIGER TANK -RIG DOWN ALL EQUIPMENT USED FOR FREEZE PROTECT -REMOVE LANDING JOINTAND BREAK OUT SIDE ENTRY SUBAND FOSV —~8,233.00 POST _ INSTALLTWCAND TEST INSTALL"H" TWC WITH DRY ROD (-FILL BOPE STACK WITH WATER TO BLIND RAMS AND TEST TWC TO 3500 PSI FOR 5 MIN. PASS -BLEED OFF PRESSUREAND OPEN BLIND RAMS -BLOW DOWNAND RIG DOWN TESTING 'EQUIPMENT __ i 8,233.00 _ POST EVACUATE ALL SURFACE LINES -FLUSH ALL SURFACE LINES -BLOW DOWN ALL SURFACE LINESAND BLOW DOWN TIGER TANK LINE -EVACUATE FLUIDS FROM BOPE STACK WITH _VACUUM SYSTEM Y 8,233.00 i POST NIPPLE DOWN BOPE STACK -BLEED AIR BOOTS FROM RISER AND PULL RISER FROM STACK -TURN OFF BLEED BOPE ACCUMULATOR -REMOVE ANNULAR PREVENTER FITTINGS AND PLUG ANNULAR PORTS -REMOVE ALL RATCHET BINDERS FROM DOPE STACK '.-CONNECT BOPE SLINGS FROM BLOCKS FOR SECONDARY RETENTION -LIFT ROPE STACK WITH BRIDGE CRANES AND SECURE IN CELLAR _ _ —RELEASE RIG AT 1300 HRS" Printed 12/5/2019 11:02:32AM **Ail depths reported in Drillers Depths"" ***JOB CONTINUED FROM 29 -OCTOBER -2019*** (SLB ELINE JB/USIT) CONTINUE RIH WITH JUNK BASKET. TAG CUT AT 8220'. LOG USIT FROM 8190' TO SURFACE. RIG DOWN ELINE. PROCESS DATA. 10/29/2019 ***JOB COMPLETE ON 30 -OCTOBER -2019*** ***JOB CONTINUED FROM 29 -OCTOBER -2019*** (SLB ELINE JB/USIT) CONTINUE RIH WITH JUNK BASKET. TAG CUT AT 8220'. LOG USIT FROM 8190' TO SURFACE. RIG DOWN ELINE. PROCESS DATA. 10/29/2019 ***JOB COMPLETE ON 30 -OCTOBER -2019*** ***JOB CONTINUED FROM 29 -OCTOBER -2019*** (SLB ELINE JB/USIT) CONTINUE RIH WITH JUNK BASKET. TAG CUT AT 8220'. LOG USIT FROM 8190' TO SURFACE. RIG DOWN ELINE. PROCESS DATA. 10/29/2019 ***JOB COMPLETE ON 30 -OCTOBER -2019*** ***JOB CONTINUED FROM 29 -OCTOBER -2019*** (SLB ELINE JB/USIT) CONTINUE RIH WITH JUNK BASKET/ 8.3" GAUGE RING. TAG CUT AT 8220'. LOG USIT FROM 8190' TO SURFACE. RIG DOWN ELINE. PROCESS DATA. 10/30/2019 ***JOB COMPLETE ON 30 -OCTOBER -2019*** T/I/O=TWC/0/0. Post CDR2. RU THA, torque to API specs 1518 FT LBS. PT'd 5000 psi for 15 min. (PASSED) RU production tree. Torqued to API specs 675 FT/LBS.***JOB IN 10/31/2019 PROGRESS***. Final WHP's TWC/0/0. see log for details. T/I/O=TWC/0/0 **Job in Progress** R/U lubricator, PT'd through lubricator against TWC 300/low..5000/high.. pass. see "Field Charted Tests" attempted to pull TWC. Ran into ice in TWC. Removed tree, thawed out TWC, re -installed tree, Torqued to API specs. R/U lubricator, PT'd through lubricator against TWC 300/low..5000/high.. pass. Pulled 4" CIW "H" TWC. R/D lubricator, installed tree cap with new O-ring, pt'd 500 psi. Removed 11/1/2019 integrals from IA & OA and installed tapped blinds with jewelry. Pt'd 2500 psi... pass. Job ***WELL FOUND S/I ON ARRIVAL*** ASSIST LRS & HES IN SETTING OF PACKER 11/8/2019 ****CONT WSR ON 11-09-19**** T/1/0=35/58/22 Temp=S1 (LRS Unit 46 -Assist Slickline: Circ Well, Set Packer, MIT -T, MIT -IA) Pumped the following down the IA, taking returns up the tubing, to Z -26's Flowline 5 bbls 60/40 Meth spear 150 bbls 140* Diesel 309 bbls 120*F 1 % KCI w/MI Corrosion Inhibitor. Flush line with 1 bbl 60/40. 151 bbls 95* Diesel Freeze Protect U-tube TxIA (PER SSL WSL) 11/8/2019 *** WSR continued on 11/09/19 *** Daily Report of Well Operations PBU Z-25 ****CONT WSR FROM 11-8-19****(post rwo) DROP BALL & ROD LRS & HES SET PACKER PULL B&R FROM 8133' SLM. PULL RK-DGLV FROM STA #2 (5496' MD) & RKP-SHEAR VALVE FROM STA #3 (3104' MD). SET RK-LGLV IN STA#3 (3104' MD) &. RK-OGLV IN STA#2 (5496' MD). PULL 4-1/2" RHC -M FROM X NIPPLE AT 8156' MD. DRIFT W/ 20 x 2-7/8" GUNS (3.16" OD) AND 2.5" LIB TO PX -PLUG @ 10,749' 11/9/2019 SLM/10,759' MD.(no issues getting down) *** WSR continued from 11/08/19*** (LRS Unit 46 - Assist Slickline: Circ Well, Set Packer, MIT -T, MIT -IA) MIT -T PASSED to 3700 Test #2) Max Applied Pressure=3750 Target Pressure=3500 psi Pressured TBG to 3716 psi with 2.6 bbls Diesel MIT -T lost 29 psi in 1st 15 minutes and 18 psi in 2nd 15 minutes for a total 47 psi during a 30 minute test Bled TBG to 1540 psi rovering - 1.2 bbls MIT -IA PASSED to 3785 psi Max Applied Pressure=4000 spi Target Pressure=3615 psi Pressured IA to 3819 psi with 8.2 bbls Diesel. MIT -IA lost 20 psi in 1st 15 minutes and 15 psi in 2nd 15 minutes and for a total loss of 35 psi during a 45 minutes test. Bled T/IA to 0/0 psi rcovering - 9.6 bbls 11/9/2019 SSL in control of well upon LRS departure. CV's=OTG, Tags Hung ***WELL S/1 ON ARRIVAL*** (ELINE PERF/SBHPS) PERFORATE 7,912'- 7 918'W/ 2-7/8" PJO'S 6 SPF 60 DEG PHASE GUN. PERFORATE 7,874' - 7,890'W/ 2-7/8" PJO'S, 6 SPF, 60 DEG PHASE GUN. ALL LOGb UUKRELA I LU 10 SLB CNL DATED 25 -FEB -1989. 11/11/2019 ***JOB CONTINUED ON 12-NOV-2019*** LRS Well Test Unit 1; Post CDT Flowback / Well Test / Rate Verification. Start WSR on 11/12/19. Inlet Well- Z-25, Outlet Well- Z-26. MIRU. Barriers: IL- SSV, Wing, Swab. OL - 11/12/2019 SSV, Wing, Swab. Continue WSR on 11/13/19 ***JOB CONTINUED FROM 11-NOV-2019*** (SLB ELINE SBHPS) PERFORMED SBHPS PER PROGRAM (STATION STOPS @ 8189', 8030', 7877', 7726'). 11/12/2019 ***JOB COMPLETE ON 12-NOV-2019*** LRS Well Test Unit 1; Post CDT Flowback / Well Test / Rate Verification. Continue WSR from 11/12/19. Inlet Well- Z-25, Outlet Well- Z-26. Pressure Test Hard line, Vessel PT, 11/13/2019 Pop flow well. Barriers: IL- Hardline & Vessel, SSV. OL- SSV, OSDV. Continue WSR on LRS Well Test Unit 1; Post CDT Flowback / Well Test / Rate Verification. Continue WSR from 11/13/19. Inlet Well- Z-25, Outlet Well- Z-26. flow well. Barriers: IL- Hardline & 11/14/2019 Vessel, SSV. OL- SSV, OSDV. Continue WSR on 11/15/19. LRS Well Test Unit 1; Post CDT Flowback / Well Test / Rate Verification. Continue WSR from 11/14/19. Inlet Well- Z-25, Outlet Well- Z-26. flow well, Start 12hr Test. Barriers: IL - 11/15/2019 Hardline & Vessel, SSV. OL- SSV, OSDV. Continue WSR on 11/16/19. LRS Well Test Unit 1; Post CDT Flowback / Well Test / Rate Verification. Continue WSR from 11/15/19. Inlet Well- Z-25, Outlet Well- Z-26. flow well, Complete 12hr Test, RDMO 11/16/2019 Barriers: SSV, swab. OL- SSV, Swab. WSR complete on 11/16/19. T/I/0=1280/1400/100, Temp = SI (LRS Unit 46 -Freeze Protect Flowline***FREEZE PROTECT POST WELL TESTING**** Pumped 38 bbls 60/40 down TBG AT 5 BPM for TBG freeze protect Valve positions: SV/C WV/C SSV/C MV/0 IA/O OA/O, DSO informed of well status at 11/17/2019 Ideparture Daily Report of Well Operations PBU Z-25 ***WELL SHUT IN ON ARRIVAL*** (post rig) SET 4-1/2" X-CATCHER AT 7,802' MD PULL STA# 2 OGLV FROM 5,496' MD 11/22/2019 ***CONT. TO 11/23/19 WSR*** T/1/0=1300/1300/20 Temp=Sl Assist SLine w/ IA Load and Test (RWO SUPPORT) 11/23/2019 Pumped 354 bbls of 20* DSL down IA for load. See log for details... WSR continued to ***CONT. FROM 11/22/19 WSR*** PULL LGLV STA# 3 @ 3104' MD SET RK-DGLV STA# 3 @ 3104' MD LRS LOAD IA-T (see Ins log) SET RK-DGLV STA# 2 @ 5496' MD 11/23/2019 ***CONT. TO 11/24/19 WSR*** ***CONT. TO 11/24/19 WSR** (rwo capital) PULL X CATCHER @ 7802' MD SET 4-1/2" MCX (.50" BEAN) SSSV NIP @ 2203' MD 11/24/2019 ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** T/1/0=1666/2744/29 LRS unit 46 WSR continued from 11/23/19 ***Assist SLine w/ IA Load and Test (RWO SUPPORT)*** Monitored IA pressure, IA continued to increase —5 psi per 15 min, Unable to complete MIT-IA due to pressure increase, SL to continue 11/24/2019 bleeding IA to FL, SL in control of well atdeparture AFE sign hung at well FWHPs T/1/0=915/410/45 (LRS unit 76 - MIT-IA) MIT-IA **PASSED** to 2689 psi per WSL Jerry Lau (Target 2500 psi, Max 2750 psi). Pumped 6.1 bbls diesel down IA to reach test pressure. 1st 15 min IA lost 41 psi. 2nd 15 min IA lost 15 psi for a total of 56 psi lost in 30 min. Bled IAP, bled back — 6 bbls. RDMO. Hung caution and info tags on IA/WV. 11/28/2019 Swab/SSV/WV=Shut, IA/OA=OTG. FWHP=930/400/50 T/I/0=968/442/432Temp=Sl MIT IA (AOGCC MIT IA Pre injection) State witness by Austin Mcleoe MIT IA PASSED @ 3521 psi Target 3400 Max applied 3600 Pumped 8.1 bbls of 40* diesel down IA to reach test psi 1st test 1st 15 min IAP lost 47 2nd 15 min IAP lost 20 for a total of 67 psi in 30 min Bleed back —7.7 bbls diesel Wing shut swab shut ssv shut 11/30/2019 1 master open casing valves open to gauges Final Whp's=969/442/44 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax return via courier or sign/scan and email a copy Delivered to: ` -'k Z/AOGCC 'w ( ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 ., Anchorage, AK 99501 BAY WL BAY I WL Date Schlumberger and BP Schlumberger -Private 188159 TRANSMITTALDATE TRANSMITTAL # FINAL FIELD IF30.0ct-19 lqA Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the Package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Tuesday, November 12, 2019 8:59 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ; AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW, AK, OPS WELL PAD W, AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Nottingham, Derek; Peru, Cale; Stechauner, Bernhard Cc: Regg, James B (CED); Fore, Glenn J; AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AMMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector Z-25 (PTD #1881590) passed MITs post RWO All, Wag Injector Z-25 (PTD #1881590) recently had a rig workover on 10/31/19 to reconfigure the injection profile. On 11/09/19 after CDR2 ran the new completion, Slickline and Fullbore set the packers and performed a passing MIT -T to 3,700 psi and passing MIT -IA to 3,784 psi. The passing MITs confirm two competent barriers to formation and the well is now classified as OPERABLE. Prior to putting the well on injection, the plan is for E -line to add perforations and flow the well through a portable test unit to clean the perforation zone. Plan forward: 1. Slickline/Fullbore —Drop Ball and Rod/Set Packers— Done 2. Slickline —Set LGLVs, pull TTP —Done 3. Eline—Add Perforations 4. Portable Well Test Unit —Temporary Flowback 5. Slickline/Fullbore: Set DGLVs, Perform pre injection AOGCC witnessed MIT -IA 6. Operations: Put on Injection 7. DHD: Perform post injection AOGCC witnessed MIT -IA Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, May 20, 2019 12:50 PM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad HUQ AK, OPS Well Pad LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; AK, OPS Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Nottingham, Derek, Peru, Cale Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R, Tempel, Joshua; Worthington, Aras J Subject: NOT OPERABLE: Injector Z-25 (PTD #1881590) tubing cut pre-RWO All, WAG Injector Z-25 (PTD #1881590) is currently being prepared for a Rig Workover. On 05/19/19 E -line performed a tubing cut. The well is now classified as NOT OPERABLE until the RWO is complete and the downhole barriers have been re-established. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization - Alaska Office: 907-659-8110 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission Re: Prudhoe Bay Field, Borealis Oil and Prudhoe Bay Oil Pools, PBU Z-25 Permit to Drill Number: 188-159 Sundry Number: 319-133 Dear Mr. Mclaughlin: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Lie 1. C ielowski Commissioner DATED this 1 (0 day of April, 2019. RBDMSZVJAPR 162019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ®' Re-enter Susp Well ❑ Alter Casing ❑ Other Commingle pools 0 ' 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development p 5. Permit to Drill Number. 188-159 • 3. Address: P.O. Box 198812 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 0• 6. API Number: 50-029-21902-00-00• 7. If perforating: 42 7 0 _3F/li What spacing 8. Well Name and Number: Regulation or Conservation Order governs well in this pool? Will planned perforations require a spacing exception? !9 Yes ❑ No 0 PBU Z-25 9. Property Designation (Lease Number): 10. Field/Pools: y'rccl-�.r�C /) t4- ADL 0028262 PRUDHOE BAY. PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11800 9210 11750 9171 2720 None None Casing Length Size MD TVD Buret Collapse Structural Conductor 80 20" 39-119 39-119 Surface 2611 13-3/8" 38-2649 38-2649 4930 2270 Intermediate 1 10950 9-5/8" 36-10986 36-8598 6870 4760 Production Liner 1071 7" 10729 - 11800 8409-9210 7240 1 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11380- 11508 1 - 8984 4-1/2" 12.6# L-80 35-10786 Packers and SSSV Type: 4-12" HES TNT Penn Packer Packers and SSSV MD (ft) and TVD (ft): 10555 / 8285 4-1/2• HES MCX SSSV 2085/2085 12. Attachments. Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: April 10, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date. GAS ❑ WAG 0 • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name. Browning, Zachary H be deviated from without prior written approval. Contact Email: Zacharv.Bfowningalop.com Authorized Name: Mclaughlin, Sean M Contact Phone. +1 907 584 5220 Authorized Title: Engineering Team Lead - CTD 8 RWO Authorized Signature. Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a re esentative may witness Sundry Number: '1 it /✓1 —/ Plug Integrity ❑ BOP Test Mechanical Integrity Test a Location Clearance ❑ Other: KJRG /k/q Ayc&4o,T1be-55 /19 rT--T�p To 3�%o�si RBDMSIE�� APR 16 2019 Post Initial Injection MIT Req'tl? Yes ❑ No ❑/- Spacing Exception Required? Yes ❑ No C9 Subsequent Form Required: /Q— Y10 y ' APPROVEDBYTHE I� Approved by: COMMISSIONER COMMISSION Date: N ' to I IJ IJ ORIGINAL 4,4227AN�Q/� Submit Form and Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission From: Zach Browning RWO/CTD Engineer Date: March 20, 2019 Z Re: Z-25 Sundry Approval Well Type: Injector Current Status: The well is currently an operable Ivishak injector Request: Sundry approval is requested to recomplete with a straddle packer completion for comingled injection (Borealis Oil Pool, BOP, and Prudhoe Oil Pool, POP). An Area of Review is attached for new Kuparuk injection. Note - A separate application for amendment to Area Injection Orders 22E, 24B and 38 has been submitted for commingling of Injection between two pools. �` �� rs K�c •� Thr,�r� s� J F zi• /� History and current status: Z-25 is a EWE Ivishak WAG injector that was originally drilled in 1989 and last worked over in 2009. It is currently an operable Ivishak injector, but the Kuparuk penetration of Z-25 is in an ideal location for WAG injection to improve sweep, so this is an attractive recomplete candidate. This is already a WAG injector, so no surface piping work is required. Based on nearby analog injectors, boosted water is not needed in this pattern. Injectors Z-114 and Z-103 have sufficient injectivity at un -boosted pressure (1500 psi). The zonal isolation is provided by the 9-5/8" primary cement job, which was 431 bbls class G cement, 1506 sx. volumetric Assuming 40% washout, this puts TOC at -6401' MD. No losses were reported during the job, but plug was not bumped and cement was found -800' high in the casing. The TOC assumes the casing was filled with cement from tthe Ze first tag to the shoe, giving 73 bbls of cement inside casing. This TOC is 1471' MD above TKUP.- A/sa s bv�e f(2Z This well will be brought back into service as a commingled Ivishak/Kuparak Injector. The plan is to retain '{ Ivishak injection as it is high value (supports full-time producers Z-148, Z-24, Z -26A totaling -500 bopd IOR). The well is currently operable and has been online for the majority of 2018 injecting into the current Ivishak perforations. The most current IA test was performed on 10/8/2017 to 2271 psi and witnessed by .3 ZtH AOGCC inspector Lou Laubenstein. Proposed plan: The All American Oilfield 111 pulling unit will recomplete the well with a straddle packer completion across the Kuparuk to allow for co -mingled injection. MASP=2720 psi. AAO 111 BOPE will be configured as follows (BOP schematic attached for reference): • One Annular preventer • One Blind Ram -type preventer • Mud cross with outlets for choke and kill lines • One Ram -type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low for all components. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of both the current and proposed wellbore is attached for reference. Scope of Work: The primary objective of this RWO is to recomplete the tubing with a straddle packer completion. Prior to the new completion being ran, a LIST will be ran to verify annular cement. Pre-Riq (Estimated start 4/10/19): 1. PPPOT-T to 5000 psi. PPPOT-IC to 3500 psi (will likely fail). Function all LDS 2. Isolate Ivishak with retrievable plug in X -nipple at 10,592' 3. CMIT-TxIA to 3400 psi. 4. E -Line cut tbg at approx 8200' 5. Circ in kill -weight fluid (weighted for Ivishak). CMIT-TxIA. 6. Set BPV 7. Pre -rig surface disconnect. Proposed RWO Procedure Estimated start 5/1/19: Q� 1. MIRU. Test BOPE. zy o,. �C. 4� 2. Pull BPV. Pull tubing. 3. Contingency - Replace IC mandrel packoff if needed. p " 4. USIT/CBL from 8150' to surface. 5. Contingent remedial ce ent if insufficien isolation is obs�erve (and contingent re -log after cement cures) — A9041 � A64CC� ✓-- p,spf,'LV +-�_. 6. Run 4-1/2" tubing with 2 lfackers straddled across the Kuparuk. Post ria Work: 1. Circ lightweight fluid into tubing for underbalanced perf. Ensure fluid on backside near packers is hot. Drop B&R. Set packers. zyAr to J4 0 a- q� 2. MIT -IA to a minimum 3400 psi for WAG service +. 3. Pull B&R. Install live GLV s 4. Underbalance perforate Kuparuk` SBHPS, 5. Flowback through pad separator or portable flowback skid for approx 10 days to clean up perfs. 6. Dummy GLV's, set MCX 7. Surface reconnect, lined up for MI 8. POI to MI for Kuparuk-only injection 9. Pull Ivishak isolation and install downhole choke for commingled injection after -2 months of stable Kuparuk injection tach Browning CC: Well File RWO/CTD Engineer Joe Lastufka 564-5220 Dieence to TOP of KUP Oil Pool Top of KUP Oil Pool Top of Cement Top of Cement Top BE Cement Zonal Isolation (Annular Cement OpeeatlBns Well Name Status Z-25 (MO) (NOSS) (MD) )TVOss) Determined By Reservoir Status cementfootage) summary Mechanical integrity PC Shoe Depth BAD) 1506 P, 2424 to it class G= 4585'-S61Yismular 431 bole cement. 1471'-250 BAD annular a No losses, Did not hump 2¢5 cement above TKUP plug, found cement at 10,003' MO. Assuming worst ValumO1104016 PP at 10,551' MD (see case that the 51W —a washout) praposetluhotion.for totally filed with cement= Operable WAG (USITplanned during Inshak parts open for Planned completion) 73 lousiness, f.An,. 358 Passing MIT -IA to 2271 Be Dn Ingather 0 7872 6497 5368'-6401' 482e 5501 swelorer) injection obis pumped=6401'MD. 30/8/37 / 10,986' 7310' annular cement. 113 Operable 3403' MO above TKUP 1650 5,1931 to h dassG Volumetnc(40% IvisM1akperfsopen for =343 holy passing MIT -IA to 3080 psi an Producer 1005' 8M0 6489 503]'MD 4648' washout) production PIP at 12,@1'MO 11/27/15 12347' A cement bond log run BUST) and the lee showed isolation between the Schrader Bluff and Ppmped through ES me Toe swank. but Insufficient cemem bisaid. _ emer By 791W BAD the euparuk from the Sag Rlvec 226 ad, 3% to it Lite Crete Iwlmion between the nuaruk 70.5 hots, and Sae was wNnmed via three 200 re, 1]] or it class G= I-3911 pert depths 1107W' mast, 31,6 hots. and ]011%poet Fbowed no . miearonote and the entire Attempted remddhol cement then Formation packed In. job with perforations al A FIT to 9.a or EMw was '0A... 30,863 and 10,780'. perfmmedwhen ma thea sun edllmem. Unable to inject (]/28/06) Operates Miter perfs open for Passing MIT -IA to 2500 qi on Producer 1129' 6545 6545 4967'(TOL) 4967' OL • 4662' USIT production pp., tge6e'Mo 11/12/14 31,022'(Wmdowat5115) 4]]6' MO annular cement. 1423 so, 20311 our R clan G= 2.]4 3315-MOabove TKUP. a 3136616. Volumetric _ IvisM1aprw=cPen for Passi11/17 1p to 26]9 ps ProducGinnie'e Producer 6D' 7471 6529 5156' QJ8' N0%washout) production pp at 9456' AD No lasses, jumped! plug. oral/11/ll 9932' 1565v,2365mf clenG= 421 bids 5263' MD annular cement. Z36 2131' MD above TKUP. No lone. Did not bump plug, but Found cement only Operable PP at 10,653'MD 2tl above PC (10 hots in Vol—,ho IWslsa4cerh open for aring .share...ck) MFF-IAto3000pY on Producer 786' 7854 6523 SR3' SM3' (40M wasM1auO production 12/12/ II/]3/11 30,9116' UST TDCat 3345 MDA MD Annular cement. z 6 4607' MDabweTKUP. • 595 we 11.5 we LITE CRETE, Operable Ivishok perfs open for and 252 or list class G Passing MIT -IA to 3000 psi to Producer 1015' 7952 6552 3345' 3150' USITIoe production pp .19984. MO 9/24/14 10,280' 'A mile radius from Z-20 and Z-25 .+ oVG4VV OVJGW GU9WV WibW W'll1UV M1b4W TKUP Structure Map ♦ with TKUP Tops Posted Z-]8 Z ssC `z-11 Z24 1 ♦ • zaz rx zn Z� • L41 ♦ _ t' i 1-14 2100 zaa sax z.nt]e] zpgs� z4] z-ro Ln02 6800 597600 598400 599200 r z'� zar 600800_601600 Elevation depth [ftUS] 627500 -630000 632500 ti -635000 -6375.00 -6400.00 6425.00 -645000 6475.00 g 6500 00 6525.00 -655000 6575.00 -660000 M 604n 6048nn 6625.00 -650.00 -6675.00 -]700.00 .672500 -]75000 -6775.00 -6800.00 -6825.00 -685000 -6875.00 -690000 -692500 -695000 -6975.00 -700000 -7025.00 705000 -707500 710000 -712500 715000 1-717500 0 500 1000 1500 2000 25000116 113000 by ti c c g c M 604n 6048nn 6n66nn t AAM 0 500 1000 1500 2000 25000116 113000 by TREE= MCEVOY WELLHEAD= MCEVOY ACTUATOR= OTIS KB. ELEV = 91.45' BF. ELEV = 55.05 KOP= 3201' Max Angle = 52' @ 9975' Datum MD= 11385' Datum TVD = 8800'SS 1 13-3/8" CSG, 68#, L-80, IO = 12.415" 1 Minimum ID = 3.725" @ 10759' 4-1/2" HES XN NIPPLE SAFETY NOTES: H2S READINGS AVERAGE 125 ppWHEN ON MI. WELL REQUIRES Am Z-25 UL -4112" HROMEENIPPLES"'SSSVWHEN ON 2081' 412" HES X NE (9 -CM, 10515' 412" HES X NIP (8-Cl2(, IO = 3.873" TOP OF T' LNR 10728' 4-12" TBG, 12.69, L-80 TCII, 10782' .0152 bpf, ID = 3.958" " CSG. 47#. L-80. ID = 8.681"10986' SIZE 10561' —19-518" X 412" HES TNT PKR, ID = Opn/Sgz 10682' 412" HES X NIP (9 -CFI, ID = 3.81 2-18" 10769' 41/T HES XN NIP (9 -CFI, ID = 3.t S 10782' 4-12" WLEG (9 -CR), ID = 3.958" 10774' ELMD TT LOGGED 04/16189 6 11380 - 11412 PERFORATION SL#VWRY REF LOG- CET ON 03/19/89 ANGLE AT TOP PERF: 41" @ 11380' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2-18" 6 11380-11412 S 0727198 3-38" 6 11380 - 11412 0 08703/11 2-18" 6 11434 - 11440 S 0727/98 2-1 W' 6 11434 - 11448 O 01/03105 2-18" 4 11434 - 11463 0 08/17798 2-1/2" 6 11440 - 11463 O 08/0288 2-1/4" 12 11448-11454 0 01/03/05 2-19' 6 11454 - 11508 O 01703/05 2-18" 6 11460 - 11490 S 072798 2-18" 4 11500 - 11550 S 0727/98 T' LNR, 26#, L-80, 0383 bpf, ID = 11348' H7"MARKER JOINT DATE REV BY COMMENTS DATE I REV BY I COMMENTS 03104/89 DGH ORIGINAL COMPLETION 0123/12 TNWJMJ ADDED H2S SAFETY NOTE 1022#09 D14 RNO 10127/09 SV DRLG HO CORRECTIONS 01/12/10 DB/JMD CRLG DRAFT CORRECTIONS 02/16/11 M3/JMD ADDED SSSV SAFETY NOTE 08/15/11 TM PJC RE -PERF (813(l1) PRUDFIOE BAY UNIT WELL. Z-25 PERMIT ND: 1881590 AR No: 50-029-21902-00 SEC 19, T11 N, R1 2F 721' FNL 8 1808' SP Exploration (Alaska) TREE= MCEVOY VALLWAD= MCEVOY ACTUh7O R= OTIS 103. ELEV = 91.46 BF. ELEV = 55.06 KW= 3201' Max Angle = 52' Q 9976 Datum MD= 11386 Datum TVD = 8800'SS A SAFETY NOTES: HZS READINGS AVERAGE 125 ppm Z_25 WHEN ON MI. WELL REQUIRES A SSSV WHEN ON Proposed RWO ML "'4-12- CHROME MPPLFS"' 13-3/8' CSG, 68#, L-80, D =12.415' Minimum ID = 3.726" @ 10769' 4-1@" HES XN NIPPLE .0152 bpf, D = 3.958' i 9-5/8" x 4-12- Lk*ue (v�chine Overshot 10551' 10692' W12•FESXP1Pt9-CR.D=3.813• I 51W X 4-12" FTS TW (RKR D = 3.903 12" FES X PP(e-CFq, D = 3.813' (2" FES X Np(97CFQ, D= 3.613' /e' X 41/2' FES TW POR, D = 3.903' 12' FES X NP (9 -CFO. D = 3.813' FES X FP (9 -CM, D = 3.813' 10759' —I4-12" FES XN NP (9 -CR), D= 3.813' TBG, 12-6#, L-80 TC{ 10782' 10782' 4-12' WLEG (9 -CR), D= 3.958' W, D = 3.958' 10774' B_ND ® TT LOGGED PERFORATION SLAWARY REF LOG: CET ON 03/19/89 ANGLE AT TOP PE RF: 41- @ 113W Wte: Refer to Production DB for historical perf data SIZE SPF KFERVAL Opn/Sgz DATE 2-118' 6 11380- 11412 S 0727/98 3-3/8' 6 11380 - 11412 O 08/03/11 2-1/8" 6 11434 - 11440 S 0727/98 2-1/4" 6 11434-11448 O 01/03/05 2-1/8' 4 11434-11463 O 08/17/98 2-12' 6 11440- 11463 0 08/02/98 2-1/4' 12 11448- 11454 0 01/03/05 2-1/4" 6 11454-11508 0 01/03/05 2-1/8" 6 11460- 11490 S 0727/98 2-1/8' 4 11500- 11550 S 0727!98 7" LNR 26#, L-80, .0383 bpf, D = DATE REV. BY COINVENTS DATE I REV BY I CONENTS 03IM89 DGH ORIGINAL COMPLETION 0123/12 TMWJND ADDED FQS SAFETY NOTE 10122/09 D14 RWO 10/27/09 SV ORLG HD CORRBUTp 01112110 DBUMJ DREG DRAFT CORFECTKM 02/16111 M30W ADDED SSSV SAFETY NOTE 08115111 TTPJ PJC R ---PERF (8011) PRIAHOE BAY tl4T VAIL: Z-25 FERNfT No: '1881590 AR No: 50-029-21902-00 SEC 19, T71 N, R12E, 721' FTL & 1808' FAL BP EXploratton (Ates ka) 1 2 3 4 4'-2" A ° ° A SHENKAI SL 13-5M ANNULAR 6'-103/6" SHENKAI SL 13-5M DOUBLE RAM B B 17/ 16 T_25/s" 6-1/2" C. 1''93/4' o oI0 o L. 0 0 0 0 o + 0 10'-4" V11.4,/" -41/2" G O O O ZMINPEN °IO 5'-31/" CLOSING / OPENNING VOLUME (GAL) ITEMS CLOSING VOL OPENNING VOL 30° ANNULAR 23.59 17.41 O RAM 4.39 3.91 p HCR 0.40 0.40 NOTES THE CONTENTS OF THIS IXUWNG PROJECT TIRE BOP INFORMATION IN THIS ERVICE CORPNYRN ENERGY SERVICES DWG NO 13-5M BOP STACK DRAWING IS FOR REPRODUCTIONOFTHIS I9AER0 A-000-15-002 REFERENCE ONLY AND IS NOT FOR ORAWNG WTHOU THE EXPRESS PERMISSION OF WESTERN I, , I .'TAwmt"C" DRANKWTE TV sCPLE .TWEIGHT 28/Feb/2018 N.S. REV 0 IWTAL RELEASE TY MJP D1/M°rRO1B CONSTRUCTION. ENERGY SERVICES CORP IB APPROVEDDATE SFLE SHEET 0 REV DESCRIPTION BY AFRO DATE STRICTLY PROHIBITED. MJP 01/M8F/2018 A 1 OF 1 2 1 3 1 4 Rixse, Melvin G (DOA) From: Browning, Zachary H <Zachary.Browning@bp.com> Sent: Tuesday, March 26, 2019 11:39 AM To: Rixse, Melvin G (DOA) Subject: RE: PTD 188-159 Z-25 Straddle and perforate, comingle additional pool Sundry 319-133 Mel, See my answers below: Thanks, Zach From: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Sent: Friday, March 22, 2019 4:09 PM To: Browning, Zachary H <Zachary.Browning@bp.com> Subject: PTD 188-159 Z-25 Straddle and perforate, comingle additional pool Sundry 319-133 Zach, A couple questions regarding Sundry request 319-133. 1. Because I don't know the wellhead design, do you have to split the stack to change IC packoff? If so, what are your barriers/procedures? It can be pulled through the BOPE. Barriers are KWF and tested downhole plug (and BOPE since no splitting is required). 2. 1 haven't seen this BOPE stack before. (Actually I have never seen a 13" stack.) Is it actually a 13" drift or is it 13-5/8"? 13-5/8" 3. Can you provide a very brief description for a remedial cement squeeze? Would it be?: a. Perf above TOC b. Set retainer c. Squeeze Correct, we would set a composite bridge plug below, perforate above logged TOC, and squeeze cement. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCCI, State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 )or (Melvin. RixsePalaska.eov(. SPREADSH E ET_Prod-Inject_Cumes_W ell_V119_1881590_PBU_Z-25_20190321.xlsx 3/21/2019 BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UNIT Z-25 (188-159) PRUDHOE BAY, PRUDHOE OIL Monthly Production Rates 1,000,000 - _ 1,000.000 � Produced Gas (MCFM) Produced Water (BOPM) Produced Oil (BOPM) 100,000-- - A - — --- --- -- 100,000 C 10,000 N 10, 000 H 41-- -_- ,P - ---- _— --- V CIL - --- —_ ° -I- - --- --_-- N U. 1,000 1,000 c---_ -- -- 100 ---- -- - S — -- — -- 100 Cum. Prod Oil (bbls): 2,904,766 Cum. Prod Gas (mcf): 11,904,646 Cum. Prod Water (bbls): 4,656,971 30 — Jan -1985 30 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 Monthly Injection Rates 1,000,000 Injected Ga, (MCFM) —e- - Injected Water (BOPM) - - - - - - - 1,000,000 100,000 _ —_.— — — -- t 100,000 r0 10,000 --- _ 10,000 1,000 =-- __ - -__ --- MLL U --_ _ _ _ _ --_ --_— 1,000 13 _ fD 100 — - ---- ---- - - --- ---- 3 _—__ lao ---- ----- Cum. Inj Gas (mcf): 8,954,241 Cum. Inj Liquid (bbls): 10,881,897 10 Jan -1985 10 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SPREADSH E ET_Prod-Inject_Cumes_W ell_V119_1881590_PBU_Z-25_20190321.xlsx 3/21/2019 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,October 12,2017 TO: Jim Regg P.I.Supervisor i]�wr SUBJECT: Mechanical Integrity Tests b BP EXPLORATION(ALASKA)INC. Z-25 FROM: Lou Laubenstein PRUDHOE BAY UNIT Z-25 Petroleum Inspector Src: Inspector Reviewed By: err, P.I.Supry J R— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT Z-25 API Well Number 50-029-21902-00-00 Inspector Name: Lou Laubenstein Permit Number: 188-159-0 Inspection Date: 10/8/2017 Insp Num: mitLOL171008133415 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z-25 - Type Inj W' TVD 8282 ' Tubing 687 691 ' 689 ' 689 - PTD 1881590 Type Test SPT Test psi 2070 IA 63 2300 • 2281 - 2271 - BBL Pumped: 3.4 • BBL Returned: 3.1 ' OA 119 - 336 332 - 326 -I Interval1 4YRTST P/F P ,/ Notes: Good Test Thursday,October 12,2017 Page 1 of 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) ~wo-Sided RESCAN DIGITAL DATA ~/' Color items: [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: TOTAL PAGES: ~ [~ NOTES: ORGANIZED BY: BEVERLY BR~ SHERYL MARIA LOWELL Project Proofing O~nnable) [] Other items scannable by large scanner 0VE~E'D (Non-Sca n na ble) 'V Logs of various kinds [] Other DATE: [] By: /s/ Staff Proof Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ (at the time of scanning) SCANNED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE; /si General Notes or Comments about this file: PAG ES: Quality Checked (done) RevlNOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: l S~ l ~~ FILE # a. a To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ~ 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 Voice (907) 279-1433 +Fax (907) 276-7542 STATE OF ALASKA ALASKA" AND GAS CONSERVATION COMMISSIIII0 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ `' 188 -1590 3. Address: P.O. Box 196612 Stratigraphic Service 0 6. API Number: Anchorage, AK 99519 -6612 _ 50- 029 - 21902 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028262 • PBU Z -25 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11800 feet Plugs (measured) None feet true vertical 9209.97 feet Junk (measured) —11455 feet Effective Depth measured 11750 feet Packer (measured) 10551 feet true vertical 9171.12 feet (true vertical) 8282 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H-40 36 - 116 36 - 116 1490 470 Surface 2614' 13 -3/8" 68# L -80 35 - 2649 35 - 2649 4930 2270 Production 10952' 9 -5/8" 47# L -80 34 - 10986 34 - 8598 6870 4760 Liner 1072' 7" 26# L -80 10728 - 11800 8408 - 9210 7240 5410 Liner g Liner '' ?kti ti AUG <i 1 207r Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _, _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 32 - 10782 32 - 8448 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" HES TNT Perm Packer — 10551 - 8282 12. Stimulation or cement squeeze summary: EC E1\/ ' Intervals treated (measured): AUG 2 9 2011 Treatment descriptions including volumes used and final pressure: $ Oil & � G v a$ Cam" Geraligdni 13. Representative Daily Pilil$ PYUFJLction or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 3272 614 Subsequent to operation: 3360 569 14. Attachments: 15. Well Class after work: s 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 ❑ GSTOR ❑ WINJ ❑ WAG la 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.O. Exempt: 311 -207 Contact Joe Lastufka Printed Na e oe Last A i Title Petrotechnical Data Technologist Signat e Phone 564 -4091 Date 8/26/2011 V30. /t Form 10 -404 Revised 10/2010 RSDMS AUG 2 9 2011 ' ! Submit Original Only Z -25 188 -159 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Z -25 3/3/89 PER 11,510. 11,550. 8,985.74 9,016.25 Z -25 10/31/90 APF 11,450. 11,455. 8,940.37 8,944.13 Z -25 11/10/90 SQZ 11,450. 11,550. 8,940.37 9,016.25 Z -25 11/18/90 RPF 11,450. 11,474. 8,940.37 8,958.47 Z -25 11/18/90 RPF 11,500. 11,550. 8,978.15 9,016.25 Z -25 5/8/94 RPF 11,474. 11,490. 8,958.47 8,970.57 Z -25 5/8/94 APF 11,380. 11,412. 8,887.72 8,911.76 Z -25 5/8/94 APF 11,434. 11,450. 8,928.31 8,940.37 Z -25 7/27/98 SQZ 11,380. 11,660. 8,887.72 9,101.19 Z -25 8/2/98 RPF 11,440. 11,460. 8,932.83 8,947.9 Z -25 8/17/98 RPF 11,434. 11,463. 8,928.31 8,950.17 • Z -25 1/3/05 APF 11,454. 11,508. 8,943.38 8,984.22 Z -25 1/3/05 APF 11,434. 11,448. 8,928.31 8,938.86 Z -25 1/3/05 APF 11,448. 11,454. 8,938.86 8,943.38 Z -25 1/4/05 APF 11,488. 11,508. 8,969.05 8,984.22 Z -25 9/3/08 BPS 10,612. 11,380. 8,324.76 8,887.72 Z -25 2/3/09 BPP 10,612. 11,380. 8,324.76 8,887.72 Z -25 5/24/09 BPS 10,732. 10,735. 8,410.99 8,413.19 Z -25 8/12/09 BPP 10,732. 11,380. 8,410.99 8,887.72 Z -25 8/24/09 SPS 11,032. 11,550. 8,631. 9,016.25 Z -25 10/16/09 SPR 11,032. 11,380. 8,631. 8,887.72 Z -25 10/16/09 SPR 11,380. 11,510. 8,887.72 8,985.74 Z -25 8/3/11 APF 11,380. 11,392. 8,887.72 8,896.73 Z -25 8/3/11 APF 11,392. 11,412. 8,896.73 8,911.76 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • Z -25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/2/2011 *** WELL INJECTING ON ARRIVAL* ** (E -LINE: PERF) INITIAL T /I /O = 560/0/100 PSI INITIAL VALVES CONFIGURATION = WING, SSV, MASTER = OPEN. SWAB = CLOSED ARRIVED TO LOCATION. BEGAN RIG UP. HELD SAFETY MEETING. PRESSURE TESTED ** *JOB IN PROGRESS * ** 7 3 8/3/2011 * ** JOB IN PROGRESS FROM 2 -AUG- 2011 * ** RIH WITH 3 -3/8" 20' GUN TOOLSTRING AND PERFORATED 11392 FT -11412 FT. CCL TO TOP SHOT = 5 FT AND CCL STOP DEPTH = 11387 FT. RIH WITH A 3- 3/8" 20' GUN (BOTTOM 12' LOADED) AND PERFORATED 11380 FT - 11392 FT. CCL TO TOP SHOT = 12.9 FT AND CCL STOP DEPTH = 11367 FT. ALL PERFORATIONS WERE MADE WITH 3 -3/8" HSD POWER JET, 6 SPF, 60 DEG PAHSING WITH 36.5" OF PENETRATION AND 0.37" OF ENTRANCE HOLE. ;POOH AND RIGGED DOWN FINAL T /I /O = 0/0/0 PSI I * ** JOB COMPLETE * ** (WELL SHUT IN UPON DEPARTURE) FLUIDS PUMPED BBLS NO FLUIDS PUMPED WELL MCEVOY HEAD = MCEVOY Z.25 ONM! * 12" HROMENI PLES A ` 5SSVWHEN A CTUATOR = OTIS KB. ELEV = 91.45' I ' BF. ELEV = 55.05' KOP = 3201' Max Angle = 52° @ 9975' 1 1 I 2081' H4-1/2" HES X NIP (9 -CR), ID = 3.813" 1 Datum MD = 11385' Datum TVD = 8800' SS 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 1 - 1 2649' 1 • Minimum ID = 3.725" @ 10759' 4 -1/2" HES XN NIPPLE I 10515' H4 -112" HES X NIP (9 -CR), ID = 3.813" 1 1 10551' H9 -5/8" X 4 -1/2" HES TNT PKR, ID = 3.903" 1 1 10592' 1 — I4 - 1/2" HES X NIP (9 -CR), ID = 3.813" I (TOP OF 7" LNR 1—i 10728' 1 ' 1 10759' H4 -1/2" HES XN NIP (9 -CR), ID = 3.813" 1 4 -1/2" TBG, 12.6 #, L -80 TCII, -- 10782' 1 / ■ I 10782' H4 -1/2" WLEG (9 -CR), ID = 3.958" 1 .0152 bpf, ID = 3.958" 1 10774' H ELMD TT LOGGED 04/16/89 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 1 - 1 10986' 1 A 11348' 1--17" MARKER JOINT 1 PERFORATION SUMMARY REF LOG: CET ON 03/19/89 ' ANGLE AT TOP PERF: 41° @ 11380' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/8" 6 11380 - 11412 S 07/27/98 3 -3/8" 6 11380 - 11412 0 08/03/11( 2 -1/8" 6 11434 - 11440 S 07/27/98 2-1/4" 6 11434 - 11448 0 01/03/05 2 -1/8" 4 11434 - 11463 0 08/17/98 2 -1/2" 6 11440 - 11463 0 08/02/98 2-1/4" 12 11448 - 11454 0 01/03/05 2 -1/4" 6 11454 - 11508 0 01/03/05 2 -1/8" 6 11460 - 11490 S 07/27/98 2 -1/8" 4 11500 - 11550 S 07/27/98 I'BTD I-3 11750' IrAvolreiVA.A.A. 7" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" I--1 11800' DATE REV BY COMMENTS DATE _ REV BY COMMENTS PRUDHOE BAY UNIT 03/04/89 DGH ORIGINAL COMPLETION WELL: Z -25 10/22/09 D14 RWO PERMIT No: x 1881590 10/27/09 SV DRLG HO CORRECTIONS AIR No: 50- 029 - 21902 -00 01/12/10 DB /JMD DRLG DRAFT CORRECTIONS SEC 19, T11 N, R12E, 721' FNL & 1808' FWL 02/16/11 MB /JMD ADDED SSSV SAFETY NOTE 08/15/11 1 1H/ PJC RE -PERF (8/3/11) BP Exploration (Alaska) • • 7 r iE FL S 1 All i =.,_ bft\ SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Carolyn Kirchner Petroleum Engineer 1 5/ BP Exploration (Alaska), Inc. ).....„(:),,____----- P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z -25 Sundry Number: 311 -207 Z�� , t,, , Nit JUN Dear Ms. Kirchner: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday • , eekend. 40 ,,, 1 1 1 1 io - , rma om Toner DATED this 7R of June, 2011. Encl. x STATE OF ALASKA X C" t �, C E V w ./ / ' ALASKAINAND GAS CONSERVATION COMMISSIO i. APPLICATION FOR SUNDRY APPROVALS j '; ` ;� 7 i vo /17 Zn 20 AAC 25.280 rt-r 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ tllgt 416theMpertaif 149t0 11X1 Suspend ❑ Plug Perforations ❑ Perforate 151- Pull Tubing ❑ > ; z cnFri xtension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 188 -1590 , 3. Address: P.O. Box 196612 Stratigraphic ❑ Service is _ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21902- 00 -00- 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU Z -25 Spacing Exception Required? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028262 - PRUDHOE BAY Field / PRUDHOE BAY Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11800 , 9209.97 - 11750 9171.12 NONE -11455 Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 36 116 36 116 1490 470 Surface 2614' 13 -3/8" 68# L -80 35 2649 35 2649 4930 2270 Production 10952' 9 -5/8" 47# L -80 34 10986 34 8598 6870 4760 Liner 1072' 7" 26# L -80 10728 11800 8408 9210 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 32 10782 Packers and SSSV Tvoe: 4 -1/2" HES TNT Perm Packer Packers and SSSV MD and TVD (ft): 10551 8282 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/6/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 151 - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Carolyn Kirchner Printed Name Carolyn Kirchner Title PE Signature Phone Date otiw 56 190 6/22/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓ ■ `- a 0 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /6 —Y• Y • APPROVED BY � Approved by: COMMISSIONER THE COMMISSION Date: '(/ / RR pp (0 t, 5 82O1f " 1 R1G1NAE. � Z7 r Form 10-403 Revised 1/2010 Submit in Duplicate Z -25i: Add Perfs 1. Add uphole perforations shown in orange as follows: mvnss_1 �O� \ �� 91 00 FffiT $600 FACIES 4 ?i �RD 1 DT N 1 1 °HIS II3 F 42P 11380' 11410' 30' 8796.2' 8818.8' 4.5' -- 1 Rn , PPHT_CPNL_l ' PI • - ODUN " 2 P" TOTAL LENGTH 30' TOTAL HEIGHT 21.1' 4, 1 1120° monmarifirsunomammemo 1. - - Current Estimated Fluid Contacts 1 - _ - GOC: W ithin the Z -25 pattern the GOC ranges from -8765 to -8800. ,"` — 8700 The GOC is deeper towards the northeast and shallower towards the - - I southwest. I OW Estimate a t 8850 -8880' s in the 41P/31P Y1 The C o : WC in the Z -14B which w drill in 2006 was seen at -8885 in . rt a - — the 31 P. The rest of the wells in the pattern are swept higher than this and are producing primarily water out of perforations lower than 8850 — ' tvdss. .� ATri -- tAlliNIMNIMMEINNINIIIMIlimillIMMINIMI 4 :" 1 � eao° ° I �— Pattern Overview and Adperf Summary � . �. ,.�� 1 1 � . I = As a pattern, this one is underperforming. The wells do not have good a , o.n -time due to high gas rates and velocity constraints. However there = is excellent recovery to date with a 45% RF. Z -25i pattern now includes: Z -26a, Z -15, Z -14b, Z -24. The Z 2 5i is a WAG injector and the Z -14B saw great benefit when the injector was on MI. The Z -25i is _ ` . _ currently injecting water with an injection target of 4500 BWPD, but it often underinjects at 2500 BWPD. The max safe injection rate is set at seNi In Y1500 5 MBWPD, but data shows well has and can take more fluid. Likely the 8 9 °° well is /was thermally fractured. The plan to run (PROF may give an : mi - indication of where fluid is going, but hard to interpret if fractured and — since there is only one continuous pelf inerval. Warmback passes may - 111011111 MMOMMIMIUMMIIMWMMIN be more informative but can't get below bottom perfs. ; '4.‘\.;'\‘': ! 1 *" . , ' "11.111 i — iiiiiiMill"MinUnallanarailliMi B y pe the 42P all the offset wells which currently are open in 116430 this zone will be supported. The offset wells all produce gas from the - OMNI, 1111NallUDIMMINIMINIMMIIII 42P and by injecting water into this zone the gas underrun in the 42P t } + may be su ppressed. In the Z -24 a patch is being set across the 42P 'VI _ >� ° perfs to shut off gas and get the well back online. At this time the Z -25i - IIMIUMII"UMIMMMNIIMMNIMIMII - is currently on water injection. It would be best to keep Z -25i on WI MUM - while 42P is open to injection to prevent further increasing gas rates in ,,, _ the area and /or loosing MI into the gas cap. Water injection would help 1 - - support the wells and hold off gas. u ate . , , i , ;. i CK/ ACG06/21 /2011 Z -24- currently open in the 42P,41 P, 31 P. Shutting Z-1 5-currently open in the 42P, 41 P, 31 P. Well off 42P to shut off gas. shut in for high GOR and high WC. c - m O i i t Q TVDS$ 1 ° n �, ? t R D 1 sz P CIQL 1 FEET a�oo y Ill 11. Crain 1 C -i � TVDSS 1 CPNL 1 I I FEET £11 r 1. °' I1 . P4 - �st _ RRR PI 150 1. OFII+A1 n 140 3 1 40 �� :� �� - - - -, ' �e "< 1 RD 1IT_N_1 jimmiliii 1 I MUM ... 1 1d UQ suril f imm inl om illiMill wom , $011 I mint17111Mmossimumil::111111nP:,,IMINIMMumni1711111114.01"1111ifIl■ 4471111111M11" , i*L, \ " • \ ,,,,„, - - -A ,ozn - 11111 _ - siummu mmummi w is ,A=.4, 1.11111. 0*., 111111111111111111 - - X1111111 � - - if �M _ - 1111111111III Iuail!' f �� - winaiil;n a i - _ 111III•11IIIh i111IIIIIhIIl$ ■� 8700 ��miil�s ■ �� 1� _ 11III11 1111IIF>11111IIND. JINN .E Lr�t • _. _ - //IIMIONINNI I � 'MO .� ..... - - -- - - - - � nt � IIIIIIII � IIIIC IIN��>E t� - .n hImo lug m� n6n sso9 ■111 11111 11111( �1111111rR ra - .,_.1111111111.111 loam mmumminual - anomii�m�i _ III _ ounmiumea*. ME am_ Al - ma _, Nllil 1111111i:l1 - 1111 1 h /lIa so 1111 �, 104W 8806 -M. � � I��. _ M I - flks''141111111.11 I ��1118111� �F mom - - s� 11604 a1G�l�lllltIIiip l: III II�IH11�1111111�� _,- ... a. 8 999 Wammin �_ �� IIIIII�IIIIlflllll11��1/� _ - - 111111111111100 11111111111111111111N111 * 4,, mi : ININIENINUMANUM .1111011101191110% Ilf!NI!II�N��i i os90 _ 1uuiair'aliU _ 890D ..: 1691 m - lu ■ _ IHIII �� igtillinini - 11790 IIIiiui111 1 � ,06,00 - N II�E. matiommum _ �f 6,909 X111 l �/' - - 11II I11IIIIIllliNr �1l _ - MINEIR11.11111111111111111114111111 Z-1 4B This is a pre - producing injector that is still on production. It is currently producing out of the 42P, 41 P, and 31 P. A 'MOSS 1 h ;l NPHI 1 Timing for conversion to injection has not yet been TM FAT S��a y y po determined. � 1 '. 1 Rn -1 RHOS1 PI 156 I. OluN 1 1.49 G /C3 _ 2.69 MOMMIINICANINININNISIMMA � _ - s?ao H111nlnu !! IIIII II� I•� ■J _ IIII INS �� H � �AJ � � - 111111111111111111 � '41 N 11111111II��I 1111110111111111111 _ - ■11111111./1111F 11111111 ■10111101r ml•Ia N$II �'IIHIIIHO C m■al - _ _ .IIIIH11.11111 911H11■�' . -�� t. �. a _ _ .IIIIII1111I . 4111111111w��i. i 117 ■IUIII11.111 1111111111111nl�r 1P� ■u■ 111111111111111111 - 111111111111111111111.11111 . �1�� - .IHIII.INIII AIIIIIIL�T R, n. 8 �� - 80D .111HII. Ei11N111 a 11111111 ■ $e Nfl a, ' �` .. ,,4. IIIII IMP" 911111111 ,? — IIIINI. � - �` � - ■!IIlNII9!�JNI� 111111 - .1111111111111111111 :I _ H11 ■ IIMMIIIIIIMI i 1500 aeon r:. ., ��,..,...........,.__.._ : _immifilIMMIONINIM nano 9000 - Ii i ''' \ti4,.,. . 1. `b � PEC - — maiinumeitatoingarsasem win Comma* Structure map of area with GO data: O: C -8765, GOC d uring early EWE de -8775 .,;,.. lt,,,,,,, i „ I_ 87 Z 7,1 \ co , _........iiiiii.„ . a wt, 4.,,,,,,14,,,,,,,,::.,,,, t `.° '-' / 13,,.:, . �`4 ` & GOC est: - 8770 ,. V z ' A �, m a o 1,c), PP ' _ e 1 r I o GOC est: 8800 ° 9A� . Nikki - i.iiiiik: I., ,.,... Pk .. 7 +, p� � „ a�, a 874 -25 -Q6.4, d;. V 1.9 0 10 - '?J*1:44.sit*"..\,:;.:.**; ''''‘-'::\•:!''‘;'' - GOC es -8795 Sys G OC est: -8760? n GOC est: -8760? S : an � � �-,',, ,� GOC est: -8 ' , Ira ''''''''''fic\‘'‘.. >''` ' GOC e.st: - 8770' `, �re -p mp ° o " �,� i rr l ectok Curked ntly 406, ' �' � � � �' � ti p re pr`ot� oduc icing � � � 1A � A 11 3B A, F..i.,,z,..0,,toiliN ,, A ,.../ , , ,,,,,,,::,,, -\\,,,, ,,,„ -Ain asooN., .4k ‘ MO. l'4' '10 , Mitir,frAkb.,mv bp �� G OC est. 8770. dirifitaiih, ..„ „, , , , . ., (poo v erb ... AO a Ilikr,4441.-.4101, • y 455 ca 10,66.,1 1 Illir � . ( JOG es - t: 8 770 _ ti � ,b rillia/WIF04 ,, ,. ;. tad ! � less) Wall cP wq --;Mill • rf� f G ° l r r � iiii‘,414.1 kw . a 'It 11111111111w-- rICI---.6111re i a ' x a if a] ,saw 4 10 r s� � ° GOC est: 8775 GOC est: 8880 p� , (good vertical p °II di --. ,. k f � ` connectivit 1 Ilir 3 9 A �2o W Q JJ ° GOC est: 8810 40010r ri iii, ;id �C 4 meters ° . 4., Pressure map of Z -25 area Faults highlighted in brown to show the main fault block area. 1 _16 / 370 ,. x/04/09 01/29/09 ..,.. ... - 8770 W -26 W-19AL1 , -21 Z-32B 21A Z _ - 8800 3Vt94 8 04/12410 3763 Z -32A 708 3662 26A 3403 07 -8760? 2 1/09 08 /24/09 W- 2911/25/10 3574 3578 4 W-23A 5 Z : 06/29109 Z (3� , 2005 Z 15 • 3694 /09110 3554 3451 W-2 7 �HEV181112 _______i11108 Z -14B 3608 - 88 50 0912717 09/22/07 /09 8760? 02/06/ W-21) MP00151112 c t ■ .50 Z 23/09 W - 31A WW28A .. 31 Z -23 8770? W -31 •` W - 24 06/ ` `a, , \ Z8236A. 05 331;7 - 8770 1 (poor - 2 6� WA-AL I vertical 4 597 .;, ;, 3288 iiA9 16,52,,, Z -14A Z-20 connectivty) t 0212/11 /, r W -34A u ) W -30 W-18 W- 3615Z-04,_,_ - 8770 646 6% • /01/07 m ____ ...w ` 06/17/09 640 0 3568 - (good ,43 729/09 10;'15110 vertical )6/11 THIS IS INTERESTING! W -6 connectivity) W -2 27 W -35 (See commeiltt in notes - /088 Z 39A 637 A'WETW 03/08/08 • HIGLion of ppt. ) 3667 - 8775 10/10/10 Z -33A Z 02 04/10/09 W -39A Z -03 KUPSYW,A Z -11A _ 3772 w est: 8810 05/21/38 �' —4 3707 I )551 • • 8• 3671 2 09/15/07 06/10/10 W ` F • ,+0 O 2006 W -42 W -0 ` 59 Ir I 47/09 3727 t 3599 91 107 1500 feet x /06/10 •' '04/08/10 AO() meters Z -12_ ,___� .\ w -45 f • 2011 • 2007 or earlier, not used in gridding • 2010 2009 2008 FILE COPY Olt Scfllt�irlberger CEMENT EVALUATION LOG (CET) COMPANY BP EXPLORATION WELL 2 - 25 } i FIELD PRUDHOE BAY • d A BOROUGH NORTH SLOPE STATE ALASKA eltr. w g 721' SF& 1 3143' WEL wyµ 70.2983 Other Services: GYRO AT SURFACE PET 9 < i API SERIAL NO. SECT. TWP. RANGE 8 T I 50- 029 - 21902 -00 19 11N 1 12E Permanent Datum MSL Bev. 00 F ENv.: KB.II1.6 F Lop Wasund Fran RKB 91.6 F above Perm. Datum DP.111.5 F Ceiling Measured From IIKB 01.64.1 F Date 3 -2 -1 848 Run No. ONE Depth Drew 11760.0 F Depth Ledger (Betel) 111764.0 F Bun. Lop imam, 11748.0 F mm Top Log Merval 10736.0 F Type Fluid In Hale ERNE Salleny NOCI penalty 9.40 9.40 L6 /0 FMB Level Max. Roe. Temp. • Deviation 52 DEG Longer on Bottom 1700 � Equip. ILwgtlon 8286 ..,._. -- I_RUoHOE BAY . _L ._..,._.._..___.. Reoorded By O.BARBA Witnessed By K. YEAGER BOREHOLE RECORD Mt Stag 12 1/4' 8 1/2" Depth CASINO I TUBING RECORD Bits B 6/8' 7 IN_ndIt 47.0000 LB/F 26.0000 LB/F Oastnq Tq -DrMer 0.0 F 10728.0 F Oadnp Tap- Leppsr 107350 F Casing Ahoe-0rdler 10990.0 F 11800.0 F J casing Bhoe- Lepper T . 0 • !I IIIINNI emu ii i i111 iiuiiii zg 1:!� !u i;ir11i1rsii Ir;!!!IIIIUia! , :51!111111111 • •• I •• •• ■s ■ ■ l ,as , •ran ns w •naa a q • f �.••• a • •• •: a • • •r 34/41;;;;;:i,!"""" r+�rP :ail; i!'. i.a:�4 ; idioti r.ttllIIlu1 .1vhi i.iiiii iiiuuit iii!M ■,� :.:.... .. 11111i 11IIIIU _ I 1 IMMI IlIMNIMI IMI h l 1 1 1►1N 1� 111 k 111ll 111I111111 1%0111IIIM MIIMINIIIIM MENMUIMMMIIMIMMIHMIIIMPIffilli 11 11111 1h11111111 ' I !uh 1111111111111i111111N1 11N11 11111111hhhiihIf11111111111111i1111111ii1111 11 1111111111; 1111111. �1l I�. 1I1111111111111111I1111111IN11 NMI .111N111111I1111111111111111111111111111 II 1111111II hJ111111111111ii111111 Barnum n1 1 1 1 1111111 1 I111111111111111hIN1 11 1111 11 1 1 11 1 1 11 #■ M u ■PR.■ ■■■ N■we ■ NW, .0 ■ mP ■ P, i... ■ • ;4$.4 zp , 1G1 e 0 111 1111N1IIIN1E111N1111111 111N111111111111UNM1111N111111H111N1111 1111 111111111111 III 111111111111NI11I11IIIIIIIIIIIIIIII11I111111111111111181111I11111I11I111 IIIIIIII11111111111I11 17119; rrIZITIP :1A111117 'P': ;��! Ili*141111u`2 , 1 1�INII II,��n��••■ ■•••�'•• dint '!.''.': �'n�i .iiii I.,ilk NCi 1111'1111i1`I 1111i111iikaill Viil ► i 1111 IPPII11i11i11 1P 11!1111111 1 1111111 hh1 11i1! I,IINhII INII111111I III111NI1`I'r11111NtIli!I'II ihi i ,` _ I110111111 111 h hhNINI 1P11 IMIit111IIMMIN1111NN� 1 11 itilIAihh hh1I 11111nn11 110 0 11 1 1 11� 11.11911.11 x1111111 ' '' ` 111111 11. nl� 11li 111 lir fir. . - . ; .W 77 'i. � * �. -NIP: `1 'fir" \RR�R ' �, 111 _, t 1 i `� , -: 0 . r , 1 , I :! ..! : i r ! 1 J i;t 1 ' . i i 1 C 1. ■ 1 i i ' .: 1 1 ' i 1 1 : . . i 1411::Zi ' . t 7 t I'. 0"-''' . . tr 3, 1, i I. 11 1 i • ♦ ♦7 i} E, T „ f 1 • • PERFORATING PROCEDURE Ver 1.2, Rev 10/21/01 Well: Z -25i API #: 50 -029- 21902 -00 Date: 6/20/11 Prod Engr Carolyn Kirchner Office Ph: 564 -4190 H2S Level: Home Ph: N/A injector Cost Est: $60 Cell /Pager: 227 -6169 CC or AFE: APBZPDWL25 WBL Entries IOR Type Work Desciption 50 S Drift with 3 -3/8" Dummy Gun, TEL & 4 -1/2" dummy patch 50 E Add Perf, Jewelry l09 Well Obiectives and Perforating Notes: Add perforations in the 42P for conformance with offset producers prior to 3rd MI slug. Water should help hold back 42N gas underruns in area & gas cap. Consider patching zone during gas injection - drift for 4- 1/2 "x7" expandable liner patch. RWO 10/2009 to repair tubing leak. Tagged TD 11/8/09 at 11484' MD. 3.725" min ID at 10,859' MD. The jewelry log is for records post RWO - new completion. Plan to follow up with an (PROF on water, but uncertain of value at this point due to pert configuration and thermal fractures. Attachment: Reference log with proposed perfs annotated, 5 "/100' scale Reference Log Tie in Log Add 0 feet Log: BHCS CET to the tie -in log to be on Date: 2/24/1989 3/19/1989 depth with the reference log. Company: SWS SWS Depths (from -to) Depths (from -to) Feet SPF Orient. Phasing Zone Ad /Re /Iperf 11,380' - 11,412' 11,380' - 11,412' 32 6 Random 60° 42 Add Perf Requested Gun Size: 3 -3/8" Powerjet Charge: Powerjet 3406 HMX Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessary. Preferred Amount of Drawdown /Suggestions to Achieve Drawdown Last Tag: 11,498 MD ft MD on 11/11/2004 Est Res. Pres. @ 11,385 MD is 3700 psi Perforation Summary Summary Dist Well: Z -25i Town: Date: API #: 50- 029 - 21902 -00 Prod Engr: Anch Prod Engr P.D. Center PBTD General Comments: Depths Balance Based on Ref Log Gun Dia. Orient. SPF Phasing Zone Adperf/Reperf O /B /U - O /B /U - O /B /U - O /B /U - O /B /U - O /B /U - O /B /U - WELLHEAD = MCEVOY Z -25 SAFETY Nt H ROM RENPP LES S ** SSSV WHEN ACTUATOR = OTIS KB. ELEV = 91.45' ( _ ' BF. ELEV = 55.05' KOP = 3201' Max Angle = 52° @ 9975' ' ' ( 2081' 1 HES X NIP (9 -CR), D= 3.813 "' IL Datum MD = 11385' Datum TV D = 8800' SS I 13 -3/8" CSG, 68 #, L -80, ID = 12.415" 1-1 2649' 1---41 Minimum ID = 3.725" @ 10759' 4 -1/2" HES XN NIPPLE i 10515' I-14 -1/2" HES X NIP (9 -CR), ID = 3.813" 1 X 10551' 1 I_19 - 518" X4-112" HES TNT PKR, ID = 3.903" 1 I I I 10592' H4-1/2" HES X NIP (9 -CR), ID = 3.813" I TOP OF 7" LNR 1--I 10728' 1 • N 1 10759' H4-1/2" HES XN NIP (9 -CR), ID = 3.813" 1 4 -1/2" TBG, 12.6 #, L -80 TCII, --1 10782' 1 / k I 10782' H4 -1/2" WLEG (9 -CR), ID = 3.958" I .0152 bpf, ID = 3.958" I 10774' 1 - 1 ELMD TT LOGGED 04/16/89 1 19 -5/8" CSG, 47 #, L -80, ID = 8.681" 1-1 10986' 1 4 ■ I 11348' H7" MARKER JOINT 1 PERFORATION SUMMARY REF LOG: CET ON 03/19/89 ANGLE AT TOP PERF: 41° @ 11434' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/8" 6 11380 - 11412 S 07/27/98 ' 2 -1/8" 6 11434 - 11440 S 07/27/98 2 -1/4" 6 11434 - 11448 0 01/03/05 ' 2 -1/8" 4 11434 - 11463 0 08/17/98 2 -1/2" 6 11440 - 11463 0 08/02/98 2-1/4" 12 11448 - 11454 0 01/03/05 2 -1/4" 6 11454 - 11508 0 01/03/05 2-1/8" 6 11460 - 11490 S 07/27/98 2 -1/8" 4 11500 - 11550 S 07/27/98 PBTD 1-1 11750' 1 MOO. 17" LNR, 26 #, L -80, .0383 bpf, ID = 6.276" 1-1 11800' , AvAVA DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/04/89 DGH ORIGINAL COMPLETION WELL: Z -25 10/22/09 D14 RWO PERMIT No: 9881590 10/27/09 SV DRLG HO CORRECTIONS API No: 50- 029 - 21902 -00 01/12/10 DB /JMD DRLG DRAFT CORRECTIONS SEC 19, T11N, R12E, 721' FNL & 1808' FWL 02/16/11 MB /JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) • • MEMORANDUM TO: Jim Regg ' 1~ l Iz ~ 3 ~ t~~ P.I. Supervisor "~~ FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, December 03, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Z-2s PRUDHOE BAY UNIT Z-2s Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~Z Comm Well Name: PRUDHOE BAY UNIT Z-25 API Well Number: 50-029-21902-00-00 Inspector Name: Bob Noble Insp Num: mitRCN091201060216 Permit Number: 188-159-0 Inspection Date: 11/30/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --~-- ~r------- - Well ~z_zs Type Inj. ~G , TVD s2az IA 6so za9o 1881590 ~ 2490 'I OA 20~ 390 "'T± zags -~ 2a~o 390 390 ~ TypeTest I Test psi P.T.D _ ~--- ~ -- ---~ - ~ - ~ -----1- Tubing~zsso zsso ~ ? ~ Interval INITAL '~ p/F 2sso zsso_~ _ _ _ __ _ Notes: POs ~tl,~~J !`~~~ccr?r~„~- ~.2wG~ ~cz ~; iNl l V\. (it t i~'~~ ~ Sys- (>r2~:51/i/Y= 1 t~~a~~~~y ~ ~ ~ r, ~~ ~~~ Thursday, December 03, 2009 Page 1 of 1 STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COMI~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~~~~~ ;~C~V' ~ ~ 20Q9 1. Operations Performed: ~,~~~}(,~ ~g~ ~t ~ro~S OI1S. OII11~115 ^ Abandon ~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended V1~Chn~B~@ ^ Alter Casing ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: Permit To Drill Number: / BP Exploration (Alaska) Inc. ^ Deveiopment ^ Exploratory 188-159 3. Address: ~ Service ^ Stratigraphic API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21902-00-00 7. Property DesignatiQn: Well Name and Number: ~ ADL 028262 PBU Z-25i 9. Field / Paol(s): ~ ~ - Prudhoe Bay Field / Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured `y, 11800' feet true vertical ~ g2~ p~ feet Plugs (measured) None Effective depth: measured 11750' feet Junk (measured) -11455' truevertical g~7~' feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2649' 13-3/8" 2649' 2649' 4930 2270 Intermediate Production 10986' 9-5/8" 10986' 8598' 6870 4760 Liner 1072' 7" 10728' - 11800' 8408' - 9210' 7240 5410 ~'~LY~~~~1 ~~ ~ ~'.~ ~ ~ L.Q6>~ , PerForation Depth: Measured Depth: 11434' - 11550' True Vertical Depth: 8928' - 9016' Tubing (size, grade, measured and true vertical depth): 4-1/2", 12.6# L-80 10782' 8448' Packers and SSSV (type, measured and true veRical depth): 9-5/8" x 4-1/2" HES 'TNT packer 10551' 8282' ~ 11. Stimulation or cement s4ueeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bb1 Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13. Attachments: ~ Copies of Logs and Surveys run • W~II Class after work: ^ Exploratory ^ Development ~ Service ~ Daily Report of Well Operations ~ Well Schematic Diagram • W~~~ Status after work: ^ Oil ^ Gas ^ WDSPL ^ GSTOR ~ WAG ^ GINJ ~ WINJ ^ SPLUG 76. 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: Contact David Bjork, 564-5683 309-253 Printed Name Terrie Hubble Title Drilling Technologist Si t '~ ~~l~ Prepared By Name/Number: D t na ure 9 a e Phone 564-4g28 Terrie Hubble, 564-4628 ~ion Form 10-404 Revised 07/2009 . ~~ ~ ~ ~ ' ~( //~ . ~ Submit riginal Only i' ~, i ` ; ~~~l~~ t j::~' \ ~ ~ ~ Z-25, Well History (Pre Rig Workover) Date Summary 8/1/2009 WELL S/I ON ARRIVAL. RAN 2.70" CENT & 225" LIB, TAGGED P-PRONG C~ 10,733' SLM / 10,754' MD. LIB SHOWED IMPRESSION OF PRONG. WELL LEFT S/I, PAD OP NOTIFIED. 8/2/2009 T/I/O = 400/100/100, Temp = S/I. CMIT Tx IA FAILED to 4000 psi, MITOA FAILED to 1000 psi (PRE RWO). CMIT TxIA; Pressured up TBG to 4000 psi with 11 bbls crude. Maintained 4000 psi with 5 bbls crude. LLR= 1.1 BPM C~3 4000 psi. Total volume pumped= 16 bbls crude (see log). Pressured up IA to 3800 psi with 28 bbls crude. Maintained 3800 psi with 2 bbls crude. LLR = 2.6 BPM C«~ 3800 psi. Total volume pumped = 30 bbls crude (see log). MITOA; Pressured up OA to 1000 psi with 4.8 bbls crude. Maintained 1000 psi with 4.8 bbls crude. LLR = 0.5 BPM C~ 1020 psi. Total volume pumped= 9.6 bbls crude (see log). FWHP = 50/350/100 WV, SV = Closed. SSV, MV = Open. IAV, OAV = OTG. 8/12/2009 WELL S/I ON ARRIVAL. PULLED P-PRONG & 3-1/2" XN-PLUG BODY FROM XN-NIPPLE C~3 10730' SLM. RAN 2.5" CENT., DUAL PETREDAT GAUGES (GOOD DATA). LEFT WELL S/I, TURNED WELL OVER TO PAD-OP. 8/23/2009 MIRU. RIH w/ 2.65" PigShear. Tagged fill at 11480 CTM. PUH to 11350 and perform injectivity test. In 5 minutes tbg pressure went from 370 to 1300 psi at 1.5 bpm. Begin circulating 2% XS KCL. 8/24/2009 Circulate 180 bbls of 2% XS KCL. Circulate 35 bbls of diesel down the backside and up the coil. Lav in 10000#'s of 20/40 Carbolite from 11470' and 11000'. PUH to safety. RIH and tagged 20/40 Carbolite at 11084' CTM (Final Tag). Pumped 2 bbls of 15.8 ppg cement, est top of cement is 11 Q32'. Job Complete. 8/27/2009 WELL S/I ON ARRIVAL. DRIFT W/ 2.70" CENT, 2.50" S-BAILER TO 11011' SLM. 1 CUP CEMENT RECOVERED. WELL LEFT S/I, DSO NOTIFIED. 8/28/2009 T/I/O = 250/300/0 ""*CMITTxIA PASSED to 1000psi'"' Reached test pressure w/ 7.5bbls crude. Tubing and IA lost 20psi 1st 15min, Opsi 2nd 15min, for a total of 20psi in 30min. Bled to starting. FWHP's = 250/300/0 Swab, Wing = shut. SSV, Master, IA, OA = open. 8/30/2009 WELL SHUT IN ON ARRIVAL. INITIAL T/I/0=200/250/0 JET CUT 3.5" TUBING IN MIDDLE OF FIRST FULL JOINT ABOVE PACKER AT 10677'. LOG CORRELATED TIED-IN TO TUBING TALLY DATED 3- MARCH-1989. TUBING CUT AT 10627'. WING, SWAB = CLOSED. MASTER, SSV = OPEN. CV = OTG. PAD OPERATOR NOTIFIED OF STATUS. FINAL T/1/0=150/250/0 WELL LEFT SHUT IN. JOB COMPLETE. 9/6/2009 T/I/0=0/240/50 Circ-out (RWO Prep) Pumped 1 bbl meth and 1073 bbls of seawater down tbg thru cut to IA taking returns down Z-24 flowline. Swapped valves on reverse out skid to pump diesel down IA. Pumped 67 bbls 110° diesel down the IA thru cut to tbg taking returns down Z-24 flowline. 9/7/2009 Circ. out, CMIT TxIA PASSED to 1000 psi (RWO prep). Continued pumping 73 bbls of 110° diesel (140 bbls total) down IA to tbg taking returns down Z-24 flowline. U-tube TxIA to freeze protect well. Pumped 2 bbls of diesel down IA to achieve test pressure. T/IA lost 40/40 1 st 15 mins and 30/30 psi 2nd 15 mins for a total loss of 70 psi in 30 mins. Bled whp's to 0 psi. FWHP's=0/0/0 Tags hung on WV and IA. Valve positions upon departure: WV,SV = closed, SSV, MV, IA, OA = open. All hardline block valves = closed, SV on Z-24 = closed, operator notified. 9/10/2009 T/I/O = VacNac/30. Temp = SI. Bleed WHPs to 0(pre pack off work). OA FL near surface. SV, WV = C. SSV, MV = O. IA, OA - OTG. NOVP. 9/14/2009 T/I/1= 0/0/0. Temp.= SI. PPPOT-T, PPPOT-IC PPPOT-T stung into test void 50 psi. Bled to 0 psi. Pumped fluid until returns were clean. Pressure tested to 5,000 psi. Lost 100 psi. in 15 min. lost 0 psi. in 30 min. Passed. Bled void to 0 psi. Functioned all LDS. all moved freely. PPPOT-IC Stung into test void 0 psi pumped fluid until returns were clean. Unable to pressure past 1,800 psi. Functioned & Re Torqued all LDS all moved freely. Tried to pressure again with same results. FAILED. NOTE. Unable to pump plastic through packing void. Page 1 of 1 • ~ BP' EXPLORATION Page 1 of 11 Opera~ions ~umrnary R~pc~rt Legal Well Name: Z-25 Common Well Name: Z-25 Spud Date: 2/6/1989 Event Name: WORKOVER Start: 10/5/2009 End: 10/22/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/22/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To } Haurs Task I Code NPT Phase ' Description of Qperations I 10/5/2009 107:00 - 19:00 I 12.001 RIGD I P 19:00 - 00:00 5.00 MOB P 10/6/2009 00:00 - 00:00 24.00 MOB P I 10/7/2009 00:00 - 03:00 3.00 MOB P 03:00 - 10:00 I 7.001 RIGU I P 10:00 - 12:00 2.00 RIGU P 12:00 - 13:30 1.50 RIGU P 13:30 - 15:00 1.50 RIGU P 15:00 - 16:00 1.00 RIGU P 16:00 - 17:30 1.50 RIGU P 17:30 - 19:30 2.00 WHSUR P SKID RIG FLOOR AND PREP TO MOVE RIG DOWN GRAVEL RAMP. SET RIG MATS FOR RIG. MOVE RIG DOWN FROM RAMP TO PAD LEVEL. INSTALL BOOSTER WHEELS AND FRAMEWORK. PULL BOP STACK OUT OF CELLAR AND SET IN CRADLE. PREP RIG FOR MOVE TO Z-25. MOBILIZE RIG FROM DS-02 TO Z-25. CONTINUE TO MOBILIZE RIG DOWN OXBOW TO SPINE TO Z PAD. RIG ON LOCATION AT 22:00 HRS. BEGIN TO PREPARE THE RIG FOR Z-25i. PICK UP AND SIT BACK THE BOPE STACK FROM THE CRADLE. RE-INSTALL THE CELLAR DOORS. WORK THROUGHOUT THE RIG IN ORDER TO PREPARE FOR THE UPCOMING WELL. SECURE THE BOP STACK ON THE STUMP AND REMOVE THE YOKE. CHANGE OUT THE ANNULAR, REINSTALL THE YOKE, AND THE CELLAR HEATERS. PRE MOVE THE RIG OVER THE WELL. PRE PJSM, SECURE THE AREA, AND SKID THE RIG FLOOR. PRE SPREAD HERCULITE AND SPOT THE ROCK WASHER. PRE HOOK UP THE LINES UNDER THE RIG FLOOR, SPOT THE SLOP TANK AND MAKE UP THE HARDLINE. BEGIN TO TAKE HEATED SEAWATER INTO THE PITS. PRE MAKE UP THE ANNULAR VALVE AND THE 1502 FLANGES ON THE TREE. ACCEPT THE RIG AT 16:00. WHDTRE PJSM WITH THE DOYON RIG CREW AND DSM. RIG UP THE LUBRICATOR AND TEST TO 500 PSI FOR 5 MINUTES. GOOD TEST. PULL THE BPV AND RIG DOWN TH,~_ LUBRICATOR. PRE PRE PRE PRE PRE 19:30 - 21:00 1.50 WHSUR P WHDTRE RIG UP TO CIRCULATE OUT THE DIESEL FREEZE PROTECT. TEST THE HARDLINE TO 2500 PSI. GOOD TEST. 21:00 - 00:00 3.00 WHSUR P WHDTRE CIRCULATE OUT THE FREEZE PROTECT TO THE OUTSIDE TANK. REVERSE CIRCULATE 25 BBLS AT 2 BPM WITH 270 PSI ICP AND 360 PSI FCP. CIRCULATE DOWN THE TUBING 130 BBLS AT 2 BPM WITH 60 PSI ICP INCREASING THE RATE TO 4 BPM WITH 800 PSI FCP. ALLOW THE WELL TO EQUALIZE FOR 20 MINUTES. CIRCULATE DOWN THE TUBING 20 BBLS AT 4 BPM WITH 800 PSI. 10/8/2009 00:00 - 02:30 2.50 WHSUR P WHDTRE REVERSE CIRCULATE 25 BBLS AT 2 BPM WITH 120 PSI DUE TO TUBING SHOWING SIGNS OF BEING OUT OF BALANCE. WAIT 10 MINUTES. TUBING STILL FLOWING. REVERSE 50 BBLS AT 2 BPM WITH 120 PSI ICP WORKING UP TO 4 BPM WITH 380 FCP. TUBING STILL FLOWING. 02:30 - 07:00 4.50 WHSUR P WHDTRE RIG UP AND CIRCULATE 150 BBLS (1.5X TUBING VOLUME) DOWN THE TUBING TAKING RETURNS TO THE PITS AT 5 BPM WITH 1260 PSI. MONITOR FOR 30 MINUTES. TUBING STILL FLOWING. CONTINUE CIRCULATING 600 BBLS ADDITIONAL BBLS AT 5 BPM WITH 1250 PSI. TUBING STOPPED FLOWING. 07:00 - 10:30 3.50 WHSUR P WHDTRE RIG UP TO DRY ROD IN THE TW~. TEST THE TWC FROM ABOVE TO 400 PSI LOW AND 4000 PSI HIGH FOR 10 Printed: 11/2/2009 2:54:30 PM , ~ ~ BP EXPLORATlON Page 2 of 11 Operatians Summary Report Legal Well Name: Z-25 Common Well Name: Z-25 Spud Date: 2/6/1989 Event Name: WORKOVER Start: 10/5/2009 End: 10/22/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/22/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours' Task Cc~de NPT Phase Description of Operations 10/8/2009 07:00 - 10:30 3.50 WHSUR P WHDTRE MINUTES. GOOD TEST. TEST THE TWC FROM BELOW TO 400 PSI LOW AND 1000 PSI HIGH FOR 10 MfNUTES. GOOD TEST. 10:30 - 12:00 1.50 WHSUR P WHDTRE CLEAR CELLAR OF ALL CAMERON BIEED OFF CONTROL LINES AND HANGER VOID TOOLS. BEGIN TO NIPPLE DOWN THE TREE. 12:00 - 13:30 1.50 WHSUR P WHDTRE FINISH NIPPLING DOWN THE TREE AND ADAPTER FLANGE. REMOVE FROM THE CELLAR. CHECK THE HANGER THREADS BY SCREWING IN THE CROSSOVER 11.5 TURNS. TOP HANGER THREADS ARE 3 1/2" 8RD EUE 13:30 - 20:00 6.50 BOPSU P WHDTRE NIPPLE UP THE 3' SPACER SPOOL, BOP'S, CHOKE HOSE, RISER, AND FLOW LINE. 20:00 - 00:00 4.00 BOPSU P WHDTRE RIG UP TO TEST THE BOPE. BEGIN 8Y TESTlNG THE ANNULAR WITH 3.5" TEST JT. TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH. GOOD TEST. TEST THE CHOKE MANIFOLD TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES EACH. GOOD TESTS. TESTS WITNESSED BY BP WSL CHRIS KOBUCK AND DOYON TOURPUSHER TOM SHONES. STATES RIGHT TO WITNESS THE TEST WAIVED BY AOGCC REP. CHUCK SCHEVE. 10/9/2009 00:00 - 04:00 4.00 BOPSU P WHDTRE FINISH TESTING THE CHOKE MANIFOLD AND ASSOCIATED EQUIPMENT WITH THE 3.5" TEST JOINT TO 250 PSI LOW AND 4000 PSI HIGH. GOOD TESTS. TEST THE LOWER 2 7/8" X 5" VBR AND UPPER 3 1/2" X 6" VBR TO 250 PSI LOW AND 4000 PSI HIGH WITH THE 3.5" AND 4.5" TEST JOINTS. GOOD TESTS. TESTS WITNESSED BY BP WSL CHRIS KOBUCK AND DOYON TOURPUSHER TOM SHONES. STATES RIGHT TO WITNESS THE TEST WAIVED BY AOGCC REP. CHUCK SCHEVE. 04:00 - 04:30 0.50 BOPSU P WHDTRE RIG DOWN BOP TESTING EQUIPMENT, CLEAN AND CLEAR THE FLOOR. 04:30 - 05:30 1.00 BOPSU P WHDTRE RIG UP THE LUBRICATOR AND PRESSURE TEST TO 500 PSI FOR 5 MINUTES. GOOD TEST. PULL THE TWC. 05:30 - 06:00 0.50 BOPSU P WHDTRE RIG DOWN THE LUBRICATOR , CLEAN AND CLEAR THE FLOOR. 06:00 - 07:00 1.00 PULL P DECOMP MAKE UP 3.5" 8 RND EUE CROSSOVER TO A JOINT OF DRILLPIPE AND SCREW INTO THE HANGER 11.5 TURNS. SCREW INTO THE TOP DRIVE AND PICK UP 130K BREAKING THE HANGER LOOSE. CONTINUE PICKING UP UNTIL THE HANGER IS ABOVE THE ROTARY TABLE. 07:00 - 10:00 3.00 PULL P DECOMP ESTABLISH CIRCULATION AND PUMP DOWN THE TUBING TAKING RETURNS THROUGH THE CHOKE MANIFOLD. CIRCULATED A SURFACE TO SURFACE (745 BBLS) CONTAINING A SOAP PILL. RETURNS STARTED OUT VERY OILY AND CLEANED UP AFTER THE SOAP PILL WAS BACK TO SURFACE. PUMPED 9 BBLS/MIN AT 1820 PSI. 10:00 - 11:00 1.00 PULL P DECOMP MONITOR THE WELL FOR 10 MINUTES. STATIC. LAYDOWN THE HANGER AND JOINT OF DRILLPIPE. CHANGE OUT THE ELEVATORS, RIG UP SCHLUMBERGER CONTROL LINE SPOOLER AND CASING TONGS. 11:00 - 00:00 13.00 PULL P DECOMP LAYDOWN 3.5" 92# TDS TUBING WITH CONTROL LINE ~~ P' Printed: 11/2/2009 2:54:30 PM ~ ~ BP EXPLORATION ` Page 3 of 11 Qperations Summary Report Legal Well Name: Z-25 Common Well Name: Z-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC Rig Name: DOYON 14 Date From - To ~ Hours Task ` Code 10/9/2009 I 11:00 - 00:00 I 13.001 PULL I P 10/10/2009 I 00:00 - 01:00 I 1.001 PULL I P 01:00 - 02:00 I 1.001 PULL I P 02:00 - 03:00 I 1.00 I DHB I P 03:00 - 06:00 I 3.001 DHB I P 06:00 - 06:30 0.50 FISH P 06:30 - 07:00 0.50 FISH P 07:00 - 10:00 I 3.001 FISH I P 10:00 - 12:30 ~ 2.50 ~ FISH ~ P 12:30 - 22:30 10.00 FISH P 22:30 - 00:00 1.50 FISH P 10/11 /2009 I 00:00 - 02:30 02:30 - 03:30 2.50I FISH ~ P 1.001 FISH I P Start: 10/5/2009 Rig Release: 10/22/2009 Rig Number: i4 Spud Date: 2/6/1989 End: 10/22/2009 PT Phase Description of Operations DECOMP FROM 10627' TO 8580'. PIPE AS VISUAL CORROSION ON IT AND PIN AND BOX ENDS LOOK GOOD. RIG DOWN CONTROL LINE SPOOLER. CONTINUE TO LAYDOWN 3.5" 9.2# TDS FROM 8580' TO 300'. DECOMP CONTINUE TO LAYDOWN 3.5" 9.2# TDS FROM 300' TO SURFACE'. RECOVERED A TOTAL OF 329 FULL JOINTS OF TUBING, 7 GLMS, 1 SSSV, 32 CLAMPS, 30 PINS AND 15.20' CUT JOINT FLARED TO 4 3/8". DECOMP CLEAN AND CLEAR THE FLOOR OF ALL THE CASING TOOLS. DECOMP PUT STEAM ON THE WELLHEAD AND PREPARE TO PULL THE PACK-OFF. PICK UP THE BAKER FISHING TOOLS. DECOMP WHEN BACKING OUT THE LDS THE CAMERON HAND NOTICED TENSION ON THE MANDREL PACK-OFF. HE RAN THE LDS BACK IN AND FLUSHED OUT THE OLD PACKING AND REPLACED IT WITH THE NEW PACKING. PLACED A 5000 PSI TEST FOR 30 MINUTES. GOOD TEST. CONSULTED WITH OUR ANCHORAGE TOWN ENGINEER WHO CONFIRMED TO NOT CHANGE OUT THE PACK-OFF. DECOMP INSTALL THE WEAR RING. DECOMP PICK UP BAKER FISHING TOOLS TO THE RIG FLOOR AND PREPARE THE MAKE THEM UP. DECOMP MAKE UP THE BAKER FISHING BHA CONSISTING OF THE FOLL WING ITEMS: -8.125" DOUBLE BOWL O.S. W/ HOLLOW MILL CONTAINER AND 8.375" GUIDE -6.25" BOWEN LUB. BUMPER SUB -6.25" OIL JAR -PUMP OUT SUB -XO SUB -4 STANDS OF 6.75" DRILL COLLARS -XO SUB -XO SUB DECOMP SLIP AND CUT THE DRILLING LINE. SERVICE AND INSPECT 7HE TOPDRIVE AND BLOCKS. REPLACED 2 SAFETY CABLES AND SERVICE THE CROWN. GREASE THE DRAW WORKS AND INSPECT THE PIPE SKATE. DECOMP SINGLE IN THE HOLE FROM THE PIPE SHED WITH 4" HT-38 DRILLPIPE TO 10569'. DECOMP ESTABLISH PAAAMETERS OF UP WT. 212K / DOWN WT. 163K / ROT. WT. 185K PUMPING AT 2 BPM WITH 90 PSI. K-ANCHOR FREE 3 TIMES. NO SUCCESS. WORK FROM 15 - 350 ~i THE OVERSHOT SEA~ ASSEMBLY FREE. NO SUCCESS. DECOMP JAR UP 325K WITH NO SUCCESS. ATTEMPT TO PUSH THE FISH DOWN WITH NO SUCCESS. CONSULT WITH THE ANCHORAGE TOWN ENGINEER AND DECISION WAS MADE TO RELEASE FROM THE FISH AND COME OUT OF THE HOLE. ROTATE OFF OF THE FISH AND RACK BACK ONE STAND. DECOMP PREFORM A POST JARRING INSPECTION OF THE DERRICK, TOP DRIVE AND DRAW WORKS. Printed: 11/2/2009 2:54:30 PM i ~ BP EXPLORATION Page 4 of 11 Operations Summary Report Legal Well Name: Z-25 Common Well Name: Z-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code N'PT 10/11/2009 I03:30 - 08:00 I 4.50 ~ FISH I P 08:00 - 10:00 I 2.001 FISH I P 10:00 - 10:30 I 0.50I FISH I P 10:30 - 11:00 0.50 FISH P 11:00 - 13:00 2.00 FISH P 13:00 - 13:30 0.50 FISH P 13:30 - 17:00 3.50 FISH P 17:00 - 20:00 3.00 FISH P 20:00 - 22:30 I 2.501 FISH I P 22:30 - 00:00 I 1.501 FISH I P 10/12/2009 I 00:00 - 01:30 I i.50I FISH ~ P 01:30 - 02:30 I 1.00 ~ FISH ~ P 02:30 - 08:00 ~ 5.50 ~ FISH ~ P 08:00 - 09:30 I 1.501 FISH I P Spud Date: 2/6/1989 Start: 10/5/2009 End: 10/22/2009 Rig Release: 10/22/2009 Rig Number: 14 Phase Description of Operations DECOMP MONITOR THE WELL FOR 15 MINUTES. STATIC. BEGIN TO PULL OUT OF THE HOLE FROM 10627' TO 34' RACKING , BACK 4" DRILLPIPE AND 6 3/4" DRILL COLLARS. DECOMP LAYDOWN THE FISH WHICH CONSISTS OF THE FOLLOWING: ~~~Ik -1 JT. 3.5" TDS TUBING 16.36' -1 X/O PUP 8RD X TDS 1.92' -1 X NIPPLE 1.20' -1 3.5" TOS PUP JOINT 10.08' -1 SEAL ASSEMBLY AND HANDLING PUP 20.71' DECOMP CLEAR THE FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPERATIONS. DECOMP PICK UP THE NEW FISHING BHA TO THE FLOOR. DECOMP MAKE UP THE NEW FISHING BHA TO MILL UP THE PACKER. -8.5" PRT ASSEMBLY W/ 4" PRT HYD. SPEAR GRAPPLE -4 7" BOOT BASKETS -BIT SUB -6.25" BOWEN LUB. BUMPER SUB -6.25" OIL JAR -PUMP OUT SUB -XO SUB -5 STANDS OF 6-3/4" DRILL COLLARS -XO SUB -6.25" BOWEN ACC. JAR -XO SUB DECOMP SERVICE THE TOP DRIVE, CROWN, AND DRAW WORKS. DECOMP RUN IN THE HOLE FROM 517' TO 10588" DECOMP ESTABLISH PARAMETERS OF UP WT. 220K / DOWN WT. 165K / ROT WT. 190K WITH 4K TORQUE AT 80 RPM. PUMPING AT 5 BPM WITH 920 PSI. SLACK OFF AND TAG TIGHT AT 10620'. MILL THROUGH THE TIGHT SPOT. WASH AND REAM THROUGH UNTIL CLEAN. DECOMP WASH DOWN AND TAG THE PACKER AT 10669'. ENGAGE THE GRAPPLE AND MILL THE PACKER FROM 10669' - 10672'. WOB 5-15K / 80 RPM AT 5 BPM W ITH 920 PSI. PUSH THE FISH TO 10680'. DECOMP FLOW CHECK THE WELL FOR 15 MINUTES. STATIC. PUMP 30 BBL HIGH VIS SWEEP SURFACE TO SURFACE (730 BBLS) AT 5 BPM WITH 850 PSI. DECOMP CONTINUE PUMPING SURFACE TO SURFACE (730 BBLS) AT 5 BPM WITH 850 PSI. DECOMP MONITOR THE WELL FOR 10 MINUTES. STATIC. RUN IN THE HOLE TO TAG THE 7" LINER TOP AT 10728'. CONFIRM FISH IS STILL CONNECTED. PULL OUT OF THE HOLE TO 9755' RACKING BACK THE DRILLPIPE. DROP THE PUMP OUT SUB DART AND PUMPED DOWN AT 4 BPM WITH 570 PSI. CONFIRMED THE PUMP OUT SUB OPENED BY PUMPING AT 4 BPM WITH 340 PSI. PUMP A DRY JOB. DECOMP PULL OUT OF THE HOLE FROM 9755' TO 45' RACKING BACK THE DRILI. PIPE. DECOMP BREAK OUT AND LAYDOWN THE BOOT BASKETS, BIT Printed: 11/2/2009 2:54:30 PM ! • BP EXPLORf~-TION Page 5 of 11 Operatians Summary Report ILegal Well Name: Z-25 ~Common Well Name: Z-25 Spud Date: 2/6/1989 Event Name: WORKOVER Start: 10/5/2009 End: 10/22/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/22/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operatiflns 10/12/2009 08:00 - 09:30 1.50 FISH P DECOMP SUB, BUMPER SUB, AND ATTEMPT TO CLEAN OUT THE BOOT BASKETS. THE BOOT BASKETS CONTAINED PIECES OF RUBBER AND METAL SHAVINGS FROM THE PACKER. 09:30 - 10:30 1.00 FISH P DECOMP PUNCH HOLES IN THE TAILPIPE AND LAY DOWN THE FISH. ~, ~ 10:30 - 11:30 1.00 FISH P DECOMP CLEAR THE FLOOR OF ALL THE TOOLS NOT CLEAN A NEEDED FOR UPCOMING OPERATIONS. 11:30 - 14:00 2.50 FISH P DECOMP RUN IN THE HOLE WITH THE 6 3/4" DRILL COLLARS AND PULL OUT OF THE HOLE WYING THEM DOWN. 14:00 - 15:00 1.00 FISH P DECOMP SERVICE THE TOP DRIVE, DRAW WORKS, IRON ROUGHNECK, AND OTHER VARIOUS RIG TOOLS. 15:00 - 18:00 3.00 FISH P DECOMP PICK UP CLEAN OUT/ 9.625" SCRAPER BH~ WHICH CONSISTS OF: -6.125" JUNK MILL -(4) 4.75" BOOT BASKETS -BIT SUB -4.75" OIL JARS -XO SUB -(6) 4J5" DRILL COLLARS -(9) 4" HWDP -(11) JTS. OF DRILL PIPE -XO SUB -DOUBLE PIN SUB -9.625" SCRAPER -BIT SUB -XO SUB 18:00 - 20:00 2.00 FISH C DECOMP SAFETY STAND DOWN DURING CONFERENCE CALL BETWEEN DOYON 14 RIG MANAGEMENT AND TOWN. 20:00 - 21:00 1.00 FISH P DECOMP CONTINUE TO RUN IN THE HOLE FROM 854' TO 3350'. RIG UP TO CIRCULATE WITH THE CEMENT LINE THROUGH A HEAD PIN. OPERATION DECLARED AT A SAFE POSITION TO SHUT DOWN FOR SAFETY STAND DOWN. 21:00 - 00:00 3.00 FISH C DECOMP SAFETY STAND DOWN WITH THE RIG CREW TO DISCUSS RECENT ACCIDENTS, CONTROL OF WORK, PEOPLE WORKING ALONE, TO GAIN ACCEPTANCE THAT "IT COULD HAPPEN TO ME." HAD THE HANDS WRITE DOWN INDIVIDUALLY THINGS THAT THEY FEEL WE NEED IN ORDER TO ALLOW THEM TO COMPLETE ALL THEIR JOBS SAFELY. ALSO GIVE US INPUT ON THEIR IDEAS OF HOW TO MAKE SAFETY BETTER ON DOYON 14. 70/13/2009 00:00 - 06:00 6.00 FISH C DECOMP SAFETY STAND DOWN WITH THE RIG CREW TO DISCUSS RECENT ACCIDENTS, CONTROL OF WORK, PEOPLE WORKING ALONE, TO GAIN ACCEPTANCE THAT "IT COULD HAPPEN TO ME." HAD THE HANDS WALK THROUGHOUT THE RIG AND LOOK FOR HAZARDS, THEN WRITE DOWN INDIVIDUALLY THINGS THAT THEY FEEL WE NEED IN ORDER TO ALLOW THEM TO COMPLETE ALL THEIR JOBS SAFELY. ALSO GIVE US INPUT ON THEIR IDEAS OF HOW TO MAKE SAFETY BETi'ER ON DOYON 14. 06:00 - 12:00 I 6.00~ FISH IC I IDECOMP ~CONTlNUE WITH THE SAFETY STAND DOWN FOCUSING Printed: 11/2/2009 2:54:30 PM ~ ~ BP EkPLORATfON Page 6 ofi 11 Qperations Summary Report Legal Well Name: Z-25 Common Welt Name: Z-25 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To ~ Hours Task Code NPT I 10/13/2009 I06:00 - 12:00 I 6.00 I FISH I C 12:00 - 00:00 ~ 12.00 I FISH I C 10/14/2009 I 00:00 - 12:00 I 12.00 I FISH I C Spud Date: 2/6/1989 Start: 10/5/2009 End: 10/22/2009 Rig Release: 10/22/2009 Rig Number: 14 Phase Description of Operations DECOMP ON RECENT ACCIDENTS, CONTROL OF WORK, PEOPLE WORKING ALONE, TO GAIN ACCEPTANCE THAT "IT COULD HAPPEN TO ME." HAD THE HANDS WALK THROUGHOUT THE RIG AND LOOK FOR HAZARDS, THEN WRITE DOWN INDIVIDUALLY THINGS THAT THEY FEEL WE NEED IN ORDER TO ALLOW THEM TO COMPLETE ALL THEIR JOBS SAFELY. ALSO CONTINUING TO CIRCULATE 10 BBLS AN HOURS DOWN THE DRILL PIPE TO PREVENT FREEZING UP. HOLD A MEETING WITH TEAM COMING ON TOUR TO GET THEIR THOUGHTS AFTER HAVING 12 HOURS TO THINK ABOUT OUR POSITION ON SAFETY AND THE EXPECTATIONS. DECOMP CONTINUE WITH THE SAFETY STAND DOWN. ALLOW THE RIG HANDS TO GATHER AND TALK AMONGST THEMSELVES AS WELL AS SHARE THEIR IDEAS WITH THE RIG MANAGEMENT TEAM. ALSO CONTINUING TO CIRCULATE 10 BBLS AN HOURS DOWN THE DRILL PIPE TO PREVENT FREEZING UP. DECOMP SAFETY STAND DOWN WITH THE RIG CREW TO DISCUSS RECENT ACCIDENTS, CONTROL OF WORK, PEOPLE WORKING ALONE, TO GAIN ACCEPTANCE THAT "IT COULD HAPPEN TO ME." HAD THE HANDS WALK THROUGHOUT THE RIG AND LOOK FOR HAZARDS, THEN WRITE DOWN INDIVIDUALLY THINGS THAT THEY FEEL WE NEED IN ORDER TO ALLOW THEM TO COMPLETE ALL THEIR JOBS SAFELY. ALSO GIVE US INPUT ON THEIR IDEAS OF HOW TO MAKE SAFETY BETTER ON DOYON 14. 12:00 - 00:00 I 12.00 I FISH ~ C 10/15/2009 100:00 - 12:00 I 12.001 FISH I C 12:00 - 00:00 I 12.001 FISH I C DECOMP CONTINUE HOIDING A SAFETY STAND DOWN THROUGHOUT OUR OPERATION. PULL ALL OF THE HANDS TOGETHER TO RE-DISCUSS THE "IT COULD HAPPEN TO ME" BULLET POINT. HAD SOME REALLY GOOD IDEAS THAT WILL BE SHARED WITH DOYON MANAGEMENT IN THE MORNING. HAD 3 CREW MEMBERS FROM RJ'S CREW ATTEND VINCE'S PRE-TOUR MEETING AND SHARE THE IDEA'S OF THEIR CREW. DECOMP CONTINUING WITH OUR SAFETY STAND DOWN. CONCENTRATING ON THE "IT COULD HAPPEN TO ME" BULLET POINT. ALLOWED THE RIG CREW TO DISCUSS AMONGST THEMSELVES AND WITH THE RIG MANAGEMENT TEAM. GREAT IDEAS ARE COMING FROM THIS. ALSO TALKED ABOUT WAYS TO RE-ENGAGE THE RIG CREWS IN THE PRE-TOUR MEETINGS. GREAT IDEAB FROM THE CREWS. DECOMP SAFETY STAND DOWN WITH THE RIG CREW TO DISCUSS RECENT ACCIDENTS, CONTROL OF WORK, PEOPLE WORKING ALONE, TO GAIN ACCEPTANCE THAT "IT COULD HAPPEN TO ME." HAD THE HANDS WALK THROUGHOUT THE RIG AND LOOK FOR HAZARDS, THEN WRITE DOWN INDIVIDUALLY THINGS THAT THEY FEEL WE NEED IN ORDER TO ALLOW THEM TO COMPLETE ALL THEIR JOBS SAFELY. ALSO GIVE US INPUT ON THEIR IDEAS OF HOW TO MAKE SAFETY BETTER ON DOYON 14. Printed: 11/2/2009 2:54:30 PM ~ ~ BP EXPLORATION Page 7 of 1'~ Qperations Summary Repart Legal Well Name: Z-25 Common Well Name: Z-25 Spud Date: 2/6/1989 Event Name: WORKOVER Start: 10/5/2009 End: 10/22/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/22/2009 Rig Name: DOYON 14 Rig Number: 14 Date Fram - To Hours Task Code NPT Phase - Deseription of Operations 10/15/2009 12:00 - 00:00 12.00 FISH C DECOMP 10/16/2009 00:00 - 00:00 24.00 FISH C DECOMP CONTINUING WITH OUR SAFETY STAND DOWN. CONCENTRATING ON THE "IT COULD HAPPEN TO ME" BULLET POINT. ALLOWED THE RIG CREW TO DISCUSS AMONGST THEMSELVES AND WITH THE RIG , MANAGEMENT TEAM. GREAT IDEAS ARE COMING FROM I THIS. ALSO TALKED ABOUT WAYS TO RE-ENGAGE THE '~ RIG CREWS IN THE PRE-TOUR MEETINGS. GREAT IDEAS ~ FROM THE CREWS. ATAPPROX. 19:30 BP FIELD SUPER ' INTENDENT OF RWO CONTACTED THE RIG WSL AND ', DOYON 14 WAS RELEASED TO RESUME OPERATIONS. DUE TO HAVING THE CHANGE OUT OF A RIG CREW TODAY WE HELD A 2 HOUR SAFETY MEETING WITH DOYON HSE, THE RIG CREW, TOURPUSHER, AND BP WSL TO VERIFY THAT EVERYONE ON THE CREW WAS ON BOARD WITH OUR NEW SAFETY STANDARDS AND HAD A CHANCE TO VOICE THEIR INPUT. RIG WORK WILL NOT RESUME UNTIL 00:00. CONTACTED THE SERVICE COMPANIES AND THE AOGCC TO INFORM THEM THAT THE RIG WAS RELEASED BACK TO WORK. 10/17/2009 00:00 - 02:00 2.00 CLEAN C DECOMP REVIEW THE NEW DOYON SAFETY GUIDELINES AND CONTINUE TO PUMP 106BLS/HR TO KEEP FROM FREEZING UP. 02:00 - 02:30 0.50 CLEAN P DECOMP PJSM, SERVICE THE TOP DRIVE, CROWN, AND DRAW WORKS. 02:30 - 04:00 1.50 CLEAN P DECOMP PJSM, SLIP AND CUT 60' OF DRILLING LINE. PREPARE FLOOR FOR PULLING OUT OF THE HOLE. 04:00 - 06:00 2.00 CIEAN P DECOMP PULL OUT OF THE HOLE RACKING BACK THE 4" DRILL PIPE, HWDP, AND DRILL COLLARS. LAYDOWN THE FISHING BHA ON THE BEAVER SLIDE. 06:00 - 07:30 1.50 CLEAN P DECOMP REMOVE THE WEAR RING, INSTALL THE TEST PLUG AND 4" TEST JOINT. RIG UP THE TEST CHART AND CLEAR THE FLOOR OF ALL UN-NEEDED TOOLS. 07:30 - 09:30 2.00 CLEAN N DECOMP WAIT ON THE AOGCC REP. TO WITNESS THE TEST. ~ 09:30 - 16:00 6.50 CLEAN P DECOMP BEGIN BY TESTING THE ANNULAR WITH 4" TEST JT. TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH. GOOD TEST. TEST THE CHOKE MANIFOLD TO 250 PSI LOW AND 4000 PSI HIGH FOR 5 MINUTES EACH. GOOD TESTS. TEST THE LOWER 2 7/8" X 5" VBR AND UPPER 3 1/2" X 6" VBR TO 250 PSI LOW AND 4000 PSI HIGH WITH THE 4" AND 4.5" TEST JOINTS. GOOD TESTS. TESTS WITNESSED BY BP WSL RICHARD BORDES AND DOYON TOOLPUSHER NICK MARMON. STATES RIGHT TO WITNESS THE TEST WAIVED BY AOGCC REP. LOU GRIMALDI. 16:00 - 16:30 0.50 CLEAN P DECOMP RIG DOWN THE TEST EQUIPMENT AND BLOW DOWN THE CHOKE MANIFOLD. REMOVE THE TEST PLUG. 16;30 - 17:00 0.50 CLEAN P DECOMP INSTALL THE WEAR BUSHING. 17:00 - 17:30 0.50 CLEAN P DECOMP INSPECT AND SERVICE THE TOP DRIVE AND DRAW WORKS. 17:30 - 18:00 0.50 CLEAN P DECOMP PICK UP CLEAN OUT / 9.625" SCRAPER BHA WHICH CONSISTS OF: -6.125" JUNK MILL Printed: 11/2/2009 2:54:30 PM ~ ~ BP EXPLORATION Page 8 of 11' Operations Summary Report Legal Well Name: Z-25 Common Weli Name: Z-25 Spud Date: 2/6/1989 Event Name: WORKOVER Start: 10/5/2009 End: 10/22/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/22/2009 Rig Name: DOYON 14 Rig Number: 14 Date Fram - To Hours Task Cade NPT Phase Description of Operations 10/17/2009 17:30 - 18:00 0.50 CLEAN P DECOMP -(4) 4.75" BOOT BASKETS -BIT SUB -4.75" OIL JARS -XO SUB -(6) 4.75" DRILL COLLARS -(9) 4" HWDP -(11) JTS. OF DRILL PIPE -XO SUB -DOUBLE PIN SUB -9.625" SCRAPER -BIT SUB -XO SUB 18:00 - 21:00 3.00 CLEAN P DECOMP RUN IN THE HOLE ON 4" DRILL PIPE TO 10580'. 21:00 - 22:30 1.50 CLEAN P DECOMP RIG UP AND TEST THE 9.625" CASING TO 4000 PSI FOR 30 22:30 - 23:30 I 1.00 I CLEAN I P 23:30 - 00:00 I 0.50I CLEAN ~ P 10/18/2009 100:00 - 06:00 I 6.001 CLEAN I P 06:00 - 08:00 I 2.00 I CLEAN I P 08:00 - 10:30 ~ 2.50 ~ CLEAN ~ P 10:30 - 11:30 I 1.00 I CLEAN I P 11:30 - 12:00 0.50 CLEAN P 12:00 - 13:00 1.00 CLEAN P DECOMP CONTINUE IN THE HOLE TO 10728' AND ESTABLISH PARAMETERS. UP WT. 190K / DOWN WT. 155K. ENTER THE 7" LINER TOP AT 10728' AND CONTINUE IN THE HOLE UNTIL TAGGING ON SAND AT 11025'. CONTINUE IN THE HOLE MILLING/WASHING DOWN AT 60 RPM WITH 5K TQ PUMPING AT 5.5 BPM WITH 770 PSI. DECOMP DRILL CEMENT / WASH DOWN FROM 11025' TO 11053' AT 60 RPM WITH 5K TQ PUMPING AT 5.5 BPM WITH 770 PSI WORKING UP T0 7 BPM WITH 1200 PSI. DECOMP DRILL CEMENT / WASH DOWN FROM 11053' TO 11247'. CEMENT WASH MIXED IN WITH SAND THROUGHOUT THE AREA. THERE WERE NO PLACES OF VERY THICK CEMENT, BUT DID SEE IT COMING BACK OVER THE SHAKERS. PUMPED A HI-VIS SWEEP SURFACE TO SURFACE (8300 STKS) AND SAW A LARGE AMOUNT OF CEMENT, FRAC SAND, AND PIECES OF RUBBER. DRILLED/ WASHED DOWN AT 60 RPM WITH 5K TQ PUMPING AT 7 BPM WITH 1200 PSI. CIRCULATED SURFACE TO SURFACE AT 10 BPMS WITH 2340 PSI. MILU WASH DOWN FROM 11247' TO 11510'. TOOK 10K AT 11502' AND MILLED TO 11510'. DECOMP PUMP A HI-VIS SWEEP AT 10 BPM WITH 2200 PSI ROTATING AT 100 RPM. WORKED THE PIPE SEVERAL TIMES BUT IT TORQUED UP AND STALLED OU7, ATTEMPTED WITHOUT ROTATING AND IT RAN IN THE HOLE GOOD TO 11474'. STARTED TO TAKE WT. AT 11474' AND WORKED IT BACK DOWN TO 11510'. DECOMP MONITOR THE WELL FOR 10 MINUTES. STATIC. ATTEMPT TO LAY DOWN THE DRILL PIPE BUT AFTER 3 JTS. IT BEGAN TO HAVE OVERPULL. PUMPED OUT TO THE 7" LINER TOP AT 11728' BUT CONTINUED TO SEE OVERPULL. DECOMP CIRCULATE DOWN FROM 10674' TO 10769' PUMPING A HI-VIS SWEEP ACROSS THE 7" LINER TOP. ROTATING AT 40 RPM, 7K TQ, AT 10 BPM AT 2360 PSI. DECOMP RUN IN THE HOLE FROM 10769' TO 11263'. DECOMP TIGHT SPOT AT 11263'. WASH DOWN 1 STAND BUT UNABLE TO WORK THE PIPE WITHOUT THE PUMP, 3'' 0 ~ Printed: 11/2/2009 2:54:30 PM ~ ~ BP ExPLORATION Page 9 of 11 Operations Summary Report Legal Well Name: Z-25 Common Well Name: Z-25 Spud Date: 2/6/1989 Event Name: WORKOVER Start: 10/5/2009 End: 10/22/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/22/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase ! Description of Operations 10/18/2009 12:00 - 13:00 1.00 CLEAN P DECOMP CONTINUE TO WASH DOWN TO 11510' AT 4 BPM WITH 700-900 PSI. SHOWED SIGNS OF PACKING OFF EVERYTIME WE TURNED THE PUMPS ON. 13:00 - 16:00 3.00 CLEAN P DECOMP BREAK CIRCULATION AT 40 RPM WTIH 8K TQ WHILE PUMPING A HI-VIS SWEEP AT 12 BPM WITH 3000 PSI. SAW RETURNS OF LARGE QUANTITIES OF FRAC SAND FROM THE SWEEP. PUMP A SECOND HI-VIS SWEEP SEEING LARGE QUANTITIES OF FRAC SAND BACK TO THE SURFACE AGAIN. RACK BACK A STAND AND OBSERVE THE WELL FOR 10 MINUTES. STATIC. SAW TIGHT SPOT AT 11465'. 16:00 - 17:00 1.00 CLEAN P DECOMP TRIP OUT OF THE HOLE FROM 11510' - 10678'. 17:00 - 19:30 2.50 CLEAN P DECOMP PUMP 2 HI VIS SWEEP SURFACE TO SURFACE 100 BBLS APART AT 14.5 BPM WITH 3600 PSI. SAW LESS SAND THAN BEFORE, BUT STILL SEEING FRAC SAND COMING OVER THE SHAKERS. 19:30 - 20:30 1.00 CLEAN P DECOMP TRIP IN THE HOLE FROM 10678' TO 11510' WITH UP WT. 220K / DOWN WT. 170K. 20:30 - 21:30 1.00 CLEAN P DECOMP PUMP A HI-VIS SWEEP AT 40 RPM ANO 13 BPM WITH 3100 PSI. SAW SMALL AMOUNTS OF FRAC SAND BACK TO SURFACE. 21:30 - 22:00 0.50 CLEAN P DECOMP TRIP OUT OF THE HOLE FORM 11510' - 10678'. DID NOT SEE ANY OVERPULL OR DRAG. 22:00 - 23:30 1.50 CLEAN P DECOMP PUMP A HI- VIS SWEEP AT 40 RPM WITH 8K TQ AT 12 BPM WITH 3000 PSi. SAW A SMALL QUANTITY OF FRAC SAND AT SURFACE. MONITOR THE WELL FOR 10 MINUTES. STATIC. 23:30 - 00:00 0.50 CLEAN P DECOMP RIG UP AND PREPARE TO TRIP OUT OF THE HOLE LAYING DOWN THE 4" DRILL PIPE. 10/19/2009 00:00 - 00:30 0.50 CLEAN P DECOMP SERVICE THE TOP DRIVE, DRAW WORKS, AND CROWN. 00:30 - 09:30 9.00 CLEAN P DECOMP BEGIN TRIPPING OUT OF THE HOLE FROM 10678' TO 33' LAYING DOWN THE 4" DRILL PIPE. 09:30 - 10:00 0.50 CLEAN P DECOMP LAY DOWN THE 4.75" JARS, BIT SUB, HWDP, BOOT BASKETS AND JUNK MILL. BOOT BASKETS WERE FULL OF 20X40 PROPET. 10:00 - 10:30 0.50 CLEAN P DECOMP CLEAR THE FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPERATIONS. 10:30 - 12:00 1.50 RUNCO RUNCMP PULL THE WEAR BUSHING AND RIG UP TO RUN 4.5" TCII COMPLETION. 12:00 - 12:30 0.50 RUNCO P RUNCMP INSPECT THE TOP DRIVE, BLOCKS, CROWN, AND DRAW WORKS. 12:30 - 14:00 1.50 RUNCO P RUNCMP RIG UP THE POWER TONGS, AIR SLIPS, AND TORQUE TURN EQUIPMENT. 14:00 - 00:00 10.00 RUNCO RUNCMP RUN 4.5" TCII 12.6#. L-80 COMPLETION CONSISTING OF: - 4.5"WLEG - 4.5" XN NIPPLE W/ RHC-M PLUG - 3 JTS. OF 4.5" TCII L-80 TUBING - 4.5" X NIPPLE - 9.625" X 4.5" HES TNT PACKER - 4.5" X NIPPLE - 180 JTS. OF 4.5" TCII L-80 TUBING ALL CONNECTIONS BELOW THE PACKER WERE BAKERLOK'D AND TORQUED TO OPTIMUM TORQUE OF Printed: 11/2/2009 2:54:3o PM • • BP EXPLORATION Page 10 of 11 Operations Summary Repor~ Legal Well Name: Z-25 Common Well Name: Z-25 Spud Date: 2/6/1989 Evenf Name: WORKOVER Start: 10/5/2009 End: 10/22/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/22/2009 Rig Name: DOYON 14 Rig Number: 14 ~ Date From - To Hours Task Gode NPT Phase Description of Operations 10/19/2009 14:00 - 00:00 10.00 RUNCO RUNCMP 3850 FT/LBS. JET LUBE SEAL GUARD WAS USED ON ALL CONNECTIONS ABOVE THE PACKER. 10/20/2009 ~ 00:00 - 07:00 I 7.00 07:00 - 11:30 4.50 RUNCO 11:30 - 14:00 2.50 RUNCO 14:00 - 16:00 2.00 RUNCO 16:00 - 19:00 3.00 RUNCO 19:00 - 21:00 2.00 BOPSU P 21:00 - 23:00 2.00 BOPSU P 23:00 - 00:00 1.00 BOPSU P 10/21 /2009 00:00 - 03:30 3.50 W H SU R P 03:30 - 06:00 2.50 WHSUR P 06:00 - 00:00 I 18.001 WHSUR I N RUNCMP CONTINUED IN THE HOLE WITH THE REMAINDER OF T E COMPLETION CONSISTING OF: . 4.5" TCII L-80 TUBING - 4.5" X NIPPLE - 48 JTS. OF 4.5" TCII L-80 TUBING - CAMERON SSH 13" X 4.5" TCII TOP AND BOTTOM THREADS DX-2 MS/CCL TUBING HANGER ALL JOINTS WERE TORQUED TO OPTIMUM TORQUE OF 3850 FT/LBS AND JET LUBE SEAL GUARD WAS USED ON ALL CONNECTIONS. - FINAL UP WT. 163K / DOWN WT. 130K - RILDS RUNCMP PJSM. REVERSE CIRCULATE 160 BBLS OF CLEAN SEAWATER, 560 BBLS OF CLEAN SEAWATER WITH CORROSION INHIBITOR AT 3 BPM / 230 PSI. RUNCMP PJSM. R/U LRS LINES TO PUMP DIESEL FREEZE PROTECT. P!T HOSE TO 3,500 PSI. PUMP 160 BBLS OF 60 DEG DIESEL DOWN IA WITH FINAL CIRCULATING PRESSURE OF 2 BPM / 400 PSI. RUNCMP ALLOW WELLTO EQUALIZE AND U-TUBE DIESEL FROM IA TO TUBING FOR 1.5 HRS. RUNCMP DROP BALL AND R~D AND ALLOW TIME TO FALL. SF~T PACKER AND TEST TUBING TO 4.000 PSI FOR 30Jv11N (PACKER SET AT 2,100 PSI). BLEED DOWN TO 1,500 PSI. TEST IA TO 4,000 PSI FOR 30 MIN - PASSED. CHARTED BOTH TESTS. BLOW DOWN LINES AND UD LANDING JOINT. RUNCMP PJSM. P/U DRY ROD AND SET TWC WITH CAMERON TECH. UD DRY ROD. TEST FROM ABOVE TO 4,000 PSI FOR 10 MIN - PASSED. BIOW DOWN ~INES AND VAC OUT STACK. RUNCMP PJSM. ND ~OPE AND SET IN STAND. L~(D MOUSE HOLE. R/D FLOWLINE AND HOLE FILL LINES. UD SPACER SPOOL. RUNCMP CLEAN HANGER AND PREP CELLAR FOR TUBING ADAPTER AND SPOOL. PJSM WITH CAMERON. RUNCMP CREW CHANGE. PRE-TOUR CHECKS. PJSM WITH CAMERON. NU ADAPTER FLANGE. NU TREE. TEST HANGER VOID WITH CAMERON TO 5,000 PSI FOR 30 MIN - PASSED. RUNCMP TEST TREE WITH DIESEL TO 5,000 PSI FOR 5 MIN, NO LEAKS - PASSED. REMOVE DOUBLE ANNULUS VALVE. INSTALL GAUGES AND JEWLERY ON TREE AND ANNULUS PORTS. REMOVE INTREGAL FLANGE ON WING VALVE AND INSTALL PORTED BLIND FLANGE. SECURE CELLAR, SHUT TREE AND ANNULUS VALVES. WAIT RUNCMP WAITING ON WEATHER. PHASE 2 ON ROADS AND ACCESS PADS. SHUT DOWN OPERATIONS FROM MOVING RIG. WELL SECURE AND TREE N/U AND TESTED. WIND GUSTING TO 44 MPH. Printed: 11/2/2009 2:54:30 PM , ~ ~ BP EXPLORATION Page 11 of 11 Operations Summary R~part Legal Well Name: Z-25 Common Well Name: Z-25 Spud Date: 2/6/1989 Event Name: WORKOVER Start: 10/5/2009 End: 10/22/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 10/22/2009 Rig Name: DOYON 14 Rig Number: 14 Date From - To ~ Hours Task Code NPT Phase Description of Operations 10/22/2009 100:00 - 15:00 15.00 WHSUR N WAIT RUNCMP CONTINUE TO WAIT ON PHASE 2 CONDTIONS TO CEASE CONDUCT TABLE TOP DRILLS. LIMIT ALL WORK TO SCRUBBING AND SMALL PROJECTS. COMPLETE ALL TASK HAZARD ANALYSIS FOR EACH TASK. ELIMINATE ANY WORK OUTSIDE EXCEPT FOR BUDDY ENVIRONMENTAL WALKAROUNDS. WIND GUSTING UP TO 48 MPH. , 15:00 - 19:00 4.00 RIGD P POST PHASE 2 CONDITIONS LIFTED TO PHASE 1. COORDINATE W ITH HEAVY EQUIPMENT TO ASSIST IN RIG MOVE. HEAVY EQUIPMENT STILL BLOWN IN AFTER PHASE CONDITIONS. RIG DOWN UNIT AND PREPARE RIG FLOOR TO SKID RIG FLOOR. DISCONNECT ROCKWASHER. 19:00 - 21:00 2.00 RIGD P POST SKID RIG FLOOR AND PREPARE RIG TO MOVE OFF WELL SLOT. 21:00 - 22:00 1.00 RIGD P POST MOVE RIG OFF WELL SLOT WITH WSL AND PAD-OP WITNESS. RIG MADE CONTACT WITH TOE BOARD ON WELL HOUSE ROOF. ALL NOTIFICATIONS MADE. PAD-OP CALLED OUT TO INSPECT. DAY WSL NOTIFIED RWO MANAGER. 22:00 - 00:00 2.00 RIGD P POST MOVE RIG OFF WELL SLOT. MOVE TO EDGE OF PAD TO PREP FOR TAKING OUT BOP STACK AND INSTALLING BOOSTER WHEELS. RIG RELEASED AT 2400 HRS ON 10-22-09. Printed: 11/2/2009 2:54:30 PM TREE _ ' MCEV OY W~LLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV - . 91.45' BF. ELEV - 55.05' KOP = 3201' Max Angle = 52 @ 8973' Datum MD = 11384' Datum ND = 8800' SS ~ ~~ ~ ~~ ~~~~~ SAFETY ES: JUNK: APPROX 280 STRIP (~1N CHARGE~(S LEFT IN HOLE DURING 11 /18/90 PERFng. EQUATES TO APPROX 2' OF FlLL IN 7" Z-25 ` LNR. MADE OF STEEL (BELL) 2081' ~~4-1!2"' HES X NIP, ID = 3.812" 13-3/8" CSG, 68#, L-80, ID = 12.415" [CtICYilIC~1IQ=~.~s~'~ ""'~~,7~r'.,J'~ 4-"112" XN NIPPLE 10515~ 4-1/2" NES X i~IP, ID = 3.812„ 10551' -~ 9-5i8" X 4-9l2" HES TNT PKR, ID = 3.903" ') U592' 4-112"` HES X NIP, Id = 3.812" TOP OF 7" LNR 10728• °~ ~~~~` ~~-112" NES XN N1P, ID = 3.725" 4-1l2" TBG, 12.6#, L-84. TC-IE, .0162bpf, ID = 3.958" '1Q7$2" '~07$2` 4-1;2" WLEG, ID = 3.958„ 9-5/8" CSG, 47#, L-80, ID = 8.681" 10986~ PERFORATION SUMMARY REF LOG: CET ON 03/19/89 ANGLE AT TOP PERF: 41 @ 11434' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 11380 - 11412 S 07/27/98 2-1/8" 6 11434 - 11440 S 07/27/98 2-1/4" 6 11434 - 11448 O 01/03/05 2-1/8" 4 11434 - 11463 O 08/17/98 2-1/2" 6 11440 - 11463 O 08/02/98 2-114" 12 11448 - 11454 O 01/03/05 2-1/4" 6 11454 - 11508 O 01/03/05 2-1/8" 6 11460 - 11490 S 07/27/98 2-1/8" 4 11500 - 11550 S 07/27/98 PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 7" MARKER JOIMf 11455~ FISH- X-LOCK CATCHER SUB LEA KEY (02/07/01) 11730~ FISH -PERFING CHARGE DISC (11/18/90) 11480~ FISH- 15" X 1" X 1/4" STEEL. SHEATH FOR BOWSPRING (08/17/98) DATE REV BY COMMENTS DATE REV BY COMMENTS 03/04/89 DGH ORIGINAL COMPLETION 70/22/09 D14 RWO 10/27/09 SV DRLG HO CORRECTIONS PRUDHOE BAY UNff WELL: Z-25 PERMff No: ~1881590 API No: 50-029-21902-00 SEC 19, T11 N, R12E, 721' SNL & 3143' WEL BP Exploration (Alaska) Alaska Drilling and Wells Safe~tand Down • Page 1 of 2 Maunder, Thomas E (DOA) From: Hobbs, Greg S (ANC) [Greg.Hobbs@bp.com] Sent: Thursday, October 15, 2009 4:55 PM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel Subject: RE: Alaska Drilling and Wells Safety Stand Down ~~~~5`A~.~~~,~ 1 ~r!tl',/ ~ `~ ~~~~,~a ~ _ Tom- l~"s-i~~ Doyon 14 - Z-25 - Operations shut down at 21:00 hours on 10/12/09. Cement Plug in place at 11,032'. Clean-out BHA hung off from floor to 3350' with circulation through the cement line whiie the shut-down is ongoing. Doyon 16 - Q-04A Had just tested BOP's and were preparing to pull tubing when~operations were shut down. Two way check installed in tubing and tested. Kill lines blown down. Begin stand down at 22:30 on 10/12/2009. Nordic 1- 06-18A Finish logging run of newly run and cemented liner. Clear floor, Jet Stack, begin Stand Down at midnight, 10/12/09. Nordic 2- H-05B Drill to 13,795' MD. Trip for bit. Test BOP's. Begin safety stand-down at 15:45 hours 10/14/09. Fill hole every six hours with a loss rate of 1 barrel per hour. Nabors 4es - Move to MPL-29. Incident occurred at approximately 12:00 hours on 10/10/09. Begin Safety Stand-down at 12:30 p.m. Still rigging up at time of incident. Rig over well, pits full, no wellwork started. Nabors 7es - L-223 7" casing run and cemented. Emergency slips set with pack-off. NU BOP. Test casing spool to tubing spool flange to 5000 psi and FMC pack-off with hand test pump. Change rams from 7" to VBR's, test. Freeze protect OA. Begin Stand Down at 0900 Hours 10/14/09. Nabors 9es - S-218 Currently finishing up running and cementing 7" longstring. Freeze protect OA. Anticipated start of Safety Shut-down- 10:00 hours 10/15/09. Hope that will suffice. Sorry about the delay- the computer has been acting up today- Thanks and don't hesitate to get back with me if you need more information- Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, October 15, 2009 11:15 AM To: Hobbs, Greg S (ANC) Cc: Schultz, Mikel; DOA AOGCC Prudhoe Bay; Regg, James B(DOA); Aubert, Winton G(DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C(DOA); Davies, Stephen F(DOA); Roby, David S(DOA) Subject: RE: Alaska Drilling and Wells Safety Stand Down Greg, Thanks for the information. Unfortunate that events have prompted this significant response. You indicate that the stand downs began with the wells at a"safe place" which is appropriate. With the wells secure and no 10/20/2009 Alaska Drilling and Wells Safe~tand Down ~ Page 2 of 2 operations taking place, the need to accomplish BOP tests on the proscribed time interval is not necessary. You are correct that where the test time intervals have been exceeded that the BOP test will need to be accomplished as the first order of business when operations are resumed. For our records, would you please provide a summary of the wells associated with each rig and the wellbore conditions at the time of SD? Keep us informed as operations are resumed. Please call or message with any questions. Tom Maunder, PE AOGCC From: Hobbs, Greg S (ANC) [mailto:Greg.Hobbs@bp.com] Sent: Thursday, October 15, 2009 11:04 AM To: Maunder, Thomas E (DOA) Cc: Schultz, Mikel Subject: Alaska Drilling and Wells Safety Stand Down Tom- To follow up on our phone conversation yesterday, ADW is taking a safety stand down after a high potential incident over the weekend (Saturday) on Nabors 4es. Nabors 4es has been shut down since this event, Nabors 7es went down yesterday, and Nordic 1 and 2 and Doyon 14 and 16 started their stand-downs at a point in between. Nabors 9es is starting its stand-down today. This last incident, and our current safety statistics have created significant concern for ADW management that our current safety culture is not in the place it needs to be. The directive from Steve Robinson is that the stand down be used to address gaps in our safety culture that have allowed 50% of the incidents that have occurred to happen to employees with five years of experience or less. Of these incidents, 40% have occurred with employees working alone. By having every contractor and rig come up with a plan to address these issues, ADW management expects that occurrence of events at the top of the pyramid will be pushed out further into the future. Steve Robinson has asked that plans be presented to him, and they wilf require his approval. This stand down is unique in that each rig has shut down at a safe point, and there is no planned end time. Start-up on a rig by rig basis is dependent on contractors providing a plan that immediately adresses the above statistics which should defer more significant events. The plan also needs to address longer term changes to embed behaviors that will make a significant change in our current safety culture The reason for this mail is to make you aware that BOP tests could go beyond their timing requirements during the stand down. If this is the case, they wi(I occur as the first operation following ADWE managemenYs approval for a rig to re-start operations. We wanted to make you aware of this potential issue, and appreciate your support, and management wants everyone focuesd on their safety plans, not operations at this time. If you have any questions, feel free to get back with me. Thanks- Greg Hobbs 10/20/2009 . BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 4~~~~~~~~ ` ~~{~'~r ~ ~ ~L~J~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, ~ bp ~~~~~~~~ OCT 0 5 2009 ~l~ska Dii ~ Gas Cons. Cort~~~~4~ Anchota~e ~ g ~- ~~~ ~--` ~'"`~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ i BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900100 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-O6 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-O8A 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670100 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 500292t9860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 50029219770000 NA 12 NA 8.50 7/26/2009 Z-13A 2042030 50029220690t00 NA 3.6 NA 24.66 7/26/2009 Z-14B 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-is 1890960 50029219710000 NA 02 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7l26/2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-22B 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-23B 2041080 50029219500200 NA 0.3 NA 1.70 7/23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA 1.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 500292t8790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 tVA 0.3 NA 3.40 7/26/2009 Z-328L1 1970350 500292t9246000 NA 02 NA t.70 7/25/2009 Z-33A 1890050 50029218950100 NA 0.5 NA 3.40 S/S/2009 Z-35 1980930 50029228840000 NA 1.3 NA 11.50 7/4/2009 Z-3s 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-100 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 10.20 7/23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 10.20 7/25/2009 Z-108 2052010 50029232920000 NA 1.5 NA t 1.90 7/24/2009 Z-112 2071720 50029233a0000o NA surface NA ~ • ~~~ _ ~ ~vz~ ~~~ ~~~ ~.. ~a ~ ~ ~ ~ . SEAN PARNELL, GOVERNOR Mr. David Reem Engineering Team Leader BP Exploration (Alaska), Inc. `'S P.O. Box 196612 ~ ~ ~ Anchorage, AK 99518-6612 $ ~ . ...._ ~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z-25i Sundry Number: 309-253 1 ~ `_„ ~'t~~j ~ '~° ~~~%;~ Dear Mr. Reem: ::°~t~~~~~~=~°' R Enclosed is the approved Application for Sundr~,,~ Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considerEd timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair ~ DATED thi~ ~ day of July, 2009 Encl. ~,- .o~ ~V' ~ STATE OF ALASKA ALP~ OIL AND GAS CONSERVATION COM~ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 -~~~ ~-fiT ~0~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ~~ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ~ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 188-159 `~ 3. Address: -~ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21902-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU Z-25i - Spacing Exception Required? ^ Yes ~ No 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): ADL 028262 ~ 91.50 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12• PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11800 - 9210 ~ 10754 8427 10754' -11455 a in en h iz MD ND Burst Ila s ru ral n or 11 ' " 11 ' 110' 14 470 urface 2649' 1-3/8" 2649' 2649' 4930 2270 I ermediate Pr i n 10 86' 9-5/ " 1 86' S' 70 476 Liner 1072' 7" 10728' - 1180 ' 8408' - 9210' 7240 5410 PerForation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft}: Below Pluq 11380' - 11550' 8888' - 9016' 3-1/2", 9.2# L-80 10766' Packers and SSSV Type: 9-5/8" x 3-1/2" TIW packer Packers and SSSV MD (ft): 10677' 13. Attachments: 14. Well Class after proposed work: ~ Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: September 15, 2009 ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ~ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Biork, 56a-5683 Printed fVame id Reem Title Engineering Team Leader Prepared By NameMumber Signature Phone 564-5743 Date ~ j2~J Sondra Stewman, 564-4750 Commission Use Onl Sundry Number: ~_ ' J3 Conditions of approval: Notify Commission s that a representative may witness ^ Plug Integrity ld'BOP Test lldMechanical Integrity Test ^ Location Clearance other. '~OQU ~ s~ a~ P Te.r f' ~ Z$DO pS~ rn~rt ~Q n n•,..lq.M /es-~' Subsequent Form Required: j p- Y O'~{ APPROVED BY / G ~ A roved B~ COMMISSIONER THE COMMISSION Date L Form 10-403 Revised 06/2066 ,~ ~'.~ ~ ~ i R '~ ~ ~ ~....._ . AI`~ P...rn ~ u'i14 F~ " t,~JR/~ Submit In Duplicate ~~ ~/~~~ ~ 7/2 S/ a k ~~ ~ ~ ~~ Z-25i Expense Rig Workover • Scope of Work: Pull 3-1/2" completion, mill and retrieve 9 5/8" x 3-1/2" TIW packer, clean out to ~11,600', change out 9-5/8" pack-offs, run 4-'h" L-80 tubing with Baker S-3 packer set at ~10,600' MD. MASP: 2,857 psi Well Type: WAG Injector Estimated Start Date: September 15, 2009 Production Engineer: Dan Robertson Intervention Engineer: David Bjork Pre-Riq Prep Work: F 1 MIT-OA to 1,000 si CMIT-TxIA to 4,000 si. E 4 Power Jet cut 3-1/2" L-80 tubing (~10,630') near the middle of the 1S full joint above the TIW acker. Reference tubin tall dated 03/03/89 F 5 Circulate well with seawater and diesel freeze protect thru the cut. CMIT TxIA to 4,000 si. W 6 Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. W 7 Set a BPV in the tubin han er. O 8 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU Doyon 16. ND tree. NU and test BOPE pipe rams to 4,000 psi. Test annular preventer to 3,500 psi. Circulate out freeze protection fluid and circulate well to seawater through the cut. 2. Retrieve 3-1/2" tubing string down to the tubing cut. 3. Mill & retrieve 9 5/8" x 3-1/2" TIW Packer at 10,677' MD. 4. Clean out to ~11,600' and change 9-5/8" casing pack-offs. 5. Run 4-~h" L-80 TC-II tubing with Baker S-3 packer set at ~10,670' MD. 6. Displace the IA to packer fluid, freeze protect to 2,200' MD. 7. Set the packer, test tubing and IA to 4,000 psi. . 8. Set BPU. ND BOPE. NU and test tree. RDMO. TR~ = MCEV OY WELLHEAD = MCEVOY ACTUATOR = OTIS KB. E1EV = 91.45' BF. ELEV = 55.05' KOP = 3201' Max Angle = 52 @ 8973' Datum N~ = 11384' Datum ND = 8800' SS 13-3/8" CSG, 68#, L-S0, ID = 12.415" SAFETY OTES: JUNK: APPROX 280 STRIP GUN CHAR~ISKS LEFT IN HOLE DURING 11/18/90 PERFng. EQUATES TO APPROX 2' OF FlLL IN 7" LNR MADE OF STEEL (BELL) 2092' 3-1/2" OTIS SSSV LAND NIP, ID = 2.75" • Z-25 ' ~ GAS LIFT MANDR~S ST MD ND DEV TYPE VLV LATCH PORT DATE 7 3008 2915 3 CAM •"DMY RK 0 11/17/07 6 5896 5166 49 CAM *"DMY RK 0 11/17/07 5 7872 6497 48 CAM '"DMY RK 0 11/17/07 4 9033 7229 51 CAM DMY RK 0 01/20/06 3 9784 7697 51 CAM •"DMY RK 0 11/17/07 2 10472 8137 47 CAM DMY RK 0 01/20/06 1 10594 8221 45 CAM "'DMY RK 0 11/17/07 Minimum ID = 2.750" @ 2092' 3-1/2" OTIS SSSV NIPPLE TOP OF 7" LNR 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 9-5l8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY R~ LOG: CET ON 03/19/89 ANGIE AT TOP PERF: 41 @ 11434' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 11380 - 11412 S 07/27/98 2-1/8" 6 11434 - 11440 S 07/27/98 2-1 /4" 6 11434 - 11448 C 01 /03/05 2-1/8" 4 11434 - 11463 C 08/17/98 2-1/2" 6 11440-11463 C 08/02/98 2-1/4" 12 11448 - 11454 C 01/03/OS 2-1/4" 6 11454 - 11508 C 01/03/05 2-1/8" 6 11460 - 11490 S 07/27/98 2-1/8" 4 11500 - 11550 S 07/27/98 u 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" "S I A I KJNJ ?Fl , r~s, r~5, ~xi ~x ~i = rw5 rx i r~vutu rACaciNe; 10645' 3-1/2" PARKB~ SWS NIP, ID = 2.750" 10657~ TUBING SEAL ASSY ~ 10677' H9-5/8" X 3-1/2" TIW PKR, ID = 2.992" 10722~ 3-1/2" PARKB~ SWS NIP, ID = 2.750" 10754~ 3-1/2" PARK82 SWS NIP, ID = 2.750" 10754' 3-1/2" PX RUG (05/24/09) 10766' 3-1/2" TBG TAIL, ID = 2.992" 10774' E1N~ Tf LOGG~ 04/16/89 11348' 7" nnAwc~t ~on~rrT 11455~ FISH- X-LOCK CATCHER SUB LEA KEY (02/07/01) 11730' FISH -P6~FING CHARGE DISC (11/18/90) 11480~ F~I-F 15" X 1" X 1/4" STES SHEATH FOR BOWSPRING (08/17/98) DATE REV BY COMMENTS DATE REV BY COMMBVTS 03/04/89 DGH OWGINAL COMPLETION 02/06l09 CJWSV PULL PX PLUG (02/03/09) O6/19/01 F2WTP CORRECTIONS 05/24/09 MBMrTLH PX PLUG SET 09/09/03 JGWKK GLV GO 02/08/05 JRA/TLH ADPERF (01/07/05) 11/27/07 JLJ/PJC GLV GO (11/17/07) 10/07/08 JRA/TLH PX PLUG SET (09/05/08) PRUDHOE BAY UNff WELL: Z-25 PERMff No: 1881590 API No: 50-029-21902-00 SEC 19, T11 N, R12E, 721' SNL & 3143' W~ BP Exploration (Alaska) TREE = MCEV OY WEILHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 91.45' BF. ELEV = 55.05' KOP = 3201' Max Angle = 52 @ 8973' Datum MD = 11384' Datum TVD = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" Minimum ID = 3.725" -10,745' 4-1/2" YN NIPPr 4-1/2" TBG, 12.6#, L-80, TGII ~10,762~ TOP OF 7" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: CET ON 03/19/89 ANGLE AT TOP PEFiF: 41 @ 11434' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 11380 - 11412 S 07/27/98 2-1/8" 6 11434 - 11440 S 07/27/98 2-1 /4" 6 11434 - 11448 C 01 /03/05 2-1/8" 4 11434 - 11463 C 08/17198 2-1/2" 6 11440 - 11463 C OS/02198 2-1 /4" 12 11448 - 11454 C 01 /03/05 2-1 /4" 6 11454 - 11508 C 01 /03/05 2-1/8" 6 11460 - 11490 S 07/27/98 2-1/8" 4 11500 - 11550 S 07/27/98 PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ^-2,~p0~ ~~4-1/2" HES X nipple ID = 3.812" - ~~0,$~$' 4-1/2" HES X nipple ID = 3.812" ~~~,~~' 9-5/8" X4-1/2" BKR S-3 PKR -10,634~ 4-1/2" HES X nipple ID = 3.812" -10~ ~745~ ~~4-1/2" HES XN nipple ID = 3.725" ~10,762' 4-1/2" WLEG, ID = 3.958„ 11348' I-~ ~" ~ ~~ JOIM 114~, I-j FISI-F X-LOCK CATCHER SUB LEA KEY ( 11730~ FISH -PB~FING CHARGE DISC (11/18/90) 11480~ FISH- 15" X 1" X 1/4" STEF1 SHEATH FOI BOWSPRING (08/17/98) DATE REV BY COMMENTS DATE REV BY COMMENTS 03/04/89 DGH ORIGINAL COMPLETION 02/06/09 CJWSV PULL PX PLUG (02/03/09) 06/19/01 RN/TP CORRECTIONS 05/24/09 MBIWTLH PX PLUG SET 09/09/03 JCfWKK GLV GO 02/08/05 JRAlfLH ADPERF (01/07/05) 11/27/07 JLJlPJC GLV GO (11/17/07) 10/07/08 JRA/TLH PX PLUG SET (09/05/08) PRUDHOE BAY UNIT WELL: Z-25 PERMff No: 1881590 AR No: 50-029-21902-00 SEC 19, T11 N, R12~ 721' SNL & 3143' WEL BP Exploration (Alaska) Z-~ ~ SAFETY NOTES: JUNK: APPROX 280 STRIP GUN ~ CHAR~ISKS LEFT IN HOLE DURING 11/18/90 Pro~~ PERFn . EQUATES TO APPROX 2' OF FlLL IN 7" LNR MADE OF STEEL (BELL) o~n aios ~Chr~l~h~l'~~~~' N0. 5310 l~laska Dat~ & Gonsuiting Services , - ~: =r ~~, i~ Com an State of Alaska ~ r p Y~ 2625 Gambell Street, Suite 400 ~~, y~,~~; ~~~,,;,a~ .~ ~J ~. `~ t~~ ~' `~ Alaska Oil & Gas Cons Comm l~nchorage, D,If 99503-2838 Attn: Christine Mahnken !-1TYi~: Be4h 333 West 7th Ave, 5uite+ 100 Anchorage, AK 99501 WeIB Job # Log Description Date BL Color CD ~-20 AP3Q-00043 SBHP SURVEY - 06/17/09 1 1 P2-31 AZCM-00029 LDL L d - O6l17/09 1 1 12-03 AY1M-00022 SBHP SURVEY 06/15/09 1 1 Z-14B AYQQ-00036 TEMP SURVEY & BHP 06/23/09 1 1 R~-96 AP3Q-00042 SBHP SURVEY ` ~ ~ O6/i6/09 1 1 V~p5....,, 11999053 USIT - 10/12/08 1 1 ' N-11C ` AP3Q-00042 SBHP SURVEY O6/16/09 1 1 ` '" -'T3-1~ AY3J-00030 LDL _ 06/12/09 1 1 1~1-30 AVY5-00049 PRODUCTION PROFILE -~j bb 06/22/09 1 1 17-07~ AYQQ-00031 SBHPSURVEY "'3 '~(5 O6/11/09 1 1 OS-25B AP3Q-00040 SBHP SURVEY - 06/11/09 1 1 B°27A AXBD-00028 MEM INJ PROFILE 06/12/09 1 1 19-36 B14B-00066 CROSSFIOW & IBP L 06/23/09 1 1 ~°21~ 8148-00065 SBHP SURVEY - pg/21/pg ~ 1 X-17 AYTU-00043 PROD PROFILE -/ 06/08/09 1 1 Z-25 AW18-00018 LDL ()~~ '~y- 05/28/09 1 1 02-338 AYTU-00033 USIT °~ ~ 05/19l09 1 1 P~-07 AVYS-00051 PRODUCTION PROFILE ~f ~ ~ 06/25/09 1 1 93-03 AWL8-00020 LDL 06/01/09 1 1 3-17F/I(-30 62NJ-00008 MEM INJ PROFILE (J 06/15/09 1 1 MPS-08 AYS4-00080 LDL O6/15/09 1 1 i3-12 AViH-00019 LDL ( 07/05/09 1 1 01-25 AYTU-00046 USIT ° ~b 06/28l09 1 1 W-39A AWLB-00023 STATIC TEMP SURVEY ~" ~ 06/26/09 1 1 ~-35 AYTO-00022 SBHP SURVEY ~ 06/29/09 1 1 Z-16 AV1H-00017 SBHP SURVEY j O ' 06/29/09 1 1 i8-20 8581-00004 LDL - ~ ,_ _} pg/27/pg ~ ~ Z-29 AVY5-00053 SBHP SURVEY '~~ ~ a~)E~~' P j" , 07/03/09 1 1 L5-09 AYQQ-00032 RST C- ~ 06/13/09 1 1 07-10A n~ ~„~~ ...~.~..,.,~ ~..,.~ .,.- 61JJ-00022 ,.~..._ .... ........ MCNL .r ~~ .._ --•- ---• •--°-•- 05/26/09 1 __"__"'_._..._..._...........~..r.. . ................rv.v..a..vn~~m~av~~cliVrl CNVfI ~v. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. i ~ ~ ~- ~ % ~, : , i\ _ - '. „ . ~ _ 1 F,' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ ~ From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, May 25, 2009 7:21 AM ~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) ~~qq~~ , `~ ,~, Cc: NSU, ADW Well Integrity Engineer; Roschinger, Torin T. ~f'1_`'C.l ~ Subject: May MIT Forms '_"lu) Attachments: MIT END 5-02 05-06-09.x1s; MIT END 5-02 05-14-09.x1s; MIT END 5-02 05-23-09.x1s; MIT PBU 09-10 05-19-09.x1s; MIT PBU 17-08 05-19-09.x1s; MIT PBU M-30 05-19-09.x1s; MIT PBU W-215 05-10-09.x1s; MIT PBU Y-03A 05-19-09.x1s; MIT PBU Z-12 05-19-09.x1s; MIT PBU Z- 25 05-05-09.x1s Jim, Tom and Bob, Please see that attached May MIT forms for the following wells: 5-02/SD-10 (PTD #1811180) MIT-T with open mandrel below IA cement for variance compliance 05/06/09. Witnessed by AOGCC representative Bob Noble. 5-02/SD-10 (PTD #1811180) MIT-T with side pocket memory gauge for variance compliance 05/14/09. MIT-IA above cement failed on two attempts. Witnessed by AOGCC representative Bob Noble. 5-02/SD-10 (PTD #1811180) MIT-IA for variance compliance (upper IA above cement) 05/23/09. Witnessed by AOGCC representative Lou Grimaldi. 09-10 (PTD #1760820) MIT-IA for variance compliance. Witnessed by AOGCC representative Chuck Scheve. 17-08 (PTD #1810740) MIT-IA post-tubing patch. Witnessed by AOGCC representative Chuck Scheve. M-30 (PTD #1920300) MIT-IA post-initial injection. Witnessed by AOGCC representative Chuck Scheve. W-215 (PTD #2031310) MIT-IA for 4-year UIC compliance. Witnessed by AOGCC representative Chuck Scheve. Y-03A (PTD #2042350) MIT-IA for variance compliance and MI swap. Witnessed by AOGCC representative Jeff Jones. Z-12 (PTD #1891020) MIT-IA for MI swap. Witnessed by AOGCC representative Chuck Scheve. `~ Z-25 (PTD #1881590) Failed MIT-IA to evaluate for noted IA repressurization. «MIT END 5-02 05-06-09.x1s» «MIT END 5-02 05-14-09.x1s» «MIT END 5-02 05-23-09.x1s» «MIT PBU 09-10 05-19-09.x1s» «MIT PBU 17-08 05-19-09.x1s» «MIT PBU M-30 05-19-09.x1s» «MIT PBU W-215 05- 10-09.x1s» «MIT PBU Y-03A 05-19-09.x1s» «MIT PBU Z-12 05-19-09.x1s» «MIT PBU Z-25 05-05-09.x1s» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 .: 5/26/2009 ~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. _ Prudhoe Bay /PBU / Z Pad ~~ 5~~~ I~5 05/05/09 ~~ Taylor Wellman Packer Depth Pretest Initial 15 Min. 30 Min. Well Z-25 Type Inj. N TVD 8,371' Tubing 100 1,300 Interval O P.T.D. 1881590 Type test P Test psi 093 Casin 3,000 P/F F Notes: MITIA conducted due to repressurization seen on IA. MITIA failed as pressure fell off immediately, LLR 1.51 b OA 80 80 pm. Well is currently under AA A103.021 for slow TxIA comm. Well T pe Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes 1 =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT PBU Z-25 05-05-09.x1s "NOT OPERABLE: Z-25 (PTD 81590) Failed MITIA • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ ~ I2~1`f Sent: Friday, May Oa, 2009 2:30 ~M To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; Robertson, Daniel B (Alaska) Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: Z-25 (PTD #1881590) Failed MITIA AI I, -~ Well Z-25 (PTD #1881590) failed a MITIA at 1.5 bpm at 1550 psi while on water infection. The well has been reclassified as Not Operable due to the failed MITIA and not meeting the requirements of it's AOGCC Administrative Approval for slow TxIA communication on MI. The well will be evaluated for repair. Until then, please leave the AA in place in the wellhouse. We will wait for a potential repair before cancelling the AA. Thank you, Anna ~u6e, ~. E. Wet! Integrity Caordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 I~.a ~ ~~~,.. ~ ~~ ~~~ ~~~ From: NSU, ADW Well Integrity Engineer Sent: Monday, May 04, 2009 12:39 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; Robertson, Daniel B (Alaska) Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: Z-25 (PTD #1881590) Possible TxIA communication on PWI AI I, Well Z-25 (PTD #1881590) was put on MI injection to perform a leak detect log on 04/13/09. When the well was swapped back to water injection on 04/26/09 an increased IA pressure was noted. The increase in pressure was initially believed to be due to trapped MI that entered the IA during the logging operation. However, during an IA bleed on 05/04/09 fluid came to surface and the IA pressure tracked the tubing pressure. The well was shut-in at that time. The well has been reclassified as Under Evaluation. The plan forward for the well is as follows: 1. F: MIT-IA to 3000 psi; LLR if fails. 2. WIC: Eval to maintain or cancel AA A wellbore schematic, injection plot and TIO plot have been included for reference. Please call with any questions or concerns. 5/28/2009 NOT OPERABLE: Z-25 (PTD 81590) Failed MITIA • Page 2 of 2 Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, April 04, 2009 3:17 PM To: 'Regg, James B (DOA)'; Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer; Varble, Doug A; NSU, ADW Well Operations Supervisor; Engel, Harry R Subject: Z-25 (PTD #1881590) Swap to MI for diagnostics Jim and Tom, Well Z-25 (PTD #1881590) has been limited to produced water injection per A103.021 for TxIA communication while on MI injection. At this time we would like to gain permission to put the well on MI injection to perform a leak detect log; in hopes of locating and repairing the leak to MI. The well will be shut-in and/or swapped back to produced water injection immediately following the log. I have attached a TIO plot, injection plot and wellbore schematic for your reference. Please let me know if you need additional information to aid in your decision. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 5/28/2009 LTNDER EVALUATION: Z-2~TD #1881590) Possible TxIA com~ation on PWI Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com) / ~~' ~ ~~I~~ Sent: Monday, May 04, 2009 12:39 PM ~~ To: Regg, James B(DOA); Maunder, Thomas E(DOA); Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Optimization Engr; Robertson, Daniel B (Alaska) Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany Subject: UNDER EVALUATION: Z-25 (PTD #1881590) Possible TxIA communication on PWI Attachments: Z-25 TIO and Injection Plots.doc; Z-25.pdf All, Well Z-25 (PTD #1881590) was put on MI injection to perform a leak detect log on 04/13/09. When the well was swapped back to water injection on 04/26109 an increased IA pressure was noted. The increase in pressure was initially believed to be due to trapped MI that entered the IA during the logging operation. However, durinq an IA bleed on 05/04/09 fluid came to surface and the IA ren ssure ~ked the tubinc~ rq essure. The well was shut-in at that t me. The well has been reclassified as Under Evaluation. The plan forward for the well is as follows: 1. F: MIT-IA to 3000 psi; ~LR if fails. ~ 2. WIC: Eval to maintain or cancel AA A wellbore schematic, injection plot and TIO plot have been included for reference. «Z-25 TIO and Injection Plots.doc» «Z-25.pdf» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~ ~j~~~7 ~.;. ., ~~11~ ~~~ti~,.~ `.F;.,~'~ From: NSU, ADW Well Integrity Engineer Sent: Saturday, April 04, 2009 3:17 PM To: 'Regg, James B(DOA)'; Maunder, Thomas E(DOA) Cc: NSU, ADW Well Integrity Engineer; Varble, Doug A; NSU, ADW Well Operations Supervisor; Engel, Harry R Subject: Z-25 (PTD #1881590) Swap to MI for diagnostics Jim and Tom, Weil Z-25 (PTD #1881590) has been limited to produced water injection per A103.021 for TxIA communication while on MI injection. At this time we would like to gain permission to put the well on MI injection to perform a leak detect log; in hopes of locating and repairing the leak to MI. The well will be shut-in and/or swapped back to produced water injection immediately following the log. 7/27/2009 LTNDER EVALUATION: Z-2~PTD #1881590) Possible TxIA com~ation on PWI Page 2 of 2 I have attached a TIO plot, injection plot and welibore schematic for your reference. Please let me know if you need additional information to aid in your decision. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 7/27/2009 PBU Z-25 PTD 188-159 5/4/2009 TIO Plot ~i,U00 3,000 2.000 1,000 f Tbg ~- IA -~- OA OOA -~- OOOA ~ On 02/07109 02l14109 02I21J09 0212$109 03/07lD9 03J1di09 031211Q9 0~~28/09 04l04J09 04I11J09 0411$J09 Od1251~J9 051C12109 • • PBU Z-25 PTD 188-159 5/4/2009 ection Plot 3,400 3,200 3,0~0 2,800 2,600 2,aoo 2zoo 2,000 =1,800 ~ 1,600 1,400 1,200 1,000 800 600 400 200 4,200 a,noo 3,800 3,600 3,400 3,200 s nnn z,suu ~ 2,400 ~ 0 2,200 ~ 2,000 T 1,800 0 1,600 1,400 1,200 1,000 800 600 400 2D0 - WHIP SW - PW - MI - GI - Other ~ On ~ ~ 02l07/03 02~14l09 02~'21109 02/28/03 03/07109 03114I09 03/21/09 03J28109 04l04109 04/11109 04.?l0,•'03 0:1.?~~?03 051021U9 TREE = MCEV OY ~!VELLHEAb= MCEVOY ACTUATOR = OTIS KB. ELEV = 91.45' BF. ELEV = 55.05' KOP = 3201' Max Angle = 52 @ 8973' Datum MD = 11384' Datum ND = 8800' SS 13-3/8" CSG, 68#, L-80, ~= 12.415" SA TES: JUNK: APPROX 280 STRIP t~1N CHAR SKS LEFT IN HOLE DURING 11/18190 PERFing. EQUATES TO APPROX 2' OF FlL~ IN 7" LNR. MADE OF STF~L (BELL} ~ Z-25 2092' ~ 3-1/2" QTIS SSSV LAND NIP, ID = 2.75" ~ ( GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7 3008 2915 3 GAM *`DMY RK 0 11(17l07 6 5896 5166 49 GAM **DMY RK 0 11(17/07 5 7872 6497 48 CAM "DMY RK 0 11/17l07 4 9033 7229 51 CAM DMY RK 0 01/20(06 3 9784 7697 51 CAM "DMY RK 0 11/17/07 2 iQ472 8137 47 CAM DMY RK 0 01/20/06 1 10594 8221 45 CAM *"`DMY RK 0 11(17/d7 Minimum ID = 2.750" @ 2092' 3-1/2" C}TIS SSSV NIPPLE I TOP OF 7" LNR 3-1l2" 1BG, 9.2#, L-8Q, .0087 bpf, ID = 2.992„ 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFdRATION SUMMARY REF LOG CETON 03t19i89 ANGLE AT TOP PERF: 41 @ 11434' Nate: Refer to Production DB for historical perf data SIZE SPF IN?ERVAL Opn/Sqz DATE 2-1/8" 6 11380 - 11412 S 07/27i98 2-1/8" 6 11434 - 11440 S Q7/27/98 2-1/4" 6 11434 - 11448 O 01/03l05 2-1/8" 4 11434 - 11463 O 0$(17/98 2-1/2" 6 11440 - 11463 O 08/02/98 2-1l4" 12 11448 - 11454 O 01/03/05 2-1/4" 6 11454 - 11508 O 01103/05 2-1(8" 6 11460 - 11490 S 07/27l98 2-1(8" 4 11500 - 11550 S 07/27/98 PBTD 7" LNR, 26#, L-$Q, .0383 bpf, ID = 6.276" `S1A1 K3NS #1, #;i, #5, #(i c'k #/ = HHJ tX I I-JVUtU F'HI:KINI.i 10645~ 3-1/2" PARKER SWS NIP, ID = 2.750" 10657~ TUBING SEAL ASSY 10677' 9-5/8" X 3-1/2" TM/ PKR, ID = 2.992„ 10722' 3-1/2" PARKER SW5 NIP, ID = 2.750" 10754~ 3-1/2" PARKER SWS NIP, ID = 2.750" 10766~ -~3-1/2" TBG TAIL, ID = 2.992" j 10774' -~ MD Tf LOGGED 04/16189 11348' - 7" nna t~~ ~oi ~ 11455~ FISH- X-LOCK CATCHER SUB LEA KEY (02/07I01) 11730" FISH -PERFING CHARGE DISC (11/18/90) 11480~ F{SH- 15" X 1" X 1/4" STEEL SHEATH FOR BOWSPRING (08117198} DA7E REV BY COMMEN7S DATE REV BY COMMENTS 03/04/89 DGH ORIGINAL COMPLETIOPI 02/06/09 CJWSV PULL PXPLUG (02/03ld9) Q6l1@/01 RN/TP CORRECT10N5 09/09/03 JCM/KK GLV C/O 02/08/05 JRA/TLH ADPERF (01/Q7105) 11J27/07 JLJ/PJC G~V CJQ (11117/07) 10/Q7/0$ JRAITLH PX PLUG SET (09105/08} PRUDHOE BAY UNIT WELL: Z-25 PERMIT No: ~1881590 API No: 50-029-21902-OQ SEC 19, T11N, R12E, 721' SNL & 3143' WEl BP Eupioration (Alaska) Z-25 (PTD #1881590) Swap to~ for diagnostics , Regg, James B (DOA) From: Regg, James B (DOA) /~' C ~ i~(a Sent: Wednesday, April 08, 2009 1:00 PM ~~ ~ I To: 'NSU, ADW Well Integrity Engineer'; Maunder, Thomas E (DOA) Cc: Varble, Doug A; NSU, ADW Well Operations Supervisor; Engel, Harry R Subject: RE: Z-25 (PTD #1881590) Swap to MI for diagnostics OK to put PBU Z-25 on MI for LDL Jim Regg ..,.J ts.1 ..v +.iY.~ ~ VM+J 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 Page 1 of 1 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Saturday, April 04, 2009 3:17 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer; Varble, Doug A; NSU, ADW Well Operations Supervisor; Engel, Harry R Subject: Z-25 (PTD #1881590) Swap to MI for diagnostics Jim and Tom, Well Z-25 (PTD #1881590) has been limited to produced water injection per A103.021 for TxIA communication while on MI injection. At this time we would like to gain permission to put the well on MI injection to perform a leak detect log; in hopes of locating and repairing the leak to MI. The well will be shut-in and/or swapped back to produced water injection immediately following the log. I have attached a TIO plot, injection plot and wellbore schematic for your reference. «Z-25.pdf» «Z-25 TIO and Injection plot.doc» Please let me know if you need additional information to aid in your decision. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 4/8/2009 PBU Z-25 PTD 188-159 4/4/2009 a,ooo a,o~ 2,OW 1,000 -f- Tbg ^ IA ~ - OA OOA OOOA On • U TIO Pressures i PBU Z-25 PTD 188-159 4/4/2009 Injection Plot 1,000 900 800 700 600 3 500 400 300 200 100 s,ooo 5,50D 5,000 4,500 4,000 3.500 ~ 0 3,aoo ~ 2,500 ° 2,000 1,500 1,000 500 - WHIP sw Pw -- MI GI -Other -~- On • • 04/1810$ 05/19/08 06119!08 07/20/08 08.%20!08 D9iL0108 10/21/08 11f21/08 12!22%08 01f22/09 02i22.f09 03!25109 TRFF= MCF\/nY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV - 91.45' BF. ELEV - 55.05' KOP - 3201' Max Angle= 52 @ 8973' Datum MD = 11384' Datum ND = 8800' SS 13-3/8" CSG, 68#, L-80, ID = 12.415" STES: JUNK: APPROX280 STRIP GUN CHAR ISKS LEFT IN HOLE DURING 11118!90 PERFng. EQUATES TO APPROX 2' OF FlLL IN 7" LNR. MADE OF STEEL (BELL) ~ Z-25 2092' 3-1/2" OTIS SSSV LAND NIP, ID = 2.75" I I GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7 3008 2915 3 CAM "`DMY RK 0 11/17/07 6 5896 5166 49 CAM "*DMY RK 0 11/17/07 5 7872 6497 48 CAM *'DMY RK 0 11/17/07 4 9033 7229 51 CAM DMY RK 0 01/20/06 3 9784 7697 51 CAM "DMY RK 0 11/17/07 2 10472 8137 47 CAM DMY RK 0 01/20/06 1 10594 8221 45 CAM ~*DMY RK 0 11/17/07 Minimum ID = 2.750" @ 2092' 3-1 /2" OTIS SSSV NIPPLE TOP OF 7" LNR 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORAl10N SUMMARY REF LOG: CET ON 03/19/89 ANGLE AT TOP PERF: 41 @ 11434' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 11380 - 11412 S 07/27/98 2-1 /8" 6 11434 - 11440 S 07!27/98 2-1/4" 6 11434 - 11448 O 01/03/05 2-1/8" 4 11434 - 11463 O 08/17/98 2-1 /2" 6 11440 - 11463 O 08/02/98 2-1 /4" 12 11448 - 11454 O 01/03/05 2-1 /4" 6 11454 - 11508 O 01/03/05 2-1 /8" 6 11460 - 11490 S 07/27/98 2-1 /8" 4 11500 - 11550 S 07/27/98 PBTD 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" "S IA I IUNS i#1, #:3, #5, #fi cY~ #/ = I1AS tX I tNUtU F'A(:KIN(i 10645' 3-1/2" PARKER SWS NIP, ID = 2.750" 10657' TUBING SEAL ASSY 10677' 9-5/8" X 3-1/2" TM/ PKR, ID = 2.992" 10722' 3-1i2" PARKER SWS NIP, ID = 2.750" 10754' 3-1/2" PARKER SWS NIP, ID = 2.750" 10~ 766' ~~ 3-1/2" TBG TAIL, ID = 2.992" 10774' ELMD TT LOGGED 04/16/89 11348' 7" MA RKER JOINT 11455' ~ FISH- X-LOCK CATCHER SUB LEA KEY (02/07/01) 11730' FISH -PERFING CHARGE DISC (11/18/90) 11480' FISH- 15" X 1" X 1/4" STEEL SHEATH FOR BOWSPRING (08/17/98) DATE REV BY COMMENTS DATE REV BY COMMENTS 03/04/89 DGH ORIGINAL COMPLETION 02/06/09 CJN/SV PULL PXPLUG (02/03/09) 06/19/01 RN/TP CORRECTIONS 09/09/03 JCM/KK GLV C/O 02/08/05 JRA/TLH ADPERF (01/07/05) 11/27/07 JLJ/PJC GLV C/O (11/17/07) 10/07/08 JRA/TLH PXPLUG SET (09/05/08) PRUDHOE BAY UNIT WELL: Z-25 PERMIT No: 1881590 API No: 50-029-21902-00 SEC 19, T11N, R12E, 721' SNL & 3143' WEL BP Exploration (Alaska) MEMORANDUM • To~ Jim Regg P.I. Supervisor ~ ~ ~ ~~~ ~~ ~~~ FROM: john Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, January 14, 2008 SliBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC Z-25 PRUDHOE BAY UNIT Z-25 Src: Inspector NON-CONFIDENTIAL Reviewed By: P,I. Suprv Comm Well Name: PRUDHOE BAY iJNIT Z-25 Insp Num: mitJCr080 1 1 41 0093 1 Rel Insp Num: API Well Number: 50-029-21902-00-00 Permit Number: 188-159-0 Inspector Name: John Crisp Inspection Date: 1'6/2008 Packer Depth ~ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i Z 2j Type Ind. I W ~ Z'~7D ~i 8371 IA ~ ~~ 920 ~ 3000 ?940 2920 ~i -- -- P.T. ~~ ~sais9o ITYpeTes SPTt ~~ Test psi zo~z.~s ~, pA i loo ~ iso ~~~ iso ~ iso ~ _ Interval RiiQvAR P/F P / Tubing ~I _ sso sso aso ~~ sso ~~, NOteS' 6.8 bbl`s pumped for test. '~~'~ ~I~ JAS ~ ~ 200 r ;: __. Monday, January 14, 2008 Page 1 of I ra~C i ul i Re James B DOA • 99, ~ ) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, December 14, 2007 10:50 AM ~ ~~ ~ 12 ~ ~ ~ ~~ ~ To: Regg, James B (DOA) Cc: Fleckenstein, Robert J (DOA); NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: RE: PBU Z-25 MIT Attachments: MIT PBU Z-25 12-09-07.x1s Jim, ;/ Our calculated packer TVD is 8371'. The by field representative must have entered the wrong MD into the database and provided the inspector with the wrong TVD. Since, the AOGCC witnessed MlTIA on 12109/07; we have repeated the MITIA and it passed only requiring 7.4 bbls to fiil up. We will bleed the annulus to help ensure the well has no gas cap and plan on repeating the witnessed test early next week. Please see the attached MIT form for the test performed on 12/09/07. Please call with any questions or concerns. Thank yau, Andrea Hughes From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, December 13, 2007 3:30 PM To: NSU, ADW Well Integrity Engineer Subject: PBU Z-25 MIT Reviewed inspector report of 12/9/2007 witnessed MIT at PBU Z-25 PTD 1881590). His report shows TVD packer of 7794 feet -information would have come from BP's field rep. ~~ I calculate the packer ND as 8376 feet based on: - 10667 ft MD reported on 2/5/2007 Report of Sundry Well Ops (10-404); - Directional survey. The depth difference does not impact the test pressure as performed on 12/9. Because of the large volume of fluid pumped for the test, the AOGCC Inspector requested bleeding the well after 2 days to work gas out and retest. Please advise regarding the packer TVD and the requested bleed. Thank you. Jim Regg AOGCC 333 L^J.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 12/14/2007 MEMORANDUM To~ Jim Regg '~ J .~ 7 P.I. Supervisor ~ ~j~ 1 ' ~' ~ l FROivI: I,ou Grimaldi Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Monday, December 10, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC z-zs PRUDHOE BAY UNIT Z-2s Src: Inspector NON-CONFIDENTIAL . b~~ ~~ Reviewed By: P.I. Suprv J~~ Comm Well Name: PRUDHOE BAY UNIT Z-2s API Well Number: 50-029-21902-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG071209143329 Permit Number 188-159-0 Inspection Date• 12/9!2007 Rel Insp Num: L` j7[~ Packer Depth _ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ Z-2s T,ype Inj. ;, W ~ T~ ~ ~ I IA 49s 3000 2960 29s0 p.T Issts9o jTypeTest ; SPT ~! Test psi sooo OA ; zzs ~ zso !, zso zso Interval IiVITAL p/I; /Y ~ Tubing aoo ~ s2o ~ azo ago ~ _ __ Notes' Excessive fluid pumped (10.4 bbl's). Well held good, advised to bleed well after two days to work gas out and retest. Initial test after W/L work. Well had leak in tubing and GLV's were chan ged to attempt repair. ~~ Gl%I~tCL~C~~J Monday, December 10, 2007 Page 1 of 1 ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS FE8 0 9 2005 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 Stimulate 0 WaiverO Repair Well 0 PluQ PerforationsD Pull Tubing 0 Perforate New Pool 0 Operation Shutdown 0 Perforate ŒJ 4. Current Well Class: Development 0 Stratigraphic 0 9. Well Name and Number: Z-25 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Exploratory 0 Service ŒJ 91.50 8. Property Designation: ADL-0028262 11. Present Well Condition Summary: Total Depth measured 11800 feet true vertical 9210.0 feet Plugs (measured) Junk (measured) Effective Depth measured 11750 feet true vertical 9171.1 feet Casing CONDUCTOR LINER PRODUCTION SURFACE Length 80 1072 10952 2614 Size 20" 91.5# H-40 7 Inch 26 Lb L-80 9-5/8 Inch 47 Lb L-80 13-3/8 Inch 68 Lb L-8 MD TVD 36 116 36.0 - 116.0 10728 - 11800 8408.1 - 9210.0 34 - 10986 34.0 - 8597.7 35 - 2649 35.0 - 2648.7 Perforation depth: Oil & Gêth~~! ^m~bm,'ð'M Time EifértsrOh ~.- Re-enter Suspended Well 0 5. Permit to Drill Number: 188-1590 6. API Number 50-029-21902-00-00 None 11730,11480,11455 Burst Collapse 470 5410 4760 2270 1490 7240 6870 4930 Measured depth: 11434 -11440,11440 -11448,11448 -11450,11450 -11454,11454 -11455,11455 -11460,11460 -11463 11463 -11474,11474 -11488,11488 -11490,11490 -11500,11500 -11508 True vertical depth: 8928.31 - 8932.83,8932.83 - 8938.86,8938.86 - 8940.37,8940.37 - 8943.38,8943.38 - 8944.13,8944.13 - 8947.9 8947.9 - 8950.17,8950.17 - 8958.47,8958.47 - 8969.05,8969.05 - 8970.57,8970.57 - 8978.15,8978.15 - 8984.22 Tubing ( size, grade, and measured depth): 3-1/2 Inch 9.3 Lb L-80 @ 32 10766 Packers & SSSV (type & measured depth): 3-1/2" TIW Packer @ 10677 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SCANNED FEB 11 2005 R8DMs 8Ft FEe 1 II 2D/JS Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl Casing Pressure No Prior Injection 640 Well Shut-In 640 Tubing Pressure 0 0 13 Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD Copies of Logs and Surveys run - Daily Report of Well Operations - ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron A~ C~. Form 10-404 Revised 4/2004 DevelopmentD ServiceŒ] WAG D GINJD WINJŒ) WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant 2/8/05 Signature. 0 RIG I rrl\r64-4657 Date ') ) Z-25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/03/05 GUNS: 2.25 PJ 2306 HMX 6 SPF PERFORATED 11,488-11,508 (20') PERFORATED 11,468-11,488 (20') PERFORATED 11,448-11,468 (20') PERFORATED 11,434-11,554 (20') OVERLAPPED FROM 11448 - 11454' (12 SPF) TAGGED TD AT 11509' FLUIDS PUMPED BBLS I No Fluids Pumped 0 I TOTAL Page 1 bp .,. ..\1'.'", -......~ ~.~ ~..- --:....-- --1\ F"'-' .'1'''.\- ". ( 11f'-- 1(1 ì' ~, To: Doug Cismoski/John Smart, GPB Well Ops TL From: Dan Robertson 304 -- /7 '- Area PE Date: June 24, 2004 Subject: Z-25 CT Fill Cleanout and Repeñ Zone 3 Est. Cost: $100 M lOR: 500 bopd Cost Code: 4P1930.0 (EWE injection project code) Sundry approval #: 304 - 11 2...- Please perform the attached procedures as part of the EWE Injection Project. This work scope includes the following steps: Step Type Procedure 1 S Drift wi 2.5" DG and TEL, static pressure survey 2 C Fill cleanout to minimum of 11,560 MD 3 E Reperf 11,520-11,550 MD ~/ 4 F Injectivity test 5 S Install SSSV 6 0 AOGCC witnessed MITIA once well is POI. Current Status: Max Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: SI, awaiting injection 52 degrees @ 9046' 2.75" 10 @ 2092' SSSV Nipple 11,456' wlm (Static 1/7/00) 9/9/03 - Caliper Highest level recorded on Z-Pad was 20 ppm (Z-35 8/17/00), however generally -1 Oppm. CET 3/19/89 Tie in Log: It is now planned to add perforations to make this primarily a zone 3 MI injection well initially. A prior procedure included additional zone 4 add perfs; this procedure should be deleted. Zone 4 perfs will be reconsidered in the future after the production response to zone 3 injection is evaluated. Well Z-25i should provide injection support to offset producers Z-13, Z-21, Z-24, and Z-26. The well has passed all the requisite mechanical integrity tests to allow MI injection. However, it is still possible that mechanical integrity problems may develop when placed in M I injection service. The last TO tag on 1/7/00 indicated approximately 100' of fill over the bottom proposed perf interval. A coiled tubing fill cleanout is likely required to access the proposed perf ( t interval. Two fish are noted on the well bore schematic, a key from an X lock catcher sub at 11,455 MD lost on 2nl01 and a 0.25" x 1" x 15" steel sheath from a bowspring centralizer at 11,480 MD on 8/17/98. A trip with a bit and motor may be necessary to get past these fish. Comments or questions can be directed to Dan Robertson at 564-5546 (W), 346-3714 (H), 529-5818 (C). cc: w/a: Well File w/o: 1. Drift to TO with 2.6-2.7" 00 DG , TEL and sample bailer. Perform static pressure s~rvey with a,30,minute~top at 88.g0 TV[)SS and .~ 19 minute stop at 8700 TVE?SSo.u 1. RU 1.75" coiled tubing. PT. RIH with a 2.5" jet swirl nozzle, dual check valves, hydraulic disconnect. Tag TO to establish depth control. Jet with slick water and biozan sweeps as needed down to a minimum of 11,560 MDBKB. Clean out as deep as possible past this depth if cleanout is going well, stop cleanout at this depth if cleanout is going slowly. Run a 2 1/8" motor and 2.60" 00 5 blade carbide junk mill if debris prevents cleanout with n~zzle alone. 1. Perforate 11,520-11,550 MDBKB as per attached perforation form. 1. RU pump truck and vac truck or tanks with 2% KCL water. Bullhead 150 bbls of 20/0 KCL water down tubing to load well. Shut down to allow pressure to bleed down. Perform a step rate test at 0.5, 1, 2, 3, 4, 5 BPM (or maximum rate at 3000 psi maximum wellhead pressure) with 2 % KC!. Hold the first rate for 5-10 minutes and the remaining rates for 3 minutes each. Note the rate and pressure at the end of each step on the WSR. (The pressure does not have to be completely stable). Filter all fluids to 3 microns. 1. Install SSSV. Begin MI injection. 1--;;'\,"1 .. ... \ . ')lit 1. AOGCC witnessed MIT after stabilized injection is obtained. U"::;;"~"""''''fj;''''''~p''':''''¡::¡~'-.''''''''''::;;''õ''tf:::'' '¡~"''['''''''':''''''''''''..'''''''''''..''''...'''''''''.'''''''''''''''''''''''''''''.",,,,,,,,, ,,,,,,,,,,,,,"',,.,,,,,, 4pt ~194.ed ¿'/l'l/ÙJDf r \lJ6 Au-/;~ 2 v 1 - .. ~.. - . -. . ~ 073 s7 /0/ )Z:. STATE OF ALASKA RECEIVED ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROV AUAAY 1 0 2004 20 AAC 25.280 ¡-'\ BP Exploration (Alaska), Inc. Development 0 AIBGka Oil & Gas Cons. Gnmmission PerforatelXJ waiv~OrAg"ular Disposal 0 StimulateŒ Time ExtensionO OtherD Re-enter Suspended Well 0 5. Permit to Drill Number: 188-159( /' Exploratory 0 1. Type of Request: Abandon D Alter Casing 0 Change Approved Program D 2. Operator Name: Suspend D Repair Well 0 Pull Tubing D Operation Shutdown 0 Plug Perforations D Perforate New Pool D 4. Current Well Class: Casing StratigraphicD Service Œ] ,/ 9. Well Name and Numb? Z-25 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY I Total Depth TVD (ft):' IEffective Depth MD (ft): IEffective Depth TVD (ft): 9210.0 11750 9079.6 Length Size MD TVD 6. API Number ,/ 50-029-21902-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 91.50 KB 8. Property Designation: ADL-0028262 11. Total Depth MD (ft): 11800 Plugs (md): None Burst Junk (md): 11455,11480,11730 Collapse Conductor 80 Liner 1072 Production 10952 Suñace 2614 Perforation Depth MD (ft): 11434 - 11440 11440 - 11450 11450 - 11455 11455 - 11460 11460 - 11463 Packers and SSSV Type: 3-1/2" TIW Packer 12. Attachments: Description Summary of Proposal D 20" 91.5# H-40 7" 26# L-80 9-5/8" 47# L-80 13-3/8" 68# L-80 Perforation Depth TVD (ft): 8928.3 8932.8 8932.8 8940.4 8940.4 8944.1 8944.1 8947.9 8947.9 8950.2 top bottom top bottom 36 116 36.0 116.0 1490 470 10728 11800 8408.1 9210.0 7240 5410 34 10986 34.0 8597.7 6870 4760 35 2649 35.0 2648.7 4930 2270 Tubing Size: Tubing Grade: Tubing MD (ft): 3.5" 9.3 # L-80 32 10766 Packers and SSSV MD (ft): 10677 13. Well Class after proposed work: Detailed Operations Program Œ] BOP Sketch D /ì M,{2,gAOO4 ~ Exploratory 0 DevelopmentD ServiceŒ] 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: 15. Well Status after proposed work: Oil D GasD PluggedD AbandonedD WAG IKI / GINJD WIN~ WDSPLD Prepared by Garry Catron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel Robertson Printed Name Signature ~:R~_- . Title Phone Sr Petroleum Engineer 564-5546 5/6/04 Commission Use Only I Sundry Number: 3ó4-/7r ~/ Conditions of approval: Notify Commission so that a representative may witness BOP TestD Mechanciallntegrity Test œI Other: Location Clearance D Form 10-403 Revised 12/2003 ORIGINAL BY ORDER OF i1~ THE COMMISSION Date: 0 J It) ,,~ _BfL ' .11aU~ Approved by: SUBMIT IN DUPLICATE ocr :: r"\ ~ To: Doug Cismoski/John Smart, GPB Well Ops TL Date: May 4, 2004 From: Dan Robertson/ Beverly Luedke-Chan Area PE Subject: Z-25 Static, Reperf, Step Rate Test. Mud Acid Est. Cost: $130 M 4P1930.0 lOR: 500 bopd Please perform the attached procedures as part of the EWE Injection Project. This work should be performed in the following order: Step Type Procedure 1 S Drift w/ 2.5" DG and TEL 2 S Static Su rvey / 3 E Reperf 11 ,380-11 ,412 and 11 ,434-11 ,463' /' 4 F Step rate/ injectivity test 5 CP Contingent mud acid stimulation / 6 0 AOGCC witnessed MITIA once well is POI. ./ Current Status: Max Deviation: Min. 10: Last TO tag: Last Downhole Ops: Latest H2S level: SI, waiting for injection 52 degrees @ 9046' 2.75" 10 @ 2092' SSSV Nipple 11,456' wlm (Static 1/7/00) 9/9/03 - Caliper Highest level recorded on Z-Pad was 20 ppm (Z-35 8/17/00), however generally -1 Oppm. ,/ CET 3/19/89 Tie in Log: This well had an injectivity test done on 11/19/03. Injectivity was 0.6 bpm at 2450 psi, insufficient to be able to put on water or MI injection. The objective is to open 2 intervals to injection - the upper 41 P and the 42P. The plan is to drift and tag, with a possible FCC being required based on the results, get a static pressure to determine /' regional pressure prior to the start of injection in this region, reperforate existing perforations and old squeeze perfs and perform a step rate test to see if injectivity has improved. A contingent mud acid treatment is included if injectivity is still inadequate. Comments or questions can be directed to Dan Robertson at 564-5546 (W), 346-3714 (H), 529-5818 (C). cc: w/a: Well File w/o: Slickline: '. .. 1. Drift to TO with 2.5" DG, TEL and sample bailer. Perform static pressure survey ...o>,~. ._-"~. . _....._..._.~.=.=..=..=......._- ...- ~".~=-' "'=m"~=-- r"\ ~ ~ ~.. with a 30 minute stop at 8800 TVDSS and a 10 minute stop at 8700 TVDSS. t ,~ 0 ,mr"m"_W__""~oo=m.. ~~: , 1. Perforate 11,380'-11,412' and 11,434'-11,463' MDBKB as per attached perforation form. =". .. _,~,~m.. "'m=o=o=..o'ooo=oo=~~oo "__00 = o~ "0.."0 ryFulll:!lore: ",..""... .."..!,,",.'+< " .. ~ 1. RU pump truck and vac truck or tanks with 2% KCL water. Apply 1500 psi to inner , annulus with diesel. Perform a step rate test at 0.5, 1, 1.5,2,3,4, 5 BPM (or / maximum rate at 3500 psi maximum wellhead pressure) with 2 % KCI. Hold the first rate for 10 minutes and the remaining rates for 3 minutes each. Note the rate and pressure at the end of each step on the WSR. (The pressure does not have to be completely stable). 2. Shut down for 20 minutes, then pump at 1 and 2 bpm until pressure is relatively stable at each rate to compare to the initial injection pressures at these rates i.e. to ! see if pumping in at maximum rate has improved injectivity. RD pump truck. -_m ~ ~=~..o--J ~ICentingent Mud;Açicl" ~tim'l~tio.,:Pen.rlpthi$,,:~tilJ~lation if step rate test lindicates finalinjectivity ofle$$than, 2.SIIÞmat200D p$i. 1. Trap 1000 psi on the inner annulus. RIH with nozzle and tag TO (compare to slickline tag or post FCO tag) for depth control. 2. Make multiple passes across the perfs and pump the following at maximum rate down the CT with maximum wellhead pressure below frac gradient as established by the step rate test (exceed frac gradient if needed to establish injection, but attempt to pump the bulk of the treatment at matrix rates): 25 bbls 3% NH4CI with 10% U-66 and 0.2% F103 100 bbls 7.5% HCI 50 bbls 9% - 1 % HCI-HF 150 bbls 3% NH4CI with 10% U-66 and 0.2% F103 overflush (behind pipe) ¡ I , All fluids should be filtered to 3 microns. Please note the initial and final injectivity in the WSR summary. Please note the rates and pressures in the WSR when each stage hits the perfs. Please run a ¡ cable so that the pump truck can record back side WHP on the treating report. t Please e-mail the EXCEL treating report (1 minute readings) to Dan Robertson. I Treatment Design: / l.,- -175 bbls 3% NH4CI water with 10% U-66 and 0.2% F103 ,mo, =Tm= =~=- oyo_- "-~ü= 2 .? ' :; r"\ ~ 4200 gal 7.5% HCI 0.5% A261 0.5% A201 20 ppt L58 0.2% F103 0.5% W54 0.5% W35 2100 gal 9/1 HCI/HF 0.5% A261 0.5% A201 20 ppt L58 0.2% F103 0.5% W54 0.5% W35 Please note the acid titrations and iron ppm on the WSR. 3. Repeat Step #2 and wait 15 minutes. - ~ - 4. Perform a step rate test at 0.5, 1, 1.5,2, 3, 4 BPM (or maximum rate maximum wellhead pressure) with 2 % KC!. Hold the first rate for 5 minutes and the remaining rates for 3 minutes each. Note the rate and pressure at the end of each step on the WSR. (The pressure does not have to be completely stable). 5. POOH. Freeze protect. Bleed down the IA. RDMO. Well can be placed on MI . i~j~ction .é:lssyming adequate injectivity wa~_9btained. ~._~. ~--_.- ._-_J 3 Z-25 (PT~D #1881590) Passing MITIA Subject: Z-25 (PT~~18~r15~0~assing MITIA Date: Wed, 24 Sep'2003q-8:56:l 1 -0500 From: "Dube, Anna T" <Anna. Dube~BP.corn> To: "AOGCC Bob Fleckenstein (E-mail)" <Bob_Fleckenstein~adrnin.state.ak.us>, "AOGCC Field Inspectors (E-mail)" <AOGCC_Prudhoe_Bay~adrnin.state.ak.us>, "AOGCC Jim Regg (E-mail)" <Jirn_Regg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <Winton_Aubert~adrnin.state.ak.us> Attached is a MITIA form for Z-25 pre-injection start. Let me know if you have any questions. <<MIT PBU Z-25 09-21-03.xls>> Anna Dube Well Integrity Engineer 907-659-5102 i~ ~IIle: ivli I I"DLJ L-Z9 UY-Z I-UD'XIS l ~_)MIT PBU Z-25 09-21-03.xlst Type: Microsoft Excel Worksheet (application/vnd.rns-excel) ~.~~_ Enc. ~.~ odi~g: base6~__ 4 .............................................................. -- ............ 1 ofl 9/24/2003 5:20 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / Z Pad 09/21/03 Anna Dube Packer Depth Pretest Initial 15 Min. 30 Min. P.T.D. I1881590 Type test P Test psiI 2092.75 Casingl. 1001 4,0001 3,9801 3,9801 P/FI P Notes: Initial MITIA, pre-injection start. Another MITIA will be conducted post-injection start. w."l '.i. TVD I Tubin~l p.T.D.I ITyPe test Test psiI P/F~ Notes: Well[ Type Inj.[ TVD I Tubin~l] Type tes~ Test psiI P/FI Notes: w.,,I Type ,nj.I TVD I Tubin l Type tes~ Test psiI P/FI Notes: We,,[ Type Inj.I TVD I Tubingl Type tes~ Test psi] P/F/ Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperat[~re Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-0921_MIT_PBU_Z-25_preinj,,xls L STATE OF ALASKA Oi'~ ALAS OIL AND GAS CONSERVATION C ,MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonFI SuspendE] Operation ShutdownFI Perforate FI variancel'-I Annuar DisposalFI After Casin~D RepairWellD Pluq PerforationsD Stimulated Time ExtensionD Other[] Change Approved ProgramFI Pull Tubingr-I Perforate New PoolE] Re-enter Suspended WellFI WAG CONVERSION 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Development F1 ExploratoryFI 188-159 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic FI Service, 50-029-21902-00-00 7. KB Elevation (ft): 9. Well Name and Number: 91.45 Z-25 " 8. Property Designation: 10. Field/Pool(s): ADL 028262 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 11800 feet true vertical 9210 feet Plugs (measured) TD Tagged @ 11455' (02/07/2001) Effective Depth measured 11455 feet Junk (measured) true vertical 8944 feet Casing L(~ngth Size MD TVD Burst Collapse Conductor 110' 20" 146' 146' 40K 520 Surface 2613' 13- 3/8" 2649' 2649' 80K 2670 Intermediate 10950' 9-5/8" 10986' 8598' 80K 4760 Liner 1072' 7" 10728'-11800' 8408'-9210' 80K 7020 Perforation depth: Measured depth: Open Perfs 11434'-11463'. Sqzd Perfs 11380'-11412', 11460'-11490', 11500'-11550'. True vertical depth: Open Perfs 8963'-8950' Sqzd Perfs 8888'-8912', 8948'-8971', 8978'-9016' Tubing: ( size, grade, and measured depth) 3-1/2" 9.2# L-80 TBG @ 10766'. Packers & SSSV (type & measured depth) 9-5/8"x3-1/2" TIW PKR @ 10677'. 3-1/2" Otis SSSV Landing Nipple @ 2092'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Avera,qe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after proposed work: ExploratoryB DevelopmentB Service~ Copies of Logs and Surveys run _ 16. Well Status after proposed work: OilFi Gas[-I WAG~ GINJr"] WlNJD WDSPLD Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.C. Exempt: Contact DeWayne R. Schnorr I 303-230 Printed Name DeWayne R. Schnorr . _ Title Techical Assistant Signature ~u~.~*~~~"// Phone 907/564-5174 Date Sept19, 2003 07/21/2003 Z-25 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FIRST TIME WELL Z-25 IS REPORTED IN OMAR AS AN INJECTION WELL. 07/21/03 EVENT SUMMARY FIRST TIME WELL Z-25 IS REPORTED IN OMAR AS AN INJECTION WELL. NO WATER OR WAG HAS BEEN INJECTED INTO THE WELL AT THIS START TIME. FLUIDS PUMPED BBLS 0 ITOTAL Page 1 i' STATE OF ALASKA i" ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA 20 ~C 25.280 1. Type of Request: Abandon D :suspencl [-'] Operation Shutdown r"] Perforate[--] VadanceC~] Annuar DisposalD Alter Oasina I-'l Repair Well [--I Plucl Perforations F"! Stimulatel--I Time Extension [--I Otherl Chancle Approved Proeram ]--I Pull Tubing3 [--I Perforate New Pool I'"1 Re-enter Suspended Well[] CONVERSION-WAG 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc, Development I Exploratory[~] 188-159" 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphicr'l Service~-I 50-029-21902-00-00 ~' 7. KB Elevation (ft): 9. Well Name and Number: RKB 91.45 Z-25 '" 8. Property Designation: !10. Field/Pool(s): ADL 028262 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft):l 1800 ITotal Depth TVD (ft): I Effective Depth MD (ft): I Effective Depth TVD (ft): IPlugs (measured): IJunk (measured):9210 I 11455 (02/07/2001) 8944 None I 11455' Casing Length Size M D TVD Burst Collapse top bottom top bottom Conductor 110' 20" 146' 146' 40K 520 Surface 2613' 13-3/8" 36' - 2649' 36' - 2649' 80K 2670 Intermediate 10950' 9-5/8" 36' - 10986' 36' - 8598' 80K 4760 Production 1072' 7" 10728' - 11800' 8408' - 9210' 80K 7020 Perforation Depth MD (ft): J Perforation Depth TVD (ft): Tubing Size: I Tubing Grade: Tubing MD (ft): 11380' - 11412'I 8888' - 8912' 3-1/2"I L-80 10766 Packers and SSSV Type: Packers and SSSV MD (ft): 9-5/8"x3-1/2" Packer; 3-1/2" Otis SSSVLN Packer @ 10677', SSSVLN @ 2092' 12. Attachments: Description Summary of ProposalI 13. Well Class after proposed work: Detailed Operations Program [-'] BOP Sketch [-1 Exploratory[-] Development[~] Service! 14. Estimated Date for September, 2003 '" 15. We~ll~tus afte;aP~!]osed W~/uk;ged~] Commencing Operation: Abandoned ~] 16. Verbal Approval: Date: WAG~ GINJ[-] WlNJ I--J WDSPLI"-I Commission Representative: Perpared by DeWayne R. Schnorr 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact A.my Frankenbur9 Printed Name Am}, Frankenbur~l Title Senior En~lineer Signature~~-x~"'--"t. ~ =, ~',,""-,-~-'-----,, Phone 907/564-4503 Date. Jun 19, 2003 Q~m~ission Use Only Sundry NumJ~) ~) Conditions of approval: Notify Commission so that a representative may witness ~,~,. ,..,,~.~ ~:)' Plug Integrity ~ BOP TestY"] Mechancial Integrity Test[~ Location ClearanceE~] .: Other: ~, , Subsequent Form Required: ~, ~ - ~_ (.~ ~ '?/?"?.i'~ , · ,, Approved by: COMMISIONER THE COMMISSION Date: Form 10-403 Revised 2/2003 SUBMIT IN DUPLICATE 'rREE= MCEVOY,~ A~ SAFErYNOTES: JUNK: APPROX 280 STRIP GUN CHARGE DIS KS LEFT IN HOLE DURING 11118190 ACTUATOR OTIS~--- ~-- I.~ PERfing. EQUATES TO APPROX 2' OFRLL IN 7" I~, ELEV 91.45' - ...... LNR. MADEOFSTEB. (BELL) BF. ELEV = 55105' KOP = 3201 DatumMaxAngle=rv!3 = 52@8973'1~.-i ~0~ H~-~,~"o,~ ~v,^,~,,,.,~=~.~'I Datum TVD 8800. ss GAS LIFT MAI~DRELS S~ ~ 'IV""--~' D--'~ TYP~ V~ Lr'~"~' ~ D A~' ! I I 6 5896 5166 49 CAM RK 5 7872 6497 48 CAM RE "--4 9033 7229 51 CAM RK Minimum ID =2.750" @ 2092' 3 9784 7697 51 CAM RK ' 2 10472 CAM RK 18137 47 j 3-1/2" OTIS $$$V NIPPLE 1 10594L8221 46 CAM RK ~ I----t 10~45'H 3-1/2" PA RKER SWS NIP, ID=2.750"I I I~ ~-'~"~ 10677' H9-5/8"X3-1/2"TIWPKR, ID=2.992" I -- ~t 10722' H 3-1/2" PARKER SWS NIP, ID = 2.750" I I ! ' H I , ANGLE ^1 lOP PERF: 44 @ 10530' Note: Refer to Production 128 for historical perf data II II SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 11380 - 11412 S 07~27/98 r'l 2-1/8" 6 11434 - 11440 S 07~27/98 2-1/z' 6 11440 - 11463 O 08/02/98 2-1/8" 4 11434 - 11463 O 08/17/98 2-1/8" 6 11460 - 11490 S 07/27/98 I II ~ aa~5' I'-t ,~Ke~FmMX-LOC~ C~TC.mSUH-02/071011 BOWSF~ING LI=FT IN HOLE - 08/17198 17"LN~26#,L'~0,.030abP~,~D=6.276'' ~ aa8oo' ~ I DATE REV BY COMIV~NTS DATE R~t BY GOI~I~ITS PRUI~OE B~Y UNIt 03/04/89 DGH ORIGINAL COMPLETION WFIL: Z-25 03/12/01 SIS-QAA CONVERTED TO CANVAS PERMIT No: 1881590 03/14/01 SIS-MD FNAL APINo: 50-029-21902-00 ; 06/19/01 RN/TP CORRECTIONS SEC 19. T11 N. R12E 721' SNL & 3143' WEL BP Exploration (Alaska) PERFORATION SUMMA RY REF LOG: CE'I' ON 03/19/89 ANGLE AT TOP PERF: 44 @ 10530' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 6 11380 - 11412 S 07~27/98 2-1/8" 6 11 434 - 11440 S 07~27/98 2-1/Z' 6 11440 - 11463 O 08/02/98 2-1/8" 4 11434 - 11463 O 08/17/98 2-1/8" 6 11 460 - 11490 S 07/27/98 2-1/8" 4 11500 - 11550 S 07/27/98 DATE REV BY COMIVENTS DATE REV BY COIVlVlENTS 03/04/89 DGH ORIGINAL COMPLETION 03/12/01 SIS-QAA CONVERTED TO CANVAS 03/14/01 SIS-MD FNAL 06/19/01 RN/TP CORRECTIONS bp BP Exploration (Alaska), Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, Alaska 99519-6612 (907)561-5111 12August 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry notice for Z-25 swap from producer to WAG injection BP Exploration Alaska, Inc proposes the following wellwork to prepare to swap Z-25 from production to WAG (water alternating gas) injection with MI start-up estimated to occur in September, 2003 (TIFL test passed on 6/13/03) 1 S 2 O dummy off gas lift valves & caliper tubing MITIA to 4000 lbs. (witnessed by AOGCC) Z-25 is shut in now due to construction activities associated with the tie-in of the surface injection facilities. Facility tie-in as a WAG injector will be complete in September 2003. Z-25 will be put on injection beginning with a slug of MI. A copy of the wellbore diagram is attached. Please contact Amy Frankenburg at 564-4503 with any questions Sincerely, Amy Frankenburg ~ EWE Production Engineer ACF (8/12/2003) 1 of 1 ~CHAN!CAL il~qEGRITY RZPORT · Liner- -~'~ U'ub~¢:_..= ~-I/z, Packer /0/~ ~ T'~; Set az 10~77 [lole Size / f.z/~" and {~'/2" ; Perfs I/ f =o C=_~ iNTEGRITY - P .~fRT ¢ 1 Annulus Press Test: ; !5 rain ; 30 mit ~w~--~CH~_NiC>_L iNTEGRITY - PART ~2 Cement Volumes :- ~nt. Liner ; DV ---- AOGCC File Cement Bond Log (Yes or No) '~ ; Production Log: Type ; Evaluation MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner. THRU: Tom Maunder, P. I. Supervisor FROM: Lou Gdmaldi, DATE: April 21, 2001 SUBJECT: Petroleum Inspector SVS Tests BPX Z-pad Prudhoe Bay Field Saturday, April.21, 2.001; I witneSsed the three-month SVS retests on BPX Z pad in the~Westem:OperatingArea of the Prudhoe Bay Field. Merv Liddelow performed the SVS tests today. The test results (one SSV Failure) are noted on the accomPanied SVS test spreadsheet. All well houses were in "OK" condition. This was the first experience t ~have-had ~with:the new SV control system on Z pad andfound~ it~to oPerate quiteweil~ The tem~atures today were somewhat mild (+15) ~and it~re~ins 'to-. :be :seen ~h~:~-they~will~ hold: up dudng next winter's cold season: ~WeilS?Z~5 ~and~ Z-8 bad,SloW cl0Sing ~SSV's (+ 2. minutes), Merv called the Automati0nlcrewand theSe~Were being worked On before I left the pad. The pad is being used as a staging area for some pipeline fabrication and has some equipment and material stored on it. This was kept for the most part neat and orderly. SUMMARY: I witnessed the three-month SVS retests on Z pad in the Prudhoe Bay 'Field. 20 wells, 40 components, One'failure,- ~4°/0~ 34 Wellhouse inspections, no problems. Attachments: SVS PBU Z pad 4-21-01 LG.XLS NON-CONFIDENTIAL SVS PBU Z pad 4-21-01 LG Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Merv Lid&low AOGCC Rep: Lou Grimaldi Submitted By: Lou G. Date: Field/Unit/Pad: Pmdhoe Bay Field, Z pad Separator psi: LPS 159 HPS Well Permit Separ Set L/P Test Tnt Test Date o~ WAG, GINJ, Number Number PSI PSI Trip Code Code Code Pa~ed GAS or CYCLE Z-01' ' 1880660: I~ '125 125 '"P P Z-02A 1960430! Z~03 .... 1971~10! 159 .... 125 115 P ~ ....... Z-04 1891230i ........ Z-05 1900780~ 156 '125 1~5 P ' P ' ' ' Z-06 " 1880320 159 125 125 P P .... Z-07A 19311001 Z-08A 1931'280! 159 ¥25 120 P P .... z_09" 1890856! ....... z-10 1891160 z-11 1900720 159 125' 12~ P P ' " z-12 1891020! z-13 1900940! 1'59 125 '125 ' P" p ' . Z-14A ',",[,"1'9805]0 ....... , ' ', .... Z-15 1880880 Z'16 1920120 159 ' 125~' 125 P P ..... Z-17 1891390 159 125i 1251 p p Z-18 1890960 , Z-!9 ,,,192~230 , , Z-20 1881000 Z-21" 1890420 159 "1'~5 125 P P .... Z-25B ' J~60350 " 159 125 " 115' 'P P .... Z-23A 1950430 159 125 125 P P Z-24 1890180 '"159 125 125 ~ 4::i~ ~,~'~ ~'-~\~ /~? '' Z'-25' 18'81'590'"159 '" 125 '"i25 P P " Z-26 1890520 159 125 125 P P Z-27 1900310 ' 159 .....125 125 P "'P ' , , Z-28- 1881270 Z-29 1890650 159 125 120 P P ........ Z-50 ' 1900230 159: 125 120 "P P.... z-31 1881120 Z'3}B 1970340 .1'59! 125 125 P " P ' " Z-33A 1890050 Z-35 1980930 Z-38 " 1980600 159 125 1'20 P " P ' RJF 1/16/01 Page 1 of 2 SVS PBU Z pad 4-21-~..~ ~_G Well Number Wells: _ I_.! I _ I~ L Permit Number 20 Remarks: Separ I Set LfP ! Test I~tI %tI'I~te PSI ] PSI Trip I Code ] Code] Code I Passed Components: 40 Failures: 1 Failure Rate: Oil, WAG, GINJ, GAS or CYCLE 2.50% E] gO Day Z.-5 & ,8 Lq..,ng closure times on SSV. RJF 1/16/01 Page 2 of 2 SVS PBU Z pad 4-21-01 LG MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: jUlie Heusser ~'~. Commissioner DATE: January 23, 2001 THRU: FROM: Tom Maunder. ~_~,.~cb7 P, !. Supervisor jeff JoneS, .SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Unit -Z-Pad · Friday. JanUary 19j 200_! :- I traVeled to BPX's Z Pad in the Prudhoe Bay Field and witneSsed surface safety valve system testing. Merv Liddelow was the BPX representative'in charge of testing. As the attached AOGCC Safety. Value System Test Report indicates I witnessed the testing of 21 Wells and 43 COmponents with ~6 failures,~ The pilot On well Z-03 failed to trip and the pilot on well Z-08 was frozen and once thawed it passed a retest but the SSV on this well had an unacceptable closure time (12-min.). The SSV on well Z-18 also had an unacceptable closure time (15-min.) and the SSV's on wells Z-22B and Z-24 failed to pressure test. The high failure rate on Z Pad requires it be placed on a 90- day test interval. . Mr. Liddlow indicated to me today that all failures have been repaired except the slow SSV clOsure of wells Z-08A and Z-18. The hydraulic lines on these wells need to be flushed and he has arranged for the maintenance crew to perform the work. WeilhouSe inspections were COnducted on the 21 wells tested with no exceptions noted. Summa~: I witnessed SVS testing at BPX's PBU Z Pad. 21 wells, 43 CompOnents, 6 failures. 13.9% failure rate. 21 wellhouse inspections conducted. Attachment: SVS pBu Z Pad 1-19-01 JJ Alaska Oil and Gas Conservation CommissiOn Safety Valve System Test Report Operator: BPX Operator Rep: Merv Liddelow AOCK2C Rep: Jeff Jones Submitted By: Jeff Jones Field/Unit/Pad: PBF/PBU/Z Pad Separator psi: LPS 159 Date: 1/19/01 HPS Well' Permit SePar' Set L/P Test Test Test Date Oil, WAG, GI~IJ, Numb?, Number PSI PSI , T, ri,p Code Code Code Passed GAS or C,YCLE Z-01 1880660 159 125 125 P OIL Z.02A ' i~60430! ............ '- ............. Z-03' " 19~1510: 159 1.25 ' "0 " 1 .... P .... OIL Z-04 1891230 Z-05 .... '? 1'900780! ' 'i59 125 ' 120 P "'b ' .... OIL Z-06 1880320: " Z'-07A '1'9~1i00' ' ........................ Z-0SA 1931280: 125 "~ o' 2 ' 43 ' ' ' 1/23/6i ' ' Z_09 " i89q850.~.' . . .., ........ Z-lO 1891160 Z-11 :' , 1'900720 .... 156 125 "125 ' P V .......... OIL Z-12 I 1891020 Z-13 : l~J00~40'" 159 .... 1'25 125 'P .... P .... OIL Z-14A 11980510 " " ' Z- 15 1880880 Z-16 1920120 1~9" '1'3_5' :'1'25 ' P ' "P ............... OIL Z-17 ' ' 1891390 " 159 125 " ' i3~S P P ' " OIL Z-18 1890960 159 125 :- ' 120 P 43 OIL Z-19 ' 1920230 .... i ........ . Z-20 . 1881000 ' Z-21 " 1890420 · " ' ' ............... ~-22B '" '1960350 '1'5~3" ' 125 ~125 P 4 ' ' oIL Z-23A 1950430 'Z'-24" 1890180- 159 "' ~25 130. P 4 " 0IL ~;-'25 - 18871590 159' ' 125 "' 125 P ' P OIL Z.26 1890~20 159 125" 125'' ' ~ ' P OIL Z-27 190~)310 159 i2 " 125 'P " P OIL 'Z-28 ' ' '188'1270. ~ ......... Z'-~29 1890650 ' 'i5'9 125: 120 p P ........ OiL 'Zi30 '..,.1960230 .'159 '12~!' ' 11,51. 'p'_ p ' , .,',' .... OiL Z-31 1881120 Z-32B , 19~0340 159 ' "12~i .... i251 'P ' P _, ' ' ' ~)IL Z.33A 189005~ '2750'' 2666 2500 p. p p GINj Z-35 1980930 159 125 120 P P OIL! 1/24/01 Page 1 of 2 SVS PBU Z Pad 1-19-01 JJ.xls 'Well permit Separ Set L/P Test Test Test Date oi~ Number Number - PSI . PSI Trip Code Code Code passed GAS or CYCLE i i ii ! i Z-38 1980600 i59 125 120 -P P OIL . . Wells: Remarks: 21 Components: 43 Failures: ~ 6 - Failure Rate: 13.9°/dlt9o oar z,O8..A sS.V" failed: !2 minute close,..Z-18 ssv failed: 15 min.'ute close, frozen pilot ... thawed & passed retest, 1/24/01 page 2 of 2 SVS PBU Z Pad 1-19-01 JJ.xls Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Desc.: Pipe Use: BP Exploration (Alaska) Inc. January 7, 2000 1033 1 3.5' 9.2 lb. L-80 TDS Tubing Well: Z-25 Field: Prudhoe Bay State: Alaska APl No.: 50-029-21902-00 Top Log Intvl: Surface Bot. Log Intvl: 10,766 Ft. (MD) Inspection Type- Corrosive Damage Inspection ,I COMMENTS' This survey was run to assess the condition of the tubing with respect to corrosive damages. The caliper recordings indicate that the tubing ranges from good to poor condition with respect to corrosive damage. Most of the tubing appears in fair condition, with maximum joint penetrations falling between 20% and 40% wall thickness. Most of the damage appears in the form of isolated pitting below 1,850', and mostly as general corrosion with a deeper line of corrosion above this point. The deepest penetration recorded is located in Joint 247 @ 7,891', and measures 57% wall penetration. Significant cross-sectional wall loss is recorded in the Pup Jt. and 3 joints just above the SSSV. The most severe area is located in Pup. Jt. 65.1 @ 2,085' and measures 29% wall loss. The appearance and location of this metal loss points to contribution by erosional forces caused by fluid turbulence as it exits the smaller ID in the SSSV. A cross-sectional drawing of the tubing at the location of this damage is included in the report. Moderate pipe buckling is indicated in the interval 9,200' to 10,766'. The most significant bend recorded appears in Jt. 322 @ 10,311'. The tubing ID is restricted by approximately 0.14" to 2.86" at the elbow of this bend in the pipe. The bending would result in increased restriction as the dgid length of an object attempting to traverse this interval increases. A cross-sectional drawing of the pipe at the elbow of this bend is included in the report. MAXI MUM RECORDED WALL PENETRATIONS ' Line Corrosion (57%) Jt. 247 @ 7,889' MD General Corrosion/Erosion (44%) Jt. 65.t @ 2,084' MD General Corrosion (44%) Jt. 314 @ 10,053' MD General Corrosion (41%) Jt. 70 @ 2,236' MD Pitting (41%) Jt. 141 @ 4,529' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS · Corrosion / Erosion (29%) Jt. 65.1 @ 2,084' MD Corrosion / Erosion (24%) Jt. 63 @ 2,007' MD Corrosion / Erosion (24%) Jt. 64 @ 2,013' MD Corrosion / Erosion (24%) Jr. 65 @ 2,048' MD RECEIVED MAXIMUM RECORDED ID RESTRICTIONS' (Next Page) FEB 04 ~,laska 0il & ~S (;0nS. C0mmlssion MAXIMUM RECORDED ID RESTRICTIONS · The maximum recorded ID restriction occurs in the elbow of a bend due to pipe buckling in Jt. 322 @ 10,311 .' Other, less restrictive bending occurs over the interval 9,200' to 10,766'. Slight depositional buildup is recorded in joint no.'s 4 and 5 that restdct the ID to a minimum of 2.91 In. [Intentionally Left Blank) RECEIVED FEB 04 ~laska 011 & Gas Cons, ~mmission Anchorage I Field Engineer' R. Richey Analyst: J. Burton W~ness: Dave Romberg I Page 2 Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA PDS Caliper Overview Body Region Analysis Survey Date: JAN. 7, 2000 Tool Type: MFC40 No. 99812 Tool Size: 1 11/16 In. N o. of Fi~gers: 24 Analysed; _ , Bun'on Tubing: Size Wei¢~t Grade & Thread Nora. OD Nora.iD Nora. Upset 3.5 ins 9,2 ppf L4t0 TDS 3.5 ins 2,992 ins 3.5 ins penetration body ~;~¢>; metal loss body 0to I to 10to 20 to 40 to above 1% 10% 2CP/o 40*/0 85% 85% Number ofjoing analysed (total= 350) Pone 0 40 ~01 203 6 0 Loss 30 298 16 6 0 0 l:~ge Co~[on ( bo~y ) Number of joil~t~ damaged (total - 292) 171 42 79 0 0 [[~ge PeoPle (% ~) penetration body ~Fx metal loss body 0 5O 1 GLM 7 GLM 6 192 GLM 5 GLM 4 286 GLM 3 Bottom of Survey = 332.3 1 O0 Analysis Overview page 2 Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA PDS Caliper Overview Upset Region Analysis Survey Date: JAN~ 7, 2000 Tool Type: MFCqO No. 99812 Tool Size: 1 t 1/16 In. No. of Fingers: 24 Analysed: J. Burton Tubing: Size Weight Grade & Thread Nom,OD Nora. ID Nom. Upset 3.5 ins 9.2 ppf L-80 TDS 3.5 ins 2.992 ins 3.5 ins Penetration and Metal Loss (% wall) penetration upset 0to 1 to 10to 20 to 40 to above 1% 10% 20% 40% 85% 85% Number of joints analysed (total = 350) Pene 325 1 3 21 0 0 Damage Configuration ( upset ) N umber o~' ioints damaged (total = 24) 20 4 0 0 0 Damage Profile (% wall) penetration upset 0 5O 1 GLM 7 GLM 6 192 GLM 5 GLM 4 286 GLM 3 GLM ~ Bottom of Survey = 332.3 100 Analysis Overview page 3 CA R OtNT TAgULATION Pig~e: 3.5 ins 9.2 ppi L~O IDS Wal~ ~fickness. Body: 0,254bs Upse~ = 0.254~s Nominal ID: L992 i~ts Well: Field: Company: Daf~: Z-2S PRUDHOE BAY BP E×PLORAJ1ON ALASKA USA .{AN. 7. 2003 inches 3.07 corrosion. 3.03 ~_~ine coPmsio~. 3.03 I Line co~'tosion. 2.91 ] General corrosion~ DEPOSITS. 232 TGene~alco~osion. DB'~OSITS. 2.97 1_.General cowosion, 2.98 ~e~al co~ros~o~. I Une Shal~ .02] 3,01 [Line 3.01 ~ couosion. 3.00 J Shallow 3.01 Line ~halbw corrosion. 3.00 Line co~'osion. 2.99 Line corrosion. 3.01 Line 3 .~ 3.00 L[r~e co~osion. 3.~ Line corr~ion. 3,0t N~e 3.0~ Line corrosion. 3.01 Line 3.01 Nr~e 501 Line cosrosio~. 3.01 Gene~ 3.02 Li~e 3.01 Line 3.01 Line 3.00 Line corrosion. 3.01 Line corrosion. 3.01 Lbe 3.01 Line co~osion. 3.00 Line 3.~ Lbe 3~0~ Une co~osbn. 3~01 Line co~ion. 3.~3 Line co~ion, 3.C~ Lir~ corr~ion. 3.01 Uae 3.01 Lbe co~osio~i. 3.~ Li~ co~im~. 3.01 3.01 Line corrosion. 3.01 Line con'osion. 3.01 Pipe Tabub6ons page ~ penet~at~or~ bedy ~:~ mefal loss body Dan~.,a, ge 50 / PDS CA R JOINT TABULATION Pipe: 3.5 ins 9.2 ppf L~80 TDS Wall thickness. Body: 0.254ins Upset: 0.254ins Nominal ID: 2.992 ins U~et [ Body inches inches I Well: Field: Company: CokCntry: Date: Z-25 PRUDHOE BAY BP EXPLORATION ALASKA USA JAN. 7, 2000 Minimum ID Comments inches 2,99 General corrosion. 2.99 Line corrosion. 3.00 t. ine corrosion, 2.99 Line corrosion. 3.00 Line corrosion. 2.99 Line corrosion, 3.00 Line corrosion. 3.00 Line corrosion. 2.99 "Pitting. 3.00 Pitting. 3-01 ~ Une corrosion. 3.01 Line corrosion. 3.01 I Line corrogion. 3,05 GenerM corrosion. 3.02 General corrosion, 3.03 PUP General corrosion. 3.01 SSSV 3.01 PUP Sballow pitting. 3.00 Pitting. 2.97 Genera[ corrosion, 2.98 Pitting: 3.01 General corrosion. 2.99 General corrosion. 3.00 General con,ion, 3.00 Line corrosion. 2.99 ~nera[ corr~ion. 3.00 Line corr~ion. 3.0I 2.96 2.99 Shailow pitting. 2.99 [~P'~ 2.98 [ Pit~og. 2.99 Pitting. 2.99 2.98 2.99 Pitting. 2.98 2.97 &.hallow pitting. 2.98 2.97 Pitting. 2.98 ~i~ng: 2.97 Shallow pitting. 2.97 2.98 Pitting. 2~98 Shallow pitting. 3.01 Pitting. 2.96 PUP 3.00 [ 3.00 PUP GLM 7 (No Hole Dev.) 2.99 ] Pitting~ penetration body metal loss body tDamage profile (% wall) 50 100 Pipe Tabulations page 2 PDS CA R JOINT TABULATION Pipe: 3.5 ins 9.2 ppf L-80 TDS Wall lhickness. Body: 0.254ins Upset = 0.254ins Nominal ID: Z992 ins Penetration Well: Field: Company: Country: Date: Minimum i~J, cghes IC°rnrnents 2,99 j Pitting. 3.00 I Shallow pitting. 2.99 2.98 2.99 2.99 2.99 2.98 2.98 3.00 3.00 3.00 3.00 3,00 3.00 2.98 2.99 2.98 2.98 3.00 2.99 2.97 3.00 3.01 3.00 2.99 2.98 2.99 3.01 2.99 2.97 3.01 3.01 2.99 2.98 2.99 3.00 3.00 3.00 Shallow pitting, 3.00 2.99 Shallow pitdng. 2.98 3.00 2.98 2.99 3,00 2.98 2.98 2.99 2.99 Pittir Pipe Tabulations page 3 Z-25 PRUDHOE BAY BP EXPLORATION ALASKA USA JAN, 7, 2000 penetration body metal loss body Damage profile (% wall) 50 100 PDS CA R JOINT TABULATION Pipe: 3.5 ins 9.2 ppf L4~0 TDS Wall thickness. Body: 0.2S4ins Upset-0.254in~ Nominal ID: 2,992 ins Penetration Body Well: Field: Company: Country: Date: Z-25 PRUDHOE BAY BP EXPLORATION ALASKA USA )AN. 7, 2000 Minimum D Comments inches 3.00 2.98 2.98 2.98 Z98 2.99 Z99 2.99 2.96 2.98 Z99 2.98 2.99 2.98 2.98 2.97 2.96 3.00 2.97 2.97 2.97 Z97 2.99 2.98 Z98 2.94 2.98 2.98 2.97 Shallow pitting~ 2.99 Line corrosion. 2.97 2.96 3.00 Shallow pitting. 2.97 2.97 Shallow pitting. 2.99 Shal[ow pitting. 2.95 _Shallow pitting. 2.99 2.98 3.00 Shallow pitting. 2.92 PUP Shallow pitting 2.99 GLM 6 (Latch @ 1:30) 2.99 PUP 2.99 Line corrosion. 2.9S Shallow pitting. 2.96 Shallow pitting. 2.99 Shallow pitting. 2.99 Shallow pitting. 2.99 Shallow pitting. 2.99 Shallow pitting. penetration body metal loss body Damage profile % wall) 50 100 Pipe Tabulations page 4 PDS CA R JOINT TABULATION Pipe: 3.5 ins 9.2 ppf L~0 TDS Wall thickness. Body: 0.254ins Upset - 0.254ins Nominal ID: 2.992 ins Penetration Upset [ Body inches inches Well: Field: Company: Country: Date: Z-25 PRUDHOE BAY BP EXPLORATION ALASKA USA JAN. 7~ 2000 Minimum D Comments inches 3.00 2.96 2.99 2.98 2.97 2.98 2.99 2.97 2.99 2.97 2,98 2.99 2.98 2.98 2.99 Shallow pitting. 3.00 2.96 2.99 3.00 3.00 3.00 2.99 2.99 2.99 2.99 2.99 2.98 2.99 2.98 2.96 2.99 2.98 Shallow pitting. 2.99 Shallow pitting. 2~99 Shallow pitting. 2.99 3.01 Line corrosion. 3~01 Line corrosion. 3.01 Line corrosion. 3.01 Line corrosion. 2.98 Line corrosion. 2.99 ShaJJow pitting. 3.02 GeneraJ corrosion. 3.00 Line corrosion. 3.01 General corrosion. 3.01 Line corrosion. 3.00 Line corrosion. 3.00 Line shallow corrosion. 3~01 Line corrosion. 3.00 Line corrosion. 2,98 Line corrosion. penetration body metal loss body Damage profile %wa ) 50 100 Pipe Tabulations page 5 PDS CA R JOINT TABULATION Pipe: 3,5 ins 9.2 ppf L4K} TDS Wa}t thickness, Body: 0.254ins Upset = 0.254ms Nominal IO: 2.992 ins Peneg'alion Body inches [ % Well: Z-25 FiekJ: PI~UDHOE BAY Company: BP EXP[IOILAT[ON Aba, SKA Corem, y: USA Da[e: JAN. 7, 2C~ Minimum bO Comments i$~ches 2.9`5 ;enet~al co[r~sion. 2.99 General 2,98 L~e 2.97 Une corrosio~, 2.99 Ge~a~ co~r~on. 2.87 PUP Ge~e~al sha[bw 2.99 2.99 2,98 2.97 2.99 2.97 2.98 2,97 2.99 2.96 2.97 2.99 2.97 2.98 2.94 2.96 2.97 2.96 2.97 2.98 2.97 2.99 2.98 2.98 2.97 Z97 ZgB 2.9,6 2.97 2.97 2.97 2.97 .~LM 5 (Latch @ 5:00} PUP Sgalto~w Ge~a} corrosion. 2.98 2 2.97 2.85 PUP Sha[{~' taitling. 2.94 GLM 4 {Latch @ 9:G©} 2.94 PUP 2.9.5 Gef~era[ cmmsio~. 2.97 General cm'rosion 2.93 Line corrosion. Pipe Tabulations page 6 ~E(Ei FEB 04 pe~e~ation body metal loss Damage profile (% wa~l} ~00 PDS CA R JOINT TABULATION Pipe: 3.5 ins 9.2 ppf L430 TDS Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Penetration Upset inches Well: Field: Company: Count[y: Date: Z-25 PRUDHOE BAY BP EXPLORATION ALASKA USA JAN. 7, 2000 Minimum ID Comments inches 2.96 2.92 2.94 2.91 2.95 2.93 2.93 2.89 2.95 2.93 2.95 2.94 General corrosion. 2.93 2.91 2.93 2.90 2.92 2.90 2.89 BUCKLED PIPE. Line corrosion. BUCKLED PIPE. 2.94 General corrosion. 2.89 PUP Pitting. 2.94 Latch @ 9:00) 2.94 PUP Line light deposits. 2.95 2.96 General corrosion. 2.94 General corrosion. 2.95 Line corrosion. 2.90 General corrosion. BUCKLED PIPE 2.95 2.92 General corrosion. BUCKLED PIPE. 2.90 2.90 General corrosion. BUCKLED PIPE_ 2.89 2.90 2.90 2.91 2.90 2.90 2.90 BUCKLED PIPE. BUCKLED PIPE. General corrosion. BUCKLED PIPE. 2.86 BUCKLED PIPE. 2.92 2.92 2.93 General corrosion. 2.93 BUCKLED PIPE. 2.87 PUP Shallow pitting. 2.96 GLM 2 {Latch @ 10:00) 2.96 PUP 2,88 Generalcorrosion. BUCKLED PIPE. 2.93 Line corrosion. 2.92 Pitting. penetration body metal loss body Damage profile (% wall) 50 100 Pipe Tabulations page 7 RECEIVED Anchota~le PDS CA~R JOINT TABULATION SH~ Pipe: 3.5 ins 9.2 ppf L4~0 TDS Wall thickness. Body: 0.254ins Upset=0.254ins Nominal iD: 2.992 ins Welk Field: Company: Country: Date: Z-25 PRUDHOE BAY BP EXPLORATION ALASKA USA JAN. 7, 2000 penetration body metal loss body Joint j Penetration No. Upset Body ] inches inches I 329.1] .02 .04 [ 17 329.2j 0 0 32~9.3 ] 0 .05I 19 3a0 0 .09 35 330.1 j 0 0 G 330.2 j 0 .00[ 2 330.3 ] 0 0 I 331 j 0 .02 9 .L 1,1] o o [ ~2 ] 0 .02 t 332.1I0 0 [ L 2.2 0 .o11 2 ~a2.3l9_ 0 i 0 MetalI Proj, Loss Upset % inches 3 t.08 00 0° 4 0 4 0 0 0 0 0 0 0 3 0 0 0 3 0 0 0 0 0 ~ction igody inches J .02 J o i .03 .02 i o j o i 0 i .04 o o o Minimum ID Comments inches 2.88 PUP Shallow pitting, 2.92 GLM 1 (Latch @ 4:30} 2.92 PUP Shallow pitting. 2.93 General corrosion. 2.86 X-NIPPLE 2.86 PUP 2.91 PACKER 2.91 BUCKLED PIPE. 2.91 X-NtPPLE 2.91 BUCKLED PIPE. 2.89 X-NIPPLE 2.89 PUP 2.91 WLEG Damage profile %wa ) 50 100 Damage Classifications Penetration / projection class, in order of damage severity Hole - penetration exceeds 85% of nominal wall thickness Ring - damage area exceeds 75% of circumference, but depth range does not exceed 1 * pipe ID Line - damage depth range exceeds 10 * pipe iD, but extends less ~han 20% of circumference General - damage depth range exceeds 1 * pipe iD and/or extends more than 20% of circumference isolated * damage depth range does not exceed I 0 * pipe ID or extend more than 20% of circumference Damage reporting threshold = 30 thou inches deviation in body, 50 thou in upset. Modal line length = 0.440 feet. Pipe Tabulations page 8 RECEIVED AJagka Oii& Ga~ Co~s, Commamor PDS Caliper Sections Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Tubin$: 3.5 ins 9,2 ppf L-80 TDS Survey Date: JAN. 7, 2000 Tool Type: MFC40 No. 99812 Tool Size: I 11/16 In, No. of Fiegers: 24 Analysed: J. Burton Cross section for Joint 247 at depth Tool speed = 46 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 89 % Tool deviation = 55 ° 7890.57 ft Finger 16 Penetration = 0,146 ins Line of Corr. 0.146 in.: 57% HIGH SIDE = UP Cross-Sections page 1 PDS Caliper Sections Well: Z~25 Field~ PRUDHOE gAY Company: BP EXPLORATION ALASKA Couetry: USA Tubin 3~5 ins 9.2 L-80 TDS Survey Date: JAN. 7, 2000 Tool Type: MFC40 No. 99812 Tool Size: 1 11/16 In. No. of Fingers: 24 Analysed: J. Burton Cross section for Joint 314 at depth Tool speed: 44 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area -- 95 % Tool deviation -- 62 ° FE~ 04 ~ 10053.05 ft Finger 22 Penetration = 0.111 ins Corrosion 0,111 in,=44% HIGH SIDE= UP Cross-Sections page 2 Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Tubing: 3,5 ins 9,2 ppf US0 TDS PDS Caliper Sections Survey Date: JAN. 7, 2000 Tool Type: MFC40 No. 99812 Tool Size: 1 11/16 In, No, of Fingers: 24 Analysed: J, Burton Cross section for Joint 65.1 Tool speed = 46 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 76 % Tool deviation = 1 ° at depth 2084.86 ft Finger 17 Penetration = 0.1 t I ins Corrosion/erosion above SSSV 0.111 in. = 44% HIGH SIDE = UP Cross-Sections page 3 Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Tubin 3.5 ins 9.2 b80 TDS PDS Caliper Sections Survey Date: JAN. 7, 2000 Tool Type: MFC40 No. 998~ 2 Tool Size: 1 11/16 In. No. of Fingers: 24 ~ , __.~. Burton Cross section for Joint 322 Tool speed = 45 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 100 % Tool deviation = 53 ° at depth 10310.78 Finger 19 Projection =-0,092 ins Elbow of Bend in Buckled Area Min. ID = 2.86 in. Cross-Sections page 4 PDS :kLIPER JOINTTALLY SHEET Pipe: 3.5 ins 9.2 ppf L-80 TDS Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Date: JAN. 7, 2000 Joint Depth Length Measured Type No. ID feet feet inches I 30.08 30.96 nominal 2 61.04 30.94 nominal 3 91.98 31.96 nominal 4 123.94 31.60 2.995 5 155.54 31.62 3.003 6 187.16 31.66 3.016 7 218.82 31.88 3.028 8 250.70 3i .95 2.996 9 282.65 31.87 3.020 10 314.52 30.89 3.015 11 345.41 31.67 3.032 12 3 77.08 31.68 2.995 13 408.76 31.70 3.036 14 440.46 30.93 3.019 15 471.39 31.35 3.031 16 502.74 32.13 3.023 17 534.87 30.52 3.026 ' 18 565.39 31.76 3.027 19 597.15 31.27 3.025 20 628.42 31.85 3.02 7 21 660.2 7 30.94 3.028 22 691.21 3!.70 3.031 23 722.91 31.61 3.023 24 754.52 31.27 3.023 25 785.79 31.52 3.030 26 81 7.31 30.92 3.026 2 7 848.23 31.36 3.025 28 879.59 31.61 3.028 29 911.20 31.53 3.034 1 I 30 942.73 31.44 3.037 31 974.1 7 31.43 3.032 32 i 1005.60 31.37 3.0311 _~° 1036.97 31.61 3.035 34 1068.58 31.53 3.032 35 1 !00.11 31.44 3.032 36 1131.55 31.44 3.026 37 1162.99 31.50 3.040 38 1194.49 31.47 3.035 39 1225.96 31.39 3.032 40 1257.35 31.58 3.037 41 1288.93 31.44 3.034 42 1320.3 7 3 t .53 3.034 43 1351.90 31.44 3.034 44 1383.34 31.52 3.039 45 1414.86 31.45 3.03 7 46 1446.31 31.35 3.032 47 1477.66 31.44 3.036 48 1509.10 31.44 3.034 49 1540.54 3I .52 3.035 50 1572.06 31.63 3.030 Joint Depth Length Measured Type No. ID feet feet inches 51 1603.69 31.35 3.031 52 1635.04 31.61 3.023 53 1666.65 31.36 3.029 54 1698.01 31.27 3.025 55 1 729.28 31.61 3.032 56 1760.89 31.35 3.031 57 1792.24 31.53 3.024 58 1823.77 31.44 3.026 59 1855.21 31.47 3.018 60 1886.68 31.50 3.023 61 1918.18 31.39 3.029 62 1949.5 7 31.42 3.034 63 1980.99 31.60 nominal 64 2012.59 31.44 nominal 65 2044.03 31.1 8 nominal 65.1 2075.21 9.99 3.000 Pup 65.2 2085.20 14.61 nominal Sssv 65.3 2099.81 9.87 3.032 Pup 66 2109.68 31.24 3.030 67 2140.92 31.35 3.028 68 2! 72.27 31.68 3.026 69 2203.95 31.41 3.036 70 2235.36 31.43 3.031 71 2266.79 31.55 3.034 72 2298.34 31.31 3.012 73 2329.65 31.44 3.022 74 2361.09 31.53 3.023 7~ 2392.62 31.61 3.024 76 2424.23 31.79 3.019 77 2456.02 31.00 3.020 78 2487.02 31.48 3.013 79 2518.50 31.51 3.012 80 2550.01 31.37 3.015 81 2581.38 31.92 3.018 82 2613.30 31.20 3.014 83 2644.50 31.79 3.018 84 2676.29 31.77 3.013 85 2 708.06 31.78 3.01 7 86 2739.84 31.04 3.011 87 2770.88 31.59 3.013 88 2802.47 31.48 3.016 89 2833.95 31.50 3.007 90 2865.45 31.65 3.013 91 2897.10 31.70 3.010 92 2928.80 31.44 3.032 93 2960.24 31.70 3.028 93.1 2991.94 9.96 3.033 Pup 93.2 3001.90 10.29 nominal GIm7 93.3 3012.19 7.95 3.020 Pup 94 3020.14 31.53 3.016 Joint Tally page 1 PDS'._,: LIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.2 ppf L-80 TDS Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint Depth Length I Measured Type No.[ ID feet feet inches 95 3051.67 31.39 3.026 96 3083.06 31.61 3.029 97 3114.67 31.64 3.020 98 3146.31 31.33 3.028 99 3177.64 31.57 3.020 100 3209.21 31.74 3.018 101 3240.95 31.62 3.023 102 3272.57 31.44 3.015 103 3304.01 31.40 3.018 104 3335.41 31.49 3.023 105 3366.90 31.53 3.026 106 3398.43 31.44 3.026 107 3429.87 31.52 3.027 108 3461.39 31.27 3.027 109 3492.66 31.53 3.028 110 3524.19 32.03 3.030 111 3556.22 30.85 3.025 112 3587.07 31.96 3.024 113 3619.03 31.01 3.026 114 3650.04 31.53 3.028 115 3681.57 31.27 3.023 116 3712.84 31.35 3.024 117 3744.19 31.61 3.029 118 3 775.80 31.2 7 3.028 119 3807.07 31.53 3.026 120 3838.60 31.71 3.024 121 3870.31 31.08 3.027 122 3901.39 31.45 3.024 123 3932.84 31.61 3.033 124 3964.45 31.76 3.025 125 3996.21 31.21 3.029 126 4027.42 31.35 3.026 127 4058.77 31.44 3.032 128 4090.21 31.35 3.026 129 4!21.56 31.62 3.019 130 4153.18 31.36 3.024 131 4184.54 31.61 3.026 132 4216.15 31.44 3.027 133 4247.59 31.53 3.021 134 4279.12 31.27 3.025 135 4310.39 31.69 3.024 136 4342.08 31.45 3.025 ' 137 4373.53 31.35 3.021 138 4404.88 31.62 3.015 139 4436.50 31.35 3.025 140 4467.85 31.44 3.032 141 4499.29 31.27 3.021 142 . 4530.56 31.53 3.024 143 4562.09 31.61 I 3.020 144 4593.70 31.36I 3.022 Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Date: JAN. 7, 2000 Joint Depth Length Measured Type No. ID feet feet inches 145 4625.06 31.44 3.028 146 4656.50 31.52 3.022 147 4688.02 31.2 7 3.020 148 4719.29 30.92 3.018 149 4750.21 31.36 3.026 150 4781.57 31.27 3.021 151 4812.84 31.61 3.030 152 4844.45 31.29 3.029 153 4875.74 31.61 3.021 154 4907.35 31.34 3.016 155 4938.69 31.52 3.022 156 4970.21 31.45 3.026 157 5001.66 31.61 3.026 158 5033.27 31.20 3.024 159 5064.47 31.44 3.024 160 5095.91 31.70 3.018 161 5127.61 31.45 3.016 162 5159.06 31.69 3.02 7 163 5190.75 31.26 3.027 164 5222.01 31.79 3.022 165 5253.80 31.61 3.019 166 5285.41 31.47 3.018 167 5316.88 31.53 3.028 168 5348.41 31.53 3.019 169 5379.94 31.62 3.023 1 70 5411.56 31.61 3.018 171 5443.17 31.79 3.023 1 72 5474.96 31.46 3.019 173 5506.42 31.59 3.013 174 5538.01 31.59 3.023 1 75 5569.60 31.68 3.020 176 5601.28 31.43 3.020 1 77 5632.71 31.61 3.023 178 5664.32 31.12 3.015 179 5695.44 30.96 3.013 180 5726.40 31.30 3.019 181 5757.70 31.65 '3.018 182 5789.35 31.55 3.024 183 5820.90 31.32 3.01 7 184 5852.22 31.22 3.023 184.1 5883.44 10.08 3.022 Pup 184.2 5893.52 10.01 nominal GIm6 184.3 5903.53 8.36 3.024 Pup 185 5911.89 31.23 3.022 186 5943.12 31.70 3.025 187 5974.82 31.35 3.023 188 6006.17 31.56 3.024 189 6037.73 31.50 3.028 190 6069.23 31.27 3.021 191 6100.50 31.27 3.027 Joint Tally page 2 RECEIVED FEB 04 2000 Alaska, Oil & Ge$ Cons. L;ommlss~or Anchorage PDS'. · ,LIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.2 ppf L-80 TDS Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint Depth Length Measured Type No. ID feet feet inches 192 6131.77 31.80 3.027 193 6163.57 31.44 3.019 194 6195.01 31.69 3.020 195 6226.70 31.46 3.017 196 6258.16 31.80 3.013 197 6289.96 31.24 3.014 198 6321.20 31.63 3.021 199 6352.83 31.69 3.021 ~200 6384.52 30.43 3.024 201 6414.95 30.39 3.020 202 6445.34 31.61 3.011 203 6476.95 31.63 3,021 204 6508.58 31.57 3.014 205 6540.15 31.54 3.025 206 6571,69 31.52 3.028 207 6603.21 31.33 3.026 208 6634.54 31.55 3.026 209 6666,09 31,39 3,030 210 6697.48 31.49 3,033 211 6728,97 31.46 3.033 212 6760.43 31.50 3.030 213 679! .93 31.52 3.030 214 6823.45 31.57 3.028 215 6855.02 31.64 3.028 216 6886.66 31.52 3.022 217 6918.18 31.39 3.028 218 6949.57 31.63 3.017 219 6981.20 31.53 3.024 220 7012.73 31.6t 3.023 221 7044.34 31.53 3.021 222 7075.87 31.62 3.026 223 7107.49 31.49 3.024 224 7138.98 31.68 3.022 225 7170.66 31.57 3.024 226 7202.23 31.63 3.026 227 7233.86 30.78 3.031 228 7264.64 31.63 3.022 229 7296.27 31.49 3.011 230 7327.76 31.27 3.007 231 7359.03 31.54 3.019 232 7390.57 30.30 3.025 233 7420.87 31.44 3.010 234 7452.31 31.32 3.021 235 7483.63 31.11 3.009 236 7514.74 31.51 3.008 237 7546.25 31.40 3.009 238 7577.65 31.39 3.023 239 7609.04 31.26 3.013 240 7640.30 31.28 3.015 241 7671.58 31.15 3.018 Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Date: JAN. 7, 2000 Joint Depth Length Measured Type No. ID feet feet inches 242 7702.73 31.55 3.030 243 7734.28 31.05 3.019 244 7765.33 31.58 3.021 245 7796.91 31.25 3.022 246 7828.16 31.51 3.009 246.1 7859.67 10.33 3.024 Pup 246.2 7870.00 10.44 nominal GIm5 246.3 7880.44 7.45 3.024 Pup 247 7887.89 31.39 3.010 248 7919.28 31.70 3.014 249 7950.98 31.66 3.020 250 7982.64 31.48 3.019 251 8014.12 31.62 3.019 252 8045.74 31.61 3.020 253 8077.35 31.61 3.019 254 8108.96 31.62 3.020 255 81 40.58 31.59 3.015 256 8172.17 31.78 3.022 257 8203.95 31.30 3.005 258 8235.25 31.30 3.011 259 8266.55 31.70 3.011 260 8298.25 32.25 3.018 261 8330.50 30.72 3.006 262 8361.22 31.27 3.003 263 8392.49 32.16 3.005 264 8424.65 30.72 3.022 ~265 8455.37 31.69 3.020 1266 8487.06 31.21 3.018 267 8518.27 31.53 3.009 268 8549.80 31.47 3.005 269 8581.27 31.72 3.012 270 8612.99 31.35 3.006 271 8644.34 31.52 3.012 272 8675.86 31.78 3.007 273 8707.64 31.59 3.008 274 8739.23 31.44 3.006 275 8770.67 31.63 2.998 2 76 8802.30 31.55 3.008 277 8833.85 31.59 3.002 2 78 8865.44 31.64 3.006 279 8897.08 31.50 3.010 280 8928.58 31.2 7 3.012 281 8959.85 31.44 2.998 282 8991.29 31.36 3.010 282.1 9022,65 10,00 3.004 Pup 282,2 9032.65 10,61 nominal GIm4 282.3 9043.26 8.02 2.986 Pup !283 9051.28 31,21 3.000 :: 284 9082.49 31.30 3.004 1285 9113.79 31.56 2.990 Joint Tally pase 3 RECEIVED FEB Al~k~ Oil & Gas Cons. Commlss~or~ Anchorage PDS . ,LIPER JOINT TALLY SHEET Pipe: 3.5 ins 9.2 ppf L-80 TDS Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint Dep~ Length ~Measured Type No. ID feet feet inches 286 9145.35 31.12 2.998 287 9176.47 31.45 I 2.990 288 9207.92 31.20] 2.995 289 9239.12 31.56 2.985 290 92 70.68 31.37 3.002 291 9302.05 31.78 2.988 292 9333.83 31.15 2.995 293 9364.98 31.1 9 2.984 294 9396.17 31.59 2.990 295 9427.76 31.35 2.991 296 9459.11 31.1 9 2.996 297 9490.30 31.56 nominal 298 9521.86 31.41 3.004 299 9553.27 31.52 nominal 300 9584.79 31.76 3.005 301 9616.55 31.36 2.990 302 9647.91 31.71 3.000 303 9679.62 31.58 [ 2.994 304 9711.20 34.32 nominal 305 9745.52 28.38 3.005 305.1 9773.90 9.62 2.990 Pup 305.2 9783.52 11.1 8 nominal Gim3 305.3 9794.70 7.39 2.990 Pup 306 9802.09 30.72 3.000 307 9832.81 31.58 3.002 308 9864.39 31.36 2.998 309 9895.75 31.46 3.002 310 9927.21 31.29 2.985 311 9958.50 31.75 nominal 312 9990.25 30.98 3.000 313 10021.23 31.22 nominal 314 10052.45 31.44 3.001 315 10083.89 31.12 2.989 316 10115.01 31.70 2.990 317 10146.71 31.15 2.991 318 10177.86 31.53 nominal 319 10209.39 31.85 nominal 320 10241.24 30.98 2.990 ~321 10272.22 31.60 2.994 322 10303.82 31.58 2.999 323 10335.40 32.01 2.988 324 10367.4t 31.08 2.990 325 10398.49 31.25 2.996 326 10429.74 31.62 nominal 326.1 10461.36 9.92 3.002 Pup 326.2 10471.28 10.81 nominal Gim2 326.3 10482.09 7.54 3.006 Pup 32 7 10489.63 32.24 2.996 328 10521.87 30.53 3.002 329 10552.40 31.82 3.004 Well: Z-25 Field: PRUDHOE BAY Company: BP EXPLORATION ALASKA Country: USA Date: JAN. 7, 2000 joint Depth Length Measured Type No. ID feet feet i' inches 329.1 10584.22 10.64 3.022 Pup 329.2 10594.86 8.59 nominal Glml 329.3 10603.45 9.10 2.996 Pup 330 10612.55 33.39 3.010 330.1 10645.94 1.26 nominal X-nip 330.2 10647.20 8.74 2.990 Pup 330.3 10655.94 35.24 nominal Packer 331 10691.18 29.92 2.976 331.1 10721.10 2.23 nominal X-nip 332 10723.33 30.43 2.985 332.1 10753.76 2.36 nominal X-nip 332.2 10756.12 10.93 2.983 Pup 332.3 10767.05 unknown 2.995 Wleg Joint Tally page 4 STATE OF ALASKA AL~oKA OIL AND GAS CONSERVATION COMMIS,.._,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 721' SNL, 1809' EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 1306'SNL, 229' WEL, SEC. 18, T11N, R12E, UPM At effective depth 1080'SNL, 29'EWL, SEC. 17, T11N, R12E, UPM At total depth 1058'SNL, 51'EWL, SEC. 17, T11N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11800 feet BKB 9210 feet 11750 feet BKB 9171 feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE= 91.45 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-25 (11-17-11-12) PBU 9. Permit number/approval number 88-159 / 10. APl number 50- 029-21902 11. Field/Pool Prudhoe Oil Pool Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20 136 136 Surface 2613 13 3/8 3684 c.f. 2649 2649 Intermediate 10950 9 5/8 2424 c.f. 10986 8598 Production -- Liner 10 72 7 365 c.f. 10 728-11800 8408-9210 Perforation depth: measured 11510' - 11550' 1450'-1 1465' true vertical subsea 8894'- 8925' Tubing (size, grade, and measured depth) 3 1/2" L-80 to 10678' with 3 1/2" tailpipe to 10767' Packers and SSSV (type and measured depth) AUG ;50 1995 ~;~t_as~ Liil .& Gas Cons. Commiss'!~n ....... ~-, ~mchorage. 9 5/8' TlWpacker at 10678'; 3 1/2" SSSV at 2093' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations .X'_ 676 1000 259 2481 950 408 1565 1356 7158 1514 16. Status of well classification as: Oil X Gas Suspended Service 17.1 hereby c§rtify that the forpejo'~g,,is,,tru~e and correct to the best of my knowledge. Sign ed ~---~~~ L~7'-//' / ' '~/,,~/~-dx'~,4~ Title Senior TechnicalAssistantll Form 10-40'.4 Rev 06/15/88 Date SUBMIT IN DdPLI~ATE 05/08/94 05108/94 WELL Z-25(11-17-11-12) Addperf/Reperf Operation The following additional interval were perforated using 2 1/8" 6 SPF, 0° orientation and 0° phasing. 11380'-l1412'MD 11434'-l1450'MD The following interval were reperforated using 2 1/8" 6 SPF, 0° orientation and 0° phasing. 11474'-l1490'MD ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 17 May 1994 RE: Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION z-28 K-10 (31-05-11-14) J-lO (10-11-13) q~-12~ S-38 (24-26-12-12) 0~.?__ iO~L S-33 (11-35-12-12) ~-i~ S-35 (23-26-12-12-) (41-34-12-12) Cont/ ./1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /1 PFC/PERF FINAL BL 1 PFC/PERF RF SEPIA /~ DIFF.TEMP. FINAL BL 1 DIFF.TEMP. RF SEPIA 1 DIFFTEMP/GR FINAL BL /1 DIFFTEMP/GR RF SEPIA /1 PLS FINAL BL 1 PLS FINAL RF SEPIA ~ PLS FINAL BL 1 PLS FINAL RF SEPIA 1 PLS FINAL BL 1 PLS FINAL RF SEPIA ~1 PLS FINAL BL 1 PLS FINAL RF SEPIA .~1 PDK/GR/CCL FINAL BL 1 PDK/GR/CCL RF SEPIA ECC No. Run # 1 6196.00 Run # 1 Run # 1 6162.01 Run # 1 Run # 1 3556.04 Run # 1 Run # 1 4887.03 Run # 1 Run # 1 5840.03 Run # 1 Run # 1 5750.09 Run # 1 Run # 1 5867.05 Run # 1 Run # 1 Run # 1 5788.05 Run # 1 5858.05 Run # 1 STATE OF ALASKA AI~A~KA OIL AND GAS CONSERVATION COMMIS,b~oN REPORT OF SUNDRY WELL OPERATIONS ~tT'~m~ ~ P-~uggi~ ~ ~ 1. Operations performed: Operation shutdown Pull tubing Alter casing Repair well Other (~ ~ 6. Datum elevation (D~-~). KBE = 91.45¢,'AM~L feet 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 721'SNL, 1809'EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 1306' SNL, 229' WEL, SEC. 18, T11N, R12E, UPM At effective depth 1080'SNL, 29'EWL, SEC. 17, T11N, R12E, UPM At total depth 1058'SNL, 51'EWL, SEC. 17, T11N, R12E, UPM 5. Type of Well: Development Exploratory Stratigraphic 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-25 (11-17-11-12) PBU 9. Permit number/approval number 88-159/ 10. APl number 50- 029-21902 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured true vertical 11800feet Plugs (measured) BKB 9210feet Effective depth: measured 11750feet true vertical BKB 9171feet Junk (measured) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 136 Surface 2613 13 3/8 3684 c.f. 2649 Intermediate 10950 9 5/8 2424 c.f. 10986 Production -- Liner 1072 7 365 c.f. 10728-11800 Perforation depth: measured 11510'- 11550' 11450'-11465' True verticaldepth BKB 136 2649 8598 8408-9210 truevertical subsea 8894'-8925' Tubing (size, grade, and measu red depth) 3 1/2" L-80 to 10678' with 3 1/2" tailpipe to 10767' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 10678~ 3 1/2" SSSV at 2093' RECEIVED MAlt 1 5 199; 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Alaska Oil & Gas Cons. C0mmiss[, Anchorage Treatment description including volumes used and final pressure 14. Representative Dai_ly Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 670 1180 104 759 · 1480 1564 1446 856 253 312 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ,~,~~ G -~ ('~/~ Title Senior TechnicalAssistantl Form 10-4~4 l~v 06/15/88 I Date SUBMIT IN DUPLICATE~ WELL Z-25(11-17-11-12) PBU STIMULATION PROPOSAL A HCI tubing wash was performed on Z-25 on January 13, 1991 using the following fluids: 30 Bbls fresh water spearW/0.2% NE-41 surfactant 32 Bbls 15% HC1W/10% Hylene (fresh water carrier) 62 Bbls diesel displacement. This was followed by a BOHCL/MUD ACID on January the 27, and 28, 1991: The matrix acid treatment fluid summary was as follows: 208 BBls 6% HC1 328 BBls 6% HC1/.75% HF 448 BBls 2% NH4CL 14 Bbls divert 1 17 bbls diesel The BOMA was as folllows: 800 7/8" ball sealers 89 Bbls 6% HCL 36 Bbls diesel 125 Bbls NH4CL A Scale Inhibitor was performed on March 15, 1991 34 Bbls seawater. 50 Bbls west scale 46/49Bbls seawater/1 drum chemical . 120 Bbls scaletreat ESL/107 Bbls seawater/10 drums ESL 45 gal. act. 9.6 Bbl divert 1 (30 ppt hec/and 1 ppb divert 1) 15 Bbls meth. fjh 3/03/92 RE( EIVED MAR 1 5 199 Alaska Oil & Gas Cons. Commission Anchorage ~ ' STATE OF ALASKA '~"~" ALA-o~,A OIL AND GAS CONSERVATION COMMISS,,.,,q "~ REPORT OF SUNDRY WELL OPERATIONSr/ 1. Operations performed: Operation shutdown __ Stimulate Plugging Perforate Pull tubing X Alter casing Repair well Other -V~- 5. Type of Well: 6. Datum elevation (DF or 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 721'SNL, 1809'EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 1306'SNL, 229'WEL, SEC. 18, T11N, R12E, UPM At effective depth 1080'SNL, 29'EWL, SEC. 17, T11N, R12E, UPM At total depth 1058'SNL, 51'EWL, SEC. 17, T11N, R12E, UPM Development X KBE = 91.45 AMSL feet ,= 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-25 (11-17-11-12) PBU 9. Permit number/approval number 88-159/90-553 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11800feet BKB 9210feet 11750feet BKB 9171feet Exploratory Stratigraphic Service Plugs (measured) Junk (measured) 10. APl number 50- 029-21902 11. Field/Pool Prudhoe Oil Pool Casing Length Structural -- Conductor 110 Surface 2613 Intermediate 10950 Production -- Liner 1072 Perforation depth: Tubing (size, grade, and measured depth) Size Cemented Measured depth 20 136 13 3/8 3684 c.f. 2649 9 5/8 2424 c.f. 10986 7 365 c.f. 10728-11800 measured 11510'- 11550' 11450'-11465' true vertical subsea 8894'- 8925' 3 1/2" L-80 to 10678' with 3 1/2" tailpipe to 10767' Packers and SSSV (type and measured depth) 9 5/8" TiWpacker at 10678'; 3 1/2" SSSV at 2093' True vertical depth BKB 136 2649 8598 8408-9210 RECEIVED [vi&R 1! 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14, Prior to well operation Subsequent to operation Re.Dresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure **JOB WAS CANCELLED** Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby,certify that the foregoing is true and correct to the best of my knowledge. C~')~O~,~([2 ~1~~ TltleSeniorTechnica/Assistant, Signed _/ _ Form 10-404 Rev 06/15/88 SUBMIT IN DL4PL~A'(E Well 7.-25(11-17-11-12) Ri~Workover Pull Tubin~ -- -- APPROVAL # 90-553 The proposal to perform a Rig Workover (Pull Tubing) was sent to you for Z-25. The job was cancelled. fjh 2/10/93 BP EXPLORATION . BP Exploration (Alaska) In{:. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 08/07/92 Tg 83783 BP MAGNETIC LIS TAPES Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. -17 CH/TDT-P BORAX FIN 07/09/92 #1 ~685.00-11356.00 1600B?i API#500292061900 9049->T?g /4~28 CH/TDT-P FIN 07/18/92 gl //9143.00- 9757.50 1600BPI API#5002922273~0 ~_ 9050->TPg /,- v 10969.00-11736.00 A?[#500292190200 9051->??g Information Control Well Records Adrian J. Martin SCH REF#92416 SCH RE'g92436 FIN 07/12/92 gl 1600BPI SCH REF#92424 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 07/16/92 T~ 83723 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564~4004. J-17 ~ ~_ CNL CN . 07/11/92 #3 07/12/92 #1 10000.00-10929.00 SCH 5 " 10980.00-11705.00 SCH 5 " Information Control Well Records Adzian J. Martin z ECEIVED JUL 2 1 ~99~ Alaska Oil & 6as Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519.6612 (907) 561-5111 TO: DISTRIBUTION Date: 01/08/91 T#:81990 FROM: SUBJECT: Information Control Well Records LR2-1 BP C,A,~ED HOLE FINAL,~ Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. ~,t~-07 COLLAR 11/10/90 #1 9500-9811 HLS 5" -18 PERF 11/06/90 #1 9000-9450 HLS 5" Z-25 COLLAR 10/30/90 #1 11328-11602 HLS 5" Z-29 COLLAR 10/27/90 #1 10897-11757 HLS 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED JAN 1 5 1991 Alaaka 011 & (las Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (g07) 561-5111 TO: DISTRIBUTION Date :12/04/90 T#:81860 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedal listed below, if you have any questions, please contact BP Well Records at (907) 564-4445. D-23 PITS 11/06/90 #1 9850-11515 Camco 5" 'G-02 Leak Det 11/17/90 #1 10100-10201 Camco 5" , H-18 Prod-F 11/07/90 #1 9250 -9734 Camco 5" H-18 Collar Log 11/02/90 #1 9250-9734 Camco 5" · R-26A GR Temp 11/15/90 #1 7440-9365 Camco 5" , U-02 GR/TIE !N 11/19/90 #1 9450-10061 Camco 5" · Y-18 INJ 11/14/90 #1 10850-11290 Camco 5" Z-25 Leak Det 11/08/90 #1 9600-10092 Camco 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES 0 A!aska Oil & ¢~s Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date: 11/21/90 T#:81821 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE ~NAL~ Enclosed is your cOpy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. S-02 PITS 11/1 7/90 #1 10350-10874 SCH S-02 PERF 11/1 6/90 #1 9682-10680 SCH Z-25 PERF 11/18/90 #1 11250-11623 SCH # Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES STATE OF ALASKA n R ~ ~'1 AL,~S~KA OIL AND GAS CONSERVATION COMMIbo,ON U ~ · "" APPLICATION FOR SUNDRY APPROVALS IN 1. Type of Request: Abandon __ Suspend __ Operation Shutdown ~ Re-enter suspended well__ Alter casing ~ Repair well .__ Plugging Time extension __ Stimulate __ Change approved program __ Pull tubing X Variance~ Perforate x Other x __ Cement Squeeze 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory __ Stratigraphic.__ Service 6. Datum elevation (DF or KB) 91.45 feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 8. 721'SNL, 3143; WEL, SEC. 19, T11N, R12E At top of productive interval 1305' SNL, 229' WEL, SEC. 18, T11N, R12E At effective depth 10. 1080' SNL, 5232' WEL, SEC. 17, T11N, R12E At total depth 11. 1057' SNL, 5228'WEL, SEC. 17, T11N, R12E Well number Z-25 (41-18-11-12) 9. Permit number 88-159 APl number 50- 029-21902 Field/Pool Prudhoe Bay Fie/d/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11800 feet Plugs (measured) 9210 feet BKB 11750 feet Junk (measured) 9171 feet BKB Length Size Cemented 80' 20" 8 cu yds 2619' 13-3/8 3684 cu ft 10956 9-5/8 2424 cu ft 10 72 7 365 cu fl measured 11510-11550' true vertical subsea 8894'-8925' Tubing (size, grade, and measured depth) 3-1/2, 9.2# L-80 with tailpipe to 10767 Packers and SSSV (type and measured depth) TiW@ 10678, SSSV@2092 Measured depth True vertical depth 110' 110' 2649 2649' 10986' 8598' 10728'-11800' ~ ,.~ 8409'-9210' 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation July, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Gas Oil X Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~-~'~_~ TitleCompletionEngineeringSupervisor FOR COMMISSION USE ONLY Suspended Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ORIGINAL SIGN~0 BY Approved by order of the Commission LONNIE C $M~'r:~ Commissioner Form 10-403 Rev 06/15/88 Approved Copy R~turne(~ SUBMIT IN TRIPLICATE 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Attachment I Well Z-25 Workover Outline Procedure: 1. MIRU workover rig. 2. Pull BPV. 3. Circulate diesel from well. 4. Install two-way check valve. 5. ND tree. NU and test BOP's to 5000 psi, 6. Pull 3-1/2" tubing string. 7. Test the 9-5/8" packoff and replace if necessary. 8. Recover slick stick. 9. RIH with mill and PRT and recover the 9-5/8" Packer and tailpipe assembly. 10. RIH with 7" Test Packer and test 9-5/8" casing and 7" liner lap. 11. RIH with 6" bit and 7" casing scraper to PBTD. Reverse circulate hole clean. 12. Shoot squeeze pedorations in channel. 13. Set cement retainer on drill pipe immediately above squeeze perforations. 14. Cement squeeze with Class G cement. 15. Drill out cement to top of retainer and test. Re-squeeze if necessary. 16. RIH with 9-5/8" casing scraper to 7" liner top. Reverse circulate hole clean. 17. RIH with 7" casing scraper to PBTD. Reverse circulate hole clean and change over to filtered inhibited brine. 18. RIH with drill pipe-conveyed pedorating assembly, log into position with GR/CCL. Perforate and flow well to surface. 19. RIH with PIP and acid stimulate all pedorations. Underbalance with nitrogen and flow back well. Run 8.5" gauge ring/junk basket to 7" liner top. Run 6.0" gauge ring/junk basket to PBTD. RU E-line, set 7" isolation packer with 3-1/2" tailpipe assembly. Run existing 3-1/2" tubing and wellhead equipment. Set and test the 9-5/8" packer. Set two-way check valve. ND BOP's. NU and test tree to 5000 psi. Pull two-way check valve. Shear valve in the GLM and displace annulus to 140 bbls diesel. U-tube diesel to the tubing. Set BPV. Release rig. BOP STACK CONFIGURATION 13 5/8", 5000 PSI WP TRIPLE RAM ST ACK ATTACHMENT II WORKO VER I RISER ANNULAR PREVENTER 2" KILL LINE MANUAL HYDRAULIC GATE GATE i I I .I PIPE RAMS I ' ' PI PE RAMS I I DRILLING SPOOL 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE ! I BLIND RAMS I BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: From: Subject: DISTRUBUTION Information Control Well Records LR~I~ . BP CASED HOLE FINAL LOGS Date: 04/22/90 · Transmittal:.-. 81078 · ., .. .. Enclosed is your copy of the material listed below.' If questions, please contact BP Well Records at (907) 564-4445. you have E-26 Spinner/Temp 12/15/89 #1 9300-9670 R-13 PRDO-F 12/19/89 #1 9600-9956 W-24 CCL 12/21/89 #1 8750-9100 W-37 Spinner/Temp 12/14/89 #1 9800-10228 Z-23 PERF 12/12/89 #1 9383-9731 Z-25 Temp/PITS 12/17/89 #1 ii250-11735 HLS HLS HLS HLS HLS HLS any 1! 5" 5" 5" 5" 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS BP EXPLORATION BP E×ploration (^laska) Inc. gOO East Ben$on Boulevard P.O. Box lg6512 August 14, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Z-25 (11-17-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, Manager Production Engineering JAM: JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File Cons. Ccm, r,~[ss/on Ancn.¢rage /"--% STATE OF ALASKA ' ; ,$KA OIL AND GAS CONSERVATION COMMI,,. .ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 721' SNL, 1809' EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 1306' SNL, 229' WEL, SEC. 18, T11N, R12E, UPM At effective depth 1080' SNL, 29' EWI., SEC. 17, T11N, R12E, UPM At total depth 1058'SNL, 51'EWL, SEC. 17, T11N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Effective depth: measured true vertical BKB 5. Type of Well: Development Exploratory StratJgraphic Service 11800 feet 9210feet 11750 feet 9171feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE = 91.45 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-25 (11-17-11-12) PBU 9. Permit number/approval number 88-159 / 9-617 10. APl number 50- 029-21902 11. Field/Pool Prudhee Oil Pool Casing Length Size Cemented _. Structural .................. _-, ............... Conductor 110 20 Surface 2613 13 3/8 Intermediate 10950 9 5/8 Production -- Liner 1072 7 Perforation depth: measured 11510'- 11550' Measured depth True vertical depth BKB 136 136 3684 c.f. 2649 2649 2424 c.f. 10986 8598 365 c.f. 10728-11800 8408-9210 true vertical subsea 8894'- 8925' Tubing (size, grade, and measured depth) 3 1/2"L-80 to 10678' with 3 1/2" tailpipe to 10767' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 10678'; 3 1/2" SSSV at 2093' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 810 59 93 0 3910 1821 447 0 16. Status of well classification es: Oil X Gas Suspended 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations × 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-f/J//.J~ .,~'~/'~"'~--- Title Mana~er Production Engineering Form 1 ~l~4 Rev 06/15/88 //~ Service 231 301 Date ~-/~ '~ SUBMIT IN DUPLICATI~ WELL Z-25 (11-17-11-12~ PBU STIMULATION OPERATIONS A mud acid treatment was performed 7/21/89 on the following perforated interval in Well Z-25. 11510'- l1550'MDBKB The treatment was pumped via coiled tubing as follows: a) b) c) d) e) f) g) h) i) j) 12 bbls. Arctic diesel preflush 10 bbls. 10% HCI 5 bbls. diverter 15 bbls. 10% HC1 5 bbls. diverter 25 bbls. 10% HCI 75 bbls. 9% HC1/3% HF mud acid w/OSR 143 bbls. 3% NH4CI brine 24 bbls. Arctic diesel overflush Displace from CT with 23 bbls. diesel ............ The--well was--returned.-to-production slowly, then tested. --. jam 8/3/89 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 12, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well Z-25 (11-17-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, J. A. Bragg Manager Production Engineering JAM: JAM Enclosures (9) cc: L. Burke (MB12-1) Well File · 1. Type of Request: !'""'~ STATE OF ALASKA ~'"'~ ~'~// ~..~SKA OIL AND GAS CONSERVATION COMM~..,ON "~J' APPLICATION FOR SUNDRY APPROVALS Abandon ~ Suspend Operation Shutdown ~ Re-enter suspended well Alter casing ~ Repair well Plugging ~ Time extension ~ Stimulate X Change approved program ~ Pull tubing __ Variance ~ Perforate ~ Other ~ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 721' SNL, 1809' EWL, SEC. 19, T11N, R12E, UPM At top of productive interval 1306' SNL, 229' WEL, SEC. 18, T11N, R12E, UPM At effective depth 1080' SNL, 29' EWL, SEC. 17, T11N, R12E, UPM At total depth 1058'SNL, 51'EWL, SEC. 17, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 11800 feet true vertical BKB 9210 feet Effective depth: measured 11750 feet true vertical BKB 9171 feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) KBE = 91.45 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Z-25 (11-17-11-12) PBU 9. Permit number 88-159 10. APl number 50- 029-21902 11. Field/Pool Prudhoe Oil Pool Casing Length Size Cemented Measured depth Structural -- Conductor 110 20 136 Surface 2613 13 3/8 3684 c.f. 2649 Intermediate 10950 9 5/8 2424 c.f. 10986 Production -- Liner 1072 7 365 c.f. 10728-11800 Perforation depth: measured 11510'- 11550' true vertical subset 8894'- 8925' Tubing (size, grade, and measured depth) 3 1/2"L-80 to 10678' with 3 1/2"tailp~oe to 10767' True vertical depth BKB 136 2649 8598 8408-9210 Packers and SSSV (type and' measured depth) 9 5/8" TlWpacker at 10678'; 3 1/2" SSSV at 2093' 13. Attachments Description summary, of proposal X . Deta!.led operations program BOP sketch 14. Estimated date for commencing operation I July 1989 16. If proposal was verbally approved Oil X Name of approver Date approved Service 17. I hereby certify that the forog~ is true and correct to the best of my knowledge. 15. Status of well classification as: Gas ~ Suspended / ' ~..~,J FOR COMMISSION USE ONLY ' - Conditions of approval: Not~ Commission so representative may witness Plug integrity ~ BOP Test Location clearance ~ Mechanical Integrity Test __ Subsequent form required lO- ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Form 10-403 Rev 06/15/88 Date I Approval .o. Approvea L,-Opy Returned __ Commissioner Date SUBMIT IN TRIPLICATE WELL Z-25 (11-.17-11-12~ PBI~I STIMULATION PROPOSAL A mud acid treatment is proposed for the following perforated interval in Well Z-25. 11510'- l1550'MDBKB The treatment will be pumped via coiled tubing as follows: a) b) c) d) e) £) g) h) i) j) 12 bbls. Arctic diesel preflush 10 bbls. 10% HCI 5 bbls. diverter 15 bbls. 10% HCI 5 bbls. diverter 23 bbls. 10% HC1 71 bbls. 9% HCI/3% HF mud acid w/OSR 143 bbls. 3% NH4C1 brine 24 bbls. Arctic diesel overflush Displace from CT with diesel The well will be returned to production slowly, then tested. jam 6/27/89 CoiXtd Tubing' ~BIow-Out-Preven~kr~ Coiled Tubing .o P a c ~(-0 Blind Rams ~ U Cutter Rams H~ / .~~~. Slips ~--.- Pipe Rams .Pump-In Sub · (Circuta t e/F!, e turn Welt Head Swab Valve : PERIOD OF CONFIDENTIALITY DATE OF COMPLETION, SUSPENSION OR ABANDONMENT 30'DAY FILING DATE RELF~S E DATE COMMENTS '..13. B.RFC.02 (05/89) Very truly yours, T. B. Gray, Manager, Reservoir Surveillance TBG:DMH:dmh CC: R.E. MacDougal (Exxon) D.F. Scheve (ARCo) O.D. Smith (ARCo) R.E. 6.1 RE EIVED MAY - 9 }9~.u ~las~l.0ll .& Gas Cons. Cemmisslo. ''. Anchorage BP EXPLORATION TO: HOUSTON ARCO CHEVRON EXXON TEXACO MARATHON BP Explomlion (Alaska) In~ 900 East Benson Boulevard P.O, Box 196612 Anchorage, Alaska 9951~6612 (907) 561-5111 Date: 03-03-89 79870 MOBIL PHILLI~.S STATE OF ALASKA GEOSCIENCES '- REFERENCE: ARCHIVES BP 'OPEN HOLE FINAL LOGS The following material ls being submit~red herewith. Please acknowledge receipt by signing a copy of this le~fer and returning It to this offlce: HOU/UNIT / STATE: 'Z--25 BHCS 02-24.-89 #1 10990-11760 Sch 2"/5" Z-25 CNL Poro/Raw 02-25-89 #1 7750-11778 Sch 5" Z-25 CST 02-25-89 #1 11516-11674 Sch; 5" Z-25 DIL 02-24-89 #1 10990-11796 Sch 2"/5" Z-25 SS TVD 02-25-89 #- 11525-11605 Sch 2" STATE O~Y: DI~CTION~ S~S Ma~etic Sin Directional Su~ey Date: Received Date ,. Job#: Job#: Shirley R. McCurry I NFORMAT tON CONTROL Wel I Records LR2-1 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5'111 May 2, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. C. V. Chatterton Well Z-25 (11-17-11-12) PBU Enclosed, in duplicate, is form 10-407, our Report of Well Completion. This information reflects the current condition and status of the well. Also enclosed are two copies each of daily drilling reports, directional and gyroscopic surveys, and open hole logs. Y.OO.~s~s very truly, PBU Drilling Engineering Supervisor TOS/KTH Enclosures (4) Jan Martin (MB 9-4) Well Records w/10 Well File STATE OF ALASKA ~ ALASKA-OIL AND GAS CONSERVATION COI~MISSION WELL COMPLETION OR RECO PLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration 88-159 3. Address 3. APl Nur~ber P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-21902 4. Location of well at surface . ,,.--,,,,~_. __ ~, g. Unit or Lease Name 'I'Cr-'ATIOI~' Prudhoe Bay Unit 721 SNL, 3143' WEL, SEC. 19, T11N, R12E i ~i~|j=,~..D to. Well Number At Top Producing Interval 1305'SNL, 229'WEL, SEC. 18, T11N, R12E ' Z-25 (11-17-1.1-12) 11. Field and Pool At Total Depth ~ ~ Prudhoe Bay Field/Prudhoe Bay Pool 1057' SNL, 5228' WEL, SEC. 17, T11N, R12E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 91.45' I ADL 28262 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ~1'5. Water Depth, if offshore 116. No. 0f Completions 02/06/89 02/24/89 03/04/89I N/A feet MSL.. I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD', 19. Directional Survey 120. Depth where SSSV set 121.' Thickness of Permafrost 11800'MD /9210'TVD 11750'MD /9171'TVD YES [] NO []I 2093feet MD i 1942' 22. Type Electric or Other Logs Run GR/DIL/BHCS, GR/CNL/LDT, CS~.~, SS 23. CASING, LINER AND CEMENTING RECORD SET'rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING R~ AMOUNT PULLED 20" Condutor Surface 110' 13-3/8" 68# L-80 Surface 2649' 17-1/2" 3684 cu ft Permafrost 9-5/8' 47# NT80S Surface 10986' 12-1/4" 2424 cu fl Class G 7" 26# L-80 10728' 11800' 8-1/2" 365 cu ft Class G 24. Pe~iorations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIzE DEP'rH SET IMD) . PACKER SET {MDt Schlumberger5"@ 4 spf 3-1/2" 9.2# 10,767' 10,678' L-80 w/tai/pipe MD TVDss 26. ACID, FRACTURE, CEM. ENT SQUF~'TF. ETC. 11,510' - 11,550' 8894' - 8925' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 13-3/8" X 9-5/8" Down Squeezed Annulus with 175 BBLS Dry Crude. 27. PRODUCTION TEST Date First Production IMethod ol Operation (Flowing, gas lilt, etc.) March 3, 1989 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF ~VATER-BBL ~SIZE IGAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF ~VATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 7-1-80 ~INUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS Fr. JRMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. SAG 10997' 8606' SHUBLIK A 11039' 8636' ZONE 4 11223' 8771' 31. LIST OF ATTACHMENTS -- 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores ta~ken, indicate "none". Form 10-407 BP EXPI.OR~N Daily Drilling Report .- Prudhoe Bay Unit February 7, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 615' Day: 1 24- Hour Ftg: 535' Current Operation: Change swivel packing. Accepted rig @ 1300 hours, on 2-05-89. Spudded Z-25 @ 2100 hrs. on 2-06-89. DriIIed 17-1/2" hole to 615'. Mud Type: $1.YRVEY WT: VIS: PV: YP: FL: ANGLE DIRECTION TVD SE~FION Solids: Temp: °F COORDINATES. DLS BP EXPLORK]~N Daily Drilling Report-- Prudhoe Bay Unit February 8, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) ~ AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 2,394' Day: 2 24- Hour Ftg: 1,779' Current Operation: Drilling 17-1/2" hole. Drilled 17-1/2" hole to 2,394'. Mud Type: Nondisp. ~SURVE¥ MD, WT: 10.1 VIS: 126 PV: 19 ANGLE DIRECTION ~ YP:21 FL: 11 SECTION Solids: 9.5 Temp: COORDINATES. 52°F DL$, · P EXPLOFI.~'ION Rig: Audi #2 Well: Z-25 (11-17-11-12) Daily Drilling Report -- Prudhoe Bay Unit February 9, 1989 at 0600 hrs AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 2,670' Day: 3 24- Hour Ftg: 276' Carrent Operation: Nipple Up BOP's. Drilled 17-1/2" hole to 2,760' TD. Run and cement 13-3/8" casing. Mud Type: Non-Disp. WT: 9.6 VIS: 33 PV: 7 YP: 5 FL: 12 ANGLE DIRE~rIQN TVD SECTION Solids: 7.5 Temp: '-, COORDINATE~ 62°F DL$ · BP EXFI.OR~N Daily Drilling Report-- Prudhoe Bay Unit February 10, 1989 at 0600 hrs Rig: Audi #2 WeLl: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 3,078' Day: 4 24- Hour Ftg: 400' Current Operation: Drilling 12-1/4" hole w/motor. NU and tested BOP's. Tested casing to 3000~. Drilled out cement and shoe. Drilled 12-1/4" hole to 3,078'. Mud Type: Dispersed SURVEY MD WT: 9.5 VIS: 36 PV: 8 YP: 6 FL: 16 ANGLE DIRECTION .TVD SECTION Solids: 7 Temp: . 60 °F COORDINATES DLS, Daily Drilling Report-- Prudhoe Bay Unit February 13, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: - Current Amount: 0600 Depth: 7072' Day:. 7- 72- Hour Ftg: 3994' Current Operation: Drilling 12-1/4" hole. Drilled 12-1/4" hole to 7072'. Mud Type: Dispersed -WT: 9.9 VIS: 40 PV: 13 . ..~,URVEY .... MD ...... ANGLE .... DIRECTION ...TVD YP: 6 FL: 5.4 · ~ECTION Solids:10 "Temp:-85°F CO0~A~S DLS BP EX..ORaN Daily Drilling Report -- Prudhoe Bay Unit February 14, 1989 at 0600 hrs Rig: Audi #2 W¢11:Z-25 (11-17-11-12); AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: Current Operation: 0600 Depth: 8028' Day: 8 24- Hour Ftg: 956' Drilling 12-1/4" hole. Drilled 12-1/4" hole to 8028'. Mud Type: DISPERSED WT: 10.4 VIS:38 PV: 10 SURVEY MD ANGLE DIRECTION TVD . · YP: 6 FL: 4.4 SECTION Solids: 12 Temp: 84 °F COORDINATES DLS~ BP EXPLOHJ~'ION Daily Drilling Report-- Prudhoe Bay Unit February 15, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 8600' Day: 9 24- Hour Ftg: 572' Current Operation: Drilling 12-1/4" hole. Drilled 12-1/4" hole to 8600'. Mud Type: DISPERSED WT: 10.4 VIS:42 PV: 13 SURVEY MD, ANGLE DIRECTION TVD YP: 8 FL: 4.4 SECTION Solids: 11.8 Temp: 88 °F COORDINATES DLS. BP EXPLORatION Daily Drilling Report -- Prudhoe Bay Unit February 16, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12). AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 9102' Day: 10 24- Hour Ftg: 502' Current Operation: Drilling 12-1/4" hole. Drilled 12-1/4" hole to 9102". Mud Type: DISPERSED WT: 10.5 VIS: 45 PV: 16 SURVEY MD ANGLE DIRECTION TVD YP: 12 FL: 3.8 SECTION Solids: 12.5 Temp: COORDINATES 83W DLS, BP EXPLOR~N Rig: Audi #2 Well: Z-25 (11-17-11-12) Daily Drilling Report -- Prudhoe Bay Unit February 17, 1989 at 0600 hrs AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 9534' Day: 11 24- Hour Ftg: 432' Current Operation: Drilling 12-1/4" hole. Drilled 12-1/4" hole to 9477'. POH. Pulled wear ring at tested BOP's. Drilled to 9534'. Mud Type: DISPERSED WT: 10.5 VIS:44 PV: 14 SURVEY ME ANGLE DIRECTION .TVD YP: 12 FL: 3.8 SEC"I'ION Solids: 12.5 Temp: COORDINATES 94 °F DLS BP EXPLORNION Daily Drilling Report -- Prudhoe Bay Unit February 20, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) , AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 10009' Day: 14 72- Hour Ftg: 1457' Current Operation: POH to mn 9-5/8" casing. Drilled 12-1/4" hole to 10,991' TD. Mud Type: DISPERSED WT: 10.5 ~URVEY MI) ANGLE VIS: 40 PV: 18 YP: 10 FL: 3.8. DIRECTION, TVD SECTION Solids: 13.0 Temp: COOP. Dr ^TES 88°F DLS. Rig: Audi #2 Well: Z-25 (11-17-11-12) . Daily Drilling Report -- Prudhoe Bay Unit February 21, 1989 at 0600 hrs AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 10991' Day: 15 24- Hour Ftg: 0' Current Operation: Test 9-5/8" packoff. Ran and cemented 9-5/8" casing. Mud Type: DISPENSED WT: 9.6 SURVEY MD ANGLE VIS: 30 PV: 12 DIRECTION TVD YP: 3 FL: 7.8 Solids: 8 Temp: COORDINATES oF DLS Daily Drilling Report-- Prudhoe Bay Unit February 22, 1989 at 0600 hrs Rig: Audi #2 'Well: Z-25 (11-17-11-12) , AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 10991' Day: 16 24- Hour Ftg: 0 Current Operation: Drilling cement at 10760'. Tested BOP. Tested 9-5/8" casing to 3000~. Mud Type: DISPENSR'n') WT: 9.4 SURVEY MD ANGLE VIS: 120 PV: 12 DIRECTION TVD YP: 32 FL: N/C SECTION Solids: 6.5 Temp: 84°F COORDINATES DLS Daily Drilling Report -- Prudhoe Bay Unit February 23, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 10991' Day: 17 24- Hour Ftg: 0 Current Operation: Drilling cement and shoe. Drilled cement and float collar. Tested casing @ 10916' to 3000g. Drilled cement to 10982'. Mud Type: DISPERSED VeT: 9.5 $1.TRVEY MD ANGLE VIS:51 PV: 15 YP: 12 FL: 8.0 Solids: 3.5 Temp: DIRECTION TVD SECTION COORDINATES 89~F DL$, Daily Drilling Report -- Prudhoe Bay Unit February 24, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 11725' Day: 18 24- Hour Ftg: 734' Current Operation: Drilling 8-1/2" hole. Drilled 8-1/2" hole to 11725'. Mud Type: DISPERSED WT: 9.5 /.~]]~._V.V.V.V.V.V~ MD. ANGLE VIS: 42 PV: 12 DIREr'ION TVD YP: 9 FL: 7.2 ,$.ECTION Solids: 4 ' Temp: 98 °F COORDINATES. BP EXPLOR~N Daily Drilling Report -- Prudhoe Bay Unit February 27, 1989 at 0600 hrs [g: Audi g2 tell: Z-25 (11-17-11-12) AFE # 120626 APE 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 11800' Day: 21 72- Hour Ftg: 75' urrent Operation: Conditioning hole for cement job. Drilled 8-1/2" hole to 11,800' TD. RU Schlumberger & mn logs and side wall cores. RIH w/7"liner. Iud Type: DISPERSED WT: 7.5 URVEY MD ANGLE VIS: 39 PV: 11 DIRECTION TV'D YP: 8 FL: 6.4 SECHON Solids: 4 Temp: 100 °F COORDINATES DLS BP E~R. ORATION Daily Drilling Report -- Prudhoe Bay Unit February 28, 1989 at 0600 hrs (ig: Audi #2 Veil: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 11800' Day: 22 24- Hour Ftg: 0 2urrent Operation: Change RAMS to 3-1/2". Ran and cemented 7"liner. Drilled out cement. vlud Type: DISPERSED WT: 9.3 SURVEY MD ANGLE VIS: 37 PV: 7 DIRECTION TVD YP: 5 FL: 10 SECTION Solids: 415 Temp' 87 °F COORDINATES DLS BP EXPLORATK)N Daily Drilling Report -- Prudhoe Bay Unit March 1, 1989 at 0600 hrs ~ig: Audi #2 Veil: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 11750' Day: 23 24- Hour Ftg: 0 2urrent Operation: Change over to brine. RII-I w/6" bit. Cleaned out cement in 7" liner to 11750/ vtud Type: SURVEY WT: VIS: PV: YP: FL: ANGLE DIRECTION TVD SECTION Solids: Temp' °F COORDINATES .DL,S. BP EXPLOR,~'ION Daily Drilling Report -- Prudhoe Bay Unit March 2, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 11750' Day: 24 24- Hour Ftg: 0 Current Operation: POH for logs and perforating. Displace well to brine. POH. Test BOP's. RIH w/7" scraper to 11750' PBTD. Pump pill. Mud Type: BRINE SURVEY MD. WT: 9.4 VIS:26 PV: yP: FL: Solids: Temp: °F ANGLE DIRECTION TVD ~ COORDINATES, DLS. BP EXPLORATION Daily Drilling Report -- Prudhoe Bay Unit March 3, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 11750' Day: 25. 24- Hour Ftg: 0 Current Operation: RD Loggers. RU Schlumberger. Ran logs, gyro and perforated. Mud Type: BRINE SURVEY MD WT: 9.4 VIS:26 PV: YP: ANGLE DIRECTION TVD SECTION Solids: Temp: °F COORDINATES DLS BP EXPLORA~'ION Daily Drilling Report -- Prudhoe Bay Unit March 5, 1989 at 0600 hrs Rig: Audi #2 Well: Z-25 (11-17-11-12) AFE # 120626 API: 50-029-21902 AFE Amount: Current Amount: 0600 Depth: 11750' Day: 27 48- Hour Ftg: 0 Current Operation: Released rig @ 0600 hrs 3/4~89.Moving to Z-24. Ran 3-1/2" tubing. ND BOP's. NU & tested 3-1/2" tree. Pressure tested 3-1/2" tubing to 3000 psi and annulus to 2500 psi. Down squeezed 13-3/8" X 9-5/8" annulus w/dry crude. Mud Type: BRINE WT: 9.4 SURVEY MD ANGLE VIS: PV: YP: FL: DIRECTION TVD SECTION Solids: Temp: °F COORDINATES DLS SUB-SURFACE DIRECTIONAL $URVEY ~]UIDANCE ~]ONTINUOUS F'f] DeL Company BP, EXPLORATION Well Name Z-25(ll-17-11-12)(721',SNL,1809' EWL,SEC 19,TllN,R1,2E) Field/Location PRUDH,OE BAY, NO,RTH SLOPEr ALASKA Job Reference No. 73166 BARBA Date 2-MAR-89 Computed By: SINES SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR 8P EXPLORATION Z - Z5 (11-17-11-12) PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: OZ-M~R-B9 ENGINEER: D.BARBA ME'THUDS OF COMPUT~TZON TOOL LOC~TiON: TANGENtiaL- AVERAGED DEVIATION AND' ~ZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH CF NORTH 32 DEG 40 MIN EAST COMPUTATION D~TE: 7-MAR-89 BP EXPLORATION Z - 25 PRUDHOE BAY NORTH SLUPE, ALASKA INTERPOLATED VALUES FOR EVEN 100 FFET [3F TRUE MEASURED VERTICAL DEPTH DEPTH KELLY 0.00 0.00 100.00 100.00 ZO0.O0 200.00 300.00 300.00 400.00 400.00 500.00 495.99 600.00 599.99 700.00 699.98 800.00 799.98 900.00 89~).97 ._ PAGE 1 DATE OF SURVEY: OZ-N~R-89 BUSHING ELEVATION: 91.45 FT ENGINEER: O.BARBA 1000.00 9"~9.96 1100.00 1099.96 1200.00 1199.95 1300.00 1299.94 1400.00 1399.92 1500.00 1499.90 1600.00 1599.89 1/00.00 16V9.'87 1800.00 1199.86 1900.00 1899.85 MEASUPSD DEPTH ZO00.O0 1999.84 ZlO0.O0 Z099.83 Z200.00 2199.83 2300.00 2299.81 2400.00 2399.79 ZSOO.OO 2499.77 2600.90 2599.75 2700.90 Z699.73 ZUUO.O0 2799.71 2900.00 2899.71 SUB-SE~ COURSE VERTICAL DOGLEG R,ECT~NGULAR VERTZCAL DEVIATION ~ZZ'4UTH SECTION SEVERITY NORTH/SOUTH DEPTH DEG MIN DEG MTN FEET DES/lO0 FEET ~000.00 2999.62 3100.00 3099.2~ 3ZO0.O0 3198.31 3300.00 3296.57 3~00.00 3393.81 3500.00 3489.89 3600.00 3584.65 3700.00 3677.8~ 3800.00 3769.76 3900.00 3859.61 -91.45 0 0 N 0 0 E 0.00 0.00 8.55 0 5 N 15 19 W -0.07 0.00 108.55 0 15 S 43 23 W -0.27 0.34 208.55 0 13 S 21 3~ W -0.67 0.00 308.55 0 18 S 39 1Z W -1.15 0.00 408.54 0 26, S 29 55 W -1.84 0.00 508.54 0 31 S 22 9 W -Z.67 . 0.00 608.53 0 40 S 14 31 W -3.71 0.00 708.53 0 41 S 9 6 W -4.82 0.20 309.52 0 42 S 0 53 E -5.86 0.00 908.51 0 39 S 10 11 E -6.80 0.00 1008.51 0 41 S 1! 28 E -7.64 0.18 1108.50 0 46 S 12 7 E -8.56 0.21 1208.~9 O 54 S 1Z 4~ E -9.67 0.09 1308.47 I 0 S 20 23 E -10.73 0.21 1408.45 1 6 S 23 45 E -11.78 0.1~ 1508.~4 1 7 S 25 ~ E '-12.~4 0.25 1608.42 0 51 S 14 48 E -13.86 0.00 1,708.41 0 4? S 36 27 E -14.85 0.28 1808.40 0 42 S 16 10 E -15.69 0.26 190~.39 0 47 S 21 38 E -16.~9 0.00 2008.39 0 48 S 20 30 ~ -17.29 0.10 2108.38 0 50 S 18 lq E -19.15 0.14 2208.36 1 2 S 3 41 !5 -19.~7 0.03 2309.34 1 6 $ 4 50 W '-20.93 0.06 2408.32 1 12 S 12 46 W -22.81 0.13 2508.30 ] 12 S 16 47 W -24.94 0.00 2608.28 1 3 S 13 19 W -26.85 0.43 ZTO~.Z6 0 57 S 10 8 W -28.71 1.37 2308.26 0 31 N 54 5 :_ -29.11 2.5~ 290~.17 3 35 N 28 Z~+ E -25.46 2.24 3007.79 6 14 N ~6 37 E -16.84 1.42 3106.86 9 13 N 27 57 5 -3.¢0 2.17 3205.12 12 9 N 27 54 E 15.05 2.72 3302.36 14 42 N 27 35 E 3~J.25 Z.63 3398.44 17 17 N 25 25 E 65.78 2.50 3493.20 lO 3 N 26 Z1 E 9'7.45 2.79 358.6.44 2Z 10 N Z", 57 E 133.29 2.52 3678.31 24 26 N ZO 53 E 172.10 2.82 3768.16 27 38 N ZO 1,9 E 214.97 3.22 COORDIN4TES HORIZ. EAST/WEST OIST. FEET ;EFT 0.00 N 0.14 N O.lO N O.ZB S 0.67 S 1.24 S 1.99 S 3.02 S 4.18 S 5.37 S 0.00 E 0.34 W 0.65 W 0.81 W 1.09 W 1.48 W 1.85 W 2.17 W 2.41 W 2.48 W 6.57 7.72 8.97 10.46 12.05 13.75 15.52 17.09 18.54 19.76 2.35 W 2.13 W 1.86 W 1.60 W 1.08 W 0.39 W 0.42 E 0.98 E 1.~O E I.T5 E ZO .98 22.26 23.59 25.20 27.0~, 29.05 31.12 33.12 35.08 35.65 2.17 E 2.68 E 3.16 E 3.41 F 3.41 E 3.06 E 2.52 E 1.91 E 1.53 E 1.6F~ E DEPARTURE' AZIMUT'H DES MIN 0.00 N 0 0 E 0.37 N 68 18 W 0.66 N 81 16 W 0.86 S 71 5 W 1.27 S 58 26 W 1.93 S 50 Z W 2.72 ' S 42 53 W 3.72 S 35 37 W 4.82 S Z9 59 W 5.92 S 26 49 W 6.98 S 19 38 W B.O0 S 15 24 W 9.16 S 11 43 W 10.58 S 3 40 W 12.10 S 5 7 W 13.75 S 1 38 W 15.52 S 1 32 E 17.12 S 3 16 E 18.59 S 4 18 E 19.84 S 5 3 E 21.09 S 5 54 E 22.42 S 6 52 E 23.80 5 7 37 E 25.43 S 7 ~Z E 27.26 S 7 11 E 29.21 S 6 1 E 31.22 S ~ 37 E 33.17 S 3 18 E 35.1 1 S Z 29 E 35.69 S Z 41 E 32.70 S 3.83 E 32.92 S 6 40 E 25.02 S 7.82 : 26.21 S 17 Z1 E 13.01 S 14.00 ~ 19.ll S 47 5 E 3.23 N 22.85 E 23.08 N 81 57 E 23-72 N 33.87 E 41.35 N 54 59 E 48.49 N 46.25 E 67-01 N 43 38 E 77.25 N 60.08 E 97.86 N 37 52 E 109.87 N 75.59 E 133.36 N 34 31 E 146.41 N 90.50 E 172.12 N 31 43 E 187.49 N 105.85 E 215-31 N 29 26 E 8P EXPLORATION L - 25 PRUDHOE BAY NORTH SLOPE RL~$RA COMPUTAT!'ON D ~,TE: 7-MAR-89 KELLY PAGE Z D~TE OF SURVEY: 02-MAR-89 BUSHING ELEVATION: 91.45 FT ENGINEER: D.BARB& INTERPDLATEO VALU£S FOR TRUE SU'8-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 4000.00 5947.00 3855.55 4100.00 4031.93 3940.48 4200.00 4113.79 4022.34 4300.00 4192.20 4100.75 4400.00 4256.39 4174.94 4500.00 4337.05 4245.60 4600.00 4406. O0 4314.55 4700.00 44'74.43 4382.98 4800.00 4542.52 4451.07 4900.00 4609.64 4518.19 5000.00 4676.06 4584.61 5100.00 4741.76 4650.31 5200.00 4806.B6 4715.41 5]00.00 4871.3'7 4779.92 5400.00 4935.95 484~.50 5500.00 5000.59 4909.14 5600.00 5065.25 4973.B0 5700,00 5130.11 5038,66 5800,00 5195,13 5103,68 5900.00 52.,50.54 5169.09 6000.00 5326.21 5234.76 6100.00 5392.21 5300.76 6200,00 5458,70 5367,25 6300,00 5525,34 5433.99 6400.00 5591.88 5500.43 6500,00 5658.51 5567.06 6600.00 57Z4.89 5633.44 6700.00 5791.27 569g.~2 6800.00 5858.31 5766.86 6~00,00 59Z6.02 5934.57 7000,00 5994.10 .5902.65 7100,00 6062,49 5971.03 7200,00 6131,05 6039,50 7300,00 6199,90 6109,45 1400,00 6269.25 6177,90 7500.00 6338.43 6246.9H 7600.00 5406.73 6315.Z8 7700,OO 6474.12 6382.67 7800.00 6540.89 6449.44 7900.00 6606.82 6515.37 COURSE DEVIATION AZIMU'TH DEG MIN DEG MIN 30 25 N 20 ~ E 33 22 N 20 44 E 36 39 N Z1 34 E 40 13 N 22 7 E 43 47 N Z1 57 E 46 6 N Z1 46 E 46 37 N 21 4~ E 46 52 N 21 51 E 47 27 N 21 49 E 48 7 N 21 5'5 E 48 43 N Z1 40 E 49 9 N 21 27 E 49 40 N Z! 18 E 49 49 N 21 1Z E 49 4,2 N 2,1 4 E 49 47 N 21 O E 49 35 N ~0 50 E 49 34 N 20 43 E 49 20 N ZO 32 E 49 0 N ~0 1~5 E 48 56 N 20 17 5 48 29 N 20 14 E 4B 11 N lO 5 E 48 16 N 19 5q 6 48 12 N lO ZO E 48 1~ N 20 44 E ~B 30 N 20 54 E 48 14 N Et 26 E 47 33 N 22 ~ ~ 47 15 N 22 39 E 46 56 N 23 31 E 46 43 N 24 59 E 46 34 N 26 25 E 46 24 N 29 35 E 45 54 N 31 35 E 46 32 N 31 4 7 E 47 20 N 31 51 E 47 50 N 3~ O E ~8 24 N 32 7 E 48 58 N 32 19 E EVEN VERTIC SECTI FEE 262. 313. 370. 431. 497. '566. 637. 709. 781. 854. 927. 1001. 1075. 1150. 1225. 1300. 1374. 144'9. 1523. 1597. 100 FEET OF MEASURED OEP'TH ~L DOGLEG RECTANGULAR COORDINATES HURIZ. DEPARTURE ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH T OEG/IO0 :EET ~EET FEET DEG MIN 39 2.75 233.13 q 122.53 E 263.37 N 27 43 E 95 3.03 282.58 N 140.91 E 315.77 N 26 30 E 21 3.36 33~.12 N 161.65 E 372.97 N 25 41 E 14 3.79 393.68 N 1~4.77 E 434.88 N 25 8 E 01 3.18 455.79 N 209.93 5 501.81 N 24 43 E 52 1.14 521.45 N 236.30 E 572.49 N 24 22 E 64 0.76 588.71 N 263.15 E 644.84 'N 24 5 E 26 0.15 656.40 N 290.27 E 717.71 N 23 51 E 20 0.98 724.~7 N 317.54 E 790.91 N 23 40 E 02 0.44 79'3.15 N 345.18 E 865.00 N 23 31 E 43 0.66 862.55 N 372.94 E 939.73 N 23 72 E 42 0.75 932.66 N 400.67 'E 1015.08 N 23 14 E 86 0.9.1 1003.34 N 428.34 E 1090.95 N 23 7 E 75 0.10 1074.56 N 456.03 E 116?.32 N 22 59 E 57 0.26 1145.77 N 483.58 E 1243.64 N 22 52 E 31 0.36 1216.98 N 510.98 E 1319.90 N 22 46 E 99 0.40 1288.23 N 538.22 E 13'96.14 N 22 40 E 49 0.31 1359.39 N 565.24 E 1472.22 N 22 34 E 80 1.00 1430.48 N 592.04 E 1548.16 N 22 29 E 71 0.36 1501.38 N 618.39 E 1623.74 N 22 23 E 1671,36 1744.75 1817,67 1B90.42 196.'3,30 2036.21 2109.41 2182.69 2255.55 2327.95 17 35 59 86 86 06 09 97 40 60 2400. 2472. 2544. 2616. 2688. 2761. 2834. 2907. 2992. 3057. 0.16 1572.13 N 644.49 E 1699.11 N 22 17 E 0..36 1642.60 N 670.55 E 1774.20 N 22 12 E 0.13 1712.71 N 696.29 E 1848.84 N 22 7 E 0.29 1782.77 N 721.81 E 1923.35 N 22 2 E 0.73 1852.86 N 7~7.50 E 1997.96 N 21 58 E 0.20 1922.67 N 773.71 E 2072.51 N 21 55 E 0.31 1992.57 N 800.30 E 21~7.2.~ N 21 52 E 0.83 2062.34 N 827.26 E 2222.07 N 21 51 E 0.82 2131.25 N 854.76 E ~296.27 N 21 51 E 0.5,9 2199.30 N ,882.77 E Z359.85 N 21. 52 E 1.1l 2266.71 N 911.42 E 2443.09 N 21 54 E 0.98 23~3.22 N 941.43 E 2515.99 N 21 58 E 1.66 2398.84 N 972.92 E 2588.63 N 22 4 E 2.19 2462.90 N 1006.90 E Z650.77 N 21 14 E 0.91 2524.80 N 1043.75 E 2732.04 N 22 27 E 0.43 2586.21 N 1081.74 E 2803.32 N ZZ 41 E 1.04 2648.27 N 1120.25 E 2875.47 N 22 55 E 0.49' Z710.97 N 1159.34 E 2948.46 N 23 9 E 0.95 2774.06 N 1198.83 E 3022.02 N 23 22 E 0.33 2837.63 N 1239.00 E ]096.33 N 23 35 E COMPUTATION DATE: 7-M~R-B9 BP EXPLORATION DATE OF SURVEY: Z - 25 PRUDHOE BAY NORTH SLOPE~ ALASKA KELLY BUSHING ELEVATION: ENGINEER: INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH MEASURED DEPTH T RUE VERTICAL DEPTH SUB-SEa VERTICAL DEPTH COURSE VERTICAL DEVIATION AZIMUTH SEC'TION DEG MIN DEG MIN FEET DOGLEG RECTANGULAR SEVERITY NORTH/SOUTH DEG/tO0 FEET PAGE 3 02-MAR-89 91.45 FT D.BARBA 8000.00 8100.00 8200.00 8]00.00 8400.00 8500.00 8600.00 8 [00. O0 8800.00 8900.00 5671.98 6735.91 6798.51 6850.87 6923.46 6986.32 7049.46 '7112.58 7175.61 7238.5'5 6580.53 49 48 6644.4'6, 50 45 670'7.06 51 32 6769.42 51 19 6832.01 51 10 6894.87 50 55 6958.01 50 47 7021.13 50 55 7084.16 50 54 7147.10 51 8 N 31 56 E 3133.44 N 32 27 E 3210.33 N 33 0 E 3288.32 N 33 45 E 3366.48 N 34 38 E 344~.44 N 35 15 E 3522.16 N 36 ~ E 3599.59 N 37 B E 3676.96 N 38 5 E 3754.31 N 3g 2~ E 3831.56 1.OZ 2901.90 N 1279.29 E 3171.37 N 23 47 E 1.36 2966.99 N 1320,22 E 3247.46 N 23 59 E 0.63 3032.5~ N 1362.40 E 3324.56 N 24 11 E 0.65 3097.86 N 1405.40 E 3401.75 N 24 24 E 0.72 3162.38 N 1449.22 E 34T8.63 N 24 37 E 0.59 3226.12 N 1493.79 F 3555.17 N 24 50 E 0.95 3289.09 '.',11539.03 E 3631.36 N 25 4 E 0.65 3351.29 N 1585.37 E 3707.37 N 25 19 E 1.19 3412.82 N 1632.70 E 3783.26 N 25 33 E 0.97 3473.36 ,N 1681.4~ E 3858.94 N 25 49 'E 9000.00 9100.00 9200.00 9300.00 94O0.00 9500.00 9600.00 9100.00 9800.00 9909.00 7300 7352 7424 7486 7549 7612 76}'4 7736 779B 7860 .75 .45 .42 .75 .37 .08 .49 .47 77.09.30 51 53 7!71.00 51 43 7332.97 51 33 7395.30 51 20 745 },. 92 51 5 7520.6;3 51 17 758 3,04 51 27 7645.30 51 32 7707.39 51 45 7'769.02 52 10 N 39 5'1 E 3909.27 N 40 18 E 3987.30 N 40 35 E 4065.07 N 40 59 5 4142.48 N 41 31 E 4219.58 N %2 7 E 4296.46 N 42 8 E 4373.53 N 42 1'5 E 4450.71 N 43 8 ~ 452'7.91 N 44 16 E 4605.20 0.73 3533.57 N 1731.48 E 3934.99 N 26 6 E 0.29 3593.78 N 17'32.15 E 4011.40 N 26 22 E 0.35 3653.50 N 1833.08 E .4087.57 N 25 38 E 0.32 3712.72 N 1834.15 F. 4163.45 N 26 54 E 0.6'9 3771.37 N 1935.51 E /,239.04 N 2'/ 10 E 0.30 3829.36 N 19'37.53 E 431/,.42 N 27 25 E 0.14 3887.29 N 2039.95 E 4390.04 N 27 41 E 0.4'7 3945.29 N 20'92.48 E 4455.85 N 27 56 E 0.96 4002.96 N 2145.58 E 4541.72 N 28 11 E 0.95 4059.87 N 2200.0'1 E 4617.64 N 29 27 E lO00O.O0 10100.00 10200.00 10300.00 10400.00 10500.00 10600.00 IOTO0.UO 10800.00 10900.00 7921 7983 8046 8112 8179 8247 8316 8387 8461 8534 .63 .34 .85 .52 .40 .23 .35 .69 .15 7739.18 52 18 7891.B9 51 16 7955.40 49 45 8021.07 48 20 8987.94 47 40 8155.78 46 53 8224.90 45 26 8Z96.24 42 26 8369.70 ~2 25 8443.~2 42 40 N 45 32 E 4682.51 N 46 21 E 4759.08 N 47 3 E 4~34.01 N 47 33 E 4906.94 N 47 2'9 E 4978.~0 N 47 6 ff 5049.99 N 47 36 E 5119.80 N 48 2~ E 5187.35 N 4~ 54 E 5252.57 N 50 47 E 5317.28 1.01 4115.91 N 2255.86 E 4693.57 N 28 43 E 1.5Z 4170.60 N 2312.43 E 4758.77 N 29 0 E 1.96 4223.5~ N 2368.65 f 4842.41 N 29 17 E 0.47 4274.61 N 2~24.15 E 4914.14 N 29 33 E 0.92 4324.81 N 2479.00 E 4984.92 N 29 49 E 0.97 4374..~5 N 25.32.97 E 5055.05 N 30 4 E 2.13 4423.64 N 2586.10 E 5124.11 N 30 18 E 1.75 4470.45 N 2638.24 E 5190.88 N 30 32 E 0.97 4515.28 N 2689.16 ;- 5255.41 N 30 46 E 1.57 4559.06 N 2740.77 E 5319.49 N 31 0 E 11000o00 11100.00 llZO0.O0 11300.00 11400.00 11500.00 11600.00 11700.00 11800.00 6607.84 8680.31 8753.66 8827.97 8902.74 89 78.1 9054.74 9132.29 9209 8516.39 43 32 8588.86 43 17 8662.21 42 19 8736.52 41 48 8811.29 41 17 8~86.72 40 3~ 8963.29 39 32 9040.84 39 1' 9118.53 39 1 N SZ 6 E 5381.84 N 52 4 E 5446.88 N 52 0 E 5510.94 N 51 0 E 5576.27 N 50 4 E 5637.47 N &8 42 E 5700.29 N 46 4'7 ~ 576Z.40 N 46 8 E 5~Z3.74 N 46 q E 5884.97 1.07 4601.44 N 2794.28 E 5393.43 N 31 16 E 1.15 4643.92 N 2848.53 E 5447.95 N 31 31 E 1.01 4695.60 N 2902.23 E 5511.60 N 31 46 E 0.7,5 4727.25 N 2954.60 E 5574.64 N 32 0 E 0.79 4769.46 N 3005.86 E 5637.63 N 32 13 E 1.94 4812.07 N 3055.80 E 5700.35 N 3~- 24 E 1.92 4855.34 N 3193.38 E 5762.40 N 32 35 E 0.00 4898.93 N 3149.05 E 5823.75 N 32 43 E 0.00 4942.55 N 3194.45 E 5885.01 N 32 52 E C3DRDINATES HORIZ. DEPARTURE- E&ST/WEST DIST. AZIMUTH FEET ~E~T DEG MIN C;.1MPUT~TION DATE: 7-MAR-89 gAGE 4 BP tXI-'LURAT ION Z. - Z5 PRUOHQE BAY NORTH SLOPE ALASKA ZNTERPDLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPTIt TRUE SU6-SEA VERTICAL VERT IC~L DEPTH DEPTH COURSE VERTICAL DOGLEG DEVIATION AZTMUTH SECTION SEVERITY DEG MIN DEG MIN FEET DEG/IO0 0.00 0.00 -91.65 1000.00 999.96 908.51 ZO00.O0 1999.84 1908.39 3000.00 Z999.62 2908.17 4000.00 3947.00 3~55.'55 5000.00 4676.06 4584.61 6000.00 5326.21 5Z34.76 ?OOO.O0 5994.10 5902.55 8000.00 5671.9~ 6580.53 9000.00 1300.75 7209.30 0 0 N 0 0 E 0.00 0.00 0 39 S 10 11 E -6.80 0.00 0 47 S 21 38 E' -16,49 0.00 3 35 N 28 24 E -25.46 2.24 30 25 N 20 5 E 262.39 2.75 ¢8 43 N 21 40 5 927.43 0.66 48 56 N 20 17 E 1671.36 0.16 46 56 N 23 31 E 2400.17 1.11 49 48 N 31 56 F 3133.44 1.02 51 53 N 39 51 E 390'9.27 0.73 10000.00 7921.63 7830.18 11000.00 8607.84 8516.39 11800.00 9209.98 9118.53 52 lB N 45 32 E 4582.51 1.01 43 32 N 52 6 E 5381.84 1.07 39 I N 46 8 E 5884.97 0.00 D~TE OF SURVEY: O2-MAR-89 KELLY 'BUSHING ELEVATION: 91.45 FT ENGIN.~ER: D. BARBA MEASUR RECTAN NORTH/ . 6. ~0. 32. 233. 862 · 1572. 2266. 2901. 3533. ED DEPTq GULAR CgORDIN~TES MORIZ. DEPaRTURe. SOUTH E~ST/WEST DIST. AZIMUTH T ':EET FEET DEG MIN O0 N 0.00 E 0.00 N 0 0 57 S 2.35 W 6.98 S 19 38 98 S 2.17 E 21.09 S 5 54 70 S 3.83 E 32.92 S 6 40 13 N 122.53 E 263.37 N 27 43 55 N 372.94 E 939.73 N 23 22 13 N 644.49 E 1699.11 'N 22 17 71 N 91!.42 E ~443.09 N 21 54 90 N 1279.29 E 3171.37 N 23 ,47 57 N 1731.48 E 3934.99 N 25 6 E W F E E E 4115.91 N 2255.86 E 4693.57 N 28 43 E 4601.44 N 2794.28 E 5383.43 N 31 16 E 4942.55 N 3194.45 E 5885.01 N 32 52 E COMPUTATION DATE: 7-MAR-89 BI-' EXPLORa, TtON Z - 25 PRUDHOE BAY NORTH SLOPE, AL~,SKA KELLY MtA$URED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH COURSE VERTICAL DOG DEVIATION AZIMUTH SECTION SEV DEG MIN DEG MTN FEET OEG 0.00 91.45 191.45 291.45 391.45 491.46 591.46 691.47 791.4`7 891.48 TRUE SUB-SEa VERTICAL VERTICAL DEPTH OEPTH 0 0 N 0 O E 0.90 0 4 N 10 53 W -0.08 0 15 S 51 26 W -0.23 0 13 S 19 50 W -0.64 0 18 S 39 10 W -1.10 0 26 S 30 22 W -1.78 0 31 S 22 33 W -2.60 0 40 S 14 43 W -3.62 0 40 S 9 40 W -4.73 0 42 S 0 ~ E -5.77 991.49 1091.49 1191.50 1291.51 1391.53 1491.54 1591.56 1691.58 1791.59 1891.60 0.00 -91.45 91.45 0.00 191,.45 100.00 Z91.45 200.00 393..45 300.00 491.45 400.00 591.45 500.00 691.45 600.00 791.4'5 ?OO.O0 891.45 800.00 0 40 S 9 53 E -6.73 0 40 S 11 11 E -7.57 0 45 S 11 55 E -~.48 0 54 S 11 57 E -9.58 0 59 S lg 56 E -10.64 1 5 S 23 2'7 E -11.69 I 7 S 25 13 E -12.75 0 51 S 14 Zl E -13.77 0 51 S 16 3'3 E -14.77 0 42 S 15 52 E -15.52 1991.60 Z091.61 2191.62 2291.64 2391.65 2491.67 2591.70 2691.'~Z Z791.74 ZB91.74 991.45 900.00 1091.45 1000.00 1191.45 1100.00 1291.45 1200.00 1391.45 1300.00 14'71.45 1400.00 159'1.45 1500.00 1691.45 1600.00 1791.45 1700.00 18~1.45 1900.00 0 47 S 21 34 E -15.42 0 49 $ 20 33 E -17.22 0 50 S 18 50 E -18.08 1 1 S 4 '1 E -19.25 1 5 S 3 4 3 W -ZO. 79 1 12 S 12 41 W -22.64 1 1Z S 16 39 W -24.68 I 9 S I~ 19 W -26.69 1 3 S 9 40 W -28.57 0 21 N 75 34 E -2'9.17 2991.81 3092.17 3193.05 3294.77 3391.55 3501.63 3607.23 3714.66 ~823.91 ~936.11 1991.45 1900.00 Z091.45 2000.00 2191.45 2100.00 2291.45 2200.00 2391.45 2300.30 2491.45 2400.00 2591.45 2500.00 2691.45 2600.00 2791.45 Z700.OO 2891.45 2800.00 12 '14 17 20 22 28 LEG RECTANGULAR E'RI TY NORTH/SOUTH /100 FEET Z991.45 2900.00 3091.45 3000.00 3191.45 3100.00 3291.4,'5 3200.00 3391.45 3300.00 3491 .~5 3400.00 3591.45 3500.00 3691.45 3600.00 3791.45 3'100.00 3891.45 3800.00 D~TE 38 SH lNG OF SURVEY: ELEVATION: ENGINEER: PAGE 5 O2-MAR-89 91.45 FT D.EARBA COORD'IN~TES HORIZ. DEPARTURE E~ST/WEST DIST. AZIMUTH FEET FEET DEG MIN 0.00 0.00 N 0.00 E 0.00 0.11 0.12 N 0.34 W 0.36 0.37 0.12 N 0.62 W 0.63 0.00 0.25 S 0.80 W 0.84 0.00 0.6'3 S 1.06 W 1.23 0.00 1.15 S 1.45 W 1.87 0.00 1.92 S 1.qZ W 2.64 0.00 2.93 $ 2.14 W 3.62 O.OT 4.08 S 2.40 W 4.73 0.00 5.26 S 2.48 W 5.82 0.00 6.47 S 0.12 7.61 S 0.08 8.86 S O. 20 10.33 S 0.23 11.91 S 0.04 13.60 S 0.06 15.37 S 0.00 16.97 S 0.14 18.42 S 0.21 19.66 S 2.36 W 6.89 2.15 ~ '7.91 1.89 W 9.06 1.63 W 10.46 1.13 W 11.97 0.46 W 13.60 0.35 E 15.37 0.95 E 17.00 1.36 E 18.4`7 1.72 E 19.73 2.13 E ZO.9B 2.64 E 22.31 3.12 E 23.68 3.40 E 25.28 3.42 E 27.10 3.10 E 29.05 2.57 E 31.06 1.96 E 33.01 1.55 E 34.97 1.6.! E 35.72 3.59 E 33.33 7.44 E 26.83 13.4 ;J E 19.43 22.34 E 22.46 33.53 E 40.80 46.46 E 57.47 61.15 E 100.Z6 77.82 E 138.83 94.08 E 182.01 111.71 E 232.12 0.00 20.87 S 0.00 22.15 S 0.16 23.47 S 0.24 25.05 S 0.32 26.89 S 0.01 28.8B S 0.00 30.95 S 0.41 32.96 S 0.54 '34.94 S 1.77 35.68 S 24 N 29 17 c -25.96 2.43 33.14 S 7 N 26 49 ~ -17.68 1.07 25.77 S 4 N 27 57 E -4.50 2.29 13.99 S 1 bi 27 50 F 13.96 2.66 2.26 N 3q] N Z7 3~3 E 37.6_~ 2.49 23.17 N 19 N 25 25 E 66.26 2.51 48.93 N 15 N 26 27 E 99.38 2.69 79.44 N 28 N 23 20 E 138.79 2.60 114.97 N 9 N ZO 41 E 181.94 3.1Z 155.81 N 43 N 20 3 E 231.59 2.66 203.47 N S S ' S S S S N 0 0 E N 69 49 W N 78 35 W 57247 W 59 9 W 50 43 W 'x 43 Z8 W 36 11 W 30 25 W 25 15 W S ZO 2 W S 15 44 W S 1Z 0 W S 8 56 W S 5 25 W S 1 55 W S 1 17 E S 3 11 E S 4 13 E 5 4 59 E S 5 49 S 6 47 S 7 34 S 7 44 S 7 15 S 6 7 S 4 44 S 3 23 S Z 33 S 2 35 E E E E E S 6 10 E S 16 5 E S 43 57 E N 84 13 E N 55 23 E N 43 30 E N 37 35 'E N 34 5 E N 3! 7 E N 2~ 46 E COMPUTATION D.~TE: 7-M~R-8g PAGE BP EXPLORATION O&TE OF SURVEY= OZ-M~R-89 Z - 25 KELLY ~USHING ELEVATION: 91o45 FT PRUDHOE BAY NORTH SLOPE, ALASKA ENGINEER: g.~ARBA INTERPOLA'TE9 VALUES FOR EVEN lOg ~EET OF SUB-SE~ DEPTH TRUE SUB-SE~ COURSE VERTICAL DOGL'SG RECTANGULAR COORDINATES HORIZ. DEPARTURE. MEASURED V~RT[CAL VERTICAL DEVIATION A]T.~UTH S'ECTIgN SEVERITY NORTH/SOUTH E6ST/WEST Df[ST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/100 FEET FSET FEET DEG ~051.91 J991..45 3900.00 31 54 N ZO 22 E 288.56 3.10 258.28 N 131.79 E 289.96 N 27 4172.27 4091.45 4000.00 35 44 N 21 21 E 354.08 3.32 320.82 N 155.63 'E 356.58 N 25 52 4299o01 4191°45 4100.00 40 10 N 22 '7 E 430.51 3.80 393.08 N 194.5.2 E 434.2'3 N 25 8 E ~35°01 4231.45 4200.00 44 48 N 21 56 E 521.03 2.5! 478.47 N 219.06 E 526.23 N 2~ 36 E ~578°82 4391.45 4300.00 46 29 N 211 45 6 622.52 0.23 574.42 N 257.43 ~ 629.47 N 24 8 E 4724°91 4491.45 4400.00 46 54 N 21 52 ~ 727.12 0.28 673.27 N 297.04 E 735.89 N 23 48 5 4872°79 4591.45 4500.00 48 ! N 21 56 E 834.13 0.88 774.37 N 337.62 E 8~4.77 N 23 33 E 5023.~4 4691.45 4600.rJO 48 51 N 2:1 37 E 944.66 0.31 878.86 N 379.42 E 957.27 N 23 21 E 5176.20 4791.45 4700.00 49 28 N 21 21 E 1059.07 1.02 986.4~ N 421.75 E 1072.82 N 23 8 E 5331.12 ~891.45 4800.00 49 49 N 21 11 ~. 1174.06 0.10 1096.72 N 464.63 E 1191.08 N 22 57 5485.86 ~,9'~1.45 4900.00 49 46 N 21 1 E 1289.'74 0.29 1206.90 N 507.11 E '1309.11 N 22 47 E 5640.40 5091.45 5000.00 49 32 N 20 4~ E 1405.09 0.41 1316.97 N 54'9.15 E 1426.87 N 22 38 E 5794.35 5191.45 5100.00 /,9 20 N 20 33 E 1519.61 0.91 1426.47 N 590.54 5 1543.~7 N ZZ 29 5947.08 5291.45 5200.00 48 55 N 20 14 E ~.632.39 0.23 1534.70 N 6'30.68 E 1659.23 N 22 20 609~°86 5391.45 5300.00 48 29 N 20 14 E 1'743.92 0.36 1641.80 N 6'70.25 E 1773.3~ N 22 12 E 6249°12 5491.45 5400.00 48 11 N 20 O F. 1853.~0 0.15 1747.11 a 708.84 E 1885.43 N Z! 5 E 6399.36 5591.45 5500.00 48 1.~ N 20 20 E 1962.83 0.74 1852.42 N 747.34 E [997.49 N 21 58 ~549.55 5691.45 5600.00 48 24 N !0 4~J E 2077..44 0.43 1957.28 N 7~6.85 ~ Z109.52 N 21 54 6700.27 5791.45 5700.00 48 14 N 21 26 E 2182.88 0.83 2062.53 N 8~7.33 E Z222.27 N 21 51 E 6849.01 5891.~5 5800.00 47 20 N ;~2 22 E 2291.06 0.32 21~4.68 N 868.41 5 233Z.3q N 21 51 E 6996.12 5991.4~ 5900.00 46 57 N 23 28 5 ;'397.37 1.07 2264.11 N 910.30 5 2440.25 N 21 54 E 7142.30 6091.45 6000.00 40 44 N 25 30 5 2502.'92 0.87 2361.10 N 954.57 E Z546.76 N 22 0 E 7287.74 6191.45 6100.00 46 26 N 29 11 E 2607.99 ;'.41 2455.14 N 1002.57 E 2651.96 N 22 12 E 7431.96 6291.45 6200.00 46 5 N 31 4% 5 2711.85 0.94 2544.37 N 1055.82 E 275~.74 N 22 32 E 7577.50 61391.45 6300.00 47 8 N 31 50 E 2817.57 0.75 2634.24 N 1111.53 E 2859.15 N 22 52 E 7725.85 6491.~5 6~,00.00 47 58 N ~2 0 E 2927.15 0.63 2727.23 N 1159.~0 E 2967.41 N 23 12 E 55 N 32 22 E 3039.95 0.29 2822.73 N 12!9.56 E 3078.90 N 23 32 E 7876.60 6591.45 6500.00 8030.25 6691.45 6600.00 50 4 N 32 1 ~ 3156.59 0.84 2921.53 N 1291.55 E 3194.29 N 23 50 E B188.66 6791.45 6100.00 51 30 N 32 56 E 3279.44 0.71 3025.13 N 1357.57 E 3315.78 N 24 10 E 8348°89 6891.45 6800.00 51 14 N ~, 9 5 3404.52 0.73 3129.52 N 1426.70 E 34'39.33 N 24 30 8508o1~, 6991.45 6900.90 50 54 N 35 20 E 3:528.47 0.60 3231.27 N 1497.45 E 3561.38 N 24 51 E 8666.%9 7091.45 7000.00 50 53 N 36 51 F 3651.03 0.68 3330.52 N 1569.71 E 3681.90 N 25 14 E 8~25.12 ]'191.45 7100.00 50 56 N 3~ 29 E 3773.72 1.32 3428.14 N 1644.78 E 3802.29 N 25 37 E 8984.95 7291.45 7200.00 51 47 N 39 49 E 3897.53 0.63 3524.4~ N 1723.90 E 3923.50 N 26 3 9146.~7 7391.45 7300.00 51 44 N 40 26 5 4023.79 0.46 3621.83 N 1806.01 E 4047.1& N 26 30 950i'.52 1491.45 7400.00 51 19 N 41 1 E 4148.29 0.30 3717.15 N 1888.01 5 4169.14 N 26 55 E 9467.04 7591.45 7500.00 51 1Z N 4;' 1 E 4271.11 0.68 3810.28 N 19i'0.30 E 4289.56 N 27 20 E 9627.23 7691.45 7600.00 51 28 N 42 8 E 4394.54 0.09 3903.09 N 2054.25 E 4410.67 N 27 45 E 9788.07 7791.45 7700.90 51 43 N 43 0 E 4518.70 0.96 3996.11 N !139.20 E 4532.67 N 28 9 E 9950.5l '1891.45 7800.00 52 19 N 44 53 E 4644.36 1.06 4088.37 N 22!8.12 E ~,656.10 N 28 35 E BP EXPLORATION Z - 25 PRUDHOE BAY NURTH SLOPE, ALASKA COMPUTATTON DATE: 7-MAR-B9 PAGE 7 DATE OF SURVEY: 02-MAR-89 KELLY BUSHING 'ELEVATION: 91.45 F'T ENGINEER: D.BARBA INTERPOLATED VALUES FDA EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MkASURtD VER'IICAL VERTICAL DEVIATION ~ZIMUTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 10112.97 7991.45 7900.00 51 6 IOZT~.ZO 80~1.45 8000.00 48 37 10%17.8~ 8191.¢5 BlO0.O0 47 31 10564.27 8291.45 8ZO0.O0 46 11 10705.17 8391.45 8300.90 43 22 10841.11 8491.45 8400.00 42 37 10977.45 8591.45 8500.00 43 18 11115.29 8691.45 8600.00 43 10 11Z50.~7 87'~1, . 45 8700.00 41 57 11384.95 8891.45 8800.00 41 23 1151'7.49 8991.45 8900.00 40 24 11647.47 9091 .45 9000.00 39 1 ll~JOO.O0 9209.95 9118.53 39 1 DEG MIN FEET DEG/IO0 =E~T FEET FEET DEG MIN N 46 29 E 4763.92 N 47 30 E 4883.93 N 47 24 E 4991.54 N 47 24 E 5095.03 N 4~ 28 E 5190.75 N 49 24 E 5Z79.Z3 N 52 1 E 5367.Z3 N 52 1! E 54~6.75 N 51 27 E 5543.26 N 50 1Z E 5~27.98 N 48 ZO E 5711.24 N 46 14 E 5791.51 N 46 B E 5884,97 I .19 I .21 0 1.56 1.55 1.22 1.18 0.86 1.03 0 .~Z 1.80 ~. 0.00 4177.59 N 2319.75 E 4778.44 N 29 2 E 4258.53 N 2406.58 f 4891.50 N 29 28 E 4333.72 N 24[J8.71 E %997.48 N 29 52 E 4406.33 N 2567.20 E 5099.63 N 30 13 E 4472.80 N 2640.90 E 5194.25 N 30 33 E 4533.47 N 2710.18 E 5281.80 N 30 52 E 4591.92 N 2782.07 ~ 5368.95 N 31 12 ~ "~ 4650.35 N 2856.80 E 5457.75 'N 3l 33 E ) 4706.7~ N 2929.09 5 5543.75 N 31 53 E 4763.09 N 2998.2Z E 5628.17 N 3~ 11 E 4819.60 N 3064.35 E 5711.28 N 3Z 26 E 4876.04 N 3125.21 E 5791.61 N 32 39 E 4942.55 N 3194.45 E 5885.01 N 3Z 52 E SCHLUMBERGER O I RECT I ONAL SURV E Y COMPANY BP EXPLORATION WELL Z- 25 FIELD PRUOHOE BAY COUNTRY USA RUN ONE DATE LOOOEO 02 - MAR - 88 REFERENCE WELL' Z-25 (11-17-11-12) (721' SNL, 1809' EWL, SEC 19, TllN, R12E) HORIZONTAL PROJECTION N0~TH ~000 5OOO 4OOO 2OOO 1000 -~000 -~000 NEST R~F 79166 SCALE : ]/1000 [N/FT -%-~-..--.-..-*-~-*"~---*.-T-_-r-r-4--~.~?* ..... ?-?-.'r?-. --,-++~. .... *-~-+--: ......1 I q-" !! i~ ~7~ TT' i-i T ~ -,T'TTi---i-Ti-YI-F'.:"T'F--TTi-?.-!"~--::-i-'~ :~--~',:~.-TT: :T --'..,:~;: ,z:.'_.:~:~::F ¥~:~:;:I:-~::~:~:::.'.:: :::::::::::::::::::::::: :::::::::::::::::::::::: ::::::::::::::::::::::::: :::::::::::::::::::::::::::::: ::::::::::::::::::::::::::: r't'?'i-'i-l~??i-i-;'' ";-hi:;'i-','t'l"?!--~'i'" --t-'!-t'-t'--!-'?-i-i-"-'t-t-'i-'(-]-'t-t'"t-'t--!---f-i-.t.-*;.-e---t:--t--t ...... i-t-.?f-,.-+--H--+-.-%t.--!..-t---..'--;---~.-.?.; ...... 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PROJECTION ON VERTICAL PLt:It~ 33. - 213. ,~.ED IN VF. RTIC~L DEPTJ-6 HORIZ SCALE = 1/lO00 IN/FT -. ; . ~-,..; :;. <,..~,, .,,,. ?_,.:;:, ::: .... :.;8 GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY m BP EXPLORATION .................... ~ '~( ~-:~ -~ ..... COMPANY _~ Z-25 ' ~ ~'~ ~ ' ~"~ WELL NAME WEST EILEEN LOCATION ALi$9-D5 SINGLE SHOT & MWD 2/21/89 mmm--mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm LYNN HENSLEY DIRECTIONAL TOM DUNN SUPERVISOR NAME TITLE SIGNATURE 372 FT 10934 FT DEPTH INTERVAL FROM TO 2/05/89 2/20/89 DATE SURVEY TAKEN FROM TO THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. ORF. AT LAND DIRECTIONAL. DRIL. L. TNG, INC C].~ eh1; .............. : BP EXPL.ORATZON We]] ................ : WEST EIL..EEN ~ Z-25 Vertical Section at.: N ~,-q..49 E M~.qnetJc Declination: 30 deg 48 mtn E Ddtcl fJ]e no, me ...... : R:WZ25D.DAT RECORD OF SURVEY (We'll c~ssumed ve:c. 1;Jco] 1;o MD of 2/21/8~ ComputotJon: RADIUS OF CURVATURE Survey do1;e: 2/13/89 Method ..... : SINGLE SHOT & MWD RK8 Height.: 91.S ft 0.0) "4FAS DRIFT TRUVERT SURSFA SECTION 2PTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGLE FRON WEL.L-HFAD 0 0 0 0.00 -9]..45 0.00 N 0.00 E 0.00 N 372 0 0 372.00 280.55 0.00 N 0.00 E 0.00 N 900 0 45 899.98 808.53 -3.17 S 10.00 W 3.40 S 1383 ]. 0 1382.93 1291.48 -9.80 S S.O0 W 10.71 S ~.842 ]. 0 1841.86 1TSO.41 -15.49 S 26.00 E 18.49 S 0.00 E 0.00 E 0.60 W 1.56 W 0.12 W 2'670 2. ].5 2669.70 2578.25 2800 ]. ].2 2799.~7 2708.22 3045 4 42 3044.3]. 2952.86 3232 10 ].8 3229.~3 3138.].8 .... 3422 iS 24 3414.8]. 3323.36 -28.2]. S 20.00 W -30.82 S 6.90 W -28.50 N 30.40 E -4.13 N 31.20 E 38.05 N 29.70 E 34.30 S 36.99 S 39.88 S 2.8.93 S 17.49 N 0.71 E 0.06 E 8.63 E '21.).2 E 42.53 E 359]. 20 36 3575.49 3484.04 3790 24 ].2 3759.44 3667.99 3976 29 48 3925.].0 3833.65 4].60 35 30 4079.96 3988.S1 4349 42 24 4226.86 4135.41 90.12 N 2..9.00 E ].65.10 N 21.50 'E 247.53 N 20.60 E 344.59 N 22.40 E 461.31 N 23.40 E 62.99 N 13]..52 N 210.30 N 302.62 N 412. O0 N 68.11 F 100.43 E 2.30.75 E 167.12 E 213.32 E 4536 46 12 4360.67 4269.22 589.95 N 23.80 E S31.65 N SOOS 48 30 4~78.40 4586.95 929.75 N 23.40 E 847.73 N 5288 49 42 4863.69 4772.24 2.2.40.47 N 23.80 E 1043.75 N 5576 49 42 S049.~7 4~58.52 1356.37 N 22.00 E. 1246.08 N S857 49 6 S~32.83 S141.38 ].565.70 N 22.70 E 1443.40 N 265.60 E 403.69 E 489.33 E 574.79 E 655.92 E 6141 48 2.2 S420.46 S329.01 2.774.88 N 22,00 E 1640.58 N 736.99 E 6420 48 ~ 5~06.60 55].5.15 1978.43 N 21.70 E 1833.47 N 814.34 E 4794 47 24 S858.07 S764.62 2250.09 N 23.10 E ,2089.42 N 919.83 E 7075 46 42 6049.53 S958.08 2453.30 N 26.20 E 2276.33 N 1005.61 E 7342 46 6 6233.65 6].42.20 2645.99 N 31.90 E 2445.29 N 1099.45 E CL.OSURF DISTANCE DG MN S 0.00 N 0 0 0 E 0.00 N 0 0 0 E 3.46 S 10 0 0 W ].0.83 S 8 17 52 W 18.49 S 0 22 23 W 34.30 S ]. 10 Sc4 E 36.99 S 0 S 49 E 40.8]. S ].2 2.2 ].2 E 28.36 S 48 8 2 E 45.98 N 47 38 44 E 92.78 N 47 2.4 13 E ].65.48 N 37 2]. 60 E 247.63 N 31 52 17 E 345.69 N 28 54 34 E 443.95 N 27 22 26 E S94.31 N 26 32 4.3 E 938.95 N 25 27 SO E 1152.76 N 25 7 S E 1372.26 N 24 45 47 E 1585.45 N 24 26 2.8 E ].798.51 N 24 11 27 E 2006.18 N 23 S4 SS E 2282.93 N 23 45 39 E 2488.56 N 23 SO 3 E 2681.09 N 24 12 35 E DOG L.EG deg/].O0 0.000 0.000 O. 142 0.0S2 0. 002 0.030 O. 03~ 1. 492 2. 995 2. 685 3. 077 1 3.0].2 3. 115 3. 659 2. 035 O. 492 O. 43E O. 364 O. 257 0. 345 0.07C 0.27t 0.63E 1. 132 WEST EZL.EEN /;f Z-25 2/21/89 RECORD OF SURVEY MEAR DR)FT TRUVERT RURREA SECTION DEPTH ~ MN DEPTH DEPTH DISI' DIRECT]ON RELATIVE COORDINATES ANGLE FROM WELL-HEAD 7726 47 S4 4495.53 4404.08 2924.79 N 33.40 E 2481.47 N 1251.37 81.03 SO 34 6741.40 4450.15 3212.34 N 32.90 E 2920.29 N 1407.95 829~ SI. 12 4860.80 4749.35 3359.02 N 35.00 E 3041.95 N 1489.85 8575 SO 42 7039.08 ~947.43 3578.45 N 34.10 E 3220.7~ N 1417.43 9046 SI. S4 7333.57 7242.12 3944.68 N 41.00 E 3508.14 N 1844.64 9402 SI. 6 7555.18 7463.73 4220.43 N 42.40 E 371&.15 N 2031.97 E ~794 SI. 30 780]..53 7710.08 4523.26 N 44.S0 E 3939.37 N 2243.42 E ].0072 S2 0 7972.40 7880.95 4735.22 N 46.40 E 4091.14 N 2398.14 E 102~]. 49 0 8092,~0 800]..].5 4874.49 N 48.40 F 4189.45 N 2505.45 E J. 0437 47 48 8209.45 8].].8.00 S003.87 N 48.40 E 4277.03 N 2404.07 E 10634 45 6 8346.SS R2SS.IO 5].43.00 N 49.10 E 4372.12 N 2712.49 E ].0831 42 30 8487.28 8395.83 S272.52 N SO.SO E 4459.23 N 28].S.57 E ].0934 43 0 8562.91 8471.44 S338.8~ N S3.30 E 4502.36 N 2870.58 E CLOSURE DISTANCE DG MN S 2959.08 N 25 I 2 E 3241.97 N 25 44 24 E 3387.20 N 24 S 39 E 3604.17 N 24 40 4 E 3964.48 N 27 45 42 E 4235.4]. N 28 40 ].0 E 4533.38 N 29 39 40 E 4742.2]. N 30 22 4]. F 488]..75 N 30 S2 S4 E 5007.4]. N 3]. 20 4 E S145.20 N 31 48 S7 E S273.72 N 32 ].6 6 E S339.62 N 32 3]. 14 E DOG LEE de.q/lOC O. S2E O. 72~ O. 746 O. 29~:. 0.6~E O. 32? O. 34~. 0.506 1.67? O. 482 1.34~. 1. 372 1.35~ WEST ElL.FEN E Z-25 DATA INTERPOLATED FOR EVEN ,1.00 FEET OF SUBSFA DEPTH 2/21/89 NEAS. TRU VERT SUR SEA ND-TVD VERTICAL DEPTH DEPTH DEPTH DIFF. CORRECT 9,1. 9,1. 0 0 0 191 19,1. 100 0 0 29,1. 291 200 0 0 391 39,1. 300 0 0 ~9]. 491 400 0 0 S9,1. S9,1. SOO 0 0 ~9,1. 49,1. ~00 0 0 79,1. 791 700 0 0 89,1. 89,1. 800 0 0 991 99,1. 900 0 0 109,1. 1091 ,1.000 0 0 1191 1191 1100 0 0 1292 ,1.291 1200 ]. 1 1392 ].39,1. ].300 I 0 1492 1491 1400 ,1. 0 1592 1S91 ].SOO I 0 1692 ,1.691 1600 1 0 ].79~ 1791 1700 I 0 1892 189,1. 1800 I 0 1992 199,1. 1900 I 0 2092 2091 2000 1 0 7192 2,1.91 2].00 I 0 2292 2293. 2200 1 0 2392 2391 2300 1 0 2492 2491 2400 1 0 2S92 RS91 2500 1 0 2692 2691 2600 I 0 2792 279,1. 2700 I 0 ?892 7891 2800 I 0 2992 2991 2900 1 0 RELATIVE COORDINATES FRON WELL-HEAD 0.00 N 0.00 E 0.00 N 0.00 E 0.00 N 0.00 E 0.13 S 0.02 W 0.77 S 0.14 W 1.41 S 0.25 W 2.06 S 0.36 W 2.70 S 0.48 W 3.3S S 0.59 W 4.79 S 0.78 W 6.30 S 0.98 W 7.82__ s .1..i8 W · 9.33 S 1.38 W 10.86 S .1..~4 W 12.~5 S ,1..22 W 14.2S S 0.91 W 1S.94 S 0.S9 W 17.64 S 0.28 W 19.44 S 0.07 W 21.35 S 0.03 E ?.3.26 S 0.13 E 25.17 S 0.23 E 27.08 S 0.33 E 28.99 S 0.43 E 30.89 S 0.S3 E 32.80 S 0.63 E 34.7S S 0.60 E 36.82 S 0.10 E 38.08 S 3.28 E 39.26 S 6.78 E WEST F]L.EFN E Z-25 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBREA DEPTH 212].189 NEAS. TRU VERT SUB SEA ND-TVD VERTICAL. DEPTH DEPTFI DEPTH DIFF. CORRECT 3093 309]. 3000 3].93 3].9]. 3].00 3295 329]. 3200 3398 339]. 3300 3503 349]. 3400 3608 359]. 3500 17 S 37].~ 369]. 3600 25 8 382~ 3?9]. 3?00 35 10 3938 389]. 3800 47 12 4055 399]. 3900 64 l? 4].7S 409]. 4000 84 20 4303 4191 4100 112 28 ~439 429]. 4200 148 38 4581 439]. 4300 190 42 4729 449]. 4400 238 48 4877 4S91 4S00 286 48 S025 4691 4600 334 48 S].78 4791 4700 387 S3 5331 489]. 4800 440 53 S48~ 499]. 4900 49S SS S640 S09]. SO00 549 Sq S793 S].9]. SlO0 602 S3 5946 529]. S200 655 S3 6097 S39]. 5300 706 S1 62~7 S491 S400 7S6 SO 6397 S591 SSO0 806 SO 654~ S69]. S600 855 49 ~695 S79]. S700 904 49 ~843 S89]. S800 952 48 6990 S99]. S900 999 47 RELATIVE COORDINATES FROM WEL.[.-HEAD 34.SS S 11.80 E 23.24 S ].8.54 E &.77 S 28.2~ E 1~..8.9 N 39.82 E 39.19 N S4.73 E ~8.94 N 70.92 E 10~.].9 N 88.49 E 146.74 N 106.29 E ].94.29 N ].24.S9 E 249.8S N ].4~.33 E 311.17 N ].70.73 E 385.63 N 202.18 E 469.76 N 238.S& F S62.28 N 278.98 E 661.76 N 322.4~ E 761.23 N 86]..54 N 967.32 N 1073.90 N 1182.52 N 3/.;S. 90 E 409.72 E 4SS. 94 E S02.06 E S47.94 E 1290.84 N 1398.7S N 1SOS. O0 N 1610.09 N 1714.14 N S93.20 E 637.S6 E 681.2S E ?24.46 E ?66.49 E 1817.77 N 19].9.83 N 2021.61 N 2122.01 N 2219.63 N 808.04 E 849.94 E 891.89 E 934.79 E 979.S9 E WFST F]L.EF.N ff Z-2..5 DATA ]NTERPOL.ATED FOR EVEN 100 FEFT OF SUBSEA DEPTH 2/21/89 MF.AS. TRU VERT SUB SEA MD-TVD VERTICAL DEPTH DF.PTH DEPTH DIFF. CORRECT 7281 7427 7573 77~0 7873 80~6 8]82 834]. 8499 8659 8819 8979 9].39 9300 9460 9620 9780 ~010~ ]0259 ]0410 ]O556 ]0698 ]0837 6093. 6000 1045 46 619]. 6]00 1090 45 629], 6200 1].36 46 6391 6300 1182 46 649~ 6400 1229 47 659] 6500 ].282 53 669~ 6600 ]335 53 679~. 6700 1391 56 689]. 6800 1450 59 699~. 6900 ]508 58 709]. 7000 1568 60 719]. 7],00 1628 60 7291 7200 1688 60 7391 7300 1748 60 7491 7400 1809 61 759] 7500 1869 60 769~ 7600 1929 60 7791 7700 1989 60 7891 7800 2050 61 7991 7900 2111 61 809]. 8000 2168 57 819~ 8100 22].9 51 899~ 8200 2265 46 8391 8300 2307 42 849] 8400 2346 39' RF.I. ATIVE COORDINATES FROM WELL-HEAD 2314.80 N 2406.56 N 2497.41N 2587.60 N 2677.79 N ],026.97 E 1077.94 E 1],32.98 E ]249.00 E 2774.56 N 2871.62 N 297].]7 N 3072.69 N 3]72.98 N ],312.40 F.. ]376.04 E ]442.20 F. ]511.82 E ],583.49 E 327].86 N 3369.4S N 3467.04 N 3562.47 N 3656.33 N ].658.35 ]736.12 1813.88 1895.04 ].978.67 3749.0]. N 3839.63 N 3930.24 N 4019.24 N 4106.76 N 2063.10 E 2].48.94 E 2234.77 E 2324.85 E 24].S.18 E 4188.7] N 4263.57 N 4333.91N 4399.92 N 446].6] N 2504.62 2588.90 2668.92 2745.38 28].8.60 WEST EII..EL:N ~ Z-25 DATA INTERPOLATED FOR EVEN '1000 FEET OF MEASURED DEPTH MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH RELATIVE COORDINATES FROM WEI. L.-HEAD ~000 1000 PO9 4.P2 S 0.80 W MO00 2000 1POP 21.51S 0.04 E 3000 ~9~ 2~08 3~.35 S 7.05 E 4000 3~4S 3854 222.34 N .135.4~ E SO00 467S 4S84 844.36 N 402.22 E &O00 5327 523~ 1542.&8 N &P&.74 E 7000 SP~8 SP07 222&.44 N P8~.7.1E 8000 6&74 &S83 2855.04 N 13&5.17 E ~000 7305 7214 3480.07 N ],824.~7 E ~0000 7~8 7837 405'1.5S N ~357.78 E 5OO iO00 i500 2000 ?.500 3000 35O0 4000 4500 5000 55OO 6000 6500 7000 750O BO00 8500 ~000 -500 VERTICAL SECTION BP EXPLORATION ~EST EILEEN # Z-25 ,m SECTION AT N 33.49 E TVD SCALE · i inch = lO00 feet ,.. DEP SCALE' i inch - t000 feet DRAWN '2/2t/89 ~ 0 o 0 ' B) ~ io~ ~ ~ .... ~ ,,, _ ...... ..... "' 0 500 tO00 t500 2000 P.500 3000 3500 4000 4500 5000 5500 Departure 5200 4BO0 440O 4000 3600 3200 2BO0 2400 2000 t600 i200 BOO 4OO 400 14~ke~ Identification ~ TVD DEPRT ~JKB o o o BI TD i0934 B563 5339 HORIZONTAL VIEW BP EXPLORATION WEST EILEEN # Z-25 CLOSURE: 5340 ft N 32.5 E DECLINATION: 30.BO deg E SCALE: i inch - BO0 feet DRAWN: 2/2i/B9 / ! ! ! ! ! ! ! ! ! ! , ! ! ! ! ! . , ! ! ! ! ! ! /! ~F ,I ..... , . 400 0 400 800 i200 1600 2000 2400 2BO0 3200 3600 4000 4400 .- TEL~ Teleco Oilfield Se~ s. of Alaska Inc. 6116 Nielson Way - Anchorage, AK 99502 (907) 562-2646 February 21, 1989 JOB #684 BP EXPLORATION (ALASKA) INC. WELL: Z-25 PRUDHOE BAY RIG: AUD # 2 Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to BP Exploration (Alaska) Inc. Teleco is committed to providing the highest quality MWD service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Dave Reimer Field Service Supervisor DR/el Enclosures · A ~r~l~T COMPANY TELECO OILFIELD SERVICES JOB# 684 SURVEY CALCULATIONS Date Page, 02/20/89 Company: BP EXPLORATION Well: Z-25 Location: PRUDHOE BAY Rig: A.U.D.I. #2 TELECO Job # 684 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 30,80 degrees 30.80 degrees 33.49 degrees RADIUS OF CURVATURE CALCUI~TION MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** TIE-IN 2670.00 1.2 200.0 S 20 00 W 2669.70 -28.00 33.00S 0.00E 33.00 S 0.000E 0.000 TELECO MWD 3422.00 15.4 29.7 N 29 42 E 3414.81 38.74 18.79N 41.82E 45.84 N 65.801E 2,690 3591.00 20.6 29.0 N 29 00 E 3575.48 90.81 64.29N 67.40E 93.15 N 46.353E 3.080 3232.00 10.3 31.2 N 31 12 E 3229.63 -3.43 17.62S 20.41E 26.96 S 49.198E 2.995 2800.00 1.2 186.9 S 06 54 W 2799.67 -30.11 35.68S 0.64W 35.69 S 1.032W 0.219 3045.00 4.7 30.4 N 30 24 E 3044.30 -27.80 38.57S 7.92E 39.38 S ll.601E 2.376 TELECO Job # 684 TAK 02/20/89 Page 2 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 3790,00 24,2 21,5 N 21 30 E 3759.44 165.80 132,82N 99,72E 166,09 N 36,900E 2.307 3976,00 29,8 20,6 N 20 36 E 3925,10 248,22 211.60N 130,04E 248,36 N 31,574E 3,019 4160,00 35,5 22,4 N 22 24 E 4079,96 345,28 303,91N 166.41E 346.49 N 28,703E 3,142 4349,00 42,4 23.4 N 23 24 E 4226.86 462.00 413.30N 212.61E 464.78 N 27,223E 3,666 4536,00 46,2 23,8 N 23 48 E 4360,67 590.64 532,96N 264,89E 595,15 N 26,428E 2,038 5005,00 48,5 23,4 N 23 24 E 4678.40 930,44 849,04N 402,98E 939,82 N 25,391E 0,494 5288,00 49,7 23,8 N 23 48 E 4863,69 1141.17 1045.05N 488.62E 1153.64 N 25,059E 0,437 5576,00 49,7 22,0 N 22 00 E 5049.92 1357,18 1247.48N 574.13E 1.373.26 N 24,713E 0,477 5857,~00 49,1 22,7 N 22 42 E 5232,77 1566,53 1444.82N 655,26E 1586,47 N 24,396E 0,288 6141,00 48,2 22,0 N 22 00 E 5420,39 1775,70 1642,00N 736,33E 1799,54 N 24,153E 0,367 6420,00 48,1 21,7 N 21 42 E 5606,54 1979,23 1834,88N 813,67E 2007.20 N 23,915E 0,089 6794,00 47,4 23,1 N 23 06 E 5858,00 2250.90 2090.82N 919.17E 2283.95 N 23,731E 0,334 7075.00 46,7 26,2 N 26 12 E 6049,46 2454.11 2277.73N 1004,94E 2489.57 N 23.807E 0,845 7342.00 46.1 31,9 N 31 54 E 6233,59 2646.80 2446.69N 1098.79E 2682.10 N 24,184E 1,562 7726,00 47,9 33,6 N 33 36 E 6495,47 2927.60 2682.87N 1250,70E 2960.08 N 24,994E 0.570 8103,00 50,6 32,9 N 32 54 E 6741.54 3213.17 2921.70N 1407.28E 3242.96 N 25.719E 0.730 8292,00 51.2 35.0 N 35 00 E 6860.73 3359.83 3043.36N 1489.19E 3388.17 N 26.074E 0.919 TELECO Job # 684 TAK 4 02/20/89 Page 3 MEAS DIRECTION TRUE VERTICAL COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100' **************************************************************************************************** 8575,00 50.7 36.1 N 36 06 E 7039.02 3579,46 3222,17N 1616.97E 3605,13 N 26,649E 0.350. 9046.00 51.9 41.0 N 41 00 E 7333,51 3945.50 3509,55N 1845.98E 3965.42 N 27.744E 0.851 9402.00 51.1 42,4 N 42 24 E 7555.12 4221.25 3717.57N 2031.31E 4236.33 N 28.653E 0.381 9796.00 51.5 44.5 N 44 30 E 7801.47 4524,08 3940.78N 2242.77E 4534.29 N 29.645E 0,428 10072.00 52.0 46.6 N 46 36 E 7972.34 4736.03 4092.56N 2397.48E 4743.10 N 30.362E 0.624 10261.00 49,0 48.4 N 48 24 E 8092.54 4877,51 4191.07N 10437,00 47.8 48,4 N 48 24 E 8209.39 5004.66 4278.43N 2504.99E 4882.63 2603,37E 5008,25 N 30.867E 1.749 N 31.320E 0.682 10636.00 45.1 49.1 N 49 06 E 8346,49 5143,78 4373.51N 2711,81E 5146,02 N 31.801E 1.380 10730,00 43.2 48.7 N 48 42 E 8413.93 5206.90 4416.55N 2761.14E 5208.63 N 32.013E 2,043 10831.00 42.5 50.5 N 50 30 E 8487.98 5272.89 4461.07N 2813.45E 5274.15 N 32.238E 1.396 10934.00 43.0 53.3 N 53 18 E 8563.61 5339.22 4504.20N 2868.46E 5340.03 N 32,491E 1.908 Services 6400 5600 4800 ¢000 3200 2400 EAST ~ ....; .... F"T"-T--F'"T--;-'* ...... %77 ........ · ~ _..z__...~ !_ L. ~ ..... i_...;~..t._.., ........... ! .... i ..... i ......... .._--'.. ...... : ...... ( .... ; ..... l .i._.; ..... [ .... ;. ..... t.--J ..... ; .... z...4....i ~; .... ;--,;---i ...... i ..... :.- .... i ..... ; .......... ! .... ; .... i--~i'~- ~ .... i-~-i .... i---~.-- F-5--¢----i.---i--I--.~--~ .... i .... i--?'. ~..~-..-: ..... ¢ ..... ; .... l ...... :---'--4 .... -~ ............ 4 .... ~ ...... ;---i~--i ...... '~ .... !--=-l--~, .... ~ ..... ! ~-'-t ..... i---, ........ ~--.:. ~-,.,,4.--.-4,-, -.-,'. ..... ~-~- '"~-~ -." .......... ;- - '~'- i- '-, ...... ' ........ ¢'--l'----'"~ ..... -'~ } '._ .i_!_..; t_ i L i. _;-r :---! -: IZ_--25_"_ _'-._1 Li:.._.: .... i .... iT;i._ .... :. .... .... i .... ,"----' .... ; ........ -r ............ : .... ~' "I -'; ..... '; ........................... ' . r'~':- '~T~ '~ .... ? ..... : ...... : .... . ~ - ' ' " t , i ~. i .~ .. · ~ j _.~ ! : " - ,, . .... :..._... _- ........ i ..... :-~: ;- i ..... ; .... '- --'---! ....... ! ...... I ";~ ................. i : . - i ........... i .......... ............... ,t .... - .... - ..... .................... i- -,- !.~-~?e~ '-- ~ ...... ~ ............... ~ ............... i ............. ~ ...... ? .............. . ' ' ' ~ ' .i .-. :- ........... --' ...... '--. :'"---------~-' ........ P:~-"~-% ' -i .] ; - -.'.__- ........ ,' . . ~ : : ; . - ._.,. .... ;. _ · 1 ~ : ;. ' : ' ': ' I ' ' i . , " ; :. i - ~ - ; ' . I : / I--.4 .... -- ......... ; .................. ~. ........ I ..... :-";'---~ .......... ~ , ' BOO 0 800 18013 2400 9200 4000 BO0 0 8OO 2000 ~000 ~ 8000 1 nuOO · 8000 20000 - 1000 1000 3060 5000 7000 9000 i 1 - ~ I - - ', .- OGO BP' EXPLORATION HOUSTON ARCO CHEVRON EXXON TEXAuO TO: MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE: ARCHIVES ~ BP'CASED HOLE FINAL LOGS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DaTe: T~f: 04-27-89 80013 The following material is being submll~ed herewith. Please acknowledge receipt by slgnlng a copy of this le~er and returning it to this office: A- 111 CCL/GR C-35 TEMP H-22 FM/TEMP S-18 CCL W-34 PITS X-05 TEMP/GLS Z-25 CCL 04-15-89 04-12-89 04-22-89 04--16L89 04--11--89 04--15--89 04--16--89 #1 8850'--10604 Camco 5" #1 2950-9638 Camco 5" #1 SURF---.9600 Camco 5" #1 11100-11990 Camco 5" #1 10350-10786 Camco . 5" #1 55-9500 Camco 2"/5" #1 10500-11600 Camco 5" Rece i ved DaTe ~mh0rage Shirley R. McCurry INFORIVu~TION CONTROL Well Records LR2-1 BP EXPLORATION EOUSTON ARCO CHEVRON EXXON TEY~CO MOBIL PHILLIPS ~TATE OF ALASKA ARCStIVES I NDE]XED BP Exploration (Alaska) Inc. 900 East Sanson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 Date: 04-26-89 80011 REFERE~NCE: BP F~AL DATA - PRESSURE SURVEY DATA The following material Is being submli-i'ed herewith. Please acknowledge receipt by signing a copy of t'his .let-['er and ret'urnlng If to this office: B-23 S~atic Gradient '04-20-89 Camco D-17 Static Gradient 04-18-89 Camco D-26 Static Gradient 04-22--89 Camco E-03 Static Gradient 04-16-89 Camco F-11 Static Gradient 04-20-89 Camco H-24 Flowing Gradient 04-19-89 Camco K-05 Static Gradient 04-18-89 Camco M-17 Static. Gradient 04-20-89 Camco S-18 : Static Gradient 04-16-89 Camco X-19 Static Gradient 04-20-89 Camco Z-25 Static Gradient 04-16-89 Camco Z-31 Static Gradient 04-21-89 Camco Received Shirley R. McCurry ~ NFORMAT ~ ON CONTROL Wel~ Records LR2-~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorag~ Alaska 99519-6612 (907) 561-5111 To HOUSTON ARCO CHEVRON EXXON TEXACO MOBLE PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHVIES Date:03/14/89 T#: 79885 BP CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: E-21 Perf-R 03/06/89 #1 10400-10595 Sch 5" H-04 Prod 03/04/89 #1 11300-11838 Sch 5" H-Il Prod 03/03/89 #1 9100-9695 Sch 5" J-08 Prod 03/06/89 #1 11940-12410 Sch 5" Z-25 Perf-R 03/03/89 #1 11478-11700 Sch 5" X-19 Pord 03/05/89 #1 9600-9963 Sch 5" Z-25 'CET 03/02/89 #1 10735-11748 Sch 5" Z-25 CBT 03/02/89 #1 10735-11727 Sch 5" Received: Date: Anchorage Information Control Well RecordsLr2-1 J. Dietz/S. McCurry BP EXPLORATION ARCO F~v~XON BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-511~ Date: 03/03/89 PHILLIPS ~: 79867 STATE OF AK SYSTEMS (Transmittal & Taoe) At{CHIVES REFMRF~CE: BP MAGNETIC LIS TAPES & LISTLNGS The following material is being su~nitted herewith. Please acknowl~e receipt by signing a copy of this letter and returning it to this office: Z-25 OH/DIL/BHC/LDT/CNL/MSFL 02/24/89 Tape Pos. #06346 Sch#73156 1600bpi #I 7749-11837.5 API#50-029-21902 ARCHVIES ONLY: Z-25 OH field tape 02/24/89 #I Tape Pos. #06347 Sch#73156 1600bpi API#50-029-21902 Z-25 OH field tape 02/24/89 #I Tape Pos. #06348 Sch#73156 1600bpi API#50-029-21902 * E~L~ON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and Listing(s) directly from th~espective service company. Please confirm this. January 4, 1989 Telecopy: (907)276-7542 Ted Stagg Prudhoe Bay Unit Drilling ~gineering Supervisor Standard Alaska Production Company P.O. Box 196612 ~nchorage, Alaska 99519-6612 Prudhoe Bay Unit Z-25 Standard Alaska Production Company Permit No. 88-159 Sur. Loc. 72I'SNL, 3143'WEL, Sec. 19, TllN, R12E, UM. Btn~hole Loc. 913'SNL, 5039'WEL, Sec. 17, TllN, R12E, Dear Mr. Stagg: Enclosed is the aPproved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probabla need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to co~nctng installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Ve~ truly~ y~3ar-s, .... ~ ~ C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~E CO~ISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,~-~ Revised Permit to .Drill ~"~'~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION December 29, 1988 PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] RedrillDIlb. Type of well. ExploratoryD Stratigraphic TestF'l Development Oil[] Re-Entry [] DeepenF-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Comoanv BKB = 92 feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28262 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 2s.o2s) 721' SNL, 3143' WEL, SEC. 19, T11N, R12E Prudhoe Bay Unit At top of productive interval 8. Well number Number 1095' SNL, 5160' WEL, SEC. 17, T11N, R12E Z-25 (11-17-11-12) KOO683449-G-14 At total depth 9. Approximate spud date Amount 913'SNL, 5039' WEL, SEC. 17, T11N, R12E January5, 1989 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(UDandTVD) property line ADL 47450 1000 feet Z-15 257 feet 2560 11,806'MD 9157'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 ^^c 25.035 (e)(2)) Kickoff depth 2800 feet Maximum hole angle 90 Maximum surface 3330 psig At total depth (TVD) ~00'/4390 pslg i18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD M D TVD (include stage data) 20" Cond. Surface 110' 110' 8 cu. yds. Concrete 17-1/2" 13-3/8" 68# L-80 Butt 2632' Surface 2652' 2652' 3684 cu. ft. Permafrost 12-1/4" 9-5/8" 47# NT80S NSCC 11043' Surface 11073' 8695' 2424 cu. ft. Class G 8-1/2" 7" 26# L-80 IJ4S 983' 10823' 8530' 11806' 9157' 289 cu. ft. Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate D~.~, ~ ¢,) Production Liner A_iask~ Oil & Gas C0ns~ Perforation depth: measured ~ ,...!. ~/talchpmge ~ true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certify_that xt~/~egoingJ/ /_/~ is true and correct to the best of my knowledge Si~lned ~:~,,~___.,,~'_~~ Title PBU Drilling Engineerin.q Supervisor Date / Commission Use Only / / Permit Number IAPI number IApproval date ISee cover letter ~¢-/,.5'~' 150-o~..- 5~..[?o,~... I 01/04/89 Ifor other requirements Conditions of approval Samples required [] Yes ,]~rNo Mud Icg required []Yes ~J'No Hydrogen sulfide mej_a~.ures [] Yes ~LNO Directiona~,l survey requ~rea ~ Yes [] No Required wor~~~,~,~~~/~5M; I-il0M; 1-115M;by order of Other: Commissioner commission Date Approved by , tne Form 10-401 Submit in' ate Revised-December 29~ 1988 AFE No. 120626 PROPOSED DRILLING AND COMPLETION PROGRAM W]gLL Z-25 [11-17-11-121 PBU Install and cement 80' of 20" conductor to surface. Install 20" diverter. The Drilling fluid program will consist of an 9.5 - 10.0 ppg spud mud in the 17- 1/2" hole, a 9.5 - 10.4 ppg water base mud in the 12-1/4" hole and a 9.5 ppg water base mud in the 8-1/2" hole. Drill 17-1/2" hole to 2672' and cement 13-3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12-1/4" hole to the 9-5/8" casing point at the Sag River Sandstone. Run 9-5/8" 47# NT80-S NSCC casing to within 5' of 12-1/4" TD and cement using Class G cement around the 9-5/8" shoe. The 13-3/8" x 9-5/8" annulus will be freeze protected with dry crude. Directionally drill 8-1/2" hole to TD. Run 7" liner from TD to 250' inside 9-5/8" casing shoe and cement using Class G cement. Clean out to 7" float equipment. Change over to 9.5 ppg. filtered NaCL completion fluid. Test casing and lap to 3000 psi. Perforate well with wireline conveyed guns. Run 9-5/8" production packer on 3.5" tubing with a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Tubing Size: 3-1/2", 9.3# L-80 EUE 8 Round A/B Mod IPC TBG with 8 GLM's. Tailpipe Size: 3-1/2" Tailpipe RIS' 29-Dec-88 Revi~d December 29, 1988 PROPOSED DOWNHOLE DIAGRAM WELL Z-25 [11-17-11-12] PBU/EWE PROPOSED DEPTH BKB 20" Conductor 110 Ball Valve 1992 13-3/8" Casing Shoe 17-1/2" Open Hole 2652 2672 3-1/2" 9.3# L-80 EUE 8 Rd A/B MOD. Butt IPC Tubing with 8 GLM's 9-5/8" Packer 10773 7" Tieback Assembly 10823 9-5/8" Shoe 12-1/4" Open Hole 7" 26# L-80 IJ4S Liner 11073 11078 7" PBTD 7" Liner Shoe 8-1/2" Open Hole 11766 11806 11806 RIS 29th Dec 1988 B.O.P. STACK CONFIGURATION 13-5/8 IN. TRIPLE RAM STACK 5'000 PSI W'P DRILLING ANNULAR PREVENTER I- I I I PIPE RAMS I ! I i' 2 IN. KILL LINE GATE GATE I I BL I ND RAHS I ! DRILLING SPOOL I PIPE RAHS ! 4 IN. CHOKE LINE GATE GATE GROUND LEVEL FLOWLINE DRILL ING RISER DIVERTER SYSTEM DETAIL DRILL. DEPT. April 1982 i/ 20" 2000 PSI WP ANNULAR PREVENTOR Butterfly-valve a~tically% opens when ann~ Prev~ter 12" DRILLING SPOOL 20" CONDUCTOR PIPE NOTE: DIVERTER ~INE HAS T~O DIRECTION DISCHARGE CAPABILITY AFTER LEAVING RIG SUB-BASES. SURFACE HOLE DIVERTER SYSTEM Two lines venting 90° apart in directions that insure safe down wind venting, and extending to a point at least 100' (feet) from any potential source of ignition. 10 3/4" manual t~Jtterfly valves 10 3/4" 55~ Buttress 10-3/4" Hydraulic operated ~ Butterfly valve 20" D~verter S._~-~D] w/10 3/4'" SJc:.o O.:t]et. NOTES 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movement. 2. Manual 10-3/4" butterfly valves, mechanically connected to insure that one valve is fail- safe open at all times. 3. All turns are 90° (degrees) and targeted. #ORTH ~ ' - I , 1 , ! /~ ~ I ~ ~ I~,~1 ~ ~ 3~ .-;~3-,-~z ~ ~4 ;,,o~-~ , ~ ~ , . .,. , --~ oF ~ _il~ '~ WELL PAD 'Z' CERTIFICATE OF S~VEYOR' .~..- ~--.<,~,, ,~ ,o z-~ REGISTERED AND UCENSED TO 'R*CTICE ~,',~-- ' ---~ --~ ..... ~--~' ~ PROTRACTED ~CT. 19 , T. II N., R. I2E., ~M. AND THAT THIS PL&T REPRESENTS A ~a ~-· ~.n, ,~ ~ L~AT~N S~R~ MA~ BY MI OR UN~R qA ~ · .'' ~ ' MY 8~l~ON, ~D ~&T ALL ~ENSIONS ~k ~P~ ''~ ~ ~ - ~0FESSiONAL~. P~EPARED ~Y : D~TE : NOV. 2o,e6 AND OTHER D~LS F CORRECT' -- ''' '''''' KUUKPIK - ~~~/ ~ov zo, e~ TECHNICAL ~RY. INC. oe~wa e~: ~T. ~ , SURVEYOR DATE: SHEET I 'OF 2 PRUDHOE BAY OFFICE CHKD. BY . R,H. I I II I I I I II I NORTH LINE ~ SECTION 19 NW CORN. OF SECT. J'L · · · · · · SUMP 1809' SUMP 1 SHEET 2 OF 2 WELL PAD 'Z* · W£LL N° Z-2§ AS-II, JILT LOC&TED IIII KC'T. II, ~r. I i., I. Is'Ir,U,M. I U RYE:YE D POR : Sl'A.NDA~D ALA.Sx.~ P~T~q CO. OATE; IIOV. ~'O, IG DNAW# IY: ~ _$~$DUA94: [DRANO25]Z25_CLOSAP_SHORT. LIS; 1 ' Search Radius= ~00 COURSE LINE For proposed well: Z-25 [41-18-11-12] Location = W-E S-N TVD¢SBS> Top 599529.00 5959360.00 -92.00 Bottom 60~538.61 5~644~0.38 8~67.00 Note: All depths in Peet Below Kellg Bushing 19-DEC-1~88 10:13 --- Closest Approach Analysis --- Date' I~-DEC-88 Time' 10:13:13 Page I Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART CLOSEST DISTANCE A029-2051100 CHEVTR 7012.7 3616.~ 7428.2 3053.6 2137. 5 A02~-2184400 Z-14 100.0 0.0 100.0 0.4 ~5.3 AOa?-a184700 Z-lO 184~.6 0.0 1842.4 111.~ 25&~7 A02~-2185900 Z-20 700.6 '0.0 700.0 1. 7 367.6 Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART VERTICAL DISTANCE SUMMARY The well which comes closest to the p~oposed well is~ A0~-~184900 Z-15 Closest approach distance KICK OFF ~or this run ~56.7 Feet 2800.0 Feet _$2$DUA94: [DRANO25]Z25_CLOSAP_SHORT7, LI8~ Search Radius= 200 7 DEQREE LEAD LINE For proposed well: Z-25 [41-18-11-12] Location = W-E. S-N TVD(SBS) Top 5~95~.00 595~350.00 -92.00 Bottom 6018~0. ~4 5~5481B. ~2 8~67.00 Note: All depths In Feet Below Kellg Bushing 19-DEC-1988 I0:13 --- Closest Approach Analgsis --- Date: I~-DEC-88 Time: 10:13:45 Page 1 Closest Approach WELL IDENT /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART A029-2051100 CHEVTR 7124.8 3744.5 7352.2 2997.2 A02~-2184400 Z-14 100.0 0.0 100.0 0.4 A02~-2184900 Z-15 1842.6 0.0 1842.4 111.2 A029,2185900 Z-20 700.6 0.0 700.0 1.7 CLOSEST' DISTANCE 1700.3 265.3 256.7 367.6 Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART VERTICAL DISTANCE SUMMARY The well which comes closest to the proposed well is: A0~-2184900 Z-15 Closest approach distance KICK OFF for this run 256.7 feet 2800.0 feet ! I&d 66~. 18¥ ~6L ~Ur~T IO~J , , I ~4, . L~..J ~0 P~I~P$ I'o 1 - Brandt Dual Tandem Shale Shaker 1 - Eem~o 6-12" Cone Shale Desander 1 - Demco 416H w/16 cones & (1) Demo 48H w/16 cones (Desilter) 1 - Drilco Atmospheric Mud Degasser 0£~co 12.1 5'0 ~ 1- 200 gpm Operating Capacity. Centrifuge 15 - Brandt MA5 Mud Mix Agitators 1 - 150 bbl. Trip. Tank 1 - Recording drilling fluid pit level indicator with both visual and audio warning devices at driller' s console I:~JA L 70 T'~I O £ ~ 1- Drilling fluid flow with readout at drill%~.',s console IT~ ~P~O~ DA~ ~ ~S NO Fee i. Is ~he pe~ fee a~:ached ..................................... ,., ,, , e e ~ ~ e ,, Cz thru 8) (i4 thru 2.2) ,. (23 uhr',z 28) . . , F?c /t?ze/¢r (29 =btu 31)' ,vt 08/II/88 011 2. Is well to be locaued in a daf/ned pool ............................. ~ 3. Is well ioca=ed proper dls=ance from properr7 1/ne ................. ~ ~. ~. Is well loca=ad proper dis=anco from ocher wells .................... ~ 5. Is sufflc*-'en= untied±cared acreage available in :his pool ............ ~ 6. Is well to be deviated and is ~el!bore pla= included .; .............. ~ ?. Is opera=or =he oui¥ elf ac=ad parr7 .................... 2 ............ ,, ~ 8. Can perm.%= 5e approved 5efore f±f=ae:-da~.wai= ...................... ~>4 9 Does operaUor have a bond in force , 1i. Is aJm~nis~ra~iva approv~ ~aa~a~ ................................... 1Z. Is ~ha laasa m~har appropria~a ..................................... I3. Does =he well have a u~qua ~e ~d n~ber ........................ 14 Is conduc=or suring provided ' I~. ~i~ sur~aca casin~ pro~ac~ ~ zonas ~aasonahl7 ~ac~a~ 17. ~1 c~en~ =la ~ surface ~d ~e~edia~e or produculon su~s ... 18. Wi~ careen= cover all ~o~ produc=ive hot, ohS ..................... 19. Wi~ ~1 cas~g Eive adequate s~e~ ~ collapse, tension 20. Is =~s we~ =o be ~c~d off from ~ ~s=~g wellhora ............. 2I. Is old we~bore ab~do~en=.procadura ~cludad on i~403 ............ . 22 Is adeq !ibora separa=io~ pro~os d ' ' =~=~ ~e e ............... . ............ 23. Is a diver=ar sys=~ required ....................................... 24. 'Is =he dr~E fluid progr~ sche~=ic ~d lis= of eq~pmen= adequa=a 25. ~e necessa~ dtagrnms ~d descrip=ions of diver=mr ~d BOPE a:=ached. 26. Does BOPE have sufflcian= pressure ra=~ - Tes= =o ~ooo 27. Does =he choke ~old co w ~-53 .................. 28. ~ ~a presence of H2S Ecs probable ................................. For ~Iora=o~' ~d S=ra=iErap~c we~s: 29. ~e dana pres~Ead on po=an=i~ ove~rassure zonas~. ................. 30. ~e sei~c ~/sfs dana presen=ad on shadow gas zones ............ 31. ~ ~ offshore loc., are su~ey rasui=s of seabed condi=ions 32 Additional requ/r~menus ' SHORE i '"X Addi=Ionai ~.~rks: _ . .o Well History File APPENDIX Information of detailed nature that is not particularly germane 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. * ALASKA COMPUTING CENTER * * ............................ * ....... SCHLUFIBERGER ....... * ............................ * RECEIVED JUL 0 2 1998 Alaska Oil & Gas ~ns, Commission An~orage COMPANY NAME : BP EXPLORATION (ALASKA), INC. WELL NAME : Z-25 FIELD NAFiE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292190200 REFERENCE NO : 98270 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/29 ORIGIN : FLIC REEL NAFiE : 98270 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, Z-25, PRUDHOE BAY, 50-029-21902-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/06/29 ORIGIN : FLIC TAPE NA~E : 98270 CONTINUATION # : 1 PREVIOUS TAPE : COf4~M~T : BP EXPLORATION, Z-25, PRUDHOE BAY, 50-029-21902-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: Z-25 API~ER: 500292190200 OPERATOR: BP EXPLORATION (ALASKA), INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 4-JUN-98 JOB NUFIBER: 98270 LOGGING ENGINEER: VETROMILE/PA OPERATOR WITNESS: L PHONG SURFACE LOCATION SECTION: 19 TOWNSHIP: lin RANGE: 12E FNL: 721 FSL: FEL: FWL: 3143 ELEVATION(FTFROM MSL O) KELLY BUSHING: 91.50 DERRICK FLOOR: 91.50 GROUND LEVEL: 54.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 11800.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(F~ASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUAiBER : PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 11617.0 11614.0 11608.0 11605.5 11602.5 11602.0 11597.5 11596.0 11595.0 11587.0 11578 0 11577 0 11568 5 11563 5 11554 5 11554 0 11545.0 11541.5 11538.5 11536.0 11535.5 11532.0 11527.0 11525.5 11523.0 11522.0 11519.0 11514.5 11513.5 11512.0 11511.5 11509.0 11506.5 11503.5 11500.0 11491.0 11486.5 11486.0 11483.0 11482.5 11476.5 11476.0 11473.0 11472.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH TDTP 88886.5 88888.0 11606.5 11601.0 11595.0 11586.0 11577.0 11555.5 11549.0 11541.0 11536.0 11532.5 11528.0 11525.5 11521.5 11514.0 11511.5 11508.5 11505.0 11492.5 11486.0 11482.0 11475.0 11472.5 11617.0 11614.0 11603.5 11601.0 11597.5 11595.0 11577.0 11567.5 11563.5 11555.5 11541.0 11536.0 11525.5 11523.0 11518.5 11513.5 11511.5 11509.0 11503.0 11500.5 11486.0 11483.0 11475.0 11472.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11469.5 11470.5 11467.5 11467.0 11467.0 11467.5 11464.5 11464.0 11464.0 11464.0 11461.5 11461.5 11461.0 11459.5 11460.0 11459.5 11459.0 11456.5 11453.5 11453.0 11449.5 11449.0 11449.0 11448.5 11446.5 11443.0 11442.0 11442.5 11441.0 11439.5 11438.5 11437.0 11435.5 11436.5 11435.5 11414.5 11413.5 11412.5 11411.5 11412.0 11411.0 11409.5 11408.5 11404.5 11405.5 11401.0 11401.5 11397.5 11396.5 11397.0 11394.5 11394.5 11391.5 11393.0 11389.5 11390.0 11388.0 11388.0 11386.0 11385.5 11385.5 11383.0 11382.0 11382.5 11382.0 11380.0 11379.0 11377.0 11376.5 11368.0 11367.0 11367.5 11367.0 11356.0 11355.5 11355.5 11352.5 11351.0 11351.0 11351.5 11349.5 11348.0 11347.0 11345.0 11346.0 11345.5 11344.0 11343.0 11340.5 11340.5 11338.5 11338.0 11337.0 11335.5 11332.5 11332.5 11332.5 11330.5 11330.0 11329.5 11329.5 11322.5 11321.5 11318.5 11319.0 11318.0 11319.0 11315.5 11314.5 11315.0 11315.0 11312.0 11311.0 11311.5 11311.0 11308.5 11309.0 29-JUN-1998 15:09 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11305.5 11305.5 11303.5 11303.0 11292.5 11293.5 11290.0 11290.0 11287.5 11287.0 11287.0 11287.5 11283.5 11283.0 11283.0 11280.5 11280.0 11279.0 11280.0 11276.5 11277.0 11275.5 11276.5 11272.5 11273.0 11269.0 11269.0 11269.0 11265.0 11264.5 11264.5 11257.5 11257.5 11257.0 11257.0 11255.0 11254.0 11252.5 11253.0 11252.0 11253.0 11250.5 11250.5 11250.0 11250.5 11247.5 11248.0 11245.0 11244.5 11243.5 11244.5 11240.5 11241.0 11238.5 11237.0 11237.0 11237.0 11234.0 11234.5 11234.5 11226.0 11226.0 11225.5 11226.0 11223.0 11222.5 11222.0 11222.5 11217.5 11216.0 11214.5 11214.0 11213.5 11212.5 11211.5 11210.5 11211.0 11210.0 11208.0 11207.0 11207.5 11206.5 11199.0 11198.5 11198.5 11194.5 11194.0 11194.0 11194.0 11191.0 11189.5 11189.0 11187.5 11187.0 11186.5 11184.5 11183.0 11184.0 11183.0 11181.0 11179.0 11179.5 11178.0 11176.5 11176.0 11175.5 11173.5 11173.0 11171.5 11171.0 11169.0 11166.5 11165.5 11163.5 11164.0 11162.0 11163.5 11162.5 11160.5 29-JUN-1998 15:09 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 11158.5 11157.5 11153.5 11149.5 11148.5 11145.5 11143.0 11140.5 11139.5 11136.5 11135.0 11129.0 11125.0 11122 5 11120 0 11117 0 11114 5 11112 5 11109 0 11108 5 11105 0 11102 5 11097.0 11092.5 11091.5 11090.0 11087.0 11083.5 11081.5 11080.0 11077.5 11075.0 11073.5 11072.5 11071.5 11067.5 11064.5 11063.0 11060.0 11058.5 11055.5 11050.5 11047.5 11046.0 11045.5 11041.5 11040.0 11036.0 11034.0 11029.5 11016.0 11015.0 11012.0 11010.0 11009.0 11007.5 11157.0 11154.5 11150.0 11146.5 11143.0 11140.5 11138.5 11134.0 11132.0 11126.0 11120.5 11117.0 11114.0 11112.0 11111.0 11106.5 11102.0 11099.5 11091.5 11088.5 11087.5 11085.0 11080.5 11078.0 11073.0 11071.0 11066.0 11059.5 11058.0 11056.0 11053.5 11048.5 11045.5 11043.5 11039.5 11036.0 11026.5 11013.0 11010.5 11009.0 11006.0 11146.5 11138.5 11126.0 11111.0 11092.0 11083.0 11078.0 11073.0 11070.5 11066.0 11048.0 11040.0 11035.5 11018.0 11009.0 29-JUN-1998 15:09 PAGE: ! LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 11005.0 11004.0 11003.0 11006.0 11000.5 11000.0 10999.5 11000.0 10997.5 10996.5 10995.0 10996.5 10991.5 10990.5 10990.0 10988.5 10985.0 10986.5 100.0 99.5 99.0 $ THIS FILE CONTAINS THE LDWG FORMATTED CASED HOLE TDTP EDIT OF BP EXPLORATION'S Z-25 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATION BETWEEN GRCH BASE PASS #1 AND THE BCS GAlV~4A RAY, ALSO BASE PASS #1 SIGMA AND THE BCS GAMFiA RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREF~: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11608.5 10986.5 TDTP 11609.0 10985.0 $ CURVE SHIFT DATA - PASS TO PASS (f4EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: RE~ARJ~S: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1185972 00 000 O0 0 1 1 1 4 68 0000000000 SIGMTDTP CU 1185972 00 000 00 0 1 1 1 4 68 0000000000 TPHI TDTP PU-S 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 SBHF TDTP CU 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 SBHNTDTP CU 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 SIGC TDTP CU 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 SIBHTDTP CU 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 TRATTDTP 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 SDSI TDTP CU 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 BACK TDTP CPS 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC TDTP CPS 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 TCAIVTDTP CPS 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 TCAF TDTP CPS 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 TCND TDTP CPS 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 TCFD TDTP CPS 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 TSCN TDTP CPS 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: NAME SERVUNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD AU]M~ SAMP ELEM CODE (HEX) TSCF TDTP CPS 1185972 INND TDTP CPS 1185972 INFD TDTP CPS 1185972 GRCH TDTP GAPI 1185972 TENS TDTP LB 1185972 CCL TDTP V 1185972 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 00 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 11622.000 SIGM. TDTP 13.884 TPHI.TDTP 15.603 SBHF. TDTP SBHN. TDTP 50.464 SIGC. TDTP 0.651 SIBH. TDTP 56.631 TRAT. TDTP SDSI. TDTP 0.237 BACK. TDTP 40.455 FBAC. TDTP 13.421 TCAN. TDTP TCAF. TDTP 19642.969 TCND.TDTP 28094.898 TCFD. TDTP 10148.117 TSCN. TDTP TSCF. TDTP 3998.643 INND. TDTP 2306.404 INFD. TDTP 448.971 GRCH. TDTP TENS. TDTP 1585.000 CCL.TDTP 0.000 DEPT. 10976.500 SIGM. TDTP 45.008 TPHI.TDTP 74.011 SBHF. TDTP SBPiN. TDTP 57.939 SIGC. TDTP 0.000 SIBH. TDTP 77.627 TRAT. TDTP SDSI.TDTP 1.195 BACK. TDTP 129.719 FBAC. TDTP 26.789 TCAN. TDTP TCAF. TDTP 5643.250 TCND. TDTP 15625.750 TCFD. TDTP 3639.688 TSCN. TDTP TSCF. TDTP 354.063 INND. TDTP 2015.188 INFD. TDTP 352.359 GRCH. TDTP TENS. TDTP 1373.047 CCL.TDTP 0.000 ** END OF DATA ** 37.826 1.639 42141.445 8578.570 -999.250 51. 625 1. 864 23019. 000 1394. 844 47. 672 **** FILE TRAILER **** FILE NA24~ : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE ' FLIC VERSION : O01CO1 DATE · 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: FILE HEADER FILE ~ER : 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUFIBER : 2 DEPTH INCREF~_Jfr: 0.5000 FILE SUF~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11610.0 10986.0 TDTP 11608.0 10984 . 5 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS ~ER : 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88888.0 88886.0 11605.5 11603.5 11603.5 11601.0 11600.5 11599.5 11598.0 11597.5 11595.5 11595.0 11586.0 11586.0 11583.5 11583.0 11582.0 11581.5 11573.5 11572.0 11573.0 11572.0 11564.5 11564.0 11557.0 11557.0 11558.0 11551.0 11552.0 11542.5 11543.0 11540.5 11541.5 11535.5 11536.0 11528.5 11528.5 11524.0 11523.5 11523.0 11523.0 11522.0 11521.0 11519.0 11519.0 11516.0 11516.0 11514.0 11513.5 11512.0 11511.5 11511.5 11509.5 11509.0 11507.0 11505.5 11503.5 11502.5 11501.0 11500.0 11500.0 11500.0 11495.5 11495.5 11492.0 11492.0 11491.5 11492.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 10 11490.5 11487.5 11481.0 11476.5 11474.5 11472.5 11469.5 11467.5 11464.5 11462.5 11459.5 11458.5 11453.0 11450.0 11449.5 11448.0 11439.5 11436.5 11434.0 11432.5 11431.0 11429.0 11424.5 11415.0 11412.0 11407.0 11401.0 11400.5 11397.5 11395.0 11393.5 11391.5 11389.0 11386.5 11385 5 11383 0 11382 5 11380 0 11379 0 11377 0 11374 0 11373 5 11369.0 11368.0 11362.0 11359.5 11359.0 11356.0 11353.5 11352.0 11349.0 11348.5 11343.5 11341.0 11340.5 11486.0 11475.5 11472.5 11467.5 11464.0 11461.5 11457.0 11449.0 11446.0 11438.5 11432.5 11432.0 11430.0 11422.5 11411.5 11404.5 11401.0 11396.5 11394.5 11390.0 11385.5 11383.0 11379.0 11376.5 11374.0 11369.0 11367.0 11361.5 11359.0 11355.5 11352.5 11348.0 11343.0 11341.0 11490.0 11480.5 11475.5 11473.0 11470.5 11467.5 11464.0 11457.0 11451.5 11449.0 11438.5 11435.5 11426.5 11415.0 11411.0 11400.0 11397.0 11394.5 11391.5 11385.5 11381.5 11378.0 11372.5 11367.0 11358.0 11355.5 11352.0 11347.5 11343.0 11340.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 11 11339.0 11335.0 11334.5 11333.0 11332.5 11331.0 11326.0 11321.0 11318.5 11318.0 11316.0 11315.5 11312.0 11311.0 11309.0 11308.0 11302.0 11298.0 11297.5 11295.5 11291.5 11289.5 11287.0 11286.5 11283.5 11281.5 11280.0 11275.5 11273.5 11272.5 11270.5 11269 5 11267 5 11265 5 11264 0 11262 5 11258 5 11258 0 11252 0 11250 5 11249 5 11248 0 11247 0 11243.0 11241.5 11238.0 11237.0 11233.5 11226.5 11223.0 11221.5 11219.0 11215.0 11213.5 11211.0 11338.5 11334.5 11332.5 11330.5 11326.0 11318.0 11315.5 11311.0 11309.0 11297.5 11293.5 11289.5 11286.5 11283.0 11280.5 11277.0 11273.5 11270.5 11267.5 11265.0 11261.5 11257.0 11253.0 11250.5 11248.5 11241.5 11237.0 11223.0 11218.5 11215.5 11212.5 11210.0 11334.5 11332.5 11321.5 11318.5 11315.5 11311.0 11307.5 11302.0 11297.5 11292.0 11287.0 11283.0 11280.5 11276.5 11273.0 11269.5 11264.0 11258.0 11253.0 11250.5 11247.5 11242.0 11237.0 11234.0 11227.0 11222.0 11218.0 11214.0 11210.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 12 11207.5 11201.5 11199 0 11194 5 11194 0 11191 0 11185 0 11184 0 11181 0 11180 5 11178 0 11176.5 11175.5 11171.5 11171.0 11169.5 11168.5 11167.0 11164.5 11162.5 11162.0 11157.5 11156.5 11153.5 11153.0 11150.5 11148.0 11145.0 11142.5 11140.5 11140.0 11136.5 11134.5 11134.0 11128.5 11126.0 11125.0 11122.0 11119.5 11118.5 11113.0 11108.5 11107.5 11101.5 11101.0 11097.5 11096.5 11095.0 11094.0 11091.0 11089.5 11086.5 11086.0 11080.5 11079.5 11206.5 11201.0 11198.5 11193.5 11190.0 11183.5 11179.0 11176.5 11175.0 11173.0 11171.0 11168.0 11166.5 11163.5 11160.5 11154.5 11150.5 11147.5 11143.0 11138.5 11134.0 11132.0 11126.0 11123.5 11120.5 11117.0 11110.5 11106.5 11099.0 11094.5 11091.5 11088.5 11087.5 11085.0 11078.0 11207.0 11198.5 11194.0 11183.0 11179.5 11171.0 11168.0 11162.0 11155.5 11151.5 11149.0 11146.5 11143.5 11141.5 11139.0 11136.0 11134.0 11126.0 11120.5 11110.5 11102.5 11097.5 11095.0 11085.5 11080.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 13 11077.0 11078.0 11075.0 11073.0 11074.0 11073.5 11072.5 11071.0 11071.0 11070.5 11068.5 11066.5 11063.0 11065.5 11062.0 11059.5 11060.5 11063.0 11060.0 11058.0 11057.5 11055.5 11055.5 11053.5 11051.5 11053.5 11050.5 11048.5 11047.0 11045.5 11045.5 11048.0 11045.0 11043.0 11041.5 11040.0 11040.5 11040.5 11036.5 11036.0 11036.0 11036.0 11029.5 11029.5 11029.0 11031.5 11026.5 11029.0 11023.5 11023.0 11020.0 11022.0 11019.5 11018.0 11019.0 11018.0 11014.5 11013.0 11012.0 11012.0 11011.0 11010.5 11009.5 11009.0 11008.5 11009.5 11007.0 11006.0 11005.0 11004.5 11004.0 11003.0 11002.5 11005.5 11000.5 11000.0 10999.0 11000.0 10997.0 10996.5 10995.5 10996.5 10995.0 10994.0 10993.0 10994.0 10992.0 10990.5 10988.5 10988.0 10987.5 10988.5 100.0 101.0 99.5 $ THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 14 LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMTDTP CU 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 SBHNTDTP CU 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 TSCNTDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~ SAMP ELE~ CODE (HEX) TENS TDTP LB 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1185972 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. SBHN. TDTP SDSI. TDTP TCAF. TDTP TSCF. TDTP TENS. TDTP 11620 000 45 067 0 355 19469 320 3935 451 1532 000 DEPT. 10969. 500 SBHN. TDTP 56. 775 SDSI. TDTP 1. 092 TCAF. TDTP 6095. 479 TSCF. TDTP 408. 249 TENS. TDTP 1424. 000 SIGM. TDTP 14.102 TPHI.TDTP 20.622 SBHF. TDTP 37.579 SIGC. TDTP 0.732 SIBH. TDTP 47.461 TRAT. TDTP 1.617 BACK. TDTP 126.858 FBAC. TDTP 33.257 TCAN. TDTP 41278.031 TCND.TDTP 27399.602 TCFD. TDTP 9972.350 TSCN. TDTP 8343.775 INND.TDTP 2106.542 INFD. TDTP 452.959 GRCH. TDTP -999.250 CCL. TDTP 0.000 SIGM. TDTP 43.377 TPHI. TDTP 74.644 SBHF. TDTP SIGC. TDTP 0.467 SIBH. TDTP 74.986 TRAT. TDTP BACK. TDTP 170.312 FBAC. TDTP 35.136 TCAN. TDTP TCND. TDTP 17024.438 TCFD. TDTP 3937.225 TSCN. TDTP INND. TDTP 2309.303 INFD. TDTP 375.637 GRCH. TDTP CCL.TDTP 0.000 49. 726 1. 917 25014. 980 1593. 757 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~iE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUB~ER: EDITED CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 16 Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SOT~VZARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 11609.0 10984.5 TDTP 11609 . 5 10986.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUFIBER : 1 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH GRCH TDTP 88888.0 88887.0 88887.5 11606.0 11605.5 11604.5 11603.5 11602.0 11601.0 11601.0 11597.5 11597.5 11596.0 11595.0 11594.5 11595.0 11590.0 11590.5 11586.0 11587.0 11585.0 11586.0 11581.0 11580.5 11579.5 11577.5 11570.0 11568.5 11564.0 11563.5 11556.0 11558.0 11551.5 11552.0 11550.5 11549.5 11547.0 11546.5 11540.0 11541.0 11535.5 11536.0 11531.0 11530.5 11530.5 11532.0 11525.5 11525.5 11525.0 11525.5 11522.5 11523.0 11518.5 11518.5 11514.0 11514.0 11513.5 11512.0 11511.5 11509.5 11508.5 11509.0 11509.5 11507.0 11505.0 11505.0 11506.0 11503.0 11503.0 11501.5 11499.0 11499.5 11500.0 11496.0 11496.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 17 11492.5 11494.5 11490.0 11490.5 11488.0 11487.5 11486.5 11485.5 11484.0 11484.0 11484.5 11482.5 11481.5 11481.0 11480.5 11477.0 11475.5 11476.0 11475.0 11473.5 11472.5 11471.5 11472.5 11469.5 11470.0 11470.5 11468.5 11467.5 11467.0 11467.5 11464.5 11464.0 11464.0 11464.0 11458.5 11457.0 11458.0 11457.0 11454.5 11452.5 11452.5 11451.0 11449.5 11449.5 11449.0 11448.5 11448.0 11446.5 11446.5 11446.5 11445.0 11444.5 11443.0 11441.5 11442.5 11440.0 11438.5 11439.5 11439.0 11436.5 11436.0 11435.5 11435.0 11433.5 11432.5 11432.0 11432.0 11430.5 11430.0 11428.5 11425.5 11426.0 11424.5 11423.0 11419.5 11419.5 11414.5 11413.5 11414.5 11411.5 11411.0 11411.0 11410.5 11408.0 11407.0 11407.0 11406.5 11405.0 11400.5 11401.0 11400.0 11397.5 11397.0 11397.0 11396.5 11393.5 11394.5 11393.0 11394.5 11389.0 11390.0 11389.0 11385.5 11385.0 11385.0 11385.5 11383.0 11383.0 11382.5 11382.0 11379.5 11378.5 11378.5 11378.5 11376.5 11377.0 11373.0 11373.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 18 11371.0 11367.5 11367.0 11361.5 11358.5 11356.0 11355.5 11351.5 11349.0 11348.0 11343.5 11341.5 11340.5 11339.0 11337.0 11334.5 11332.5 11329.5 11326.0 11321.5 11318.5 11318.0 11315.5 11315.0 11312.0 11311.0 11309.0 11308.0 11307.5 11302.5 11298.0 11293.5 11292.0 11291.0 11289.5 11286.5 11283.0 11280.5 11278.5 11275.0 11274.5 11272.0 11268 5 11267 0 11264 5 11264 0 11257 5 11253 5 11252 0 11251.5 11250.0 11249.5 11246.0 11243.0 11242.5 11373.5 11367.0 11359.0 11355.5 11351.5 11348.0 11341.5 11338.5 11335.5 11332.5 11330.0 11319.5 11315.5 11311.0 11308.5 11305.5 11293.5 11290.0 11286.5 11283.0 11280.0 11274.0 11272.5 11269.0 11267. 0 11265.0 11257.0 11253.0 11250.5 11245.0 11367.0 11362.5 11358.0 11355.5 11352.5 11348.0 11343.5 11341.0 11334.5 11330.0 11326.0 11322.5 11318.5 11315.5 11311.5 11307.5 11302.5 11297.5 11294.5 11292.0 11290.0 11287.5 11283.0 11280.0 11276.5 11273.0 11269.5 11264.5 11258.0 11254.5 11253.0 11250.5 11247.5 11243.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 19 11241.0 11241.0 11237.0 11237.0 11236.0 11237.0 11233.0 11234.5 11234.0 11230.0 11231.0 11226.0 11226.5 11225.0 11226.0 11223.0 11223.0 11221.0 11221.0 11222.0 11218.0 11218.5 11217.5 11217.0 11215.0 11216.0 11213.0 11213.0 11211.0 11210.0 11210.5 11207.0 11206.5 11206.5 11206.5 11204.0 11204.0 11202.0 11201.0 11201.5 11201.0 11198.5 11198.5 11198.0 11198.5 11195.0 11194.5 11193.5 11194.0 11191.0 11190.0 11188.0 11187.5 11187.0 11186.5 11186.5 11187.0 11184.0 11183.0 11183.5 11183.0 11180.0 11179.0 11179.5 11179.0 11177.5 11176.5 11177.0 11176.5 11175.5 11175.0 11171.0 11171.0 11170.5 11171.0 11168.5 11168.0 11168.0 11166.5 11162.5 11161.5 11162.0 11160.5 11159.0 11158.5 11158.0 11157.0 11156.0 11155.5 11154.5 11153.5 11153.5 11150.5 11152.5 11151.5 11150.0 11147.5 11149.0 11148.5 11146.5 11148.0 11146.5 11145.0 11143.0 11144.5 11143.5 11142.0 11141.5 11140.0 11138.5 11139.0 11138.5 11136.0 11134.0 11136.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 20 11134.0 11129.0 11124.0 11122.5 11119.5 11118.5 11115.5 11113.5 11112.5 11108.0 11107.5 11101.5 11101.0 11096.5 11094.0 11091.5 11090.5 11088.5 11085.0 11084.5 11079.5 11079.0 11077.0 11076.5 11073.5 11072.0 11070.5 11068.0 11062.5 11059.5 11057.5 11055.0 11051.0 11049.0 11047 0 11045 5 11045 0 11041 0 11039 5 11035 5 11034 0 11026.0 11025.5 11020.0 11019.0 11017.0 11010.5 11009.0 11008.5 11006.5 11004.5 11002.0 11000.0 10999.0 10996.5 11132.0 11120.5 11117.0 11114.0 11112.0 11106.5 11099.5 11092.0 11088.5 11087.5 11084.0 11078.0 11076.0 11071.0 11066.5 11059.5 11058.0 11056.0 11053.5 11048.5 11045.5 11043.5 11040.0 11036.0 11026.5 11020.5 11010.5 11009.0 11006.0 11004.0 11000.0 10996.5 11134.0 11129.5 11125.5 11120.5 11115.5 11110.5 11102.5 11097.5 11094.5 11092.0 11088.5 11085.5 11080.0 11078.0 11073.5 11070.5 11065.5 11063.0 11053.5 11048.0 11040.0 11035.5 11029.0 11022.0 11017.0 11012.0 11009.0 11006.0 11000.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 21 10994.0 10993.5 10991.0 10990.0 100.0 $ 10994.0 10990.5 99.5 10996.5 10991.5 101.5 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP BASE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS ~3 AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #3 AND SIGMA BASE PASS #1, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 SIGMTDTP CU 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 SBHNTDTP CU 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 22 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP EL~4 CODE (HEX) TRAT TDTP 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 TSCNTDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 GRCHTDTP GAPI 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1185972 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 11625.500 SIGM. TDTP 13.351 TPHI. TDTP 21.103 SBHF. TDTP 37.792 SBHN. TDTP 50.852 SIGC. TDTP 0.688 SIBH. TDTP 58.550 TRAT. TDTP 1.605 SDSI.TDTP 0.286 BACK. TDTP 188.145 FBAC. TDTP 42.769 TCAN. TDTP 43369.766 TCAF. TDTP 20783.605 TCND. TDTP 28226.953 TCFD. TDTP 10463.045 TSCN. TDTP 8791.205 TSCF. TDTP 4212.909 INND.TDTP 2133.145 INFD. TDTP 466.382 GRCH. TDTP -999.250 TENS.TDTP 1571.000 CCL.TDTP 0.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAM~ : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 23 FILE HEADER FILE NUMBER: 8 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREFiENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS ~ERS 1, 2, 3, TDTP THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 80 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE ND?4B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 24 NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SBPiNPNAV CU 1185972 00 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 TCAFPNAV CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 TCNDPNAV CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 TCFDPNAV CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 INNDPNAV CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1185972 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 11622.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBPL~.PNAV -999.250 SIGC.PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 40.455 FBAC. TDTP 13.421 TCAN. PNAV -999.250 TCAF. PNAV -999.250 TCND.PNAV -999.250 TCFD. PNAV -999.250 TSCN. PNAV -999.250 TSCF. PNAV -999.250 INND.PNAV -999.250 INFD.PNAV -999.250 GRCH. TDTP -999.250 DEPT. 10976.500 SIGM. PNAV 44.175 TPHI.PNAV 72.465 SBHF. PNAV SBHN. PNAV 57. 738 SIGC. PNAV 0.224 SIBH. PNAV 77.175 TRAT. PNAV SDSI.PNAV 1.165 BACK. TDTP 129. 719 FBAC. TDTP 26. 789 TCAN. PNAV TCAF. PNAV 5889.248 TCND.PNAV 16148. 408 TCFD. PNAV 3763.937 TSCN. PNAV TSCF. PNAV 378.103 INND.PNAV 2130.582 INFD. PNAV 369.687 GRCH. TDTP 53.215 1. 848 23926. 492 1454. 990 47. 672 ** END OF DATA ** **** FILE TRAILER **** FILE NAFIE : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 25 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUF1BER 9 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREM~2Fr : 0.5000 FILE SUI~4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11652.0 10937.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAIV~IA RAY TDTP THERMAL DECAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 12-MAY-98 8Cl -205 1805 13 -MAY-98 11750.0 11640.0 10954.0 11626.0 TOOL NUMBER CGRS-A TDT- P 8.500 11800.0 SEA WATER/BORAX 8.35 220.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 26 FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Tied into BHC SONIC log dated 24-Feb-89 SHUT IN PASS MADE WITH WELL FILLED WITH 150 BBL SEA WATER 3 PASSES MADE WITH 150 BBLS OF SEA WATER IN THE HOLE PUMPING AT 0.5 BBL/MIN 60 BBLS OF BORAX WATER PUMPED AT 4 BBL/MIN 3 PASSES MADE WITH 20, 40, AND 60 BBLS OF BORAX THROUGH THE PERFS ONE FINAL PASS MADE WITH 50 BBLS OF WATER FLUSHING BORAX OUT. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 27 TYPE REPR CODE VALUE 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 SBPiNPS1 CU 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PSl CU 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TCAFPS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TCNDPS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TCFDPS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 INNDPS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1185972 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 11653.000 SIGM. PS1 -999.250 TPHI.PS1 -999.250 SBHF. PS1 SB}{N. PS1 -999.250 SIGC. PS1 -999.250 SIBH. PS1 -999.250 TRAT. PS1 SDSI.PS1 -999.250 BACK. PSI -999.250 FBAC. PS1 -999.250 TCAN. PS1 TCAF. PS1 -999.250 TCND.PS1 -999.250 TCFD.PS1 -999.250 TSCN. PS1 TSCF.PS1 -999.250 INND.PS1 -999.250 INFD.PS1 -999.250 TENS.PSi GR.PS1 27.121 CCL.PS1 0.000 DEPT. 10938.000 SIGM. PS1 44.674 TPHI.PS1 74.575 SBHF. PS1 SBHN. PS1 60.924 SIGC. PS1 0.000 SIBH. PS1 84.397 TRAT. PSl SDSI.PS1 1.217 BACK. PSi 121.495 FBAC. PS1 26.916 TCAN. PS1 TCAF. PS1 5472.889 TCND.PS1 15374.135 TCFD. PS1 3535.682 TSCN. PS1 TSCF. PS1 345.748 INND. PS1 2000.216 INFD. PS1 345.808 TENS.PSi -999.250 -999.250 -999.250 -999.250 920.000 55.763 1.851 22356.547 1352.584 1372.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 28 GR.PS1 51.756 CCL.PS1 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUM~ER 10 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH 11649.5 10928.0 TDTP LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 12-MAY-98 8Cl -205 1805 13-MAY-98 11750.0 11640.0 10954.0 11626.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 29 GR GAM~A RAY TDTP THERMAL DECAY $ CGRS-A TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11800.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~PERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER/BORAX 8.35 220.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Tied into BHC SONIC log dated 24-Feb-89 SHUT IN PASS MADE WITH WELL FILLED WITH 150 BBL SEA WATER 3 PASSES MADE WITH 150 BBLS OF SEA WATER IN THE HOLE PUMPING AT 0.5 BBL/MIN 60 BBLS OF BORAX WATER PUMPED AT 4 BBL/MIN 3 PASSES MADE WITH 20, 40, AND 60 BBLS OF BORAX THROUGH THE PERFS ONE FINAL PASS MADE WITH 50 BBLS OF WATER FLUSHING BORAX OUT. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 3O ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 SBH~PS2 CU 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TCANPS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TCAFPS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TCNDPS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TCFDPS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TSCF PS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 INNDPS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 INFDPS2 CPS 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1185972 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 31 ** DATA ** DEPT. 11651.500 SIGM. PS2 SBHN. PS2 -999.250 SIGC.PS2 SDSI.PS2 -999.250 BACK. PS2 TCAF. PS2 -999.250 TCND.PS2 TSCF. PS2 -999.250 INND.PS2 GR.PS2 421.176 CCL.PS2 DEPT. 10930.000 SIGM. PS2 SBHN. PS2 58.737 SIGC. PS2 SDSI.PS2 1.150 BACK. PS2 TCAF. PS2 6331.849 TCND.PS2 TSCF. PS2 389.794 INND.PS2 GR.PS2 46.050 CCL.PS2 -999.250 TPHI.PS2 -999.250 SIBH. PS2 -999.250 FBAC. PS2 -999.250 TCFD. PS2 -999.250 INFD.PS2 0.000 44.418 TPHI.PS2 0.454 SIBH. PS2 174.444 FBAC. PS2 16733.914 TCFD. PS2 2301.052 INFD. PS2 -999.250 -999.250 SBHF. PS2 -999.250 TRAT. PS2 -999.250 TCAN. PS2 -999.250 TSCN. PS2 -999.250 TENS.PS2 73.558 SBHF. PS2 79.437 TRAT. PS2 37.836 TCAN. PS2 3940.296 TSCN. PS2 396.738 TENS.PS2 -999.250 -999.250 -999.250 -999.250 844.000 55.062 1.854 25517.027 1516.061 1387.000 ** END OF DATA ** **** FILE TRAILER **** FILE NA~iE : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE . 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER 11 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INC~: 0.5000 FILE SUF~WzARY VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 11651.5 10932.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 32 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): 12-MAY-98 8Cl -205 1805 13 -MAY-98 11750.0 11640.0 10954.0 11626.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS-A TDT- P BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 11800.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER/BORAX 8.35 220.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELIArE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 12000 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Tied into BHC SONIC log dated 24-Feb-89 SHUT IN PASS MADE WITH WELL FILLED WITH 150 BBL LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 33 SEA WATER 3 PASSES MADE WITH 150 BBLS OF SEA WATER IN THE HOLE PUMPING AT 0.5 BBL/MIN 60 BBLS OF BORAX WATER PUMPED AT 4 BBL/MIN 3 PASSES MADE WITH 20, 40, AND 60 BBLS OF BORAX THROUGH THE PERFS ONE FINAL PASS MADE WITH 50 BBLS OF WATER FLUSHING BORAX OUT. THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 88 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 SBHNPS3 CU 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 SIGC PS3 CU 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 SIBH PS3 CU 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 SDSI PS3 CU 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 BACK PS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 34 NAME SERV UNIT SERVICE API API API API FILE NUFIB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) TCANPS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 TCAFPS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 TCNDPS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 TCFD PS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 TSCN PS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 TSCF PS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 INNDPS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 INFD PS3 CPS 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1185972 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 11654.500 SIGM. PS3 SBHN. PS3 -999.250 SIGC. PS3 SDSI.PS3 -999.250 BACK. PS3 TCAF. PS3 -999.250 TCND.PS3 TSCF. PS3 -999.250 INND.PS3 GR.PS3 298.333 CCL.PS3 -999.250 TPHI.PS3 -999.250 SBHF. PS3 -999.250 -999.250 SIBH. PS3 -999.250 TRAT. PS3 -999.250 -999.250 FBAC. PS3 -999.250 TCAN. PS3 -999.250 -999.250 TCFD.PS3 -999.250 TSCN. PS3 -999.250 -999.250 INFD.PS3 -999.250 TENS.PS3 906.000 0.000 DEPT. 10935.000 SIGM. PS3 44.858 TPHI.PS3 73.876 SBHF. PS3 52.424 SBHN. PS3 57.291 SIGC. PS3 0.000 SIBH. PS3 76.157 TRAT. PS3 1.872 SDSI.PS3 1.371 BACK. PS3 196.647 FBAC. PS3 39.245 TCAN. PS3 23474.445 TCAF. PS3 5908.612 TCND.PS3 16302.617 TCFD.PS3 3774.671 TSCN. PS3 1510.311 TSCF. PS3 396.575 INND. PS3 2237.816 INFD. PS3 365.842 TENS.PS3 1373.000 GR.PS3 51.716 CCL.PS3 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JUN-1998 15:09 PAGE: 35 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/06/29 ORIGIN : FLIC TAPE NAIVE : 98270 CONTINUATION # : 1 PREVIOUS TAPE : COM~T : BP EXPLORATION, Z-25, PRUDHOE BAY, 50-029-21902-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 98/06/29 ORIGIN : FLIC REEL NAM~ : 98270 CONTINUATION # : PREVIOUS REEL : COI4MENT : BP EXPLORATION. Z-25, PRUDHOE BAY, 50-029-21902-00 * ALASKA C~MPUTING CENTER , ****************************** *-~-'--' SCHLUMBERGER ****************************** COMPANY NAME : BP EXPLORATION WEbI,~ NAME : Z-25 FIELD M~E : PRU~3HOE BAY BOROUGh4 : NORTH SLOPE STATE : ALASKA API NUMBER ~ 50-029-21902-00 REFERENCE NO : 92424 IS Tame vertflcat.!on Listing chlumber.~er Alaska COmPUtiDQ Center 5-AUG-1992 15:46 *~** REEL HEADER **** SERVICE NAME : EDIT DATM : 92/08/ 5 ORIGIN : FbIC ~EEI, NA~E : 92424 CONTINI..I~TION ~ : COW~ENT ~ BP EXPLOPATION,PRUDHOE ~A¥,Z-25,500292190200 **** TAPS HEADER **** SERVICE N~E : EDI'T DATE : 92/081 5 ORIGIN : Fb!C T~PM MA~E : 92424 CONTINUATION ~ : ~. PREVIOUS TAPE : CO~ENT : BP EXPLORATION,PRUDMOE ~AY,Z-25,500292190200 TaP~ WEADER PRUDHOE BAY UNIT CASED HOLE WlRELINE bOGS WELL MA~E: API NU~ER: OPERATOR: LOGGING COMPANY: TAP~ CREATION DATE: JOB NUMBER: [,OGLING E~GINEE~: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWN.SHIP: RANGE: FEL: ELEVAT![}M(FT FPO~ MSL O) KELLY BUSH!MG: DERRICK FLOOR: GROUND LEVEL: WEL5 CASING RECORD SURFA. C~ LOCA. TION ~ST STRING 2ND STRING ~RD STRING PRODUCTION STRING BP EXPLORA, TION SCHLUMBERGER WELL SERVICES 5-AUG-9~ 92424 G, JOHNSON M, CHAmBeRS %iN ~2E 3143 g1~50 ~ 0 OPEN H[)[.,[~ C~S!NG DRILLERS CASING ]BIT SIZe', (iN) SIZE (IN) DEPTH (FT) WEIGHT (bB/FT) 12. 250 9,625 10986'0 47.00 8,500 7,000 11800,0 26,00 PAGE: Tame verlflcat~.on bistino 5-AUG-lg92 .1.5:46 chlumberqer Alaska Computing Ce.n..ter CURVE SNIFT DAT.A - AbI., PASSES TO STAIgDAR[~(~E~SURED DEPTH) ~.SELINE CURVE FOP SMIFTS PBU TOOL CODE: BCS PRU C[I~VF CODE: GR PASS ~U~BER: LOGGING C[]~,.~PANY: gASELIN 1.1689.5 11_661 5 11661!0 .i 1511. 5 !1464,0 ! 1447 0 11440i0 ~ 1433 0 a 3 . i. 1~82 5 I 121,.6.0 11~11,0 l,1183.5 11178,0 11144,5 1 ! 109,0 .11054 5 1, 1045'0 1!041,0 ~ 1040,5 1,0~98,5 1. O996,5 100,0 --- ....... EOUI¥'ALENT UNSHIFTED DEPTHm---- E DEPTH GRCM C~TD ~ 88 5 11689,0 11661.0 11661.0 11511,5 1.1464,0 11464,0 11447.0 11439,0 11433,0 !1397,0 11332,5 11,.332,5 11250.5 11250.5 11222.5 1. t216,0 1..1~10,5 11202,0 1.11.83,0 1,1,176.5 1.1143,0 1.1.126,0 11107,0 11053,5 11043,5 11,040,0 11040,0 11000,0 10996,5 !00,0 101,5 Open hole data such as 1, ogglng date, logging company, runtape· numberDrovl, ded. and byDassthenumberclient,WaSTn°the depthsuppliedshiftswlthshownthe above reflect, cased hOle~GR to open hole GR nad cased hole NPHI,to open ,hole Field enqineer remarks: Ti, ed-in to..,.CET dated 3/2/89 ~ell shtlt-ln at 10:30 on 7/1.2/92 SIWHP= ~050 PSiG 2.5" CNTD ran on sandstone matrl~ Apparent GOC at It352' $ PAGE~ IS Tape Verificat. ion I..,istino chlumberger Alaska Commutino Center 5-A. UG- ~, 992 15:46 **** FILE {-qEADER **** FILm MA~E : EDIT ,00l SFRVICE : rL!C VERSIOM DATE : 92/08/ 5 MAX REC SIZE : 1.024 FILF TYPE : LO LAST FILE FIL~ NUMBER: 1 EDITED CURVES DePth shifted and cl!~ped curves for' each Pass ~D separate files. PAS8 NU~BER: DEPTH INCREMENT 0.5000 FTbE SUMMARY PBU TOOL CODE START DEPTH c~CH 11.69~ CMTD 1~704.0 $ CURVE SHIFT DATA - PASS TO PhSS(~EASI..~ED DEPTH) BASELINE CI.]R.'VE~ FOR SHIFTS PBU CURVE CODE: P~SS STOP DEPTH 10980,0 I(:)980.0 ,.--,.------5.~{)I. JIVA!!EMT~ UMSHIFTED DE'PTH-,-------.,,,. RE~aPKS: This ~::ile contains CNTD , ' data P, IS FOR!~Ii%T O,hTh pass to pass ~' T ;' . ** DhTA F[]R,~2T SPEC!,[ ICR I[':'~N R[,C[:]PD ** ** SET TYPE - 64EB ** TYPE. . P~ COP~ V~LUE I 66 O 2 66 0 ] 73 4O IS Tame Verification Listinq chlumber~er AlasKa ComputinO Center 5-AUG-19g2 1.5:46 PAGE: 4 66 5 66 6 73 ? 65 8 68 045 9 65 1~ 66 ~5 1~ 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ** S~T Na~E SERV U~I~ ID DEPT NP~I CNTD PU-S NR&T CNTD C~AT CNTD NCNT CNTD CPS FCNT CNTD CPS. CNTC CNTD CPS CFTC CNTD CPS G~CH CNTD GAPI TENS CNTD TYPE SERVICE APl ORDER ~ LOG TYPE 440557 O0 000 00 0 I 440557 00 000 00 0 440557 O0 000 00 0 440557 O0 000 00 0 440557 00 000 00 0 1 440557 O0 000 O0 0 440557 00 000 O0 0 44(:)557 00 000 O0 0 440557 00 000 00 0 I 440557 O0 000 O0 0 1 -CRAN ** API AP1 FlUE NIteR NUMB SIZE REPR PROCESS CLASS MOD NUmB S~MP ELEM CODE (HEX) ! 1 4 68 0000000000 1 I 4 68 0000000000 ! 1 4 68 0000000000 1 t 4 68 0000000000 1 ! 4 68 0000000000 1' 1 4 68 0000000000 1 1 4 6~ 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1. 1 4 68 0000000000 , * D a T ~ * * DEPT. 1170,4,()00 NCNT.CNTD 4.249.233 ~RCH. CNTD -999. 250 O E P T. 11. 500,000 ~NT.CNTD 4576.098 ~ CW.CNTD 31 DS:PT. 11000,000 N CNT,CNTD 4556,854 ~ C~ CNTD 53,563 D=,PT, 10980 000 NC~T,CNWD ~013.0~5 NPHI.CNTD 27. 568 FCNT.CNT.D 983.333 TENS.CNTD 1910.000 TD 19.502 NPHI .CNT FCNT, CN D 1~66.667 NPHI CNTD 17,518 FCNT:CNTD 1292,242 FC P,CNTD 272,340 T E N .$ , C', N T D 1715 . 000 NRAT.CMTD CNTC.CNTD MRAT.CNTD CNTC,CNTD NRAT,CNTD CNTC,CNTD MRAT,CMTD CNTC.CNTD 4 644, 40682466 3.684 4500.784 3,553 441.3,053 7,500 1,967.973 CRAT.,CNTD CFTC.CNTD CRAT.CNTD CFTC,CNTD CR~T.CNTD CFTC,C~ITD CRAT.CNTD CFTC.CNTD 4.745 927,'833 3,686 1,194,714 1,29~:It0 ,IS Tare Verification Listi. no ichlUm'berger ,~laska Computinc~. Center 5-AUG-1,99~ 15:46 PAGE: ** END OF DATA **** FILE TRAILER **** FILE NA~E : EDIT .001 SERVICE ! FL!C V~RSION : O0~A07 DATE : 92/08/ 5 MAX REC SIZE : ~024 FIL~ TYPE LAST FILE : **** FILE HEADER **** FILE MA~E : E~IT SERVICE : FblC VERSION : O0~A07 DATE : 92/08/ 5 ~AX REC SIZE ! 10~4 F~LE TYPE bAST FILE FILE HEADER FIbM NUMBER~ EDiTL[ CURVES Depth shi~t, ed and cl~pped curves for each pass PASS NUMBER: 2 DEPTH IMCREM~MT 0°5000 FILE SUmmARY PBU TOOL CODE START DEPTH ~RCH }1692,0 CNTD $ CURVE S~{IFT DATA ' PAS8 TO PASS fM~CASURED DEPTH) BASELINE CURVE FOR SHIFTS PB'U CURVE CODE: GRCH PASS N{.I~BER: 1 BA.SELINE DEPTH . , 1, I6'86,5 ~1664,0 11661,0 ,1, 165 ii , 0 DEPTH 9880,0 o.o separate i~ll. es, ----------E(~U I V ALENT UNSHIFTED G~ C~ C N TD 11686,5 11. 6 64.0 11660~5 IS Tare verification i..,istin~ cblumberqer Alaska Computinq Cent, er B-AUG-1992 15:46 11 11 11 · 1 !1 11 1. 560,0 527,0 520,5 519,0 464 5 418:0 394,0 3gO,O 379,5 376,5 333.0 31.5,5 1264,5 1.255,0 1250 5 1250i0 1201. 0 lJ. 98 0 1184 1150 1135 !072 1,041 099g 0997 (t989 1,,00 S LT S 11559,5 !!.527,0 11520,0 1. I51.9,0 II. 464.0 ~.!4~8.0 11393.0 11390,0 1.1379.0 1.!376.5 11332.0 11315,0 11,~64.5 I1~54.5 11~50.0 ~1250,0 11~01,0 111.98,5 11150,0 11134,0 11.072,0 1.!041,0 10998,5 1.0996.5 I0989,0 99°5 99.5 This file contains CNTD PaSS Shown above relect C~.C)~' Pass MPHI pass #2 t.o I'tPFlI pass FORMAT DATA 82, The depth #2 to GRC)~ pass s~i~ts and PAGE: OR. MAT ,,,, ~:. ..... IFICA. TION ** SET TYPE - 64EB 7' Y P ~'; ~ E P R ~ 6 4 5 7 8 9 R E C .,} R D * * CODE V,ALtIE 6 0 66 0 73 40 66 1 66 73 65 6~ 66 0,5 ~5 · .IS Tape Verification I...istl. nq ;chlumberger AlasKa COmPUtI. Dg Cent. er 5-AUG-1992 1,5:46 7 TYPE R~DR CDD~ VAI..,I.IE 12 68 13 66 0 14 65 15 66 68 16 66 0 66 ** SET NA. SERV UNIT I D DEPT FT NDHT CNTD PU-S NR~T CNTD CRAT CNTD NCNT CNTD CPS FCNT CNTD CPS G~CH CNTD GAPI CNTC CNTD CPS CFTC CMTD CPS TENS CNTD LB TYPE - CHAN ** ..... '"";""' ..... SERVICE A I API AP ORDER # bOG TYPE CLASS MOD N 440557 O0 000 O0 0 2 440557 O0 000 O0 0 2 ~40557 O0 000 O0 0 440557 O0 000 O0 0 440557 O0 000 O0 0 4.4.0557 O0 000 O0 0 440557 O0 000 O0 0 440557 00 000 O0 0 2 440557 O0 000 O0 0 2 440557 O0 000 O0 0 PI FIbE ~UMB NUMB IZE ~F, R ROCES$ UMB SA~.~P EI.~EN. CODE (HEX) 68 0000000000 68 0000000000 68 O000OO0000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68, 0000000000 ** [, ~r,~ ** D~.,PT. 11704 000 NCN?. CNTD 4151: 174 C~'TC. C.NTD 906,054 D [{,l p T., 1. I, 500.00 0 NCNT, CNT[) 4666,666 CFTC,CNTD 1184,311 DEPT, 1 i000,000 NCNT,CNTD 4284,803 CFTC,CMTD 1 !55,162 DFPT. ' ') 10980,000 NCNT,CNT[ ~074.389 CwTC.CNTD 264,337 NPHi ,CNTD FCNT,CNTD T E D.]C~, CNTD NPHI ,CMTD FCNT, CNTD TENS, CMTD NPHI .CNTD FCNT' C~T'D TENS. CNTD U ~ H I . C N T [) CNTD FCNT, CNTD TENS, , , 28,644 NRAT.CNTD , .4.700 CRAT.CNTO 979,592 GRCH,CMTD -999.250 CNTC,CNTD 1885.000 20,221. NRAT,CNTD 3.733 CRAT.CNTD 1250.000 GRCH.CNTD 33.656 CNTC,CNTD 1'155,000 17,~25 NRAT.CNTD 3 .437 CRAT.CNTD 1183,~33 GRCH,CNTD 62:039 CNTC,CNTD 1730,000 52,281 ~RAr. CNTD 7. 94 CRAT.CNTD 283,333 ~,RCH C~TD 59. 81 CNTC CNTD 1700,000 4,878 4099.289 4509.594 4157'570 ** END C)F DATA ** lis Ta~.e verlficatJ, on !,isting chlu~berger Alaska Computing Center 5-AUG-1992 15:46 $**$ FILE TRAILER F.]LE NA~E : EOIT .002 SF,~VICE : FblC VF,~SION : 00~A07 D~TE : 92/08/ 5 ~AX REC SIZE : ~0~4 FILM TYPE : LO LAST FILE : $~$ FILE ~E~DER FIL~7 NAME : El)IT .003 SERU ICF.., : FLIC VERSION : 00lA07 DATE : 92/0~/ 5 ~aX F~EC SIZ%~ : 1024 FI5~ TYPE : LO L.~S· FILE FIl, F HEADER EDITED CURVES De.otb Shifted add CliPPed curves for each pass ~n separate f:.ll,.es. P.~S8 NU~BER: 3 DEPTH I NCRE'~ENT 0,5000 PBU TOOl., CODE START DEPT[{ STOP DEPTH C'NTO 11704,0 109 O, CI.JRV~ SHIFT DA,.~A - PASS TO F~oS(~EAS[..IRED DEPTH) 8A~,,,LLINE CURVE FOR S}'{IF..S PBU CURV~% C(]D~Jll GRCH BA. SELI ,NE D~PTH 11687,5 ,~ 1684.5 ~1675,5 ~ ~.669,0 1 1661.0 I. 1660.5 . ,.i657,0 ~ 1577,0 ,., 1539,0 ~ ~5~ ~0 1, 1 88.5 ----------EQ[)IV.lkLENT U~SHIFTED DEPTH--'------- ~8888.5 11,661.0 11..685 0 11668.5 ~.1661,0 1.1657'5 1.1576,5 11511.5 IS Tape verification Listing cblumberQer Alaska ComputJno Center 5-adG-1992 1,5:46 ~1397.0 11397.0 ~1379.0 1.1379,0 11366,0 11366,5 ~1355o0 11.355,0 ~1332,5 !1332,5 J~282,5 1~.282,5 ~50,O 11250,0 ~1150~0 - 11150.0 ~145o0 1.1071,5 11072,0 11006,5 RE~ARKS: his file contains CNTD Pass showm above relect GRCH Pass NPNI pass ~3 to NPHI pass ~.1.,. S LIS FORMAT DATA The depth to GRCH pass # 1 and PAGE~ DATA FORgAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE V~LIJE 1 66 0 ~ 66 0 3 73 4 66 5 66 6 73 7 65 8 68 0~+5 g 65 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 1,6 66 0 66 IS Taoe Vertilcation Listinq chlumberoer Alaska ComputtnO Center 5-Al)G-1992 15:46 PAGE: ** SET TYPE - CNAN ** NAPE S~]RV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD N(J~ SAMP ELEM CODE {HEX) DEPT FT ~ 05 7 00 0 O0 3 1 1 4 68 00 00000 NPHY CNTD PU-S 440557 O0 000 00 0 ] 1 1 4 68 0000000000 N~AW CNTD 440557 O0 000 00 0 3 1 ! 4 68 CRAT CNTD 440557 00 000 O0 0 ] 1 I 4 68 NCNT C~TD CPS 440557 00 000 00 0 3 1 1 4 68 FCNT C~!TD CPS 440557 00 00O 00 0 ~ 1 1 4 68 G~CH C~TD G,~P! 440557 O0 000 00 0 3 1 1 4 68 CNTC CNTD CPS 440557 00 000 00 0 ~ ~ 1 4 68 CFTC CNTD CPS 440557 00 000 00 0 ] ! 1. 4 68 T~NS CNTD LB 440557 00 000 O0 0 3 1 1 4 ,68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 10 ** DATA ** DEPT. NCMT.CNTD CFTC.CNTD 4537,500 FCNT:CNTD 129,, o-. 5 o o o o o 1 "' t* C~?TD 1690,000 ~80,000 MP"i C'TD 49 790 ~9 796 ~CgT.CNTD 250~000 DEPT. NCMT.CNTD T CFTC,CN..D C F T C . C N T D NCNT.CNTD CFTC.CNTD ** END OF DATA, ** NRAT CNTD GRCH:CNTD BIP,&T,CNTD GRCH,CNTD R.A,T,CNt GRCH.CNTD NRAT'CNTD GRCH;CNTD 4 679 CRAT CNTD -999:~50 CNTC:CNTD 3,602 CRAT CNTD 35.688 CNTC:CNTD ~ ~6 C~.C~TD 62:6 2 CNTC.CNTD C~TC:C~T~ 4,~21 ~7~2. 76 3.719 4423,875 429~:441 547 °° ,4,9 **** FILE TRAILE~ **** F!bE NAMer : EDIT ,003 $~RVICE : FL!C VERSION : OO!A07 ~aX R~;C SIZE : ~024 FILE TYPE L~Sv FILE IS Ta~e veri~ication blstinq chlumberger AlasKa ComDutinq Center 5-AUG-1992 15:46 PAGE: 11 **** FILE HEADER **** FILM NA~E : E[~IT .004 SERVICE : VFRSIOb! : 001A07 D~TF : 92/08/ 5 ~AX PMC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER EDITED CURVES Depth sh].fted and clipped, ctlrves for each pass ~m separate files, P~SS N{.,~BER: 4 DEPTH IMCREMEMT 0,5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH ~RCH 1~692,0 10980.0 CNTD ~ !704,0 10980,0 CURVE SHIFT DATA ' PASS TO PASS(MEASURED DEPTH) 8ASEL. INE CURVE FOR SHIFTS PBU CURVE CODE: GRCH P~SS NUM:BER: BASELINE DEPTH 8888~.0 ~170~.5 11688 0 11657 5 11635 5 11.559 5 11553 5 11.529 5 1151.1,5 11464,0 11450,0 11449.5 ~1440 0 ~1421.5 ~1397,0 11,356,0 11333.0 t133~.5 11283.5 11283.0 ----------EQUIVAbENT UN'SHIFTED ~888 11688.0 1.1464.0 !1449.0 11448.5 11440.0 1!..432.0 11420.5 1.1396.5 1133~.0 11,282.5 CNTD 88887.5 11704'0 11.657,5 1.1.63~.0 1:1.55..5 11553.0 115~9.0 11511.5 11432.0 1.1355,0 11332.5 1.1283.0 IS Tape Verlficati..on Listing chlumberoerAlasKa Computing. Center 5-AUG-199~ 15:46 11211 5 11211,0 11184~5 1]..184.0 loo .o ~0990,0 10989,5 100,0 99,5 99,5 $ # # LIS This file contains CNTD pass shown above r'elect GRCR Pass NP~! pass #4 to NPHI pass #1, S FORMAT DATA #4, The depth #4 t.o GRCH pass and PAGE: 12 ** DATA FORMAT SPECIFICATI[)N RECORD ** ** SET TYPE - 64EB ** TYPE REPR COD~ VALUE 1. 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT 1!, 66 25 1~ 68 I~ 66 0 14 65 FT ~..5 66 68 16 66 ~,, ¢) 66 1 IS Tape Verification Listinq chlumberqer Alaska ComPutiDq Center 5-AUG-1992 15:46 PAGEc ** SET TYPE - Cf'IA~J ** '"'"'"' · .... . m~mmmm~mm~mmmmm~mmm~mmmm~m~mmm~mm~m~mm~mmm~mm~m~~mmm~mmmmmm~m~mmm~mmm~m~ PT FT 440557 O0 000 O0 0 4 I 1 4 68 0000000000 NPHT CNTD NRA? CNTD C~A3' CNTD NCNT CNTD FCZT C~ID GRCH CNTD CNTC CNTD C~TC CNTD PII-S 440557 O0 000 O0 440557 O0 000 O0 440557 O0 000 O0 CPS 440557 O0 000 O0 CPS 4.40557 O0 000 O0 GAPI 440557 O0 000 O0 CPS 440557 O0 000 O0 0 4 1 1 0 4 1 0 4 1 0 4 1 1 0 4 1 0 ¢ 1 0 4 1 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 DATA ** DEPT. 11.704 000 NPHI CNTD 28,592 NCNT. C ' ) ' . Nr[.. 3751:50:t FC~",~: C~TrJ 785.855 C~TC,CNTD 752,805 TENS,CNTD 1835.000 ~C,~iiCN~ 4789,125 FCNT:CMTD 1235,.~t 5 CFTC,CNTD 1194,969 TENS,CN' D .... r.. 1.690 727 D~T. 11000,000 ','~'I. CMT[, 17:~35 M~ T~CNTD 4515,337 Ff. qT,CNTD 12892_96 C... TC.C.I1D ~228 170 TENS.CNTD 1650 000 DEPT. 10980,000 NPHI'.. CNTD 47,~31 MCMT,CNTD 1995,9~0 FCNT,CMTD 272,600 CFTC,CNTD 286,8o3 TENS.CMTD 1620,000 NRAT, CNTD GRCH, CMTD NRAT, CNTD GRCH,CNTD 5RA~ CNTD GRC }., CNTD' NRAT, CMTD GRCH,C~TD 4,760 CRAT.CNTD 999,250 CNTC.CNTD 3'.80~ CRAT CNTD 38.5,31, CNTC:CNTD · 531. CNTC.CNTD 7,765 CRAT,CNTD 56,000 CNTC,CNTD 4 87 4530, 3.,475 4340,259 6 ** END OF DATA ** 1:3 **** FILE TRAILER FILE ~A~E : ~;DIT ,00 SERVICE : F[,IC VW..RSION : O01A07 D.~T~ : 92/08/ 5 f~hX REC SIZE : 1024 FII.,E TYPE : LO LAST FILE IS ?ape Vertf~.catfon f..,istiD~ chlumberqer Alaska Comp~.]tinq Center **** FIbE HEADER **** FIbE NA~E : EDIT .005 SERVICE : ~LIC VERSION : 001A07 DaTE : 92/08/ 5 MAX PEC SIZE ~ 1024 F~bF TYPE : LO LAST FILE : 5-AUG-:~ 997 15:46 Compensated Meutron: Arithmetic average of edited passes ~or all, ct~rves. pUlSed Neutron: Unavera~ed edited Pa~s 1 ~amma ray and backround COUnts; artth~etic average o~ edtted stat~.c baseline passes ~or all. other curves, DEPTH I~CREMENT 0.5000 PASSES INCbUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS ~E~RKS: The arithmetic average of passes 1,2,~ & 4 was computed after all, depth shifts and clipp~,n~ was applied, $ L!$ FORe, AT DATA ** DATA FORMAT SPECIFICATION RECORD ** ~ 66 0 2 66 0 3 73 40 4 66 ~ 5 66 ~ 73 7 65 8 6~ 0 5 ~1 66 25 12 6~ ~,3 66 0 !,4 65 FT :15 65 68 IS Tame Verification chlumberqer ~lasKa Compt)tina Center 5-~UG-1992 15~46 PA~: Y E R .... CODE V UE III~lmIImIImImI.~IIIIlII'I'.'I la 66 1 0 66 1 ** SI~T TYPE - CHAN * '''''''''''''''''';~'~/;~''i';'NI%MS $~RV,... ,INIT.. ID ORDEP ~ LOG ''''''''''''''''''''''''~ ~T 440 5 .... 00''' PU-S 440557 NPH? CNAV O0 N~AT CNAV 440557 O0 CRAT CNAV 440557 O0 NCM~ CNAV CPS 440557 O0 FCNT CNAV CPS 440557 O0 CNTC CNAV CPS 440557 O0 CFTC CNAV CPS a40557 O0 G~CH CNAV GAPI 440557 O0 TFN$ CNAV bB ~40557 O0 ,PI ~PI P ..... TYPE CLASS MOD N ...'--..--'--'--'''; 000 00 0 'IINNIII . .IImIIIII LIMB SAMP ELEa CODE (HEX) ~.'l.''''II~'ll'.'ll'';'l .... 1 1 4 B 0000 00000 000 O0 0 5 ~ ! 4 68 0000000000 000 O0 0 5 1 I 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 ©00 O0 0 5 ~ 1 4 68 O000000OO0 000 O0 0 5 1 t 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 00. 0 5 ! I 4 68 0000000000 ** DATA ** DEPT 1.1704 000 NPHI,cNA¥ G~C~.C~aV 34.805 TE~.~5. C,aY DEPT. t~000,000 NPHI.CN~V NCN~ Cl~ a V 4470,624 FCNT,C~AV '~ ' T C N G....CH,CMAV 61,701 . FINS, 28,450 NRAT,CNA¥ 4.696 CRAT CNAV 907,234 CNTC, CN.AV 3893,999 CFTC~CNAV 1875.000 19,944 NRAT,CNA¥ 3.706 CRAT.CNAV 1260,854 C~.3:'C, CNAV 4491,134 C. FTC, C~AV 1748,854 17,716 NRAT,CNAV 3.422 CRAT,CNA'V ¢, :soo ' ' ' 50.220 7.706 C aT.C aV 269..418 CNTC,CNAV 1993.384 CFTC.C~AV 1680,000 4,854 845,989 3o445 1221.,080 27 ~789 ** END OF DATA ** IS Tape Verification bisttn~ CblUmber~er A.las~a Computing Center 5-AUG-1992 15:46 1¸6 **** FILE TRAILER **** FIL~ NAgE : ~DIT ,005 S~RvICE ~ FLIC VERSION DATE : 92/08/ 5 ~AX NEC SIZE : 1074 FILE TYPE : LAST FILE **** FILE HEADER FILF NAME : EDIT .006 S~RVICE : FLIC VERSION : O01A07 DATE : 92/08/ 5 MAX REC SIZE : i024 FILE TYPE : LAST FILE FIL~ RAW CURVES Curves amd loq header PAS8 NUMBER~ 1 DEPTN INCREMENT: -,5000 FILE SUMaARY VENDOR,TOOL CODE START DEPTH CNT''''~""'''''''''' ''''''~''''11.736. LOG HE~DER DATA DATE LOGGEDI SOFTWARE VERSION: TIHE LOGGER ON TD D~ILLER (FT)~ TD LOGGEP(FT): TOP LOG INTERVAL ~OTTOM LOG INTERVAl, LOGGING SPEED DEPTH COMTROL USED (YES/NO): STOP DEPTH 10975,0 TOOL STRING (TOp TO BOTTOM) v ENDOP, TOOL COI':)E TOOb TYPE C, t¢ ,~ p E N $ ~ T E D N' E (.1T'R 0 N C~TD AtI'X,I'LI~RY T ELE CART,. C ~,~T'O COLLAR LOCATOR CNTD AUXIL'IARY TEbE ~[)DULE 12-JUb-9~ CP 32,6 1300 12'JUL-,92 1.170B.0 109 .0 11705.0 1800.0 TOOL NUMBER CNC-DA-146 ATC-CB-1199 CAL-UB-1269 AT~-AA-374 IS Tape Verlflcation l,,istino chlumherqer AlasKa Computin~ Center 5-AUG-1992 ]5:46 ~OP.EHObE AND C.~STNG DATA OPEN HOLE MIT SIZF, (IN): DRILLERS CASING DEPTH (FT): [,OGGERS CASING DEPTH BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE T~MPE~ATURE (DEGF): BOTTOM HOLE TEmPERaTURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RAT~ AT WELL}'~E~D (FIPN): W~TEI~ CI]TS [PCT): GSS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOl, TYPE (EPITHER~qAL O~ THERMAI,): ~T~IX: ~ATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL Z~NE TOP NORMALIZING WINDOW BASE NORMALIZING WINDOW BLUEt, INE COUNT RAT~ SCALES S~T BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE' HIGH SCALE (CPS): NEAR COUNT ~ATE LOW c~CAb~ (CPS) NEAR COUNT RATW HIGH SCAI,~ (CPS): TOOL STANDOFF' (',IN): REMARKS: TIED-IN 50 CET [)AT. EL 312189 WELL SHUT-IN AT 10:30 ON 7/12/92 $IWHP= 2050 PSIG 2,5" CNTD PA~ ON SANDSTONE MATRIX APPARENT GOC AT 11352' S LIS F(3RNAT DATA 8,500 1~.80o.0 PRODUCED FLUIDS 48.0 233.0 THERMAL SANDSTONE ~.65 0 50OO 0 ~2000 PAGE: 17 ** DATA FORMAT SPECIFICaTiON' RECORD ** SET TYPE - 64EB ** TYPE RFiPR CODE ~. 66 2 66 IS Tape verlf,,i, cati.,,oD blstinc! chlumberoer Alaska ComputiD~ Center 5-AIJG-1992 15146 PAGEI !8 3 73 4 66 1 5 66 7 65 ~ 68 0,5 9 65 FT !1 66 23 12 68 1~ 66 0 14 65 FT 15 66 68 16 66 1 o 66 ~ ** SET TYPE - CWAM * ID ORDE~ ~ bOG DEPT FT 440557 00 ~P~I PS~ PU 440557 O0 RTN~ PSi 4,40557 O0 TN~A PS~ 440557 O0 RCNT PSi CPS 4,40557 O0 RCFT PSi CPS 440557 O0 CNTC PS~ CPS 440557 O0 CFTC PS1 CPS 440557 O0 G~ PSi G~PI 440557 O0 TENS PSi bB 440557 O0 CCh PS1 V 440557 O0 , TYPE CLASS o00 O0 0 6 1, 1 000. O0 0 6 1 1 000 O0 0 6 000 O0 0 6 1 1 000 00 0 6 000 00 0 6 1 000 O0 0 6 000 O0 0 6 ! 1 000 O0 0 6 1 1 000 O0 0 6 000 O0 0 6 P FIhE N!,I B NUMB S ZE REPR ,,ROCES$ OD NI)~B SAMP ELEM CODE (HEX) 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 ** DATA ** E 117,36.00 0 N P H I D.-,PT, . , . ~'"' :. RCN~,PS1 49~.9,949 t..C,.~ GR, PS1 3 1 ,85,9 TENS, RCNT' " .PSI 4 , GR PS1 31,344 ~FNS DEPT 1 !000.000 N~HI. GP, PS 1, 52. 344 TENS, PS1 25,~¢.4 RTNR,PSle PSi. 1118. 0 C'NTC,Pol 3~ PS1 19,502 RTNR.PS1 PS~. 1266.667 CNTC,P$1 'PSi 1780.000 CCh,PSI '" PS1 PS1 986, 5 CN~'C. PSI, t695,000 CCh. PSi 440 T c 0.000 4500 84 0.000 3.724 TNRA.,PS1 4069.894 CFTC.P$~ 0.000 4.507 1057.021 1191 '686 ,7i4 IS Tape Verification !.,istino chlumber~er Alaska Co~Duting Center 5-AUG-1992 15:4,6 DFPT. 10975.000 NP~!I.PSi ~CNT.PS~ 2%76.408 ~C T.PS1 G{~ PS1 53.2~1 TEMe PSi ,.. ~ ..... .~9~ .. 27~:o51 CNTC.PS~ ~720.000 CCh. PS! 8.000 205~.947 0.000 TNRA,PSI CETC.PS1 7.274 294.733 ** E~.!D O~ DATA **** FILE TRII.!,,FR **** FIL~ NA~E : EDIT .006 SERVICE : FLIC VFRSION : O01A07 D~TE : 92/08/ 5 ~,X REC SIZE : i0~4 FIL~ TYP~ bAST FILM **** FILE HEADER **** FILE NAME : EDIT ,007 SERVICE : FL!C FIL~ TYPE : LO L~ST FILE : FILM !~EADER FIL~ N U~B~]R 7 RAW CURVES Curves and lo~;~ ~eader data for each Pass In separate files; ra~ bac~oroun~ Pass la last, file PAS~ NU~iBER: 2 DS~PTH INCREMENT: -.5000 FILE SUMM .&RY, VENDON TOOL CODE START DEPTH ...-.--.-..---.. C N T'O . ~. 5 S LOG HEADER DATA DATE LOGGED: $,OFTWARE VERSION: TI~E LOGGER 0(~,~ BOTTO~ TD DRILLER (FT): mD LOGGE9 (FT): TOP bOG INTERVAL B[)TTO~ LOG INTERVAl, LOGGING SPEED (FPHR) P~ .... I,'H CONTROl, US~]D CY~,,S/N~'~): STOP DEPTM 10976,0 1.2-JUL-92 cp 1300 12-JIJL-92 I170~,0 1170 ,0 10980 0 7os:o !800,0 NO IS TaPe Yeri~fcation Ltstin~ ChlUmberoer ~laska Computi 0n. Center 5-AOG-1992 15:46 PAGE: 2O TOOt, STRING (TOP TO BOTTOM) VENDO~ TOOL, CODE TOOL TYPE; .. B C[~PE~S ED t~EIJTRON C~TD AUXILIARY TFLE CART, CN:TD COLLA~ C~TD AUXILIARY TELE ~IODU[,E B[)~EHOLE AND CASING DATA OCEN ~OI.,E 8IT SIZK D~ILLE~S CASING DEPT~ LOGGERS C~SING DEPTH (FT): BO~E~O[,E CONDITIONS FLUID TYPE: FLUID DEb~SITY [LB/G): SURFACE TEMPERATURE (DEGF'): BOTTO~ }'~tOLE TE~P~].RATURE (DEGF): FLUID S~LiNITY (PP~): FLUID LEVEL (PT): . FLUID RATE AT %~ELLHEAD blATER CUTS (PCT): GAS/OIL CNOKE (DEG): NE, i~TRON TOOl,, ~3OL TYPE (E~ITHERMA[~ OR THER~AL)~ ~ATRiX DENSITY: ~nI.,E CORRECTION (IN): BLUELI~.~E CO~.INT RATE ~ORMALIZATION tN OIL ZONE TOP '~OP,.~ALIZING Wl}~DON (FT): BASE NOR~,AI.,IZING W~ND[JW B[,UEL!NE COUNT RAT~ SCALES c ..... :~T BY FIELD ENGINEER FAR COU~'~T RATE LOW SCALE (CPS) ~"A~ COU~T RATE HIG~ SCALE (CPS): '~,',AR CO'UNT RATE bow SCA.bE (CPS) : NEAR COUb]T RATE NIG}{ SCALE [CPS): TOOL STAUDOFF (IN)I ,,E,~A. RKS: IED-IN TO CbT DATgD 3/2/89 ';~'ELL SH[]T-IN AT 10:30 ON 7/12/92 SI WH'P= ~050 2,5" CNTD RA~ O~,~ SANDSTONE ~ATRIX APPAREt~T GOC AT 1~..352' # LIS FOR~,~,T DATA C~C- :146 5TC-CB-1199 CAL-U8-1269 AT~-AA-374 5OO ll~oo.o PRODUCED FLUIDS 48.0 233.0 THERMAL SANDSTO~{~: 2.65 0 5000 0 22000 IS TaDe verification I.,lstlnn chlumberqer Alaska Computinq CeDter 5-~UG-1992 1.5:46 PAGE) 21 FORMAT SPSICIF!CATION ** $~T TYPE - 64~3B TYPE REPR ! 66 2, 66 3 73 4 66 5 66 6 73 7 65 8 6a 9 65 11 66 1.~ 68 13 66 I,,4 65 1~ 66 16 66 0 66 RECORD ** ** C 0 P E V A L U E 0 0 44 0,5 FT 23 0 FI,' 68 ** SET TYPE - CHhN ** ORDER # LOG TYP D~P? FT 440557 O0 000 NPHI PS2 Pti 440557 O0 000 RTNR PS2 440557 00 000 TNRA PS2 440557 O0 000 RCNT PS~ CPS 440557 00 000 RCFT PS~ CPS 440557 O0 000 CNTC PS2 CPS 440557 O0 000 CFTC PS2 CPS 440557 00 000 G~ PS2 GAP'I 440557 00 000 TENS PS2 LB 440557 O0 000 ,CCL ,PS2 V 440557 O0 000 T~ F 'I AP1 A:PI F~,, ..... NUMB NUMB SIZE REPR PROCESS E CI, ASS MOt) NUMB SAMP EbEM CODE CHEX) 00 0 7 1 I 4 68 0000000000 O0 0 7 1. 1 4 68 0000000000 00 0 7 1 1 4 68 0000000000 00 0 7 ~, 1 4 68 0000000000 00 0 7 1 1 4 68 0000000000 O0 0 7 1. 1 4 68 0000000000 00 0 7 I 1 4 68 0000000000 00 0 7 1 I 4 68 0000000000 00 0 7 1 1 4 68 0000000000 O0 0 7 1, I 4 68 0000000000 O0 0 7 i 1. 4 68 0000000000 , * D A T ,~ ,, DF:PT 1. 1.728,500 NPHI.PS2 RCNT:PS2 4919, . .... ' '~ ~ PS2 .... 'q4q RCFT.PS2 GP,PS2 40.344 TEI~., $. D F., P T I :t. 5 () 0.000 N P ~ I. P $ 2 ' " 6 PS2 RCNT,P$~. 46.':ti 734 G~.PS~ 3:656 TEM$,P .... 2 23 ~97 RTNR,PS2 4 17~ TNRA.PS2 117g:161 CNTC,PS2 4764:~7. CFTC,PS~ 1085,000 CCL,PS2 0' 000 20,41,9 RTNR,PS2 3733 TNRA,P$2 1.250.000 CMTC'PS2 4509:594 CFTC.PS2 1760,000 CCL.PS2 ' 0,000 4,274 14,677 3,809 8.3 · 906 .IS Tame Verlflcat~.on biSt~.nq .chlumber~er Alaska Comput~.D~ Center 5-A. UG-~.992 15t46 PAGES 22 DEPT. 11000,000 NPHI.PS2 RCNT.PS2 4066.667 RCFT.FS2 GR,PS2 57,031 TENS,PS2 D~PT. 10976,000 NPHI.P$2 RCNT'PS2 2142.401 RCFT,PS2 G~.PS2 53,219 TENS,PS2 ** END OF DATA ** 18 079 RTNR.PS2 1207i226 CNTC,P$2 ~720 000 CCt.,PS2 53 ~23 RTNR,PS2 289i054 CMTC,PS2 1730 000 CCL,PS2 3.296 TMRA.PS2 3980.381 CFTC.PS2 0.000 7,647 TNRA,PS2 2050.880 CFTC,PS2 0.000 3,494 ~096,227 7,69] 276,855 **** FILE TRAILER **** FILE NA~E : EDIT ,007 SERVICE : FLIC V~RSIO~ t O01A07 D~T~ : 92t0~f 5 MAX REC SIZE : ~.0~4 FILE TYPE : LO LAST FILE : **** FILE }4EADER **** FILE NA~E : F:DIT .008 SERVICE : FLIC VERSION ~ O01A07 I)~T~ ~ 92/0~/ 5 M.a.X REC SIZE : ~02~ Flb~ TYPE : 50 LAST F'I[,E : FILM MEADER FIDE MLI~BER 8 Curves and log header data for each pass in separate files; raw background Pass in last f.~le PASS NUMBER: 3 DMPTB INCREMENT: -.5000 # FILE ~ENDOR TOOt, CODE START .DEPTH $ .L,,G HEADER ..DATA DATE LOGGED: ~OF'rw AR TD D~ILLER (VT): TD LOGGER STOP DEPTM 1.0969,0 ~.2-jUL-92 CP 32,6 1300 12-JUL-92 ~708,0 ~1.708.0 IS WaDe Verification Listing chlumbermer .AlasKa ComDutlnq Center 5-~UG-1992 15:46 PAGE: 23 BOTTOM LOG INTERVAL LOGGIN~ SPEED (FPHP): D~PTH C[}NTPOL USeD (YES/N[}): '.POOL STRING (TOP TO BOTTOm) VENDOR TOOL CODE TOOL TYPE CNTD ~tJXILIARY TELE CART. CMTD COLLAR LOCATOR CNTD AUXILIARY TELE MODULE BOREH[][,E AND CASING DAT~ OPEN HOLE BIT SIZE DRILLERS CASING DEPTH [,OGGERS CASING DEPTH ~O~E~{OLE CONDITIONS FLUID DENSITY (LB/G): SURFACE TE~PERA.~tRE (DEGF) BOTTO~ ~O[,E TEMPerATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELl, HEAD WATER CUTS (PCT): (~AS/OIL N E~',I'RON TOOl,, TOOL TYPE (EPITHE:RM~L O.R THERMAL): MATRIX DENSITY: HOI.,E COR~EC'~ION (IN): BbUELINE COUNT ~ATE NORMALIZATION IN OIL ZONE TOP NOP~AblZING WINDOW (FT): BbUELIME COUNT RaTE SCALES SET BY FIELD ENGINEER WAR COUNT~ R..TE, HIGH SCALE NEAR COt,t~,~' ~RATE LOW SCA!;.,~F': (CPSJ: ~EA.R COUNT RATE HIGH ,.,,CAI, Es (C $): TOOL STAN'D[]FF (IN)~ ~EMARKS: TIED-IN TO CET DATED WELL S~.'}UT-IN AT ~.0:30 ON 7/12/92 8]'.W~P= 2050 PSIG 2,5" C{qTD RAN ON $~MDSTONE ~A. TRIX APPARENT GOC AT ~J~352' 10980.0 11705.0 1800,0 NO TOOb NUMBER DA'146 ATC-CB-l~.99 CAb-UB-1269 AT~-AA-374 8,500 1,1800.0 PRODUCED FLUIDS 48.0 233,0 SANDSTONE 0 5000 0 22000 ~I8 Ta.~e ver.i~ication 'CblUmber.q. er AlasKa Computind Center 5-AUG-l, 992 15:46 PAGE= 24 I_~TS FOR)4&T DATA ** D~T~ FOR.~AT SPECIFICATION RECORD ** 2 66 0 3 73 44 4 66 5 66 6 73! 7 65 ~ 68 0,5 9 65 FT 1~. 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 oET TYPE - C~4AM ** ~i,~ A ~t ~ $ ~,: R V L! hl ! T S E R V I C E A P I .A P I A P I ~ P I F I b E ~ U ~ ~ N U ~ B S I Z E ~ E P R P R 0 C ~i S 8 ID ORDER ,~ bOG TY...E CLASS ~40[) N[I~B S,A~P ELEM E (HEX). ~ 440557 00 000 00 0 8 1 i 4 68 0000000000 NPHI PS3 PU 440557 O0 000 O0 0 8 1. t 4 68 0000000000 RTNR PS3 440557 O0 000 00 0 8 I 1 4 68 0000000000 TM~ 983 440557 O0 000 O0 0 8 I 1 4 68 0000000000 RC~!T PS3 CPS 440557 O0 000 O0 0 8 I i 4 68 0000000000 RCFT PS3 CPS 440557 O0 000 O0 0 8 1 1 4 68 0000000000 CMTC PS3 CPS 440557 00 000 00 0 8 1 1 4 68 0000000000 CFTC PS3 CPS 440557 00 000 00 0 8 1 1 4 68 0000000000 G~ PS3 GAPI 440557 00 000 00 0 8 1 1 4 68 0000000000 TENS PS3 LB 440557 O0 000 O0 0 8 ! 1. 4 69 0000000000 CCL PS3 V 440557 00 000 O0 0 @ 1 i 4 68, 0000000000 ** DATA ** DMPT. ~CNT,P$3 GR,,PS3 11727.500 t~PFiI PS3 29 039 RTMR,Po3 4.81.0 TNRA.,PS3 4009 9~5 RC,~?,,PS3 8~3,747 C~.~TC.PS3 3883.210 CFTC,PS3 56'000 TENS PS3 760,000 CCh. PS3 0 000 ,IS Tape verification Listi. nq ichlumberger Alaska Computi.~ Center 5-AUG-i992 15:46 PAGE~ 25 DEPT. 11500.000 NPNI.PS3 RC~!T.PS3 4617.234 RCFT,P83 GR.PS3 35,688 TENS,PS3 DEPT, 11000.000 NPMI,PS3 RCN~ PS3 3866,667 ~CFT,PS3 G~PS3 55.2~1 T~NS.PS3 DEPT, 10969,000 NPHI,PS3 RCNT,PS3 2122.4z~9 ~CFT.PS3 GR.PS3 62.438 TEMS.PS3 ** END OF DATA ** 18.762 RTNR,PS3 1266,5~3 CNTC,PS3 ~800.000 CCh,PS3 18.22B RTNR,PS3 1077,551 CNTC.PS3 1650.000 CCL'PS3 51 587 RTNR.PS3 300!000 CNTC,PS3 I675 000 CCL.PS3 3.747 TNRA,PS3 4478.~05 CFTC,PS3 0,O00 3.333 TNRA,PS3 3791 382 CFTC,PS3 0:000 ' 7 11~ TNRA,PS3 2049:897 CFTC,PS3 0.000 3,586 1245,583 3.514 1006,559 7,506 276,460 **** FIhE TR.AILE~ **** FTLE NA~E : EDIT ,008 SERVICE : FL!C VER. SIO~ : 001A07 D~TE ~ 92108/ 5 ~X REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILF NAME : EDIT .009 SERVICE : FLIC VERSION : 00~..A07 DAT~ : 92/08/ 5 ~X REC SIZE : 1024 FILE TYPE : 130 LAST FILE : FILE HEADER FILM NUMBER 9 RAW CURVES Curves and log header data for each pass i~ separate fi. les; raw background pass ~n last f~le DEPTH INCREMENT: -,5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD 1~, 17 , 0 LOG }'{E,ADER DATA DATE Lr]GGED: STOP DEPTH ~ 0972.5 12-JUL-92 IS Tape Veri~lcatJ. on Listin~ chlumber...qer Alaska Comt}utlnq Center 5-AUG-1992 15:46 PAGE: ¸26 ~OFTWARE VERSION: TI~E LOGGER ON BOTTOM: ?D DRILLER CFT): TO LOGGEP(FT): TOP LOG INTER¥hL (FT): BOTTOM LOG INTERVAL (FT): LCGGING SPEED (FPHR): DEPTH CONTRDL USFD (YES/NO): TOOL STRING (T~P TO BOTTOM) V~NDO~ TO~L CODE TOOL TYP~; CNTD O~PEMSATED NEUTRON CNTD AUXILIARY TELE CART, CNTD COLLAR [.,OCATOR CNTD AUXILIARY TELE ~ODULE $ BOREHOLE ~ND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEP~ LOGGERS CASING DEPTH CP 32.6 13o0 11708.0 11708.o 10980.0 11705.0 180o.0 12-JUL-g2 TOOL NUMBER CI,!C- DA- ! 6 AT'C-CB-l~99 CAL-UB-I.~69 ATM-AA-]74 8 5O BO. REHOLE CONDITIONS FLUID TYP~]: FLUID DE~$SITY (LB/G): SURFACE TEMPERATURE' (DEGF): BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SALINITY {PPM): FL~ID LEVEI..~ (FT)~ FLUID RATE AT WELLHEAD WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS 4 8,0 233.0 ~EI..~TRO N TOOL TOOL TYPE (EPITHERMA[, OR MATRIX: ~ATPIX DENSITY: 2,65 }.{[!bE CO~RKCTION (IN): BLUELiNE COUNT RATE NOR~ALIZATION IN OIL ZONE TOP NO~M.ILIZ!NG WINDOW (FT): BASE N[)R~AL!ZING NINDOW BI,,,UELiNE COUNT R~TE SCALES SET BY FIELD FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT ~ATE HIGH SC:AbE (CPS): 5000 ,, 87 ' NEIR COON.T RATE LOW ..CAI.,E (CPS) 0 NEaR C[)U~T RATE MI~H SCALE (CPS): 22000 Tf]OL STANDOFW (IN): ~E:MA~KS: TIED-IN TO CET DATED 3/2/89 WELL SHUT-IN ~T ~.0:30 O~ 7/12/92 TI4ER{~fAL SAN DSTONE IS Tame Verlficat,lon LJstino chlumber,qer Alaska CommutS. nO Center 5-AUG-1992 15:46 SIWH~= 2050 PSIG 2,5" CMTD RAN OM SANDSTONE M~TPIX APPA~K~4T GOC AT ~352' $ bis FORMAT PAGE: ** DATA FORMAT SPMC!FICATIgN RECORD ** ** SET TYPE: - 64EB ** TYPF; ..EP~ COD V A 1,1...I E 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 ~ 68 0,5 9 65 FT 11 66 ~3 ~3 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 '** SET TYPg - CHAN ** , NAME SERV UNIT SERVICE i~PI APl AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDSi:R ~ bOG TYPE CLASS MOD NUmB SAMP,. EbEM CODg (HEX) DEpT FT 440557 O0 000 O0 0 g ! I 4 68 NPMI PS4 pi,! 440557 O0 000 O0 0 9 I I 4 68 RTNP PS4 44,0557 O0 000 O0 0 9 1, I 4 68 TMRA P$4 4,40557 O0 000 O0 0 9 ~, 1 4 68 ~CMT PS4 CPS 44,0557 O0 000 O0 0 9 ~, 1 4 68 RCF? PS4 CPS 4:40557 O0 000 00 0 9 I 1 4 68 CNTC PS4 CPS 4,40557 O0 000 00 0 9 1 1 4 68 CFTC PS4 CPS 440557 O0 000 O0 0 9 I 1 4 68 G9 PS4 GAPI 4~0557 O0 000 00 0 9 1 1 4 68 T:EN~ PS4 bS 440557 O0 000 O0 0 9 ~. 1 4 68 CCL P$4 V 44:0557 O0 000 ,00 0 9 i 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000. I$ Tape Verificatlor Listi, r~O chlumberqer AlasKa Computin<] Center 5-AUG-1992 15:46 PAGE: 28 DEPT. 11727,000 NPHI.PS4 RCNT,PS4 389B,477 RCFT,PS4 GR,PS4 53.031 TENS,PS4 DEPT. 11500.000 NPMI.PS4 RC~T,PS4 4800,000 ~CFT.P84 GR.P$4 38,531 TENS.PS4 DEPT. 11009.000 I~PHI, PS.i ~!CNT.PS4 444,0 816 ~CFT.PS4 G~.PS4 57;5q4 TENS,PS4 DEPT. 10972,500 NPMI.PS4 ~CNT.PS4 2159.509 RCFT,PS4 G~.PS4 59,906 TENS.PS4 31.092 RTNR,PS4 71.574 CNTC,P$4 g50.O00 CCL.P$4 20.397 RTNR.P$4 1228.346 CNTC,PS4 1690.000 CCL,P$4 1.7.632 RTNR,PS4 1~82.565 CNTC.PS4 1.650.000 CCh,PS4 .46 993 RTNR.PS4 342:$57 CNTC.PS4 1685,000 CCh. PS4 5.053 3775.284 0.000 3.846 4528.399 0,000 3.325 4267.807 0.000 6.381 2109.680 0.000 TNRA.PS4 CFTC.PS~ TNRA,PS4 CFTC.PS~ TNRA.PS4 CFTC.PS4 TNRA,PS4 CFTC.PS4 5,176 729.379 3.806 1193.738 3,434 1186,161 6,980 298,82O ** EMD OF DATA ** **** FIhE TRAILER **** FILE NA~E : EDIT .009 SERVICE : FLIC VERSION : 001A07 DATE : 92/08/ 5 ~AX R~C $IZ~ : !024 FILE TYPE : LO LAST F'II',~E : **** TAPE TRAILER **** SERVICE NA~E : EDIT DAT~. : 92/0~/ 5 O~I~IN : FLIC T,~P~: NA~E : 92424 CONTINUATION # EVIOUS TAPE O~ENT " : BP EXPLORATION,PRUDHOf' BAY,Z-25,500292190~O0 **** REEL TRAILER **** SERVICE N~E : EDIT DATE : 92/08/ 5 ORIGIN : FbIC REEL NA~E : 92424 CONTI~,}'UA, TION ~ : CO~4~ENT : BP EXPi,.,(~3RATION,PRUD'i!OE 'f~hY,Z-25,500292190200 ~.~ ~.~~~~~ ~LASKA COMPUTING SCHL'UMBERGER CDMPANY NAME :~ BP EXPLORATION WEL:L NAME : Z.-25 Cl1-1'7-11-12) FIELD NAME : PRUDHOE BAY STATE : ,~LASKA !BOROUGH : NORTH SLOPE API NUMBER : 50-029-2'[902-00 REFERENCE NO : 73156 IS~ TAPE' VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER , , 1-MAR-1989 16:01 ~ REEL HEADER SERVICE NAME : EDIT DATE : 89/03/ 1 ORIGIN : FLIC REEL NAME : 73156 CONTINUATION ~ PREVIOUS REEL COMMENT : BP EXPLORATION Z-25 (11-17-11-12), API ~50-029-21902 PAGE: ~ TAPE HEADER ~ SERVICE NAME : EDIT DATE : 89/03/ 1 ORIGIN : FLIC TAPE NAME : 73156 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : )P EXPLORATION Z-25 (11-17-11-12), API #50-029-21902 · ~** FILE HEADER ~* FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01AOZ DATE : 89/03/ 1 MAX RE'C SIZE : 1096 FI'LE 'TYPE : LO LAST FILE : · ~ SCHLUMBERGER WELL SERVICES ¢~ COMPANY NAME: BP EXPLORATION WE'LL: Z-Z5 Cl1-17-11-12) FIELD: PRUOHOE BAY BOROUGH: NORTH SLOPE STATE: ALASKA API NUMBER: 50-029-21902-00 LOCATION: 7Zl' SNL & 3143' WEt SECTION: 19 TOWNSHIP: llN RANGE: 12E PERMANENT DATUM: MSL ELEVATION: '0., TAPE' VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER , 1-MAR-1959 16:01 LOG MEASURED FROM RKB 91o5 ABOVE PERMANENT DATUM ELEVATIONS KB: 91-5 DF: 9!.5 GL: 54.1 DATE LOGGED= RUN NUMBER: TD DRILLER: TO LOGGER: 24-FEB-89 ONE 11800. 11804. CASING 1: 9 5/8" @ DRILLER DEPTH OF 10986 AND LOGGER DEPTH OF 10990 BIT SIZE 1: 8 1/2# @ 11800. lYPE FLUID IN HOLE: DISPERSED DENSITY: PH: VISCOSITY: 39. MUD RESISTI¥IT¥: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY:' 3.74 @ 62. 3.63 @ 60. 2.98 @ 63. TIME CIRCUL.~TION ENDED: 10:00 24-FEB TIME LOGGER ON BOTTOM: 16:30 24-FEB MAXIMUM TEMP RECORDED:' 204 LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: PRUDHOE BAY TINKHAM WHITE/CUNNINGHAM/HABERTHUR TOOL NUMBERS: DIS 1096 SGC 2471 SLC 149 NLM 1338 OIL 1422 SLS Z001 IBM 1347 SLM 1552 FIELD REMARKS: SEVEN RUBBER FIN STANDOFFS & HOLE FI'NOER USED ON TOOL. SONIC DOWNHOLE GAIN = SP NOISEY ON MAIN P~SS BETWEEN 11605' - 11525' GR CURVE FROM MAIN PASS ALSO US'ED 'FOR REPEAT PiSS AS GR RESPONS'E WAS ~TTENUATED FOLLOWING F'I~LE ~5. 2 DITD BEFORE CALS PRESENTED TO ACCOUNT FOR SHIFT IN ILO. MEAS. PLUS VALUE BETWEEN MAIN AND REPEAT PASSES. AFTER CAL REFLECTS LATTER BEFORE CAL (.24-FEB-89 1.6:30). SP SHIFT @ 11702". PAGE: DATE JOB STARTED: 01-MAR-SD JOB REFERENCE NO: 73156 LOP/AMA: J. KDHRING COMPUTING CENTER REMARKS: MS~L DEPTH :CORRECTED TO MATCH SFLU. gI:L LOG AND REPEAT FILMS REMADE IN COMPUTING CENTER. THE FIELD MEASURED V~LUES 'DF CALS FROM THE MSFL ARE AROUND 2.6". 'THEREFORE, CALS ON THE BLUEL'INE OF THE MSFL PASS IS ACTU~LLY DISPLAYED IS' TAPE' VSR'IFIC~TION LISTING CHLUM,~ERGER ALASKA COMPUTING CENTER 1-MA~-1959 16:01 PAGE: WITH ~ BACKUP SCALE DF -3" TO 7", AND NOT 7" TO 17". THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS FILE (EDIT.O01): <SEE FILE EDI'T.OO2 FOR 2" SAMPLED MSFL DATA> DUAL INDUCTION SPHERICALLY FOCUSED LOG (.OIL) FIRST TO LAST READING: 11796' TO 10990' ,~OREHOLE CDMPENSATED LOG (.BHC) FIRST TO LAST READING: 11760' TO 10'990' LITHO-DENSI'TY COMPENSATEO LOG (.LOT) FIRST TO LAST RE~DYNG: 11765' TO 10990' COMPENSATED NEUTRON LOG (oCNL) FIRST TO LAST REAOING: 11778' TO 10,990' NEUTRON ~ND GAMMA RAY IN C~SING (.CHL) FIRST TO LAST READING' 11001' TO 7750' TABLE TYPE : CONS CN PN WN NATI S TAT CDUN SECT TOWN R A NG FL E NGI SON APIN TUNI VALU B'P EXPLORATION PRUOHOE' BAY Z-25 (11,-'17-1'I-12) US.~ ALASKA NORTH SLOPE 19 721' SNL & ~4~' WEL TIN,HAM 5.¢8.¢1Z 50-029-21902 O0 D E F I 'COMPANY 'NAME F I ~'_" L 0 N~ME WELL NAME N.AT I 0 N STATE OR PRO'VINC~ COUNTY SECTION TOWNSHIP RANGE FIE:LO LOCATION ENGINEER'S NAME SERVICE OROER NUMBER API SERIAL NUMSER TABLE TYPE : CURV DEFY DEPT TENS DEPTH CH,~NNEL NAME 'TE NS ION IS' TAPE VERIFICATION LISTING CHLUM~ERGER ALASKA COMPUTING CENTER 1-MAR-19~9 16:01 PAGE: SFLU ILM ILO SP GR TENS DT GR TENS NPHI TNRA RTNR RCFT RCNT CFTC CNTC MRES MTEM HTEN GR TENS DPHI DRHO RHOB PEF QLS QSS LS LU LL LITH SS1 SS2 LSHV SSH¥ S1RH LSRH LURH CALI AZIM D E V I RB PIAZ MRES MTEM HTEN GR TENS NPHI TNRA RTNR RCFT RCNT DEFI SFL UNAVERAGED IL-MEDIUM RESISTIVITY IL-DEEP RESISTIVITY SPONTANEOUS POTENTIAL GAMMA RAY TENSION DELTA-T GAMMA RAY TENSION NEUTRON POROSITY CALIBRATED THERMAL NEUTRON R~TIO RAW THERMAL NEUTRON RATIO RCFT RCNT CFTC CNTC MUD RESISTIVITY MUD TEMPERATURE HEAD TENSION ,GAMMA RAY 'TENSION DENSIT'¥ POROSITY DELTA RHO ~ULK DSNSI'TY PHOTO-ELECTRIC FACTOR QUALITY CONTROL OF LONG SPACING FOR LOT QUALITY CONTROL ON SHORT SPACING FOR LOT LONG SPACING COMPUTED COUNT RA'TE (LL~LU,/2) LONG UPPER 1-2 WINOO'W COUNT RATE (LUI+LU2) LONG LOWER WINDOW COUNT RATE LITHOLOG WINDOW COUNT RATE SHORT SPACING 1 WINDOW COUNT RAT5 SHORT :SPACING Z WINDOW COUNT RATE LONG SPACING HIGH VOLTAGE OUTPUT SHORT SPACING HIGH VOLTAGE LOOP OUTPUT SHORT SPACING 1 DENSITY LONG SPACING RHOB (UNCORRECTED) LONG UPPER RHO~ CALI~ER AZIMUTH OF HOLE DRIFT OEVI ATIO'N RELA'TIVE BEARING PAO I AZIMUTH MUD RESISTIVITY MUD TEMPERATURE HEAD T~NSIgN GAMMA RAY TENSION NEUTRON POROSITY CALIB'RATEO THERMAL NEUTRON R~TIO ~ A W T IH 'E R M A L N E U T R 0 'N R A T I O RC FT RCNT IS' TAPE VERIFICATION LISTING CHLUMBERGER RLASRA COMPUTING CENTER CFTC CNTC MRES MTEM HTEN GR TENS AZIM DEVI RB PIAZ MRES MTEM HTEN CALS GR D'EFI CFTC CNTC MUO RESISTIVITY MUD TEMPERATURE HEAD TENSION GAMMA RAY TENSION AZIMUTH OF HOLE DRIFT DEVIATION RELATIVE BEARING PAD 1 AZIMUTH MUD RESISTIVITY MUD TEMPERATURE HEAD TENSION SONIC CALIPER GAMMA RAY 1-MAR-1989 1,6:' 01 PAGE: DATA FORMAT SPECIFICATION RECORD ~.t. SET TYPE - 64EB ~ TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 284 4 66 5 66 6 73 ? 65 8 68 0.5 9 65 FT 11 66 3 1~ 6B 1'3 66 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE- CHAN ** NAME SERV UNIT SERVICE APl API API AP1 FILE NUMB NUMB SIZE REPR I!O ORDER ~ LOG TYPE CLASS MOO NUMB SAMP ELEM CODE DEPT FT 548412 O0 000 O0 0 1 1 I 4 68 TENS OIL LB 548412 O0 000 OO 0 I 1 I 4 68 SFLU OIL OHMM 548412 O0 OOO O0 0 1 1 1 4 6B PROCESS CHEX) 0000000000 O00OO00000 0000000000 .IS' TAPE' VERIFICATION LISTING iCHLUM,~ERGER ALASKA COMPUTING CENTER 1-MAR-1989 16:01 PAGE: NAME SERV UNIT SERVICE API API API ~P! FILE NUM9 NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MO0 NUMB SAMP ELEM CODE (HEX) ILM OIL OHMM 548412 O0 ILO OIL DHMM 548412 O0 SP OIL MY 548412 O0 GR OIL G~PI 548412 O0 TENS BHC L~ 548412 O0 DT ~HC US/F 54~4t2 O0 GR BHC G~PI 548412 O0 TENS CNL LB 548412 OD NPHI CNL PU 548412 O0 TNRA CNL 548412 O0 RTNR CNL 548412 O0 RCFT CNL CPS 548412 O0 RCNT CNL CPS 548412 O0 CFTC CNL CPS 548412 O0 CNTC CNL CPS 54~412 O0 MRES CNL OHMM 548412 O0 MTEM CNL DEGF 548412 O0 HTEN CNL Lfl 548412 O0 GR CNL G~PI 5484.12 O0 TENS LDT LB :548412 O0 DPHI EDT PU 548412 O0 DRHO LDT G/C3 548412 O0 RHOB LDT G/C3 548412 O0 PEF LOT 548412 O0 QLS LDT 548412 O0 USS LOT 548412 O0 LS LOT CPS 548412 O0 tg LOT CPS 548412 OO LL LOT CPS 548412 O0 LITH LDT CPS 54841Z O0 SS1 LOT CPS 548412 O0 S52 LOT CPS 548412 O0 LSHV LDT V 54841Z O0 S,SHV LOT V 548412 O0 S1RH LOT G/C3 548412 O0 LSRH LOT G/C3 548412 O0 LURH LOT G,/C3 548412 OO CALI LD'T IN 548412 O0 AZIM LDT DEG 548412 O0 DEVI LOT DEG 545412 O0 R'B LD'T DEG 548412 O0 P1AZ LDT OEG 548412 O0 MRES LOT OHMM 548412 O0 MTEM LDT DEGF 548412 O0 HTEN LOT LB 548412 O0 GR LDT GAPI 548412 O0 TENS CHL L~ 548412 O0 NPHI CHL PU 548412 O0 TNRA CHL 548412 OO RTNR CHL 548412 O0 RCFT CHL CPS 548412 O0 000 0.0 0 1 I I 4 68 0000000000 000 O0 0 I I 1 4 68 O000OO0000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 1 1 1 4 68 DO00000000 000 O0 0 1 1 1 4 68 OOOO000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 I I 1 4 68 0000000000 000 O0 0 1 1 1 4 68 O0000000OO DO0 OO 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 ,4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I I I '4 68 0000000000 000 O0 0 1 1 1 4 68 DO00000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I I 1 4 68 O000OO0000 000 O0 0 I I I 4 68 0000000000 000 O0 0 I I I 4 68 OOOO000000 000 O0 0 1 1 1 4 68 00'00000000 000 O0 0 1 I I 4 68 0000000000 OOO O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 O00000OO00 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 '1 1 4 6,8 O000000OO0 000 O0 0 I 1 1 4 68 O0000000OO 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 O00000OOOO 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 1 1 1 ,4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 OO 0 1 1 1 4 68 0000000000 OOO O0 0 1 1 I 4 68 O0000000OO 000 O0 0 I 1 1 4 68 0000000000 000 O0 0 1 1 1 4 68 0000'000000 000 0'0 0 I 1 1 4 68 0000000000 O00 O0 0 1 1 I 4 68 O0000000OO 000 OO 0 1 1 I 4 68 0000000000, 000 O0 0 I 1 1 4 68 O000000OO0 000 O0 0 I I I 4 68 0000000000 009 O0 0 1 I 1 4 68 0000000000 000 O0 0 1 1 I 4 68 0000000000 000 O0 0 1 1 1 4 68 0000000000 000 O0 0 I 1 I 4 68 OOOO000OO0 000 O0 0 1 1 1 ,4 68 0000000000 000 O0 0 1 1 1 4 68 OOOOOOOO00 IS' TAPE' VERIFICATION LISTING CHLUMBERGER ~LASKA COMPUTING CENTER , 1-MAR-1989 16:01 NAME SERV UNIT SERVICE API ~PI AOI ID ORDER e LOG TYPE CLASS RCNT CHL CPS 548412 O0 000 O0 CFTC CHL CPS 548412 O0 000 00 CNTC CHL CPS 548412 O0 000 O0 MRES CHL OHMM 548412 O0 000 O0 MTEM CML OEGF 543412 O0 000 O0 HTEN CHL LB 548412 O0 000 O0 GR CHL GAPI 548412 O0 000 O0 TENS MSF LB 548412 O0 000 O0 AZIM MSF BEG 548412 00 000 O0 DSVI MSF DEG 548412 O0 000 O0 RB MSF OEG 548412 O0 000 O0 P1AZ MSF DEG 548412 O0 000 OO MRES MSF OHMM 548412 O0 000 O0 MTEM MSF DEGF 548412 O0 000 O0 HTEN MSF LB 548412 O0 000 00 Cats MSF IN 548412 O0 000 O0 GR MSF GAPI 548412 O0 000 OO aPI FILE MOO NUMB NUMB NUMB SAMP ELEM SIZE 4 4 4 4 .4 4 4 4 4 0 1 I 1 0 1 1 1 0 1 1 1 0 1 1 1 0 1 1 1 0 1 1 1 0 1 1 1 0 1 1 1 0 1 1 1 0 1 1 1 Q 1 1 1 0 1 1 1 0 1 1 1 0 I I 1 0 I I 1 0 1 1 1 0 1 I I REPR PRDCES CODE (HEX) 68 0000000 68 0000000 68 0000000 63 0000009 68 0000000 68 OOOO000 68 0000000 68 0000000 68 0000000 68 0000000 68 0000000 68 O00000D 68 0000000 68 0000000 68 0000000 68 0000000 68 0000000 S 000 000 000 OOO 000 000 000 000 000 000 000 000 000 000 000 000 000 PAGE: ** DATA DEPT. 11837.500 TENS.OIL ILO.OIL -999.250 SP.DIL D'T.BHC -999.250 GR.BHC TNRA.CNL 2.1'30 RTNR.CNL CFTC.CNL Z069.739 CNTC.CNL HTEN.CNL 138.2 50 GR,. CNL DRHO.LDT 0.066 RHOB.LDT QSS,LDT 0.146 tS,LOT LITH.LDT 38.406 SS1.LDT SSHV.LDT 13,47.000 S1RH.LOT CA~LI.LDT Z.887 AZ!M.LDT P1AZ.LDT 221.675 MRES.LDT GR.LDT 39.938 TENS.CHL RTNR.CHL -999.250 RCFT.CHL CNTC.CHL -999.250 MRES.CHL GR.CHL -999.250 TENS.MSF RB.MSF -999.250 P1AZ,MSF HTEN. MSF -999.250 C~LS.MSF -999,250 -999,250 -999,250 2.26,0 4375, 222 39.9 3:8 Z. 416 300.250 Z25.875 Z,.ZO1 41.924 0.960 -999.250 -999.250 -999.,2!50 -999.Z50 -999.250 -999.250 DEPT. 11800.000 TENS.DI'L 6432.000 ILO.OIL 2.474 SP.DIL -103.313 DT.BHC 70.813 GR.BHC 35.063 TNRA.CNL 2.091 RTNR.CNL 2.297 CFTC.CNL Z107.226 CNTC.CNL 4404.782 H'TEN.CN~L 891.000 GR.CNL 35.719 DRHO.LDT 0.059 RHOB.LgT 2.406 QSS,LDT O,11B tS,LOT 301.250 LITH.LDT 37.000 SSI.LDT 224.375 SSHV.LDT 13,48.000 S1RH.LDT 2,209 SFLU.DIL GR.DIL TENS.CNL RCFT.CNL MRES.CNL 'TENS.LOT PEF.LDT LU.LDT SS2,LDT LSRH,LDT DEVI,,LDT MT~M,LDT NPHI,CHL RCNT,CHL MTEMoCHL AZIM.MSP MRESoMSF GR.MSF SFLU.DIL GR.D, IL TENS.CNL RCFT.CNL MRES.CNL TENS .LOT PEF.LDT LU.LDT SS2.LOT LS~H.LDT -99 9. Z 50 -999. Z 50 2.47 0.0 O0 1978.176 0.960 247 O. 000 6.375 ,Z 92. ,25 O 27 5.000 2,350 37.932 208.500 -999.250 --99 9.250 -999.25'0 --999.250 - 99 9.250 -999.250 5,387 35,063 5'91 Z, 000 2053,542 0,9.60 591 Z, 000 21,031 288.75 O 283.000 Z, ;346 'ILM. OIL TENS.BHC NPHI.CNL RCNT .CNL MTEM.CNL DPHI.LDT QLS .LDT LL. LO T LSHV.LDT LURH.LDT RB .:LOT HTEN.LDT TNR~.CME CFTC. CHL HTEN.CHL DEVI.MSF MTEMoMSF ILM.DIL TENS.BHC ~ NPHI.CNL R~CNT. CNL MTEM.CNL DPHI.LDT qLS .,LDT LL .LDT LSHV.LDT LURH,LD'T -999.250 -999.250 26.149 4560.365 208.500 ,14.18,4 -0.045 154.000 1472.000 2.367 1'79.804 '138.250 -999.Z50 -999.250 138.250 -999.250 -999.250 ,2.2,14 6,432.000 25.56,6 4597.761 208,500 14.792: -0.023 156.750 14'73.000 2.375 IS' TAPE VERIFICATION LISTING CHLUM,BERGER AL~SK~ COMPUTING CENTER CALI.LDT Z.BB7 AZIM.LgT PIAZ.LOT 222.191 MRES.LDT GR.LDT 35.719 TENS.CML RTNR.CHL -999.250 RCFT.CHL CNTC.CHL -999.250 MRES.CHL GR.CHL -999.250 TENS.MSF RB.MSF -999.250 PIlZ.MSF HTEN.MSF -999.250 C~LS.MSF DEPT. 11700.000 TENS.DIE ILO.DIE 1.731 SP.DIL DT.BHC B4.563 GR.BHC TNRA.CNL 2.359 RTNR. CNL CFTC.CNL 1684.094 CNTC.CNL HTEN.CNL 1070.750 GR.CNL DRHO.LDT 0.001 RHOB.LOT QSS.LDT 0.019 tS.LOT LITH.LDT 95.938 SS1.LOT SSHV.LDT 134'9.000 S1RH.LDT CALI.LDT 8.414 ~ZIM.LgT PIAZ.LDT 230.250 MRES.LDT GRoLDT 21.609 TENS.CML R'TNR.CHL -999.250 RCFT.CHL CNTC.CHL -999.250 MRES.CHL GR.CHL -999.250 TENS.MSF RBoMSF -9'99.250 PI,~Z.MSF HTEN.MSF -999.250 CALS.MSF DEP'T. 1,1600o000 TENS.DIE ILO.OIL 3.003 SP.DIL DT.SHC 76.813 GR.BHC TNRA.CNL 2.187 RTNR.CNL CFTC.CNL 1951.500 CN'TC.CNL HTEN.CNL 978.500 GR.CNL DRHO.LDT 0.004 RHOB.LDT QSS.LD'T 0.005 aS.LOT LITH.LOT 69.500 SS1.LDT SSHV.LDT 1351.000 S1RH.LDT CALI.LDT 8.414 ~ZIM.LDT PiAZ.LDT 234.245 MRES.LOT GR.LDT 16.438 TENS.CHL RTNR.CHL -999.250 RCFT.CHL CNTC.CHL -999.250 IMRESoCHL GR.CHL -999.250 TENS.MSF RS.MSF 154.514 PlAZ.MSF H'TEN.MSF 1153.000 CALS.MSF DEPT. 11500.000 TENS,.DIL ILO.DIE 12.99Z SP.DIL DT.BHC 77,500 GR.BHC TNRA.CNL 1.916 RTNR.'CNL CFTC.CNL 2391.709 CNTC.CNL HTEN.CNL 9Z9,.OOO GR.CNL DRHO.LDT 0.010 RHOB.LDT QSS.LDT 0.024 tS.LOT 1-M~R.-.19~9 16:,D1 42.094 DEVI.LDT 0.960 MTEM.LDT -999.250 NPHI.CHL -999.250 RCNT.CHL -999.250 MTEM.CHL -999.250 AZIM.MSF -999.250 MRES.MSE -999.250 GR.MSF 6412.000 SFLU.DIL -82.500 GR.DIL 18.250 TENS.CNL 2.539 RCFT.CNL 3939.888 MRES.CNL 21.609 TENS.EDT 2.337 PEF.LDT 324.000 LU.LDT 205.375 SS2.LDT 2.334 LSRH.LDT 43.171 DEVI.LDT 0.956 MTEM.LOT -999.250 NPHI.C'HL -999.250 RCNT.CHL -999.250 MTEM.CHL -999.250 AZIM.MSF -999.250 MRES.MSF -999.250 GR.HSF 6144.000 SFLU.DIL -123.250 GR.DIL 19.109 'TENS.CNL 2.220 RCFT.CNL 4196.'972 MRES.CNL 16.,438 TENS.LOT 2.457 PEF.LDT 264.250 LU.LOT 200.375 SS2.LDT 2.436 LSRH.LOT 43.B96 DEVI.LDT 0.952 MTEM,.LOT -999.250 NPHI.CHL -999.250 RCNT.CHL -999.250 MTEM.CH'L 6124.000 AZIM.MSF 1230.287 MRES.MSF 2.61'7 GR.MSF 6104.000 SFLU.DIL -87.500 GR.DIL 15.867 TENS.CNL 2.058 RCFT.CNL 4576.517 MRES.CNL 16.969 TENS.LOT 2.395 PEF.LDT 299.750 LU.LDT 37.851 208.500 -999.250 -999.250 -999.250 -999.250 -999.25D -999.250 4.460 18.250 6164.000 1612.826 0.956 6164.000 3.023 303.500 297.250 ,2.336 38.534 Z10.875 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 5.932 1 9. 109 5'792. 000 1833.174 ,0.952 5792.000 3.010 251.1;!,5 2 B 8.750 2.4 5 3 39.31.4 21 ,Z. Z 5:0 -999.250 -999.250 -999.250 44.4,6,4 0.868 1 7.625 15.431 15.867 568O.0O0 2,306.928 0.958 5680.000 2.898 280.000 RB.LDT HTEN.LDT TNR&.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT EL.LOT LSHV.LDT LURH.LDT RS.EDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEV[.MSF MTEM.MSF I'LM. OIL TENS.BHC NPHI.CNL RCNT.CNL MTEMo CNL DPHI.LDT QLSoLDT L:L. L D T LS HV. LDT LURHoLDT R B. L D T HTEN.LDT TNRA,.CHL CFTC .CHL HTEN.CHL DEV I. MSF MTEM.MSF ILM.DIL T E N S. B H C NPHI. CNL RCNT.CNL MTEM.CNL DPHI .LOT QtS .LOT Lt. LDT P/~GE: 180.076 891.000 -999.250 -999.250 891.000 -9'99.250 -999.250 1.832 6412.000 24.403 3986.835 210.875 18.965 0.003 171.250 1475.000 2.344 185.548 1070.750 -999.250 .-999.250 1070.7'50 -999.250 -999.250 3.141 614,4.000 21.820 4335.791 212.2:50 11.671 0.008 138.625 1476.0'00 2.4,65, 188.042 978.500 -999.250 -9'99.250 978.500 39.2.62 Z04.625 12.61'9 61,04.000 17.710 4801.851 210.875 15.443 O.O17 159.750 IS' TAPE VERIFICATION 'LISTINS CHLUMBERSER ALASKA COMPUTINS CENTER L ITH. LOT 97. 438 S S1 .LOT $ SHV.LDT 1351o 000 S1 RH. LOT C ALI. LOT 8.4 53 AZ IM. LOT PI~Z.LDT 236. 140 MR E'S.LDT GR.LDT 16.969 TENS.CHL RTNR.CHL -999. 250 RCFT. CHL CNTC. CHL -999. 250 MRES. CHL GR.CML -999.250 TENS.MSF RB. MSF I 83 o 806 Pl AZ. MSF HTEN.MSF 1Z45. 000 C~LS.MSF DEPT. 11400.000 TENS.OIL ILD.DIL 17.059 SP.DIL DT.BHC 84.063 GR.BHC TNRA.CNL 2.ZlO RTNR.CNL CFTC.CNL 1655.988 CNTC.CNL HTEN.CNL 997. go0 GR.CNL DRHO.LDT O. 008 RHaB.LOT QSS.LDT 0.029 LS.LOT LITH.LDT 85. 375 SS1.LOT SSHV. LOT 11352. 000 S1 RH. LOT CALI.LDT 8.547 AZIM.LDT P1AZ.LDT Z35.068 MRES.LDT GR.LDT ZO. 203 TENS.CHL R'TNR.CHL -999. 250 RCFT.CHL CNTC.CHL -999.250 MRES.CHL GR.CHL -999.250 TENS.MSF RS.MSF 178.'353 PIAZ.MSF HTEN.MS~ 1311.000 CALS.MSF DEPT. 11300.0'00 TENS.OIL ILO.OIL 47.784 SP.DIL DT.SHC 88. 000 GR. BHC TNRA.CNL 2. 261 RTNR. CNL CFTC.CNL 1727.281 CNTC.CNL HTEN.CNL 972.5 O0 GR. CNL DRHO.LDT -0.004 RHOB.LOT QSS.LDT 0.018 LS. LOT LITH.LD'T 107.188 SS1.LDT SSHV.LDT 1351.000 SIRH.LDT CALI.LD'T 8.547 ~ZIM.LOT P1AZ.LDT 236.771 MRESoLDT GR.LDT 20.734 TENS.CHL RTNR.CHL -999.250 RCFT.CHL CNTC,CHL .-999.250 MRES.CML GR.CHL -999.250 TENS.MSF RB.MSF 193.417 PIAZ.MSF HTEN.MSF 12,49.000 CALS.MSF DEPT. 11200.000 TENS.DIL ILO.OIL 14.302 SP.DIL DT.BHC 79.563 GR.BHC TNRA.CNL 1.720 RTNR.CNL CFTC.CNL 235.4.7,47 CNTC.CNL HTEN.CNL 1127.000 GR.CNL 1-MAR-1989 16:01 207.750 SS2.LOT 2.344 LSRH.LDT 45.372 DEVI.LDT 0.958 MTEM.LDT -999.250 NPHI.CHL -999.250 RCNT.CHL -999.250 MTEM.CHL 6,292.000 AZIM.MSF 231.000 MRES.MSF 2.617 GR.MSF 6128.000 SFLU.DIL -76.$00 GR.DIL 19.Z34 TENS.CNL 2.306 RCFT.CNL 3789.115 MRES.CNL 20.203 TENS.LDT 2.381 PEF.LOT 303.500 LU.LDT 207.500 SS2.LDT 2.340 LSRH.LDT 46.314 DEVI.LDT 0.967 MTEM.L~T -999.250 NPHI.CHL -999.250 RCNT.CHL -999.250 MTEM.,CHL 6368.000 AZIM.MSF Z2,4.156 MRES.MSF 2.621 GR.MSF 5944.000 SFLU.DIL -9,4.250 GR.DIL 17.344 'TENS.CNL 2.430 RCFT.CNL 3897.579 :MRES.CNL 20.7'34 TENS.LDT 2.251 PEF. LDT ~5~.500 LU.LDT 205.500 SSZ.LDT ,Z.303 L:SRH.LDT 4'7.324 DEVI.LDT 0.971 MTEMo'LDT -999.250 NPHI.,CHL -999.25'0 RCNT.CHL -'999.250 MTEM.CHL 6128.000 AZIM.MSF 232.049 MRES.MSF 2o621 GR.MSF 6104.000 SFLU.DIL -3'7.500 GR.DIL 63.969 TENS.CNL 1.700 RCFToCNL 3720.449 MRE,S.CNL 57.531 TENS.LOT 295.250 2.385 40.709 210.875 -999.250 -999.250 -999.250 45.989 0.881 19.984 26.19:3 19.234 5708.000 1585.464 0.967 5708.000 2.963 281.500 293.750 2.3'73 41.100 208.875 -999.250 '- 999.250 -999.250 46. 341 0.901 22.266 50.213 1 7.344 55,5 ,Z. 000 1658.340 0.971 555 Z. 000 :3. 254 3 Z 7. l' '50 30 O. 500 2.285 41.588 206.375 -999.250 -999.250 ,-999.250 47.487 0.908 21.125 12.663 63.969 5928.000 2382.5'66 0.983 5928.000 LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI. CNL RCNT .CNL MTEM.CNL DPHI.LDT QLS.LDT LL. LgT LSHV.LDT LURH.LDT RB.LDT HTEN oLDT TNRA.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF I:LM. DIL TENS.BHC NPHI.CNL RCNT .CNL MTEM.CNL DPHI. LOT QLS .LDT LL .EDT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNRA.CHL CFTC. CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI.C'NL RCN'T.CNL MTEM.CNL D~HI.LDT PA,SE: 1418.000 2.395 188.203 929.000 -999.250 -999.250 929.000 40.642 204.250 14.120 6128.000 Zl.990 4023.451 208.875 16.289 0.026 162.625 1479.000 2.3'91 186.619 997.000 -999.250 -999.250 997.000 41.101 202.125 36.989 5944.000 ZZ.764 4009.049 206'3'75 22.356 O.OlZ 190.500 '1479.000 2.297 187.094 972.500 --999.250 -999.250 972.500 41.551 199.875 13.4,66 6104'000 14.311 3679.855 204.000 8.556 ,IS TAPE VERIEIC~TION LISTING ,CHLUMBERGER ~LASK~ COMPUTING CENTER DRHD.LDT 0.004 RHDB.LDT QSS.LDT 0.014 LS.LDT LITH.LDT 67.563 SS1.LDT SSHV.LDT 1351.000 S1RH.LDT CALI.LDT 8,828 AZIM,LDT PlAZ.LDT 230.706 MRES,LDT GR,LDT 57.531 TENS,CHL RTNR.CHL -999.250 RCFT.CHL CNTC.CHL -999.250 MRES.CHL GR,CHL -999,250 TENS.MSF RB,MSF 180.914 PI~Z,MSF HTEN.MSF 1379.750 CALS.MSF DEPT. 11100.000 TENSoDIL ILD,DIL 10,240 SP,DIL DT.BHC 86.313 GR,BHC TNR~.CNL 2.140 RTNR.CNL CFTC.CNL 1585.353 CNTC.CNL HTEN.CNL 1037.125 GR.CNL ORHg. LOT 0.026 RHgB.LOT QSS.LDT 0.039 ES.LOT LITH.LDT 51. 219 S SI. LOT SSHV,LDT 1350.000 S1RH,LDT C&LI,LDT 9,5.Z3 ~ZIM,LDT P1AZ.LDT 239.209 MRES.LOT GR.LDT 97.625 TENS.CHL RTNR.CHL -9'99.250 RCFT.CHL CNTC,CHL -999.250 MRES,CHL GRoCHL -999.250 TENS.MSF RB,MSF 178.894 P1AZ,MSF HTEN,MSP 1371,500 CALS,MSF OEP'To 11000.000 TENS.OIL ILO.OIL 8.545 SP.DIL DT,SHC 81.938 GR,BHC TNRA.CNL 1.7,24 RTNR.CNL C'FTC.CNL 25.40.755 CNTC.CNL HTEN.CNL 1059.000 GR.CNL DRHO.:LDT O.OOT RHOB.LOT QSS.LDT 0.017 LS.LDT L I T H. L D T .67.813 $ S 1. 'L D'T SSHV,LDT 1350.000 S1RH,LDT CALI.LDT 9.383 ~ZIM.LDT PIAZ.LDT 221.749 MRES,LDT GR,LDT 84,063 TENS.CHL RTNR.CHL 1.737 RCFT.CHL CNTC,.CHL ,4053.155 MRES.CHL GR.CHL 108.500 TENS.MSF RB.MSF 179.8,45 P1AZ.MSF HTEN.;MS~ 13,40.750 CALS.MSF 1.-MAR-19$9 16:01 2.508 PEF.LDT Z44.000 LU.LDT 197.250 SSZ.LDT 2.488 LSRH.LDT 4B.297 DEVI.LDT O. 983 MTEM.LDT -999.250 NPHI.CHL -999.250 RCNT.CHL -999.250 MTEM.CHL 6420.000 AZIMoMSE 229.377 MRES.MSF 2.621 GR.MSF 6332,90'0 SFLU,DIL -30.500 GR.DIL 71.063 TENS,CNL 2.10,4 RCFT.CNL 3370.195 MRES.CNL 97.625 TENS.LOT Z. 548 PEF.LOT 233.875 LU.LDT 204.625 SSZ.LDT 2.443 LSRH.LDT 47.899 DEVI.LOT 0.991 MT'EM.LOT -999.250 NPHI.CHL -999.250 RCNT.CHL -999.250 MTEM.CHL 6332.000 AZIM.MSF 226.325 MRES.MSF 2.621 GR.M'SF 5804,000 SFLU,DIL -38,000 GR,DIL 59.594 'TENS,CNL 1.806 RCFToCNL 4379.463 MRES.CNL 8,4.063 TENS.EOT 2.523 PEF.LDT 23'9,625 LU.LOT 198.250 SS2.LDT 2,486 LSRH.LDT 44.276 DEVI.LOT 1.001 MTEM.LOT 628~,000 NPHI.CHL 2173.315 RCNT.CHL 0.'95'9 MTEM.CHL 6228,D00 .~ZIM,MSF 224.007 MRES.MSF 2.586 GR..MSF 2.645 231.500 277.750 2.504 42.229 204.000 -999.250 -999.250 -999.250 48.143 0.929 83.063 11.124 71.063 5640.000 1687.416 0.991 5640.000 4.906 22 9. 500 277.000 2.521 43.079 200,.:625 -999.250 -999.250 -999.250 47.839 0.941 97.313 19.357 5'9.594 5800.000 2469.676 '1.00I 5800.000 3.039 23~0.375 2'77.250 Z, 516 4,3. 136 197.250 11.796 4189.320 18,6.500 44.21'9 0.958 82,063 QLS.LDT EL.LOT LSHV.LD'T LURH.LDT RB.LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM,DIL TENS,BHC NPHI,CNL RCN'T ,CNL MTEM,CNL DPHI ,LDT QLS, LDT LL .LDT LSHV.LDT LURH,LD'T R~B,LDT HTEN.LDT TNRA.CHL CFTC.CHL HTENo CHL OEVI,.MSF M T E M. M $ F ILM,DIL TENS,BHC NPHI,CNL RCNT,CNL MTEM,CNL DPHI,LD'T QLS,LDT LL,LDT LSHV,LDT LURH,LDT RB,LDT HTEN.LDT TNR~,CHL C~TC,CHL HTEN.CHL DEV'I.MSF MTEM.MSF DEPT. 10900.000 TENS,.DIL -999,.250 SFLU.DIL -999.250 ILM.DIL ILD.DIL -999.250 SP.DIL -999.250 GR.DIL -999.250 TENS,.BHC DT.~HC -999.250 GR.BHC -999.250 'TENS.CN'L -999.250 NPHI.CNL TNRA.CNL -999.250 RTNR.CNL -999.250 RC~T.CNL -999.250 RCNT.CNL PAGE: 10 0.023 128.125 1480.000 2.520 181,7B4 1127,000 -999.250 -999.250 1127,000 ~2.252 197,875 9.663 6332. 000 19.753 3Z33.30B 200.625 6.196 -0,024 119.125 1481,000 2.525 188.311 1037.125 -999.250 -999.250 1037.125 ~3.106 1'95.000 9.028 5804.000 13.696 4811.076 197.250 7.670 0.005 124..43B 1478.000 2.521 178,156 1059.000 1.89B 2186.3'75 1059.000 43.118 192.250 -999.250 -999.250 -999.250 -999.250 IS' TAPE VERiFICaTION LISTING CHLUMBERGER ALASK,~ COMPUTING CENTER CFTC.CNL -999.250 CNTC.CNL HTEN.CNL -999.250 GR.CNL DRHO.LOT -999.250 RHOB.LDT QSS.LDT -999.250 tS.LOT tITH,LDT -999,250 SSi,LOT SSHV.LDT -999,250 SiRH,LDT CALI.LDT -999.250 AZIM.LDT P1AZ.LDT -999.250 MRES.LgT GR.LDT -999.250 TENS.CML RTNR.CHL 3.692 RCFT.CHL CNTC.CHL 1551.8T0 MRES.CHL GR.CML 72.188 TENS.MSF RB.MSF -999.250 Pl~Z.MSF HTEN.MSF -999.250 CALS.MSF DEPT. 10800.000 TENS.DIL ILO. OIL -999.250 SP.DIL DT.BHC -999.250 GR.BHC TNRA.CNL -999,250 RTNR.CNL CFTC.CNL -999.250 CNTC.CNL HTEN,CNL -999,250 GR,CNL DRHO.LDT -999,250 RHOB.LDT QSS.LDT -999.250 LS.LDT L ITH, LD'T -999,250 SSi,LOT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999.250 ,~ZIMoLDT PIAZ.LDT -999.250 MRES.LOT GR.LDT -999,250 TENS.CHL RTNR.CHL 4.579 RCFT.CHL CNTCoCHL 1454.457 MRES.CHL GR.CHL 77.375 TENS.MSF R~.MSF -999.250 PI~Z.MSF HTEN,MSF -999,250 CALS,MSF DEPT. 10700.000 TENS.OIL ILD:.DIL -999.250 SP,.DIL DT.BHC -999,250 GR.BHC TNRA.CNL -999,250 RTNR.CNL CFTC.CNL -999°250 CNTC.CNL HTEN.CNL -999,250 GR.CNL DRHO.LDT -999,250 RHOB.LDT QSS.LDT -999.250 LS.LDT LITH,LDT -999.250 SSI,:LDT SSHV.LDT -999,250 S1RH.LOT :C~LI,LDT -999.,Z50 AZ'IM.LOT P1AZ.,LDT -99'9,250 MRES,LDT GR,LDT -999,250 TENS,CML R'TNR.CML 4.619 RCFT.CHL CNTC.CHL 1525.991 MRES.CML GR.CML 76.563 TENS.MSF RB.MSF -999.250 Pl~Z.MSF HTEN.MSF -999.Z50 CALS.MSF 1-MAR-lOB9 16:01 -999. -999. -999. -999. -999. -999. -999. -999. 6172. 366. O. -999. -999. --999. 250 MRES.CNL -999.250 .250 TENS.LDT -999.250 250 PEF.LDT -999.250 250 LU,LDT -999,250 ZSO SS2.LDT -999.250 250 LSRH.LDT -999.250 250 DEVI.LOT -999.250 250 MTEM.LDT -999.250 000 NPHI.CHL 49.660 430 RCNT.CHL 1'700.869 976 MTEM.CHL 185.125 Z50 ~ZIM.MSF -999.250 250 MRES.MSF -999.250 250 GR.MSF -999.250 --999.250 SFLU.DIL -999.250 - 999. 250 GR. OIL -99 9.7-50 -999.250 TENS.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 MRES.CNL -999.250 -999.250 TENS.LOT -999.250 -999.250 PEF.LDT -999.250 -999. 250 LU.LOT -999.250 -999.250 SS2.LOT -999.250 -999. 250 LSRH.LOT -999.250 -999.250 DEVI.LDT -999.250 -999,250 MTEM.LOT -999,250 6052.0010 ' NPHI. CHL 58.201 267.911 RCNT,CHL 1388.776 '0. 993 MTEM,.CML 183.500 -999,250 AZTM. MSF -999,250 -999.250 MRES.MSF -999.250 -999. 250 GR, MSF -999.250 -999. -999. - 99'9. -999° -'999. - 99'9. - 999. -- '999. -- 999. -999. -999. -9 '99. 6 '044. 369. -999. -999. -999. ,250 SFL,U.DIL -999. 250 250 GR. OIL -'999.2.50 250 'T E N S , C N L -999 , .250 250 RCFT.'CNL -999:,,250 250 MRES.CNL -999.250 250 'TENS.LDT -999.250 250 PEF.LDT -999.250 250 LU,LOT -999.250 2,50 SS2.LOT -999.250 250 LSRH.LOT -999,250 250 OEVI. LOT ,-999. 250 250 'MTEM.LOT -99'9.250 000 NPMI.CMI 47.577 507 RCNT.CHL 1508.868 003 MTEM.CHL 182.000 2,50 RZIM.MS'F -999.250 250 MRESoMSF -999.250 ZSO GR, MSF -999.250 MTEM. CNL DPHI .LDT QLS.LDT LL.LDT LSHV.LDT tURN.LOT RB .LDT HTEN.LDT TNRA.CHL CFIC.CML HTE'N.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS,BHC NPHI.CNL RCNT,CNL MTEM.CNL DPHI.LDT QLS.LDT LL,LDT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNR,~.CHL CFTC.CHL HTEN.CHL gEVI.MSF M'TEM.MSF ILM. DIL TENS.SHC NPHI .CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT L'L.LDT LSHV.LDT LURH.LOT R:B.LDT MTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL OEVI.MSF MTEM.MSF PAGE: -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.127 403.941 -999.Z50 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 '-999.250 -999.250 4.595 313.621 -999.250 -999.250 '-999.250 -999,250 -999.250 -999.250 -9'99.2,50 -999.25:0 -999,25'0 -999.250 '-999.250 -999.250 -999.250 -999.250 -999.250 4.012 391.593 -999.250 -999.250 -999-250 IS' TAPE VERIFIC,ATION LISTING CHLUMBERGER ~LASKA COMPUTING CENTER 1-MAR-1989 1,6:01 DEPT. 10600.000 TENS.OIL -'999.250 SFLU.OIL -999.250 ILO.OIL -999.250 SP.OIL -999.250 GR.DIL -999.250 DT.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 qCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHD.LDT -999.250 RHOB.EDT -999.250 PEF.LDT -999.250 QSS.LDT -999.250 LS.LDT -999.250 LU.LDT -999.250 LITH.LD'T -999.250 SSI.LOT -999.250 SSI.LOT -999.250 SSHV.LDT -999.250 S1RH.LOT -999.250 LSRH.LDT -999.250 CALI.LDT -999.250 AZIM.LOT -999.250 DEVI.LDT -999.250 PIAZ.LDT -999.250 MRES.LOT -999.250 MTEM.LDT -999.250 G~.LDT -999.250 TENS.CHL 5900.000 NPHI.CHL 41.746 RTNR.CHL 3.862 RCFT.CHL ~50.069 RCNT.CHL 1670.221 CNTC.CHL 1584.916 MRES.CHL 1.026 MTEM.CHL 180.375 GR.CHL 70.063 TENS.MSF -999°250 AZIM.MSF -999.250 RB.MSF -999.250 PI~Z.MSF -999.250 MRES.MSF -999.250 HTEN.MSF -999.250 C~LS.MSF -999.250 GR.MSF -999.250 DEPT. 10500.000 TENS.OIL -999.Z50 SFLU.DIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 GR.DIL -999.250 D'T..BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNRoCN'L -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.25'0 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHO.LDT -999.250 RHOB.LOT -999.250 PEF.LDT -999.250 QSS.LDT -999.250 LS.LDT -999.250 LU,.LDT -999.250 LITH.LDT -999.250 SSI.LOT -999..250 SS2.LDT -999.250 SSHV.LDT -999.250 SIRH.LOT -999.250 LSRH.LD'T -999.250 CALI.LDT -999.250 ~ZIM.LOT -999.250 OEVI.LOT -999.250 PI~Z.LDT -999.250 MRES.LDT -'999.250 MTEM.LOT -999.,250 G.R.LOT -9'99.250 TENS.CHL 5844.000 NPHI°CHE 39.466 RTNR.CHL 3.3'94 RCFT.CHL 468.'767 RCNT.CHL 2009.232 CNTC.CHL 1800.185 MRES.CHL 1.033 MTE'M.CHL 178.625 'GR.CHL 56.8'75 TENS.MSF -999.250 AZIM.MSF. -999°250 RB.MSF -999.250 PI~Z.MSF -999.250 MR'ES.MSF -'999.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -999.250 DEPT. 10400.000 'TENS.OIL -'999.250 SFL'U.DIL -999.250 ILO.DIE -999.2,50 SP.DIL -999.250 GR.DIL -999.250 DT.BHC -999.250 GR.BHC -999.250 'TENS.CNL -999.250 TNRA.CNL -999.250 RTNRoCNL -'999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 HTE'N.CNL -999.250 GR.CN:L -999.250 TENS.EDT ,-'999.250 DRHO.LDT -999.250 RHOB.LOT -999.Z50 PEF.LDT -999.:250 ,QSS.LDT -999.250 LS.L~T -999.250 LO.LOT -999.250 LITH.LDT -999.250 SSI.LOT -999.250 SSZ.LDT -999.250 SSHV.LDT -999.250 S1RH.LDT -999.250 LSRH.LO'T -99'9.250 CALI.LOT -999.250 AZIM.LDT -999.250 DEVI.IOT -999.250 P1AZ.LDT -999.250 MRES.:LOT -999.250 MTEM.LOT -999.250 GR.LDT -999.250 TENS.CHL 5768.000 NPHI.CHL 39.605 RTNR.CHL 3.316 RCFT.CHL 484.572 RCNT.CHL 1914.339 CNTCoCHL 1858.~10 MRES.CHL 1.050 MTEM.CHL 176.875 GR.CHL 56.969 TENS.MSF -999.250 AZIM.MSF -999.250 RB.MSF -999.250 PI~,Z.MSF -999.250 MRES,.MSF -999.250 ILM.OIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LOT QLS.LDT LL.LDT LSHV.LDT LURH.LDT R~.LDT HTEN.LDT TNR~.CHL CFTC.CHL HTEN.CHL DEVIoMSF MTEM.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LD~T QLS.LDT LL.LDT LSHV.LDT LURH.LDT RB,.L:DT H'TEN.LOT TNRA.CHL CFTC.CHL H'TEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT :LL.LDT LSH¥.LDT LURHoLDT R~.LDT HTEN.LOT TN~oCHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF PAGE: 12 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.693 44~.381 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 -999.250 -99'9 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.568 507.259 -999.250 -999.250 -999'250 ,-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -,999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.575 522.306 -,999.,25'0 -999.250 -999.250 IS' TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 1-MAR-1989 16:01 HTENoMSF -999.250 CALS.MSF -999.250 GR.MSF DEPT. 10300.000 TENS.DIL -999.250 SFLU.DIL ILO.OIL -999.250 SP.DIL -999.250 GR.DIL DT.BHC -999.250 GR.BHC -999.250 TENS.CNL TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL CFTC.CNL -999.250 CNTC.CNL -999.Z50 MRES.CNL HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT DRHO.LDT -999.250 RHOB.LOT -999.250 PEF.LOT QSS.LDT -999.250 LS.LDT -999.Z50 LU.LDT LITM.LDT -999.250 SSI.LDT -999.Z50 SS2.LDT SSHV.LDT -999.250 SIRH.LDT -999.250 LSRH.LDT CALI.LDT -999.250 AZIM.LDT -999.250 DEVI.LDT PI~Z.LDT -999.250 MRES.LOT -999.250 MTEM.LDT GR.LDT -999.250 TENS.CML 5660.000 NPHI.CHL RTNR.CHL 3.333 RCFT.CHL 551.764 RCNT.CHL CNTC.CHL 1755.554 MRES.CHL 1.048 MTEM.CHL GR.CHL 60.656 TENS.MSF -999.250 ,~ZIM.MSF RB.MSF -999.250 PIAZ.MSF -999.250 MRES.MSF HTEN.MSF -999.250 CALS.MSF -999. Z50 GR.MSF -999.250 -999.Z50 -999.25'0 -999.250 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 36.538 1940.568 175.625 -999.250 -999.250 -999.250 DEPT,. 10200.000 TENS.DIL -999.250 SFLU'DIL -999.25D ILD. DIL -999. 250 SP. OIL -999. 250 GR.DIL -999.250 DT.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.25:0 RCFT. CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES'CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHO. LDT -999.250 RHOB.LDT -999.250 PEF,.'LDT -999.250 QSS'LDT -999.250 LS.LOT -999.250 LU.LOT -999.25'0 LITH'LDT -999.250 SSI.LOT -'999.250 SSZ.;LOT -999.250 SSHV.LDT -999.250 S'IRH.LOT -999.250 LSRHoLDT -999.250 CA'LI.LDT -999.250 AZIM.LOT -'999.250 DEVI.'LOT -999.250 PiAZ.LDT -999.250 MRES.LDT -999.250 MTEMoLDT -999.250 GR.LDT -999.250 TENS.CML 5568.000 NPHI.CHL 48°,442 RTNR.CHL 4.480 RCFT.CHL 384.749 RCNT'CHL 1601.807 CNTC.CHL 1533.354 MRES.CHL 1.0616 iMTEM.CHL 174.125 GR.CHL 71.188 TENS.MSF -999.250 AZIM.MSF -99'9.250 RB.MSF -999.250 PI~Z.MSF -999.250 MRES.MSF -999.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -999.250' DEPT. 10100.000 TENS.DIL -999.250 SFLU.DIL -999.250 ILD.DIL -999,. 250 SP.DII -999. Z50 GR.DIL -999.2,50 DTo3HC -999.250 GR.BHC -9:99. 250 TENS,.CNL -999.250 TNRA.CNL -999.2,50 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.,250 CNTC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHD.LDT -999.2'50 RHOB,.LgT -999.25'0 PEF.:LDT -999.250 QSS. LOT -999. Z50 LS. LOT -999. 250 LU.LDT -999. 250 LITH.LDI' -999.250 SS1.LQT -999.250 SS2.LDT -999.250 SSHV,.LDT -999°250 SIRH.LOT -999.2.50 LSRH.:LOT -999.250 CALI.LDT -999.250 ~ZIM.LDT -99'9.250 OEVI,.LOT -999.250 Pi~Z.LDT -999.250 MRES.LDT -999.250 MTEM.LD'T -999.250 GR.LDT -999.250 TENS.CML 5',464. 000 NPHI.CHL 47.989 RTNR.CML 5.200 RCFT.CHL 380.254 RCNT.CML 1415.07Z CNTC.CML 1396.769 MR ES.'CHL 1.086 MTEM.CHL 172.12,5 ILM.DIL TENS.BHC N~HI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LOT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.OIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURM.LDT RB.LD'T HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL OEVI.MSF MTEM.MSF ILM.DIL TEN,S.BHC NPHI.CNL RCNT.CNL MTEM,.CNL DPHI.LDT QLS.LDT LL.LDT LSH¥.LDT LURH.LDT RS.LOT H'TEN.LgT 'TNRA,.CHL CFTC.CHL HTEN.CHL P~GE: 13 -999°250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.407 5Z0.431 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999-250 -999.250 4.060 391.226 -999.250 -999.250 -999.250 -999.250 -999.25'0 -999.250 -999.250 -99:9.250 '-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4. 035 354 - 4 '? 3 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER 8LASK~ COMPUTING CENTER 1-MAR-1989 15:01 GR.CHL 66.188 TENS.MSF -999.250 AZIM.MSF -999.250 RB.MSF '-999.250 PIAZ.MSF -999.250 MRES.MSF -'999.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -999.250 DEPT. lO00O.O00 TENS.OIL -999.250 SFLU.DIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 GR.DIL -999.250 DT.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CN'TC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.259 TENS.LDT -999.250 DRHO.LDT -999.250 RHOBoLDT -999.Z50 PEF.LOT -999.250 QSS.LDT -999.250 LSoLOT -999.250 LU.LOT -999.250 LITH.LDT -999.250 SS1.LDT -999.250 SS2.LOT -999.250 SSHV.LDT -999.250 S1RH.LDT -999.250 LSRH.LDT -999.250 CALI.LDT -999.250 AZIM.LOT -999.250 DEVI.LDT -999.259 P1AZ.LDT -999.Z50 ~!RES.LDT -999.250 MTEM.LDT -999.250 GR.LDT -999.250 TENS.CHL 5320.000 NPHI.CHL 53.339 R'TNR.CHL 4.2B6 RCFT.CHL 333.706 RCNT.CHL 1605.191 CNTC.CHL 1470.723 MRES.CHL 1.099 MTEM.CHL 170.000 GR.CHL 62.219 TENS.M:SF -999.250 AZIM.MSF -999.250 RB.MSF -999.250 P1AZ.MSF -999.250 MRES.MSF '-999.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -999.250 DEPT. 9900.000 TENS.OIL -999.250 SFLU.DIL -999.250 ILO.OIL -999.Z50 SP.DIL -999.250 GR.DIL -999.250 O'T.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.25'0 TENS.LOT --1999.250 DRHO.LDT -999.250 RHOB.LDT -99'9.250 PEF.LOT -'999.250 QSS.LDT -999.250 LS.LDT -999.250 L:U.LDT -999.250 LITH.LDT -999.250 SS1.LDT -999.250 SS2.LDT -999.250 5SHV.LDT -999.250 SIRH.LDT -999.250 LSRH.LO'T -999.250 CALI.LDT -999.250 AZIM.LOT -999.250 OEVI.LDT -99'9'250 PIAZ.LDT -999.250 MRES.!LDT -999.250 MTEM.LOT -999.250 GR.LDT -999.25'0 TENS.CHL 5268.000 NPHI.:CHL 3'7-008 RTNRoCHL 3.815 RCFT.CHL 484.572 RCNT.CHL 1550.550 CNTC.CHL 1667.450 MRES.CHL 1.1'05 MTEM.CHL 16:8.25'0 GR.CHL 49.594 TENS.MSF .-999.250 ~ZlM.MSF -999°250 RB.MSF -999'250 P1AZ.MSF -999.250 MRES.MSF -999.250 HTEN,.MSF -999.250 CALS..SF -999.250 GR.MSF -999.25'0 DEPT. 98~00.000 TENS.DIL ,-99'9. 250 SFLU.DIL -999.250 ILD.OIL -999.250 SP. OIL -999. 250 GR. DIL -999,. 250 DT.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL .-999.250 RTNR.CNL -999.250 RCFT.CNL ,-999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LDT --999.250 DRHO.LDT -999.250 RHOB.LDT -999.250 PEF.LOT -999.250 QSS.LDT -999.250 LS.LDT -999. 250 LU,. L DT -999.25:0 LIT'H.LDT -999.250 SS1.LDT -999.250 SSZ.LDT -999.250 SSHV.LDT -999.250 S1RH.LDT -99'9.250 LSRH.LOT -'999.,250 CALI.LDT -999.250 AZIM.LDT -999.250 DEVI.LOT -99'9.250 P1AZ.LDT -999.250 MRES.LgT -999.250 MTEM.LDT -999.250 GR.LDT -999.250 TENS.CHL 5268.000 NPHI.CHL 40.609 DEVI.MSF MTE'M.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT RS.LDT HTEN.LDT TNR~.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM,.OIL TENSo~HC NPHI .CNL RCNT.CNL MTEM.CNL DPHI.LDT QLSoLDT LL.LDT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL O,~V'I.MSF MTEM.MSF ILM.DIL TENS.SHC NPHI.CNL RCN'T'CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT R'B.LDT HTEN.LDT T'NR~.CHL PAGE: 14 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.329 359.983 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.,250 -99'9 · 250 · -999.250 -999.2~0 -99'9.250 -999.250 -999.250 -99'9.250 -999.250 3.~33 496.686 -999.25Q -999.Z50 -'999.250 -999.2,50 .-999.Z50 -999.250 -999.250 -999.250 -999.2!50 -999. Z 50 -999.250 -999.250 -999.250 -999.250 -999,25~ 3.630 IS' TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 1-MAR-lO89 16:01 RTNR.CHL 3.731 RCmT.CHL 434.235 RCNT.CHL 1673.750 CNTC.CHL 1579.493 MRES.CHL 1.112 MTEM.CHL 167.000 GR.CML 53.188 TENS.MSF -999.250 ~Z!M. MSF -999.250 RB.MSF -999.250 Pl~Z.MSF -999.250 MRES.MSF -999.250 HTEN.MSF -999.250 C~LS.MSF -999.250 GR.MSF -999.250 DEPT. 9700.000 TENS.OIL -999.250 SFLU.DIL -999.250 ILO.OIL -999.250 SP.DIL -999.250 GR.DIL -999.,250 DT.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNR~.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 'TENS.LOT -999.250 DRHO.LDT -999.250 RHOB.LOT -999.250 PEF.LDT -999.250 QSS.LDT -999.250 LS.LDT -999.:~50 LU.LDT -999.25D LITH.LDT -999.250 SS1.LDT -999.Z50 SS2.LOT -999.250 SSHV.LDT -999.250 SIRH.LOT -999.250 LSRH.LDT -999.250 CALI.LDT -999.250 AZIM.LDT -999.250 OEVI.LOT -999.250 P1AZ.LDT -999.250 MRES.LDT -999.250 MTEM.LDT -999.250 GR.LDT -999.250 TENS.CHL 5220.000 NPHI.CHL 44.852 RTNR.CHL 4.714 RCFT.CHL 451.952 RCNT.CHL 1704.{57 CNTC.CHL 1569.19~ MRES.CHL 1.123 MTEM.£HL 165.875 GR.CHL 50.250 TENS.MSF -999.250 ,AZIM.MSF -999.250 RB.MSF -999.250 P1AZ.MSF -999.250 MRES.MSF -999.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -999.250 DEPT. 9600.000 TENS.DIL -999.250 SFLU.DIL -99'9.250 ILD.DIL -999.250 SP.DIL -999.250 GRoDIL -999.250 O'T.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -99'9.25'0 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHU'LDT -999.250 'RHOB.LDT -'999.250 PEF.LOT -999.250 QSS.LDT -999.250 tS.LOT -999.25'0 L'U,.LDT -999.250 LITH.LDT -999.250 SSt.LOT -999.250 SSZ.LDT -999.250 SSHV.LDT -999.250 S1RH.LOT -999.250 LSRH.LOT -99'9.250 CA'LI.LDT -999.250 AZIM.LDT -'999.250 DEVI.LDT -999.250 PI~Z.LDT -999.250 MRES.LOT -999.250 MTEM.'LDT -999.250 GR.LOT -999.250 'TENS.CHL 5232.000 NPHI.CHL 33.194 RTNR.CHL 3.654 RCF'T.CHL 534.958 RCNT.CHL 1708.060 CNTC.CHL 1667.630 MRES.CHL 1.151 MTEM.CHL 164.750 GR.CHL 40.188 TEN'S.MSF -999.250 AZIM.MSF -999.250 RB.MSF -999.Z50 PI~Z.MSF -999.250 MRES.MSF -99'9.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -99'9.250 DEPT. 9500.000 TENS.OIL -999.Z50 SFLU.DIL -999.,250 ILO.git -999. Z 50 SP. DIL -999. 250 GR. OIL -999. 250 D'T.BHC -999.250 SR.~HC -999.250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CN'TC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHO.LD'T -999.,250 RHOB.LDT -99'9.250 PEF.LOT -999.250 QSS.. LOT -999. Z 50 tS.LOT ,- 999.7_ 50 LU. LOT -999. 250 LITH.LDT -999.250 SS1 .LDT -999.250 SSZ.LDT -999.250 5SHV.LD'T -999.250 SIRH.LOT -999.250 LSRH.LDT -999.,250 C,~LI.LDT -999.250 AZIM.L, OT -999.,250 DEVI.LOT -999.250 CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT R~.LDT HTEN.LDT TNR~.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.~BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT 'QLS.LDT L:L.LDT LSHV.LDT LURH.LDT RB.LDT H'TEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEV,I.MSE MTEM.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT R~.LDT PAGE: 15 451.033 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 3.863 4Z6.816 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 -999.250 -999.250 -999.250 3.223 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25'0 -999.250 -999.2,50 -999.250 -999.250 -999.250 -9'99.2!50 1S TAPE VERIEICATION LISTING CHLUMBERGER ,~LASKA COMPUTING CENTER 1-'MAR-lOB9 16:01 P1AZ.LDT -999.250 MRES.LDT -999.250 MTEM.LDT -'999.250 GR.LDT -999.250 'TENS.CHL 5204.000 NPHI.CHL 35.288 RTNR.CHL 3.769 RCFT.CHL 467.788 RCNT.CHL 1653.110 CNTC.CHL 1590.922 MRES.CHL 1.169 MTEM.CHL 162.125 GR.CHL 42.344 TENS.MSF -999.250 AZIM.MSF '-999.250 RB.MSF -999.250 P1AZ.MSF -999.250 MRES.MSF -999.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -999.250 DEPT. 9400.000 TENS.OIL -999.250 SFLU.DIL -999.250 ILD. OIL -999.250 SP. OIL - 999. 250 GR. OIL -999.250 DT.BHC -999.250 GR.BHC -999°250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 HTENoCNL -999.250 GR.CNL -999,.250 TENS.LOT -999.250 DRHD.LDT -999.250 RHOB.LDT -999.250 PEF.LDT -999.250 QSS.LDT -999. 250 LS.LOT -999. 250 LU.LDT -99 9. 250 LITH.LDT -999.250 SSI.LDT -999.250 SS2.LDT -999.250 SSHV.LOT -999.250 S1RH.LOT -999.250 LSRH.LOT -999.250 C,ALI.LDT -999.250 AZIM.LDT -999.250 DEVI.LDT -999.2'50 PIAZ.LDT -999.250 MRES.LDT -999..7_50 MTEM.LOT -999.250 GR.LOT -999.250 TENS.CHL 5'108.000 NPHIoCHL 48.271 RTNR.CHL 4.545 RCFT.CHL 367.194 RCNT.CHL 1445.125 CNTC.CHL 1468.030 MRES.CHL I.ZOZ MTEM.CHL 159.500 GR.CHL 53.938 TENS.MSF -999. ZSO AZIM.MSF -999.250 RB.MSF -999.250 P1AZ.MSF -999.250 MRES.MSF -999.250 HTE,N.MSF -999.250 CALS.M'SF -999.250 GR.MSF -999.250 DEPT. 93'00.000 TENS.OIL -999.250 SFLU.OIL -999.Z50 ILO. Oil -9'99. Z 50 SP.DIL - 999. ZSO GR. DI'L -999. 250 D'ToBHC -999.250 GR.BHC -999.250 TENS.CN'L -999.250 TNRA,CNL -999,250 RTNR,CNL -999,250 RCFToCNL -999,250 CFTC.CNL '-999.250 CNTC.CNL -'999.250 MR,ES.CNL ,-999.Z50 HTEN.CNL -9'99.250 GR.CNL -999.250 TENS.LDT -999. Z50 DRHO.LDT -999,2.50 RHOB.LOT -999,250 PEF,LgT -999,25'0 QSS.LOT .-999. 250 LS.LOT -999. 250 LU.LDT -'999.250 L'ITH. LOT -999.250 SS1 .LOT -999.250 SS2oLOT -999.250 SSHV.LDT -999.250 S1RH.LDT -999.,25'0 LSRH,.LDT -999.250 CALI.LDT -999.250 AZIM.LDT -999.250 OEVI.LOT ,-999.250 PI~Z.LDT -999.250 MRES.LDT -999.250 MTEM.LOT -999.250 GR.LDT -999.250 TENS.CH'L ]5064. 000 NPHI.CHL 4:.5,918 RTNR.CHL 4.350 RCF'T.CHL 3,30.342 RCNT.CHL 1448.167 CNTCoCHL 1401.843 MRES.CHL 1.227 MTEM.CH'L 157.000 GR.CHL 67.313 TENS.MSF -999.250 AZIM.M:SF -999.250 RB. MS~: -999.250 PIAZ.MSF -999.250 MRES.MSF -999.250 HTEN,MSF -999,250 CALS,MSF -999.250 GR.MSF -999,250 DEPT, 9Z00o000 TENS.OIL -999.250 SFLU'OIL -999.250 ILO. DIL -999. 250 SP. OIL -999. 250 GR.DIL -999. 250 DT,BHC -999,250 GR,BHC -999.250 TENS,CNL -999,250 TNRA.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999,250 CNTCoCNL -999.250 MRES.CNL -999,2.50 HTEN.CNL -999.250 GR.CNL -999,250 TENS,:LDT -999,250 DRHO.LDT -999.250 RHOB.LDT -999.Z50 PEF.LDT -999.250 QSS.LD'T -999. Z 50 LS.LDT -999.25'0 LU.LDT -99 9.Z50 LITH.LDT -999.250 SSI.LOT -999.250 SSZ.LDT -999.250 HTEN.LDT TNR.~.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.OIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT RB.LDT HTEN.LD'T TNR~,CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT :QLS.LDT LL.LDT LSHV.LDT LURfl.,LDT R~.LDT HTEN.Lg'T TNRA.CHL CFTC,.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LD'T PAGE: 16 -999.250 3.338 486.145 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.051 366.117 -999.250 -999.250 -999.250 -,999. 250 -999.250 -999. 250 ,-999.250 -999.250 -999. 250 -999,2'50 -999.250 -999.2:50 -999.250 -999.250 -999.250 3.921 351.549 -999.250 -999.250 -999.2,50 -999.250 -999.Z50 -999.Z50 -999.Z50 -99'9,250 -999.250 -999.250 -999.250 -9'99.250 IS' TAPE VSRIFICATIDN LISTING CHLUMBERGER ~LASKA COMPUTING CENTSR SSHV.LDT -999.250 SIRH.LDT CALl. LOT --999.Z50 AZIM.LOT P1AZ.LDT -999.250 MRES.LDT GR.LDT -999.250 TENS.CHL RTNR.CHL 4.900 RCFT.CHL CNTC.CHL 1449.798 MRES.CHL GR.CHL 57.938 TENS.MSF RB.MSF -999.250 PlAZ.MSF H'TEN.MSP -999.250 CALS.MSF 1--MAR-'1989 16:01 -999.250 LSRH.LOT -999.250 DEVI.LDT -999.250 MTEM.LDT 5028.000 NPHI.CHL 31.6.970 RCNT.CHL 1. 220 MTEM.CHL -999.250 AZIM.MSF -999.250 MRES.MSF -999.250 GR.MSF -999.250 -999.250 -999.250 54.624 1502.500 155.625 -999.250 -999.250 -999.250 DEPT. 9100.000 TENS.DIL -999.250 SFLU.DIL -999.250 ILO. OIL -999. Z 50 SP. OIL - 999. 250 GR. DIL -999.250 DT.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL .-999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNt -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHO.LDT -999.250 RHOB.LOT -999.250 PEF.LOT -999.250 QSS. LOT -999. 250 LS. LOT -'999.,, 250 LO.LOT -999.2 50 LITH.LDT -999.250 SS1.LDT -999. 250 SS2.LDT -999.250 SSHV.LOT -999.250 SIRH.LDT -999.250 LSRH.LOT -999.250 CALI.LDT -999.250 AZIM.LDT -999.250 DEVI.LDT -999.250 P1AZ.LDT -999.250 MRES.LDT -999.250 MTEM.LOT -999.250 GR.LDT -999.250 TENS.CHL 5044.000 NPHI.CHL 59.315 RTNR.CHL 5.333 RCFT.CHL 316.970 RCNT.CHL 1547.290 C'NTC.CHL 1441.7'79 MRES.CHL 1.225 MTEM.CHL 154.125 GR.CHL 57.250 TENS.MSF -999.250 AZIM.MSF -999.250 RB.MSF -999.250 P'IAZ.MSF -999.250 MRES,.MSF -999.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -999.250 -999.250 SFLU.DIL -'999.250 -999,. 250 GR. OIL -99 9. ,250 -999.250 TENS.CNL -999.250 -999.250 RCFT.CNL -999.250 -999.250 MRES.CNL ,-99'9.250 -'999 . 250 T E N S - 't D'T - 999 . 1250 -999.250 PEF.LOT -999.,250 - 999.. 250 LU.LOT -999.250 -999.250 SS2.LDT -999.250 -'999.250 LSRH.LDT -999,.250 --999.250 DEV!.LDT -999.250 -999.250 MTEM.'LOT -99 9.,250 4944.000 NPHI.CHL 49.887 351.180 RCNT.'CHL 1514.621 1.232 MTEM.CHL 153. O0'O -999. 250 ~ZIM.RSF -999.250 -99'9.250 MRES.MSF -999.250 -999. 250 GR'. MSF '-'999. 250 D:EPT'. 9000.000 TENS.OIL ILD.DIL -999. 250 SP.DIL DT. BH:C -999.250 GR.BHC TNRA'CNL -999.250 RTNR.CNL CFTC.CNL -999. 250 CNTC,.CNL HTEN. CNL -999. 250 GR. CNL DRHO.LDT -999.250 RHOB-LOT 'QSS.LDT -999.2 50 LS. LOT LITH.LDT -999. 250 S S1.LOT SSHV.LDT -999. 250 SIRH.LOT CALI.LDT -999.250 AZIM.LDT P1AZ.LD'T -999.250 MRES.LDT GR.LDT -9'99.250 TENS.CHL RTNR.CHL 4.7FJ9 RCFT.CHL C:N'TC. C, HL 1461.103 MRES,.CHL GR.CHL 70.813 TENS.MSF R~.MSF -999.250 PI,~Z.MSF HTEN.MSF -999.250 C~LS.MSF OEP'T. 8900.000 'TENS.DIL -999.250 SFLU.DIL ,-9,99. 250 ~ILD. OIL -999 . Z 50 SP . OIL - 999. 250 GR .DIL -99 9. ZSO DT. BH'C ,-999. 250 GR.BHC -999.250 TENS.CNL -999.250 TNR,A.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 'MRES.CNL -'999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHO.LDT -999.250 RHOB.LgT -999.250 PEF.LOT -999.25:0 t URH. LOT RB.LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN. CHL DEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS .LOT LL.LDT LSHV.LDT LURH.LDT RBoLDT HTEN.LDT TNRA .CHL CFTC.CHL HTEN.CHL DEVI.MSF MT E M. MS F ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI .LOT QLS.LDT LL. LD'T LSHV .LDT L'U R H. 'L D T RB.LDT HTEN.LDT TNR~.CHL CFTC.CHL HTEN.CHL D 'EV'I. MS F MTEM,.MSF ILM. ,OIL 'TENS.. BHC NPHI.CNL RCNT.CNL M'TEM. CNL DPHI.LDT QLS. LDT P~GE: 17 -999.250 -999.250 -999.250 4.399 342.475 -999.250 -999.250 -999.250 -999.250 1-999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.25.0 -999.250 -999.250 -999.250 4.656 330.545 -999.250 -999.25'0 -999.250 -999.250 -999.250 999.250 -999.250 -999.250 -999.250 -999.250 .-999.2,50 -999.250 -999.250 -999.250 -999.250 4.139 3,53.699 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 .-999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA CgMPUTIN'G CENTER 1-MAR-1989 16: 0l QSS. LOT -999. 250 LS. LOT -999. 250 LU.LDT -999. 250 LITH.LDT -999.250 SSI.LOT -999.250 SS2.LDT -999.250 SSHV.LDT -999.250 S1RH.LDT -999.250 LSRH.LDT -999.250 C~LI.LDT -999.250 AZIM.LOT -'999. 250 OEVI.LDT -999.250 PIAZ.LDT -999.250 MRES.LOT -999.250 MTEM.LDT -999.250 GR.LDT -9'99.250 TENS.CHL 4~6~.000 NPHI.CHL 45.753 RTNR.CHL 3.950 RCFT.CHL 349.718 RCNT.CML 1465.219 CNTC.CHL 1447.997 MRES.CHL !. 26.~ MTEM.CHL 151.125 GR.CHL 50.719 TENS.MSF -999.25'0 ,~ZIM.MSF -999.250 RB.MSF -999.250 P1 ~Z.MSF -999.250 MRES.MSF -999.250 HTEN.MSF -999.250 CALS.MSF -999.250 GR.MSF -'~99.250 DEPT. B800.O00 TENS.OIL -999.250 SFLU.DIL -999.250 ILO. OIL -999. 250 SP. OIL -999. 250 GR. OIL -999.2 50 lIT. §HC -999.250 GR.BHC -999.250 TENS.CNL -99'9.250 1NR~.CNL -999.250 RTNR.CNL -999.250 RCFT.CNL -999.250 CFTC.CNL -999.250 CN'TC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -999.250 TENS.LOT -999.250 DRHD.LDT -999.250 RHOBoLDT -999.:250 PEF.LDT .-999. ~-50 QSS.LDT -999. Z 50 LS.LDT -999. 250 LU.LDT -99 9. 250 LITH.LDT -999. 250 SS1.LD~T -'999.250 SS2.LDT -999.250 SSHV.LDT -999.250 S1RH.LDT -999.250 LSRH.LDT -'999.250 C~LI.LDT -9'99.250 AZIM.'LDT -999.250 DEVI.LDT -999.250 P1AZ.LDT -999.250 MRES.LDT -999. 250 MTEM.L~T -999.250 GR.LDT ,-999.250 TENS.CHL 4860.000 NPHI.CHL 45.:B61 R'TNR.CHL 3.958 RCFT.CHL '369.344 RCNT.CHL 156'7.631 CNTC.CHL 1470.173 MRES.CHL 1.273 MTEM.CHL 1,49.500 GR.CHL 55.906 'TENS.MSF -9:99. 250 AZIM.M'SF -999.,250 RB.MSF -999.250 P1AZ.MSF -999.250 MRES.MSF -999.25'0 HTEN.MSF -999.250 CALS.MSF -999.250 GR,.MSF -999.250 DEPT. 8700.000 TENS.OI:L -999.250 SFLU.DIL -999.250 ILO. OIL -999. Z 50 SP.DIL - 999. 250 GR.DIL -999. 250 DT.BHC -999.250 GR.BHC -999.250 'TENSoCNL -999.250 TNRA.CNL -999. 250 RTNR.CNL -999o,250 RCFT.CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 HTEN.CNL -999.250 GR.CNL -99,9. ~50 'TENS.:LDT -999.250 ORHD.LDT -999.250 RHOB.LDT -999.250 PEF-LDT -999.250 qSS. LOT -999.250 LS. LOT .-999. 250 LU.LDT -999.250 LITHoLDT -999.250 SS1.LDT -999.250 SSZ.LDT -999..250 SSHV.LDT -999.Z50 S1RH.LgT '-99'9. 250 LSRH.'LOT -999.250 CALI,.LDT -999.250 AZIM.LDT -999.250 DEVI.LDT -999.250 PIAZ.LDT -999.250 MR'ES.LOT -999.250 MTEM.LDT -999.250 GR.LDT -999.250 TENS.CHL 479Z.000 NPHI.CHL 4'9.355 RTNR.CHL 4.600 RCFT.CHL 316.970 RCNT.CHL 1411.604 CNTCoCHL 14'58.648 MRESoCHL 1.274 MTEM.CHL 148.250 GR.CHL 56.500 TENS.MSF -999.250 AZIM.MSF -999.250 RB.MSF -999.250 PIAZ.MSF -999.250 MRES.MSF -999.250 HTEN.MSF -999.250 CALS.NSF -99'9. 250 GR.MSF -999.250 DEPT. 8600-000 TEN:S.DIL -999.250 SFLU.DIL -999,.25'0 ILO. D'IL -999.250 SP. OIL -,999. 250 GR. DIL -999. 250 DT,.~HC -999.250 GR.BHC -999.250 TENS.CNL -999.250 'TNRA.CNL -999.250 RTNR,.CNL -999.250 RCFT.CNL -'999,. 250 CFTC.CNL -999.250 CNTCoCNL -999. 250 MRES.CNL -999.250 LL.LDT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNRA.CHL CFTC.CHL H'TEN. CHL DEVI .MSF MTEM.MSF ILM.OIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT L L. L O T LSHV.LDT LURH .LOT R~ .LOT HTEN. LOT TNRA.CHL CFTC.CHL HTEN. CHL D ~E'V I. M,$ F MT EM. :MS F !LM.OIL TENS.BHC NPH I. CNL RCNT.CNL MT E,M. CNL DPHI.L~T q L 'S. t D T LL.LDT LSHV.LDT LURH.LDT RB .LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM. MSF ILM.DIL TENS.BHC NPHI,.CNL RCNT.CNL MTEM.CNL PAGE: 18 -999.250 -999.250 -999.250 -999.250 -9'99.250 3.912 3T7.582 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.~50 -999.250 -999.250 -999.250 -999.250 3.918' ~0,6.553 .-.999.250 -999.250 -999.250 -999.250 -999. -999.250 -999.250 -999.250 -9'99.250 -999.250 -999 -999.250 -999.250 -999.250 -999.Z50 4.110 360.207 -999.250 -999.250 -999.250 -999.250 -99'9.250 -999.2 50 -999.250 -999.250 TAPE VERIPICATIDN LISTING CHLUMBERG~R 8LASK~ COMPUTING CENTER HTEN.CNL -999.250 GR.CNL DRHU.LDT -999.250 RHOB.LDT QSS.LDT -999.250 LS.LDT LITH.LDT -999.250 SSI.LDT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999,250 AZIM.LDT PIAZ.LDT -999.250 MRES.LDT GR,LD'T -999,250 TENS,CHL RTNR,CHL 4.688 RCFT.CHL CNTC.CHL 1460,920 MRES,CHL GR.CHL 57.500 TENS,MSF RB,MSF -999.250 PI~Z,MSF HTEN, MSF -999.250 CALS,MSF DEPT. 8500. 000 TENS.DIL ILD. DIL -999.250 SP. DIL DT. BH'C -999. Z 50 GR, BHC TNRA,CNL -999. 250 RTNR.CNL CFTC.CNL -999.250 CNTC,CNL H'TEN,CNL -999,250 GR,CNL DRHO.LDT -999.250 RHOB.L~)T QSS.LDT -999. 250 LS.LDT L ITH.LDT -999.2 50 SS1,LOT SSHV.LDT -999.250 S1RH.LDT CALI.LDT -999.250 AZIM.LgT PIRZ.LOT -9'99.250 MRIES,LDT GR,LDT -999.250 TENS,CHL RTNR.CHL 4.048 RCFT.C?IL CNTC,CHL 1421.559 MRES.CHL GR,CHL 54.594 TENS,MSF RIB,MSF -999,.250 P1AZ,MSF HTEN,MSF -999.Z50 C~LS,MSF DEPT. 8400. 000 TENS.DIL ILO.DIL -999' 250 SP.DIL DTo BHC -999,250 GR.BHC TNRA.CNL -999.250 RTNRoCNL CFTC.CNL -999.2'50 CNTC,. CNL HTEN,CNL -999,250 'GR, CNL DRHI3'LDT -999.250 RHO'8.LDT QSS.LDT -999.250 LS.LOT LITH.LDT -999. 250 SSI.'LDT SSHV.LDT -999.250 S1RH.LDT CALI.,LDT -999.250 .~ZIM,LDT P1AZ,LDT -999,250 MRES,LDT GR,LDT -999.250 TENS,CHL R'TNR,CHL 4,556 RCFT.CHL CNTC,CHL 1483,052 MRE'S,CHL GR.CHL 54.031 TENS,MSF R~,MSF -999.250 Pl~Z..MSF HTENoMSF -999.250 C~LS,MSF 1-MAR-1989 16:01 -999.25D TENS.LDT -993.250 -999.250 PEF.LDT -999.250 -999. 250 LU. LOT --999. 250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.250 -999.250 DEVI.LDT -999.250 -999.250 MTEM.LDT -999.2513 ~TZB,.O00 NPHI.CHL 53.630 350,447 RCNT.CHL 1515.402 1.294 MTEM,CHL 147.250 -999.750 AZIM.MSF -999.250 -999.250 MRES,MSF -999.250 -999. ZSO GR.MSF -999.250 -999.250 SFLU.DIL -999.250 -999. 250 GR. DIL -999. 250 -999.250 TENS.CNL -999.250 -999.250 RCFT.CNL -999,250 -999.250 MRES,CNL -999.250 -999, 250 TEN:S,LDT -999.250 -999.250 PEF.LOT -999.250 -999. 250 LU.LDT -999.250 -999.250 SS2,LDT -999.250 -999.250 LSRH.LDT -999.250 -999.Z50 DEVI.LOT -'999.250 -999.250 MTEM.LDT -999.250 47'40,000 NPHI,CHL 44.729 367,194 RCNT,CHL 14.3 B. 503 '1.301, MT~M.CHL 146.000 -999.,250 AZIM. MSF -999.250 -999..Z50 MRES.MSF -999.250 -999. 250 GR.MSF -999.250 -999,250 SFLU,DIL -999,250 GR,OIL -999,250 TENS,CNL -999,250 RCFT,CNL -999,250 MRES,CNL -999.250 TENS.LDT -99'9.250 PEF.'LDT -999.25'0 LU.LDT -999.250 SSZ,LOT -999.250 LSRH,LDT -999.250 DEVI.LDT -999.250 MTEM.LDT 4672.000 NPHI.CHL 350.447 RCN'T.CHL 1,311 MTEM.CHL -999.250 AZIM.MSF -999.250 MRES,MSF -999.250 GR..MSF -999.250 -999. ,250 -99 9. 250 -999.250 - 999.2 50 -g99.250 - 99 9. Z 50 -999. Z 50 -999.250 -99'9.250 -999. 250 -999,.250 4,6. 158 1502. 500 144. 875 -999.250 -999.250 -999.250 DPHI .LDT .QTS. LD'T LL. LDT LSHV.LDT LURH.LDT RB.LD'T HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEVI .MSF MTEM.MSF ILM,DIL TENS ,BHC NPHI,CNL RCNT,CNL M'TEM,CNL D PH I, LDT qLS,LDT LL,LDT LSHV, LD'T LURH,LDT RB .LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEVI ,MSF MTEM, MSF ILM.DIL TENS.gHC N PHI. CNL ,RCNT. CNL M'TEM. CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNRA.CHL C FTC. C HL HTEN.CHL DEVI.MSF MTEM,MSF PAGE: 19 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.344 347.958 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.856 374.999 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.935 392.471 -999.250 -9~9.250 -999.250 IS TAP~ VERIFICATION LISTING CHLUMBERGER ,~LASKA COMPUTING CENTER DEPT. 8300.000 TENS.OIL ILO.OIL -999.250 SP.DIL DT.BHC -999.250 GR.BHC TNRA.CNL -999.250 RTNR.CNL CFTC.CNL -999.250 CNTC.CNL HTEN.CNL -999.250 GR.CNL DRHO.LDT -999.250 RHOB.LOT QSS.LDT -999.Z50 LS.LDT LITH.LDT -999.250 SS1.LDT SSHV.LDT -999.250 S1RHoLDT CALI.LDT -999.Z50 AZIM.LOT P1AZ.LDT -999.250 MRES.LDT GR.LDT -999.250 TENS.CHL RTNR.CHL 4.750 RCFT.CHL CNTC.CHL 1452.849 MRES.CHL GR.CML 58.000 TENS.MSF RB.MSF -999.250 olAZ.MSF H'TENoMSM -999.250 CALS.MSF DEPT. 8200.000 TENS.OIL ILO.OIL -999.250 SP.DIL DT.BHC -999.250 GR.BHC TNR~.CNL -999.250 RTNR.CNL CFTC.CNL -999.250 CN'TC.CNL HTEN.CNL -999.Z50 GR.CNL DRHO.LDT -999.250 RHOBo'L. DT QSS.LDT -999.250 LS.LDT LITH.LDT -999.250 SS1.LDT SSH'V.LDT -999.250 S1RH.LDT CALI.LDT -999.250 AZIM.'LDT PIAZ.LDT -99'9.250 MRES.LDT GR.LDT -999.250 TENS.CML RTNRoCHL 3.957 RCF'T.CHL CNTC.CML 1448.610 MRES.CHL GR.CHL ,69.594 TENS.MSF R~.MSF -999.250 PIAZ,.MSF HTEN.MSF -999.250 C~LS.MSF 1-MAR-1989 16:01 -999.250 SFLU.DIL -999.250 GR.DIL -999.250 TENS.CNL -999.250 RCFT.CNL -999.250 MRES.CNL -999..Z50 TENS.LOT -999.250 PEF.LDT -999.250 LU.LDT -999.Z50 SS2.LDT -999.250 LSRH.LOT -999.250 DEVI.LDT -999.250 MTEM.LDT 456B.000 NPHI.CHL 331.146 RCNT.CHL 1.320 MTEM.CHL -999.250 AZIM. MSF -999.250 MRES.MSF -999.250 GR.MSF -999.250 SFLU.DIL -999.250 GR.DIL -999.250 TENS.CNL -99'9.250 RCFT.CNL -999.250 MRES.CNL -999.250 'TENS.EDT -999.250 PEF.LgT · -999.250 'L'U.LDT -999.250 SSZ.LDT -999.250 LSRH.LDT -999.250 DEVI.LOT -999,.250 MTEM.~LOT 4504..000 NPHI.CHL 350.691 RCNT.CHL 1.331 MTEM.CHL -99'9.250 AZIM.MSF -999.25'0 MRES.MSF -999.250 GR.MSF -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 52.397 1.417.061 143.875 -999.250 -999.250 -999.250 -999.250 -9'99.250 '-999.250 -999.250 -999.250 -999.250 -99'9.250 -99 9. 250 -999.25Q --999.250 -999.250 -999.250 47.149 1570.940 142.625 -999.250 -999.,25Q -999.250 DEPT. 8100.000 TENS.OIL -999.250 SFLUoDI'L -999.250 ILO. OIL -999. 250 SP. OIL -999,. 250 GR. OIL -99 9. Z50 DT.BHC -999.250 GR.BHC -'999.250 TENS.CNL -999.250 TNRA.CNL -999.250 RTNR,CNL -99'9.25'0 RCFT. CNL -999.250 CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CNL -999.250 H'TEN.CNL -999.250 GR.CNL -99,9.Z50 TENS.LOT -999.2.50 DRHO.LDT -999.250 RHOR.LQT -999. Z50 PEF.LOT -999.250 QSS.LDT -9'99. 250 tS. LOT -999. 250 LU. LD'T -999.250 LITH.LDT -999.250 SS1.LDT -999.250 SSZ.LDT -999.250 SSMV.LDT -999.250 S1RH.LDT -999.Z50 LSRM.LOT -999.250 C~LI.LDT -999.250 ~ZIMoLDT -999.250 OEVI.LDT -99'9.250 P1AZ.LDT -999.250 'MRES.LDT -999.250 MT'EM.LOT -999.250 GR.LDT -999.250 TENS.EHL 451:2.000 NPHI.CHL 47.031 RTNR.CHL 4.750 RCFT.CHL 350.447 RCNT.CHL 1,4.85.403 CNTC.CHL 1415.916 MRES.CHL 1.356 MTEM.CHL 141.250 GR.CML 55.3,44 TENS.MSF -999.250 AZIMoM:SF -999.,250 RB.MS~ -9'99.250 PIAZ.MSF -999.250 MRES.MSF -999.250 ILM.OIL TENS.BHC NPHI.CNL RCNT. CNL MTEM.CNL DPHI.LDT QLS .LOT LL.LDT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNR~.CHL CFTC.CHL HTEN.CHL DEVI .MSF MTEM.MSF ILM.OIL TENS.BHC NPHI.CNL R CNT. CNL MTEM.CNL DPHI. LOT OL S. LD'T LL. LOT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNR,~. CML CFTC.CML HTEN.CML DEVI.MSF MTEIM.MSF ILM. OIL TENS. BHC NPHI.CNL RCNT.CNL MTEM.CNL DPMI.LDT QLS .LOT L L. L D T LSHV .LOT LURH.LDT R8. LDT HTEN.LDT TNRA,.CHL CFTC.CHL HTEN.CHL D:-VI. :MSF MTEM.MSF PAGE: -9'99.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.277 340.958 -999.250 -999.250 -999.250 -999 · -999. -999. -999. - 9'99. -999. -999. -999. -999. -999. -999. -999. 3. 366. --99 9 · -999 o -9'99. 25O 25O 25O 25O 25O 250 25O 25O 25O 25O 25O 25O 989 615 2.50 25O 7O -999.250 -999.250 -999.250 -9'99.250 -9'99.250 -9'99.250 -999.250 -999.250 -9'99.250 -999.250 -999.250 -999.250 3.983 362.457 -999.250 -999.250 ,-9'99.250 IS TAP~ VERIFICATION LISTING CHLUMBERGER ~LASK.,~ COMPUTING · C E.NT ER 1-MAR-I989 16:01 HTEN.MSE -999.250 C~LS.VSF -999.225'0 GR.MSF -999.250 DEPT. 8000.000 TENS.DIL ILO.OIL -999.250 SP.DIL DT.BMC -999.250 GR.BHC TNR~.CNL -999.250 RTNR.CNL CFTC.CNL -999.250 CNTC.CNL HTEN.CNL -999.250 GR.CNL DRHO.LDT -999.250 RHOB.LDT QSS.LDT -999.250 LSoLDT LITH.LDT -999.250 SS1.LDT SSHV.LDT -999.250 SIRH.LDT CALI.LDT -999.Z50 AZIM.LDT PIAZ.LDT -999.250 MRES.LDT GR.LDT -999.Z50 TENS.CHL RTNR.CHL 4.556 RCFT.CHL CNTC.CHL 1405.363 MRES.CHL GR.CHL 55.094 TENSoMSF RS.MSF -999.250 PIAZ.MSF HTEN.MSF -999.250 CALS.MSF DEPT. 7900.000 TENS.OIL ILD.DIL ,-999.250 SP.OIL D'T.BHC -999.250 GR.BHC TNRA.CNL -999.250 RTNR.CNL CFTCoCNL -999.250 CNTC.CNL HTEN.CNL -999.250 GR.CNL DRHO.LDT -999.250 RHOB.LDT QSS.LDT -999.250 LSoL~T LITH.LDT -999.250 SSI.LDT SSHV.LDT '-999.250 SIRH.LDT CALl. LOT -999.250 AZIM.LDT PIAZ.LDT -999.250 MRES.LDT GR.LDT ,-999.250 TENS.CHL RTNR.CHL 3.783 RCFT.CHL CNTC.CHL 1419.306 MRES.CHL GR.CHL 41.ZB1 TENS.MSF RB.MSF -999.250 PIAZ.MSF HTEN.MSF -999.250 C~LS.MSF -999.250 ISFLU.DIL -999. Z50 GR.DIL -999.250 TENS.CNL -999.250 RCFT.CNL -999.250 MRES.CNL -999.250 TENS.LOT -999.250 PEF.LDT -999.2250 LU.LDT -999.250 SS2.LDT -999.250 LSRH.LDT -999.250 DEVI.LOT -999.250 MTEM.LDT 4464.000 NPHI.CHL 331.955 RCNT.CHL 1.379 MTEM.CHL -999.250 ~ZIM.MSF -999.250 MRES.MSF -999.250 GR.MSF -999.250 SFLU.DIL -999.250 GR.OIL -999.250 TENS.CNL -999.250 RCFT.CNL -999.Z50 MRES.CNL -999.250 TENS.LOT -999. Z50 PEF.LDT -99'9. 250 LU.LOT --999'250 SS2.LDT -999. 250 LSRH.LDT -999. 250 9EVI .LDT -999.250 MTEM.LDT 4452.'000 NPHI.CHL 435.143 RCNT.CHL 1.396 M'TEM.CHL -999.2250 AZIM.MSF -999.250 MRES.MSF -999.250 GR.MSF -999.2250 -999.250 -999.250 -999.250 -999.2250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 50.550 1519.603 139.62!5 -999.250 -999.250 -999.250 -999.250 -999.250 -99'9.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 40.821 1534.,551 138.500 -999.2250 -999.250 -999.250 DEPT. 7800.0'00 'TENS.DIL -999.250 SFLU.DIL -999.250 ILD. OIL -999.250 SP.DIL - 999. 250 GR.DIL -99 9.2. 5'0 D'T.BHC -999.250 GR.BHC -999.250 TENS.CNL -999.250 TNRA.CNL -9919.2,50 RTNR.CNL -99'9.2250 RCFT.CNL -999.250 ,CFTC.CNL -999.250 CNTC.CNL -999.250 MRES.CN'L -999.250 HTEN.CNL -9'99.2 50 GR.CNL ,- 999.25'0 TENS.LOT -999.250 DRHO.LD'T -999.250 RHOB.LOT -999.250 PEF.LOT -999.250 ,QSS. LDT -999' 250 LS. LDT - 99'9. 250 LU.LDT -999..250 LITH.LDT -999.25'0 SS1.LOT -999.250 SS2.LOT -999.250 SSHV.LD'T -999.250 S1RH.LDT -999.250 LSRH.LDT --999.250 C~LI.LDT -999.250 AZIM.LDT -999o250 DEVI.'IDT --999.250 P1AZ.LDT -999.250 MRES.LDT -999.250 MTEM.LDT -999.250 GR.LDT -999.250 TENS.CHL 4,~$4. ,rJ Og NPHII.CHL 55.545 RTNR.CHL 5.643 RCFT.CHL 300. :B66 RCNT.CHL 1458.456 CNTC.CHL 1364.6,~2 MRES.CHL 1.410 MTEM.CHL 136.875 ILM.DIL TENS.BHC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LDT RB.LDT HTEN.LDT TNR~.CHL CFTC.CHL HTEN.CHL OEVI.MSF MTEM.MSF ILM.DIL TENS.BHC NPHI,.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSH'V.LDT LURH.LDT RB.LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL DEVI.MSF MTEM.MSF ILM.DIL TENS. 8HC NPHI .CNL RCNT.CNL MTEM. CNL DPHI.LDT Q'LS.LDT L~L. LOT LSHV.LDT LURH. LDT RB .LOT HTEN.LDT T NRA. CHL C FTC. :CHL H'TEN.CHL PAGE: 21 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4.176 3'33.538 -999.2,50 -999.250 -999.250 -999.2250 -999.250 -999.250 -999.250 -999.250 -999.250 -,9'99.250 -999.250, -999.250 -999.250 -999.2!50 -999'~50 3.642 400.48;B -999.250 -999.250 -999.250 -999.Z50 -999.250 -9'99.250 -999.250 -999.250 -999.2:50 -999.250 -999.250 -999.250 -999.250 -9'99.250 -999.250 4.450 317.237 -999o250 IS TAPE YERIFIC.~TION LISTING CHLUMBERGER ALASKA COMPUTING CENTER GR.CHL 126.250 TENS.MSF RB.MSP -999.250 PIAZ.MSF HTEN.MSF -999.250 CALS.MSF DEPT. 7749.000 TENS.OIL ILD.DIL -999.250 SP.DIL DT.BMC -999.250 GR.BHC TNRA.CNL -999.250 RTNR.CNL CFTC.CNL -999.250 CNTC.CNL HTEN.CNL -999.250 GR.CNL DRHU.LDT -999.250 RHOB.LOT .QSS.LDT -999.250 LS.LDT LITH.LDT -999.250 SSI.LOT SSHV.LDT -999.250 SIRH.LDT C~LI.LDT -999.250 AZIM.LDT PIAZ.LDT -999.250 MRES.LDT OR.LOT -999.250 TENS.CHL RTNR.CHL 4.185 RCFT.CHL CNTC.CHL 1348.364 MRES.CHL GR.CHL 96.125 TENS.MSF RB.MSF -999.250 PI,~Z.MSF HTEN.MSP -999.250 C~LS.MSF END DP DATA 1-MAR-1989 1,6:01 -999.250 AZIM.MSF -999.250 -999.250 MRES.MSF -999.250 -999.Z50 GR.MSF -999.250 -999.250 SFLU.DIL -999.250 -999.250 OR.OIL -999.250 -999.250 TENS.CNL -999.250 -999.250 RC~T.CNL -999.250 -999.250 MRES.CNL -999.250 -999.250 TENS.LOT -999.250 -999.250 PEF.LDT -999.250 -999.250 LU.LDT -999.250 -999.250 SS2.LDT -999.250 -999.250 LSRH.LDT -999.2.50 -999.250 DEVI.LDT -999.250 -'999.250 MTEM.LOT -999.~50 4460.000 NPHI.CHL 53.499 283.514 RCNT.CHL 1434.968 1.416 MTEM.CHL 136.375 -999.250 ~ZIM.MSP -999.250 -999.250 MRES.MSF -999.250 -999.250 GR.MSF -999.250 DEVI.MSF MTE'M.MSF ILM.DIL TENS.6HC NPHI.CNL RCNT.CNL MTEM.CNL DPHI.LDT QLS.LDT LL.LDT LSHV.LDT LURH.LD'T RB.LDT HTEN.LDT TNRA.CHL CFTC.CHL HTEN.CHL OEVI.MSF MTEM.MSF PAGE: ZZ -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.2~0 -999.250 -999.250 -999.250 -999.250 -9~9.250 ~.337 313.892 -999..250 -9'99.250 -999.250 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSIDN : 001A02 DA~E : B9703/ 1 MAX REC SIZE : 1096 FILE TYPE :' LO LAST PILE : ~:~ FILE HEADER ~ FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001402 DATE : 89/03/ 1 MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : THIS DATA HAS NOT BEEN DEPTH :SHIF'TED - OVERLAYS FIELD PR'INTS ~~ IS TAPE VERIPICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER ,, 1-MAR-1989 16:01 PAGE: 23 SCHLUMBERGER LOGS INCLUDED WITH T~IS FILE (EDIT.O02): ~ <SEE FILE EDIT.O01 FOR 6" S~MPLED DIL/BHC/LOT/CNLIGR> * MICRO SPHERICALLY FOCUSED LOG (.MSF) * FIRST TO LAST READING: llSBO' TO 10990' * TABLE TYPE : CONS TUNI CN FN WN NATI STAT C gUN SECT TOWN R A N g FL ENGI SON APIN VALU DEFI BP EXPLORATION PRUOHOE BAY Z-ZS' ('11-17-11-12) U S A ALASKA NORTH SLOPE T2~' SNL & 314~' WEL T ! NKH ~M 548412 50-029-21902-00 COMPANY NAME FIELD NAME WELL NAME NATION STATE OR PROVINCE COUNTY SECTION TOWNSHIP RANGE FI!ELD LOCATION ENGINEER'S NAME SERVICE ORDER NUMBER API SERIAL NUMBER TABLE TYPE : CURV DEFI DEPT DEPTH CHANNEL NAME MSFL MSFL RESISTIVITY *,~ DATA FORMAT SPECIFICATION RECORD SET' TYPE - 64EB ** TYPE R:EPR CODE V A L U E ! 6,6 O 2 66 0 3 73 8 IS T~P'E YERIFICATION LISTING CHLUMBERGER ~LASKA COMPUTING CENTER ,, 1-MAR-1989 16:01 TYPE REPR CODE VALUE 4` 66 5 66 6 73 ? 65 B 68 0.166 9 65 FT 11 66 13T 1Z 68 13 66 O 14, 1.5 66 68 16 66 1 0 .66 1 ~- SET TYPE - CHAN ~ NAME SERV UNIT SERVICE API API API AP~ FILE NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLASS MOD NUMB S~MP ELEM CODE DEPT FT 548412 O0 000 O0 0 2 I I 4, 68 MSFL MSP DHMM 548412 O0 000 O0 0 2 1 1 4 68 PROCESS (HEX) 0'000000000 0000000000 PA(;E: Z4 DEPT. 11610.832 MSFL.MSF 17-125 DEP'T. 11600.000 MSFL.MSF 17.125 DEP'T. 11500.000 MSFL.MSF 12.625 DEPT. 114,00.000 MSFL.MSF 30.914 DEPT. 11300.000 MSFL.MSF 27o77'? DEPT. 11200.000 MSFL.MSF 9.094 DEPT. 11100.000 MSFL.MSF 19.531 DEPT. 11000.000 MSFL.MSF 18.13'7 DEPT. 10974.500 MS~L,.MSF 0.4`71 END OF DA'TA ~ IS "TA'P~E VER'IEICATION LISTING CHLUM~ERGER ALASKA COMPUTING CENTER ., ~,*~ FILE TRAILER ~'~ EILE NAME : EDIT .002 SERVICE : FLIC VERSION : OOIA02 DATE : ~9/03/ 1 MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : 1-MAR-1989 16:01 PAGE:' 25 · ~ TAPE TRAILER SERVICE NAME : EDIT DATE : 89/03/ DRIGIN : FLIC TAPE NAME : 73156 CONTINUATION ~ : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATT. DN Z-25 (11-1T-11-12)~ API #50-029-21902 · '~ REEL 'TRAILE~ :~:~ SERVICE NAME : EDIT DATE : 89/0:3/ 1 ORIGIN : FLIC REEL NAME : 73156 CONTINUATION ~ : PREVIOUS REEL : CDMME'NT : BP EXPLORATION Z-25 El1-17-1I-I2), API #50-029-21902