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191-134
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:Regg, James B (OGC) To:PB Wells Integrity Cc:Oliver Sternicki Subject:RE: 04-40 K-valve question Date:Thursday, August 8, 2024 3:36:00 PM PBU 04-40 (PTD 1911340) can be produced up to 14 days without a K-valve to facilitate an updated valve design. The SVS components at surface (LPS, SSV) must be function tested before and pass a performance test not later than 5 days after the well is put online. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Thursday, August 8, 2024 1:40 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: 04-40 K-valve question Mr. Regg, Producer 04-40 (PTD #1911340) requires a SSSV in accordance with 20 AAC25.265 (d). The well is not configured for a surface controlled SSSV so historically a K-valve has been utilized to comply with regulation. The K-valve was pulled in September 2019 for intervention work which included logging and perforating. The plan in 2019 was to use the updated production rates after the adperf to redesign the K-valve. The well came online and was not competitive due to high GOR and was shut back in before a K-valve was set. A cement squeeze was performed in June of 2021 but when trying to flow the well it kept dying off due to high water cut and was shut-in before a K-valve was designed and installed 04-40 is no longer receiving PWI support so the water production rates are expected to be reduced compared to the last time it was online in 2021. The Operations Engineer would like to get the well online and get a new K-valve design. Can we flow the well up to 14-days without a K-valve to get updated rates for a new valve design? Please respond at your earliest convenience Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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. Originated: Delivered to:2ͲMayͲ24Halliburton Alaska Oil and Gas Conservation Comm.Wireline & PerforatingAttn.:Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska99501Anchorage, Alaska 99518Office: 907Ͳ275Ͳ2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#11DͲ117 50Ͳ029Ͳ22844Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 21ͲAprͲ24 0 121EͲ05A 50Ͳ029Ͳ20479Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 2ͲAprͲ24 0 131HͲ102 50Ͳ029Ͳ23580Ͳ00 909266407 Kuparuk River Multi Finger Caliper Field & Processed 22ͲAprͲ24 0 142BͲ03B 50Ͳ029Ͳ21151Ͳ02 909270379 Kuparuk River Perforation Record FieldͲFinal 11ͲAprͲ24 0 152CͲ12 50Ͳ029Ͳ21222Ͳ00 n/a Kuparuk River Leak Detect Log FieldͲFinal 29ͲAprͲ24 0 162DͲ13 50Ͳ029Ͳ21070Ͳ00 909258948 Kuparuk River Leak Detect Log FieldͲFinal 11ͲAprͲ24 0 172DͲ13 50Ͳ029Ͳ21070Ͳ00 909258948 Kuparuk River Multi Finger Caliper Field & Processed 9ͲAprͲ24 0 183GͲ24 50Ͳ103Ͳ20145Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 8ͲAprͲ24 0 193JͲ14 50Ͳ029Ͳ21496Ͳ00 909238639 Kuparuk River Leak Detect Log FieldͲFinal 7ͲAprͲ24 0 110 3JͲ14 50Ͳ029Ͳ21496Ͳ00 909238639 Kuparuk River Multi Finger Caliper Field & Processed 6ͲAprͲ24 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T38757T38758T38759T38760T38761T38762T38762T38763T38764T3876483GͲ2450Ͳ103Ͳ20145Ͳ00 n/aKuparukRiverPlugSettingRecordFieldͲFinal8ͲAprͲ24 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:191-134 6.50-029-22224-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9643 9329 8731 8317, 8425, 9315 9379 7834, 7926, 8719 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 32 - 110 32 - 110 1490 470 Surface 3458 10-3/4" 32 - 3490 32 - 3489 5210 2480 Intermediate 8998 7-5/8" 30 - 9028 30 - 8459 6890 4790 Production Perforation Depth: Measured depth: 9330 - 9510 feet True vertical depth:8733 - 8892 feet Tubing (size, grade, measured and true vertical depth)4-1/2" x 3-1/2" x 2-7/8" 13Cr80 28 - 9392 8317, 8425, 9315 7834, 7926, 8719Packers and SSSV (type, measured and true vertical depth) Baker S-3, SB-3A Hyd, FB- Perm Liner 906 5-1/2" 8737 - 9643 8200 - 9009 7740 6280 12. Stimulation or cement squeeze summary: Intervals treated (measured): 31 bbls Class G, 3200 psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1341132534170 13370 1852 27910 1 746 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Authorized Name: Authorized Title: Authorized Signature with Date:Contact Phone: Treatment descriptions including volumes used and final pressure: 13. Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9009 Sundry Number or N/A if C.O. Exempt: Junk Packer Printed and Electronic Fracture Stimulation Data Operations shutdown Change Approved Program 9089 - 9099, 9184 - 9189 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028325 PBU 04-40 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Bo York Sr Operations Manager Torin Roschinger torin.roschinger@hilcorp.com (907)564-4887 N/A By Samantha Carlisle at 9:26 am, Jun 30, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.06.29 18:13:41 -08'00' Bo York MGR30JUL2021 RBDMS HEW 6/30/2021DSR-6/30/21 SFD 6/30/2021 ACTIVITYDATE SUMMARY 1/6/2021 ***WEL S/I ON ARRIVAL*** DRIFTED CLEANLY W/ 5' x 2.125" STEM, AND 2.25" CENT THROUGH TARGET DEPTH OF 9050' MD. TAGGED @ 9240' MD (~49' ABOVE CMT RETAINER). **WELL LEFT S/I ON DEPARTURE*** 6/1/2021 CTU#6 1.75" CT Job Objective: Cement Perf Squeeze. MIRU SLB CTU#6. Completed weekly BOP testing. Close lateral valve on production line, PT wing valve 2600 psi - good. Drift CTC/BHA. 6/2/2021 CTU#6 1.75" CT Job Objective: Cement Perf Squeeze. Make up BHA = 1.75" Cold Roll CTC, 2" Stingers, 2.25" BD JSN (5/8"). Bullhead 180 bbls of 1% slick SKI w/SL down tubing followed by 90 bbls of diesel. RIH w/2.25" JSN, tag WFT CMT Retainer @ 9,272' ctm. Paint flag. PU 10' & establish step rate baseline injectivity down coiled tubing into formation. HES pumped 30bbls of cement down CT, layed in cement to the top of 3.5" crossover at 8,661. Squeezed 3bbls of cement into perforations before WHP locked up at 3,100psi, shut down pump to monitor but WHP did not fall off. Lay in remaining cement and then contaminated with 50bbls of gel over 2 passes down to 8,750'. RBIH to 8,750 and circulate cement out of well, pumped an additional 25bbls of gel while chasing OOH, slowing down to jet jewelry on the way out. Make up TBird Milling BHA = 2.30" PDC Mill. RIH w/milling BHA, tagged up 8,332' ctm. Begin milling cement. ***Job in Progress*** 6/3/2021 CTU#6 1.75" CT Job Objective: Cement Perf Squeeze. Continue milling cement w/2.30" PDC mill 8,332' ctm - 9,215' ctm. Consistent 1:1 returns. Pumped 5 bbl gel sweeps and chased up to 3.5" x 2.875" XO while back reaming. Mill down to 9,265', pum p gel sweep and chase up hole. Performed LOT to 1,000psi on squeezed perfs, lost 68psi in 10 minutes. Verified LOT with OE and proceeded with milling operations. RBIH and resumed milling, made it down to 9,281' before getting frequent stalls near retainer depth. POOH and inspected tools, found missing buttons on mill and wear on the side. C/O motor & mill = 2.30" junk mill. RIH w/milling BHA, mill through WFD cement retainer @ 9,289' MD, maintain 1:1 returns w/gel sweeps. Back ream/wiper trip up to 8,400' ctm, mill through WFD CBP @ 9,329' MD. Lost WHP and returns, make wiper trip up to 8,400' to verify 2-7/8" tbg is clear above. RIH and tag 2.205" XN nipple @ 9,373' ctm, stalled mill twice to verify no CBP debris. Pooh w/BHA. ***Job in Progress*** 6/4/2021 CTU#6 1.75" CT Job Objective: Cement Perf Squeeze. Pooh w/BHA. At 8,400' ctm (4.5" tbg), 10 bbls gel out BHA, bullhead 30 bbls of SKI down CTBS to verify injectivity and flush 2-7/8" Tbg. FP tubing w/38 bbls of diesel while Pooh. RDMO CTU6. ***Job Completed*** Daily Report of Well Operations PBU 04-40 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:191-134 6.50-029-22224-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9643 92 7854 none 9289 , 9329 7834 , 7926 , 8719 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" 32 - 110 32 - 110 1490 470 Surface 3458 10-3/4" 32 - 3490 32 - 3489 5210 2480 Intermediate 8998 7-5/8" 30 - 9028 30 - 8459 6890 4790 Production Perforation Depth: Measured depth: 9089 - 9189 feet True vertical depth:8514 - 8605 feet Tubing (size, grade, measured and true vertical depth)4-1/2" x 3-1/2" x 2-7/8" 13Cr80 28 - 9392 8317,8425,9315 7834,7926,8719Packers and SSSV (type, measured and true vertical depth) Baker; S-3, SB-3A Hyd, FB-1 Perm Liner 906 5-1/2" 8737 - 9643 8200 - 9009 7740 6280 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 142452938522036879 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Torin Roschinger Torin.Roschinger@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:907-564-4887 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9009 Sundry Number or N/A if C.O. Exempt: 319-332 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028325 PBU 04-40 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 8317 , 8425 , 9315 NO SSSV 49 24622 126 1184 898 This 10-404 Sundry is closing out the associated 10-403 Sundry #319-332, although the last step to set the K- valve was never installed. The subsequent well tests to design the K-valve, proved to be uneconomic and setting the K-valve was postponed to date. New well work is planned for 04-40, and installation of a new K-valve will be included with the follow up 10-404 Sundry Report for that work. By Samantha Carlisle at 9:22 am, Nov 12, 2020 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.11.10 19:25:58 -09'00' Bo York SFD 11/17/2020DSR-11/13/2020 RBDMS HEW 11/12/2020MGR13NOV2020 ACTIVITYDATE SUMMARY 9/17/2019 ***WELL S/I ON ARRIVAL*** (Perforation) RIG UP SWCP 4517 ***CONT WSR ON 9-18-19*** 9/18/2019 ***CONT WSR FROM 9-17-19*** PULL 45 KB PKR W/ K-VALVE ATTACHED FROM 1,914' SLM DRIFT TO 9,124' SLM W/ 36' x 2.16" DMY PERF GUNS BAIL FROM 9,124' SLM TO 9,230' SLM ***CONT WSR ON 9-19-19*** 9/19/2019 ***CONT WSR FROM 9-18-19*** CONT BAILING 9,230' SLM TO 9,250' SLM ***CONT WSR ON 9-20-19*** 9/20/2019 ***CONT WSR FROM 9-19-19*** BAIL WITH 2.25'' AND 1.75'' DRIVE DOWN BAILERS THROUGH CEMENT FROM 9249' TO 9254' SLM. DRIFT W/ 30'x2.16'' DUMMY GUNS, TAG CEMENT RETAINER AT 9254' SLM. ***WELL TURNED OVER TO DSO*** 9/24/2019 ***WELL SHUT IN ON ARRIVAL*** SPOT IN EQUIPMENT, PERFORM LTT, PREP FOR PNC3D/CO/BORAX LOGGING ***CONTINUED ON 25-SEP-19 WSR*** 9/25/2019 T/I/O-= 1937/1457/vac (Assist E-line with RPM log) Pumped 3 bbls 60/40 Meth spear followed by 160 bbls 1%KCL to load TBG. Pumped 310 bbls 1%KCL while Eline logs followed by 150 bbls borax down tbg. Then pumped 150 bbls of 1 % KCL to flush borax into formation. Job continued on 09/26/19. 9/25/2019 ***CONTINUED FROM 9/25/19 WSR*** LRS PERFORM L&K. RIH W/ 1.69" BAKER RPM TOOL. PERFORM TWO x PNC3D PASSES FROM 8,550'-9,280' AT 10 FPM PERFORM THREE x C/O PASSES FROM 9,000'-9,280' AT 2FPM LRS PUMP BORAX PILL, WHILE LOGGING FIRST BORAX PASS AT 25 FPM, BAKER RPM TOOL FAILED. POOH. ***CONTINUED ON 9/26/19 WSR*** 9/26/2019 (Job continued from 09/25/19) Assist E-Line with RPM Log. Pumped 150 bbls 1% KCL to flush borax out to formation. Pumped 30 bbls 1%KCL to fluid pack TBG. Further pumped 76bbls of borax down TBG. E-Line had equipment issues had to start borax portion over again. Pumped 30 bbls 1%KCL followed by 130 bbls of borax down TBG. Then pumped 337 bbls KCL down TBG while E-line logged. **Job continued 09/27/19*** 9/26/2019 ***CONTINUED FROM 9/25/19 WSR*** LRS PUMP BORAX PILL. LOG BAKER RPM BORAX PASSES FROM 9,280' TO 8,500'. LRS PUMP 1% KCl FOR BORAX FLUSH. ***CONTINUED ON 9/26/19 WSR*** 9/27/2019 ****Job continued from 09/26/19***(Assist E-line with RPM log) Pumped 15 bbls of 1% KCL while E-Line continued to log. Then pumped 165 bbls 1 % KCL to flush the borax from tubing. Freeze protected well with 27 bbls crude and 12 bbls 50/50 meth. E-Line still on well upon departure. FWHP=423/1210/0 Daily Report of Well Operations PBU 04-40 Daily Report of Well Operations PBU 04-40 9/27/2019 ***CONTINUED FROM 9/26/19 WSR*** FINISH BORAX LOGGING. PUMPED FLUSH VOLUME AND VERIFIED BORAX IS AWAY FROM WELLBORE. PERFORATE FROM 9,184' - 9,189', W/ 2" MAXFORCE GUNS. 60* PHASING AND 6 SPF. ***WELL S/I ON DEPARTURE. NOTIFY PAD OP*** 4/25/2020 T/I/O= SSV/1500/0 Freeze Protect FL (WELL TEST) Pump 3 bbls 60/40, 50 bbls crude to freeze protect Pump 1 bbl 60/40 to pressure up to 1500 psi FWHPs=SSV/1500/0 BA ER PRINT F IGHES BAT GE company COMPANY BP Exploration Alaska Inc. WELL NAME 04-40 FIELD Prudhoe Bay Unit COUNTY North Slope 191134 31346 DISTRIBUTION LIST Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, 1112-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.com to acknowledge receipt of this data. LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska --- LOG DATE September 25, 2019 AUTHORIZED BY Dirk Zeijlemaker EMAIL Dirk.zeiilemaker@bakerhughes.com TODAYS DATE October 18, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NOT DELIVER TO P.O. BOX) PERSON ATTENTION V BP North Slope. FOA. PBOC, PRB-20 (Office 109) D&C Wells Project Aids Agatha Rutka & Barbara Glassmaker 900 E. Benson Blvd. Anchorage. Alaska 99508 2 Conoco Phillips Alaska Inc. Attn: Ricky Elgarico ATO 3-344 700 G Street Anchorage, AK 99501 3 1 Exxon Mobil, Alaska Attn: Lynda M. Yaskell and/or Lisa Boggs '13201 C Street, Suite 505 Anchorage, AK 99503 FIELD/ FINALCD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY REPORT LOGS CGM, Final Surveys) (Compass) # OF PRINTS # OF COPIES # OF COPIES # OF COPIES J; 4 I 4 lu RE AOGCC 4 6tate of Alaska - AOGCC 1 1 Attn: Natural Resources Technician 11 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 5 DNR - Division of Oil & Gas •*• 'I Attn: Garret Brown 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 6 BP Exploration (Alaska) Inc. L Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Attn: David Itter 0 TOTALS FOR THIS PAGE: 0 1 4 0 0 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Meredyth Richards Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-40 Permit to Drill Number: 191-134 Sundry Number: 319-332 Dear Ms. Richards: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.oloska.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, Jessie L. Chmielowski Commissioner DATED this 19' day of July, 2019. g13DMS±'�'JUL. 18 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 R NE 07s' ✓/ 7117 JUL 12 2019 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Opera'on h= Suspend ❑ Perforate m Other Stimulate ❑ Pull Tubing ❑ Change Ap o Plug for Rednll ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other Design K Valve 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development m 5. Permit to Drill Number 191-134 3, Address: P.O. Box 196612 Anchorage, AK 99519-8612 St2tigraphic ❑ Service ❑ 8. API Number: 50-029-22224-0040 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ Nom PBU 04d0 9. Property Designation (Lease Number). I 10, Field/Pools: ADL 028325 ' 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): 9643 9009 9289 8695 9289.9329 None Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" 32-110 32-110 1490 470 Surface 3458 10-3/4" 32-3490 32-3489 5210 2480 Intermediate 8998 7-5/8" 30-9028 30-8459 6890 4790 Production Liner 906 5-1/2" 8737-9643 8200-9009 1 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 9089-95111 851 - 8892 4-1/2" x 3-1/2" x 2-718" 13CB0 28-9392 Packers and SSSV Type: 4-112" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 8317 / 7834 312" Baker SB -3A Hyd Packer 8425/7926 2-718" Baker FB -1 Perm Packer 9315/8719 45KB PKR WITH HES K -VALVE 193911939 12. Attachments: Proposal Summary m Wellbore Schematic m 13. Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development m Service ❑ 14. Estimated Date for Commencing Operations: data 20, 2019 15. Well Status after proposed work: TLL Oil m • WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: �'iL$'f19 GAS ❑ WAG ❑ 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: Richards, Meredyth be deviated from without poor written approval. Contact Email: Meredyth.Richardsabp.com Authorized Name: Richards, Meredyth Contact Phone: +1 9075644867 Authorized Title: Petroleum Engineer Authorized Signature: /A �� Date: I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: IJ vl �i Plug Integrity ❑ BOP Test ❑ Mechanical Integnty Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 2" Subsequent Form Required: /Q `%� APPROVEDBYTHE Approved by: COMMISSIONER COMMISSION Date. W/ rX 0 RBDMS &iut. 19 2019 ORIGINAL ��oval, 7� At Submit in DForm and Form 10403 Revised 0412017 Approved application is valid for 12 months from the date o approval. C q�achments in Duplicate �B �/�►q 10-403 Sundry Application for Well PBU 04-40 PTD# 191-134 Expected Start Date: July 20, 2019 V Current condition of well: Gas Lift Producer, Operable, Offline: Oil rate 326 bopd Gas Rate: 33020 Mscf/da Water Rate: 2191 bw d FTP: 1373.9 psi Shut-in Wellhead Pressure: 2340 psi Reservoir Pressure: 3333 psi Well objective(s): 04-40 is an uncompetitive producer with < 40% 12 -month on time due to HGOR. Recent petrophysical review of DS -04 and DS -11 suggests potential for an oil lens within the upper Victor package in the area. This program aims to confirm the presence (or absence) of this potentially -bypassed oil and, should it exist, modify 04-40's profile to enable effective production. Due to the anticipated change in production following the adperfs, a revised K -Valve design is necessary. • Identify bypassed oil in the Victor package at 04-40 • If bypassed Victor Oil exists, add Victor perfs then, if productive, isolate gassy 43P perfs • Confirm cement integrity (i.e. no channels to Victor or breakdown in Z3 squeezed perfs) • Set K -Valve per revised design from GLE Proposed program: 1. Pull K -valve. D&T cement retainer (-9,289 ELM) with 2" dummy guns. 2. Assist EL with logging: load tubing with 1 % KCI for C/O with gas view passes and then pump Borax slugs for Borax passes as per attached pump schedule. 3. Perform C/O with gas view and Borax logging. Town to finalize pert depths as soon as data is reviewed. 4. Due to the anticipated change in production following the adperfs, a revised K -Valve design is necessary. This new design depends upon updated well tests performed during a temporary flowback period without a K -Valve. The GLE will coordinate these tests and then use their results to size a new K -Valve that will then be installed. Sundry approval for this work will be in -hand prior to job scheduling. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 04-40 PTD# 191-134 Minilog: 0 Producer Minilog , echlDg Well: 04-40 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 .hham► i�� aw- maw-- ON �I ��J��1 � CJS-- � .►�� � 7 ! ��mmiumc, BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 04-40 PTD# 191-134 Perforation Form: woPENDING PERFORATING PROCEDURE 9edentien $pmmary 910bot wallala orpanazaSaOo Well'. O:aO W<It. 0"0 :914 {90]1 W1 7rxf Leel_ Dare 6/IS/2019 9 f 0.1.. M.-oih etaxt $ec>EahN 190i� X20 Moue 10A TYPE v/m Dep:..o.+m 350 ANSee ebeaun 0.Mxim aenY:a-e-: .a a-6rc +_pon (;O blyy rtvhz PenerY:cMLJeepmnsdtrc:pp ane 9nrepryzaxxrlaWN-M ,.x CO ueem.e6 Data:me:ebwn A9aD:uut><x tnevon pe P�dh erettx:ce rb epaa eren;�ae glnr6Pe:axN�rcnr-ape},late.vrt te[>nR:he ten+tK re;'n VatroRrY'r aevyae ba:eb Me. rna.e>D' dpeA; n a 30' mp HI xaen rtiy. err, sa:b ee.er d aseal�ce:d pq1 iac TMe < ac�arce:nxtneen�xbn wall baa ro a eecaan-e roe xbaa wetpae w.' 9e:serce ro9 6M6 LOG. DLTE.12/1/199 [empna' AD Tie' 1e6 a6e -2 s rotYetl.n ebb peen Oe9a wrtY!Fe rt4rtneiq het Sp D�erexv 9axn6 Sere K0.f ttK 3P3D:+ra,6e 6 mean 60' 129f:t9l319 :DD Kiif 9aeuettG G,n Sae 2'160 aar, Vewe•lev Mr. w'e:e :o 221 M1la 9ner ,lµe. Lw Ma Swot ,Ga: 321' I: Draw[eun lle[eKarYlDeiRe/UnrcCcarY W nn6 ier!Mene 90t+reJ:nwr. d P•raewrvSa36eewx ro Ye ee pawabwn l Onh. 9106 RMDm 4YWw10 Ge Wp. Reaurt �4 S..MO'TN.: MDp 3333 m BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 9edentien $pmmary 5:,...a- D:[ Well'. O:aO 9aefnOr. sewn Daa :aa SD02i22321A10 96N anc �r O.D. teem ,q,r GaeN Cemmerea- OeRh: Gvn pa Orcn�tbn 5K 9naan6 .erw appeAlPrpeA ealarte Rdereaae to encs o/e/u o/e/u o/e/u o/e/u 0/e/u o/e/u Ole/u o/e/u O/6/u BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Tie -In log: 10-403 Sundry Application for Well PBU 04-40 PTD# 191-134 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 04-40 PTD# 191-134 Maximum Recorded BHT Circulation Stopped Time Logger On Bottom - Time LMR Number Location Recorded B Witnessed By 5 -DEC -1991 03:50 05 -DEC -1991_ 0955 2005 1 PRUDHOE BAY G. SARBER(H, HAMMOND_ BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 BHC SONIC - GR 0 w Z V - qQY Schkimberger O m CO U) U) O Z r _ = u- Q j M C) Q N u) ¢ Z a O Q 0 a z O < U 1269 FNL, 307'FEL (AT SURFACE) Ebv.: KB. 80 F G.L 27 F D.F. 59 F Permanent Datum. _MEAN SEA LEVEL _ Log Measured From FKB _ Drilling Measured From: RKB Elev.: 0 F 80.0 F above Perm. Datum pg s = E m u' 8 API Serial No. 50-029.22724 SECTION 34 TOWNSHIP 11N RANGE 15E Logging Date ._ _ 05 -DEC -1991 _y .. - ---- , --- Run Number --.--- 9643 F ------ ----- -- DepM Driller ---- --- Schlumberger Depth 9632 F 9557 F Bottom Log Interval 9018 F T LOU Interval 7.6251N -p Gado Driller Size @ Depth Casin Schlumberger 9018F BR Size &7501N — — — --_ - T pe'FluidIn Hob LSND ------------- Density-- Vbcos 9.4 LB/G 44 S Fluid Loss PH ------.___._ 8.2 C3 9.5 .._ Source Of Sample - - CIRCULATED FIM (a7 Measured Temperature 2.7000HMM (ay7 58 DEGF (� RMF 0 Measured Tem a e ----------— --- 2.520 OHMM _--- C� 5e DEGF +� 2.500 OHM M 0 _58 DEGF - RMC Q Measured Tem afore F� �gMU MEAS URQ RM CBHT RMF (n) BHT 1.068 @D157 0.W7 157 Maximum Recorded BHT Circulation Stopped Time Logger On Bottom - Time LMR Number Location Recorded B Witnessed By 5 -DEC -1991 03:50 05 -DEC -1991_ 0955 2005 1 PRUDHOE BAY G. SARBER(H, HAMMOND_ BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 10-403 Sundry Application for Well PBU 04-40 PTD# 191-134 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 TRfE= aW WELLHEAD= 'ACTUATOR= OKE. ELEV = BF. EEEV = FMC BAKERC 60' ? KOP= 4500 Alox Angle = 33' @ 6700' Dabrm MD= 9474' Datum ND= 880(7 SS CONDUCTOR -100 41, H-40, 19.124- VXNP. D=2.313' ---f 20' BOWED CSG PATCH{ D = _•? 1� 3186' - 3190' (' 163/4• CSG, 45.5/1, L-80, D - 9.953' 3492' Minimum ID = 2.205" @ 9379' 2-718" OTIS XN NIPPLE 4-117 TBG 12.6#, 13CMG VAMTOP, .0152 bpf, D= 3.958' 13-1/Z-MULP5HOF. D = 2.992- -j U46' 5'X 3-1/2- XO, D=3A0- W 3-12' TBG, 9.39, 13CR FOX. G087 bpf, D = 2.992' 8696' 5-12' TIEBACK SLV, ID 5.75?' 8737' 7 -SIB' X 5-12' PKR & LNR HGR D = 5.875?' 8746' 7-5/8- CSG, 29.7#, L-80 BTC -M, D = 6.875' 903W PERFORATION SLA&KRY REF LOG: BHCS ON 12/05/91 ANGLEATTOPPERF: 25'@9089 tate' Refer to Production DB for historical pert data SIZE I SPF I MERVAL I Opn/Spz I SHOTT SOZ -SEE PG 2 FOR PERF SLIA& ARY- 12-7/8' TBG 6.4#, 13CR-80, FOX .0058 bpf, D - 2.441' 5-1/2' LW 17#, 13CWSO..0232 bof. D = 4.892' SAFETY N07fi : WELL REQURES A SSSV "' CHROME LNR & TBG " 3131 ' 7-5/8' FES 6 CEMENTER 3164' 7-5/6' WFETNAL CS PKR GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCHI PORT DATE 8 2833 2832 2 TEl&FD DONE 8K 16 07/14/18 7 4537 4532 12 TE -TW DMY BK 0 04/15/09 6 5236 5192 25 TETMPD DOW BK 16 07114/18 5 5935 5799 31 TE-TMK DAM BK 0 05/24114 4 6425 6218 32 TE -TW DMY BK 0 04/15/09 3 6872 6596 31 TE -TWE DAM BK 0 04/15109 2 7361 7012 31 TE -TWE DMY BK 0 04/15109 1 7806 7396 30 TE -TW DAM BK 0 04/15/09 /2" HES X NP, D=3.813' 1/2' X 2-7/8- X NP R®, D �/8- X 3-1/2- BKR SB -3A F 2' X 3-12'X0, D = 2.99, PRODUCTION MANORBS I'�7H�i44i■ STI MD I ND I DEVI TYPE I VLV I LATCH PORT DATE 9 10 8595 8669 8075 8139 1 29 28 1 TE-TGPDX I DMYRK TE-TGFDX DMY RK 1 0 0 02/14/17 02/14/17 8693' 8696' 9300' - 9310' 9316' 1 9392' 1 DATE REV BY COMBOS DATE REV BY COMMENTS 12/11191 N28E OFBGINALCOMPLErION 09120/18 JWAV FILLED XX PLUCVSEr LOWER PATCH 04116/09 D14 RWO OWMI18 ZV/JbD SEr PATCH w/K VALVESET LPPER PATC 05101118 JPK/J&D GLV GO (0428118) 06125/18 ZV/JAU GLV CIO (0620118) 07/16/18 GJBIJMD SET NP RED&XX PLUG (07/14118) 07/17118 GJBIJMD GLV C/O (07/14118) 11 PKR SWN NP, D=2.7: X 2-7/8- XO, D = 2.44- r DEPTH BY E m sm D = 3.50' D - 2.44' PRLCHOE BAY LINT WBL 0440 1 PERMT W: 1911340 AR No: 50-029-2222400 SEC 34, T11 N, R15F_ 1268' FNL & 306' FFL BP Exploration (Alaska) • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,April 29, 2018 9:07 AM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; G GPB FS2 Drillsites; Nottingham, Derek;Ohms, Danielle H; Stechauner, Bernhard; Summers, Matthew Cc: Wallace, Chris D (DOA);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; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: NOT OPERABLE: Producer 04-40(PTD# 1911340) Leak Found in Production Tubing All, Producer 04-40(PTD#1911340)was placed Under Evaluation on 04/11/18 for having sustained inner annulus casing pressure above NOL and a failing cold TIFL.On 04/12/18 the well also failed a warm TIFL. On 04/27/18 Slickline set new LGLVs but the IA pressure would not bleed down.A TTP was set and the well passed a CMIT-TxIA to 2,556 psi, but a leak was identified in the production tubing by a D&D hole finder.The leak is around the safety valve landing nipple @ 2,016' MD. Due to the compromised primary barrier,the well is now classified as NOT OPERABLE and will be left secured with a TTP. Please respond with any questions. Andrew Ogg SCAMS) Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 From: AK, GWS - I Integrity Engineer [mailto:AKGWOWellSiteEnginee@bp.com] Sent: Wednesday, Apr 2018 1:10 PM To: AK, OPS EOC Specialists,° OPS FS2 DS Ops Lead;AK, OPS FS2 Facility OTL;AK, OPS FS2 Field OTL;AK, OPS FS2 OSM;AK, RES GPB East Wells Opt •AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS2 Drillsites;Richards, Meredyth;'Regg, Jame ; DOA) (Jim.regg@alaska.gov)' Cc: AK, GWO Completions Well Integrity;AK, 9 PHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Informatio ,:K, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A;Daniel, Ryan;Dempsey, David G;Dickerman, Eric;Hibbert, hael;Janowski, Carrie;Montgomery,Travis J;Munk, Corey;Obrigewitch, Beau;O'connor, Katherine;Romo, Louis A;Ste ki, Oliver R;Tempel, Joshua;Worthington, Aras J;'ch ris.wal lace@a laska.gov' Subject: UNDER EVALUATION: Producer 04-40 (PTD# 1911340) Sustaine• •. er annulus casing pressure above NOL All, Producer 04-40(PTD#1911340)was reported to have sustained inner annulus casing pressure abo - OL 4/10/2018. The pressures were confirmed to be T/I/0=2360/2370/Opsi. The well failed a subsequent co . IFL on 4/11/18 indicating a potential loss of one or more well barriers. At this time the well is reclassified as Under Ev. ation and is on the 28 day clock for diagnostics and repair. 1 STATE OF ALASKA � • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set K Valve m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 191-134 3. Address: P.O.Box 196612 Anchorage, Development El Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22224-00-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PRUDHOE BAY UNIT 04-40 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9643 feet Plugs measured 9289/9329 feet true vertical 9009 feet Junk measured feet APR 0 4 2017 Effective Depth: measured 9289 feet Packer measured See Attachment feet true vertical 8695 feet Packer true vertical See Attachment feet 1OG 4"/ Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3460 10-3/4"45.5#L-80 31 -3491 31 -3490 5210 2480 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 906 5-1/2"17#13Cr80 8734-9640 8197-9006 7740 6280 Perforation Depth: Measured depth: See Attachment feet t°)A t` '„ :' s`p��E True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"K Valve 2016 2016 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: 70 1140 6167 1818 523 Subsequent to operation: 799 35483 0 1280 889 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations Ed Exploratory ❑ Development Ir Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-109 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature l� Phone +1 907 564 4424 Date 4/4/17 Form 10-404 Revised 5/2015 V T(- ,-7/0!/-7- 1L 2 f 7R B D M S [,, AIR - 5 2017 Submit Original Only • • OL 2 W C N CL d O 3 fl. 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E. » C) G E. 6 cn 9 g / � ¥ \ & / # f \ \ r \ < TREE CM/ • S NOTES: WELL REQUIRES A SSSV ""CHROME ' WELUEAD= FMC 04-40 LNR&TBG"' ACTUATOR= BAKER C 1 ELSr,,,2 0 f 2016' H 4-1/2"HES X NP,D 3.813" I BF.KOP= 4500' 20"CONDUCTOR — —100 I1� 2016' —I4-112'HES K VALVE(03117117) 4.4 Max Angle= 33'@ 6700' 91.5#,FI-40, '1_ Oi 3132' -17-5/8"HES ES CEMENTER Datum MD= 9474' L1=19.124" 14, Datum TVD= 8800'SS iiii _. I 3164' --17-518"EXTERNAL CS PKR J EBK CSG,29.7#,L-80 TCI,D=6.875" 3186' 1 GAS LFT MANDRH_S �_75/8 T ._. ��---- / ST MD TVD DEV TYPE VLV LATCH PORT DATE 17-5l8'BOWEN CSG PATCH,ID=_"? — 3186'-3190'/ 8 2833 2832 2 TE TMPD DOME BK 16 05/28/14 . l 7 4537 4532 12 TE-TMPD DMY BK 0 04/15/09 10-3/4"CSG,45.5#,L-80,D MI =9.953" — 3492' 6 5236 5192 25 TE-TD SO BK 20 05/28/14 5 5935 5799 31 TE TMPD DMY BK 0 05/24/14 4 6425 6218 32 TE-TMPD DMY BK 0 04/15/09 3 6872 6596 31 TE-TMPD DMY BK 0 04/15/09 Minimum ID =226" @ 9379' 2 7361 7012 31 TE-TMPD DMY BK 0 04/15/09 2 7/8" OTIS XN NIPPLE 1 7806 7396 30 TE TMPD DMY BK 0 04/15/09 8296' —14-112"HES X NP,D=3.813" MAC 8317' —17-518'X 4-1/2'S-3 PKR,D=3.87' 8341' —L44-1t2"HES X NI',D=3.813' , 8426' —17_518 X 3-1/2 BKR SB 3A HY D Fi(R,ID=3.00 I 4-1/2"TBG, 12.6#,13CR 80 VAM TOP. 8436' 8436' —14-1/2"X 3-1/2 XO,D=2.992" i 0152 bpf,ID=3.958" 8445' 1-5"MLLOUT EXTH+ISION,D=4.50" \ MIJ 8446' H3-1/2" LESHOE,D=2.992" L 8450' —{5"X 3-1/2"XO,D=3.00" PRODUCTION MANDRELS 3-1/2"TBG,9.3#,13CR FOX,.0087 bpf,D=2.997 H 8696' ST MD TVD DEV TYPE VLV LATCH FORT DATE 9 8595 8075 29 TE TGPDX DMY RK 0 02/14/17 5-1/2"TIEBACK SLV,D=5.75?"— 8737' 10 8669 8139 28 TE-TGFOX DMY RK 0 02/14/17 7-5/8"X 5-1/2"PKR&LNR HGR D=5.875?' —I 8746' 8693' --13-1/2'PKR SWN NP,D=2.75" J 7-5/8"CSG,29.7#,L-80 BTC-M,D=6.875" —I 9030' 8696' I-13-1/2"X 2-7/8"XO,13=2.44" 11 ''11'1 1 f 1'"• 8764' —{IA CMT DEPTH BY ELINE SCMT 2/12/17(2/9/17) PERFORATION SUMMARY 1111/ 111111 REF LOG: BHCS ON 12/05/91 II111� / 11.' ,.... 9204'-9222' --I2-7/8'BLAST JOINTS,ID=2.44" ANGLE AT TOP PERF: 25'@ 9089' I �1; 9289' ELM 2-7t8"VVFD CMT RET(01126/17) Note:Refer to Roduction DB for historical pert data ��,1e ��........._.__--_-- SIZE SPF NfERVAL Opn/Sqz SHOT SQZ =�'1� 9300' -9310 � 4 SPF TBG PUNCH(01/26/17) I 2" 6 9089-9099 O 02/12/17 I ► /111 9316' --{5-1/2 X 2-7/8'BKR F3-1 PERM PKR,D=300" , 2-1/8" 2 9210 9220 S 12/12/91 03/30/93 9317' 3-3/4 SEAL BORE EXTENSION,D=3.00 , 2" 6 9330-9350 C 04/17/10 ,�,_ -.�� 9323' 4"MLLOUT EXTENSION,D=3.50" 2" 6 9395-9405 C 04/17/10 - - 2-1/8" 2 9438-9450 C 02/10/95 — 9328' J--I4"X 2-7/8"XO,D=2.44"J 2-1/8" 4 9458 9466 C 06125/94 9329 — ELMj12-71s WEDCBP(01/25/17)1 2-1/8" 4 9467-9477 C 02/22/94 2-1/8" 4 9486-9510 S 12/12/91 03/30/93 9379' —I2-7/8"OTIS XN NP.D=2.25 j 2-118" 4 9486-9510 S 04/10/92 03/30/93 LI 9391' I—I2-7/8"BKR SHEAROUT SUB,D=2.44" I 2-1/8" 4 9486-9510 C 06/20/93 111 9392' 2-7/8 WLEG ID=2.44" 2-1/8" 6 9511 -9529 S 04/10/92 06/04/93 .__ ______I __._- _....__._ __ 2-1/8" 4 9514-9532 S 12/12/91 03/30/93 ■ I 9390' IHELMD TT LOG ON XX/XX/XX I 2-7/8"TBG,6.4#,13CR-80,FOX.0058 bpf,D=2.441" H 9392' 9662' 1—I PSTD I 11111111111111114 V.1.1.1.1.1AV 5-1/2"LNR, 17#,13CR-80,.0232 bpf,D=4.892" 9643' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/11/91 N28E ORIGINAL COMPLETION 02/15/17 ZV/JMD SET FLOW THRU SUB w/DH GAUGES WELL: 04-40 04/16/09 D14 RWO 02/21/17 GJB/JMD GLV C/O(02/14/17) PERMT No 1911340 01/31/17 DG/JMD RLL K VLV,SET CBFYCMT RET 03/09/17 DG/JM) PULLED FLOW-II-CU SUB&GAUGES _ API No: 50-029-22224-00 01/31/17 JTG/JMD GLV C/O(01/27/17) 03/21/17 ZV/JMD SET K VALVE(03/17/17) SEC 34,T11N,R15E, 1268'FAL&306'FEL 02/13/17 JCF/JMD IA CMT(02/09/17) 02)13/17 PVJMD EDIT IA OAT DEPT /ADPE RFS(02/12/17) BP Exploration(Alaska) OF TFJ • • THE STATE Alaska Oil and Gas ys s //rte of�T As Conservation Commission ,,.:__ x 333 West Seventh Avenue I GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 O p. Main: 907.279.1433 AL A41* Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner FS2 Lead PE AR 0 BP Exploration(Alaska), Inc. SCANNEDP 4 l' P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 4-40 Permit to Drill Number: 191-134 Sundry Number: 317-109 Dear Mr. Stechauner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this / ay of March, 2017. REsI3 1 — in; z3 2317 STATE OF ALASKA 11,LASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROVATS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other K-Valve Design 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 191-134 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development El. 6. API Number: 50-029-22224-00-00 . 99519-6612 Stratigraphic 0 Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No I I PRUDHOE BAY UNIT 04-40 ��// 9. Property Designation(Lease Number): 10. Field/Pools: ElEC '"� ADL 0028325 - PRUDHOE BAY,PRESENT WELL CONDITION SUMMARY PRUDHOE OIL ' 11. MAR 0 9 2017 0-r5 sr/°//? Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk 9643 - 9009 9289 8695 9289/9329 C. . Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3460 10-3/4"45.5#L-80 31 -3491 31-3490 5210 2480 Intermediate 9001 7-5/8"29.7#L-80 29-9027 29-8458 6890 4790 Production Liner 906 5-1/2"17#13Cr80 8734-9640 8197-9006 7740 6280 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 12.Attachments: Proposal Summary 0 Wellbore Schematic Er 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development IZ Service 0 14.Estimated Date for Commencing Operations: 3/16/17 15. Well Status after proposed work: Oil IZI • WIND 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Stechauner,Bernhard be deviated from without prior written approval. Email Bernhard.Stechauner@bp.com Printed Name Stechauner,Bernhard Title FS2 Lead PE Signature Phone +1 907 564 4594 Date 3/57 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31i-iOq Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: I.*" I l 0( Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No Er Subsequent Form Required: /t —!+-C 4- el, APPROVED BYTHE Approved by: t COMMISSIONER COMMISSION Date3-/—7 V 7i 3/l5/l 1 • Q . ti . 9INAL P 0,7 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. ttachments i Duplicate 4 ' 7 3 . / % /7 WOVer�01 Wireline Work Request 04-40 global wells organization Distribution Wireline(4) Well: 04-40 AFE: APBNRWOSSL Reading File Date: 3/9/2017 Engineer: John Paul Kenda IOR: 50 FTS: Yes AWGRS Job Scope: SSSV Design H2S Level: Problem Description Install new K SSSV design per State requirements • Initial Problem Review Remedial Plan -WIRELINE ACTION Install K valve as per the attached design For HES Shop set up only: HES set up 4.5"K valve with closing pressure at 60 degrees of 906 psi • DSO well needs to flow at a Pwh of greater than 1000 psi.Valve set to close a Pwh less than 1000 psi. Date Work Completed Well Status/Results Date by Problem Resolved ? Y N : Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate(STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC, Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "K"Valve Calculation Sheet Well 04-40 Date: 03/09/17 Test Data Test Date 03/03/17 Gross Fluid Rate 674 BLPD Flowing Well Head Pressure 1003 psi Flowing Well Head Temperature 89 deg F GOR 50935 scf/bbl TGLR 50972 scf/bbl Flowing Pressure Calculations Based on data collected from downhole pressure gauges "K"Valve Setting Depth MD 2106 ft Flowing Tubing Pressure With Gas Lift 1003 psi "salve set to close at 1000 Ansi Pwh Flowing Tubing Pressure depth @ 1000 psi Pwh 1311 psi Flowing Tubing Temperature depth @ 1000 psi Pwh 104 degrees "K"Valve Test Rack Set Pressure at 60 deg F 906 psi Valve Size &Volume Ratio 4-1/2" 1.314 NOTE: Well needs to flow at> 1000 Pwh Valve set to close at less than 1000 psi Pwh • Tubing Pressure at Valve 1.311 BPT(psis) 1325 >1238 <1238 Temperature(deg F)at Valve 104 a 8.096E-06 1.34376E-05 b 1.101112 1.085096 Base Pressure 1222 c -1337.148 -1325.49944 Base Temp (TV-60) 44 1203.7082 1203.610269 Corrected Pressure 1203.61027 psia TCF 0.90811096 _ /olume Ratio for Valve Size = 1.314 Pb @ 60 = 1190.53347 Test Rack Pressure = 906 Volume Ratios 41/2" & 51/2", 1.314 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 TREE= CM/SAFETY NOTES: WELL REQUIRES A SSSV "`CHROME WELLHEAD= MC • (0 -40 LNR ill••• ACTUATOR= BAKER C OKB.ELEV= 60 11 Ill!i• 2016' 1---4-1/2"HES X NP,D=3.81r1 -.6"r.? 1, ' -iI' 0Y. 2016' 1-4-1/2"FLOW THRU SUB ON X-LOCK KOP= 4500 20"CONDUCTOR, --1. -100 1. �I� - w Max Angle= 33°@@ 6700' 91.5#,H-40, 1� b... 1• Ii' 313T 17-5/8"HES ES CEIVENTER I P„ne,of Datum ND= 9474' D=19.124" 44 P. 44 Datum TVD= 8800'SS 3164 j-{7-518 EXTERNAL CS PKR j 1/8/17 7 5/8 TIEBK CSG,29 7#,1-80 TCI,D=6.875" - 3186' GAS LST MANDRELS L^ l ST M) TVD DEV TYPE VLV LATCH PORT DATE I 7-5/8"BOWEN CSG PATCH,D= '? --I 3186'-3190' 8 2833 2832 2 TETi4RD DOME BK 16 05/28/14 7 4537 4532 12 TE-TMAY DMY BK 0 04/15/09 10-3/4'CSG,45.5#,L-80,D -.1=9.953" � 3492' 6 5236 5192 25 TE-TWO SO ff BK 20 05/28/14 5 5935 5799 31 TET FD DMY BK 0 05/24/14 4 6425 6218 32 TE-11,11) DMY BK 0 04/15/09 3 6872 6596 31 1E—TWO DMY BK 0 04/15/09 Minimum ID =2.25" @9379' 2 7361 7012 31 TE-11,413D' DMY € BK 0 04/15/09 12 7/8" OTIS XN NIPPLE 1 1 7806 7396 30 TE-TMPD DMY BK 0 04/15/09 ' 8296' -4-1/2*HES X M?D=3.813" 0. 8317' _H7-5/8"X 4-1/2"S-3 PKR.D=3.87' ' 8341' 4-1/2"HES X NP,D=3.813" 8425' -7-5/8"X 3-1/2"BKR SB-3A HYD PKR,D=3.00' 4-1/2"TBG, 12 6#,13CR 80 VAM TOP 8436' 8436' H4-1/2"X 3-1/2"XO,I)=2.992- .0152 bpf,ID=3.958" t £ 8445' -5'MLLCXIT EXTE NSION.D=4.50" 8446' `3-1/2"PALES-C7E,D=2.992" 8450' -15"X 3-112"XO,D=3.00' L- PR017k1CTION MANDRELS 3-1/2"TBG,9.3#,13CR FOX,.0087 bpf,D=2.992' --i 8696' ST Pet) TVD DEV TYPE VLV .LATCH PORT DATE ' 9 8595 8075 29 TE:TGPDX' DMY RK 0 02/14/17 5-112"TIEBACK SLV,ID=5.75?' - $737` i 10 8669 8139 28 TE TGPDX DMY RK 0 02114/17 7-5/8"X 5-1/7 PKR&LNR HGR,D=5.875?" 8745' 8693' -1 3-112"PKR SWN NI',ID=2.75" [7-5/8"CSG,29.7#,L-80 BTC-M,1113=6.875"]- 9030' 8696` -13-1/2-X 2-7/8"XO,D=2.44" CO '• 8764' HA CMT DEPTH BY ELM SCMT 2/12/17(2/9/17) FEW-ORATION SUMMARY 1111. 44 REF LOG. BRCS ON 12/05/911111 11' 9204'-922T -I2-7/8"BLAST JOINTS,ID=2.44" ANGLE AT TOP PERF: 25°@9089' 1114 1 1� hbte:Refer to Production 06 for historical perf data 1111 #114 9289'ELM -I 2-718"WFD CMT RET(01/26/17) SIZE I SPF IfTERVAL Opn/Sgz SHOT SQZ 1111 = yeti 9300'-9310 j-- SPF TBG PUNCH(01/26/17 11'—:4♦ —.� 2" 6 9089-9099 0 02/12/17 A1�t;`*;1A1�4 9316' 5-1/2 X 2-7/8"BKR FB-1 PERM PKR,D=3.00' 2-1/8" 2 9210-9220 S 12/12/91 03/30/93 ,f.,\\ — _ _.. -- v v■ 9317' ,-3-3/4 SEAL BORE EXTENSION,D=3.00 T _ 2" 6 9330-9350 C 04/17/10 'A �_ e.e+_\0.7.---..,. 2" 6 9395-9405 C 04/17/10 . 9323' —�4"ASI LOttT EXTEftS10tV,D=3.50" 2-1/8" 2 9438-9450 C 02/10/95 ��� 9328' 4"X 2-7/8"XO,D=2.44" 2-1/8" 4 9458 9466 C 06/25/94 9329'ELM -2-7/8'INFO CBP(01/25/17), 2-1/8" 4 9467-9477 C 02/22/94 - - -- - 2-1/8" 4 9486-9510 S 12/12/91 03/30/93 1 9379' --{2-7/8"OTIS XN NIS,D=2.25" 2-1/8" 4 9486-9510 S 04/10/92 03/30/93 L 9391' j-12-7/8"BKR SHEAROUT SUB,D=2.44" I 2-1/8" 4 9486-9510 C 06/20/93 III -- - 2-118" 6 9511-9529 S 04/10/92 06/04/93 9392' �-2-718"WLEG,D=2.44" 2-118" 4 9514-9532 S 12/12/91 03/30/93 • L9390" -{FEND TT LOG ON XXlXX/XX 2-7/8"TBG,6.4#,13CR-80,FOX.0058 bpf,D=2.441' - 9392' 9662' PBTD� - 11 1114 --- _- ).1.4111445-1/2"LNR,17#,13CR-80,.0232 bpf,D=4.892" - 9643' s �atiaa — DATE REV BY COMMENTS DATE REV BY COM ENTS FRUDHOE BAY UV 12/11/91 N28E ORIGINAL COMPLETION 02/15/17 ZV/JM) SET FLOW THRU SUB w/DH GAUGES WELL: 04-40 04/16/09 014 RWO 02/21/17 GJBIJM)GLV CIO(02/14/17) PERMIT'No: 1911340 01/31/17 DG/JM) RLL K VLV,SET C8l!CMT RET,TBG FLINCH API No: 50-029-22224-00 01/31/17 JTG/JM) GLV CIO(01/27/17) SEC 34,T11N,R15E,1268'FNL&306'FEL 02/13/17 JCF/JM? 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O aQ STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPERATI S 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: YLyr. c-$p EK 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 191-134 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22224-00-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PRUDHOE BAY UNIT 04-40 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: C Total Depth: measured 9643 feet Plugs measured 9289/9329 feetTR E I V true vertical 9009 feet Junk measured feet !! Effective Depth: measured 9289 feet Packermeasured See Attachment feet MAR 0 9 2 017 true vertical 8695 feet Packer true vertical See Attachment feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3460 10-3/4"45.5#L-80 31-3491 31 -3490 5210 2480 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 906 5-1/2"17#13Cr80 8734-9640 8197-9006 7740 6280 Perforation Depth: Measured depth: See Attachment feetta ���, U 99Oe,7 +7 scog True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) No SSSV Installed 12.Stimulation or cement squeeze summary: Intervals treated(measured): In IA:8754'-9310' In Tbg:9289'-9329' Treatment descriptions including volumes used and final pressure: 57 Bbls 60/40 Methanol/Water,204 Bbls Diesel,84 Bbls Slick 1%KCL w/SafeLube,28 Bbls 1%KCL,17 Bbls PowerVis,10 Bbls Class G Cement,7 Bbls Fresh Water,76 Bbls Slick 1% KCL,3020 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 70 1140 6167 1818 523 Subsequent to operation: 799 35483 0 1280 889 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations I3 Exploratory 0 Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature „tiPhone +1 907 564 4424 Date 3/9/17 Form 10-404 Revised 5/2015 v 3/7 D /1 Submit Original Only • • Packers and SSV's Attachment PRUDHOE BAY UNIT 04-40 SW Name Type MD TVD Depscription 04-40 PACKER 3150.22 3149.42 7-5/8" EC Packer 04-40 TBG PACKER 8313.35 7830.31 4-1/2" Baker S-3 Perm Packer 04-40 TBG PACKER 8421.22 7923.26 4-1/2" Baker SB-3A HYD PERM PKR 04-40 PACKER 8741.43 8203.17 5-1/2" Baker LT Packer 04-40 TBG PACKER 9311.63 8715.68 2-7/8" Baker FB-1 PERM PKR • • QM M O O O O O O COC) la r O IT- ) O) 0) O C) C) C N V CD I� V +-' OOOOOOOOO O) e-- O) (A ch M CSO N) ea acOCDI- coOOO O a0 co co N CA CO LO O CO CD Nr CO 'ct OO) - 0) N- M CO CO CO r- co r- co CI N N- M O CV •— CO CO CO a0 N M CO M Cr) N N O C7) M CO I- N CO QpCO N- O N M CO EO O O N 1" M O 4- aD 0 CO CO M coM M O) 0) co a) co O Q = N r- O U) co a) N co coN M MN M C CO CO CO =• QQM W • W O I"' O 0 0 � aO cO O c0 _ Jaoai c9) °? •W re (/� N N CV Nr O0_ M � Ea\DNN •- � ON- 4 (.) 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R < cq I& w A & 6 u ,. 0 @ - U ' 0 / � DfooD0 . 0 * * ww / w6R / 220 % 2 � / % k2kk : 5E oe m a OC OL W 0- : : m m a m 2 0 : G > ce 2 0 0 - o T- a - LL m * ¥ ¥ d d d 2 ® 2Q % \ 72 / ¥ f N # o = - CVMr (N % % d W�IJ EAD= • 04-4 0 SARFG TES: WELL REQUIRES A SSSV ""'CHROME ACTUATOR= BAKER C 0KB E-EV= 60' ' • I L_.._2016' -4-1/2"HES X NP,D=3.813" 1 BF. EL = 2016' 1-4-1/2'FLOW THRU SUB ON X-LOCK KOP= 4500' 20"CONDUCTORH -100 1 1 w/SPARTEK DH GAUGES(02/14/17) Max Angle= 33°@ 6700' 91.5#,H-40, 1 4 3132' H7-5/8"HES ES CEMENTED Datum MD= 9474' D=19.124" Datum TVD= 8800'SS Z I 3164' i--17-5/8"EXTERNAL CS PKR l 7-5/8"TEBK CSG_29.7#,L-80 TCI,D=6.875" H 3186'. 1--t GAS MANDRELS ST MD TVD DEV TYPE LATCH PORT BATE 7-5/8"BOWEN CSG PATCH,ID= "? - 3186'-3190' I_ . 8 2833 2832 2 TE-TMPD DOME BK 16 05/28/14 ' 7 4537 4532 12 7E-TWO OW BK 0 04/15/09 10-3/4"CSG,45.5#,L-80,D=9.953" H 3492' H• 6 5236 5192 25 TE-TMPD SO BK 20 05/28/14 5 5935 5799 31 1E-TWO DMY BK 0 05/24/14 4 6425 6218 32 TE-TMPD DMY BK 0 04/15/09 3 6872 6596 31 TE-TWO DMY BK 0 04/15/09 Minimum ID =2.25" @ 9379' 2 7361 7012 31 TETVED DMY BK 0 04/15/09 2 7/8" OTIS XN NIPPLE 1 7806 7396 30 TE-TMPD DMY BK 0 04/15/09 ' ' 8296' -14-1/2"HES X NIP,D=3.813" Z X 8317' -17-5/8'X 4-1/2"S-3 FKR D=3.87" ' ' L_ A8341' J-14-112 HES XNIP,D=3.813" - / 8425' H7-518'X 3-1/2"BKR SB-3A HY D PKR,D=3.00" 4-112"TBG, 12.6#,13CR-80 VAM TOP, - 8436' (...............A._ 6' ,4-112"X 3-1/2"XO,D=2.992" .0152 bpf,ID=3.958" I I L 8445' -5"MLLOUT EXTBJSION,ID=4-50" 8446' -13-1/2"MULESHOE,ID=2.992" L 8450' -.15"X3-1/2"XO,D=3.00" PRODUCTION MANDRELS 3-1/2"TBG,9.3#,13CR FOX,.0087 bpf,D=2.992" -{ 8696' ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 8595 8075 29 TE TGPDX DMY RK 0 02/14/17 5-1/2"TEBACK SLV,D=5.75?" -I 8737' 10 8669 8139 28 TE TGPDX DMY RK 0 02/14/17 rr7-5/8"X 5-1/2 PKR&LNR HGR,D=5 875?" 8745' 8693' 3-112'PKR SWN NP,D12:75"2.75" 17-5/8"CSG,29.7#,L-80 BTC-M,67-;6.8-16; - 9030' 8696' 3-112"X 2-7/8"XO,D=2.44" Ni'1' ' *4 8764' -11A CMT DEPTH BY ELME SCMT 2/12/17(2/9/17) )PERFORATION SUMMARY 1111 11111 ' REF LOG. BRCS ON 12/05/91 141•. 1 9204'-9222' H2-7/8"BLAST JOINTS,ID=2.44" ANGLE AT TOP PERF: 25°@ 9089' 1114 . :vi Note:Refer to Production DB for historical pert data 1111 111/ 9289' ELM -I2-7/8'VVFD CMT RET(01/26/17) • SIZE SPF MERVAL Opn/Sqz SHOT SOZ 1111' - 14 9300'-9310'H4 SFF TBG PUNCH(01/26/17)1 111`— 2" 6 9089-9099 0 '02/12/17 .1�t;po 1��1 9316' -L5-1/2^X 2-7/8"BKR FB-1 PERM PKR D=3.00" 1 2-1/8" 2 9210-9220 S 12/12/91 03/30/93 9317' 1-13-3/4"SEAL BORE EXTENSION D 3.00 J 2" 6 9330-9350 C 04/17/10 :��: p���= 9323' H4-MLLOUT EXTENSION,D=3.50" 2" 6 9395 9405 C 04/17/10 •r•% 2-1/8" 2 9438-9450 C 02/10/95 -- 9328' 4"X 2-7/8"XO,ID=2.44" 2-1/8" 4 9458-9466 C 06/25/94 9329'ELM I-I2-7/8^VVFD CBP(01/25/17) 2-1/8" 4 9467-9477 C 02/22/94 2-1/8" 4 9486-9510 S 12/12/91 03/30/93 I 9379' --I2-7/8"OTIS XN NP,0=2.25" , 2-1/8" 4 9486-9510 S 04/10/92 03/30/93 / (.. 9391' H2-7/8 BKR SHEA ROUT SUB.ID=2A4" I 2-1/8" 4 9486-9510 C 06/20/93 II .__-. 2-1/8" 6 9511-9529 S 04/10/92 06/04/93 9392' 1-12-7/8"wLEG 13 2.44 2-1/8" 4 9514-9532 S 12/12/91 03/30/93 I L 9390' ]--jELMD TT LOG ON XX/XX/XX I 2-7/8"TBG,6.4#,13CR-80,FOX.0058 bpf,D=2.441" -1 9392' 9662' IHPBT3] -- 1111111{ 11/111/11111111 5-1/2"LNR,17#,13CR-80,.0232 bpf,ID=4.892" - 9643' •a�����• DATE REV BY COMVENTS DATE REV BY COPD ITS PRUDHOE BAY UNIT 12/11/91 N28E ORIGINAL COMPLETION 02/15/17 ZV/JMD SET FLOW THRU SUB w/DH GAUGES WELL 04-40 04/16/09 D14 RWO 02/21/17 GJB/JkD GLV C/O(02/14/17) PERMIT No: 1911340 01/31/17 DG/JMD PULL K VLV,SET CBRCMT RET,TBG PUNCH API No: 50-029-22224-00 01/31/17 JTG/JM3 GLV C/0(01/27/17) SEC 34,T11 N,R15E,1268'FN-&306'FEL 02/13/17 JCF/JMD IA CMT(02/09/17) 02/13/17 PVJMD EDIT IA CMT DEPTHIADFERFS(02112/17) BP Exploration(Alaska) 0 • ~ > XO O1 in ami 00P'wo L 0 N on > m �. p�W F0Y J.- r f6 +�+ O H 0) L Q a C C ++ O f0 4_, .c. a>, '5 NO Q T co Q N Q - a +., a r u Q 0 0 a� c O N L r M N N U -p f0 p N z Q 0 v Q O C f- (D v '6 N U C LU' 0 -I -I 0 tin c - U 0 NW W W W Y v 'a) 01 .p {L u u u- a 2 > -c y a Q a a a a U o (1 o • zzzz CD -C a� 4-0.).- CO ( LL LL IL EL = -0 C O ZO c Cc ,a2 pbA LC L o c a j a' Q i_ C to a o 0 CO V W > ` N a n C a re yLy W W C 7w C f+ O 0 2 0 LL '° d ,c a) 0 0 J p m 'C 0 o m m E E. - 4i m >_ W oC7 a 0 CrD RS a .i z \ Z 2 0 5 u .` an a o _I oI 3 © Zac) � W2 W >- >- >- >- S w a a a a VI g m CO m CO a W W W W Z 0 0 0 0 p 2 2 2 2 J 0 0 0 CIW > > > > f O. a a a c a WU re x 0 0 Q W s- N N - t11 N Vcc in o in ocncrn m �� O O C 0 0 E Y u„ C O O Q W > N ° Y � CO W 0 W 00 0 0 0 0 > (6 W a o Q m O u Cr I C N N N O _ Q O O O O 0 Kt +_' uu £0Cvs a+N d w Ln 16u C E O cm S gE cc ._ Ov 51 CO u d Q tw f6 N -� • ei H 01 0J 5 a CO co CO p 4, C N d z n6 z rn o N a+ ru 101/1 u J CC V1 J G a = N w O C }' in u 0 C v ,� 6-' m 0r C a STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI•N • REPORT OF SUNDRY WELL OPERATIONS ' 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other:K Valve Redesign IZI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 191-134 3. Address: P.O.Box 196612 Anchorage, Development 8 Exploratory ❑ AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22224-00-00 7. Property Designation(Lease Number): ADL 0028325 8. Well Name and Number: PBU 04-40 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9643 feet Plugs measured 8693 feet true vertical 9009 feet Junk measured feet NOV 2 9 2016 Effective Depth: measured 8693 feet Packer measured See Attachment feet true vertical 8160 feet Packer true vertical See Attachment feet AOGc Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3460 10-3/4"45.5#L-80 31-3491 31 -3490 5210 2480 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 906 5-1/2"17#13Cr80 8734-9640 8197-9006 7740 6280 Perforation Depth: Measured depth: 9210-9220 feet feet 9330-9350 feet 9395-9405 feet 9438-9450 feet 9458-9466 feet 9467-9477 feet 9486-9510 feet 9511-9514 feet 9514-9529 feet 9529-9532 feet True vertical depth: 8624-8633 feet feet 8732-8750 feet 8790-8799 feet 8829-8839 feet 8846-8853 feet 8854-8863 feet 8871-8892 feet 8893-8895 feet 8895-8909 feet 8909-8911 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"K Valve 2016 2016 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: e ,_ NNE® �',PR 2,,�1?, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 87 1419 6875 1581 404 Subsequent to operation: 80 1147 5447 1847 622 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil f13 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-538 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 11/29/16 Form 10-404 Revised 5/2015 V'TL 3/ Z /(I 1 7--RBDMS I.V DEC — 6 2016 Submit Original Only • • Packers and SSV's Attachment PBU 04-40 SW Name Type MD TVD Depscription 04-40 SSSV 2016 2015.7 4-1/2" K Valve 04-40 PACKER 3150.22 3149.42 7-5/8" EC Packer 04-40 TBG PACKER 8313.35 7830.31 4-1/2" Baker S-3 Perm Packer 04-40 TBG PACKER 8421.22 7923.26 4-1/2" Baker SB-3A HYD PERM PKR 04-40 PACKER 8741.43 8203.17 5-1/2" Baker LT Packer 04-40 TBG PACKER 9311.63 8715.68 2-7/8" Baker FB-1 PERM PKR • • CL) 0 Ry O- 00000 0 0 c0 O) CA 00 O M M CO N- I- N Lo C N r CO f- CO OD r- U y 0 0 0 0 0 0 0 C) L. O) A- O) O) co O O N- 7 N 00 CO N- m Lo co co N- co O O O OO Lo 000crONv C r- ) CO In O M (O ct CO M M 00 O) N- M N- cc 1- N N- co V O N v- CA 00 O co N M CO 00 M N r- N CA CA r- 01 00 N- ti 00 r O N- O N M co - C) 00 N V' M CA rr 00 V A- O CO '4' CO •sr M M C) C) 00 00 00 C) C.) QM V N N o) co co co N M C) M M C ( I N V 0 M 00 00 00 00 O O O O OD O O 00 CO 00 U Crir 00 a) 00 _ UMU U = 2 M M d N- N- N •N N N cc(Ni N O V C`) N = N r CO O N r toM („j L C]CO CO Ln V a) 0 O C N- ,r - co O ,r r- CA CA J co co to CA 00 N CO LU w Ct E- 0)O QQ CF- w0a •NUUww co D U Q 1 c W w Z Z Z Z Z O W w W m m m 00 O0I- E- Z : : � U OD Z z - I- H F- I- • F- Q D (/) Cl) c 5 a) O >- Q - Q E r w 2 m 1- o_ Q o c Niib O 72 Ow 2 ��0 L o o2 �Q O m �X > 0 aZ > � cr. � zQY JX3Oa Q Q ° ~ LLI >+ > wZ � J- LIJ D W Y QUcn OQ > = j C Z Y U W Q - J Q N N W Fw-- W W Z > cn N * • M W Q * _N Q (/) Q Q W 4 CD Q Q ›- CN N F- cn C r > c•1 CO I= O U Q T D= S 04-40 4-40 ISR G TES: WELL REQUIRES A SSSV `•"CHROME WELLFEAFMC ACTUATOR= BAKER C OKE.BEV= 60' I - BF ELEV= ? 'C 7 ""4111V2016' —141/2"FES X NP.D=3.813" KOP= 4500' 20"CONDUCTOR -f -100 ♦. 2016' —41/2"K VALVE(10/29/16) Max Angle= 33"@ 6700' 91.5#,H-40, Datum MD= 9474' D=19.124" Ili 3132' 1-17-5/8"HES ES CEMENTER Datum ND= 8800'SS 1 3164' 1-17-5/8"EXTERNAL CS WR J 7-5/8"T1EBK CSG,29.7#,L-80 TCI,D=6.875' —1 3186' N I _GAS LFT MANDRELS ST MD WD DEV TYPE VLV LATCH PORT DATE 7-5/8"BOWEN CSG PATCH,ID= "? -- 3186'-3190' 8 2833 2832 2 TE TMPD DOME BK 16 05/28/14 7 4537 4532 12 TE TMPD DMY BK 0 04/15/09 10-3/4"CSG,45.5#,L-80,D=9.953" H 3492' 6 5236 5192 25 TE TMPD SO BK 20 05/28/14 5 5935 5799 31 TE-INFO DMY BK 0 05/24/14 4 6425 6218 32 TE TMPD DMY BK 0 04/15/09 3 6872 6596 31 TE TMPD DMY BK 0 04/15/09 Minimum ID =2.26" @ 9379' 2 7361 7012 31 TE TMPD DMI' BK 0 04/15/09 2 7/8" OTIS XN NIPPLE 1 7806 7396 30 TE-TMPD DMY BK 0 04/15/09 ' 8296' H4-1/2"HES X NP,D=3.813" Z [ 8317' 1—{7-5/8"X 4-1/2"S-3 PKR D=3.87" 1 ' 8341' H4-1/2"HES X NP,D=3.813' 8425' H7-5/8"X 3-1/2"BKR SB-3A HYD PKR,D=3.00" 4112"TBG, 12.6#,13CR-80 VAM TOP, — 8436' 8436' H41/7x3-1/7x0.D=2.992" .0152 bpf,D=3.958" — 8445' ---i5"MLLOUT EXTENSION,ID=4.50" \ 8446' —13-1/2'NULESHOE,D=2.992" 3-1/2"TBG,9.3#,13CR FOX,.0087 bpf,0=2.992" —1 8696' 8450' ---15"X 3-1/2"XO,D=3.00" L PRODUCTION MANDRELS 5-1/2"TEBACK SLV,D=5.75?"— 8737' ST MD ND DEV TYPE VLV LATCH PORT DATE 9 8595 8075 29 TE-TGPDX FLWSLV RK - 09/21/16 C 7-5/8 X 5-1//2 PKR 8 LNR HGR.D=5.875?",—{ 8745' ■ 10 8669 8139 28 TE-TGPDX FLWSLV RK - 05/28/14 1-7-5/8"CSG,29 7# L-80 BTC-M,D=6.8751— 9030' 8693' —{3.1/2"PKR SWN NP,D=2.75" PERFORATION SUNOAARY .174 8693' —i3-112"PXN PLUG(05/26/14) REF LOG: BHCS ON 12/05/91 8696' H3-1/2"X 2-7/8"XO,D=2.44" ANGLE AT TOP PST: 26'@ 9330' Note:Refer to Production DB for historical perf data 9204' -9222' —12-7/8"BLAST JOINTS,D=2.44" SIZE SPF INTERVAL Opn/Sgz SHOT SO2 2-118" 2 9210-9220 S 12/12/91 03130/93 9315' H5-1/2"X 2-7/8"BKR FB-1 PERM PKR 0=3.00" 2" 6 9330-9350 0 04/17/10 _ 9317" 1—{3-3/4"SEAL BORE EXTENSION,D=3.00 1 2" 6 9395-9405 0 04/17/10 9323' H4"MLLOUT EXTENSION,ID=3.50" 2-1/8" 2 9438-9450 0 02/10/95 - 2-1/8" 4 9458-9466 0 06/25/94 I 1 9328' —4"X 2-7/8"XO,0=2.44" 2-1/8" 4 9467-9477 0 02/22/94 I 9379' H2-7/8"OTIS XN NP,ID=2.25" 2-1/8" 4 9486-9510 S 12/12/91 03/30/93 2-1/8" 4 94$6-9510 S 04/10/92 03/30/93IL 9391' —12-7/8'BKR SHEA ROUT SUB,D=2.44" 2-1/8" 4 9486-9510 0 06/20/93 11 2-1/8" 6 9511-9529 S 04/10/92 06/04/93 9392' H2-7/8"WLEG,ID=2.44" 2-1/8" 4 9514-9532 S 12/12/91 03/30/93 I 9390' --{ELMD TT LOG ON XX/XX/XX 1P�'1M�+'��+PA 9562' H PBTD 2-7/8"TBG,6.4#,13CR-80,FOX.0058 bpf,0=2.441^ 9392' HNlN 5-1/2"LNR,17#,13CR-80,.0232 bpf,D=4.892" — 9643' �����aa• DATE REV BY COMMENTS DATE REV BY COIMENTS PRUDHOE BAY UNT 12/11191 N28E ORIGINAL COMPLETION 09/26/16 DLW/JMD GLV CIO(09/21/16) WB.L: 04-40 04/16/09 014 RWO 10/11/16 JMMIJMD PULLED FLOTI-RU SUB&GAUGES FERMI Ib 1911340 — 06/02/14 PJC REFORMAT DRAWING 11/02/16 NLW/JMD SET K VALVE(10/29/16) API No: 50-029-2279400 06/03/14 GC/PJC TUBING CORRECTION SEC 34,T11N,R15E, 1268'FNL&306'FEL 04/23/15 ORS/JMD PEW SYMBOL CORRECTION 09/26/16 JR/JMD SET FLOW/}-RU SW&GAUGES BP Exploration(Alaska) • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, October 31, 2016 7:38 AM To: AK, OPS FS2 OSM;AK, OPS FS2 Facility OIL;AK, OPS FS2 Field OTL;AK, OPS FS2 DS Ops Lead; G GPB FS2 Drillsites;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; Stechauner, Bernhard; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO Gas Lift Engr;AK, GWO SR Slickline WSL;Catron, Garry R(Wipro); Stahl, Randy; Stair, Kelley;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy; Worthington,Aras J Subject: OPERABLE: Producer 04-40(PTD#1911340) New K-Valve Installed Attachments: 04-40 316-538.pdf All, Producer 04-40(PTD#1911340) had a new K-valve installed on 10/29/16.Sundry approval attached.The well is reclassified as Operable,and may be brought online. Work Completed/Plan Forward: 1. Operations: Flow well Under Evaluation for maximum 14 days—Completed 10/10/16 2. Well Integrity Superintendent: Reclassify Not Operable—Completed 10/10/16 3. Slickline: Pull downhole gauges—Completed 10/10/16 4. Gas Lift Engineer/Anchorage PE/PDC:Submit proposed K-valve design to AOGCC via 10-403—Approved 10/25/16 5. Slickline: Set K-valve—Completed 10/29/16 6. WI SUPT: Reclassify Operable—Completed 10/31/16 7. Full Field Well Ops Compliance Rep: Schedule AOGCC K-valve test within 5 days of POP Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 E.3 2 12017 C:(907)943-0296 H:2376 Email: AKDCWellIntegrityCoordinator@BP.com From: , - • SUPT Well Integrity Sent: Monday, Octobe :, I 6 5:23 AM To: AK, OPS FS2 Field OTL; AK, OP ' Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; Cismoski, Doug A; Daniel, Ryan; AK, RS B East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB FS2 ' ' es; AK, GWO SR Slickline WSL; Stechauner, Bernhard; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO letions Well Integrity; AK, OPS FF Well Ops Comp Rep; AK, GWO Gas Lift Engr; AK, GWO SR Slickline WSL; Catron, Garry R( r n.); Stahl, Randy; Stair, Kelley; 1 • • V OF T7" ' g ��\�yy�;• THE STATE Alaska Oil and Gas F�;-s����, ofA T c T e Conservation Commission t 5itE= == 333 West Seventh Avenue ,'1- I. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " ------ Main: 907.279.1433 04k,ALAS'' Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner Lead PE BP Exploration(Alaska), Inc. sc1�NME® MA . . Ut P.O. Box 196612 Anchorage, AK 99519-6612 i Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-40 Permit to Drill Number: 191-134 Sundry Number: 316-538 Dear Mr. Stechauner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1711 Cathy 7 Foerster 251----lay , Chair DATED this G5' day of October, 2016. RBDMS Li., U ,, L 0 [UI6 STATE OF ALAS • ALASKA OIL AND GAS CONSERVATION COSION APPLICATION FOR SUNDRY APPRALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ I Repair Well 0 Operations shutdown❑ Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing0 Other K Valve Design - m 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: Exploratory 0 Development 0, • 3, Address: P.O.Box 196612 Anchorage,AK5. Permit to Drill Number: 191-134 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22224-00-00 • 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No 0 PBU 04-40 - RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0028325• PRUDHOE BAY,PRUDHOE OIL- 11. PRESENT WELL CONDITION SUMMARY OC T 2016 Total Depth MD(ft): Total Depth TVD(ft): I Effective Depth MD: I Effective Depth TVD: MPSP p (psi): I Plugs(MD): j k ( 9643 ' 9009 - 8693 r 8160 C� Casing Length Size MD 8693 Structural TVO Burst Collapse Conductor 78 20"91.5#H-40 32-110 32-110 1490 470 Surface 3460 10-3/4"45.5#L-80 31-3491 31-3490 5210 2480 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment Liner 906 5-1/2"17#13Cr80 8734-9640 8197-Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 9006 7740 6280 Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment I Tubi Packers and SSSV Type: See Attachment See Attachment I See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program Ed BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development H Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil m WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Stechauner,Bernhard be deviated from without prior written approval. Email Bernhard.Stechauner@bp.corn Printed Name Stechauner,Bernhard �.-� Title FS2 Lead PE Signature /� Phone +1 907 564 4594 Date I0/l g//6 '�--- COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 ..�� 9 tYLocation Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No El Spacing Exception Requirqd? Yes 0 No Slr Subsequent Form Required: -4S.F i ,(LS It.6 q l4 lo �f Approved by: 6 APPROVED BYTHE 2.9.4.1....71/44.._� COMMISSIONER COMMISSIOND /� ate• ---2y) 7 VT L 10/y4l l� ORIGINAL RBDMS 0/ OCT 2 8 2016 //axiz6 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachment m Duplicate ' ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,D�LHD, EAZ,BPG 10/12/1 . 5) General Information Well Name: 04-40 Well Type: Gas Lift Producer API Number: 50-029-22224-00 Well Activity Conventional 4 Classification: Activity Description: Set K-Valve Cost Code/AFE: APBWELIR Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg 10R, bopd: - Job Type: SSSV Estimated Cost, $K: AWGRS Job Scope: SSSV MAINTENANCE Other regulatory Might need State witnessed NFT Sundry Form 10-403 requirements? Required? Yes Sundry Form 10-404 Re uired? Yes q Primary Secondary Engineer: Bernhard Stechauner Contact numbers: (907) 564-4594 (907)360-7485 Well Intervention Engineer: Johnny Kenda Contact numbers: (907)659-5863 H#2405 Lead Engineer: Danielle Ohms Contact numbers: (907) 564-5759 (907)440-9082 Date Created: August 12, 2016 Revisions(date,who,what changed): 1 Current Well Status Information Water Rate or Gas Rate or Date Oil Rate In) Rate Gas Injection GOR FTP or Injection Choke SettingGas Lift Rate (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Pressure Cut(%) (Mscf/Day) (psi) 7/22/2010 137 11463 bwpd, WC 98.81% 7,961 57,905 56 2,009 352 Current Status: Not Operable Shut In Inclination>70°at Depth(ft) None Recent H2S (date,ppm) 10/25/2009 115 Maximum Deviation(Angle and — ppm Depth) 33° 6,700' MD Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 4° 4,500' MD 1 Reservoir pressure(date, 1/20/2016 psig) Values estimated 3,600 psi Minimum ID and Depth 2.25" 9,379' MD from FL Reservoir Temp,F 200° F Shut-in Wellhead Pressure 2,470 psi Known mech. integrity problems(specifics) Not Operable due to no SSSV. Last downhole operation (date, operation) 5/27/2014 GL integrity, set flowsleeve to access Z3, set plug to isolate zones below Most recent TD tag (date,depth, toolstring OD) 7/3/2011 9,516' MD 110' x 2-1/8"stem, TEL, 1-3/4"S. bailer Surface Kit Fit-for-Service? YES If No,Why? See operator walkdown tab for more details Comments,well history, This well was worked over in 2009 and hasn't seen much on-time since then. background information, In 2011 the well failed integrity testing and was SI and blinded.All that was required to get it back was an etc: MIT-T with dummy valves, which was completed in 2014. Since then we've been waiting on unblinding the well. uuring t•rrent ua-uv snut-oown trns work was execute Also, in 2014, a flow sleeve was set in station#10, re-connecting the well to the Victor package.At the same time, a plug was set in the X nipple at 8,693' shutting off all production from below. We expect this well to come on significantly different than before. It should be gassy with not much water production. • Well Intervention Details • Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. Suspected Well Problem: Non Operable due to missing SSSV Specific Intervention or Well Objectives: 1 Install K-/PB-valve to operate well 2 Determine optimal SSSV design by running downhole gauge 3 If welltests during downhole gauge installation show low gas, perfor a No-Flow-Test. Key risks,critical issues: Mitigation plan: WIC to coordinate with SL,GL Eng,Pad OP to mark 1 Timing of POP and operable status change well UE to allow for POP with donwhole gauge installed Well needs to be SI until K-/PB-Valve desi n is 2 State g approved by WIC to mark well Non-Op following pulling of the valve to ensure we don't flow it. 3 Can't pull valve from station#9 If valve can't be pulled after 24 hours,contact APE Summary Step# Service Line Activity 1 WIC Make well UE 2 S Pull Dmy from station#9 and set flowsleeve. Set downhole gauge as per GL engineer 3 S After at least one week of production pull downhole gauge and send data to GL engineer for eval 4 DHD Pending If welltests suggest that well could pass a NFT, perform NFT as per RP. 5 WIC Make well Not Operable 6 SP Once we have 10-403 run K-/PB-Valve per GL engineer design. Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 500 MMSCFD: 15 BWPD: 100 Expected Production Rates: FTP(psi): 700 Choke setting: PI(bfpd/psi dp) Post job POP instructions: POP well to LP and test,this well has been SI since 2011 and might need some time to unload, but we expect it to be very gassy and going into HP eventually. Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: . • • TREE. CON 04-40 SA VET Y PIZTT 66.. Atil.HIC4411,5 A 554-V "'0 ROML. WR I.l*A0- FMC A CTI rm. 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I ill.V liv cxx.e4p1:7---- !.e.,L f.v. el' 6DC44.4341'5 PRIJOICE SAY lie 12/11011, MISE: .40R00114AL cow PI!11011 ';11 ,.14' e,..AC ((LV CO On TI 01HRECT1ON i WELL 04-40 --4- , 941'41091 014-jF8140 '06/07;14 R8'.. REFOF8.41T(PAW; FERL41 NM 1911340 , 1 '114,24,11i1ASS/J114)SO 4-1;7'XX P11,K;tuv04/11) '..cceryv 14 GC7 NC 4.8,xi OCWIECTION --------- AF1 No: 50-023-m24w 05/73-61141-J-LS(.4.43-013I-054 1,75"-PlUG.--C117S.,14--.) '''04123115'0W4,0 PERE SYFAIOL CORRECTION * SEC 34,T1114 RISE 1768 FT4 il 30G'FR 3.430114 ./LS/J1113 SET 1 1,7'R 1.11.1M06/14 — _ . 35730714'&SAM) GIN 00 okra 2S,14) 13P Esploration(Alaska) _____ • 6/6/01 WO Wireline Work Request 04-40 global wells organization Distribution Wireline(4) Well: 04-40 AFE: APBWELIRSL Reading File Date: 10/13/2016 Engineer: Kenda IOR: 50 FTS: AWGRS Job Scope: SSSV Design H2S Level: Problem Description Install new K SSSV design per State requirements Initial Problem Review Remedial Plan -WIRELINE ACTION Install K valve as per the attached design For HES Shop set up only: HES set up 4.5"K valve with closing pressure at 60 degrees of 505 psi DSO well needs to flow at a Pwh of greater than 404 psi. Valve set to close a Pwh less than 404 psi. Date Work Completed Well Status/Results Date _ by Problem Resolved ? Y N Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate(STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? CLP (psi)/Steady? MAINTENANCE ONLY (e.g. Fix AC, Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g.deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: / / Follow-up Recommendations: • • "K"Valve Calculation Sheet Well 04-40 Date: 10/13/16 Test Data Test Date 10/08/16 Gross Fluid Rate 6972 BLPD Flowing Well Head Pressure 404 psi Flowing Well Head Temperature 137 deg F GOR 16268 scf/bbl TGLR 492 scf/bbl Flowing Pressure Calculations Based on data collected from downhole pressure gauges "K"Valve Setting Depth MD 2106 ft Flowing Tubing Pressure With Gas Lift 404 psi Valve set to close at 404 psi Pwh Flowing Tubing Pressure depth @ 404 psi Pwh 795 psi Flowing Tubing Temperature depth @ 404 psi Pwh 153 degrees "K" Valve Test Rack Set Pressure at 60 deg F ( 505 !psi Valve Size &Volume Ratio 4-1/2" 1.314 NOTE: Well needs to flow at> 404 Pwh Valve set to close at less than 404 psi Pwh • • � I Tubing Pressure at Valve 795 BPT(psis) 809 >1238 <1238 Temperature (deg F) at Valve 153 a 1.711E-05 2.84022E-05 b 1.213714 1.179862 Base Pressure 686.603589 c -834.231 -809.61018 Base Temp (TV-60) 93 680.80266 675.2155436 Corrected Pressure 675.215544 psis TCF 0.83421738 /olume Ratio for Valve Size = 1.314 Pb @ 60 = 663.202813 Test Rack Pressure = 505 I Volume Ratios 4 1/2" & 5 1/2" 1.314 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 • N• O 0 0 0 0 0 0 0 r, co W O O CO CO CO d- N to CC) • 5 N "c � c0N � C- � U • C) 0 0C) 0 0 '4tNcoocooN.- c- c) O LOOCONtON O) co tC) O CO 0 cr O M co co C)) N-N CO N- CO F— CV M CD 0) CO 0) O N CO CO CO CO N N O CA M O N- N- CO U r CO f� O cr N M O 0) O N V- CO CA CO 0 CO M CO 0) C)) 0000 COO CCO C) V 0 03 4'j 0cz Q Mme' rt1 N N 0) CO M CO N CM C)) OC 7 M N M CSO N c00 CO 000 WMM I- 0 0 0 0 0 0 O O co co co 02 L- CO nom a) J —IU co ' 0 _ 2E 1,6 4 N up UP 4t 01 4t � N r- N ai U co co co O C7LO LO CV N r 00 M N L 4'' O f,- d' CO CO OO _O 00 O C)) W C(0 M to CA co N-J W W ct F- o,0 Q Q CF- WOO •yOU W W O O U O c Z Z Z Z ZWWW m m m m 0 D F- ~ Z D D D D O U) Z Z F- F- F- F- • • CD of m N CO 0) CO f- t- i- CO ct N t O O r- N O) 0) Nr CO N _ O 6 O) M N ‘-- LC) 00 y co to O) co ' Cp 0) CA CD r- ❑ CO N- N.- CO CO CO CO CO 0) 0) ❑ CO CO CO CO CO CO CO CO CO CO 0. 0 I- N CO CO - - LC) 0) - co ' - w CO — N LO N CO CO CO A M N O CO CO d O N U') Cb a N co O) Cy) O W ❑ Cfl N- N- c o cc co O co M o > • c000cococoaococococo 0 ce w ❑ ❑ 0 co w ❑ IW- H a w 53Y ( ° 'o to ° O „.< Y Y I_ r 0 0 Lf� O Cp I,- O . 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Eta5 L 2 Y W V O U O_ •lam L M v i a) YMm1-- CO CI U U) U) J LL ^(O L L L L O (1) a) ) (1) Y Y C.) (0 (0 (0 (0 W CO CO CO CO t+ CO N N N CO N. E ti v t N V V CO N CO Q > (3) O Cr) M Lf) N 1� NrO.3 N O c- �- CO O) N (- /� O m CI- C C 03 N M N dCfD G, , OM � r- � cS U) N c .- coeco 00 Cco CO 0) CUCL o' er o' � Y Y Y a) WUUWO O. >'Ua. aUa O_ m m O_ m 1- 1- I- a) E c aa ZNvd- vvv � • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, October 10, 2016 5:23 AM To: AK, OPS FS2 Field OTL;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 OSM;AK, OPS FS2 Facility OTL;AK, OPS FS2 DS Ops Lead; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers;G GPB FS2 Drillsites;AK, GWO SR Slickline WSL; Stechauner, Bernhard; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO Gas Lift Engr;AK, GWO SR Slickline WSL; Catron, Garry R(Wipro); Stahl, Randy; Stair, Kelley;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J Subject: NOT OPERABLE: Producer 04-40 (PTD#1911340) Flow for K-Valve Design All, Producer 04-40(PTD#1911340)flowed for 7 days with memory pressure gauges set in the subsurface safety valve nipple, in order to collect data for K-valve design optimization.As of this morning,the well has been shut in,and Slickline is in the process of pulling the downhole gauges.The well is reclassified Not Operable. Work Completed/Plan Forward: 1. Operations: Flow well Under Evaluation for maximum 14 days—Completed 10/10/16 2. Well Integrity Superintendent: Reclassify Not Operable—Completed 10/10/16 3. Slickline: Pull downhole gauges—In Progress 4. Gas Lift Engineer/Anchorage PE/PDC: Submit proposed K-valve design to AOGCC via 10-403 5. Slickline: Set K-valve 6. WI SUPT: Reclassify Operable 7. Full Field Well Ops Compliance Rep: Schedule AOGCC K-valve flow test within 5 days of POP Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) SCANNED FEB 2 ' 2017 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWellIntegritvCoordinator@BP.com From: A', e UPT Well Integrity Sent: Monday, Octobe : 2016 7:34 AM To: AK, OPS FS2 Field OTL; AK, •' DS Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; Cismoski, Doug A; Daniel, Ryan; A' PB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS Prod Controllers; G GPB F ites; Stechauner, Bernhard; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO Co etions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AK, GWO Gas Lift Engr; AK, GWO SR S i e WSL; Catron, Garry R 1 • ! Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, October 03, 2016 7:34 AM To: AK, OPS FS2 Field OTL;AK, OPS FS2 DS Ops Lead;AK, OPS FS2 OSM;AK, OPS FS2 Facility OIL;AK, OPS FS2 DS Ops Lead;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; G GPB FS2 Drillsites; Stechauner, Bernhard; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO Gas Lift Engr;AK, GWO SR Slickline WSL; Catron, Garry R(Wipro); Stahl, Randy;Stair, Kelley;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy; Worthington,Aras J Subject: UPDATE 10/03/16: UNDER EVALUATION: Producer 04-40 (PTD#1911340) Flow for K- Valve Design All, Producer 04-40(PTD#1911340)was placed on a 14-day Under Evaluation clock on 09/22/16.The well has memory pressure gauges set in the Subsurface Safety Valve nipple.The intent was to bring the well online shortly thereafter and flow the well for a maximum of 14 days,to collect data to optimize K-valve design. 3 days remain in the original Under Evaluation period, but the well has not yet been brought online. It will be brought online today. The Under Evaluation period is extended for an additional 14 days, in order to flow the well with downhole gauges in place and collect the required data for K-valve optimization.The well must be shut in on or before 10/17/16. Plan Forward: 1. Operations: Flow well Under Evaluation for maximum 14 days 2. Slickline: Pull downhole gauges 3. Well Integrity Superintendent: Reclassify Not Operable 4. Gas Lift Engineer/Anchorage PE/PDC:Submit proposed K-valve design to AOGCC via 10-403 5. Slickline: Set K-valve 6. WI SUPT: Reclassify Operable Please reply if in conflict with proposed plan. Thanks, SCANNED FEB 1 32017 Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, GWO SUPT Well Integrity Sent: Thursday, September 22, 2016 3:43 PM NOT OPERABLE: Producer 04 -40 (PTD #1911340) Failing MIT -T • Page 1 p 2 Regg, James B (DOA) • From: Reynolds, Charles (Alaska) [Charles.Reynolds @bp.com] '\ Z (0\1 fit Sent: Thursday, October 06, 2011 9:44 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Daniel, Ryan; Igbokwe, Chidiebere Cc: Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: NOT OPERABLE: Producer 04-40 (PTD #1911340) Failing MIT -T All, Producer 04 -40 failed an MIT -T on 10/4/2011 after a tubing tail plug was set. This failed test demonstrates a lack of two competent barriers. The well is currently secured with a plug and is reclassified as Not Operable. Thank You, Charles Reynolds Filling in for... Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, September 16, 2011 8:31 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'S wartz, Guy L (DOA)'; AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; A *PS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D &C Wireline Operations Team Lead; AK, D &C W: Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Arend, Jon (NORTHERN SO ONS LLC); Reynolds, Charles (Alaska) Subject: UNDER EVALUATION: Producer 04-0 (PTD #1911340) Sustained Casing Pressure on IA Above MOASP All, Producer 04 -40 (PTD #1911341 has been confirmed to have sustained casing pressure on the IA above MOASP. The tubing /IA/OA -re equal to 2000/2210/20 on 09/13/2011. The well failed a TIFL and has been reclassified as Under ' valuation. The plan forward is: 1. Downhole Diagnostics: TIFL - FAILED 10/7/2011 UNDER EVALUATION: Producer 0.0 (PTD #1911340) Sustained Casing *sure on IA Ab... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Friday, September 16, 2011 8:31 PM ( 4/ j(1(lt To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS2 OSM; AK, OPS FS2 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Reynolds, Charles (Alaska) Subject: UNDER EVALUATION: Producer 04 -40 (PTD #1911340) Sustained Casing Pressure on IA Above MOASP Attachments: 04- 40.pdf; 04 -40 TIO Plot 09- 16- 11.doc All, Producer 04 -40 (PTD #1911340) has been confirmed to have sustained casing pressure on the IA above MOASP. The tubing /IA/OA were equal to 2000/2210/20 on 09/13/2011. The well failed a TIFL and has been reclassified as Under Evaluation. The plan forward is: 1. Downhole Diagnostics: TIFL - FAILED / k ! J 2. Slickline: Change out orifice gas lift valve 3. Pumping: MIT -T, CMIT -TxIA A wellbore schematic and TIO Plot are included for reference: «04- 40.pdf» «04 -40 TIO Plot 09- 16- 11.doc» Thank you, Mehreen Vazir (Alternate Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 9/19/2011 PBU 04 -40 PTD # 1911340 9/16/2011 TIO Pressures Plot Well: 04 -40 4,000 • 3,000 — Tbg f IA 2,000 41.8440P ■ - M - OA 00A — * -- 000A On 1,000 • 06118/11 06/25/11 07/02111 07/09/11 07/16/11 07/23/11 07/30/11 08/06/11 08/13/11 08/20/11 08/27/11 09/03/11 09/10/11 TREE = CIW SAFETY ES : WELL REQUIRES A SSSV WELLHEAD = FMC , " " "CHRO.NR & TBG " " ACTUATOR = BAKER C KB. ELEV = 60' _ BF.ELEV= ■ r i " 2016' H4-1/2" HES X NIP, ID = 3.813" I KOP = 4500' Max Angle = 33° @ 6700' ! j �� I 3132' 1-17-5/8" HES ES CEMENTER I Datum MD = 9474' a 3154' H7-5/8" ECP PKR I Datum ND = 8800' SS + GAS LIFT MANDRELS E I ST MD I N D I DEV I TYPE VLV I LATCH PORT DATE t 4 1 8 2833 2832 2 TE -TMPD DOME BK 16 04/18/09 7 -5/8" BOWEN CSG PATCH, 29.7 #, —I 3190' I L • 7 4537 4532 12 TE -TMPD DMY BK 0 04/15/09 L -80 TCII, ID = 6.875" 6 5236 5192 25 TE -TMPD DOME BK 16 04/18/09 5 5935 5799 31 TE -TMPD SO BK 24 04/18/09 10 -3/4" CSG, 45.5 #, L -80, ID = 9.953" H 3492' f 4 6425 6218 32 TE -TMPD DMY BK 0 04/15/09 3 6872 6596 31 TE -TMPD DMY BK 0 04/15/09 2 7361 7012 31 TE -TMPD DMY BK 0 04/15/09 Minimum ID = 2.25" @ 9379' 1 7806 7396 30 TE -TMPD DMY _ BK _ 0 04/15/09 2 7/8" OTIS XN NIPPLE ' I 8296' H4-1/2" HES X NIP, ID = 3.813" I X f 8317' H7-5/8" X 4 -1/2" S -3 PKR, ID = 3.87" I 1 I I 8341' H4 -1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, --f 8436' I \ i 1 8436' I- 14 -1/2" X 3 -1/2" XO, ID = 2.992" I .0152 bpf, ID = 3.958" 8441' 1- 7 -5/8" X 3 -1/2" BKR SB -3A HY D PERM PKR, ID = 3.00" <_______ 8445' 1-15" MILLOUT EXTENSION, ID = 4.50" f 8446' H3-1/2" MULESHOE, ID = 2,992 "? I 8450' H5" 5" X 3-1/2" XO, ID = 3.00" (o I. p .¢ PRODUCTION MANDRELS ii 3 -1/2" TBG, 9.3 #, 13CR FOX. 8696' ® MD ND DEV TYPE VLV LATCH PORT DATE 9 8595 8075 29 TE -TGPDX DMY TG 0 03/20/92 .0087 bpf, ID = 2.992" 1 10 8669 8139 28 TE -TGPDX DMY RK 0 04/09/92 5 -1/2" TIEBACK SLV, ID = 5.75" I-1 8737' I 8693' - 13 -1/2" PKR SWN NIP, ID = 2.75" I 7 -5/8" X 5 -1/2" PKR & LNR HGR, ID = 5.875" I 874-1_ 5 ' 7 -5/8" CSG, 29.7 #, L -80 BTC-M, ID = 6.875" I-1 9030' 8606'- I3 -1/2" X 2 -718" XO, ID = 2.44" I PERFORATION SUMMARY REF LOG: BHCS ON 12/05/91 9204' - 9222' H 2 -7/8" BLAST JOINTS, ID = 2.44" I ANGLE AT TOP PERF: 25° @ 9210 9315' -15-1/2" X 2 -7/8" BKR FB -1 PERM PKR, ID = ?" I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Syz DATE L_ 9317' -1 SEAL BORE EXTENSION, ID = 3.00 I 2 -1/8" 2 9210 - 9220 0 04/10/92 _ 9323' -Ft" MILLOUT EXTENSION, ID = 3.50" I 2" 6 9330 - 9350 0 04/17/10 2" 6 9395 - 9405 0 04/17/10 I 9328' --14" X 2 -7/8" XO, ID = 2.44" I 2 -1/8" 2 9438 - 9450 0 02/10/95 I 9379' - 12-7/8" OTIS XN NIP, ID'" 2.25" I 2 -1/8" 4 9458 - 9466 0 06/25/94 2 -1/8" 4 9467 - 9477 0 02/22/94 -- I 9391' - 12 -7/8" BKR SHEA ROUT SUB, ID = 2.44" I 2 -1/8" 4 9486 - 9510 S 06/04/93 ` "---1 9392' —12-7/8" WLEG, ID = 2.44" I 2 -1/8" 4 9486 - 9510 0 06/20/93 2 -1/8" 6 9511 - 9529 S 06/04/93 L 9390' —LEWD TT LOG NOT AVAILABLE I 2 -1/8" 4 9514 - 9532 S 06/04/93 9562' I PBTD 12 -7/8" TBG, 6.4 #, 13CR -80, .0058 bpf, ID = 2.441" H 9392' + #11�� 4 X46., , I 5 -1/2" LNR, 17 #, 13CR -80, .0232 bpf, ID = 4.892" H 9643' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/11/91 N28E ORIGINAL COMPLETION 12/17/10 MB /JMD ADDED SSSV SAFETY NOTE WELL: 04 -40 04/16/09 D14 RWO PERMIT No: 1911340 04/18/09 TLH GLV C/O 1 API No: 50- 029 - 22224 -00 04/23/09 TLH CORRECTIONS SEC 34, T11 N, R15E, 1268' FNL & 306' FEL 06/17/09 AW /JMD DRLG DRAFT CORRECTIONS 04/22/10 JMF /SV ADD PERF (04/17/10) BP Exploration (Alaska) STATE OF ALASKA ~~~~ ALASKA AND GAS CONSERVATION COMMISSI~ REPORT OF SUNDRY WELL OPERATIONS AFR 2 ~ 201Q 1.Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time ensi ~ ~~' ~Ot>ytTUSSK~r ~~ii Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-ent Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory ^ 191-1340 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-22224-00-00 8. Property Designation (Lease Number) 9. Well Name and Number: ADLO-028325 ~. PBU 04-40 10. Field/Pool(s): PRUDH OE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9643 feet Plugs (measured) None feet true vertical 9008.55 feet Junk (measured) None feet Effective Depth measured 9558 feet Packer (measured) 8317 8441 9315 true vertical 8934 feet (true vertical) 7833 7940 8788 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 Surface - 110 Surface - 110 1490 470 Surtace 3492 10-3/4" 45.5# L80 Surface - 3492 Surface - 3491 3580 2090 Intermediate 9030 7-5/8" 29.7# L-80 Surface - 9030 Surtace -8461 6890 4790 Production Liner 906 5-1/2" 17# 13Cr80 8737 - 9643 8199 - 9009 7740 6280 Liner Pertoration depth: Measured depth: see attached - True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 30 -8422 30 - 7924 3-1/2" 9.2# 13Cr80 8422 - 8696 7924 - 8163 2-7/8" 6.4# 13Cr80 8696 - 9392 8163 - 8788 Packers and SSSV (type, measured and true vertical depth) 7-5/8"X4-1/2" S-3 PKR 8317 7833 4-1/2" Baker SB-3A HYD PERM PKR 8441 7940 2-7/8" Baker FB-1 PERM PKR 9315 8788 12. Stimulation or cement squeeze summary: Intervals treated (measured): `~,-;~~`~°~ `-~ ~~° ,. '~ ~ fi ~~ t '~ 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: 13 1936 3177 237 Subsequent to operation: SI 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run \ Exploratory^ Development Q Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ 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: N/A Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature Phone 564-4944 Date 4/20/2010 Form 1 04-40 191-134 PERF OTTO[:HMFNT L J • Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04-40 12/12/91 PER 9,210. 9,220. 8,623.82 8,632.92 04-40 4/10/92 APF 9,486. 9,510. 8,870.89 8,891.97 04-40 4/10/92 APF 9,529. 9,532. 8,908.64 8,911.27 04-40 4/10/92 RPF 9,514. 9,529. 8,895.48 8,908.64 04-40 9/19/92 RPF 9,486. 9,510. 8,870.89 8,891.97 04-40 9/19/92 RPF 9,511. 9,529. 8,892.84 8,908.64 04-40 3/30/93 SQZ 9,210. 9,532. 8,623.82 8,911.27 04-40 6/4/93 SQZ 9,210. 9,532. 8,623.82 8,911.27 04-40 6/20/93 RPF 9,486. 9,510. 8,870.89 8,891.97 04-40 2/22/94 APF 9,467. 9,477. 8,854.15 8,862.97 04-40 6/25/94 APF 9,458. 9,466. 8,846.21 8,853.27 04-40 2/10/95 APF 9,438. 9,450. 8,828.51 8,839.13 04-40 6/6/05 BPS 8,432. 9,643. 7,932.58 9,008.55 04-40 4/9/09 BPP 8,432. 9,643. 7,932.58 9,008.55 04-40 4/17/10 APF 9,330. 9,350. 8,732.16 8,750.08 04-40 4/17/10 APF 9,395. 9,405. 8,790.28 8,799.19 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 • • 04-40 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/14/2010 '*"W ELL S/I ON ARRIVAL"*" (pert) DRIFT TBG W/TEL, 2.10" DUMMY GUN & 1 3/4" S-BAILER (empty) LOC TT @ 9366' SLM/9392' MD (26' CORR) TAG TD @ 9482' SLM/9508' MD (2' OF FILL ABOVE BOTTOM OPEN PERF) ' T/I/0=2400/1270/0 '""'WELL LEFT S/I, DSO NOTIFIED*''* 4/17/2010 ***WELL SHUT IN ON ARRIVAL*** (E-LINE: PERFORATING) INITIAL T/I/O: 2300/1300/0 PSI. RUN 1: PERF INTERVAL: 9395' - 9405' RUN 2: PERF INTERVAL: 9330' - 9350' ', 2" HSD POWERJET 2006 HMX, PENETRATION DEPTH: 18.6" HOLE SIZE: 0.20" 'FINAL T/I/O: 2300/1300/0 ''*"*JOB COMPLETE'"*" FLUIDS PUMPED BBLS 1 DIESEL 1 Total ~_ WELL}iEAD = FMC 'ACTUATOR= BAKERC KB. ELEV = 60' BF. ELEV = ? KOP = 4500' Max Angle = 33° @ 6700' 'Datum MD = 9474' Datum TV D = 6800' SS 7-5/8" BOWEN CSG PATCH, 29.7#, L-80 TGI, ~ = 6.875" 10-314" CSG, 45.5#, L-80, ID = 9.953" ~ 04-40 Minimum ID = 2.25" @ 9379' 2 7/8" t3TIS XN NIPPLE 4-112" TBG, 12.6#, 13CR 80 VAM TOP, .0152 bpf, ID = 3.958" 3-112" TBG, 9.3#, 13CR FOX, .0087 bpf, ID = 2.992" 5-1 /2" TIEBACK SLV, ID = 5.75" (-j 8737' 7-518" X 5-1/2" Ft<R & LNR HGR ID = 5.875" 8745' 7-5/6" CSG, 29.7#, L-80 BTGM, ID = 6.875" 9030' PERFORAT~N SUMMARY REF LOG: BHCS ON 12/05/91 ANGLE AT TOP PERF: 25° @ 9210' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2-1/8" 2 9210 - 9220 O 04/10/92 2-1/8" 2 9438 - 9450 O 02/10/95 2-1/8" 4 9458 - 9466 O 06/25/94 2-1/8" 4 9467 - 9477 O 02/22/94 2-1/8" 4 9486 - 9510 S 06/04193 2-1 /8" 4 9486 - 9510 O 06120!93 2-1/8" 6 9511 - 9529 S 06!04193 2-1/$" 4 9514 - 9532 S 06/04193 2-7/8" TBG, 6.4#, 13CR-80, .0058 bpf, ID = 2.441" i-1 939Z, 5-1i2" LNR 17#, 13CR-80, .0232 bpf, ID = 4.892" 9643' SAFETY Nom: """CHROM E LNR & TBG*"* 2016' -{4-1/2" HES X NIP, ID = 3.813" 3132' 7-518" HES Es CBNEMFR~ 3154' 7-5/8" ECP PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 2833 2832 2 T~TM DOME BK 16 04/18/09 7 4537 4532 12 TE TM DMY BK 0 04115!09 6 5236 5192 25 TE~TM DOME BK 16 04/18/09 5 5935 5799 31 TE-TM SO BK 24 04/18/09 4 6425 6218 32 T6-TM DMY BK 0 04115/09 3 6872 6596 31 TE TM DMY BK 0 04/15/09 2 7361 7012 31 TE- DMY BK 0 04/15!09 1 7806 7396 30 TE DMY BK 0 04/15/09 8296' 4-1/2" HES X NP, ID = 3.813" 8317' (- j 7-5/8" X 4-1 /2" S-3 PKR, ID = 3.87" $341' 4-1l2" HES X N~, ID = 3.813" 8436' 4-1/2" X 3-1/2" XO, ID = 2.992" 8441' 7-5i8" X 3-1/2" BKR SB-3A HYD PERM PKR, ~ = 3.00" $44$' 5" M~LOUT IXTENSION, ~ = 4.50" $446' 3-1/2" MULESHOE, ID = 2.992"? 8450' 5" X 3-112" XO, ~ = 3.00' PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 10 8595 8669 8075 8139 29 28 TE-TGPDX TETGPDX Guff' DMY TG RK 0 0 03/20/92 04/09/92 869 3-1/2" PKR SWN N~, ~ = 2.75" 3-1 /2" X 2-7/8" XO, ~ = 2.44" 9204' - 9222' ~-j 2-7/8" BLAST JOYVTS, ~ = 2.44" i 9315' 5-112" X 2-7l8" BKR FB-1 PERM PKR ID = ?" 9317' SEAL BORE EXTETISION, D = 3.00 9323' 4" MILLOUT IXTFTlSION, m = 3.50" 932$' 4" X 2-718" XO, ~ = 2.44" 9379' 2-7/8" OTIS XN NF', ID = 2.25' 9391' 2-7/8" BKR SHEAROUT SUB, ~ = 2.44" 9392' 2-7/8" WLEG, ID = 2.44" 9390' ELMD TT LOG NOT AVA~ABLE 9[- 562' ~ PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 12/11191 N28E ORIGINAL COMPLETION 04/16!09 D14 RWO 04/18!09 TLH GLV C!O 04!23/09 TLH CORRECTIONS 06/17/09 AW/JMD DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 04-40 PERMIT No: 1911340 API No: 50-029-22224-00 SEC 34, T11 N, R15E, 1268' FNL & 306' FEL BP Ezploratian (Alaska) STATE OF ALASKA +lV~ ~'"G~~ s ' ALA OIL AND GAS CONSERVATION CO~SION REPORT OF SUNDRY WELL OPERATIONS~~~ ~ ~ ~~~~ ~lask~ Uil ~ C~l~~ Cnlt.~~ ~+DrOmitsinn 1. Operations Performed: AfiCh4i9 ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® 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: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. - ®Development ^ Exploratory 191-134 ' 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22224-00-00 - 7. KB Elevation (ft): 60,, 9. Well Name and Number: PBU 04-40 - 8. Property Designation: 10. Field /Pool(s): ADL 028325 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 9643' - feet true vertical 9009'- feet Plugs (measured) None Effective depth: measured 9558' feet Junk (measured) None true vertical 8934' feet Casing Length Size MD TVD Burst Collapse Structural Conductor -110' 20" -110' 110' 1490 470 Surface 3492' 10-3/4" 3492' 3491' 3580 2090 Intermediate 9030' 7-5/8" 9030' 8461' 6890 4790 Production Liner 906' S-1/2" 8737' - 9643' 8199' - 9009' 7740 6280 ' ' ' ~~~'' " ~` ~~ Perforation Depth MD (ft): 9210 - 9510 ~ ~~' Perforation Depth TVD (ft): 8624' - 8892' a-v2°, ~2s# x s-vz°, ss# x 2ais°, s.a# 13Cr80 9392' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7-5/8" x 3-1/2" Baker'SB-3A' packer; 8425'; 5-1/2" x 2-7/8" Baker'FB-1' packer 9315' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 8408'. Cut and pull 7-5/8" casing from 3187'. Run 7-5/8" (29.7#, L-80, TCII) tieback to surface. Cement w/ 150 bbls Yield 1.17, Class 'G' w/ Gas-Blok 842 cu ft / 720 sx . Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 Subsequent to operation: 402 6865 8709 1550 270 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®~OlI ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA 'rf C.O. Exempt: Contact Aras Worthington, 564-4102 309-092 Printed Name Sondra Stewman. Title Drilling Technologist t Prepared By Name/Number: Si n tune ` r Phone 564-5743 Date °Q Sondra Stewman 564-4750 Form 10-404 evised 04/2006 Submit Original Only a ! ~f I TREE= MCEVOY 4-1/16" WELLHEAD =FMC GEN N ACTUATOR = OTIS KB. ELEV = 60' BF. ELEV = __ _._ .~ KOP 4500' Max Angle = 33 @ 6700' Datum MD = 9474' Datum TVD = 8800' SS • ~. ~~® 04-40 SA~ NOTES : ***CHROM E LNR 8~ TBG*** 7-5f8" CSG; 29.7#, L-80, TGII Cemented to Surface 3186® 10-3/4" CSG, 45.5#, L-80, ID = 9.953" ~ 3492' Minimum ID = 2.25" @ 9379' 2 7/8" OTIS XN NIPPLE 4-112" TBG, 12.6#, 13CR-80, .0152 bpf, 1D = 3.958" ~~ 831T 13-1/2" TBG, 9.3#, 13CR, .0087 bpf, ID = 2.992" I ~5-1/2" TIEBACK SLV, ID = 5.75" I-i sr~,~r 7-5/8" X 5-1 /2" PKR & LNR HGR, ID = 5.875" 8745' 7-5/8" CSG, 29.7#, L-80 BTGM, ID = 6.875" ~ 9030' 2-7/8" TBG, 6.4#, 13CR-80, .0058 bpf, ID = 2.441" 9391' PERFORATION SUMMARY REF LOG: BHCS ON 12/05/91 ANGLE AT TOP PERF: 25° @ 9210' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 2 9210 - 9220 O 04/10/92 2-1/8" 2 9438 - 9450 O 02/10/95 2-1/8" 4 9458 - 9466 O 06/25!94 2-118" 4 9467 - 9477 O 02/22/94 2-1/8" 4 9486 - 9510 S 06/04/93 2-1/8" 4 9486 - 9510 O 06/20/93 2-1/8" 6 9511 - 9529 S 06/04/93 2-1/8" 4 9514 - 9532 S 06/04/93 5-1/2" LNR, 17#, 13CR-80, .0232 bpf, ID = 4.892" I-I 9643' 2916' 4-1r2" X NIPPLE, ]D = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 8 2833 2834 2 KBMG DOME BK 16 04!18/09 7 4537 4533 12 KBMG DMY BK 0 04/15!09 6 5236 5192 25 KBMG DOME BK 16 04!18/09 5 5935 5799 31 KBMG SO BK 24 04/18/09 4 6425 6218 32 KBMG DMY BK 0 04/15/09 3 6872 6596 32 KBMG DMY BK 0 04/15/09 2 7361 7013 31 KBMG DMY BK 0 04/15/09 1 7806 7396 30 KBMG DMY BK 0 04/15/09 - $295' - j4 112" X-nipple 3.813" ID 8317' 4 112°' x 7 5?8" S-3 Packer $341' 4 112" X-n€ppJe 3.813" ID 8435' 4 1/2" x 3 1i2" XO 2,99" ID $445° 3 1/2" 9.6# 13ar pup ~v r muleshoe 8425' 7-5/8" X 3-1/2" BKR SB-3A HY D PERM PKR, ID - 3.00" $445' 5" MILLOUT EXTENSION, ID = 4.50" 8450' S" X 3-1/2" XO, ID = 3.00" PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 10 8595 8669 8075 8139 29 28 TE-TGPDX TE-TGPDX DMY DMY TG RK 0 0 03!20/92 04/09/92 8693' I-~3-1/2" PKR SWN NIP, ID = 2.810" 8696' 3-1/2" X 2-7/8" XO, ID = 2.44" j 9204' - 9222' ~~ 2-7/8" BLAST JOINTS, ID = 2.44" 9315' 5-1/2" X 2-7/8" BKR FB-1 PERM PKR, ID = 3.00" 9317' SEAL BORE EXTENSION, ID = 3.00 9323' 4" MILLOUT EXTENSION, ID = 3.50" g32g' 4" X 2-7/8" XO, ID = 2.44" 9379' 2-7/8" OTIS XN NIP, ID = 2.25" 9391' 2-7/8" BKR SHEAROUTSUB, ID = 2.44" 9392' 2-7/8" WLEG, ID = 2.44" 9390' ELMD TT LOG NOT AVAILABLE 9562' I-i PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 12/11/91 N28E ORIGINAL COMPLETION 03/13/08 RC/PJC DRAWING CORRECTIONS 04/16/09 D14 RWO 04/18/09 TLH GLV C/O 04/23/09 TLH CORRECTIONS PRUDHOE BAY UNff WELL: 04-40 PERMff No: 1911340 API No: 50-029-22224-00 SEC 34, T11N, R15E, 1268' FNL & 306' FEL BP Exploration (Alaska) • PBU 04-40 Well History Date Summary 03/13/09 PULL P-PRONG FROM 2,226' SLM W/2" JDC PULL 2-7/8" PLUG BODY FROM 2,235' SLM RAN 2'x 1-7/8" STEM, 3.84" GAUGE RING TO 2,202' SLM CURRENTLY ATTEMPTING TO PULL KB PACKER FROM 2,202' SLM 03/14/09 PULLED KB PATCH FROM 2,202' SLM (35' OAL, ALL ELEMENTS RETRIEVED) RAN FLAPPER CHECKER TO 2,222' SLM, FLAPPER FUNCTIONING PROPPERLY ***CONTROL LINE ON THE FRONT SIDE OF THE WELL HEAD*** RAN 3.75" 3.80" BARBELL SET UP W/ 3.80" LIB, UNABLE TO PASS 1284' SLM RAN 4 1/2" BRUSH AND 3.805" GAUGE RING SD ~ 1285' SLM UNABLE TO PASS 1335' SLM RAN 2.72" LIB ON BARBELL SETUP, WORK PAST 1335' SLM, SD 8412' SLM, GOOD. IMPRESSION OF IBP FISHNECK SET 4-1/2" SLIP STOP CATCHER SUB C~ 2530' PULLED 1" (M-LATCH) AVA BRAIN FROM TRSSSV AT 2,216' SLM 03/15/09 MADE SEVERAL ATTEMPTS TO SET 1"AVA LOCK OUT BRAIN AT 2,216' SLM TIGHT SPOTS IN TBG FROM 1800' SLM TO 1950' SLM HYDRATES FOUND IN TOOLS SUSPECT ALSO CAUSING PROBLEMS IN TUBING TROUBLESHOOTING TUBING RESTRICTIONS LAY DOWN FOR WEATHER -41 F, TAKE EQUIPMENT TO WCP FOR MAINTENANCE ****NO OPERATING BRAIN IN AVA TRSSV, FLAPPER CLOSED**** ***THERE IS A 4 1/2 SLIP STOP SET C~3 2530'*** 03/18/09 ***WELL S/I ON ARRIVAL*** (pre rwo) PUMPED 10 BBLS METH DOWN TUBING BRUSHED TUBING TO 2,219' SLM W/ 3.83" NO-GO CENT, 4'x1/7/8" STEM, 4-1/2" BLB MADE SEVERAL ATTEMPTS TO SET AVA LOCK OUT BRAIN ***RUNNING TOOL AND AVA BRAIN LOST IN HOLE AT SVLN (2,192' MD)*** RAN 3.83" NO-GO CENT W/AVA SPACER,MERLA TMP, 1.40" LIB (MARKS INCONCLUSIVE) CURRENTLY ATTEMPTING TO FISH RUNNING TOOL, AVA LOCK OUT BRAIN FROM FLAPPER AT 2,216' SLM ***THERE IS A 4 1/2 SLIP STOP SET C~? 2530'*** 03/19/09 MULTIPLE ATTEMPTS TO FISH RK-1 RUNNING TOOL AND 1"AVA LOCK OUT TOOL (1-3/16 FN ON RK-1, .875 F.N. ON LOCK OUT BRAIN) ***THERE IS A 4 1/2 SLIP STOP SET C«~ 2530'*** 03/20/09 ATTEMPT TO FISH AVA LOCK OUT TOOL FROM AVA TRSSSV AT 2,221' SLM ***4 1/2 SLIP STOP SET Q 2530'*** 03/21/09 MADE MULTIPLE ATTEMPTS TO PULL RK-1 RUNNING TOOL AND AVA LOCK OUT BRAIN FROM TRSSV 03/22/09 ATTEMPTED TO FISH RK-1 RUNNING TOOL AND AVA LOCK OUT TOOL RK-1 RUNNING TOOL 2,213' SLM FISHING NECK 1-3/16" 1"AVA LOCK OUT BRAIN 2,213' SLM F.N..875" FISHING NECK T 900/ IA 860/ OA 20 TBG.F/L APPEARS TO BE Q 1318' SLM 4 1/2" SLIP STOP CATCHER SUB LEFT IN HOLE C~ 2533' SLM, (TRSSSV NONFUNCTIONAL ) 03/24/09 T/I/O = 870/870/20. Temp=S1. Depress TBG FL to 2500' (call-in). Flow line disconnected. Integral on flow cross companion and IA. T8G FL ~ 1410' (22 bbls). IA FL C~3 1326'. Injected gas to TBG from 04-01. IAP began tracking TP immediately. Injected for 1 hr, TP=1550, IAP=1550, TBG & IA FL unchanged. Monitor for 1 hr. TP, TBG FL, IAP, & IA FL unchanged. Final WHPs=1550/1550/20. Page 1 of 3 • PBU 04-40 Well History Date Summary 03/27/09 TAGGED 4 1/2" AVA TRSV C~ 2,223' SLM W/ 3.83" NO-GO CENT. RAN 3.83" NO-GO CENT, FLAPPER CHECKER TO 2,221' SLM (trsv flapper closed) CURRENTLY GETTING TOOLS TOGETHER TO FISH RUNNING T~nl FRC)M AVA TRSV 03/28/09 RAN 1 " POCKET POKER W/ TT-PINTO 2,229' SLM (tt -pin untoched, no marks on poker) TAGGED SIDE POCKET W/ 1.70" L.I.B. ~ 2,231' SLM (inconclusive marks on 2 - LIB's) TAGGED SIDE POCKET W/ 1.25" L.I.B. C~ 2,231' SLM (inconclusive marks on 2 - LIB's) RAN 2.30" MAGNET TO AVA TRSV FLAPPER Q 2,241' SLM. NOTHING RECOVERED. RAN MERLA TMP W/ 1.85" MAGNET TO 2231' SLM. NOTHING RECOVERED. MADE 1 ATTEMPT TO LATCH 1 "AVA BRAIN W/ MERLA TMP, 1-1/4" JDC (unable to latch, no metal marks) RAN MERLA TMP, 1-1/2" JDS TO 2,231' SLM, UNABLE TO LATCH JK-2 (skirt egged, see log) MADE 2 RUNS W/ MERLA TMP, 1.74" x 16" SPOON TO 2,231' SLM TO DISLODGE JK /AVA BRAIN (no luck) 03/29/09 PUMPED -3 GALS HYD DOWN CONTROL LINE. NO PRESSURE GAIN. MADE SEVERAL ATTEMPTS TO PULL /DISLODGE AVA BRAIN / JK-2 (see loq for info TAGGED 4-1/2" AVA TRSV @ 2,223' SLM W/ 3.83" NO-GO CENT. (flagged wire) RAN 3.83" NO-GO CENT, FLAPPER CHECKER TO 2,220' SLM (flapper closed) CURRENTLY IH W/ 4-1/2" MERLA TMP, 1-1/4" JD C~ 2,231' SLM 03/30/09 MADE SEVERAL ATTEMPTS TO DISLOGE / PULL JK-RT 1"AVA LOCK OUT BRAIN W/ VARIOUS TOOLS RECOVERED JK-2. 1"AVA LOCK OUT BRAIN FROM 2.231' SLM (m-latch bent & missing 1 collet fin er TAGGED SIDE POCKET C~ 2,230' SLM W/ MERLA TMP, 1.25" L.I.B. (impression of open pocket) CURRENTLY GETTING POCKET POKER MADE UP TO RUN 03/31/09 RAN 4-1/2" MERLA TMP, POCKET POKER W/ TT-PINTO 2,233' SLM (tt-pin indicates pocket clear) SET M-LATCH-1"AVA BRAIN IN AVA TRSV C~ 2,231' SLM TAGGED AVA TRSSSV Q 2,223' SLM W/ 3.83" NO-GO CENTRALIZER RAN 3.83" NO-GO CENT, FLAPPER CHECKER TO 2,223' SLM (trsssv functioning proper) PULLED EMPTY 4-1/2" SLIP STOP CATCHER SUB FROM 2,535' SLM. DHD SHOT FLUID LEVELS: TBG FL = 1254' (19 BBLSI IA FL= 1266' (33 BBLSI LRS PERFORMED SUCCESSFUL CMIT Tx IA TO 1000#. (see log for details) RAN 3.70" CENT 3.25" LIB. TAG 4 1/2" x 3 1/2" XO C~ 8423' SLM im ression of xo.) SET 4 1/2" JUNK CATCHER ~ 8413' SLM. (F.N. ID= 3.23", F.N. OD= 3.75")(BARB L OD= 3.54", BARREL ID= 3")(BTM OD= 3.75", OAL= 113") 03/31/09 T/I/0=190/160/5 Temp=S1 Assist S-Line CMIT TxIA 1000 qsi PASSED (RWO Prep) Pumped 53.9 bbls of 80`" crude down IA to reach 1000 psi for CMIT TxIA 1st test 1st 15 min lost 50/100 psi 2nd 15 min lost 30/20 psi for a total of 80/120 Re-psi w/.5 bbl 2nd test 1st i5 min lost 0/60 psi 2nd 15 min lost 20/20 for a total of 20/80 psi in 30 min Bleed gas gap of TBG IA fluid packed Re-psi w/.5 bbl 3rd test 1st 15 min lost 10/40 2nd 15 min lost 0/0 for a total of 10/40 psi in 30 min Bleed well head psi down Bleed back aprox. 5 bbls Final Whp's=150/150/5 wing shut swab open ssv open casing valves open to gauges Page 2 of 3 • PBU 04-40 Well History Date Summary 04/01/09 RIG UP ELINE, HEAD/WB/CCUSHOCK MANDRELS/3.65" SLB POWER JET CUTTER, LENGTH = 19', MAX OD = 3.65", WEIGHT = 230# CUT TUBING AT 8408', CCL TO TOP SHOT = 8.1', CCL STOP DEPTH = 8399.9' CONFIRMED CUTTER DID FIRE. FINAL T/I/O = 100/120/0 MASTER = 0, SSV = 0, SWAB = C 04/02/09 Circ. Out: CMIT TxIA 1000 psi PASS (RWO Prep) Pumped 5 bbls 60/40 meth, 560 bbls 1 % KCL, 1 bbl 60/40 meth, 83 bbls DSL & 2bbls 60/40 meth down TBG, taking returns up IA to jumper line to well #1. Pumped 10 bbls DSL down jumper line for Freeze Protect. U-tube TBG to IA. CMIT TxIA lost 0/10 psi 1st 15 min, 0/10 psi 2nd 15 min. PASS (2nd test) Bled WHP's to 0 psi. SV, WV=S SSV, MV=O IA, OA=OTG DSO notified and tags hung at departure. FWHP's=0/0/0 04/02/09 T/IA/OA= SI/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (FAIL) (Pre RWO) PPPOT-T RU 2 HP BT onto THA test void, 1600 psi to 0 psi, flushed void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 4850/ 15 minutes, 4800/ 30 minutes. Bled void to 0 psi, RD test equipment. Cycled and torqued "ET style" (1) LDS ~ 9:00 is left in out position hard to cycle, all others were in good working condition PPPOT-IC RU 2 HP BT onto IC test void 0 psi. Attempted to pressure void would not go above 500 psi, bled down to 0 psi. Cycle and torqued LDS "ET style" (1) LDS was not cycled, SSO in way only backed LDS out, all others were in good working condition ""` FMC notified of condition of LDS and will change out LDS on tubing spool during RWO. Per FMC Rob Simpson '*' 04/02/09 TAGGED AVA TRSV W/ 3.84" CENTRALIZER G 2221' SLM SET 4-1/2" HOLD OPEN SLEEVE W/ KEYLESS DB LOCK C~ 2234' SLM. 165" OAL. 04/03/09 T/I/O = 0/120/0 Set 4-1/16" FMC IS-A BPV #540 thru tree Q 84"....1-2' ext. used....pre-rig....no problems. 04/08/09 T/I/O=0/0/0 Pulled 4" FMC ISA BPV, post BOPE test (Doyon 14); 5-5' Ext. used &1-5' centralizer, tagged C~3 76". No problems... 04/16/09 T/I/O 0/0/0 Pulled 4" ciw twc for post tree pt than seta 4" ciw bpv for doyon 14 to move off well used 1-2' 0 = u - t ru tree, post rig. 1-2' ext used, tagged C«3 98". No problems. 04/18/09 PULL BALL & ROD FROM 8330' SLM PULLED BK-DGLV'S FROM STA'S #5 (5932' SLM, 5935' MD) -STA#6 (5229' SLM, 5236' MD) & BEK-DCK FROM STA#8 (2818' SLM, 2833' MD) SET NEW GASLIFT DESIGN IN STA'S # 8 6 & 5 PULLED 4-1/2" RHC BODY FROM 8340' SLM ~~5~ DRIFT TO 8750' SLM W/ 2.125" IBP EO. SLEEVE....IBP ALREADY PULLED Page 3 of 3 BP EXPLORATION Page 1 of 12 Operations Summary Report Legal Well Name: 04-40 !Common Well Name: 04-40 Spud Date: 11/23/1991 'Event Name: WORKOVER Start: 4/5/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/16/2009 Rig Name: DOYON 14 Rig Number: Date. From - To Hours Task Code NPT Phase ', Description of Operations 14/5/2009 18:00 - 20:30 2.501 MOB P PRE Rig Down. PJSM to move off END4-04A. 20:30 - 00:00 ~ 3.50 MOB ~ P 4/6/2009 00:00 - 01:00 1.00 MOB P 01:00 - 07:30 6.50 MOB P 07:30 - 08:30 1.00 MOB P 08:30 - 09:30 1.00 MOB P 09:30 - 10:00 0.50 MOB P 10:00 - 12:00 2.00 MOB P 12:00 - 18:00 6.00 MOB P 18:00 - 00:00 6.00 MOB P 4/7/2009 00:00 - 01:00 1.00 MOB P 01:00 - 02:00 1.00 MOB P 02:00 - 03:00 1.00 MOB P 03:00 - 06:00 3.00 RIGU P 06:00 - 08:00 2.001 WHSUR P 08:00 - 09:30 I 1.501 WHSUR I P 09:30 - 12:00 ~ 2.50 ~ WHSUR ~ P 12:00 - 13:30 I 1.501 WHSUR I P -Move off well, move down Pad. -Remove Cellar doors, Heaters, Mouse hole, & BOP Stack. -Install rear Boosters. PRE Change out: -Plug end on rear Booster steering control power supply. -Repair front Booster Main control panel power supply plug. PRE Continue to: -Repair front Booster Main control panel power supply plug. PRE Mobilize: Depart END-4 Pad @ 01:00 hrs onto ice road. -Move to DS # 4-40. Move down Ice road to Ice road turn off. PRE Wait on Endicott security. PRE Move from Ice road turn off to Endicott "Y". PRE Wait on BP security. PRE Move from "Y" to DS- 17. PRE Move from DS- 17 to DS- 4 PRE Remove front & rear Boosters. -PU BOP Stack & install in Cellar. Install Cellar heaters. -Install HCR Choke. Position conveyor # 2. -Work on Cellar. Too wide for Rig base. -Add 3" X 12" and fill with gravel. PRE Prepare Cellar. -Shim up and add gravel. PRE Lay Rig mats. Remove Star Wars. -Attach Cellar doors. PRE Spot & shim Rig over well. -Pressure on well T/ I / O = 0/0/0 PRE Rig up: -Skid Rig floor. Berm & spot Rockwasher -Hook up service lines to rig floor (Air, water, steam, etc.) -Hook up choke line & mud manifold. -Ri acce ted at 06:00 hrs DECOMP -Install secondary valve in IA. -Mobilize and RU DSM lubricator. Test same to 500 six 5 min on chart. -Pull BPV. RD DSM lubricator. SIMOPS: Hard line crew RU hard line, choke manifold and tiger tank. DECOMP -RU lines to tree and IA and hook up to hard line. -Check hard line w/ air. Steam same and test w/ water to 3500 psi. Good test. -Calibrate and test gas alarms. DECOMP Displace freeze protect out to tiger tank: -Pump 40 bbls seawater down IA, taking returns out tubing to tiger tank. 4 BPM C~ 580 psi. -Swap lines in tree. Pump 100 bbls seawater down tubing, taking returns out IA to tiger tank. 6 BPM C~2 930 psi. -Allow diesel migration f/ 30 min. Pump another 50 bbls seawater down tubing, taking returns out IA to tiger tank. DECOMP -Observe well still unbalanced. Printed: 4/20/2009 12:12:19 PM • BP EXPLORATION Operations Summary Report Legal Well Name: 04-40 Common Well Name: 04-40 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date I From - To Hours Task Code NPT - - 4/7/2009 12:00 - 13:30 1.50 WHSUR P 13:30 - 15:00 1.501 WHSUR P 15:00 - 17:00 I 2.001 WHSUR I P 17:00 - 22:00 I 5.00 22:00 - 23:00 I 1.00 23:00 - 00:00 I 1.00 Start: 4/5/2009 Rig Release: 4/16/2009 Rig Number: Page 2 of 12 Spud Date: 11 /23/1991 End: Phase Description of Operations DECOMP -Circulate well w/ 50 bbls seawater taking returns to rockwasher. Observe well static. DECOMP -FMC Rep. install ISA BPV. -Test BPV f/ below to 1000 psi x 10 min on chart. -Vac out tree. DECOMP -ND tree and adapter flange. -Remove tree and adapter flange f/ cellar. -FMC Rep. terminate control lines. -Install blanking plug in tubing hanger and check XO. Barriers in place: 1) IBP C~ 8432' ; 2) BPV in tubing hanger. P DECOMP -NU 11" x 13-5/8" adapter and 36" spacer spool. -NU BOP stack and choke line. -Install riser and flow line. P P 4/8/2009 100:00 - 06:30 I 6.501 BOPSUR P 13-5/8" 5M BOP stack configuration: - Annular preventer - 3-1/2" x 6" VBR (top rams) - Blind Rams - Mud cross - 2-7/8" x 5" VBR (bottom rams) DECOMP -Install 4" testjt. -RU testing equipment. -Fill stack and choke manifold. -MU floor valves. DECOMP I Testing BOP and related equipment per BP / AOGCC procedures and regulations: Test annular preventer w/ 4" test jt. to 250 psi low - 3500 psi high x 5min each on chart. Test witnessed by WSL, Tourpusher and AOGCC Rep (Bob Noble). DECOMP Test BOP and related equipment per BP / AOGCC procedures and regulations. Test components to 250 psi low - 3500 psi high x 5 min each on chart. Test top rams and bottom rams w/ 4" and 4-1/2" test jts. Test witnessed by WSL, Tourpusher and AOGCC Rep (Bob Noble). Tests failed (2): -Choke manifold valve #6 failed. Regrease and test again. Test OK. -Kill line leaked on graylock connection. C/O gasket and test again. Test OK. 06:30 - 07:00 I 0.501 BOPSUFi P 07:00 - 09:00 I 2.001 WHSUR I P -Perform accumulator test: 1. System pressure: 3000 psi. 2. Pressure after close: 1700 psi 3. 200 psi attained Cam? 31 sec. 4. Full pressure attained C 2 min 38 sec. 5. Nitrogen: 4 bottles x 2225 psi avg. DECOMP Pull FMC blankin plu -RD test equip. -Blow down choke and kill lines DECOMP PJSM -Install "Dutch System" lubricator extension -RU DSM lubricator Printed: 4/20/2009 12:12:19 PM • BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: 04-40 Common W ell Name: 04-40 Spud Date: 11/23/1991 Event Nam e: WORKO VER Start : 4/5/2009 End: Contractor Name: DOYON DRILLI NG INC . Rig Release: 4/16/2009 Rig Name: DOYON 14 Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations 4/8/2009 07:00 - 09:00 2.00 WHSUR P DECOMP -Test to 500 psi -Pull ISA BPV -RD DSM lubricator and Dutch System lubricator extension. 09:00 - 10:00 1.00 PULL P DECOMP Mobilize tubing handling equip. -RU tubing equip. 10:00 - 11:00 1.00 PULL P DECOMP PU 1 jt 4" DP, L.H. Acme XO -Screw into hanger (hard to start) -Pull test on hanger w/ 50k -threads pulled out -LD XO 11:00 - 11:30 0.50 PULL P DECOMP PJSM on change of scope -PU Baker S ear to catch 4 1/2" 12.6# tubin 11:30 - 12:00 0.50 PULL P DECOMP Pull hanger free -Pull tubing free w/ 165k -Pull hanger to rig floor w/ 145k 12:00 - 12:30 0.50 PULL P DECOMP Release spear -LD spear and DP -Change elevators to 4 1/2" -RU control line spool 12:30 - 14:00 1.50 PULL P DECOMP MU XO and circulatin head in r~ -Begin pumping with 6 bpm 110 psi w/ no returns < -Observe 100 psi pressure increase w/ 56 bbls away ~ -Continue um in total 260 bbls away w/ no returns observed -Shut down to wait on more fluid -Discuss w/ workover engineer 14:00 - 15:00 1.00 PULL P DECOMP PJSM on LD tubing -ACT Manager Lowell Crane Requested meeting w/ rig crew to discuss Endicott wells -Take on seawater into pits 15:00 - 18:00 3.00 PULL P DECOMP LD 50 jts 4 1/2' 12.6# 13Cr FOX tubing -Fillip hole w/ seawater at 60 bbls/hr -LD AVA SSSV and pups -Recover dual control lines and 55 SS bands. 18:00 - 18:30 0.50 PULL P DECOMP RD control line spooling unit. 18:30 - 00:00 5.50 PULL P DECOMP Cont. LD 4-1/2" 12.6# 13Cr FOX tubing and completion equipment: -LD total 190 jts + 8 GLM assys. -Last jt (where 'et cut was made) came com lete included in. total 190 jts LD). Partial cut in 't: +/- 75% around the 't. -Filling hole w/ seawater at 60 bbls/hr. 4/9/2009 00:00 - 00:30 0.50 PULL P DECOMP -LD last jt with partial cut. -Below last jt came following tail pipe assy: 4-1/2" pup jt + jt w/ 4" PBR seal 3-1/2" XO 3-1/2" jt 3-1/2" u 4-1/2" u t~ ~ ~ ~ p p x + p p + - ' ~-5 assy. Junk catcher and IBP inside this assy Qunk catcher ~ tiS t _ stickin out of 4-1/2" pu 't . Remove junk catcher. -LD tail pipe assy w/ IBP inside. -Cont. filling hole w/ seawater at 60 bbls/hr. 00:30 - 02:00 1.50 PULL P DECOMP -RD tubing handling equipment. -Clean tubing handling equipment. Clean and clear rig floor. -Copt filling hole w/ seawater at 60 bbls/hr. 02:00 - 02:30 0.50 CLEAN P DECOMP Mobilize tools for cleanout BHA to rig floor. 02:30 - 03:00 0.50 WHSUR P DECOMP Install wear bushing. Printed: 4/20/2009 12:12:19 PM BP EXPLORATION Page 4 of 12 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 04-40 ell Name: 04-40 e: WORKOVER Name: DOYON DRILLIN DOYON 14 From - To Hours Task INC. Code NPT Spud Date: 11/23/1991 Start: 4/5/2009 End: Rig Release: 4/16/2009 Rig Number: Phase I, Description of Operations 4/9/2009 03:00 - 03:30 0.50 CLEAN P DECOMP -PU 1 jt 4" DP. -MU cleanout BHA on bottom of 4" DP jt: 6-3/4" bit + 7-5/8" casing scraper + bit sub + 4-3/4" Bumper Sub + Pump Out Sub + XO. -Cont filling hole w/ seawater at 60 bbls/hr. 03:30 - 11:00 7.50 CLEAN P DECOMP RIH w/ cleanout BHA on 4" DP 1x1 f/ i e shed to 8441'. Ta to of SB-3A acker C~3 8441'. -Fill hole w/ seawater at 60 bbls/hr. -PUW 175k /SOW 148k. -Scrape int. 8360'-8270' several times when RIH. 11:00 - 12:00 1.00 CLEAN P DECOMP Clean rig floor. 12:00 - 12:30 0.50 CLEAN P DECOMP -Inspect and service top drive, blocks and drawworks. -Blow down choke and manifold bleeder. 12:30 - 15:00 2.50 CLEAN P DECOMP POOH w/ cleanout BHA f/ 8441' to BHA. -Cont. filling hole w/ seawater C~ 60 bbls/hr. 15:00 - 15:30 0.50 CLEAN P DECOMP -LD 6-3/4" bit, 7-5/8" casing scraper, bit sub, bumper sub and pump out sub. -Mobilize tools off rig floor. 15:30 - 16:00 0.50 DHB P DECOMP Mobilize 7-5/8" RBP to rig floor and MU same. 16:00 - 20:00 4.00 DHB P DECOMP -RIH w/ 7-5/8" RBP on 4" DP to 8356'. Check parameters: PUW 175k /SOW 148k. -Set RBP per HES Rep. Verify. set. Top of RBP F.N C«3 8348'. 20:00 - 21:00 I 1.001 DHB I P 21:00 - 21:30 0.50 DHB P 21:30 - 22:00 0.50 DHB P 22:00 - 22:30 0.50 DHB P 22:30 - 00:00 1.50 DHB P 4/10/2009 ~ 00:00 - 01:30 ~ 1.50 DHB ~ P 01:30 - 03:30 2.00 EVAL P 03:30 - 08:30 5.00 EVAL P -LD 1 jt 4" DP. -Fill hole w/ seawater C~3 60 bbls/hr while RIH. DECOMP -RU to pump w/ cement line. Pump down tubing and fil'ole until returns observed C~ 60 bbls pumped away. -Cont circulating w/ seawater S/S to clear air out of wellbore prior to test RBP and casing. 10 BPM ~ 1890 psi. DECOMP -Test 7-5/8" casing and RBP to 3500 psi x 30 min on chart. -RD testing equipment and cement line. Blow down kill line. DECOMP POOH w/ RBP running tool f/ 8316' to 7694'. DECOMP Service drawworks, top drive and blocks. DECOMP Cont. POOH w/ RBP running tool f/ 7694' to 3801'. -Hole taking proper fill. DECOMP Cont. POOH w/ RBP running tool f/ 3801' to surface. LD RBP running tool. -Hole taking proper till. DECOMP -Mobilize next RBP to rig floor. -RU Schlumberger a-line equipment and USIT tool. DECOMP -RIH w/ USIT tool on a-line to 4000'. Pull up and verify tool -Take USIT log f/ 3750' to surface -USIT shows top cement at 3370'. 08:30 - 10:30 I 2.001 DHB I P 10:30 - 11:00 I 0.501 DHB I P 11:00 - 12:00 I 1.001 DHB I P -RD SWS -Clear floor DECOMP PU 7 5/8" RBP on 4" DP -RIH to 3220' DECOMP Screw in T.D. -Obtain Parameters -PUW 95k -SOW 95K -Set RBP per HES Req. at 3274' (Top) - 3278' (C.O.E. DECOMP RU test equip. Printed: 4/20/2009 12:12:19 PM • BP EXPLORATION Operations Summary Report Page 5 of 12 Legal Well Name: 04-40 Common Well Name: 04-40 Spud Date: 11/23/1991 Event Name: WORKOVER Start: 4/5/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/16/2009 Rig Name: DOYON 14 Rig Number: Date From - To ', Hours. Task .Code NPT ' Phase Description of Operations 4/10/2009 11:00 - 12:00 1.00 DHB P DECOMP -Test RBP to 3500 psi f/ 10 min on chart -Bleed off, RD test equip. 12:00 - 13:30 1.50 CLEAN P CLEAN PJSM -Displace well w/ 300 bbls 9.8 ppg brine -8 bpm, 360 psi -SIM OPS -Mobilize river sand to rig floor 13:30 - 15:00 1.50 CLEAN P CLEAN PJSM -Dump 1400# of 20 / 40 river sand down DP -Pump 1/2 DP volume at 1.5 bpm 15:00 - 16:00 1.00 CLEAN P CLEAN PJSM -Cut & slip 59.5' of drilling line 16:00 - 17:00 1.00 DHB P DECOMP RIH and tag top of sand at 3220' -POH w/ RBP running tool. LD same 17:00 - 17:30 0.50 FISH P DECOMP MU BHA w/ 5-1/2" Multistrin cutter and pump out sub. 17:30 - 20:00 2.50 FISH P DECOMP RIH w/ Multistring cutter on 4" DP to 3137'. -MU TD. Check parameters: PUW 95k /SOW 92k. 20:00 - 00:00 4.00 FISH N SFAL DECOMP -Handle on suction valve in tiger tank broke. Called Well Support and requested to change valve. Well Support personnel evaluated the valve and decided to swap tiger tank. Waited until Well support brought new tiger tank and made change. -Retest hard line to tiger tank (since disconnected it to allow swapping tanks): check line w/ air. 4/11/2009 00:00 - 01:00 1.00 FISH N SFAL DECOMP 01:00 - 02:00 1.00 FISH P DECOMP 02:00 - 04:00 2.00 FISH P DECOMP 04:00 - 06:00 2.00 FISH P DECOMP 06:00 - 07:30 1.50 FISH P DECOMP Cont. testing hard line: steam hard line and test w/ brine to 3500 psi. Test good. -Blow down hard line. -RIH and locate collars w/ cutter C~3 3164' and 3206'. -PU and position cutter C~ 3187'. -Cut 7-5/8" casing ~ 3187': 60 RPM Cad 1k torque. Staged pump 84 gpm psi to 220 gpm C~ 730 psi while cutting. Pressure drop to 270 psi after cutting through. Observe pressure in OA increase f/ 0 psi to 120 psi after cutting through Also observe fluid coming out of conductor into cellar. -Close annular preventer and establish circulation out 7-5/8" x 10-3/4" annulus. Stage pumps to 168 gpm ~ 310 psi with returns out 7-5/8" x 10-3/4" annulus to tiger tank. Observe also fluid coming out of conductor into cellar. Displace arctic pac out of 7-5/8" x 10-3/4" annulus: (annular preventer closed) -Little Red pump 100 bbls 120 F diesel down drill pipe taking returns out 7-5/8" x 10-3/4" annulus to tiger tank. 1.75 BPM C«3 750 psi. Fluid coming out of conductor into cellar also. -Displace diesel out of drill pipe w/ 35 bbls Safe Surf O pill. 215 gpm CiZ 310 psi. Allow diesel to soak in 7-5/8" x 10-3/4" annulus. Finish displacing arctic pac and cleaning 7-5/8" x 10-3/4" annulus: -Pump 35 bbls hi-vis sweep followed by 130 bbls 9.8 ppg brine down drill pipe, taking returns out 7-5/8" x 10-3/4" annulus to tiger tank. -Shut down pumps and allow diesel in 7-5/8" x 10-3/4" annulus Printed: 4/20/2009 12:12:19 PM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: 04-40 Common Well Name: 04-40 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date II From - To 'Hours Task Code NPT 4/11/2009 06:00 - 07:30 1.501 FISH P 07:30 - 09:00 1.50 FISH P 09:00 - 09:30 0.50 FISH P 09:30 - 10:00 0.50 WHSUR P 10:00 - 11:00 1.00 FISH P Spud Date: 11/23/1991 Start: 4/5/2009 End: Rig Release: 4/16/2009 Rig Number: Phase Description of Operations DECOMP to migrate x 30 min. -Finish pumping w/ 120 bbls 9.8 ppg brine down drill pipe, taking returns out 7-5/8" x 10-3//4" annulus to tiger tank. -300 gpm C~ 230 psi - 640 psi DECOMP POOH w/ casin cutter. DECOMP LD casing cutter BHA. DECOMP Pull wear bushing. DECOMP -Mobilize spear dressed to enl,~age on 7-5/8" 29.7# casing to rig floor. MU assy to 1 jt 4" DP. -RIH and en a e 7-5/8" casin PU 75k to ensure spear -BOLDS. Pull casing and hanger to surface. Hanger pulled free w/ 145k PUW 132k after hanger free (blocks weight 50k). 11:00 - 12:00 1.00 FISH P DECOMP Circulate surface to surface. 360 gpm @ 120 psi. -RU to LD 7-5/8" casing. 12:00 - 12:30 0.50 FISH P DECOMP -Disengage spear. -Break out XOs. LD spear assy. and 4" DP jt. 12:30 - 13:00 0.50 FISH P DECOMP Inspect and service top drive, blocks and drawworks. 13:00 - 17:00 4.00 FISH P DECOMP Pull and LD 7-5/8" 29.7# L-80 BTC casin f/cut @ 3187'. -LD total 74 jts + 20.56' cutoff jt. -Recover also 25 centralizers and 23 stop rings. 17:00 - 17:30 0.50 FISH P DECOMP RD casing tongs and clear rig floor. 17:30 - 18:00 0.50 WHSUR P DECOMP Install long wear bushing. 18:00 - 20:30 2.50 CLEAN P DECOMP -Mobilize BHA tools to rig floor. -MU casin dressoff BHA w/ 9-5/8" x 7-5/8" Dressoff shoe + 9-5/8" washpipe extension + 8-1/4" x 6-3/4" Top dressing mill (inside extension) + 10-3/4" casing scraper + bumper sub + jars + 6 jts 4-3/4" DCs. 20:30 - 22:00 1.50 CLEAN P DECOMP RIH w/ casing dressoff BHA f/ 233' to 3170'. -Circulate BU @ 1650'. -Obtain parameters: PUW 100k /SOW 100k / ROTW 100k. 1 k torque C~ 60 RPM. 22:00 - 22:30 0.50 CLEAN P DECOMP -Run down and tag casing stump C~3.318T. Swallow 6' of 22:30 - 23:30 I 1.001 CLEAN I P 23:30 - 00:00 0.50 CLEAN P 4/12/2009 00:00 - 00:30 0.50 CLEAN P 00:30 - 01:30 1.00 CLEAN P 01:30 - 02:30 1.00 CLEAN P 02:30 - 03:00 0.50 WHSUR P 03:00 - 04:00 1.00 CLEAN P 04:00 - 05:30 I 1.501 CASE I P casin stum in shoe and wash i e extension. Ta to of stump w/ top dressing mill. Dress top of stump (mill 0.5'). -Rotate over stump with shoe and washpipe extension 3x. Work over again without rotation. PU 3'. DECOMP Pump 35 bbls hi-vis sweep and circulate S/S. 9 BPM ~ 770 psi. -Rack back 1 stand 4" DP. Blow down top drive. DECOMP POOH w/ casing dressoff BHA f/ 3170' to 2500'. DECOMP Lubricate rig. Inspect top drive. DECOMP Cont. POOH w/ casing dressoff BHA f/ 2500' to 233' (BHA). DECOMP -Rack back 4-3/4" DCs. -LD rest of casing dressoff BHA. DECOMP Pull wear bushing. DECOMP Clear rig floor of BHA tools. -Clean rig floor DECOMP PJSM -Mobilize elevators, casing pup jts, centralizers, casing patch assy. and cement head to rig floor. -RU to run 7-5/8" casing: C/O elevators, install casing tongs an torque urn egwpment. Printed: 4/20/2009 12:12:19 PM BP EXPLORATION Page 7 of 12 Operations Summary Report Legal Well Name: 04-40 Common Well Name: 04-40 Spud Date: 11/23/1991 Event Name: WORKOVER Start: 4/5/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/16/2009 Rig Name: DOYON 14 Rig Number: Date ~ From - To ,Hours Task Code NPT Phase Description of Operations 4/12/2009 105:30 - 13:00 7.50 CASE P DECOMP 7# - II in using torque turn equip -Bowen casing patch -Baker ECP -HES ES cementer -Torque turn TCII connections to 10,100 ft-Ibs. -Bakerlok all connections below ES cementer. -Ran 77 jts 7 5/8" casing to 3180' -Install 1 centralizer (floating) perjt on jts 1-76. -Obtain parameters - PUW 134k -SOW 137k (blocks weight 50k). 13:00 - 13:30 0.50 CASE P DECOMP PU space out pups (2) -MU XO's to T.D. -Screw in T.D. 13:30 - 14:00 0.50 CASE P DECOMP Break circ. w/ 2 bpm -Wash & rotate down. Observe pressure increase when engaging 7 5/8" cut at 3187' -Stop pumps -Swallow 3' to 3190' shoe depth -Set down on stub w/ 25k -Pull up 250k 14:00 - 14:30 0.50 CASE P DECOMP Pressure test to 1000 psi f/ 10 min. on chart - OK -Pressure to 1600 to open and inflate ECP -Observe 250 psi drop -Continue pressure up to 2000 psi -Hold f/ 10 min on chart - OK -Bleed pressure -Pressure up and open ES cementer w/ 3300 si 14:30 - 15:30 1.00 CASE P DECOMP Break circulation w/ 8 bpm, 120 psi -circ. until 80 de ree brine achieved 15:30 - 16:00 0.50 CASE P DECOMP top pumps -Change to long bales -Install XO pup -RU HES cement head and lines 16:00 - 16:30 0.50 CASE P DECOMP Break circ. w/ 8 bpm, 120 psi -PJSM w/ Schlumberger, Halliburton, Truck drivers 16:30 - 17:30 1.00 CASE P DECOMP Give to Schlumberger: -Pump 5 bbls water C~? 1.5 BPM. -Test lines to 4500 psi. -Pump 150 bbls 15.8 class G cement w/ Gasblok. Yield: 1.17ft3/sk -Drop closing plug and kick same w/ 2 bbls cement + 5 bbls water. 17:30 - 18:00 0.50 CASE P DECOMP Switch to rig pumps to displace cement w/ 9.8 ppg brine: -Max rate 8 BPM. Reduced to 6 BPM w/ 960 stks pumped away. Slowed to 3.5 BPM C~ 1070 stks pumped away. -Caught cement w/ 500 stks pumped away. -Close annular preventer and allow to s ueeze throu h leak in 10-3/4" casing w/ 1100 stks pumped awav. -Observe returns of cement to cellar C~? 1117 stks pumped away. -Slowed rate to 3 BPM C~ 100 stks before bumping plug. -Bump plug w/ 1365 stks pumped awav. -Bleed off pressure and check floats. OK. -24 bbls cement returns to surface (cellar). Printed: 4/20/2009 12:12:19 PM • BP EXPLORATION Operations Summary Report Legal Well Name: 04-40 Common Well Name: 04-40 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date. From - To 'Hours ' Task Code N'PT 4/12/2009 17:30 - 18:00 0.501 CASE I P 18:00 - 19:00 I 1.001 CASE I P 19:00 - 20:30 I 1.501 BOPSUR P 20:30 - 22:00 ~ 1.50 ~ WHSUR ~ P 22:00 - 00:00 I 2.001 WHSUR I P 4/13/2009 100:00 - 01:30 I 1.501 WHSUR I P 01:30 - 03:00 1.50 BOPSU P 03:00 - 03:30 0.50 BOPSU P 03:30 - 07:30 4.00 BOPSU P Start: 4/5/2009 Rig Release: 4/16/2009 Rig Number: Page 8 of 12 Spud Date: 11/23/1991 End: .Phase Description of Operations DECOMP -Keep 100k over PUW while cementing and displacing. -CIP ~ 18:00 hrs DECOMP -RD cement head. -Vac casing. -Flush stack. Work and flush bag. -Blow down kill, choke and fill up lines. DECOMP -ND flow line and fill up lines. -Lower riser. Disconnect choke line. -Break at tubing spool and lift stack to set casing on emergency slips and cut casing. DECOMP -Set emergenc slips on bowl. -Slack casing and hang in emergency slips w/ 235k (100k over PUW) DECOMP -Cut casing. LD cut jt (26.84'). -Dressoff stub. Install 7-5/8" packoff. -Set BOP stack. DECOMP -Install clamp assy. between tubing and casing spools. RILDS on 7-5/8" packoff. -Test packoff to 3800 psi x 30 min per FMC Rep. DECOMP -Cont. NU BOP. -NU choke line -Install flow line. DECOMP RU to test BOP DECOMP TesYBOP and related_ecLUipment oer BP / AOGCC procedures and regulations. Test components to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test annular preventer to 250 psi low - 3500 psi high x 5 min each on chart w/ 4" test jt. Test upper & lower rams w/ 4" & 4 1/2" test jts. Test witnessed by WSL and Tourpusher. John Crisp, AOGCC Rep, waived witness of test. -Perform accumulator test: 1. System pressure: 3000 psi. 2. Pressure after close: 1700 psi 3. 200 psi attained @ 33 sec. 4. Full pressure attained C~ 2 min 35 sec. 5. Nitrogen: 4 bottles x 2200 psi avg. 07:30 - 08:00 0.50 BOPSUF~ P 08:00 - 09:00 1.00 WHSUR P -Tested 29 components 1.13-5/8" annular. 2. 3-1/2" x 6" VBR (upper rams). 3. Blind rams 4. 2-7/8" x 5" VBR (lower rams). 5. HCR valves (kill and choke) 6. Manual valves on kill line and choke line 7. Choke manifold valves (14) 8. Manual choke and hydraulic choke 9. 4" Inside BOP, 4" FOSV (ball type), Upper and Lower kelly valves (upper and lower top drive IBOP). DECOMP RD test equipment DECOMP Install wear ring -Blow down choke /kill lines -Install bales, elevators Printed: 4/20/2009 12:12:19 PM • BP EXPLORATION Page 9 of 12 Operations Summary Report Legal Well Name: 04-40 Common Well Name: 04-40 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours ' Task Code NPT ___ _ 4/13/2009 09:00 - 10:00 1.00 CLEAN P 10:00 - 11:00 I 1.001 CLEAN I P Spud Date: 11/23/1991 Start: 4/5/2009 End: Rig Release: 4/16/2009 Rig Number: Phase Description of Operations DECOMP Mob BHA tools to rig floor -MU BHA w/ 6-3/4" bit + 4-3/4" boot baskets (2) + bumper sub +jars + pump out sub + 6 jts 4-3/4" Drill Collars. DECOMP RIH on 4" DP 11:00 - 13:00 I 2.00 I CLEAN I P 13:00 - 14:30 I 1.501 CLEAN I P 14:30 - 16:00 I 1.501 CLEAN I P DECOMP Screw in TD. Obtain parameters: -PUW 95k -SOW 95k -ROW 95k -Clean out and tag hard cement at 3060' -Drilling cement and tag ES cementer / plu at 3132' -Drilling ES cmtr /plug -8.5 bpm, 1130 psi - 70 rpm, 1k tq - WOB = 10k DECOMP Wash down and tag sand at 3220' -Dry drill and attempt to break up ES Cementer pieces. Cont. cleaning sand to 3234'. -Pump H.V. sweep around. 336 gpm Q 1150 psi DECOMP -Rack back 1 stand 4" DP. -RU testing equipment. -Test 7-5/8" casing and casing patch to 3500 psi x 30 min on -RD testing equipment 16:00 - 16:30 0.50 CLEAN P DECOMP POOH f/ 3125' to 218' (BHA). 16:30 - 17:30 1.00 CLEAN P DECOMP -Rack 2 stands 4-3/4" DCs. -LD 6-3/4" bit and boot baskets. Clean boot baskets. Recover pieces of ES Cementer and cement. -MU BHA w/ RCJB + 2 boot baskets + 7-5/8" casing scraper + bumper sub +jars + pump out sub + 2 stds. 4-3/4" DCs. 17:30 - 18:30 1.00 CLEAN P DECOMP RIH on 4" DP to 3165'. -MU TD and obtain parameters: PUW 95k /SOW 95k / ROTW 95k. 18:30 - 19:30 1.00 CLEAN P DECOMP -RIH and tag sand @ 3234'. -Dry drill 2' w/ RCJB. Cont. washing sand w/ RCJB to 3252'. -PU off sand. Drop dart and open pump out sub. 19:30 - 20:00 0.50 CLEAN P DECOMP CBU, 8 BPM Q 390 psi. -Blow down top drive. 20:00 - 21:00 1.00 CLEAN P DECOMP POOH f/ 3165' to 227' (BHA). 21:00 - 22:30 1.50 CLEAN P DECOMP -Rack back 2 stands 4-3/4" DCs. -Break out RCJB and boot baskets and clean same. Recover pieces f/ ES Cementer in RCJB and boot baskets. -Check amount and size of pieces recovered in last two trips. before running RBP retrieving tool. -MU RCJB and boot baskets and run on 2 stds 4-3/4" DCs. 22:30 - 23:30 1.00 CLEAN P DECOMP RIH on 4" DP f/ 227' to 3165'. MU top drive. 23:30 - 00:00 0.50 CLEAN P DECOMP -Run down and tag sand C~ 3253'. -Dry drill 2' w/ RCJB. Cont. washing sand w/ RCJB to 3264'. -PU off sand and CBU. 4/14/2009 00:00 - 00:30 0.50 CLEAN P DECOMP Lubricate rig. Inspect top drive. 00:30 - 02:00 1.50 CLEAN P DECOMP POOH to 227 (BHA). 02:00 - 03:00 1.00 CLEAN P DECOMP -Rack back 2 stands 4-3/4" DCs. -Break out RCJB and boot baskets and clean same. Recover a few small pieces from ES cementer in boot basket. -LD tools and clear rig floor. -Mobilize RBP retrieving tool to rig floor and MU same. Printed: 4/20/2009 12:12:19 PM BP EXPLORATION Page 10 of 12 Operations Summary Report Legal Well Name: 04-40 Common Well Name: 04-40 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To !Hours Task Code NPT 4/14/2009 03:00 - 04:30 1.50 CLEAN P 04:30 - 05:00 0.50 CLEAN P Start: 4/5/2009 Rig Release: 4/16/2009 Rig Number: Spud Date: 11 /23/1991 End: 05:00 - 07:00 2.00 CLEAN P 07:00 - 09:30 2.50 CLEAN P 09:30 - 10:30 1.00 DHB P Phase Description of Operations DECOMP RIH w/ RBP retrieving tool. Tag sand ~ 3261'. DECOMP -Pump hi-vis sweep. -Displace well w/ 135 bbls seawater. 8 BPM @ 500 psi -Wash sand w/ retrieving tool to top of RBP C~ 3274' while displacing. -Latch RBP and retrieve per HES Rep. DECOMP POOH w/ RBP. DECOMP RIH w/ RBP retrieving tool to 8264'. DECOMP -MU top drive. -Run down and latch RBP C~? 8348'. Release RBP oer HES Rep. -Well went on vac after releasing RBP. Allow well to stabilize x 10:30 - 12:00 1.50 CLEAN P 12:00 - 12:30 0.50 CLEAN P 12:30 - 16:30 4.00 CLEAN P 16:30 - 17:00 0.50 CLEAN P 17:00 - 17:30 0.50 WHSUR P 17:30 - 19:30 2.00 BUNCO P 19:30 - 00:00 4.50 BUNCO P 4/15/2009 ~ 00:00 - 07:00 ~ 7.00 07:00 - 07:30 I 0.50 30 min. DECOMP POOH w/ RBP & LD 4" DP to 6000'. -Fill hole w/ seawater ~ 40-45 bbls/h r. DECOMP Inspect and service top drive, blocks and drawworks. DECOMP Cont. POOH w/ RBP & LD 4" DP f/ 6000' to surface. -LD RBP and retrievin tool. Mobilize off rig floor. -Fill hole w/ seawater C~3 25-40 bbls/hr DECOMP -RIH 2 stands 4-3/4" DCs and 1 stand 4" DP remaining in derrick. -LD remaining 4" DP and 4-3/4" DCs DECOMP -Pull wear bushing. -LD short bales. -Clear and clean rig floor. RUNCMP RU to run 4-1/2" 13Cr Vam To tubin :install long bales and compensator, install 4-1/2" elevators and slips, RU tubing tongs w/ torque turn equipment. RUNCMP Run 4-1/2" 12.6# 13Cr Vam To tubin and com letion equipment to 2600'. -MU tail pipe: 3-1/2" 9.3# 13Cr Vam Top pup jt. w/ half muleshoe + 4-1/2" Vam Top box x 3-1/2" Vam Top pin 13Cr XO + 2 jts 4-1/2" 12.6# 13Cr Vam Top tubing + X nipple assy w/ RHC-M plug + S-3 Packer assy. -Bakerlok all connections below packer. -Torque turn all connections to 4440 ft-Ibs. -Fill hole w/ seawater @ 15-20 bbls/hr. RUNCMP Cont. running 4-1/2" 12.6# 13Cr Vam Top tubing and completion equipment f/ 2600' to 8411' -Ran total of 193 jts -Torque turn all connections to 4440 ft-Ibs -Fill hole w/ seawater C~ 10 bbls/hr. RUNCMP MU circ. head in jt # 194 -Obtain parameters - PUW 145k -SOW 133k (blocks weight 50k). -Slar•.k nff anti PntPr AB-3A packer w/ 3 1/2' muleshoe _rnntin~~o chrUnff ~n~+ nin_rn nn tnn of n~nLar ~+ Addi' /+nn\ -PU to clear packer (observe 5k overpull) -Break circ. w/ 3 bpm, 110 psi -Enter packer and NO-GO -Observe 80 -90 psi increase w/ 5k set down on NO-GO Printed: 4/20/2009 12:12:19 PM BP EXPLORATION Page 11 of 12 Operations Summary Report Legal Well Name: 04-40 Common Well Name: 04-40 Spud Date: 11/23/1991 Event Name: WORKOVER Start: 4/5/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/16/2009 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 4/15/2009 07:00 - 07:30 0.50 BUNCO P RUNCMP -PU and observe 5k overpull 07:30 - 08:00 0.50 BUNCO P RUNCMP LD jt # 194 -PU tubing hanger -MU XO & head pin in top of hanger -RU to reverse circ. 08:00 - 10:00 2.00 BUNCO P RUNCMP Reverse circulate clean warm seawater w/ 3 bpm 290 psi_ -Add corrosion inhibitor f/ 1320 stks to 2760 stks (Spotting Corr. Inh. between DCK valve and packer). 10:00 - 10:30 0.50 BUNCO RUNCMP RD circ. lines -MU landing jt -Land tubing -RILDS 10:30 - 11:00 0.50 BUNCO P RUNCMP Drop ball & rod -RU circ. head and lines 11:00 - 12:30 1.50 BUNCO P RUNCMP Pressure up tubin to 3500 psi to set acker -Hold for 30 min. Record on chart -Good test 12:30 - 13:00 I 0.501 WHSUR I P 13:00 - 13:30 I 0.501 WHSUR I P 13:30 - 14:00 I 0.50 14:00 - 16:00 I 2.001 BOPSUR P 16:00 - 19:30 3.501 WHSUR P 19:30-21:30 2.001 WHSURP 21:30 - 22:30 I 1.001 WHSUR I P 22:30 - 00:00 1.50 WHSUR P 4/16/2009 00:00 - 02:00 2.00 WHSUR P -RU to pump down IA -Pressure up IA to 3500 psi -Hold for 30 min. Record on chart - 0o test -Bleed tubing and shear DCK valve -circ. down IA through DCK w/ 2 bpm, 500 psi -circ. down tubing through DCK w/ 2 bpm, 500 psi RUNCMP RD test equip. -LD landing jt -FMC install TWC RUNCMP RU test equip -Test TWC from below to 1000 si f/ 10 min on chart -Test from above to 3500 psi on chart. -RD test equip. RUNCMP Clear floor -LD long bales -Install short bales -Blow down choke & kill lines RUNCMP PJSM -ND BOPE -Remove Flowline, riser, choke line, turnbuckles -ND spacer spool, -Stand BOP back on pedastal RUNCMP -Install adapter flange. Test same to 5000 psi x 30 min per FMC Rep. -Install tree. -Fill tree w/diesel. Test to 5000 psi x 5min on chart. RUNCMP -Mobilize DSM lubricator and RU same on tree. _Toct hihricaTnr to 5nn nci v 5min nn chart -RD lubricator and keep same on rig floor to use later to install BPV. RUNCMP -RU Little Red. Test lines to 3500 psi. -Little Red pump 90 bbls diesel down IA, taking returns out tubing, for freeze protecS~ 1.7 BPM ~ 500-700 psi. RUNCMP Jump IA to tubing and allow diesel to u-tube. RUNCMP -RU DSM lubricator. Printed: 4/20/2009 12:12:19 PM ,` BP EXPLORATION Page 12 of 12 Operations Summary Report Legal Well Name: 04-40 Common Well Name: 04-40 Spud Date: 11/23/1991 (Event Name: WORKOVER Start: 4/5/2009 End: Contractor Name: DOYON DRILLING INC. Rig Release: 4/16/2009 Rig Name: DOYON 14 Rig Number: Date 'From - To Hours i Task Code' NPT ' Phase Description of Operations 4/16/2009 00:00 - 02:00 2.00 WHSUR P RUNCMP -Install BPV. -RD lubricator. -Test BPV f/ below to 1000 psi x 10 min on chart w/diesel f/ Little Red. -Suck back lines. RD Little Red. 02:00 - 03:00 1.00 WHSUR P RUNCMP -RD lines. -Remove secondary valve in IA. -Install gauges on tree and blind flange on wing. Secure tree. OA = 0 psi / IA = 0 psi / TBG = 0 psi. Release rig ~ 03:00 4-16-2009 Printed: 4/20/2009 12:12:19 PM 04/14/09 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth _ ~ N0.5188 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite .100 Anchorage, AK 99501 1Nn11 ~..~. u ~7 +... _ n W-18 11968978 RST --( vale 12/22/08 6L 1 GOIOr (;p 1 07-02B AXBD-00013 MCNL - 02/12/09 1 1 K-OSC AWJB-00016 MCNL ~ :l 12/30/08 1 1 F-18A AYLF-00020 CEMENT IMAGE LOG i ~- 03/19/09 1 1 J-09A AP30-00024 STP CROSS FLOW CHECK ~ c ~ ~ '- 03!25/09 1 1 X-05 AYTO-00014 PFCS CALIPER LOG) _ C 04/09/09 1 1 O-04A AYTU-00023 _ LDL & PLUG SET j~5 _ ~ 04/02/09 1 1 04-40 AYTU-00025 USIT ~j- 04/10/09 1 1 06-14B AVYO-00021 SCMT ~- 04/01/09 1 1 Z-O1B AVYO-00025 INJECTION PROFILE -/p ~ 04/11/09 1 1 L3-15 AYTU-00023 _ - ~ _ PRODUCTION PROFILE ~ 04/06/09 1 1 11-30 AXBD-00021 MEM PROD PROFILE j c(, ~ 04/14/09 1 1 3-03/J-33 AZ4D-00013 RST W/INJ PROFILE - j -~ a 04/05/09 1 1 3-17F/K-30 BIJJ-00006 MEM INJECTION PROFILE - /~ J 04/03/09 1 1 3-49A/M-40 AXBD-00019 MEM INJECTION PROFILE: 04/07/09 1 1 V-114A f''~- U ~- AVY500032 INJECTION PROFILE j fhb 04/02/09 1 1 U 1 - " ~ ___ THESE 2 WELLS WERE DELIVERED SEPARETLY TO MEET COMPLIANCE TRANS # 5185 E-36A AYTU-00006 OH MWD/LWD EDIT (IFLEX) j _p'.}- ~-a9 01/14/09 1 1 MPS-43 AXML-00020 OH LDWG EDIT 12/29/08 2 1 PLEASE ACKNOWLEDGE RE CEIPT av clr_rll nln nnln ovruo~u~~~ r,.~~ ..~,.,., .-...,. r.._ _ BP Exploration (Alaska) Inc. _..., °-~'"° ~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ,. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 838 ATTN: Beth Received by: • ,_-~tJ..._.'I • • ~ ~_^~~ (~ f ,~ e~~ ~ L! '~ ^d, t.,-~ ; ~ ~-~ ~~~ ~ SARAH PALIN, GOVERNOR ALA58iA OIL A1sD GrAS 333 W 7th AVENUE, SUITE 100 C01~5IItQA7.`IOAT COMDII5SIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ~ ~~ Anchorage AK 99519-6612 ~~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PLZU 04-40 Sundry Number: 309-092 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the 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 this ~? day of March, 2009 Encl. Q STATE OF ALASKA 3- 19 `~ 1~ /,b ~ ~~ ALA OIL AND GAS CONSERVATION COMM~ION ~3/(~ MAID ~, ~ j~}~j~ ~ 3 APPLICATION FOR SUNDRY APPROVAL /)„~, 20 AAC 25.280 Alaska Oil & Gas Cons. Commission 1. Type f Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensi ~C arage ® 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 191-134 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22224-00-00 - 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 04-40 Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028325 - 60' - 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): 9643' - 9009' , 9558' 8934' 2233' & 8432' None in n h i MD TVD II Str r I r ~11 14 47 S dace 3492' 1 - /4" 4 2' 1' 0 2 90 Int rme is 7- / " 0 0' 84 1' 47 in in r 906' 5-1/2" 8737' -9643' 8199' - 9009' 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 9210' - 9510' 8624' - 8892' a-ii2~~, 12.6# x 3-1/2", s.3# x 2ais~~, s.a# 13Cr80 9392' Packers and SSSV Type: 7-5/8" x 3-1/2" Baker'SB-3A' packer; Packers and SSSV MD (ft): 8425'; 5-1/2" x 2-7/8" Baker'FB-1' packer 9315' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Program ^ Exploratory ®Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 18, 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 Aras Worthington, 564-4102 Printed Name David Reem Title Engineering Team Leader Prepared By NamefNumber Signature Phone 564-5743 Date 3 `~ ~~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ° Conditions of approval: Notify Commission so that a representative may witness `` ~/ ~t~~ ~:. VJFt`l ~co5~- C~d ~ a ^ Plug Integrity ~.@OP Test ^ Mechanical Integrity Test ^ Location Clearance p~©© ~JL~ 3~ i _ b Other:. ~~C7~ QSi i~C~~-~~~5~' ~ a-5~4 pS~ v~~ v~~ v--~.v +r-~ O~.t~~!t~.~ lC~,.°Y ~~~ Subsequent Form Required: t`.(~ 1.{ ~ / A roved B : COMMISSIONER THE OMMISSION Date Form 10-403 ReYsed 06/2006 ` Submit In Duplicate • • by c, 04-40 Expense Rig Workover Scope of Work: Pull 4-%2' completion, cut and pull 7 5/8" casing, run new 7 5/8" casing and cement to surface, run 4-%" 13Cr80 premium thread "stacker-packeP' completion. MASP: 2460 psi Well Type: Producer Estimated Start Date: Production Engineer: Intervention Engineer: March 18, 2009 Bob Chiwis Aras Worthington Pre-Rip Work Repuest: W 1 CMIT to 3500 si. S 2 Dump bail sluggits and set junk catcher on top of IBP set @ 8432' md. Drift for Jet Cutter. E 3 Jet cut the tbg @ 8396' and (reference tbg tally of 12/09/1991) in the middle of the first full ~oint above the roduction acker. F 4 Circulate well with seawater. FP w/diesel throu h the cut. Bleed WHPs to 0 si. W 5 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). Well should be secured with an IBP at this time. V 6 Set a BPV in the tubin han er. O 7 Remove the wellhouse & flow line. Level the ad as needed for the ri . D 8 Line the Cellar around the wellhead with im ermeable, s ra -sealed Herculite. Proaosed Procedure 1. MIRU. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. ND tree. NU BOPE. Pressure test to 3500 psi. 3. Pull and LD 4-'/z" tubing string to the cut. 4. Run 7 5/8" casing scraper and dress off assembly.. Dress off tbg stub. 5. Run USIT log to determine. top of cement in 7 5/8" x 10-3/4" annulus. 6. Set retrievable bridge plug 100' below the top of cement. 7. Cut and pull 7 5/8" casing from above the top of cement. Note: Pipe rams will not be changed to 7- 5/e" as the well has two tested barriers (IBP and RBP) to the reservoir. 8. Run and fully cement new 7-%" casing to surface. 9. ND BOPs and install casing packoffs and slips. Test packoffs to 3500 psi. 10. NU and test BOPs to 3500 psi. 11. Pressure test new casing and drill out shoetrack. 12. Clean out to retrievable bridge plug and retrieve same. 13. Retrieve junk catcher. 14. Run 4-%2" 13Cr-80 stacker packer completion with Baker S-3 packer. Position packer at 8300' MD. 15. Displace the IA to packer fluid and set the packer. 16. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 17. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = MCEV OY 4-1 /16" WELLFtiEAD = FMC GEN N ACTUATOR = OTIS KB. ELEV = 60' BF. ELEV.... KOP = 4500` Max Angle = 33 @6700' Datum MD = 9474' Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID= 9.953" ~ 3492' Minimum ID = 2.25" @ 9379' 2 7/8" OTIS XN NiPPLE 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958"J 8423' IBP (06/16/05) 8432' 3-1/2" TBG, 9.3#, 13CR, .0087 bpf, ID = 2.992" I~ 8696' 5-1/2" TIEBACK SLV, ID = 5.75" ~ 8737' 7-5/8" X 5-1/2" PKR &LNR HGR, ID = 5.875" 8745' 7-5/8" CSG, 29.7#, L-80 BTGM, ID = 6.875" ~~ 9030, 2-7/8" TBG, 6.4#, 13CR-80, .0058 bpf, ID = 2.441" 9391' PERFORATION SUMMARY REF LOG: BRCS ON 12/05/91 ANGLE AT TOP PERF: 25° @ 9210' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 2 9210 - 9220 C 04/10/92 2-1/8" 2 9438 - 9450 C 02/10/95 2-1/8" 4 9458 - 9466 C 06/25/94 2-1/8" 4 9467 - 9477 C 02/22/94 2-1/8" 4 9486 - 9510 S 06/04/93 2-1/8" 4 9486 - 9510 C 06/20/93 2-1/8" 6 9511 - 9529 S 06/04/93 2-1/8" 4 9514 - 9532 S 06/04/93 5-1/2" LNR, 17#, 13CR-80, .0232 bpf, ID = 4.892" ~~ 9643' 04-40 2212' ELM I ~4-1/2" KB PKR TOP (05/08/05), ID = 3.70" 2192' 4-1/2"AVA TRSV SSSV NIP, ID = 3.810" (BEHIND EXT. PATCH 05/08/05) 2244' ELM 2-7/8" OTIS X NIPPLE, ID = 2.31" 2233' SLM 2-7/a" PXX TTP (06/28/05) 2247' ELM EXT PATCH WLEG, ID = 2.41" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3012 3011 2 TE-TM DOME BK 16 05/03/05 2 5121 5086 22 TE-TM DOME BK 16 05/03/05 3 6896 6616 .31 TE-TM SO BK 24 05/03/05 4 7226 6$97 32 TE TM DMY BK 0 12/11/91 5 7590 72T0 31 TE-TM DMY BK 0 12/11/91 6 7918 7491 31 TE-TM DMY BK 0 12/11/91 7 8288 7809 31 TE-TM DMY BK 0 12/11/91 8 8359 7870 31 TE-TM DMY BK 0 12/11/91 8423' 4-1/2" X 3-1/2" XO, ID = 2.99" 8425' 7-5/8" X 3-1/2" BKR SB-3A HYD PERM PKR, ID = 3.00" 8445' S" MILLOUT EXTENSION, ID = 4.50" 8450' S" X 3-1/2" XO, ID = 3.00" PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 10 8595 8669 8075 8139 29 28 TE-TGPDX TE-TGPDX DMY DMY TG RK 0 0 03/20/92 04/09/92 8693' I~ 3-1/2" PKR SWN NIP, ID = 2.810" 8696' I~ 3-1 /2" X 2-7/8" XO, ID = 2.44" 04' - 9222' ~ 2-7/8" BLAST JOINTS, ID = 2.44" 9315' 5-1/2" X 2-7/8" BKR FB-1 PERM PKR, ID = 3.00'° 9317' SEAL BORE EXTENSION, ID = 3.00 9323' 4" MILLOUT EXTENSION, ID = 3.50" 9328' 4" X 2-7/8" XO, ID = 2.44" 9379' 2-7/8" OTIS XN NIP, ID = 2.25" 9391' -12-7/8" BKR SHEAROUT SUB, ID = 2.44" 9392' 2-7/8" WLEG, ID = 2.44" 9390' ELMD TT LOG NOT AVAILABLE PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 12/11/91 N28E ORIGINAL COMPLETION 03/08/08 JIM/PJC PXX PLUG CORRECTION @ 2233' 05/08/05 KDC/TLH GLV C/O (05/03/05) 03/13/08 RC/PJC DRAWING CORRECTIONS 06/06/05 KSB/TLH PKR SET (05/08/05) 06/16/05 RWL/PJC IBP @ 8432' 09/23/05 KSB/TLH PXN TTP SET (06/28/05) 11/23/05 COM/PJC WELLHEAD/TREECORRECTION PRUDHOE BAY UNff WELL: 04-40 PERMff No: 1911340 API No: 50-029-22224-00 SEC 34, T11 N, R15E, 1268' FNL & 306' FEL BP Exploration (Alaska) TREE= MCEVOY 4-1/16" WELLHEAD =FMC GEN N ACTUATOR = OTIS KB. ELEV = 60' BF. ELEV = ? KOP = 4500' Max Angle = 33 @ 6700' Datum MD = 9474' Datum TV D = 8800' SS ~ 04-40 Pro osdl 2200' 4-1/2" X NIPPLE, ~ = 3.813" ±,~; GAS LIFE MANDRELS 7-5/8" CSG, 29.7#, L-80, TGII Cemented to Surface 3000' 110-3/4" CSG, 45.5#, L-80, ID = 9.953" H 3492' Minimum ID = 2.25" @ 9379' 2 7/8" OTIS XN NIPPLE ~ 4-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" ~P (06/16/05) H $432' ~ 3-1/2" TBG, 9.3#, 13CR .0087 bpf, ID = 2.992" ~5-1/2" TIEBACK SLV, ID = 5.75" 7-5/8" X 5-1 /2" PKR &LNR HGR ID = 5.875" 17-5/8" CSG, 29.7#, L-80 BTGM, ~ = 6.875" I 2-7/8" TBG, 6.4#, 13CR-80, .0058 bpf, ID = 2.441" PEF8=0RATION SUMMARY REF LOG: BHCS ON 12/05/91 ANGLE AT TOP PERF: 25° @ 9210' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 2 9210 - 9220 C 04/10/92 2-1/8" 2 9438 -9450 C 02/10/95 2-1/8" 4 9458 - 9466 C 06/25/94 2-1/8" 4 9467 - 9477 C 02/22/94 2-1/8" 4 9486 - 9510 S 06/04/93 2-1/8" 4 9486 - 9510 C 06/20/93 2-1/8" 6 9511 - 9529 S 06/04/93 2-1/8" 4 9514 - 9532 S 06/04/93 5-1/2" LNR, 17#, 13CR-80, .0232 bpf, ID = 4.892" I~ 9&{3' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2851 2850 SOV 2 4525 4500 DMY 3 5252 5200 DMY 4 5949 5800 DMY 5 6413 6200 DMY 6 6877 6600 DMY 7 7346 7000 DMY 8 7811 7400 DMY 1 H4 1/2" X-nipple 3.813" ID I 4 1!2" x 7 5/8" S-3 Packer 4 1/2" X-nipple 3.813" ID 4 1/2" x 7 5/8" Unique Overshot 8423' 4-1/2" X 3-1/2" XO, ID = 2.99" 8425' 7-5/8" X 3-112" BKR SB-3A HYD PERM PKR ID = 3.00" 8445' 5" M~LOUT EXTENSION, ID = 4.50" $450' 5" X 3-1/2" XO, ~ = 3.00" PRODl.1CT10N MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 10 8595 8669 8075 8139 29 28 TE-TGPDX 7ETGPDX DMY DMY TG RK 0 0 03/20/92 04!09/92 $693' I"I3-1/2" PKR SWN NAB, ID = 2.810" 8696' 3-1/2" X 2-7/8" XO, ID = 2.44" 9204' - 9222' H 2-7/8" BLAST JOLNTS, ~ = 2.44" ~ 9315 H 5-1 /2" X 2-7/8" BKR FB-1 PERM PKR, ~ = 3.00" 931T HSEAL BORE EXTENSION, ID = 3.00 9323' 4" M~LOUT EXTENSIGV, ID = 3.50" 9328' a" x 2-7/8" xo, m = 2.44" 9379' 2-7/8" OTIS XN Nf~, ID = 2.25" 9391' H 2-7/8" BKR SHEAROUT SUB, ~ = 2.44" 9392' H 2-7/8" WL~, ID = 2.44" I 9390' ELMD TT LOG NOT AVAILABLE DATE REV BY COMMENTS DATE REV BY COMMENTS 12/11/91 N28E ORIGINAL COMPLETION 03/08/08 JMIPJC PXX PLUG CORRECTION ~ 2233' 05/08/05 KDGTLH GLV GO (05/03/05) 03!13/08 RC/PJC DRAWNG CORRECTIONS 06/06/05 KSB/TLH PKR SET (05/08/05) 06/16/05 RWL/PJC IBP @8432' 09/23/05 KSB/TLH PXN TTP SET (06/28/05) 11/23/05 COMIPJC WELLHEAD/TREECORRECTION PRUDHOE BAY UNfT WELL: 04-40 PERMfT No: 1911340 API No: 50-029-22224-00 SEC 34, T11 N, R15E, 1268' FNL 8~ 306' FEL BP Exploration (Alaska) _ STATE OF ALASKA _ ALA" Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS D D D " 1. Operations Abandon D Repair Well 0 Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 60 KB 8. Property Designation: ADL-028325 11. Present Well Condition Summary: Total Depth measured 9643 true vertical 9008.55 Effective Depth measured 9545 true vertical 8922.67 Casing Conductor Surface Production Liner Length 80 3459 8998 906 Size 20" 91.5# H-40 10-3/4" 45.5# L-80 7-5/8" 29.7# L-80 5-1/2" 17# 13Cr80 Perforation depth: Measured depth: 9210 - 9220 Closed True Vertical depth: 8623.82 - 8632.92 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signatu~~~/ Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development (;'] Stratigraphic C feet feet feet feet MD 34 - 114 33 - 3492 32 - 9030 8737 - 9643 9438 - 9450 Closed 8828.51 - 8839.13 4-1/2" 12.6# I ,L.VL.r "L-U DEC 1 6 2005 Alaska Oil & Gas Cons. Caroml$š' Stimulate D Other D WaiverD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Exploratory Service 191-1340 6. API Number: 50-029-22224-00-00 9. Well Name and Number: 04-40 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Bay Oil Pool Plugs (measured) Junk (measured) 8432 None TVD Burst Collapse 34 - 114 1490 470 33 - 3491.03 5210 2480 32 - 8460.77 6890 4790 8199.25 - 9008.55 7740 6280 9458 - 9466 Closed 8846.21 - 8853.27 9486 - 9510 Closed 8870.89 - 8891.97 9467 - 9477 Closed 8854.15 - 8862.97 13Cr80 30 - 8422 4-1/2" KB Packer 4-1/2" Baker SB-3A HYD PERM PKR 2-7/8" Baker FB-1 PERM PKR 2212 8425 9315 8~Au~)~EC: ~1 1 ¡"Inn;) (:;~" -- '---- Tubing pressure Service WDSPl RBDMS 8Ft DEC 1. ~ Title Data Mgmt Engr Phone 564-4424 Form 10-404 Revised 04/2004 OR\G\\~AL Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure SHUT-IN " . SHUT-IN 15. Well Class after proposed work: Exploratory Development {;'] 16. Well Status after proposed work: Oil {;'] Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Date 12/14/2005 Submit Original Only - - 04-40 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDA TE SUMMARY 7/19/2005 OA Down Squeeze, Pumped 7 bb160/40 Methanol, 10 bbl chemical wash, 250 bbls of fresh water. Had small leak from OA to Katchcan estimated to be about 1/2 to 1 gallon per minute. Had vac truck on standby to suck out cellar. Pumped 2 bbls Neat LiteCRETE cement flollowed by LiteCRETE with celophane flakes. The leak started to get worse. Slugged the cement with LCM but the the leak continued to worsen. Pressure on OA went from 577 to 252 in one minute. Job was aborted. Pumped methanol and imediately had methanol in Katchcan. Had Veco vac truck keep fluid in Katchcan. Leak was about 1/4 gal/ minute, Notified DSO. 7/20/2005 T/I/O=?/20/0, Temp=SI. Monitor WHP's (post down squeeze attempt). (No scaffold on wellhead), lAP increased by 10 psi to 20 psi, OAP decreased to 0 psi from 7-13-05. Water (?) is running out of conductor (approx 1 gal per min.) **NOTE** integral on companion, lA, and OA valves. 7/21/2005 TIO = ?/20/3. Temp = SI. Monitor WHP's (Post downsqueeze attempt). Overnight lAP unchanged, OAP increased from 0 psi to 3 psi. No scaffolding on tree to check TBGP from. Fluid is actively draining from conductor into catch can (about 19pm). 7/22/2005 TIO = ?/19/9. Temp = SI. WHP's, Obtain conductor leak rate (Post Downsqueeze attempt). lAP decreased 1 psi from 20 psi to 19 psi, OAP increased 6 psi from 3 psi to 9 psi (overnight). Fluid leaking from cunductor @ .25 gpm. No scaffolding on tree to monitor TBGP from. 7/23/2005 TIO = ?/16/14. Temp = SI. WHP, Monitor Conductor leak rate. (Post Downsqueeze attempt). lAP decreased 3 psi from 19 psi to 16 psi, OAP increased 5 psi from 9 psi to 14 psi, Conductor leak rate decreased from .25 gpm to .035 gpm (from 1 gallon every 4 mins to 1 gallon every 28 mins). From yesterday. Unable to read TBGP (no tree scaffolding). 7/24/2005 TIO = ?/16/18. Temp = SI. Monitor WHP's (Post Downsqueeze attempt). lAP unchanged, OAP increased 4 psi from 14 psi to 18 psi, conductor leak rate decreased from .035 gpm to 90 dripsper minute. From yesterday. .. 7/25/2005!TIO = ?/16/18. Temp = SI. Monitor WHP's (Post Downsqueeze attempt). lAP & OAP pressures unchanged from yesterday, Conductor leak rate decreased from 90 drops per minute to approx. 70 drops per min. from yesterday. Rigged up 2" trash pump and hoses so Vac truck can be released. < 1 gallon fluid in catch-can @ 09:30. 7/26/2005 TIO = ?/16/18. Temp = SI. Monitor WHP's (Post Downsqueeze attempt). lAP & OAP pressures unchanged from yesterday. Conductor leak rate unchanged @ approx. 70 drops per min. < 3 gallons fluid in catch-can @ 08:00. Re-checked well @ 17:15 with little to no change. 7/27/2005 TIO = ?/16/18. Temp = SI. Monitor WHP's (Post Downsqueeze attempt). lAP & OAP pressures unchanged from yesterday. Conductor leak rate up to ¡approx. 104 drops per min. < 6 gallons fluid in catch-can @ 08:00. 7/28/2005'TIO = ?/16/18. Temp=SI. Monitor WHP's (Post Downsqueeze attempt). lAP & OAP pressures unchanged from yesterday. Conductor leak rate unchanged from yesterday (approx. 100 drops per min) < 10 gallons fluid in catch-can @ ;08:00. 7/29/2005 TIO = ?/16/19. Temp = SI. Monitor WHP's (Post Downsqueeze attempt). Conductor leak unchanged at approx. 75 drops per min. < 9 gallons fluid in catch-can @ 17:30 - e 7/30/2005 TIO = ?/15/18. Temp = SI. Monitor WHP's (Post Downsqueeze attempt). Conductor leak unchanged at 75 drops per minute (2" total fluid in Catch- can). lAP decreased 1 psi, OAP decreased 1 psi, since yesterday. 7/31/2005 TIO = ?/?/? Monitor Whp's (Post downsqueeze attempt). Unable to get near the well due to a 50' wide x 50' wide x 6' deep trench that has been dug around the well and flagged-off with "caution" tape. 8/1/2005 Unable to inspect due to cleanup operations, but catch - can will be emptied by ACSNac truck on location. 8/2/2005 TIO = ?/17/18. Temp = SI. Monitor WHP's (Post Downsqueeze attempt). Cond uctor leak at 108 drops per minute « 15 gal fluid in Catch-can) 8/3/2005 TIO = ?/16/18. Temp = SI. Monitor WHP's (Post Downsqueeze attempt). Measured conductor depth at 2'. Conductor maybe pluged with gravel. Conductor leak at 80 drops per minute « 15 gal fluid in Catch-can). SRT appears to be done excavating contaminated gravel. Excavated >500 cubic yards so far. 8/4/2005 T/I/O = ?/15/19 Temp = SI. Monitor WHP's (post-downsgueeze attempt}. 8/17/2005 T/I/O=?/?/? (Could not access) Conductor pipe is still leaking at approx. 70 drops per min. Containment has approx. 40 gallons of fluid in it. 8/19/2005 T/I/O = ?/?/? Temp = SI. Eval SC Leak (Post Dwnsqz attempt). No access to wellhead due to water, surface casing leak appears to be secured. Vac truck ordered to evacuate cellar area. 9/5/2005 IBP MONTHLY RENTAL FOR 07/17/05 - 10/17/05, MO 2,3 & 4. NOTE IBP SET 06-16-05 9/10/2005 TIO= NA/15/18. SI Eval SC Leak. Small drip coming from SC, clean out gravel from 4" pipe and there is a continues drip coming from the 4" pipe. Can not get leak rate due to high wind blowing the fluid back around the pipe. Small film on top of fresh water, there is 16" of VOID in containment. 9/11/2005 T/I/O=N/A/15/18 Temp=SI Keep monitoring Kan & leak, needs vacced? Small drip still coming from 4" nipple on conductor pipe. There is 4" of gravel and 1" of fluid inside Kan, along with 16" of void. A small sheen on top of rainwater (smells like diesel). 9/12/2005 T/I/O= N/A/15/18. Temp= SI. Keep monitoring Kan and leak. Small leak still coming from 4" bull plug on conductor. Light sheen of oil on top of 1" of :water. There is 16" of void still in the Kan. 2" integrals installed on IA & OA. No scaffolding on tree or W/H. 9/13/2005 T/I/O=n/a/15/18, Temp=SI. Monitor Katch Kan & leak. No scaffold on well head. Small leak comming from 4" bull plug on conductor, 2" of fluid in liner, approx 3" of gravel in liner, 16"+1- of void in liner. 2" integral on IA & OA valves. 9/14/2005 T/I/O=?/15/18. Temp=SI. Monitor. (Daily check-up.) Kan has about 3" of fluids, mostly water. Steady drip from conductor. 9/15/2005 TIO = ?/15/18. Temp = SI. Monitor (kan & leak). WHP's unchanged overnight, 4-1/2" of fluid in katch-kan. 9/17/2005 TIO = ?/15/18. Temp = SI. Monitor (kan & leak). WHPs unchanged overnight, 4-1/2" of liquid in kan. 9/18/2005 T/I/O=?/15/18. Temp=SI. Monitor (Kan & Leak). WHP's unchanged from last entry. 5" of fluid in Kan. Steady drip from conductor outlet. 9/19/2005 T/I/O=?/15/18. Temp=SI. Monitor (Kan & Leak). WHP's unchanged from last entry. 5" of fluid in Kan. (Mostly water) Not dripping from conductor outlet at this time. 9/21/2005 T/I/O=?/15/18. SI. Monitor (Kan & leak). WHPs unchanged in 2 days. -5" water in kan with light sheen. 55 drips per minute of water out of conductor outlet. 9/22/2005T/I/O=?/14/18. SI. Monitor (Kan & leak). lAP decreased 1 psi overnight. e e OAP unchanged. -5" water in Kan with light oil sheen. The slow of drip of water out of the conductor is starting to freeze up. 9/23/2005 T/I/O= Unchanged Temp S/I Keep monitoring Kan & leak, needs vacced ? Approx 3" of water W/light sheen in Kan. About 50 drops per min coming from conductor vent. 9/24/2005 T/I/0=?/14/18. SI. Monitor (Kan & leak). WHPs unchanged from last entry. Approx. 5" of fluid in Kan. Very littlle drip coming out of conducter at this time. 9/25/2005 T/I/O= ?/14/18. Monitor (Kan & leak). WHP's unchanged from last entry. -5" of water in Kan with light oil sheen. Dripping out of conductor outlet at a rate of 36 drips per minute. 9/26/2005 TIO = ?/14/18. SI. Monitor (Kan & leak). Pressures unchanged overnight. 4-1/2" of frozen liquid in kan. Liquid actively dripping from conductor @ 40 drips per minute. 9/27/2005 TIO = ?/14/18. SI. Monitor (Kan & leak). Pressures unchanged overnight. 4-1/2" of frozen liquid in kan with a 13" icicle hanging from the conductor outlet. Liquid dripping from icicle @ 6 drips per minute. 9/28/2005 T/IIO = ?/14/18. Temp = SI. Keep Monitoring Kan & leak, need vacced? 4- 1/2" of frozen liquid in kan. Fluid coming from conductor outlet @ 2 drips per minute. 9/29/2005 T/I/0=?/14/18. SI. Monitor (Kan & leak). 4.5" of frozen liquid in Kan. No drips out of conductor, just ice buildup. 9/30/2005 T/1I0=?/14/18. SI. Monitor (Kan & leak). Unchanged overnight. 4.5" of frozen liquid in Kan. No drips out of conductor, just ice buildup. 10/1/2005 T/I/0=?/14/14. SI. Monitor (Kan & leak). OA pressure decreased 4 psi overnight. OA jewelry inspected for obstruction. Jewelry clear. 4.5" of frozen liquid in Kan. No drips out of conductor, just ice buildup. 10/2/2005 TIO= na/14/18. Monitor (Kan & Leak). Ice plug has built up in 4" pipe off of the Surface Casing on 1 side, the other side has gravel inside of 4" pipe which appears to have a small leak that is showing some residual wetness on the SC. Clean out most of the gravel possible, and no fluid is coming out of pipe. Kan shows no sign of fluid just Ice. 10/3/2005 T/I/O= na/14/18. Monitor (Kan & Leak). Condition is unchanged overnigtlt. !gl4/2005 T/I/O= na/14/18. Monitor (Kan & Leak). Condition is unchanged overnight. 10/5/2005 T/I/0=NA/14/18, Temp=SI. Monitor Katch Kan leak. SC leak appears to be frozen, ice built up in 4" hole on the side of the SC. No sign of fresh fluid in .cellar liner. Aprox 3" of ice in liner. 10/6/2005 T/I/0=NA/14/18, Temp=SI. Monitor cellar liner. SC leak appears to be frozen, ice built up in 4" hole on side of SC. No sign of fresh fluid in cellar liner, aprox 3" of ice/gravel in liner. 10/7/2005 T/I/0=N/A/13/18, Temp=SL Monitor cellar liner. SC leak appears to be frozen, 4" hole in side of SC has ice plug. No change in conditions from 10-6- 05. 10/8/2005 TIO= NA /13/18. Temp = SI. Monitor cellar liner. SC leak appears to be frozen, 4" hole in side of SC has ice plug. No change in conditions from 10-6- 05. 10/9/2005 TIO= NA/13/18. SI Monitor Kan & Leak. No change in conditions. Little amount of snow starting to drift up in Kan. 10/.10/2005 TIO= NA/13/18. SI Monitor Kan & Leak, No change in conditions. 10/18/2005 TI0=NA/13/18. Monitor WHP's & Kan. No fluid, about 1 inch of snow, sand, and gravel in bottom of Kan. OAP increased 2 psi and the lAP remained unchanged in 8 days. 10/25/2005 T/I/0=NA/13/18. Monitor WHP's & Kan. No fluid snow in bottom of Kan. No change in OAP or OAP. 11/2/2005 T/I/O = NA/13/18. Monitor WHP,s & Kan. Snow in Kan, but no fluid. No - e change in OAP & lAP since 10/25/05. 11/6/2005 T/I/O=NA/13/4, Temp=SI. Monitor WHP's & kan. No change in lAP, OAP decreased 14 psi from 18 to 4 psi since 11/02/05. Snow in Kan, but no fluid, ice in 4" hole on SC. **Note** that IA & OA have 2" integrals. 11/14/2005 T/I/O=NA/13/O+. Temp=SI. Monitor WHP's, Kan & Leak. No changes in pressures. No fluid in Kan at this time. 11/21/2005T/1I0= na/11/1. Temp= SI. Keep monitoring Kan & leak, needs vacced? LC 11/14. lAP decreased 2 psi. OAP is reading 1 psi. No fluid in Kan, just ice and snow. There are signs of weeping from the lock down screws at the ten and seven o'clock positions on the wellhead. Also there is a slushy build up under the weep-hole on the SSV. 11/22/2005 TIO = ?/10/1. Temp = SI. Bleed WHP's, clean LDS, monitor leaking. Bled lAP from 10 psi to 0 psi in 3 mins (all gas). Bled OAP from 1 psi to 0 psi in 1 min (1/4 cup of fluid). Cleaned LDS's. TBG hanger LDS's @ 7 o'clock & 11 o'clock are "gummy" w/ residual fluid between LDS & gland nut (not much fluid there). Flow line is blinded. No AIL. FWHPs = ?/O/O. 11/23/2005 T/I/O=?/OIO. Temp=SI. Monitor leaking LDS. No change in pressures at this time. No fluid movement at this time. No changefrom 11/22/05. 11/24/2005 T/I/O = 0/0/0 Attempted to test inner casing hanger. Void would only pressure up to 1000 psi and would bleed down to 0 psi as soon as pumping !stopped. Test failed. Lockdown screws were functioned and retorqued to 500 fUlbs Tubing hanger was tested to 5000 psi. Pressure was 4800 psi at 15 min and 4800 psi at 30 min. Test passed. Lockscrews were functioned and torqued to 500 fUlbs. 11/24/2005 T/I/O=?/4/3. Temp=SI. Monitor Leaking LDS. lAP increased 4 psi, OAP increased 3 psi over night. No change in LDS from 11/23/05. Well house was put back on well, heater on well also. 11/25/2005 T/I/O=?/4/3. Temp=SI. Monitor Leaking LDS. IA & OAP remained unchanged overnight. No new drips detected from LDS. Heater is gone. 11/26/2005 iT/I/O=?/6/4. SI. Monitor leaking LDS. lAP increased 2 psi and OAP increased 2 psi overnigbt No visible drips on LDS. 11/27/2005 T/I/O=?/6/4. SI. Monitor leaking LDS. lAP & OAP unchanged overnight. No visible drips on LDS. 11/28/2005 TI/IO = 0+/0+/0+. SI. Monitor leaking LDS. No visible leaks on LDS. Note: No scaffold or landing to access swab. 11/29/2005 T/I/O=?/6/4. SI. Monitor leaking LDS. lAP & OAP unchanged overnight. No visible drips on LDS. 11/30/2005 TIO= 81/5/3. SI. Monitor Leaking LDS. No visible leaks on LDS, clean out cellar and there is no leaks coming from the 4" ports on the surface casing. 12/1/2005 T/I/O=SI/6/4. Temp=SI. Monitor leaking LDS. Tree wet, but no visible leaks on LOS. 12/2/2005 T/I/O=0/6/4. Temp=SI. WHP's. (Monitor SC leak). Tree is wet but No visable leaks. Flow line removed and Integrel flange installed on IA casing valve. 12/3/2005 T/I/O=SI/5/3. Temp=SI. Monitor SC leak. No visible leaks. 12/4/2005 T/I/O= 0+15/2. Temp= SI. Monitor SC leak. No visible leaks. 2" integrals installed on IA & OA. 12/5/2005 T/I/O=~J/A/5/2, Temp=SI. Monitor SC leak. No well scafold, can not get TBGP. No change in lAP or OAP from 12-3-05. SC is not leaking at this time. 2" integrals on IAlOA. 12/6/2005 TIO= na/3/0. SI. Monitor SC Leak. Over night lAP decreased 2 psi & OAP decreased 2 psi. There is no leaks from the SC or LDS nor the test port caps @ this time. There is still some residual fluid marks around the LDS and Test e e port caps. 12/7/2005 T/I/O=?/5/0+. Temp=SI. Monitor SC Leak. Cellar is full of snow. Flutes are 18" above snow, no sign of leaking. There are still some residual fluid markings around LDS's, but just a tint to the snow, not an active leak. 12/8/2005 T/I/O=??/2/1. Temp=SI. Monitor SC leak. No swab platform, unable to get TP. Cellar is full of snow but flutes are visable. No sign of new leaks. SC leak is not active. 12/10/2005 T/I/O= 1/4/3. Temp= SI. Monitor SC leak (LC 12/08/05). No signs of any leakage from flutes or LDS's. 12/12/2005 TIO = 0+/3/1. Temp = SI. Monitor SC leak (LC 12/10/05). TBGP & lAP decreased 1 psi in two days. OAP unchanged. No indication of any active leaking from conductor flutes, FLUIDS PUMPED BBLS 7 MeOH 10 Chemical Wash 250 Fresh water 2 Cement 269 TOTAL .~~' ~ ,yt/~'" ~ ~ r? '''<\ II /JJ\ ri ß-E" I ' I! I / ,. I, ¡ I, i ) U I) , U ~ /~n~I~¡' I ¡ ¡ I I ¡If l i I i[ j i I ! I I ': ~~:I¡ ) ffi'" i~11 ~;o=-'\¡''';:;-'" :n~ilr ~;7~ iil\ \~ I I :,11 \ i,( ,t,:U i !/' /,1\ 1 / u \ !! I:º '\ \~~~:.; II ¡'\,I;: /þ\\, ,r-;q ,J, ,j d ru!, [1,\ :n,., L" \u ~ /.-1 ~w "~.... ' , l-J \U lINt,' \ \ ) FRANK H. MURKOWSKI, GOVERNOR AlASKA OIL AlWD GAS CONSERVAnONCO~SSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ,ql-- \3Lf Re: Prudhoe Bay 04-40 Sundry Number: 305-181 SCANNEL JUL :2; 0 Z005 Dear Ms. Julian: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petrolèum 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 0 a¡ holiday or weekend. A person may not appeal a Commission decisi, t f Superior Court unless rehearing has been requested. ~ 1/ S'Ín'c I I DATED this/5day of July, 2005 Encl. 04-40 Sundry CMIT information ) ) , 'Subject: 04-40 Sundry CMIT information From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Wed, 13 Jul2005 08:45:38 -0800 To: tomßaunder@admin.state.ak.us CC: "Mielke, Robert L." <robert.mielke@BP.com>, "Julian, Jennifer Y" <JulianJY@BP.com>, "NSU, ADW Well Integrity Engineer" <NSUADWW ellIntegrityEngineer@BP.com> Hi Tom, Thanks for the call on 04-40 this morning. After the CMIT-TxIA failed on OS/25/05, we were able to successfully set an Inflatable bridge plug and get a passing CMIT-TxIA to 3000 psi on 06/25/05. This proves our 7-5/8" production casing has integrity. Let me know if you need any more information, Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer 907 -659-5102 907-659-5100 #1923 pgr 1 of 1 7/13/2005 8:54 AM ~;'~ .,1 ) ) July 12, 2005 RECEIVED JUl 1 2 Z005 Alllk. OU & GiS CQns. Commission Anchorage Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: RE: Sundry Notice for 04-40 OA Downsqueeze BP Exploration Alaska, Inc. proposes to do the following wellwork to obtain a production waiver for well 04-40. Step Type P roced u re 1 0 OA FL depress 2 F OA cement down squeeze 3 F MIT OA after WOC Well 04-40 is a production well which requires a waiver for TxlA communication. In order to waiver the well for production, an OA down squeeze must be performed. T/I/O=2340/2340/300. CMIT TxlA on OS/22/2005 failed with LLR of 3 bpm at 1500 psi pumping drop the tubing. This program is -designed to pump a column of cement from the shoe to approximately 500 feet above the shoe for waiVer compliance. Please contact Jennifer Julian at 564-5663 (H) 274-0929, (Cell) 240-8037 with any questions. Sincerely, C~~I~~ §;,nifer JuliatV Wells Engineer ~ ~o.~~'\~~ c...\-\\\ ~C>..~ c.c."'\It~ ~'(ët^û.' \ ~rr1 '1l1yOS- r ., "L o R \ C;' i-\ .' ~. 1. Type of Request: Q>v.J 7/¥ Çf1j- ~/)-O; j ) STATE OF ALASKA ) RECEIV .~, ALASKA OIL AND GAS CONSERVATION COMMISSION ! I,? APPLICATION FOR SUNDRY APPROVA~L 12 2005 20 AAC 25.280 Alaska Oil & Gas Cons. Commission Anch.orage. Waiver [J StimulateD Time Extension D Re-enter Suspended Well D 5. Permit to Drill Nyplber: 191-1340 v' Abandon 0 Suspend 0 Alter Casing D Repair Well I!] Change Approved Program D Pull Tubing D 2. Operator Name: 3. Address: 7. KB Elevation (ft): Operation Shutdown D D D Perforate D Plug Perforations Perforate New Pool 4. Current Well Class: BP Exploration (Alaska), Inc. Development Œ] Exploratory D P.O. Box 196612 Anchorage, Ak 99519-6612 Stratigraphic D Service D 9. Well Name and Number: 04-40 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 9475 8861.0 Size MD TVD 8. Property Designation: ADL-028325 60.00 KB 11. Presen1 Total Depth MD (ft): 9643 Casing CONDUCTOR SURFACE PRODUCTION LINER PATCH OVER SSVN Perforation Depth MD (ft): 9210 - 9220 9438 9450 9458 9466 9467 9477 9486 9510 Total Depth TVD (ft): 9008.6 Length Other 0 6. API Number 50-029-22224-00-00 v Plugs (md): 8432 - IBP Burst Junk (md): None Collapse top bottom top bottom 80 20" 91.5# H-40 34 114 34.0 114.0 1490 470 3459 10-3/4" 45.5# L-80 33 3492 33.0 3491.0 5210 2480 8998 7-5/8" 29.7# L-80 32 9030 32.0 8460.8 6890 4790 906 5-1/2" 17# 13Cr80 8737 9643 8199.3 9008.6 7740 6280 35 2-7/8" EXT Patch 2212 2247 2211.6 2246.6 Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8624 - 8633.1 4-1/2 " 12.6 # 13Cr80 30 8422 8829 - 8839.1 3-1/2 " 9.2 # 13Cr80 8422 8696 8846 - 8853.3 2-7/8 " 6.4 # 13CR80 8696 9391 8854 - 8863.0 8871 - 8892.0 Packers and SSSV MD (ft): Packers and SSSV Type: 4-1/2" KB Packer 4-1/2" Baker SB-3A HYD PERM PKR 2-7/8" Baker FB-1 PERM PKR 12. Attachments: 13. Well Class after proposed work: Description Summary of Proposal Œ] Detailed Operations Proç¡ram D BOP Sketch D 14. Estimated Date for Commencing Operation: 2212 8425 9315 Exploratory D DevelopmentŒ] 15. Well Status after proposed work: Oil Œ] GasD PluggedD WAG D GINJD Abandoned D July 26,2005 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature Date: Contact c ~~~JC:f\-- G4 i G Title Phone Wells Engineer 564-5663 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Other: Subseq BOP TestD Mechanciallntegrity Test D Location Clearance D Service D WINJD WDSPLD Prepared by DeWayne R. Schnorr 564-5174. Jennifer Julian 7/12/05 Sundry Number: ..305"- /5/ RBDMS 8FL ,!UL 1 9 2005 ~~~~g~~~~ION Date: 1/,('10/ SUBMIT IN DU¡I:~J ~ O R¡ '" r: i ~J A L \¡,,-)~I\I . TREE= ? WELLHEAD = MCEVOY . . . .. ....,.. .. ACTUATOR=~ OTIS , kB:~lE:,r;,; 60' BF. ELEV = KOP = 4S00' Max Angle = 33 @ 6700' .""..".,,,,,.,,,,,,,,,,,,,,,,,,,,....,,,,,,, ...... ....."""..."... Datum MD = 9474' [)aiumTVÕ~"'8800' SS ') 04-40 &' ~ ..11. I \. 110-3/4" CSG, 45.5#, L-80, 10 = 9,953" 1-1 3492' ~ --'= Minimum ID = 2.205" @ 9379' 27/8" OTIS XN NIPPLE - 4-1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, 10 = 3.958" I~ D TOPOF 3-1/2" TBG l-raqJ~ ~l8 -I -1 I ..J 1 ~~ 13-1/2" TBG, 9.3#, 13CR, .0087 bpf, ID = 2.992" 1-1 8696' I TOP OF 5-1/2" LNR 1-1 8737' 1 17-S/8" CSG, 29.7#, L-80, ID = 6.875" 1-1 9030' r----4 - - .... 12-7/8" TBG, 6.4#, 13-CR-80, .00579 bpf, ID = 2.441" 1-1 Z:8: I .1 I I ri I 9391' ÆRFORA TION SUMMA RY REF LOG: BHCS ON 12/05/91 ANGLE AT TOP ÆRF: 24 @ 9210' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-1/8" 2 9210 - 9220 0 04/10/92 2-1/8" 2 9438 - 9450 0 02/10/95 2-1/8" 4 9458 - 9466 0 06/25/94 2-1/8" 4 9467 - 9477 0 02/22/94 2-1/8" 4 9486 - 9510 S 06/04/93 2-1/8" 4 9486 - 9510 0 06/20/93 2-1/8" 6 9511 - 9529 S 06/04/93 2-1/8" 4 9514 - 9532 S 06/04/93 I i 15-112" LNR, 17#, 13-CR-80. ,0232 bpf, ID = 4.892" 1-1 ~ 9643' DATE 12/11/91 02/18/01 11/20/01 05/27/02 05/08/05 06/06/05 REV BY COMMENTS ORIGINAL COM PLETION CJS/tp CORRECTIONS DAC/KAK SAFÐY NOTES JLMlTLH MIN ID CORRECTION KDC/TLH GL V CIO KSB/TLH PKR SET (05/08/0S) DA TE REV BY COMMENTS 06/16105 RWLlPJC IBP @ 8432' 06/2S/0S LJLlPJC ÆRF CORRECTIONS 07/1010S LJUPJC ÆRF CORRECTIONS S VY NOTES: H2S OVER 300 PPM. TTP@ 8693', L.../OUND MUL TIPLETBG HOLES FROM 500 - 1050'. ***CHROM E LNR & TBG*** ST ~1 2 3 4 S 6 7 12212' ELM 1"'4-1/2" KB PKR TOP (OS/08/0S), 10 = 3.70" I 2192' 1- 4-1/2"AVA TRSV SSSV NIP, ID = 3.810" (BEHIND EXT. PATCH OS/08/0S) 12244' ELM 1-12-7/8" OTIS X NIPPLE, 10 = 2.31" 1 12247' ELM I-1EXTPATCHWLEG, 10=2.41" 1 GAS LIFT MANDRELS MD TVD DEV TYÆ VLV LATCH 3012 3011 "y 2 TE- TMPD DOME BK S121 S087 11" 22 TE-TMPD DOME BK 6896 6616 II" 32 TE-TMPD SO BK 7226 6897 iii' 32 TE- TMPD DMY BK 7S90 7209" 31 TE-TMPD DMY BK 7918 7492 r 31 TE-TMPD DMY BK 8288 7809" 31 TE-TMPD DMY BK 8359 7870 II" 31 TE- TMPD DMY BK PORT DA TE 16 OS/03/05 16 OS/03/0S 24 OS/03/05 o o o o o 8422' 1-14-1/2"X 3-1/2" XO 1 8425' 1-17-S/8" X 4-1/2" BKR SB-3A HYD ÆRMANENT PKR 1 8432' 1-iIBP SET 6/16/05 1 8595' l-i PRODUCTION MANDREL 1 8669' I-iPRODUCTION MANDREL 1 8693' 1-13-1/2" PKR SWN NIP, 10 = 2.810" 8696' 1-13-1/2" X 2-7/8" XO 1 9315' 9379' 9391' 9392' 9390' 1-15-1/2" X 2-7/8" BKRFB-1 ÆRMANENTPKR 1-12-7/8" OTIS XN NIP, ID = 2,20S"1 1-12-7/8" BKR SOLID NOSE SHEA ROUT SUB 1-12-7/8" TBG TAIL 1 1-1 ELMO TT LOG NOT A V AILABLE 1 PRUDHOE BA Y UNIT WELL: "04-40 ÆRMIT No: "1911340 API No: Jl"500292222400 SEC 34, T11N, R15E. 2459.74 FEL 103.74 FNL BP Exploration (Alaska) 04-40 (PTD # 1911340) Classified as Problem Well ) ) Su:bject: 04-40 (PTD #1911340) Classified as Problem Well Frøm: "Anders, Joe L" <anders22@BP.com> Date: Man, 09 May 2005 12:08:28 -0800 . Tq: "Harris, Marvin L (CONOCO)" <hamnl@BP~com>,:"GPB, FS2DS Ops Lead" <GPBFS2DSOpsLead@BP.com>, "Ros·sberg, R Steven" <RossbeRS@BP.com>,:"NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>,. "GPB,.Wells Opt Erig" <qPBW ellsOpt~ng@B;P . com>, "AOGCC Ji¡p ~egg (E;-1,11aiO"<jim ~regg@1adp1in~~ta~e.a]{.us>, . . "A.OOCCWinton Aubert (E-mail)..<winton_aubert@admin.state.ak.us> ; ~'NSU, ADW WL & " " C<>.mpletion Supervisor" <NSUADWWL&Cø11ipletionSupervisor@BP.com>,· "GPB,. Ops Mgr" <GP~OpsMgr($BP . com>, "GPB,FS2/COTU·~éa· Mgr",. <GPBFS2TL@BP.com~·":, . , CC: "NSU, ADWW ell. Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com>,. "Reeves, DonaldF" '<ReevesDf@BP ~com>, "" " All, Well 04-40 (PTD #1911340) has sustained casing pressure on the IA and is classified a Problem well. The well has known tubing leaks between 520'-1050'. The TTP was pulled to prepare for running an extended patch. TIO's on 05/08/05 were 2330/2330/500. The plan forward for this well is as follows: Obj: Restore tubing integrity with Long Patch 1. FB: CMIT to 3000 psi - PASSED 2. SL: Pull TTP, 0&0, c/o GLV - DONE 3. EL: Set lower packer - DONE 4. SL: Run L TTP, CMIT TxlA to 3000 psi, pull L TTP. 5. CT: Run extended patch 6. DHD: TIFL post patch Attached is a wellbore schematic. Please call if you have any questions. «04-40.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom SCANNED JUL 0 r't 2005 Content-Description: 04-40.pdf 04-40.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/10/2005 10:43 AM ) TREE = WELLHEAD = A·ctÜi:\"'rÓR···;· .. kB. ELEV ~ B (. ELÈV ,; "kÖÞ"; ,.~ax Ang 'e.. = Datum MD = .... . ...... ........ Datu m lVD = ? MCEV OY ...·..·ÒïlS ··66;' ? 45·06' ~ 3...(~L~!.??.:. 9474' 8800' SS 110-3/4" CSG, 45.5#, L-80, 10 = 9.953" H 3492' ~ 14-1/2" lBG, 12.6#, 13-CR-80, 0.0152 bpf, D = 3.958" 1-1 hOPOF3-112" lBG 1-1 8423' 8423' Minimum ID = 2.205" @ 9379' 27/8" OTIS XN NIPPLE 13-1/2" TBG, 9.3#, 13CR, 0.0087 bpf, 10 = 2.992" 1-1 8696' ITOPOF 5-112"LNR 1-1 873T I 17 -5/8" CSG, 29.7#, L-80, 10 = 6.875" 1-1 9030' ~ 1 2-7/8" TBG, 6.4#, 13-CR-80, 0.00579 bpf, 10 = 2.441" 1-1 9391' PERF ORA TION SUMrv'LA. RY REF LOG: BHCS ON 12/05/91 ANGLEATTOP FERF: 27 @ 9438' N::>te: Refer to A'oduction DB for historical perf data SIZE SFf" INTffiVAL Opn/Sqz DATE 2 9210- 9220 C 04/09/92 2-1/8" 2 9438 - 9450 0 02/10/95 2-1/8" 4 9458 - 9477 0 06/25/94 2-1/8" 18 9486 - 9532 0 06/20/93 15-1/2" Lf\R, 17#, 13-CR-80, 0.0232 bpf, 10= 4.892" 1-1 9643' Oð. TE REV BY COMJIENTS 12/11/91 ORGIN-ð. L COM'LETION 01108/01 SIS-MWH COl'NffiTEDTO O\I'NAS 01122/01 SIS-LG REVISION 02/18/01 CJS/tp CORRECTIONS 11120/01 DAC/KAK SAFETY \()TES 05127/02 JLM'TLH MIN 10 CORRECTION 04-40 ) SAFETY N:>TES: H25 OVER 300 PPM. TTP @ 8693'. LDL FOUNJ MULTIPLETBG HOLES FROM 500·1050'. CHROME LNR& TBG 2192' H4-112"AV A TRSV SSSV NIP, 10 = 3.81 0" GAS LIFT MANDRELS ST MD lVD DEV lYPE VLV LATCH PORT Oð.TE 1 3012 3011 2 TE-TI\iPD BK-2 2 5121 5087 22 TE-TM'D BK-2 ~ 3 6896 6616 32 TE-TM'D BK-2 4 7226 6897 32 TE-TI'vPD BK-2 5 7590 7209 31 TE-TMPD BK-2 6 7918 7492 31 TE-TI'vPD BK-2 7 8288 7809 31 TE-TMPD BK-2 8 8359 7870 31 TE-TMPD BK-2 8422' H4-1/2"X 3-1/2" XO 1 J!. -.b ~ >< :::! J I I Z ::8': II- I I ~ I I ~ ~ Oð. TE REV BY COMrÆNTS 08/15102 JDMffP CLOSE PffiF 8425' 8595' 8669' 8693' H7-5/8" X 4-1/2" BKR SB-3A HYD PERVlANENT A<R H FRODUCfION rv'LA. NDREL I H FRODUCTION rv'LA. NDREL I 1-13-112" A<RSWN NIP, D =2.810" 1 8696' H3-1/2" X2-7/8"XO 1 9315' 9379' 9391' 9392' 9390' H5-1/2" X 2-7/8" BKR FB-1 PERVlANENT A<R H2-7/8" OTISXN NIP, 10= 2.205" 1 1-12-7/8" BKR SOLID NOSE SHEA ROUT SUB - 2-718" lBG TAIL I - ELI\iDTTLOG \()TAVAILABLE 1 PRUDHOE BAY UIfl 'NELL: 04-40 PERfIIIIT No: 1911340 AA No: 500292222400 SEC 34, T11 N, R15E, 2459.74 FEL 103.74 FN... BP Exploration (Alaska) THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 P M C:LO~M.DOC E E L E W ATE R IA L U N D E TH IS M A R K ER R GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9300 Company: 3/7/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RFSepia Mylar Disk ~' ~, l,~ D.S. 4-43 &SOg 95043 DUAL BURST TDT-P 0!!,095! 1 D.S. 4-40 ~(~ 95056 DUAL BURST TDT-P 011795 1 ........ P~S~ 6-10 ~5 ]) ~059 DUAL BURSTTDT-P 02079~ I . , , ,, , , Iff'"' (~' SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: MAR 0 7 1995 ~,laska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASI' "_ AND GAS CONSERVATION ( /IISSION REPORf SUNDRY WELL OP rlATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1268' FNL, 307' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 229' FNL, 2238' FEL, Sec. 34, T11N, R15E, UM At effective depth At total depth 105' FNL, 2464' FEL, Sec. 27, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 60 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-40 9. Permit number/approval number i 91-134 10. APl number 50 - 029-22224 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9643 feet 9008 feet Plugs(measured) PBTD @ 9518' MD (1/17/95) Effective depth: measured 9518 feet true vertical 8899 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 11 Yards AS 80' 80' Surface 3432' 10-3/4" 2522 cf AS III & 403 cf CIG 3492' 3491' Production 8970' 7-5/8" 522 cf MTC & 309 cf CIG 9030' 8460' Liner 906' 5-1/2" 253 cf CIG 9643' 9008' Perforation depth: measured 9438-9450'; 9458-9466'; 9467-9477'; 9486-9510' true vertical 8828-8839'; 8846-8853'; 8854-8863'; 8868-8889' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13CR, Tbg @ 8423' MD; 3-1/2", 9.3#, 13-CR, Tbg @ 8696' MD; 2-7/8", 6.4#, 13-CR, Tbg @ 9391' MD Packers and SSSV (type and measured depth) Baker SB-3A Hyd Perm Packer @ 8425' MD' Baker FB-1 Packer @ 9315' MD; AVA 4-1/2" TRSV @ 2192' MD; 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached 14. RECEIVED lv1AR - 7 1995 Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data ' _~chor,~ ' OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 218 884 2259 274 Subsequent to operation 441 1208 4940 - 295 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas .---. Suspended -.- Servce 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ./~'~'2/(4~ '~1. /~;"~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 cc: KZ, JWP SUBMIT IN DUPLICATE 4-40 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I/1 7/95: RIH & tagged PBTD at 9518' MD. 2/1 0/95: MIRU & PT equipment. Added perforations: 9438 - 9450' MD (ZlB) Ref. Log: BHCS 12/5/91. Used a 2-1/8" carrier & shot 2 spf at 90 degree phasing at underbalanced pressure. POOH w/perf gun. Noted all shots fired. Rigged down. RIH w/perforating gun & shot 12' of add perforations as follows: Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED MAR -7 1995 Aiaska 0il & Gas Cons. Commission Anchor: GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie RECEIVED FEB 2 6 995 Naska 0ii & ~as Cons. C0mmissb~ Anchorage NO. 9284 Company: 2/27/95 Alaska Oil & Gas Cons Comm Attn' Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Mylar Disk D.S. 1-11 PROD PROFILE 021 295 I 1 D.S. 1-22A PERFRECORD 021 295 I 1 D.S. 4-38 LEAK DETECTION 020995 I 1 D.S. 04-40 PERFRECORD 021 095 I 1 D.S. 09-42 PERFRECORD 021 095 I 1 D.S. 9-49 PERF RECORD 02 0 8 95 I 1 D.S. 11-04A DUAL BURST TDT-P 021 1 95 I 1 D.S. 11-06 LEAK DETECTION 020995 I 1 D.S,:' 11-16ST1' PERF RECORD 020395 I 1 D.S. 14-4 PERF RECORD 020795 I 1 D.S. 14-17 INJEC PROFILE 020795 I 1 D;S;~ 15-07A** - ~ ~ 95069 DUAL BURSTTDT-P 041194 1 D.S. 15-07A 95039 DUAL BURSTTDT-P 122794 1 D.S. 15-40 95022 MWDGR 120294 1 D.S. 15-40 95021 MWDGR 113094 1 D.S!~-07A 95068 PDCGR 100194 1 ,, _ *PLE~A'SE NOTE: THESE PRINTS'REPLACE THE ONES sENT 2/22/95. THE WELLNAME (D.s. 11-16) WAS INCORRECTr '}~PLEASE NOTE: THIS TAPE REPLACES THE ONE SENT 12/21/94, IT WAS NOT DEPTH SHIFTED; THIS ONE SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie RF. CF. IV£D FEB 0 8 1995 Alaska 0ii & Gas Cons. 60mmis$iorl Anchorage NO. 9236 Company: 2/7/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Mylar Disk D.S. 1-22A CBT SONIC IN OPENHOLE 01 1 2 9 5 I 1 D.S. 3-24 CNT-D 01 1 2 9 5 I 1 D.S. 4-38 USIT 01 3095 I 1 D.S. 4-43 DUAL BURST TDT-P 0119 95 I 1 D.S. 4-40 DUAL BURST TDT-P 01 1 7 95 I 1 D.S. 9-2 PROD PROFILE 01 1 695 1 1 D.S. 9-16 INJEC PROFILE 01 1 595 I 1 D.S. 13-30 LEAK DETECTION 01 1 795 I 1 , D.S. 15-41 STATIC PRESS SURVEY 01 1 3 9 5 1 1 D.S. 15-35 SHUT-IN BHP SURVEY/JEWELRY 01 1 495 1 1 D.S. 16-21 INFLAT BRIDGE PLUG SET RECORD 01 1 5 9 5 I 1 , D.S. 15-30 9501 7 DUAL BURST TDT-P 1 23094 I SIGNED' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest $00 W. International Airport Road Anchorage, Al( 99t118-1199 ATTN: Sherrle NO. 9086 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 11/4/94 Field: Prudhoe Bay Well Log De,,K:ription BL RR Sepia RF Sepia Mylar D.S. 4-2A ~ Ur /m GR-C,,~L 10-26-94) D.S. 4-2A -/ ! / ~-- I ( 1 1 "~ CBT (10-26-94) 1 1 D.S.4-30 ST1-J~T'T.' ~'""" ~' ~! PROD PROFILE (10-29-94) 1 1 D.S. 4-40 ~-~ ~ PROD PROFILE (10-28-94) 1 1 D.S. 9-31B C1 L~ _ ~,- ~ PERF RECORD (10-27-94) 1 1 D.S. 9-50 ~ ~.~.. i C.~ c~ GAS LIFT SURVEY (10-26-94) 1 1 D.S. 17-7 ~T- I - [,~/_ PERF RECORD (10-29-94) 1 1 .,,.k.£1Vh-i-1 _ _ _ .. SIGNED: Please sign and retum one copy of this transmittal to Sherde at the above address. Thank you. STATE OF ALASKA ALASK' ")ILAND GAS CONSERVATION (. JlMISSION REPOR'i OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1268' FNL, 307' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 5. Type of Well Development Exploratory Stratigraphic Service ORIGINAL 6. Datum of elevation(DF or KB) 60 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-40 9. Permit number/approval number 229' FNL, 2238' FEL, Sec. 34, T11N, R15E, UM At effective depth At total depth 105' FNL, 2464' FEL, Sec. 27, T11N, R15E, UM 91-134 10. APl number 50 - 029-22224 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9643 feet 9008 feet Plugs(measured) Fill @ 9519' MD (6/25/94) Effective depth: measured 9519 feet true vertical 8900 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 11 Yards AS 80' 80' Surface 3432' 10-3/4" 2522 cf AS III & 403 cf CIG 3492' 3491' Production 8970' 7-5/8" 522 cf MTC & 309 cf CIG 9030' 8460' 9643' 9008' Liner 906' 5-1,2"253 C, C, R EC E IV E D Perforation depth: measured 9458-9466'; 9467-9477'; 9486-9510' AU6 1 5 ]994 Alaska 0il & Gas Cons. Commission true vertical 8846-8853'; 8854-8863'; 8868-8889' Anch0ra~a Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-CR, Tbg @ 8423' MD; 3-1/2", 9.3#, 13-CR, Tbg @ 8696' MD; 2-7/8", 6.4#, 13-CR, Tbg @ 9391' MD Packers and SSSV (type and measured depth) Baker SB-3A Hyd Perm Packer @ 8425' MD; Baker FB-1 Packer @ 9315' MD; AVA 4-1/2" TRSV @ 2192' MD; 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Pr0dudionorlnjection Dat~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure 367 1035 1106 -- 377,'''~/,~ 1461 2459 -- Tubing Pressure 272 263 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations .. Oil x... Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '" Title Engineering ~Supervisor Form 10-404 Rev 0~/15/88 Service 1162/11 cc' KZ, JWP SUBMIT IN DUPLICATE 4-40 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 2/21/94: RIH & tagged PBTD at 9479' MD. 2/22/94: MIRU & PT equipment. RIH w/perforating gun & tagged bottom fill at 9480' MD, then PU & shot 10' of add perforations as follows: Added perforations: 9467 - 9477' MD (Z1B) Ref. Log: BHCS 12/5/91. Used a 2-1/8" carrier, & shot 4 spf, at 180 degree phasing. POOH w/perf gun. Noted all shots fired. Rigged down. 5/8/94: RIH w/CT & jetted a fill cleanout to 9499' MD. 5/9/94: RIH & tagged PBTD at 9510' MD. 6/25/94: MIRU & PT equipment. RIH w/perforating gun & tagged bottom fill at 9519' MD, then PU & shot 8' of add perforations as follows: Added perforations: 9458 - 9466' MD (Z1B) Ref. Log: BHCS Used a 2-1/8" carrier, & shot 4 spf, at 180 degree phasing. POOH w/perf gun. Noted all shots fired. Rigged down. Shot at underbalanced pressure. 12/5/91. Shot at underbalanced pressure. Returned the well to production w/gas lift & obtained a valid welltest. Gas Oo~s. Comm~ss~o~ ARCO Alaska, Inc. Date' Subject: From/Location: Telephone: To/Location: July 6, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Transmittal #: 94054 P.O. Box 100360, horage, AK 99510,a~~ JUL 7 7' 7994 · 4~ska Oil & Sas Cons. Commission Anchor~.~o i Well Number 7-O-!~0 i 1-05ST ~7..-IZq f 2-20 c~O.--i~q.q !2-28 ~- i 3-2 ~-o-- ~_~* ! 4-2 ¢5- Cci' i 4-30ST RI.-- (5~ ! 4-40 qU---'t~ ! 4-43 o/q_ !0 ! 4-44 c1 L(.-- ~.tJ, i 4-45 \I 5-03A \! 5-03A 5- 3 ~[~ ~5 ~ 5-33 Log Date (M-D-Y) 6-21-94 1 6-20-94 6-18-94 6-28-94 6-22-94 6-17-94 6-25-94 6-25-94 6-23-94 1 6-20-94 6-25-94 6-9-94 Tool Type Prod Prof /' Prod Prof Run, Sc;de ,1"&5" i I 5" IBP Setting Rec Leak Detection i 1,2" & 5" / Leak Detection i 1,1"&5" Patch Set Rec i 1 5" / Perf Rec -/ Pen` Rec · .- Comp Rec I f Pen` Rec · /' Perf Rec. 1 5" 1 5" 1 5" 1 5" ., ! 1 5" " CDN 6-9-94 ! 1,2" &5" SlimlGR i 1,2"&5" CDR i 1,2"&5" Contractor i i SCH SCH SCH SCH ,. SCH SCH SCH SCH SCH SCH SCH SCH SCH 6-9-94 SCH 6-17-94 .,' Leak Detection I 1,1" & 5" 6-29-94 --' Pen' Record ~ 6-15-94 / TDTP ! 1, 5" .-- Pen' Rec SCH SCH SCH 6-24-94 ! 1, 5" SCH 6-28-94 i ~' Pen' Rec ! 1,5" SCH t,,. Pen' Rec SCH SCH SCH 9-05A 9-05A 9-30ST 11-6 11-29i 12-02 12-7A 12-19 12-23 12-28 13-08 14-24 14-39 14-39 16-28 6-19-94 i 1, 5" i , '. 6-21-94 ~' Pen' Rec i 1 5" 6-22-94 1 ~ Pen' Rec i 1, 5" 6-29-94 ." Dual Burst i 1, 5" 6-22-94 -"'Prod Prof l"& 5" 6-27-94 6-28-94 6-27-94 6-27-94 6-28-94 .--' Perf Rec 6-15-94 -" Inj Prof i 1, 5" -"Leak Detection ! 1, 5" '"' Inj Prof ~ Prod Prof SCH SCH 1, 5" SCH SCH 6-27-94 1, 5" 6-30-94 ~ Pen` Prof i 1, 5" : 1, 5" 6-19-94 ~' CNL i "'Leak Detection i 1 SCH 1,5" SCH 1, 5" SCH SCH 6-19-94 1" &5" / Leak Detection ! 1, 2" 6-20-94 '" Pen` Rec i 1, 5" SCH i SCH I SCH ~ SCH ~ SCH ! * DS# 04-02 The APl# is 50-029-20088-00 Number of Records: 35 ARCO Alaska, Inc. is a Subsidiary of AtlanficRIcht'leldCompany ARCO Alaska, Inc. Date: Subject' From/Location: Telephone: To/Location: ,----- P.O. Box 100360, A~-~horage, AK Mar 15,' 1994 Transmittal #: 94029 ~_ John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 99510,~ ~, !wellNurrber iL°g Date(M-D-Y) Tool Type i RUn,scale Contractor i 01-02 2-26-94 Prod/Spin/Temp(,t~ 1, 5" Schlumber 01-03 2-19-94 Prod~BS/Temp~,~"3 1, 5" Schlumber ! 01-09 3-01-94 Tubing Cutter ~.> 1, 5" Schlumber I 01-11 2-27-94 Prod Prof/Spin 1, 5" Schlumber ~ 01-18 i 2-23-94 Leak Detection 1, l"& 5" Schlumber f 01-25 ~ 3-06-94 CNL I 1, 5" $chlumber '~03-20A ! 2-17-94 Perf I 1, 5" Schlumber ~03-20Ai, 3-03-94 Dual Burst '~:i~' 1, 5" Schlumber 03-32 I 2-26-94 Leak/Press/'Temp 1, 2" Schlumber ~ f 03-34A I 2-24-94 Prod/Press/Temp 1, 2"&5" Schlumber 04-01 2-19-94 Prod 1, 5" Schlumber 04-24!2-22-94 Prod I 1, 5" Schlumber 04-40 I 2-22-94 'Perf I 1, 5" Schlumber 04-46 ! 2-16-94 Rope Perf I 1, 5" Schlumber //04-47! 2-18-94 v PerfI 1, 5" Schlumber · 04-47 '2-15-94 '"' CBT-GR I 1, 5" Schlumber 'X~04-47 2-15-94 v CET-GR 1, 5" Schlumber 05-06 2-11-94 Perf 1, 5" Schlumber 05-14A 7-11-93 USlT/Cem&Con' ('j~"~l, 5" Schlumber 05-15A ! 05-15A ~ GND/GR-~v,~>~ 1, 5" Schlumber 05-26 3-02-94 Dual Burst '1'o~ 1, 5" Schlumber /'06-15 2-21-94 Prod 1, 5" Schlumber \ 06-15 2-22-94 Comp Neutron 1, 5" Schlumber 06-22A 3-01-94 Perf 1, 5" Schlumber 07-08 3-02-94 Prod/~B¢~ 1, 5" Schlumber 07-23 3-07-94 Leak/Spin/Temp/~,~ 1, 5" Schlumber 09-34 2-21-94 Tubin(:j Cutter ~., 1, 5" Schlumber 11-02 2-10-94 Inj Pmf)Si~,~f~, 5" Schlumber /'11-04 2-20-94 Tubing Cutter ~ 1, Schlumber i~,11-04 2-17-94 Tubing ~.w6,.~ ~.J, 5" Schlumber 11-7ST 3-06-94 Inj Prof/Spin I~lt'~e._ 1, 5" Schlumber 11- 2-25-94 Leak/Press/Temp 1, 1"&5" Schlumber 16ST /Spin//~F. hb ~--'lt "~111'6ST 3-08-94 Comp/l~l~table IZoCo---I%t~i01'5" Schlumber .~11-17 .2-20-94 Leak 1, 5" Schlumber 1-17 3-08-94 Prod 1, 5" Schlumber 11-23 I 8-09-91 TMD 1, 5" Halliburton /11-24A I 3-05-94 Perf/GR/CCL 1, 5" Schlumber ]\11-24A I 2-22-94 Comp/Perf 1, 5" Schlumber ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCof~ t ~njlFBS/T ~u We~ 4-24 the cod'ect AP~ # is 50.029-2150B'00 Number ot RecordS: hn F_. DeGreY philt~ps Central F~[es ANO-8 Geology Distribution: ohevfOn E~o~ ,:Stat~,of Nas~a ~ · coPY of t~ansmitt~t. ....... '-'~ '" signing and returning a p~e~se RECEIVED MA~ 1 8 '):9'94 INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 91-134 BHCS/GR 91-134 CBT 91-134 COMP 91-134 COMP 91-134 CYB 91-134 91-134 91-134 9i-134 91-134 91-134 91-134 91-134 91-134 91-134 91-134 91-134 91-134 91-134 91-134 91-134 91-134 DIL/SFL/GR GR/CCL/JWL INJP/PITS LDN (PORO) LDN(RAW) LEAK/SPIN/TEMP PERF PERF PITS ?ITS/INJP PROD SSTVD USIT(C&C) 407 DAILY WELL OP SURVEY 5150 RI,2&5",9018-9557 R1,5",6000-9500 RI, 5",9200-9490 R1,5",8600-9530 R1,5",9018-9626 Rl~2&5",9018-9626 R1~5",9200-9540 RI~ 5",8537-9500 R1,2&5'~,9018-9626 RI,2&5",9018-9626 RI,2&5",250-8550 R1,5",9321-9504 R1,5",9331-9519 R1,5",9400-9520 R1,5",9420-9522 R1,5",5050-9500 Rl,l&2",9018-9626 R1,5",3400-9530 COMP DATE:12/ll/91 11/23/91-12/12/91 SS DIRECTIONAL OH-BC~'~,9018-9628 11/17/1993 PAGE: 1 INDIVIDUAL WELL GEOLOGICAL INVENTORY REPORT PERMIT DATA DETAIL 11/17/1993 PAGE: 1 SUMMARY Are well tests required? Yes ~ Was welI cored? Yes ~ If yes, was the core analysis & description received? Are dry ditch samples WELL IS IN COMPLIANCE. Yes ~__~.. Yes COMMENTS: ~ STATE OF ALASKA ALASKA ".AND GAS CONSERVATION CC ..... 'AISSION REPORT uF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate X .... Other. X 6. Datum of elevation(DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1268' FNL, 307' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 229' FNL, 2238' FEL, Sec. 34, T11N, R15E, UM At effective depth At total depth 105' FNL, 2464' FEL, Sec. 27, T11N, R15E, UM Development Exploratory Stratigraphic Service 60 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-40 9. Permit number/approval number 91-134 10. APl number 50 - 029-22224 11. Field/Pool Prudhoe Bay Oil Pool 5. Type of Well 12. Present well condition summary Total depth: measured true vertical 9643 feet 9008 feet Plugs(measured) PBTD @ 9507' MD (8/9/93) Effective depth: measured 9507 feet true vertical 8889 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 20" 11 yards AS 115' 115' Surface 3432' 10-3/4" 2522 cf ASII & 403 cf CIG 3492' 3492' Production 8970' 7-5/8" 522 cf MTC & 309 CF CIG 9030' 8461' Liner 906' 5-1/2" 253 CIG 8737-9643' 8195-8949' Perforation depth: measured 9486-9510' true vertical 8871-8892' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13-Cr; 3-1/2", 9.3#, 13-Cr-80; 2-7/8", 6.4#, 13-Cr-80 w/tail @ 9392' MD Packers and SSSV (type and measured depth) Baker SB-3A pkr @ 8425 MD; Baker FB-1 pkr @ 9315' MD; AVA 4-1/2" SSSV @ 2192' MD 13. Stimulation or cement squeeze summary ~ ~ C ~'IV' !~ ~) Intervals treated(measured) See attached. Treatment description including volumes used and final pressure ,Alaska 0il & Gas Cons. Cor~lso,~*''" ' '~"' Representative Daily Average Production or Iniection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl easing Pressure Tubing Pressure Prior to well operation 1132 18720 4773 -- 418 Subsequent to operation 1601 1578 632 -- 261 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. Signed .~ Title Engineering Supervisor Form 10-404'l~ev 06/15/88 Date SUBMIT IN DUPLICATE 1047/5 MRM/MJB cc: SW, JWP 4-40 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE~ FOR GAS & WATER SHUTOFF & FRACTURE TREATMENT OF ZONE lA 3/28/93: A CTU Cement Squeeze for Gas & Water Shutoff was performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/1% KCl Water & Crude, then RIH w/CT & cement squeezed the perforation intervals at: 9486 - 9510' MD (ZlA) 9511 - 9532' MD (Z1A) Ref. Log: BHCS 12/5/91. Pumped 26 bbls of Latex Acid Resistive Cement & placed all the cement behind pipe at 1500 psi maximum squeeze pressure. Contaminated cement w/Biozan & jetted wellbore clean. POOH w/CT. Rigged down. 3/29/93: A CTU Cement Resqueeze for Gas & Water Shutoff was performed as follows: MIRU CTU & PT equipment. Loaded wellbore w/1% KCI Water & Crude, then RIH w/CT & resqueezed the perforations (listed above). Pumped 10 bbls Neat Latex Acid Cement, followed by 5 bbls of Latex Acid Resistive Cement w/aggregate, followed by 10 bbls Neat Latex Acid Cement. Placed 17 bbls of cement behind pipe at 3500 psi maximum squeeze pressure, held for I hour. Contaminated cement & jetted out contaminated cement from wellbore. POOH w/CT. Rigged down. 5/3/93: Performed a Pump In Temperature Survey that indicated a channel was present requiring a resqueeze. 6~4~93: A CTU Cement Resqueeze for Gas & Water Shutoff was performed as follows: MIRU CTU & PT equipment. Loaded wellbore w/Hot 1% KCl Water, then RIH w/CT & resqueezed the perforations (listed above). Pumped 15 bbls Micro Matrix Cement, followed by 15 bbls of Latex Acid Resistive Cement, and placed 19 bbls of cement behind pipe at 3500 psi maximum squeeze pressure, held for 1 hour. Contaminated cement & jetted contaminated cement from wellbore to 9530' MD. POOH w/CT. Rigged down. 6/20/93: Reperforated: 9486 - 9510' MD (ZIA) Ref. Log: BHCS 12/5/91. 7/1/93 - 7~4~93: MIRU & PT wireline equipment. RIH & set a Shear Disk in the tubing at 9367' MD, for a ROPE Treatment (Really Overpressured Perforation Extension) of the open perforations (above). Loaded Slickwater on disk to 5800' MD, then pressured up & ruptured the Shear Disk at 6320 psi. Retrieved the shear disk. Rigged down. 7/19193: MIRU & PT equipment to 9000 psi. Pumped a Data Frac followed by a Hydraulic Fracture Treatment using 16/20 mesh proppant, through the perforations (above). Pumped Data Frac consisting of 179 bbls 20# Pre Pad Gel @ 20 bpm, followed by Shutdown. ISIP @ 2100. Resumed pumping 60 bbls 30# Crosslinked Gel w/FLA @ 20 bpm, followed by 137 bbls 20# Gelled Flush, followed by Shutdown. ISIP @ 2367. Resumed pumping Fracture Treatment consisting of 30 bbls 30# Crosslinked Pad @ 20 bpm, followed by 188 bbls Slurry w/1 -10 ppg proppant stages @ 20 bpm, followed by 125 bbls 20# Flush, followed by Shutdown. Placed a total of 36,000 lbs of proppant into the formation. 7/20/93 & 8~9~93: Performed proppant fill cleanouts to 9507' MD. Rigged down. Returned the well to production w/gaslift & obtained a valid production test. RECEIVED Alaska OJJ & Gas Coi~s. {;ommisg~'u, Anchora,cjs ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ~Zff~_2-21 7-17-93 1~!~_! Burst TDTP R,m 1, ~,,,ozz~- q~- 18A 7-25-93 Pe~ Record R~m 1, ~-36 7-15-93 USIT ~lor R.n 1, 5" ~°~lz~tch ~1~ -36 7-20-93 Pe~ Record R~ 1, 5" ~q0-~ h -36 7-24-93 Pe~ Record ~z~~o R~ 1, 5" Sch 7~4-12 7-18-93 C~ ~-~a~ R~ 1, 5" Sch t~ * 4-16 7-19-93 ~ml B~t ~P ~~~ 1, 5" Sch ., ~q~4-40 7-22-93 ~ ~tect z~- ss~ R-n 1, 2"&5" Sch ' ~~~- 1 7-23-93 Pe~ Record ~5-~ R-n 1, 5" Sch ~~~-29 7-22-93 ~od ~offie ~-Io~ R~m 1, 5" ..~. Sch 5 c ~~~-32 7-22-93 ~od ~offie l~m- I~5 R.n 1," ' "' h 1-27 7-18-93 ~ Brat ~ Rl!n 1, 5" ~~~4-4 7-24-93 ~ Brat ~ R~m 1, ~~~5-3 7-14-93 ~ Brat T~P R~ 1, v .... ~cn ~ ~C~ ~~J 5-4 7-24-93 ~ B~t ~P R~m 1, ~~15-13 7-24-93 C~ R~=n 1, 5"~%~Sch 5- 7-25-03 R,,- ~~6-9A 7-26-93 ~ucflon ~gz~l~~~ 1, 2"&5" Sch ~~l 7-3 7-20-93 ~ucflon ~g R~ 1, 2"&5" Sch Ple~e s~ ~d ret~ pe at~ched copy ~ receipt of ~. ~ve A Nice ~y! ~n~ W~ce APPROVED ATO-1529 ~as~ 93~i- -- ,/ # CENTRAL FILES # CHEVRON D&M # CLINT CHAPMAN # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO The correct bottom logged interval for 4-16 is 11,507 feet. ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 8-10-93 REFERENCE: ~------1-30 ~ ~_~_~4-1 ~4-40 ~ 7.~~9-13 -26 -42 1-12 1-18 1-22 ~-1 ~-1 ~4-5A ~4-40 ' 7-1~ ~7-10 7-14-93 7-5-93 7-11-93 7-17-93 7-17-93 7-10-93 7-6-93 7-6-93 7-8-93 7-11-93 7-3-93 7-3-93 7-9-93 ?-4-93 7-4-93 7-8-93 7-2-93 7-16-93 7-16-93 7-5-93 7-6-93 7-9-93 7-13-93 7-12-93 Completion Record 197~q~,°5" Sch Perf Record ~)0~zi~ Rnn 1, 5" Sch InJ Profile ut ~-qt~o~ R~!n 1, 5" Sch Perf Record 1~%-~-~5 Rl~n 1, 5" Sch oa ~ome _ R_ 1, Sch ~ucflon ~g~lSz-q~OORnn 1, 5" Sch P~/~J ~offiea~~-n 1, 5" Sch ~ucflon ~g~~R~ 1. 1"&5" Sch ~mpleflon Record R~m 1, 5"~~sSSSch Peri Record ~~~ R~ 1, 5" Sch Peff Record ~z~- ~ ~ R-n 1, 5" Sch Pe~Record%~0-~q Rnn 1, 5" ~h ~ ~tect~-~ Rnn 1, 5" ~ ~tect Rnn 1, 2" 0- qo~ Sch ~k ~ct ~~0 R!!n 1, 2"&5" Sch ~ Brat ~P R~ 1, 5"~-~ch Pe~ Record ~- Iz~5l R~m 1, 5" Sch ~e-~ ~g- ~P ~%~b~ 1, 5" Sch ~ ~tect ~-%~o R~ 1, 2" Sch Pe~ Record ~sa~~ R~ 1, 5" Sch ~J ~~/~ ~c R~n 1, Pe~ Record ~10~ I R~m 1, 5" Sch ~ ~tect ~_ ~ot~ Rnn 1, 2" Sch Please sign and return .t~e attached copy ~s receipt of data. RECEIVED BY ~ .~__~ T----~T--' ........ ' Have A Nice Day! Sonya Wallace APPROVED ~ ........ ATO- 1529 Trans# 93081 # CENTRAL FILES # CHEVRON # CLINT CHAPMAN # BPX # EXXON # STATE OF ALASKA # MOBIL * The correct top logged interval for 11-22 is 380 feet. ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE FINALS * 1.1B~1~°~6.20_93 1-16 ~ ~"~6'25-93 1-22 ~> ~,-~ 6-29-93 1-30 ~;~".~ 6-29-93 3-25A ~ 6-27-93 3-30 '/'{--~'~ 6-23-93 3-31 ~-0z~6-23-93 3-33 ~/~/o 6-29-93 3-36 ~3~1~ 6-28-93 4-37 ~/~? 6-20-93 4-40 ~ N !~6-20-93 5-3A ~f 6-18-93 5-26 ~ ~ ~ ~ 6-25-93 6-4 ?~- ~z~6-26-93 6-13 ~ -3a 6-25-93 9-49 ~ 2-~ 6-22-93 9-50 ~"~-~t~ 6-26-93 12-26 ~'~--'~'/ 6-22-93 13-1~ ~'--~ ~ 6-27-93 13-14 ?~-~)6-28-93 13-20 ~;z.-~? 6-19-93 16-12 ~l--~-~, 6-21-93 17-20 ~) ~-;~"6-26-93 ~i~:~AGI-6 ~ ~.o? 4-25-93 AGI-8 ~-~6-19-93' *** AGI-1041~$~ 6-18-93 *** AGI- 10-~ 6-18-93 Prod Profile R.n 1, 5" Sch Perf Record R.n 1, 5" Sch Production Log R.n 1, 5" Sch Leak Detect Run 1, 5" Sch Perf Record Run 1, 5" Sch Leak Detect Run 1, 2"&5" Sch Bridge Plug Setting Run 1, 5" Sch Completion Record Run 1, 5" Sch Perf Record Run 1, 5" Sch Dual Burst TDTP (Borax) Run 1, 5" Sch Completion Record R!m 1, 5" Sch SBT/GR/CCL R!!n 1, 5" Atlas TDTP (Borax) Run 1, 5" Sch Production Log Run 1, 5" Sch Perf Record R~!n 1, 5" Sch Production Log R!]n 1, 1"&5" 8ch -production Log Run 1, 2"&5" Sch CNL Run 1, 5" Sch Leak Detect R~_m 1, 2" Sch Leak Detect Run 1, 2" Sch Plug Depth Record Run 1, 5" Sch Prod Profile Run 1, 1"&5" Sch Production Log Run 1, 5" Sch ~Acoustic.CBT Run 1, 5" Atlas Perf ReCOrd Run 1, 5" Sch GR/C(~ Run 1.5" Sch Perf Record Run 1, 5" Sch Please sign and return the attached .c~op~ as receipt of data. ,,CEiVE Sonya Wallace APPROVED_ ATO- 1529 Trans# 93074 # CENTRAL FILES # CHEVRON t ECEIVED # ~~ 'dUL 3 0 1993 # CLINT CHAPMAN ## F_..XZO~Mo~IL Alaska 011 & ~as Co.s. Com~i~io. Anchorage # BPX # STATE OF ALASKA The correct name for this log is 1-1B. This is a revised log, please discard previous copy received. The correct APl# for AGI-10 is 50-029-22353-00. ARCO ,~l~ska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 REFERENCE: DATE: 6-9-93 · 14-22A 5-6-93 Static Pressure Run 1. 5" Sch 5-8-93 Prod Profile Run 1. 5" Sch 5-10-93 Production Run 1. 5" Sch 5-11-93 CBT/New TBG/Jewelry Run 1, 5" Sch 5-10-93 Leak Detect/Spin/Temp/Press l~m 1, 2' & ~' Sch 5-4-93 USIT (Cement & Corrosion) (Color) Run 1, 5" Sch 5-3-93 lnJ Proflle/Spin/Temp/Press Run 1, 5" Sch 5-2-93 Inj Profile/PITS Run 1, [~' Sch 4-24-93 Leak Detect/Spin/Temp/Press Run 2, 5" Sch 5-7-93 D,_~! Burst/TDT-P (Borax) Run 1. 5" Sch 5-6-93 Vertilog Run 1. 5" Atlas 5-8-93 GR/Col!~r Run 1. 5" Atlas 5-6,93 Perf Record Run 1. 5" Sch 5-7-93 GR/O2L Run 1, 5" Sch 5-10-93 CNL Run 1, 5" Sch 5-11-93 Leak Detect Run 1, 2' & I~' Sch 5-7-93 Pelf Record Run 1, 5" Sch 5-9-93 TDT-P (Borax) l~m 1, 5" Sch 5-3-93 Leak Detect/Spin/Temp/Press Run 1, 5" Sch 5-3-93 Perf Record Run 1, [~' Sch 5-4-93 Production Run 1, I~' Sch 5-5-93 CCL/Perf Record Run 1, 5" Atlas 5-8-93 SBT/GR/CCL l~_m 1, ~' Atlas l~m 1, t~' Sch l~_m 1, 5" Sch Run 1, 5" Sch l~m 1. 2'& [~' Atlas a ;.~I-4 5-7-93 GR/CCL (Color) ~-~AGI-5 5-10-93 GR/CCL (Color) ~/~]~I-6 5-10-93 GR/CCL (Color] ~AGZ.S 5-3-93 sm'/G~,/cc~ Please sign and return the attached copy as receipt of data~ RECEIVED BY__~~.~~ Have A Nice Day! ~/)~/ Sonya Wallace ~.~ ~,/ ~'~/' APPROVED AT0-1529 ~d. c////~ C/~.~s~ 9306~ ..... ~ C~~ON "~ ~¢~.. PB ~~ ~ ~ CLOT C~~ "~'~ ~ BPX ~ E~ON ~ MOB~ # STATE OF ALASKA STATE OF ALASKA ALASKA ~"-'~. AND GAS CONSERVATION CC '-" ~ilSSION REPORT SUNDRY WELL OPEHATIONS(/ 1. Operations performed' Operation shutdown Stimulate Plugging Perforate X ~' ~/,/~ Pull tubing Alter casing Repair well Other - ,.. 5. Type o~f W. ell . , 6. Datum of elevation(DF or uevelopmem 2~ 60' RKB '~eet 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1268' FNL, 307' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 229' FNL, 2238' FEL, Sec. 34, T11N, R15E, UM At effective depth At total depth 105' FNL, 2464' FEL, Sec. 27, T11N, R15E, UM Stratigraphic Service Exploratory 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-40 9. Permit number/approval number 91-134 10. APl number 50 - 029-22224 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 9643 feet Plugs(measured) 9008 feet Effective depth: measured 9558 feet true vertical 8934 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 115' 20" 11 Yards AS 115' 115' Sudace 3492' 10-3/4" 2522 cf ASII & 403 cf CI 'G' 3492' 3492' Production 9030' 7-5/8" 522 cf MTC & 309 cf CI 'G' 9030' 8461' Liner 906' 5-1/2" 253 cf CI 'G' 8737'-9643' 8195'-8949' Perforation depth: measured 9210-9220';9486-9510';9511-9529' true vertical 8623-8633';8871-8892';8893-8909' Tubing (size, grade, and measured depth) 4-1/2",12.6#,13-Cr;3-1/2",9.3#,13-Cr-80;2-7/8",6.4#,13-Cr-80 w/tail @ 9392' MD 13. Stimulation or cement squeeze summary 14. Packers and SSSV (type and measured depth) Baker SB-3A pkr @ 8425 MD;Baker FB-1 pkr @ 9315' MD; AVA 4-1/2" SSSV @ 2192' MD E EiVED Intervals treated(measured) Treatment description including volumes used and final pressure i)~k~ Oil & Gas Cons. 60mm~'ss~°~ Representative Daily Averaqe Production or Injection Data 'Aflch0fS. g~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 2000 Subsequent to operation 202 _./ 2057 20 680 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. Signed .... '~-'.~ ~ ~%~"¢¢,..-,,,'.'/~ Title FS-2 Regional Operations Engineer Form 10-404 R~ 06/15/88 ~ Date 57 L~t,/~"~ '~) SUBMIT IN DUPLICATE _ .tlLY REPORT OF WELL OPER~i,IONS DS 4-40 Perforating Operations: ARCO Alaska, Inc. perforated DS 4-40 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 9/19/92. The intervals perforated were the following: 9486-9510' and 9511'-9529' MD (Reference Log: SWS-BHCS dated 12/5/91). Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 9/19/92. RU perforating unit, pressure tested BOP's and lubricator to 3000 psi, okay. RIH, opened well to flow and perforated 9486' - 9510' MD at 6 SPF, S.I. well, POOH, and confirmed all shots fired. RIH, opened well to flow and perforated 9511'-9529' MD at 6 SPF, S.I. well, POOH, and confirmed all shots fired. (ref: SWS-BHCS of 12/5/91). Rigged down and secured well. RDC: 5/14/93 RECEIVEE) MAY 2 '1 t99,3 Alaska Oil & Gas Oons. Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HOI.~ FINALS 7q_.~_~2-8 1-8-93 InJ Profile -17 1-10-93 Gas Entry -5 11-23-92 Prod Profile - 14t 1-9-93 InJ Profile 4-40 11-24-92 PITS ~-~--~___~6-12A 12-4-92 Prod Profile ~?~_.3.~=-~v 11-19-92 InJ Profile 11-22-92' Ptunp-~ Profile ~?,~_~9--42 _ ~ 11-1A ~1-1A 1-13A 1-16ST 1-12-93 12-3-92 12-3-92 12-3-92 12-6-92 12-10-92 Collar/Tubing Patch GR/CoUar Prod Profile GR/Collar PITS CCL/, eweh Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Calnco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Canlco Camco .~ 2-7A ~l~_j_~l - 1-8-93 GR/Collar Run 1, 5" ~Z~t~~14-28 1-8-93 Prod Profile Run 1, 5" ~e~esi~n~71~5and 11-22-92 Static TemPerature Run1, 5" return the attached copy as receipt of data. Calnco Camco Camco Have A Nice Day! Sonya Wallace ATO-1529 Trans# 93037 # CENTRAL FILES # CHEVRON . D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PIHLLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA_ RE CEIVED The correct APl# for 4-14A is 50-029-20310-00. ~aska 011 & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-7-93 ItEFER~NCE: ARCO CASED HOLE ~~ 10-12-92 Perf Record Rl~n 1, 5" 7 ~.'~J3-25 8-15-92 Perf Record Run 1, 5" 8-15-92 Perf Record R!m 1, 5" 9-19-92 Perf Record Run 1, 5" 5-2-92 GR/Temp Log Run 1, 5" 10-17-92 PerfRecord Run 1, 5" .~ 8-21-92 Perf Record Run 1, 5" ~ ~ c~ ~x-xz~:~-~l' 8-22-92 Perf Record Run 1, 5" ~T 6-23-92 GR/Perf Record Ru_n 1, 5" 10-19-92 Perf Record Run 1, 5" 8-11-92 Perf Record Run 1, 5" 10-16-92 Perf Record Run 1, 5" Please sign and return th attache~l ffopy as receipt of data. RECEIVED Have A Nice Da~ Sonya Wallace ~. [C~/~ ~.9 APPROVED ATO-1529 t:~ ~0 '/ t~'~ Trans# 93005 # CI~VRON PB WELL FILF~ D&M ~ R&D # EXTENSION EXPLORATION # BPX # EXXON # STATE OF ALASKA MARATHON TEXACO # MOBIL * The correct AP1 # for 3-34A is 50-029-21132-01. ** The correct AP1 # for 7-4A is 50-029-20292-01. ARCO Ahska, In~. P,O.Box 1OO36O Anchorage, Alaska 09510 DATE: 12-18.O2 REFERENCE: ARCO 1-SST ?° - ~/° 2-18 3-20 ~S-OS ts-so ~S-SS ~ ~S~T 6-0 CASED HOLE 10-11 10-23-03 IO-2-02 11.O-02 11-12-02 10-12.O2 11-7-02 16-o.o2 lO-O-O2 11-6-o2 11-12.o2 lO-S.o2 lO-18-o2 11-8.o2 1o-o.o2 10-11-02 lO-3.o2 lO-24.o2 6-18 11-13-02 7-2s&&-./~' 8-0-01 o-28 J~/-.~? o-24.o2 o-28 J~--27 o.24-o2 ~-;/~6 ~o-2o 2-28-o2 Co-2o 2-28-o2 AGI-1 ~.~-/.~/ 12-6-02 FINALS I,e&k Detect ~ezste]0 Run 1. lY'&10" Perl Record Run 1. Peri Record Run 1. Collar (IBP) Run 1. InJ Profile (Step Rate) Run 1. Leek Detect(flexstak) Run 1, Collar (IBP) Run 1. GE/Collar Run 1. Prod Profile Run 1, Collar (IBP) Run 1, Prod Profile Run 1, IS" Peri Record Run 1, Leak Detect (flezstal0 Run 1, Prod Profile Run 1, Iai Proffie/PFFS/Colhr Run 1, Prod Profile Run 1, Peri Record Run 1, Peri Record Run 1, PITS. Run 1, TMD Run 1, Peri Record Run 1, Peri Recor~ Run 1, PSG/GR (Computed Results) Run 1, IS" PSG/GR ~/ Run 1, Le~k Detect (flexstal0 Run 1, Set IBP Run 1, Peri Record Run 1, Collar Run 1, Peri Record Run 1, Iai Proffie/PIT8 ~ Run 1, Peri Record .~ Run 1, Prod Profile (flezsta]0 Run 1, Peri Record Run 1, Peri Record Run 1, Peri Record / Run 1, Prod Profile (flezstal0 .- Run 1, Iai Profile/Tamp// Run 1, Peri Recird *- Run 1, FY' GR/Collar / Run 1, 8BL/GR/CCL ," Run 1, RECEIVED BY_~~~~~_~~ "'"""'" RECEIVED the attached copy as receipt of data. m CEHTRALr 0 199 # CHEV~,,O__~.. fl, · ~,~ cons. Commission PB WELL SM~ Oil & Gas Cons. Anchora§i~ Camco HIS HIS Camco Camco Camco Camco Camco Cameo Camco Camco HIS Camco Camco Camco Camco HIS HIS Camco HIS HIS HIS HIS HIS Camco Camco HIS Camco HIS Camco HIS Camco HIS HIS HIS Camco Camco HIS Camco Atlas STATE OF ALASKA ALASKA ?" AND GAS CONSERVATION REPORT 'UF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1268' FNL, 307' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 229' FNL, 2238' FEL, Sec. 34, T11N, R15E, UM At effective depth At total depth 105' FNL, 2464' FEL, Sec. 27, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED OCT 1 2 !~'~ .Alaska 0il & Gas Cons. Commission Anchorage 6. Datum of elevation(DF or KB) 32' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-40 9. Permit number/approval number 91-134 10. APl number 50 - 029-22224 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 9643 feet 9008 feet Plugs(measured) Fill @ 9529' MD (9/19/92) Effective depth: measured 9529 feet true vertical 8906 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 11 Yards AS 80' 80' Surface 3460' 10-3/4" 2522 cf AS III & 403 cf CIG 3492' 3491' Production 8998' 7-5/8" 522 cf MTC & 309 cf CIG 9030' 8460' Liner 906' 5-1/2" 253 cf CIG 9643' 9008' Perforation depth: measured 9210-9220'; 9486-9510'; 9511-9514'; 9514-9529'; 9529-9532' true vertical 8621-8630'; 8868-8889'; 8890-8893'; 8893-8906'; 8906-8909' Tubing (size, grade, and measured depth) 4-1/2", 12.6g, 13-CR, Tbg @ 8423' MD; 3-1/2", 9.3#, 13-CR, Tbg @ 8696' MD; 2-7/8", 6.4#, 13-CR, Tbg @ 9391' M D Packers and SSSV (type and measured depth) Baker SB-3A Hyd Perm Packer @ 8425' MD; AVA 4-1/2" TRSV @ 2192' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 0 0 0 -- 2027 1724 1783 Tubing Pressure 0 305 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. Signed,~,3O'c~o~-J~- Form 10-404 Rev 06/15/88 902/12 JWS/LW cc: SW, JWP Title Sr. Area Operations Engineer Date SUBMIT IN DUPLICATE 4-40 DESCRIPTION OF WORK COMPLETED PERFORATION BREAKDOWN & ACID STIMULATION TREATMENTS 3/19/92: MIRU & PT equipment to 8400 psi. Performed a fullbore Non Reactive Perforation Breakdown Treatment, pumping through two empty mandrels, to treat the straddled perforations at: 9210 - 9220' MD (Z3) Ref. Log: BHCS 12/5/91. Pumped 63 bbls Meth Water, followed by 246 bbls Seawater @ 20 bpm/5300 psi, followed by Shutdown. ISIP @ 1480 psi. Freeze protected w/40 bbls Meth Water. Rigged down. 4/1 0/92: Added perforations: 9486 - 9510' MD (Z1A) 9514 - 9532' MD (Z1A) Ref. Log: BHCS 12/5/91. 7/2/92: MIRU & PT equipment. RIH w/CT mounted swirl nozzle & jetted paraffins from the tubing. Jetted tubing w/142 bbls Hot Crude, followed by 33 bbls 50% Diesel/50% Xylene, followed by 41 bbls Crude, followed by Shutdown for 30 minutes. Resumed pumping 140 bbls Hot Crude, followed by 10 bbls Diesel, followed by Shutdown. Rigged down. 9/19/92: Added perforations: 9511 - 9514' MD (Z1A) Ref. Log: BHCS 12/5/91. Reperforated: 9486 - 9510' MD (Z1A) 9514 - 9529' MD (Z1A) Ref. Log: BHCS 12/5/91. 9/26/92: An Acid Stimulation was performed to initiate production as follows: MIRU & PT equipment to 4000 psi. RIH w/CT mounted swirl nozzle & reciprocated the stimulation fluids across the perforations (listed above). Circulated 140 bbls Crude @ 3 bpm, then began washing the perforations. Pumped: f) 50 bbls 7.5% HCI @ 0.9 bpm, followed by g) 74 bbls 7% HCI w/0.5% HF @ 1.5 bpm, followed by h) 105 bbls 2% NH4CI Water, followed by i) 100 bbls 50% Diesel/50% Xylene @ 2.0 bpm, followed by j) 40 bbls Meth Water, followed by k) Shutdown. Rigged down. a) 50 bbls 50% Diesel/50% Xylene @ 0.5 bpm, followed by b) 50 bbls 7.5% HCI @ 0.4 bpm, followed by c) 75 bbls 7% HCI w/0.5% HF @ 0.5 bpm, followed by d) 75 bbls 2% NH4CI Water, followed by e) 20 bbls Foam Diverter Solution @ 0.5 bpm, w/2500 scfm Nitrogen, followed by Placed well on production w/gas lift & obtained a valid production welltest. Gas Cor~s. C0r~-~l~,issi0n Ar~chora[le, ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-31-92 REFERENCE: ARCO CASED HOLE FINALS 2-262.~ -/~ 5-19-92 ?/-/~// 4-40 4-10-92 ?/-/~'3 4-41 4-21-92 ?/-?~ 5-36 4-18-92 9-38 5-9-92 13-25~-~/4-20-92 ~- 3~ 16-27 5-17-92 Perforation Run 1, 5" I-ILS Perforation Run 1, 5" HI~ GR/ColI~r Run 1, 5" HI~ Perforation Run 1, 5" I-ILS Perforation Run 1~ 5" ~ Perforation Run 1, 5" ~ Perforation Run 1, 5" I-ILS Please sign and return t~.e attached copy as receipt of data. RECEIVED BY_~ Have A Nice Day!. . _ L~~~ Sonya Wnll_~ce AP P R OV ED_ ATO-1529 Trans# 92171 ~ # CENTRAL FILES # CHE~ON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED AUG 10 1992 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA .... ALASKA~-''''''' AND GAS CONSERVATION CE ~IISSIOh0 II I § I ~ REPORT uF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown Stimulate Plugging Perlorate X Pull tubing Alter camng Repair well Other .... 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1268' FNL, 307' FEL, Sec. 34, T11N, R15E, UM At top of productive interval 229' FNL, 2238' FEL, Sec. 34, T11 N, R15E, UM At effective depth At total depth 105' FNL, 2464' FEL, Sec. 27, T11N, R15E, UM 5. Type of Well Development X Exploratory ,, Stratigraphic Service 6. Datum of elevation(DF or KB) 60' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-40 9. Permit number/approval number 91-134 10. APl number 50 - 029-22224 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth' measured true vertical 9643 feet Plugs(measured) 9008 feet Effective depth: measured 9558 feet true vertical 8934 feet Junk(measured) feet Perforation depth: measured 9210-9220';9486-9510';9514-9532' true vertical 8623-8633';8871-8892';8895-8911' Tubing (size, grade, and measured depth) 4-1/2",12.6#, 13-Cr;3-1/2",9.3#',13-Cr-80;2-7/8",6.4#,13-Cr-80 w/tail @ 9392' MD Packers and SSSV (type and measured depth) Baker SB-3A pkr @ 8425 MD;Baker FB-1 pkr @ 9315' MD; AVA 4-1/2" SSSV_@ 2192' MD D i:::/"' I::: i 13. Stimulation or cement squeeze summary Intervals treated(measured) J U L. O0,~,,. Treatment description including volumes used and final pressure Alaska A.nch0rag¢, 14. Prior to well operation Subsequent to operation .Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 0 0 0 - 202 2057 20 - 680 Tubing Pressure 20OO 15. Attachments Copies of Logs and Surveys run , , _ Daily Report of Well Operations X 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. Signed ¢~~~'~¢' ~ Title FS-2 Regional Operations Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Casing Length Size Cemented Measured depth True vertical depth Conductor i 15' 20" 11 Yards AS 115' 115' Surface 3492' 10-3/4" 2522 cf ASII & 403 cf CI 'G' 3492' 3492' Production 9030' 7-5/8" 522 cf MTC & 309 cf CI 'G' 9030' 8461' Liner 906' 5-1/2" 253 cf CI 'G' 8737'-9643' 8195'-8949' ;.ILy REPORT OF WELL OPER. iONS DS 4-40 Perforating Operations' ARCO Alaska, Inc. perforated DS 4-40 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 4/10/92. The intervals perforated were the following: 9486-9510' and 9514-9532' MD (Reference Log: SWS-BHCS dated 12/5/91). Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 4/10/92. RU perforating unit, pressure tested BOP's to 3500 psi and lubricator to 3000 psi, okay. RIH and perforated 9514' - 9532' MD at 8 SPF, POOH, and confirmed all shots fired. RIH and perforated 9486' - 9510' MD at 4 SPF, POOH, and confirmed all shots fired. (ref: SWS-BHCS of 12/5/91) .Rigged down and secured well. RDC' 7/1/92 RECEIVED J U L. i 1 /~,taska Oil & Gas Cons. Comrnis¢O[~ Anchora[le ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-15-92 REFERENCE: ARCO CASED HOLE FINALS ~-- ~/ 2-9 3-25-92 Prod Profile o~ 2-18 4-28-92 Prod Profile ~a-/o? 2-26 J 3-25-92 Prod Profile ?/--(~8 2-31 ~ 4-28-92 Prod Pr0tile ~ ~? 3-11 ~ 4-4-92 InJ Profile ??~-?/ 3-13 f 4-4-92 Inj Profile ?/-~' 4-3 f 4-6-92 Prod Profile ?/~/3~ 4-40 ~ 4-7-92 GR/CCL/Jewe~ ?/~/ff$ 4-42 / 4-27-92 Static Temperature ~~? 6-18 -~ 3-31-92 PITS~ ?~// 7-3 ~ 4-7-92 Prod Profile ?~7~ 9-3 ~ 3-25-92 Prod Proffie 77-) ? 9-16 / 4-25-92 Inj Profile ~/-/d] 11-6 / 3-27-92 Prod Profile ?~-~'~ 14-1 / 3-26-92 Leak Detect ~/~/~>- 15-11 / 3-31-92 Prod Prof/Leak Detect R.n 1, 5" ~/~/ 16-6 / 4-12-92 Jewelry Run 1, 5" Rlln 1, 5" R11n 1, 5" R1111 1.5" Rim 1.5" R.n '1, 5" Rim 1, 5" Run 1, 5" R-n 1, 5" Rl~_n 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Ri_in 1, 5' R~ln 1, 5" Run 1, 5" R-n 1, 5" C~co Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco ,Camco Camco Camco Please sign and return the attached copy as receipt of data. RECEIVED BY__ff~~___~ __.~..~[C~IVED Have A Nice Day~ ~v~2~1 1~92 Sonya Wallace APPROVED Alas~l~as tons. Commission ATO-1529 Trans# 92099. ~''-A~omge # CENTRAL FILES # Ct~VRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHIL~ PB WELL ~ R&D # BPX # STATE OF ALASKA TEXACO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMI 0SI G WELL COMPLETION OR RECOMP LETION REPORT AND LOG," 1. Status o! Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 91-134 3. Address 8. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22224 4. Location of well at surface 9. Unit or Lease Name 1268' FNL, 307' FEL, Section 34, T11N, R15E, UM ...................... ~ ...... Prudhoe Bay Unit At Top Producing Interval ' : i~-.~.: ,i'k':::~¢;} 10. Well Number DS4-40 At Total Depth .~~ ....... ~ ... ~~ Prudhoe Bay Field/Prudhoe Bay Pool 105' FNL, 2464' FEL, SEC. 27, T11N, R15E, UM ............ _~ .~ ~:;~'~ . 5. Elevation in feet (indicate KB, DF, etc.) ~6. Le~e Designation and Serial No. RKB = 60' I ADL 2~25 12. Date Spudded 13. D~e T.D. Re~ 14. Date Comp., Su~. ~ Aband. J15. Water Depth, if offshore ~16. No. of Completions 11/22/91 12/5/91 12/11/91'~ N/A feet MSL ~ ONE 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)19. Directional Survey ~20. Depth where SSSV set 21. Thickness of Permafrost 96~'MD/9008'~D 9558'MD/8934'~D ~ ~ ~ ~~ 2192fee~ MD 1900' 22. Type Electric or Other Logs Run DITE/AIT/BHT/GR, LD T/CNUGR, MD ~ USlT/CBUGR, GC T GYRO 23. CASING, LINER AND CEMENTI~ ~O~ SE~G DEP~ MD CASING SIZE ~. PER ~. G~DE TOP ~OM ~LE SIZE C~~ R~ORD A~UNT ~LLED 20" 91.5~ H-40 Sudace 30" 11 Yards AS 10-3/4" 45.5~ J-55 Sudace 3492' 13-1/2" 2522 cf AS Ill & 403 cf CIG 7-5/8" 29. 7~ L-80 Su~ace 9030' 9-7/8" 522 cufl MTC & 309 cufl CI ~ 5-1/2" 17~ 13 Cr-80 8737' 96~' 6-3/4" 253 cufl cufl CIG 24. PeHorations open to Production (MD+TVD of T~ and Bottom and 25. ~GR~ORD interval, size and number) SIZE DEP~ SET(MD) PACKER SET 9210~9220'MD / 8623~8~' ~D 2 SPF 4-1/2'~3-1/2"x 9392' 9315' 2- 7/8" 26. ACID, F~C~RE, CEMENT ~UE~, ~C. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL ~ 27. PRODUCTDN TEST Date First Production lMethod of Operation (Flowing, gas lift, etc.) 3/26/92 ~ Gas Li~ Date of Test Hours Tested PROD~TI~ FOR OIL-BBL GAS-MCF WATER-BBL C~KESEE JGAS-OIL RATIO TEST P~D ~ Flow Tubing Casing Pressure ~ALCU~TED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fracture, apparent dips, and pr~ence of oil, gas or water. Submit ~re chips. None *NOTE: Drilled, Tubing Ran, a Perforated 12/11/91 Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS , ..~RMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9068' 8495' Base Sadlerochit 9510' 8892' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Area Drilling Engineer Date 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 25: If no cores taken, indicate "none". Form 10-407 ACTIVITY SUMMARY BP/AAI SHARED SERVICE , · PRUDHOE BAY NABORS 28-E NORTH SLOPE DS 4-40 AK SURF DRIL: 6.5 BOPE: 10.5 OTHR: 6.0 PROB: 1.0 PROB CODE: DS 11/23/91 ( 1) DRILLING MW: 8.8 VIS:300 TD: 700' ( 700) MOVE RIG FROM DS4-39 TO DS4-40. ACCEPT 1200 HRS. 11/22/91. SUPV:MCH DRILLING 13-1/2" HOLE TO 700'. HOLE ANGLE:26 12 DAILY:S105,496 CUM:$105,496 ETD:S105,496 EFC:$2,278,000 SURF DRIL: 20.0 TRIP: 2.5 CIRC: 1.0 OTHR: 0.5 11/24/91 ( 2) DRLG 13-1/2 HOLE & SURV MW: 9.2 VIS:300 TD: 2943' (2243) DRLG & SURVEYS FROM 700 - 2493'. CBU. DRILLING TO 2943'. SUPV:MCH HOLE ANGLE:26 12 DAILY:S68,937 CUM:$174,433 ETD:S174,433 EFC:$2,278,000 SURF DRIL: 4.5 TRIP: 5.0 CIRC: 2.0 CASG: 12.0 BOPE: 0.5 11/25/91 ( 3) N/U RISER & DIVERTER MW: 9.4 VIS:300 TD: 3500' ( 557) DRLING TO 3500' CBU. RUN 10-3/4 CASING. CIRC. TEST SUPV:MCH CEMENT LINES. RIG DOWN DIVERTER LINES. HOLE ANGLE:26 12 DAILY:St48,411 CUM:$322,844 ETD:S322,844 EFC:$2,278,000 ., P1 DRIL: 9.0 TRIP: 4.0 BOPE: 9.5 OTHR: 1.5 11/26/91 ( 4) DRLG &~'~LDG ANGLE MW: 8.8 VIS: 0 TD: 4250' ( 750) TEST BOPE. RIH TAG FLOAT COLLAR AT 3410'. TEST MWD WHILE SUPV:MCH RIH. CIRC & TES~ CSG TO 3000#. DRILL FLOAT COLLAR & CEMENT HOLE ANGLE:26 12 TO 3402'. TEST CSG TO 3000#. DRILL TO 3515'. CBU. PERFORM LEAK OFF TEST. DRILL & SURVEY TO 4250' DAILY:S80,738' CUM:$403,582 ETD:$4~3,582 EFC:$2,278,000 P1 DRIL: 16.5 TRIP: 4.0 SURV: 2.5 CIRC: 1.0 11/27/91 ( 5) DRILLING MW: 9.7 VIS: 44 TD: 5832' (1582) DRILLING FROM 4229 TO 4513' CBU. DRILL TO 5379' CBU. SUPV:LP RIH. DRILL TO 5832 HOLE ANGLE:26 12 DAILY:S85,386 CUM:$488,968 ETD:S488,968 EFC:$2,278,000 P1 DRIL: 22.5 TRIP: 1.0 CIRC: 0.5 11/28/91 ( 6) DRLG. MW: 9.8 VIS: 43 TD: 7498' (1666) DRLG F/ 5832'-6463' CBU. SHORT TRIP TO 5349' DRLG F/ SUPV:LP 6463'-7496' HOLE ANGLE:26 12 DAILY:S60,636 CUM:$549,604 ETD:S549,604 EFC:$2,278,000 P1 DRIL: 12.5 TRIP: 6.0 RIGS: 1.0 CIRC: 0.5 PROB: 4.0 PROB CODE: DS 11/29/91 ( 7) RIH. MW:10.1 VIS: 46 TD: 8575' (1077) CIRC. POOOH. RIH. WASH 30' TO BTM. DRLG F/ 7496'-8575' SUPV:LP LOST 500.PSI. POOH WET. FOUND WASHOUT IN JARS. CHANGE OUT HOLE ANGLE:26 12 JARS. ~ POOH. .'~DkILY:$94,691 CUM:$644,295 ETD:S644,295 EFC:$2,278,000 ACTIVITY SUMMARY BP/AAI SHARED SE,RVICE NORTH SLOPE · PRUDHOE BAY DS 4-40 NABORS 28-E AK P1 DRIL: 8.5 TRIP: 10.0 RIGS: 1.0 CIRC: 4.0 PROB: 0.5 PROB CODE: DS 11/30/91 ( 8) POOH. MW:10.2 VIS: 47 TD: 9038' ( 463) C/O MOTOR. RIH. DRLG F/ 8575'-9038'. CIRC. SHORT TRIP TO SUPV:LP HWDP. RIH. CIRC. POOH. L/D DP. HOLE ANGLE:26 12 DAILY:S116,420 CUM:$760,715 ETD:S760,715 EFC:$2,278,000 P1 TRIP: 5.0 CIRC: 1.5 CASG: 10.5 BOPE: 7.0 12/01/91 ( 9) TEST BOPE. MW: 8.3 VIS: 0 TD: 9038' ( 0) POOH. TEST BOPE. RIH W/ 7-5/8" CSG. CIRC. PUMP 50 BBLS SUPV:LP PREFLUSH, 93 BBLS MTC @ 12.0 PPG, 55 BBLS 'G' @ 15.8 PPG. HOLE ANGLE:26 12 DISP. BUMP PLUG W/ 2000 PSI. L/D LAND JT. RAN PACKOFF. INJECT 150 BBLS DN ANNULUS. N/U BOPE. TEST BOPE. DAILY:S238,203 CUM:$998,918 ETD:S998,918 EFC:$2,278,000 PROD DRIL: 12.0 TRIP: 9.0 EVAL: 1.0 CASG: 2.0 12/02/91 (10) DRLG. MW: 9.3 VIS: 40 TD: 9205' ( 167) RIH. TAG CMT @ 8899'. CIRC. TEST CSG. DRLG CMT, FC, CMT SUPV:LP TO 9015' CIRC. TEST CSG. DRLG CMT, FS, 10' NEW HOLE. HOLE ANGLE:26 12 CIRC. PERFORM FIT (12.5 PPR EMW). DRLG F/ 9045'-9067'~,5 . PACKOFF. RAISE. MUD WT TO 9.3 PPG DRLG F/ 9067"'- 920 . DA~Y:"$~,271 CUM:$1,043,189 ETD:S1,043,189 EFC:$2,278,000 PROD DRIL: 10.0 TRIP: 5.5 OTHR: 1.0 PROB: 7.5 PROB CODE: BIT 12/03/91 (11) DRLG. MW: 9.4 VIS: 41 TD: 9342' ( 137) DRLG F/ 9205'-9213' POOH. C/O BIT. RIH. REAM 3 JTS TO SUPV:LP BTM. UNABLE ~0 DRILL. POOH. C/O BIT, L/D MOTOR. RIH. HOLE ANGLE:26 12 REAM 2 JTS TO BTM. DRLG F/ 9213'-9342'. DAILY:S71,940 CUM:$1,115,129 ETD:SI,II5,129 EFC:$2,278,000 PROD DRIL: 23.0 CIRC: 1.0 12/04/91 (12) CBU. MW: 9.4 VIS: 45 TD: 9548' ( 206) DRLG F/ 9342'-9548' CBU. SUPV:BM HOLE ANGLE:26 12 DAILY:S84,658 CUM:$1,199,787 ETD:S1,199,787 EFC:$2,278,000 PROD DRIL: 12.5 TRIP: 9.0 SURV: 0.5 RIGS: 1.0 CIRC: 1.0 12/05/91 (13) POOH FOR OH LOGS. MW: 9.4 VIS: 44 TD: 9643' ( 95) POOH. RIH. DRLG F/ 9548'-9643'. TD WELL @ 01:30 HRS, SUPV:BM 12/5/91. CIRC. SHORT TRIP TO SHOE. CIRC. POOH. HOLE ANGLE:26 12 DAILY:S38,396 CUM:$1,238,183 ETD:S1,238,183 EFC:$2,278,000 PROD TRIP: 2.0 EVAL: 11.0 BOPE: 0.5 PROB: 10.5 PROB CODE: LT 12/06/91 (14) RIH W/ WIPER TRIP. MW: 9.4 VIS: 45 TD: 9643' ( 0) POOH. R/U SWS. LOG RUN #1: DITE/AIT/BHT/GR. LOG RUN #2: SUPV:BM LDT/CNL/GR. LOG RUN #3: MDT. STUCK TOOL. R/D SWS. TOF @ HOLE ANGLE:26 12 '9052'. RIH W/ FTA F/ TSA. LATCH FISH. PULL FREE. POOH. L/D FTA. RIH W/ WIPER TRIP. '~ DAILY:S45,460 CUM:$1,283,643 ETD:S1,283,643 EFC:$2,278,000 ACTIVITY SUMMARY BP/AAI SHARED SERVICE 'pRUDHOE BAY ' NABORS 28-E NORTH SLOPE DS 4-40 AK PROD TRIP: 5.0 12/07/91 ( 15) TD: 9643' ( 0) SUPV:BM HOLE ANGLE:26 12 PROD DRIL: 6.0 12/08/91 (16) TD: 9643' ( 0) SUPV:BM HOLE ANGLE:26 12 PROD TRIP: 8.5 12/09/91 (17) TD: 9643' ( 0) SUPV:BM HOLE ANGLE:26 12 CIRC: 9.0 CASG: 9.5 OTHR: 0.5 RIH W/6.75 BIT F/CLN OUT MW: 9.4 VIS: 43 RIH AFTER LOGS. CIRCL. POH FOR 5-1/2 LINER. R/U CASING CREW, RUN 5-1/2 LNR FINISH RIH W/5-1/2 LINER ON 3-1/2 DP TO 9643'. CIRC & COND CMT. CMT CLASS G 218 SX. SET PACKER W/3400 PSI. SHOE AT 9841'. RIH TO CLEAN OUT LINER TOP DAILY:S115,196 CUM:$1,398,839 ETD:S1,398,839 EFC:$2,278,000 TRIP: 14.5 CIRC: 3.0 EVAL: 0.5 CHING OVER TO COMP FLD MW: 8.6 VIS: 0 RIH TO 8196 & L/D DP AT 8196'. WASH TO 8299'. DRILL HARD CEMENT TO 8299 TO TOP OF LINER AT 8735'. CIRCL PUM PILL. POH L/D 6-3/4 BHA. P/U 4-3/4 CMT 3-1/2 DC & 2-7/8 DP. RIH CLEAN OUT LINER TO LC 9558' CIRCL. TEST CSG TO 3000. DAILY:S177,846 CUM: $1, 576~ 685 ETD:S1,576,685 EFC:$2,278,000 RIGS: 1.0 CIRC: 3.5 EVAL: 11.0 LOG W/ SWS. MW: 8.6 VIS: 0 DISP W/ SEAWATER. POOH. L/D BHA. R/U SWS. LOG RUN #1: USIT/CBL/GR. LOG RUN #2: GCT. DAILY:S52,449 CUM:$1,629,134 ETD:S1,629,134 EFc:$2,278,000 PROD TRIP: 12.0 EVAL: 11.0 OTHR: 1.0 12/10/91 (18) RIH W/4-1/2 TUBING MW: 8.6 VIS: 0 TD: 9643' ( 0) POH & L/D GCT TOOL N/Y'FLANGE & LUBRICATOR TEST TO 1000 . SUPV:BM PSI. RUN #3 PERFORATING . RUN #4 GUAGE RING & JUNK CATCHER HOLE ANGLE:26 12 TO 9350'. P/U' 2-7/8 TAIL PIPE ASSEMBLY & 5-1/2 PACKER. SET PACKER. TOP AT 9315' RIH W/4-1/2 TUBING. DAILY:S111,747 CUM:~1,740,881 ETD:S1,740,881 EFC:$2,278,000 RCMP: 24.0 12/11/91 (19) TD: 9643 PB: 0 SUPV:LP N/D BOPE MW: 0.0 RIH W/4-1/2 TUBING. TEST TO 5000 PSI. RIH W/4-1/2 TUBING. STAB INTO PCKR. TEST TO 5000 PSI. FREEZE PROTECT WELL. TEST CASING TO 3000 PSI. IDENTIFIED SURFACE LEAK & FIXED IT. SET BPV. N/D BOPE. DAILY:S477,229 CUM:$2,218,110 ETD:S2,218,110 EFC:$2,278,000 NDNU: 24.0 12/12/91~(20) TD: 9643 PB: 0 SUPV:LP RIG RELEASED MW: 0.0 N/D BOPE. N/U TREE. TEST CONTROL LINES & HANGER SEALS. PULL BPV. INSTALL TREE PLUG. TET TREE, PULL PLUG, SET BPV. SECURE WELL. RELEASE RIG 1000 HRS 12-11-91. DAILY:S74,284 CUM:$2,292,394 ETD:S2,278,000 EFC:$2,292,394 I II II I II ! I1 SUB - SURFA CE DIRECTIONAL r~ UIDANCE r~ ONTINUOUS r~ OOL Company Well Name Field/Location SURVEY ARCO ALASKA, I,N..C. i i ii m i i I i ii ii i i i ill D.S. ~4-,.401.1.2.69'FNL,3_O.7'FEL,SE.C 34,T11N,R15E) PRUDHOE BAY, NORTH SLOPE, ALASKA i · i i i m lmm I A~aska Oii& Gas Oons. i ii ii i i i Job Reference No. 92012 Locjcjed By: G. SARBER Date 08-DEC-1991 Computed By; R. KRUWELL I I IlI ! II II ! II I II I I I III I! II I I II II I I II II I II * SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. D.S. 4-40 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 08-DEC-1991 METHODS OF COMPUTATION TOOL LOCATION: INTERPOLATION: VERTICAL SECTION: ENGINEER: G. SARBER TANGENTIAL- Averaged Oeviation anO azimuth LINEAR HORIZ. DIST, PROJECTED ONTO A TARGET'AZIMUTH OF NORTH 59 DEG 16 MIN WEST COMPUTATION DATE: 12-JAN-92 PAGE 1 ARCO ALASKA INC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: OB-DEC-1991 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG .RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -60.00 0 0 N 0 0 E 100.00 100.00 40.00 0 9 N 60 54 E 200.00 200.00 140.00 0 6 N 65 36 E 300.00 300.00 240.00 0 8 5 27 45 E 400.00 400.00 340.00 0 8 S 68 6 E 500.00 500.00 440.00- 0 11 5 23 13 E 600.00 600.00 540.00 0 19 S 17 2 E 700.00 700.00 640.00 0 18 S 31 29 E 800.00 799.99 739.99 0 4 S 16 25 E 900.00 899.99 839.99 0 2 S 4 23 W 0 O0 0 O6 -0 03 -0 14 -0 4O -0 61 -0.94 -1.42 -1.68 -1.70 0.00 0.00 N 0.00 E 0.00 N 0 0 E 0.00 0.08 S 0.12 W 0.14 S 57 31 W 0.45 0.10 N 0.09 E 0.13 N 43 35 E 0.04 0.02 N 0.18 E 0.18 N 82 15 E 0.00 0.16 S 0.37 E 0.40 S 66 17 E 0.47 0.29 S 0.54 E 0.61 S 61 57 E 0.07 0.74 S 0.66 E 0.99 S 4! 39 E O. l Z~ 1.28 S 0.89 E 1.56 S 34 40 E 0.16 1 .54 S 1.04 E 1.86 S 34 0 E 0.11 1.60 S 1.02 E 1.90 S 32 36 E 1000.00 999.99 939.99 0 16 N 81 8 E 1100.00 1099.99 1039.99 0 27 N 52 5 E 1200.00 1199.99 1139.99 0 30 N 31 33 E 1300.00 1299.99 1239.99 0 27 N 9 26 E 1400.00 1399.98 1339.98 0 29 N 4 25 E 1500.00 1499,98 1439.98 0 32 N 3 29 E 1600.00 1599.97 1539.97 0 44 N 4 44 E 1700.00 1699.96 1639.96 1 9 N 1 44 E 1800.00 1799.91 1739.91 2 27 N 0 57 E 1900.00 1899.80 1839.80 2 48 N 11 5 E -1.90 -2.25 -2.41 -2 30 -1 95 -1 53 -1 01 -0 31 1 25 3.24 0.42 1.66 S 1.23 E 2.06 S 36 35 E 0.06 1.34 S 1.83 E 2.26 S 53 48 E 0.15 0.71 S 2.38 E 2.48 $ 73 28 E O. t6 0.05 N 2.70 E 2.70 N 88 56 E 0.29 0.82 N 2.75 E 2.87 N 73 23 E 0.00 1.73 N 2.81 E 3.30 N 58 24 E 0 . O0 2 . 89 N 2 . 89 E 4.08 N 45 1 E 0.59 4.44 N 3.00 E 5.36 N 34 0 E 0.97 7.45 N 2.98 E 8.02 N 21 47 E 0.64 12.19 N 3.48 E 12.68 N 15 56 E 2000.00 1999.69 1939.69 2 32 N 15 48 E 2100.00 2099.60 2039.60 2 11 N 17 40 E 2200.00 2199.55 2139.55 1 44 N 22 55 E 2300.00 2299.50 2239.50 1 45 N 24 11 E 2400.00 2399.46 2339.46 1 35 N 30 40 E 2500.00 2499.42 2439.42 1 20 N 34 55 E 2600.00 2599.40 2539.40 1 10 N 48 19 E 2700.00 2699.38 2639.38 1 13 N 50 16 E 2800.00 2799.36 2739.36 1 26 N 60 14 E 2900.00 2899.32 2839.32 1 52 N 64 18 E 461 5 55 6 19 6 58 6 74 6 65 621 551 4.59 3.12 1 14 0 15 0 46 0 12 041 0 21 0 O2 0.05 0.38 0.83 16.78 N 4.62 E 17.41 N 15 23 E 20.64 N 5.81 E 21.44 N 15 43 E 23.78 N 6.93 E 24.77 N 16 15 E 26.58 N 8.15 E 27.81 N 17 3 E 29.24 N 9.54 E 30.75 N 18 4 E 31.37 N 10.91 E 33.21 N 19 11 E 32.94 N 12.36 E 35.t8 N 20 34 E 34.22 N 13.93 E 36.95 N 22 9 E 35.48 N 15.75 E 38.82 N 23 56 E 36.82 N 18.26 E 41.10 N 26 23 E 3000.00 2999.26 2939.26 2 1 N 69 4 E 1.14 3100.00 3099.20 3039.20 1 58 N 78 51 E -1.25 3200.00 3199,14 3139.14 1 55 N 84 29 E -3.88 3300.00 3299.09 3239,09 1 47 5 88 13 E -6,63 3400.00 3399.04 3339.04 1 41 5 84 3 E -9,37 3500.00 3499.00 3439.00 1 37 5 78 33 E -12.03 3600.00 3598.96 3538.96 1 32 S 77 17 E -14.63 3700.00 3698.93 3638.93 1 31 5 76 50 E -17.10 3800.00 3798.90 3738.90 1 24 5 76 7 E -19.53 3900.00 3898.86 3838.86 1 23 S 75 2 E -21.89 0.49 0.20 0.12 0.06 0.54 0.02 0.61 0.78 0.00 0.22 38.24 N 21.41 E 43.82 N 29 t4 E 39.09 N 24.69 E 46.24 N 32 17 E 39.61 N 28.06 E 48.54 N 35 19 E 39.72 N 31.33 E 50.59 N 38 16 E 39.52 N 34.40 E 52.40 N 41 2 E 39.08 N 37.23 E 53.97 N 43 37 E 38.47 N 39.89 E 55.42 N 46 2 E 37.91 N 42.43 E 56.90 N 48 13 E 37.33 N 44.91 E 58.40 N 50 16 E 36.70 N 47.29 E 59.86 N 52 11 E COMPUTATION DATE: 12-JAN-92 PAGE 2 ARCO ALASKA [NC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-DEC-1991 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTE DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 4000 O0 3998.85 3938.85 0 31 N 21 7 E -23 33 4100 4200 430O 4400 4500 4600 4700 4800 4900 O0 4098.81 4038.81 2 37 N 57 3 W -20 O0 4198 63 4138.63 3 53 N 68 18 W -14 O0 4298 30 4238.30 5 8 N 78 44 W -7 O0 4397 62 4337.62 8 2 N 73 3 W 3 O0 4496 13 4436.13 11 46 N 71 3 W 20 O0 4593 65 4533.65 13 42 N 67 49 W 42 O0 4690 39 4630.39 15 41 N 64 39 W 67 O0 4785 98 4725.98 18 9 N 63 37 W 96 O0 4880 34 4820.34 20 23 N 62 31 W 129 4.17 70 2.59 87 1,93 11 1.12 93 2.85 65 3.02 38 2.39 52 2.79 76 1.56 75 1.03 36.45 N 48.81 E 60.92 N 53 15 E .38.34 N 46.87 E 60 55 N 50 43 E 40.87 N 41.60 E 58 42.91 N 33.78 E 54 45.80 N 22 65 E 51 51.14 N 6 39 E 51 58.88 N 14 30 W 60 69.19 N 37 42 W 78 82.07 N 63 77 W 103 97.06 N 93 24 W 134 32 N 45 30 E 62 N 38 13 E 10 N 26 19 E 54 N 7 7 E 59 N 13 39 W 66 N 28 24 W 93 N 37 51 W 60 N 43 51 W 5000.00 4973 95 4913.95 20 47 N 61 59 W 164.89 5100.00 5067 5200.00 5159 5300.00 5249 5400.00 5338 5500.00 5425 5600.00 5511 5700.00 5597 5800.00 5683 5900.00 5768 06 5007 06 22 5 N 61 44 W 201.31 18 5099 88 5189 27 5278 10 5365 31 5451 23 5537 01 5623 63 5708 18 23 45 N 62 50 W 240.17 88 26 30 N 63 56 W 282.14 27 28 58 N 64 6 W 328.73 10 30 18 N 63 10 W 378.17 31 30 36 N 62 12 W 428.77 23 30 53 N 61 48 W 479.87 01 31 3 N 61 30 W 531.22 63 31 1 N 60 38 W 582.86 0.58 1 .49 1 .59 4,44 1 .85 0.92 0.41 0.12 0.65 0.33 113.46 N 124.38 W 168 35 N 47 38 W 130.71 N 156.49 W 203 148.80 N 190.94 W 242 167.75 N 228.51 W 283 188.14 N 270.59 W 329 210.10 N 315.04 W 378 233.44 N 360.03 W 429 257.47 N 405.20 W 480 281.86 N 450.44 W 531 306.88 N 495.63 W 582 89 N 5O 8 W 07 N 52 4 W 47 N 53 43 W 57 N 55 11W 68 N 56 18 W 09 N 57 2 W 08 N 57 3~ W 36 N 57 58 W 95 N 58 14 W 6000.00 5854.35 5794.35 30 50 N 59 18 W 634.35 6100.00 5940.39 5880.39 30 36 N 58 53 W 685.31 6200.00 6026.28 5966.28 30 56 N 60 21 W 736.53 6300.00 6111.63 6051,63 31 57 N 61 34 W 788.61 6400.00 6196.31 6136.31 32 8 N 62 3 W 841.73 6500.00 6280.96 6220.96 32 t8 N 61 38 W 894.92 6600.00 6365.37 6305.37 32 32 N 62 4 W 948.48 6700.00 6449.55 6389,55 32 49 N 62 35 W 1002.40 6800.00 6533.85 6473.85 31 54 N 63 23 W 1056.07 6900.00 6619.20 6559,20 31 13 N 64 6 W 1108.00 1 .56 1 .01 0.45 1 .73 0.47 0.47 0.25 0.33 2.62 0.31 332.52 N 540.30 W 634.43 N 58 23 W 358.91 N 583.89 W 685.38 N 58 25 W 384.71 N 628.14 W 736.59 N 58 31 W 410.19 N 673.59 W 788 65 N 58 40 W 435.08 N 720.59 W 841 75 N 58 53 W 460.26 N 767.50 W 894 93 N 59 3 W 485.58 N 814.76 W 948 48 N 59 12 W 510.67 N 862.56 W 1002 40 N 59 22 W 535.21 N 910.42 W 1056 08 N 59 33 W 558.13 N 957.21 W 1108 04 N 59 45 W 7000.00 6704.64 6644.64 31 25 N 64 9 W 1159.78 7100.00 6789.89 6729.89 31 35 N 64 4 W 1211.88 7200.00 6875.04 6815.04 31 44 N 63 29 W 1264.14 7300.00 6960.15 6900.15 31 34 N 63 26 W 1316.51 7400.00 7045.52 6985.52 31 9 N 63 3 W 1368.45 7500.00 7131.38 7071.38 30 32 N 63 2 W 1419.62 7600.00 7217.56 7157.56 30 28 N 63 38 W 1470.21 7700.00 7303.78 7243.78 30 20 N 64 4 W 1520.71 7800.00 7390.21 7330.21 30 16 N 64 4 W 1570.82 7900.00 7475.99 7415.99 31 26 N 61 18 W 1622.13 0.16 0.32 0.31 0.41 0.53 0.65 0.31 0.58 1 .58 0.54 580.83 N 1003.95 W 1159.86 N 59 57 W 603.65 N 1050.99 W 1212.02 N 60 8 W 626.85 N 1098.00 W 1264.34 N 60 17 W 650.30 N 1144.99 W 1316.77 N 60 24 W 673.75 N 1191.47 W 1368 78 N 60 31 W 697.06 N 1237,14 W 1420 O0 N 60 36 W 719.81 N 1282.47 W 1470 67 N 60 42 W 742.14 N 1327.94 W 1521 25 N 60 48 W 764.00 N 1373.24 W 1571 46 N 60 55 W 787.77 N 1418.81 W 1622 84 N 60 58 W COMPUTATION DATE: 12-JAN-92 PAGE 3 ARCO ALASKA INC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-DEC-1991 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: G. SARBER [NTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTN DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 8000 O0 7561.37 7501.37 31 15 8100 8200 8300 8400 8500 8600 8700 8800 8900.00 8343.87 8283 O0 7646 95 7586.95 31 6 O0 7732 67 7672.67 30 53 O0 7818 58 7758.58 30 44 O0 7904 66 7844 66 30 23 O0 7991 31 7931 31 29 33 O0 8078 55 8018 55 28 55 O0 8166.27 8106 27 28 18 O0 8254.64 8194 64 27 21 87 26 35 N 61 59 W 1674 13 N 62 48 W 1725 79 N 63 21 W 1777 18 N 64 1W 1828 21 N 64 26 W 1878 90 N 65 4 W 1928 60 N 64 56 W 1977 24 N 65 6 W 2025 01 N 64 48 W 2071.58 N 64 36 W 2116.53 0.43 0.50 0.42 0.21 0.76 0.37 0.56 0.69 2.00 0.26 812.54 N 1464.58 W 1674 88 N 60 59 W 836.51 N 1510.42 W 1726 859.83 N 1556.35 W 1778 882.53 N 1602.23 W 1829 904.66 N 1648.04 W 1880 925.92 N 1693.22 W 1929 946~62 N 1737.49 W 1978 966.90 N 1781.02 W 2026 986.69 N 1823.43 W 2073 1006.11 N 1864.18 W 2118 59 N 61 1W 07 N 61 5 W 20 N 61 9 W 01 N 61 14 W 85 N 61 20 W 63 N 61 25 W 55 N 61 3O W 27 N 61 35 W 35 N 61 39 W 9000.00 8433.47 8373.47 26 7 9100.00 8523,42 8463.42 25 13 9200.00 8614.43 8554.43 24 21 9300.00 8705.00 8645.00 25 59 9400.00 8794.46 8734.46 26 59 9500.00 8882.99 8822.99 28 38 9600.00 8970.61 8910.61 28 50 9643.00 9008.28 8948.28 28 50 N 64 19 W 2160.75 N 61 59 W 2204,33 N 61 46 W 2245.73 N 61 25 W 2288.08 N 60 50 W 2332,73 N 60 44 W 2379.21 N 60 47 W 2427.37 N 60 47 W 2448.10 1 .01 3.19 1.14 1.13 0,95 1 .21 0.00 0.00 1025.20 N 1904.27 W 2162.71 N 61 42 W 1044.94 N 1943 23 W 2206.37 N 61 44 W 1064.44 N 1979 81 W 2247.82 N 61 44 W 1084.64 N 2017 06 W 2290.20 N 61 44 W 1106.24 N 2056 17 W 2334.87 N 61 43 W 1128.99 N 2096 72 W 2381.35 N 61 42 W 1152.52 N 2138 76 W 2429.53 N 61 41 W 1162.65 N 2156 86 W 2450.27 N 61 40 W COMPUTATION DATE: 12-JAN-92 PAGE 4 ARCO ALASKA INC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-DEC-1991 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUT~ SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEE~ FEET FEET DEG MIN 0.00 1000.00 999 2000.00 1999 3000.00 2999 4000.00 3998 5000.00 4973 6000.00 5854 7000.00 6704 8000.00 7561 9000.00 8433 0 O0 -60.00 0 0 N 0 0 E 0.00 99 939.99 0 16 N 81 8 E -1.90 69 1939,69 2 32 N 15 48 E 4.61 26 2939,26 2 1 N 69 4 E 1.14 85 3938,85 0 31 N 21 7 E -23.33 95 4913.95 20 47 N 6~1 59 W 164.89 35 5794.35 30 50 N 59 18 W 634.35 64 6644,6~ 31 25 N 64 9 W 1159.78 37 7501.37 31 15 N 61 59 W 1674.13 47 8373.47 26 7 N 64 19 W 2160.75 0.00 0.42 1.14 0,49 4.17 0,58 1.56 0.16 0.43 1.01 1025 0 O0 N 1 16 38 36 113 332 58O 812 0 O0 E 66 S 1 78 N 4 24 N 21 45 N 48 46 N 124 52 N 540 83 N 1003 54 N 1464 20 N 1904 0.00 N 0 0 E 23 E 2.06 S 36 35 E 62 E 17.41 N 15 23 E 41 E 43,82 N 29 14 E 81 E 60.g2 N 53 15 E 38'W 16B.35 N 47 3B W 30 W 634.43 N 58 23 W 95 W 1159.86 N 59 57 W 58 W 1674.88 N 60 59 W 27 W 2162.71 N 61 42 W 9643.00 9008.28 8948.28 28 50 N 60 47 W 2448.10 0.00 1162.65 N 2156.86 W 2450.27 N 61 40 W COMPUTATION DATE: 12-JAN-92 PAGE 5 ARCO ALASKA INC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-DEC-1991 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 -60.00 0 0 60.00 60.00 0.00 0 6 160.00 160.00 100.00 0 10 260.00 260.00 200.00 0 4 360.00 360.00 300.00 0 10 460.00 460.00 400.00 0 7 560.00 560.00 500.00 0 17 660.00 660.00 600.00 0 22 760.01 760.00 700.00 0 8 860.01 860.00 800.00 0 2 N 0 0 E S 87 51 E N 46 47 E S 39 12 E S 46 49 E 553 18 E S 12 8 E S 22 16 E 530 5 E 54941 w 0.00 0.13 0.00 -0.08 -0.29 -0.53 -0.7S -1 .22 -1 .62 -1 .70 0 O0 0 84 0 O0 0 24 0 O0 0 08 0.00 0.25 0.10 0.00 0 O0 N 0 0 0 0 0 0 1 1 1 0.00 E 11 S 0.21 W 03 N 0.02 E 09 N 0.14 E 11 S ~ 0.28 E 22 S 0,49 E 54 S 0.61 E 07 S 0.78 E 47 S 1.O1 E 58 S 1.03 E 0.00 N 0 0 E O. 24 S 62 19 W 0.04 N 30 45 E 0 17 N 58 35 E 0 30 5 69 17 E 0 53 S 66 3 E 0 81 S 48 30 E 1 32 S 36 10 E 1 79 S 34 24 E 1 89 S 33 15 E 960.01 960.00 900.00 0 9 1060,01 1060.00 1000.00 0 26 1160.01 1160.00 1100.00 0 29 1260.01 1260.00 1200.00 0 29 1360.02 1360.00 1300.00 0 26 1460.02 1460.00 1400.00 0 32 1560.02 1560.00 1500.00 0 42 1660.03 1660,00 1600.00 0 56 1760.06 1760.00 1700.00 1 51 1860.15 1860.00 1800.00 2 50 574 4 E N 58 35 E N 38 33 E N 22 8 E N 1 41 E N 4 16 E N 3 36 E N 4 22 E N 1 25 W N 7 2 E -1.78 -2.12 -2.38 -2.38 -2.09 -1.70 -1.23 -0.64 0.47 2.51 0.25 1.65 5 1.09 E 0.21 1.51 S 1.57 E 0.12 0.99 S 2.18 E 0.15 0.26 S 2.61 E 0.00 0.51 N 2.73 E 0.00 1.36 N 2.79 E 0.09 2.39 N 2.85 E 0.47 3.73 N 2.96 E 2.06 5.92 N 2.98 E 0.33 10.26 N 3. 18 E 1 98 S 33 22 E 2 18 546 5 E 2 39 5 65 36 E 2 63 $ 84 26 E 2 78 N 79 26 E 3 10 N 64 0 E 3 72 N 50 2 E 4.76 N 38 25 E 6.63 N 26 42 E 10.74 N 17 13 E 1960.27 1960 O0 1900.00 2060.37 2060 O0 2000.00 2160.43 2160 O0 2100.00 2260.48 2260 O0 2200.00 2360.53 2360 O0 2300.00 2460.56 2460 O0 2400.00 2560.59 2560 O0 2500.00 2660.61 2660 O0 2600.00 2760.63 2760.00 2700.00 2860.67 2860.00 2800.00 2 42 217 1 49 1 45 1 44 I 25 1 12 1 8 1 17 1 39 N 14 17 E N 17 29 E N 19 55 E N 23 56 E N 28 49 E N 33 10 E N 44 41 E N 52 15 E N 56 42 E N 61 17 E 4.11 5.20 5.99 6.4,4 6.72 6.71 6.42 5.80 5.03 3.75 0.36 0,24 0.04 0.28 0.20 0.34 0.72 0.15 O. 68 0.28 15 02 N 19 17 N 22 63 N 25 49 N 28 24 N 30 59 N 32 39 N 33.72 N 35.00 N 36,27 N 4.14 E 5.34 E 6.49 E 7.66 E 8.97 E 10.38 E 11.79 E 13.30 E 14.95 E 17.20 E 15.58 N 15 26 E 19.90 N 15 35 E 23.54 N 15 59 E 26.61 N 16 44 E 29.63 N 17 38 E 32.30 N 18 45 E 34.47 N 20 0 E 36.25 N 21 32 E 38.06 N 23 8 E 40.15 N 25 22 E 2960.72 2960.00 2900.00 2 0 3060.78 3060.00 3000.00 1 55 3160.84 3160.00 3100.00 1 57 3260.89 3260.00 3200.00 1 52 3360.94 3360.00 3300.00 1 46 3460.99 3460.00 3400.00 1 38 3561.03 3560.00 3500.00 1 34 3661.06 3660.00 3600.00 1 26 3761.09 3760.00 3700.00 1 24 3861.12 3860.00 3800.00 1 25 N 65 40 E N 77 18 E N 82 6 E N 89 4 E 5 86 1E S 81 1E S 76 32 E S 76 45 E S 75 59 E S 74 30 E 1.96 -0.27 -2.83 -5.55 -8.31 -11.00 -13.64 -16.16 -18.62 -20.97 0.23 0.22 0.33 O,39 0.06 0.05 0.32 0.43 0.24 0.25 37.70 N 38.82 N 39.46 N 39.73 N 39.62 N 39.27 N 38.71 N 38.15 N 37.56 N 36.95 N 20.13 E 23.40 E 26.75 E 30.08 E 33.22 E 36.14 E 38.88 E 41.48 E 43.98 E 46.36 E 42.74 N 28 6 E 45.33 N 31 5 E 47.68 N 34 8 E 49.84 N 37 8 E 51.70 N 39 59 E 53.37 N 42 37 E 54.86 N 45 8 E 56.35 N 47 24 E 57.84 N 49 30 E 59.29 N 51 27 E COMPUTATION DATE: 12-JAN-92 PAGE 6 ARCO ALASKA INC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 08-DEC-1991 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: G. SARBER [NTERPOLATED VALUES FOR EVEN lO0 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG 'RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 3961.15 3960.00 3900.00 0 46 S 78 25 E -23.08 4061.17 4060.00 4000.00 1 48 N 48 3 W -22 16 4161.29 4160.00 4100.00 3 30 N 66 5 W -17 4261.55 4260.00 4200 O0 4 54 N 77 42 W -10 4362,05 4360.00 4300 O0 7 6 N 74 36 W -0 4463.18 4460.00 4400 O0 10 20 N 71 39 W 13 4565.41 4560.00 4500 O0 13 0 N 69 9 W 34 4668,49 4660.00 4600 O0 14 59 N 65 20 W 59 4772.70 4760.00 4700 O0 17 41 N 63 43 W 88 4878.34 4860.00 4800 O0 20 1 N 62 41 W 122 32 28 9O 73 50 23 40 32 1 51 1 66 0 64 1 37 281 413 2.00 1 ,81 1 .62 1 ,98 36.39 N 48 49 E 60,63 N 53 7 E 37.46 N 48 06 E 60.93 N 52 4 E 39.91 N 43 88 E 59.31 N 47 42 E 42.25 N 37 07 E 56.21 N 41 16 E 44.40 N 27 45 E 52.20 N 31 43, E 48.88 N 13 09 E 50.61 N 15 0 E 55.94 N 6 87 W 56,36 N 7 0 W 65.67 N 29 86 W 72.14 N 24 27 W 78.35 N 56.26 W 96.45 N 35 41 W 93.64 N 86.63 W 127.57 N 42 46 W 4985.09 4960.00 4900.00 20 42 N 62 3 W 159.62 5092.38 5060.00 5000.00 21 58 N 61 41 W 198.45 5200.90 5160.00 5100.00 23 46 N 62 50 W 240.53 5311.36 5260.00 5200.00 26 52 N 64 2 W 287.29 5424.90 5360.00 5300.00 29 24 N 63 59 W 340.85 5540.44 5460.00 5400.00 30 25 N 62 37 W 398.57 5656.63 5560.00 5500.00 30 49 N 61 57 W 457.65 5773.16 5660.00 5600.00 30 57 N 61 38 W 517.41 5889.92 5760.00 5700.00 31 2 N 60 42 W 577.66 6006.58 5860.00 5800.00 30 48 N 59 10 W 637.73 0 44 1 37 1 60 3 62 1 66 0 72 0 48 0 36 O. 48 1.58 110.98 N 119.72 W 163.24 N 47 10 W 129.35 N 153.97 W 201.09 N 49 58 W 148.97 N 191.26 W 242.43 N 52 5 W 170.00 N 233.15 W 288.55 N 53 54 W 193.47 N 281.51 W 341.59 N 55 30 W 219.42 N 333.24 W 398.99 N 56 38 W 246.98 N 385.58 W 457.90 N 57 22 W 275.28 N 438.28 W 517.56 N 57 52 W 304.34 N 491.10 W 577.76 N 58 13 W 334.24 N 543.21 W 637.80 N 58 24 W 6122.79 5960.00 5900.00 30 43 N 59 17 W 696.93 6239.37 6060.00 6000.00 31 14 N 60 25 W 756,84 6357.10 6160.00 6100.00 32 13 N 62 22 W 818.92 6475.22 6260.00 6200.00 32 12 N 61 39 W 881.71 6593.62 6360.00 6300.00 32 31 N 62 2 W 945.05 6712.44 6460.00 6400.00 32 47 N 62 38 W 1009.12 6830.71 6560,00 6500.00 31 27 N 63 51 W 1072.14 6947,72 6660.00 6600.00 31 17 N 64 5 W 1132.67 7064.92 6760.00 6700,00 31 35 N 64 8 W 1193.57 7182.32 6860.00 6800.00 31 41 N 63 30 W 1254.87 1 .37 1 .42 0.40 0.42 0.21 0.32 0.91 0.15 0.24 0.46 364.87 N 593.87 W 697 O0 N 58 26 W 394.75 N 645.81 W 756 90 N 58 34 W 424.43 N 700.39 W 818 95 N 58 47 W 453.98 N 755.86 W 881 72 N 59 1 W 483 97 N 811.73 W 945 06 N 59 12 W 513 77 N 868.54 W 1009 12 N 59 24 W 542 36 N 924.86 W 1072 16 N 59 37 W 568 95 N 979.48 W 1132.73 N 59 51 W 595 62 N 1034.47 W 1193.69 N 60 4 W 622,70 N 1089.69 W 1255.06 N 60 15 W 7299.83 6960.00 6900.00 31 34 N 63 26 W 1316.42 7416.91 7060.00 7000.00 31 4 N 63 0 W 1377.17 7533.22 7160 O0 7100.00 30 29 N 63 17 W 1436.44 7649 24 7260 O0 7200.00 30 27 N 63 52 W 1495.10 7765 05 7360 O0 7300.00 30 7 N 64 24 W 1553.31 7881 27 7460 O0 7400.00 31 22 N 61 27 W 1612.38 7998 39 7560 O0 7500.00 31 15 N 61 58 W 1673.30 8115 23 7660 O0 7600.00 31 5 N 62 54 W 1733.64 8231 83 7760 O0 7700.00 30 49 N 63 33 W 1793.46 8348 16 7860 O0 7800.00 30 36 N 64 13 W 1852.69 0.40 0.55 0.36 0 42 0 26 1 12 0 43 0 47 0 39 0 46 650.26 N 1144.91 W 1316.68 N 60 24 W 677.72 N 1199.26 W 1377.51 N 60 32 W 704.68 N 1252.18 W 1436.85 N 60 38 W 730.86 N 1304.86 W 1495.60 N 60 45 W 756.37 N 1357.42 W 1553.92 N 60 52 W 783.09 N 1410.25 W 1613.08 N 60 57 W 812.15 N 1463.85 W 1674.05 N 60 59 W 840.11 N 1517.42 W 1734.46 N 61 2 W 867.12 N 1570.95 W 1794.38 N 61 6 W 893,25 N 1624.33 W 1853.73 N 61 12 W COMPUTATION DATE: 12-JAN-92 PAGE 7 ARCO ALASKA INC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY= 08-DEC-1991 KELLY BUSHING ELEVATION: 60.00 FT ENGINEER: G. SARBER INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8463.97 7960.00 7900 O0 29 49 8578.79 8060.00 8000 8692.88 8160.00 8100 8806.03 8260.00 8200 8918.03 8360.00 8300 9029.54 8460.00 8400 9140.28 8560.00 8500 9250.14 8660.00 8600 9361.39 8760.00 8700 9473.86 8860.00 8800 O0 29 3 O0 28 21 O0 27 15 O0 26 30 O0 26 2 O0 24 25 O0 25 1 O0 26 39 O0 28 9 N 64 58 W 1910.85 N 64 55 W 1967.00 N 65 5 W 2021.65 N 64 42 W 2074.32 N 64 36 W 2124.55 N 63 39 W 2173.69 N 61 58 W 2221.17 N 61 30 W 2266.62 N 60 59 W 2315.32 N 60 41 W 2366.77 1.16 0.79 942.26 N 1728 0.88 965.47 N 1777 1.83 987.87 N 1825 0.43 1009.56 N 1871 1.51 1030.90 N 1915 1,00 1052.87 N 1958 1.84 t074.39 N 1998 0.81 1097.76 N 2040 2.47 1122.90 N 2085 918.38 N 1677,05 W 1912.05 N 61 18 W 18 W 1968,36 N 61 24 W 95 W 2023,18 N 61 30 W 92 W 2076.02 N 61 35 W 45 W 2126,40 N 61 39 W 94 W 2175,68 N 61 43 W 11 W 2223,23 N 61 44 W 20 W 2268.72 N 61 44 W 96 W 2317.45 N 61 44 W 87 W 2368.92 N 61 42 W 9587.89 8960.00 8900.00 28 50 N 60 47 W 2421.53 0.00 1149.67 N 2133.67 W 2423.69 N 61 41 W 9643,00 9008.28 8948.28 28 50 N 60 47 W 2448.10 0.00 1162.65 N 2156.86 W 2450.27 N 61 40 W ARCO ALASKA INC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER LAST READING GCT TD COMPUTATION DATE: 12-JAN-92 INTERPOLATED VALUES FOR CHOSEN HORIZONS DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: PAGE 8 08-DEC-1991 60.00 FT G. 5ARBER SURFACE LOCATION = 1269' FNL, 307' FEL, SEC34 T11N R15E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 9521.59 8901.92 j 8841.92 1134.06 N 2105.77 W 9643.00 9008.28 8948.28 1162.65 N 2156.86 W COMPUTATION DATE: 12-JAN-92 PAGE 9 ARCO ALASKA INC. D.S. 4 - 40 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: KELLY BUSHING ELEVATION: ENGINEER: 08-DEC-1991 60.00 FT G. SARBER ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 1269' FNL, 307' FEL, SEC34 TllN R15E MARKER MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST LAST READING GCT TD 9521.59 8901.92 8841.92 1134.06 N 2105.77 W 9643.00 9008.28 8948.28 1162.65 N 2156.86 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 9643.00 9008.28 8948.28 2450.27 N 61 40 W DIRECTIONAL SURVEY COMPANY FIELD COUNTRY RUN ARCO ALASKA INC. 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T!"iTi'"i'"?'?"i"'?'"!-'i'"~"i" '"!"'i'"!"'i ...... ii'~""i'"i71 ...... ?i"'i'-~ ...... !-'-?-?;'i ...... i'"?'! ..... !-"i--i--'i ...... i"i"'i'"i ...... : ....... ~'"i ...... :'": ....... ' ...... t-'i"'~"i ...... !'"i" 7i ......... AOGCC GEOLOGICAL MATEHIAL~.; INVENTORY LIST FOR DEVELOPMENTAL ~,~ELLS P.F_F!M~Ta 9/ - /39x WEI.LNAME, COMPLETION DATE ~.[,~,,,_! // ! ~'/ CO, CONTACT j LOG I'YPE I ,~,,,, NO. I....... ~'CALE "! I 1 21 ~9 I'! ,il L..Etk\c Il 5l Ilti! i ARCO AI..A;~]I<A, INC,. F:' ,. O, B 0 ;.',:: i (') (.'":,.2; 6 0 ANL:HORAC-E, AI_A,':]I< A D A T Iii: ' i 2 .... .3 i '" 9 i F;tliiiFrE:I:;..'E".NCE · F;'.ECE:I VIED BY HAVIE A NICE Al";,'(](;) CASED ...biOt..F F-" I NAI...S SON YA WAI...I...ACE: A'f'O .... i ~: · ..;.2'"..;' 2....8-.9i ''/' "'r ..... ' .... . , t., J ~'~ F I.. [:. f I 0 N F;..' E C 0 I:;.: D < C 0 I... 0 F;.: ) 1:;.: U iq · '2 - Iii-'-' 9 i v'/ C: B T ( C 0 L 0 R ) I.';..' U N 2-8-9 i ,-/' US l T ( C [)1...01:;.'. ) RUi:4. 2 .... 7-9t ''/' F'DK .... i ¢(-':,/6R/CC:L. RtJN 2 .... i ?, .... 9 i '/' C': 0 L.. L.. A i.,.'-... I..' i::. i::: i-- F;.: U N 2..-i ¢.-9t "" '"r' "", ", ....... t., ..J L I... R t-,, '- I- 1::. I-,.: I- F;,' t.J N 2 .... -J t .... 9i i [-;.R Rt.J 2 .... ! 4-9i '/ COL. L_AF;:-F:'ERF RUN j..,. -. .¢, '1 "~ "'1" 2 .... i 4--9 i ,/ .,UL.I...~.-~F..--I" E:.RF RUN N A N D IR E T U R N 'T I--t E A'T'f' A C I"t E D C 0 F' Y A S R Ii:.: C E' .[ F:' "t' U F D A 'f' A, DAY! D ]:,., r !:;.: I BUT ]: [:IN · ,,.'"' C I.Z N T F;..' A t.. F :t_' i._ E $ :.": F' I--I I L.. L :1: F:' ,., 4J: C H Ii!: V R 0 N F:' B W E I.. L. F' ]: L.. lii:.S' D & I'i R & D · ,.'" EXTENSION E:Xt::'t...OR¢.~T I ON .,,.'"' BI::'X · "' EXXON :~ " '"" ... ;'.; TATE OF-' AI...A,.,, K A i"i A R A 1' t"10 N T E X A C 0 · "' MOBIL olt· RECEIVED ,JAN 1 0 1992 Alaska Oil & Gas 6ons. Commission Anchorage ARCO ALASKA, INC P~ O~ BOX i ANCHORA6E, ALA;~'K A 99 DATE' t 2-28-9t Rlii;F'EiRE;NC;;E: ARCO MAGNETIC 'TAF'E:.:(,S') WITH ~1"17'Y'I-4~ i,::.-..-7~'"' S ~ BC",-,'/DTE/2DN/CNTH-GR,NPHI RUN i ,.JOB:~75295 F:' L E A ;~:E ,'."~' I C.- N A N D F,' E l" U R N 'i' H E A'i- 'i" A CFt E D C 0 P Y A 3;' R E C EL I P T 0 F:' I) A T'A ~ RFCE:rVED BY ........... FIAVE A NICE DAY! 20NYA WAL. LACE A'T'O- ~ 529 ;i,;' C I"1 D I ~' T R I B U T I 0 N CENTRAL FILES (CH) CHEVRON D & M TAMMA2 BF,'OWN (OH/GCI-) EXXON MARATHON MOBIl_ F'FIlLL IF'$ F:'B WEL. L F'ILE2 R & D ~ BF'X ,'~TATE OF ALA~'KA l'E X A C: 0 RECEIVED JAN i 0 ~.jJL Alaska Oil & Gas Co~m. Commission Anchorage DATE: ~ 2--'J 3-.9~ I-';,'FFli:".F(EiNCE: At::,'CO OPEN HOLE FINAI..~' i 2--5--'~? t SSTVI) CC)EOF: i 2 ---'5 --9 t i 2'-"5-F i I) ]] -",S' f:' L.-' C; F( C, C. I... 0 f,, i "'~---'.S- ' ,:_ y 1 I._ L) iq ( i-( ;'.~ W ) t., U I.. U I'( i 2 "" ~.,. "" c,,, i L. ~') t-4 ,', f:' 0 t';..' 0 ,", r":.. 0 I... C)I:;,' 'l 2-'"5'"'9t RUN t, t . &2. F,'UN t, RUN i, ,,."~" &..5, ' i-,,' u ~,~ i, ,.."" ~, b" F;..'UN i, 2"&5" RUN i , 5' F'i...EA,S'E:".D3'~I[i~N A~LJRN~ THF ATTACHED COF:'Y A..? RE:'.CEiIF'T ElF: DATA. R E C E l V E ,..,,.,?r.-:: ,., R E C E IV E D DEC 1 G 1991 Alaska Oil & Gas Cons. Commission Anchorage I) I S'i" f;~ I BUT I ON ;.:,," 0 N Y A WAI..I...ACE A T [] .... i 5 2 ? CENTRAL FILES C H E V H.' U D & H EXTEiNS'I C)N EXF:'L. OF~'.AT I ON EXXON H A F;,' A'i' I-.IO N H['iBII_ F' H I !.. L.. I F:' F:' B W E L.L. F I L. E. 5; R & D :~- .?'[Ai"E []F AI..A,"~KA ~: i' E. XACO ALASKA OIL AND GAS CONSERVATION COMMISSION November 13, 1991 WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Michael Zanghi Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit DS 4-40 ARCO Alaska, Inc. Permit No. 91-134 Sur. Loc. 1269'FNL, 307'FEL, Sec. 34, TllN, R15E Btmhole Loc. 10'FSL, 2458'FEL, Sec. 27, TllN, R15E Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencieS, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE test that it wishes to witness. ° David W._~nsgon, Chairman . Alaska Oil a ~.Gas Conservation Commission BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental COnservation w/o encl. I~ prinled on recycled paper b y G,D. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ~v Re-Entry [] DeepenI-II Service [] Development Gas [] SingleZone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. KBE = 60'feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool p, O. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28325 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 1269' FNL, 307' FEL, SEC. 34, T11N, R15E Prudhoe Bay Unit At top of productive interval 8. Well number Number 29' FNL, 2392' FEL, SEC. ~4, T11N, R15E DS 4-40 U-6300610 At total depth 9. Approximate spud date Amount IO' FSL, 2458' FEL, SEC. 27, T11N, R15E November 13, 1991 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVO) prope~L line 28324 @ 2458' feet DS 4-02 @ 2100' feet 2560 9665'MD/9016'TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 9oos{eet Maximum hole angle 3o. 8 o Maximum surface 2770Pslg At total depth (TVD) ,,~'~0psig 18. Casing program Specifications Setting Depth size Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5tt H-40 WELD 80' Surface 115' 115' 2000P POLESET 13-1/2" 10-3/4" 45.5P J-55 BTC 3965' Surface 4000' 4000' 1120 sx AS/II & 350 sx 'G" 9-7/8" 7-5/8" 29. 7# L-80 BTC 4467' Surface 4502' 4500' 9-7/8" 7-5/8" 29.7# L-80 BTC/MO£ 4532' 4502' 4500' 9034' 8747' 270 sx 'G" 6-3/4" 5-1/2" 17# CR15 FL4S 931' 8734' 8215' 9665' 9016' 100 sx "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 Oonductor RECEIVED Surface Intermediate Production NOV - ? ~9~ Liner Alaska 0il & Gas Cons. C0mmissior~ Perforation depth: measured true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid pro, ram [] Time vs depth plot [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby ce~tifj t,ba't)the,Joregoing is true and correct to the best of my knowledge Si~lned~/I..~( Title Area Drilling Engineer Date/("- Commission Use Only Permit_Number IAPI number IApproval d~e ISee cover letter ..~_ ~ ] - _ ~7/ I ,/// /~_~ ,-,~/ _~,or other requirements Condritions of approval Samples required [] Yes /,~.NO Mud log required []Y~s/~ No Hydrogen sulfide measures [] Yes ~_ No Directional survey requ~recl /~Yes Required~~efor,,,.~:~~2M; 1-13M; 1~5M; []10M; F'II~M; Other: (_ _ ~'~. ~ _ -'~ Commissioner ~nebY order of commission Date i//~.1~,. Approved~ Form 10-401 Rev. 12-1-8~..~ Submit in 1.) 2.) 3.) 4.) 5.) 6.) 7.) 8.) 9.) 10.) 11o) 12.) 13.) 14.) 15.) 16.) 17.) DS 4-40 OPERATIONS SUMMARY MIRU drilling rig. NU diverter and function test same. Drill 13-1/2" surface hole to 3500' TVD/3500' MD. Run and cement 10-3/4" surface casing. Nipple up BOP's and test same to 5000 psi. P/U 9-7/8" BHA run in hole and test 10-3/4" casing to 3000 psi for 30 min. Drill 10' of new hole and perform leakoff test. Drill 9-7/8" intermediate hole to KOP at 4000' TVD/MD. Kick off well w/ 2.0-°/100' build rate. Build angle to 30.60 of inclination. Drill 9-7/8" intermediate hole to casing point at 8474' TVD/9034' MD ( 10' TVD above Sadlerochit top ). Set 7-5/8" casing and cement same. Pick up 6-3/4" BHA and RIH and test 7-5/8" casing to 3000 psi. Drill 10' of new hole and perform formation integrity test (FIT). Drill 6-3/4" hole to TD at 9016' TVD/9665'MD, condition hole to run open hole logs. Run wireline logs as programmed. Run and cement 5-1/2" production liner. Clean out the liner and test liner to 3000 psi for 30 minutes. Circulate well to 8.6 ppg filtered seawater. R/U and run cased hole logs. Run 4-1/2" completion. Freeze protect top 2000' TVD of tubing and annulus ' with diesel w/ 0.1 gpb of C120 corrosion inhibitor. Pressure test tubing and annulus to 3000 psi for 30 minutes. N/U tree and test to 5000 psi. Release drilling rig. Rig up wireline and perforate. Anticipated Formation Pressure: Maximum Anticipated Surface Pressure: Planned Completion Fluid: 3600 psi @ 8800' SS 2800 psi 8.6 ppg filtered seawater Alaska Oil & Gas Cons. ~, q~-h0rRqR Notes: b. Co d. e. DS 4-40 OPERATIONS SUMMARY cont'd Excess non-hazardous fluids developed from the well operations and as neccesary to control the reserve pit fluid level will be pumped down the 7-5/8" x 10- 3/4" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sxs of cement followed by Arctic pak. Minimum distances of wells within 200 ft. of the proposed well are: DS 4-01 · 59.2 @ 2040' MD DS 4-02 · 53.0 @ 2820' MD The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). Based on previous logs on DS 4, no potential productive zones are anticipated above 3500' TVD. No potential hazardous levels of H2S are anticipated in this well. Depth, tvd Spud to 10 3/4' csg point SET 10 3/4' CASING Depth, tvd DS 4-40 MUD P ,R,,,,OGRAM Density, ppg PV, cp YP, #/ft Int Gel 8.8 300 70 30+ to to to to 9.2 2O0 40 10 min Gel 50+ to Density, ppg PV, cp YP, #/ft Int Gel 10 min Gel FL cc/30min <25 Solids, % Mud Type 4 GeI-Benex t o Spud Mud 8 FL cc/30min Solids, % Mud Type 10 3/4' csg pt 8.8 8 6 2 6 25 2 to to to to to to to to 5000' TVD 9.7 15 15 4 10 10 6 5000' to K-10 9.7 10 6 2 4 to to to to to 9.8 15 10 4 10 10 2 to to 15 6 K-10 9.8 10 6 2 4 6 4 to to to to to to to to 7 5/8' ~g pt 10.0 15 15 4 10 10 9 SET 7 5/8' CASING Depth, tvd LSNO 7 5/8' csg pt to Density, ppg PV, cp YP, #/ft Int Gel 10 min Gel 8.8 6 10 2 8 to to to to to 9.3 15 20 4 14 FL cc/30min Solids, % Mud Type 6 <6 t o LSND 12 13-5/8" 50110 psi BOP STACK DIAGRAM ~~-~IPE RAMS~ ~___~LIND RAMS~ ~1 DRILLING L_.n r~] SPOOL CASING SPOOL BRADEN HEAD 14. 15. 16. ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSi REMAINING PRES- SURE. 13-5/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREE_ZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES . 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. CHECK DEGASSER OPERATION. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DAILY. NABORS 28E DIVERTER tSYSTEM ARCO ALASKA, INC. FILL-UP UNE RISER FLOWLINE [ I 2(7' 3:XX) PSI DIVERTER I 1(7' BALL VALVE I l I I 1(7' BA! 1 VALVE I CONDUCTOR J NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. RESERVE PIT 1(7' VENT LINE 1(7' VENT LINE DIVERTER LINES DISCHARGE 100 FT. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEES. R~:CE!VED 20" Casin$ TVD=] 1.5 T'MI)=I1-5 D~I.~ AR¢ O ALA.SKA, II' C. DS4-40 SHL: U 1 IN 1SE 34 1269' ~[L 30'7' FEL THL: U 1 1N 15E 34 29' Fl'q[ 2392' FEL BHL: U lin 15E 2'7 10' FSL 2458' FEL N59 16' N 10-3/4' Casing TV~,3=3500 TMD=3500 ~Op T~--4000 2.0 4.0. 8.0 ZO.0 ~.-~$00 ~ '---4502 DEP--~3 i2.0 14.o ..... ~22.0 ~ 24.0 26.O OC TV ~--5461 TMD=5-533 D1 x~x ~Sau TVD=$920 TMI>=6)65 DEP=671 , K- AVl ~2~/k. OE ,~d'qOLE -- 30 40 12 TVD=(8'75 ....... TMD=7175 DEP=[237 ~D=7340 TMD=?716 DEI:~-lS13 K-5 TVD=788-5 TMI>.--83.50 DEP=1836 7-5~' Casing FVD=g474 TMD=9034 DEP=2186 LCU TVD=84M TMD=9046 DEP=2 "~ Top Sadle~och{t TVD=8484 T1ViD=90,}6 DEP=2192 ~Zo'ne4A TV~=8502 TMD=-9067 DE'2202 ., ~.~ L i ~" Zone 2 se Si~dlcrochit TVD=8887 IMD:9-5I$ DEP:2431 1000 2OOO 3OOO 4ooo ~ooo 600O 70OO 1oooo 0 1000 2000 3000 4000 5000 6000 7000 VERTICAL SECTION TO PIT CAVlEM UNIT 1 ' t, CAYEM UNIT 2 TO FLARE CHOKE MANIFOLD I TO DISTRIBUTION TRIP TANK 1 ?0 BBL FILL LINE ~RAP 4 BBL CENTRIFuoE~ PIONEER Mt( I TO PIT VOLUME TANK 137 BBL EQ. DiSTRI D[TCH 131BBL 81 BBL DEGAS$1NQ TANK DESlLTER NABORS DEQA88ER DRLCO 8EEFLOW TO STAND PIPE & KILL LINE VOLUME TANK 180 BElL SUCTION 117 BBL MUD PUMPS WATER 87 BBL l, MUD HOPPERS & MIXINQ PUMPS SUCT~N 134 BBL NABORS DRLUNG LTD. RIG No. 28E MUD SYSTEM SURFACE FACILITES TOTAL ACTIVE SYSTEM: 800 BBL TOTAL SURFACE CAPACITY : 970 BBL NABORS 28E MUD SYSTEM PIT #1 130 BBLS PIT #2 81 BBLS PIT #5 117 BBLS PI?,T. PIT 20 BBLS PIT #6 135 BBLS TBT~ TANK 170 BBLS PIT #3 137 BBLS PIT $4 179 BBLS EQUIPSe~qT - DRIT.T.ING FLUID SYSTEM (3) DERRICK FLO-LINE C?,W. ANER (1) DERRICK MUD ~.~NER (1) BRANDT CF-2 C~:NT~IFUGE (1) PION~.~.~ MARK I CENTRIFUGE (1) RIG BUILT GAS BUSTER (1) DRILCO DEGASSER (1) PVT SENSOR PER PIT w/ visual and audio warning devices (1) AGITATOR PER PIT (1) DRILLING FLOW SHOW SENSOR W/ readout convenient to the driller's console ITEM (1) Fee (2) Loc ** CHECK LIST FOR NEW WELL PERMITS ** APPROVE DATE [2 thru (3) Admin ~9~h ru [10 & 13] [14 thru 22] [23 thru 28] (5) BOPE (6) Other [29 thr~J' 31] ' (6) Add l 1 3. 4. 5. 6 7 8 1 10. 11. 12. 13 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Company Is permit fee attached ............................................... Is well to be located in a defined pool .............................. _~_ Is well located proper distance from property line ................... Is well located proper distance from other wells ..................... Is sufficient undedicated acreage available in this pool ............. ~_ Is well to be deviated & is wellbore plat included ...... Is operator the only affected party ................ Can permit be approved before 15-day wait ..... Does operator have a bond in force ................................... Is a conservation order needed ....................................... . .... ~- Is administrative approval needed .................................... · DoesIS leaSewell nLrnberhave aappr°priateunique name ......................................... ~ nLrnber ,''~-- Is conductor string provided ......................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. , ,, Is adequate wellbore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions of diverter & BOPE attached .... Does BOPE have sufficient pressure rating -- test to =~::~OC~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Additional requirements ............................................. Lease & Well ~ ~~ 2~',~3~3-,' ~~ NO RFMARKS O --~ 'TZ ~O r~ z rev 03/29/91 jo/6.011 INITIAL GEO1 UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Additional remarks' Well History File APPENDIX Information of detailed nature that is not padiculady 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 C~MPUTING CENTER COMPANY NAME : ARCO AhASKA INC, ELbN.ANE : D.S. 4 - 40 iEGD NAME : PRUDHOE BAY BOROUGH : NORTH SbOPE STATE : .ALASKA APl NUMBER REFERENCE N0 : g5056 RECEIVED OH & Gas Cons. L;U~HTHS~OP, Anchorage ~IS TaDe Verl~J_catt. on Listino .chlumberqer AlasKa Computinq Center ~-~AR-1995 !.5:17 DAT~ : ~5/03/ O~IGiN : FLIC REEL ~A~E : 05056 CONTINUATION a : P~EV.IOUS REEL : COMMENT : ARCO ALASKA iNC., DS 4-40, PPUDHOE RAY, aPI 50-0~9-222~4-00 **** TAPE aEAD~R **** SERVICE NAME : FD!T DAT~ : 95/0~/ 2 ORIGIN : FLIC TAP~ NA,E : q5056 CONTINUATION # : l PREVIOUS TAPE ~ COMMENT : ARCO ALASKA INC., DS 4-40, PRUDHOE BAY, API 50-0~9-222~4-00 TAPE HEADER P~UDHOE BAY CASED Hnt,,E WI~ELINE LOGS wELL NA~E: API NUMBE~: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FML: FWL: ELEVATIONfFT FRO~ ~Sb O) DERRICK WELL CASI~G RECORD ~ST STRING 2ND STRING BRD STRING PRODUCTION D,S. 4 - 40 500292~22400 ARCO ALASKA INC. SCHbUi~{BERGER ~ELL SERVICES 2'MAR'95 95056 BAILEY MIKE REYNOLD 34: lin 1269 307 60.00 59,00 27.00 []PEN MOLE CASING DRILLERS CASING ~IT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 00 5,500 9643,0 ~.7,00 O0 O0 O0 O0 ~.B75 ~391,0 6,40 # CURVE SHIFT DATA - ~bL PASSES TO STANDARD(~4EASU~ED DEPTH) PAGE: I$ Tape Verification Listina chlumberger Al~sk~ Computing Center BASEI, INE CURVE FOR SHIFTS LDWG CURV~i CODE: GR RUN N [3 ~'~ REP DATE LOGGING ~ASEI, INE DEPTH o485'5 94!.1,0 9~91..5 9161,5 100o0 ~-~AR-!995 !5:17 .......... ~OUIVAI.,EN~ UNSMIFTED DEPTH .......... TDTP ~8~86.5 9a84.o 9457.0 9410.5 9~91.5 9~o0 THREE TOTP BASE PASSES A~D TWO TDTP BORAX PASSES. '.]['~E DEPTH SHIFTS SH[]~N ARE THE TDTP ~ASE PASS 1 GRCH TO THE (]~ GR PROVIDED BY ARCO. ~bb TDTP CURVES WERE CARRIED ;9TTH THESE SHIFTS, **** FILE ~EADER F]L~ NA~E : EDIT .00! S~RV!CE : FLIC VERSION : 001C0! D.~TE : 95/03/ 2 MAX REC SIZE : !~024 FILE TYPE : LQ LAST FILE : FILE HEADER FILE NUMBER: I EDITED CURVES Depth shifted and clipped curves lor each pass in separate ~iles. PASS NUMBER: ! DEPTH INCREMENT: 0.5000 FIL~ SUMMARY LDWG TOOL CODE 8TART DEPTH STOP OEPTH TDTP 951~'0 939!,0 $ CURYE SM!~T DATA - ~ASS TO P~SS(~ASU~ED DEPTH) BASELINE CURVE FOR SHIFTS LD~G CURVE CODE: PASS NUMBER: Tape verification bistino chlumberqer AlasKa Computino Center 9-,~A~-lgg5 15:17 PAGEt BASELINE DEPT~{ $ .......... EOUIVAI,ENT I.J~4SHIFTED OEPTH .......... !' 0 T P ~E~A~KSt TDTD BASE PASS ~ Ng PASS TO PASS SMIFTS APPLIED. $ [,TS FORMAT DATA ** DATA FOR.~AT SPECIFICATION RECOPD ** ** SET TYPE - 64EB ** TYP..~ R PR C E I 66 · .. 2 66 o 3 73 4 66 5 66 6 73 7 65 8 68 0~5 9 65 F' !~ 66 11 17 68 1~ 66 0 14 65 FT 15 66 68 16 66 0 66 0 ** SET TY'P{~;- CMAN ** ID ORDER # bob TYPE CbAGS MOD NUmB SA~P ELE~-, CODE (HEX) DEPT FT 500951 O0 000 O0 0 I I 1 4 68 8IG~ TDTP Cb 500951 O0 000 §0 0 1 I 1 4 68 8IGC TDTP CU 500951 DO 000 O0 0 1 I I 4 68 5ISH TDTP CU 500951 O0 000 O0 0 1 1 1 4 68 SDS! TDTP CI! 500951 O0 000 O0 0 1 1 1. 4 68 GB~ TDTP CU 500951 O0 000 O0 0 I I ! 4 68 ~BHF TDTP CU 500951 O0 0o0 O0 0 ! 1 1 4 68 TP~ TDTP PU-S 500951 O0 000 O0 0 i ! 1 4 68 TRAT TDTP 500951 O0 000 O0 0 I I I 4 68 TCAN TDTP CPS 500951 O0 000 O0 0 I ! 1 4 68 TCAF TDTP CPS 500951 O0 000 O0 0 1 1 I 4 6~ 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 :I.S Tape Verification t..istlHo :chlumberqer AlasKa Computino Center ~-MAR-~905 15:~7 PAGE: TCND TO?? C TCFD TDTP CmS TSCN TDTP CPS T$CF TDTP CPS IMMD TDTP CPS I~FD TDTP CPS BACg TDTP CP~ T~AC TDTP CPS TENS TDTP LB GRCH TDTP GAPI G~ SCS GAPI ...... ::--; 7--;:7-:-::-- : .................... . .......... ORDER ~ bF)G TYPE CLASS ~[.)D M[J~ SAMP EbE~ CODE (HEX) [';;[~''';;''';;~'';;0_ ~ .... ~ ........ 1 ; ..... ; ..... ~ ..... ;~. .... ;';~;:;';;'. U 0 500951 OD 000 O0 0 1 1 1 4 68 0000000000 500951 O0 000 O0 0 1 ~ 1 4 68 0000000000 ~00951 O0 O00 O0 0 1 1 1 4 68 0000000000 500951 00 000 00 0 1 1 1 4 68 0000000000 500951 00 000 00 0 I ~ 1 4 68 0000000000 500951 00 000 00 0 1 1 1 4 68 0000000000 50095~ 00 000 O0 O 1 ~ 1 4 68 0000000000 500951 O0 000 O0 0 I ~ 1 4 68 0000000000 500951 00 000 00 0 I 1 1 4 68 O000000000 500951 00 000 00 0 1 1 ~ 4 68 0000000000 ** DATA ** DEPT. 9512 SDSI.TDTP 0 TPAT.TDTP 2 TCFD,TOTP 7684 INFD.TDTP 3~! GRCH.TDTP -999 .000 SIG!4.TDTP 18.097 SIGC.TDTD ~ 522 SIBH,TDTP .4!9 S~)HN.TDTP ~9.763 SBHF.TDI'P 451314 TPHI.TDTP .314 TCAN TDTP 26464 2~5 TCAF.TDTP 1!432.826 ~iC~D,TDTP ,543 TSCN~TDTp 5675~671 TSCF,TD~P 2452.872 INMD,TOTP 359 ~.ACK.TDIP ~09 463 TBAC.TDTP 26.62~ TENS.TDTP DEPT. 9500, SDSI,TDTP O. TRAT,TDTP 2. TCFD'TDTP ~065, IMFD,TDTP 401, GRC~,TDTP ,-999, 000 SIGM.TDTP 18.718 SIGC.TDTP 1.~93 SIBH.TDT? 410 SBHN.TDTP 43.0~9 SBHF,TDTP 31,452 TPHI-TDTP 647 TCAN,TDTP 3!,016.398 TCAF,TDTP !2059.271 TCND.TDTP 352 TSCN.TDTP 7000.704 TSCF,TDTP 2645.!42 INND.TDTP 266 BACKoTDTP 41.003 TBAC.TDTP !0.890 TEN$oTDTP 250 GR.BCS 76,45j DEPT. ~391.000 SDS!.TDTP 0.5]5 TRAT,TDTP 2.603 TCFD,TDTP 6()38'000 INFD.ID?P 36!~93B GRCH,TDTP 45,965 ** END O? DATA SBHN.TDTD 00.578 SBHF,TDTP 46.578 TPHI,TDTP TCAN,TDTP ~3000.000 TCAF.TDTP 9{80,000 TCND,TDTP ,SC,..TDTP 5012.000 TSCF,TDTP 1925 500 IMND.TDTP BACK,TDTP 58 884 TBAC.TDTP 16:68] TENS,TDTP GR.8CS 74~756 68 172 241261 24136 789 2361 028 1195.000 52,i93 30,634 26725,676 2294'584 1190,000 104,750 34,635 20988,000 2347,313 !095,000 FIbE NAME SERVICE VERSION DATE MAX REC SIZE FILM TYPE L~ST F~LE TRAILER **** : EOIT : WbIC : 001C01 : 05/03/ : 1024 !,~ Tape Veri. flcat~.on Listtn.~ chlumberger Alaska Comput~no Center 15:17 PAGE: **** FIL~] HEAl)ER F![j~ NAmF. : EDT'l: .002 SFRVICE : FblC VFR$ION : 00!C01 DATF : 95/0~/ 2 MAX REC SIZE : 1024 FILE TYPE : LAST FILE FILF HE,DER F!LF NUMBER: EDimED CURVRS Depth ship,ted and cl~PDed curves for each Pass in separate f~.les. PASS DFPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPT~ STOP DEPTH 9 $ CURVE S~tFT DATA - PASS T~ PASS(MEASU~D DEPTH) BASELINE CURVE FOR SHIFTS LDWG CU~'VE CODE: GRC}! PASS NUMBER: ! ----------EQUIVALENT UNSHIFTED DEPTH---------- CHGR SIG~ BASELINE DEPTH ~8BBD 0 948] 0 9468 5 94~5 5 9424 0 9420 0 9409 5 9~97 5 9~95 5 9386,5 9~64,0 1,00.0 ~888~.0 8 7' 948~,5 9468,5 9465.5 9424,0 9420,5 9410,5 9398,5 9396,5 9386,5 9364,0 ~00.0 !.00.0 REMARKS: TDTD BASE PASS 2, BASE PASS 2 GRCH SHIFTED TO BASE PASS ! GRCH, BASE PASS 2 S!G~ SHIFTED TO BA&E PASS 1 $IG~, AND ALL TDTP CURVES CARRIED ~ITH THE SiGM SHIFTS, $ LIS FORMAT DATA ~IS ?awe 'Verl~Icatl. on Listln~ :chlumberger Alaska Computinq Center 2-MAR-1995 15:17 PAGE: DATA FORMAT SPECIFICATION PECORD ** 1 66 0 5 66 6 73 7 65 8 68 0.5 9 65 FT !~ 66 0 14 65 15 66 68 16 66 0 66 ** SET TYP~ - CHAN ** N~E SERV U I. VICE Ap AP1 APl FILE NUmB NUMB SIZE REPR P ES ID ORDER # LOG TYPE CLASS ~OD NUmB SAgP ELE~ CODE (hEX) DEPT FT 500951 O0 000 O0 0 2 SIG~ TDTP CU 500951 O0 000 O0 0 2 ! 1 4 68 $}GC TDTP CIJ 500951 O0 000 O0 0 2 ! ! 4 68 STBH TDTP CU 500951 O0 000 O0 0 2 I 1 4 68 SDS! TDTP Ct) 500951 O0 000 O0 0 2 i 1 4 68 SBHN TDTP CU 500951 O0 000 O0 0 2 I 1 4 68 SBHF TDTP CU 500951 O0 000 O0 0 2 I ! ~ 68 TPHI TDTP PU-S 500951 O0 000 O0 0 2 1 I 4 68 T~AT TDTP 500951 00 000 00 0 2 I 1 4 68 TCAN TDTP CPS 500951 O0 000 O0 0 2 I I 4 68 TCAF TDTP CPS 500951 O0 000 O0 0 ~ I 1 4 68 TCND TDTP CPS 500951 O0 000 O0 0 2 I ! 4 68 TCFD TDTP CPS 500951 O0 000 O0 0 2 1 1 4 68 TSC~ TDTP CPS 500951 O0 000 O0 0 2 1. 1 4 68 TSCF TDTP CPS 500951 O0 000 O0 0 2 ! I 4 68 INND TDTP CPS 500951 O0 000 O0 0 2 ! 1 4 68 iNFD TDTP CPS 500951 O0 000 O0 0 2 I I 4 68 BaCK TDTP CPS 500951 O0 000 O0 0 2 1 1 4 68 FBAC TDTP CPS 500951 O0 000 O0 0 P I t 4 68 TENS TDTP LB 500951 O0 000 O0 0 2 1 ! 4 G~CM TDTP GAPI 500951 O0 000 O0 0 2 1 ! 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Ta~e Verification Listino :chlumberger AlasKa Computin~ Center DEPT. g512.000 SIGM.TDTP 18.533 SIGC.TDTP ~.836 SDSY.TDTP 0.453 SBHi~.TDTP 50.3~1 SBHF.TDTP 39 155 T~AT.TDTP 2.270 TCAbi.TDTP 26023.551 TCaF.TDTP 11465~20! TCFD.TDTP 7372.045 TSCN.TDTP 5207.796 TSCF.TDTP 2294~ 399 X~F~.TDTP 371.946 BACK.TDTP 207.294 FBACoTDYP 51.488 GRC~,TDTP -999,250 S!BH.TDTP TPHI.IDTP ~CND.TDTP INND.TDTP TENS.TDTP DEPW, 9500,000 SIGg.TDTP 17.890 S!GC.TDTP ~ 578 SIBH.TDTP SDSI,TDTP 0.461 S~H~.TDTP 40.433 SBHF.TDTP 33:636 TPHI.TDTP TPAT.TDTP 2.6~7 TCA~.TDTP 3223~.836 TCAF.TDTP ~227~.576 TCND.TDTP TCFD.TDTP 7575.944 TSC~.TDTP 6602.~37 TSCF.TDTP 2513.858 INND.TDTP INFD.TDTP 380.409 ~ACK.TDTP 93.596 FBAC.TDTP 23.451 TENS.TDTP G~CM.TDTP -999.250 DEPT. 9391.000 SIG~.TDTD 17.602 SIGC.TDTP 1.623 SIBH,TDTP SDS~.TDTP 0,447 SBHN.TDTP 51.9!4 SB~F.TDTD 45.180 TPMI.TDTP TPAT.TDTP 2.591 TCAN.TDTP 270~4.000 TC~F.TDTP 10449.000 TC~D.TDTP TCFD.TDTP 6750.000 TSCN,TDTD 5557.000 TSCF.TDTP 2144 125 INND.TDTP I~FD.TDTP 385.81.3 BACK.TDTP !07.614 FBAC.TDTP 27[709 TENS.TDTP G~CE.TDTP 91.406 PAGE: 68,445 22,790 23060,563 ~964.210 1150.000 44,578 29,b18 25247.250 ~i54,982 ~50.000 77 219 23340,000 2392,i~5 1155,000 ENO OF DATA ***g FILE TRAILER FILE NA~E : EDIT ,002 SERVICE : FLIC VERSION : O01CO1 D~TE : 051031 2 M~X REC SIZE : !024 FILE TYPE : L~6T FILE : **** FILE HEADER **** FILM NAME : EDIT ,003 SERVICE : FL!C VFR$ION : 001C0! D~TE : 95103/ 2 MAX REC SIZE : ~.024 FIL~ TYPE : LO LAST FILE : FILE HEADER FILE NUNBER: EDITED CURVES Depth shiited 3 and cliDoed 3 curves for each pass in separate files, ,I$ TaDe Verif~catIon Listino ;cbl.,umberger AlasKa Com[-~utinq Center ~-~R-~995 15~17 DEPTH INCREMENT: 0.5000 # FIL~ SUMMARY I.,DWG TOOL CODE START DEPTN TDTP CURVE SHIFT DAT~ - PASS TO PASS(~FASUPED DEPTH) ~ASELINE CURVE F~R S~{I~TS LDWG CURVR CODEI GRCH PASS MU~BER: I BASEI, INE DEPTH 9~07,0 9483,0 0474 9437 0 9424 ~ 9420, 9415 0 9397 0 9]94 0 9386 0 9374 5 9370 5 !00 0 STOP DEPTH ...... ----EQUIVALENT UNSHIFTED DEPTH .......... G~CH 9462.0 9438.0 9425.0 9416.0 9395.5 9386.5 9507.0 9483 0 474:S 9421.0 939~.0 9375 5 9370i5 100 0 100.5 PEMARKS: TDTP BASE PASS 3. BASE PASS 3 G~TM . .C.! SHIFTED TO }]:;ASE PASS I, GRCH. N~' BASE PAS6 3 SIGH St{IFTED TO BASE PASS I SIG~, A D ALb TDTP CURVES C~RRIMD ~ITH THE SIGH SHIFTS. FORMAT DATA PAGE: ** DATA FORMAT SPECirF!CATION RECORD ** ** SET TYPE - 64EB TYPE REPR CODE ~LUE !. 66 0 2 66 0 3 73 ~4 4 66 5 66 IS Tare Ver.tficat!.on Listinq .chlumberqer AlasKa Compt. ltinq Center 2-~4AR-!9~5 !5:17 PAGE: ~ 73 7 65 8 68 0.5 9 65 It 66 12 13 66 o 14 65 FI 15 66 68 16 66 0 66 ** SET TYPE N .... ERV SE~V ~D ORDE D~PT FT 5009 $Ig~ TDTP CI} 5009 $IGC TDTP CU 5009 $1B~ TDTP CU 5009 $D$I TDTP. CU 5009 $BHN TDTP CU S009 $BHF TDTP CU 5009 TPHI TDTP PU-S 5009 TRAT TDTP 5009 TCAM TDTP CPS 5009 TCAF TDTP CPS 5009 TCND TDTP CPS 5009 TCFD TDTP CPS 5009 TMCN TDTP CPS 500951 TSCF TDTP CPS 500951 iNND TDTP CPS 500951 INFD TDTP CPS 500951 B~CK TDTP CPS 500951 FBAC TDTP CPS 500951 TENS TDTP LB 500951 G~CH TDTP GAP! 500951, - CHAN ** IEAPIC .~ API AP1 AP! FILE NUMB NUMB SiZE REPR PROCESS R # hOC . '~ ,, TYPE CLAoS MOD NU~B SA~P ELE~4 CODE (HEX) 51 00 000 00 0 3 I 1. 4 68 0000000000 51 00 000 00 0 3 1 1 4 68 0000OO0000 51 O0 000 O0 0 3 1 ! 4 68 0000000000 51 O0 000 O0 0 3 1 I 4 68 0000000000 5! 00 000 00 O 3 1 ! 4 68 0000000000 51 00 000 O0 0 3 ! 1 4 68 0000000000 5! O0 000 O0 0 3 I I 4 68 0000000000 5! O0 000 O0 0 3 I I 4 68 0000000000 51 O0 000 O0 0 3 1 I 4 68 0000000000 5! O0 000 O0 0 3 1 I 4 68 0000000000 51 O0 000 O0 0 3 I ! 4 6.8 0000000000 51 O0 000 O0 0 3 I I 4 68 000000000:0 51 O0 000 O0 0 3 i ! 4 b8 0000000000 O0 000 O0 0 3 i 1 4 68 0000000000 O0 000 O0 0 ~ I I 4 68 0000000000 O0 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 I 4 68 0000000000 00 000 00 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 1 I 4 68 0000000000 00 000 O0 0 3 1 1 4 68 0000000000 O0 000 O0 0 3 ! 1 4 68 0000000000 *.* DITA ** DEPT. 95t2.000 SDSI.TDTP 0,553 T~AT.TDTP 2.353 TCFD.TDTP .7250.042 iNFD'TDTP 355 :~59 G~CM,TDTP -999,250 SIc~ TDTP 1, ~,~ ~'~ 19 523 8IGC. . :~ ~,, ~ . . 626 SB~N.' ~P . . . ~D'I'~... 49 543 SBMF TDTP 44 420 TCAN.TDTD ~5~50..527 TCcAF,TD?PI !0729,375 T$Ca,TDTP 53it.959 TS.F.TDTP ~57,14! BACK.TDTP ~22.567 FBAC,TDTP 59.649 $IBH.TDTP TPH!.TDTP TCND.TDTP INND.TDTP TENS.TDTP 68-408 25,84 7 22867 '590 2 '133 ' 08.4 1140. 000 Tame Verification Llstiriq chlumheroer AlasKa Computi. nq Center 2-MAR-!995 15:!7 PAGE: 0 DEPT. qSO0,O00 SIG~.TDTP 18.4o4 SIGC.TDTP 2,618 $IBM.TDTP SDS~,TDTP 0.501 SBHN.TDTP 39.320 SBHF.TDTP 34,120 TPHI.TDTP TPA~.TDTP 2,552 TC~.TDTP 31495.832 TCAF.TDTP 1233g,227 TCND.TDTP TCFD.TDTP 7730,205 TSC!~,TDTP 655~.350 TSCF,TDTP 2567.036 IN~D.TDTP IMFD.TDTP 37~.82~ BACK,TDTD 129.199 F~AC.TDTP 33,086 TENS,TDTP G~C~,TOTP -9Q9.250 DEPT. O301.0oo S!Gb~,TDTP !B.3~2 SIGC.TOTP 1.39~ SIBH.TDTP SDST,TDTP 0,.479 SBN~.TDTP 54.~29 SBHF,TDTP 49,699 TPHI,TDTP TRAT,TDTP 2.557 TC~N,TDTD 25992.902 TCAF.TDTP ~0~67,137 IC~D,TDTP TCFD,TDTP 63~0'838 TSCN,TDTP 5205.035 TSCF.TDTP 2035,g5~ INND,TDTP INFD.TDTP 3&4.63~ BACK,TDYP 135.874 FBAC,TDTP 33.810 TENS,TDTP GPCH,TDTP 138.375 41.500 28.436 25442.160 1982.125 1125.000 83,816 30,8~0 21697,668 2425.024 1.115.000 ** END OF DATA **** FILE TRAILER **** FILE NAME : EDIT ,003 SERVICE : VBIC VERSION : O0~,CO1 OATE : 95/03/ ~X REC SIZE : 1024 FILE TYPE LAST FILE : **** FILE MEADER **** FILE NAME : EDIT ,0n4 SERVICE : FbIC VERSION : 001C01 DATE : 95/03/ 2 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : FILE HEADER FILM NUMBER: 4 EDITED CURVES Depth shifted and clipped curves P~S~ NUMBER: 4 DEPTH INCREMENT: 0,5000 FILE SD~M~RY LDWG TOOL CODE START DEPTH T 951.2.0 $ ~or each PaSS in separate STOP DEPTH files. ,IS Tape Verification ;chl.mberqer AlasKa Computino Center ~-MAR-1.995 15:17 CURVC SHIFT DATA - PASS TO PASS(hEASURED DEPTH) ~ASELINE CURVE FOR SHIFTS b~WG CURVF; CODE: GRCH PASS NU~ER~ 1 gASELINE DEPTH 94~3 5 483 9461 5 9456 0 ~43~ 5 9433 5 94~6 5 9409 0 9390 5 9390 0 9359 5 100 0 .......... EOUIVAI.,~iNT [iNSHIFTFD DE'.PTH .......... GRCH SIGH 88~88.5 ~ ~ . 9¢90.0 9484,~ 9475.0 946~,0 9457.0 9440,0 9427.5 9410,5 9391,5 9434.5 9391,5 9360.5 101,0 101,5 TDTP BORAX PASS 1, BnRAX PiSS ! GRCH SHIFTED TO BASE PASS 1GRCM, BORAX PASS 1SiGM SMIFTED TO BASE PASS ! SIGM~ AND Abb TDTO CURVES CARRIED WITH T!iE SIGH SHIFTS. $ bis FORMAT DATA PAGE~ itl ** DATA FORMAT SPEC!FICATIO~4 RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT !1 66 12 13 66 0 14 65 FT IS Ta~e refill, cation Listlnq chlumherger AlasKa ComputJ. nq Center 2-,"-a^ R- 1995 !5:!.7 12 .ID ORDEP ~ LOG TYPE CLASS ~UD NU~S SA~P DFPT FT 500951 O0 000 O0 0 4 ! 1 4 STGu TDTP CU 500951 O0 000 O0 0 4 1 I 4 $IGC TDTP CU 500951 O0 000 O0 0 4 1 1 4 SIBH TDTP CU 500951 O0 000 OO 0 4 1 1 4 SDS! TDTP CU 500951 00 000 O0 0 4 1 I 4 SBH~ TDTP CU 500951 O0 000 O0 0 4 I 1 4 SBHF TDTP CU 500951 O0 000 O0 0 4 l. I 4 TPH! TDTP PU-S 500951 O0 000 O0 0 4 1 I 4 TRA· TDTP 500951 O0 000 O0 0 4 1 1 4 TCAN TDTP CPS ~00951 O0 000 O0 0 4 I i 4 TCAF TDTP CPS 500951 O0 000 O0 0 4 1 1 4 TCND TDTP CPS 500951 00 000 O0 0 4 1 1 4 TCFD TDTP CPS 500951 O0 000 O0 0 4 ! 1 4 T$CN TDTP CPS 500951 O0 000 O0 0 4 I I 4 TSCF TDTP CPS 500951 O0 000 O0 0 4 1 i 4 IMND TDTP CPS 500951 O0 000 O0 0 4 i 1 4 INFD TDTP CPS 500951 O0 000 O0 0 4 1 1 4 BACK TDTP CPS 500951 O0 000 O0 0 4 1 i 4 FBAC TDTP CPS 500951 O0 000 O0 0 4 I 1 4 TENS TDTP LB 500951 O0 000 O0 0 4 I 1 4 G~CN TDTP GAPI 500951 O0 000 O0 0 4 1 I 4 ..... ES5 ODE (HEX) O000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 * * D 1 A ** SD$I.TDTP 0.051 SBHN:,TOTD 75.465 SBHF,TDTD 'r~A~.TDTP 2.125 TCAN::.TDi]~aP 16555.'2~4 TCAF*TDTP TCFD.TDTP 5092.159 TSCN.TDTP 3659.,6~4 T~CF.TDTP INFD.TDTP 346,311 BACK,TDTP ~37.554 FBAC.TDTP G~CN.TDTP -999.250 D~PT. 9SO0.O00 $IG~.TDT¢ 20.576 SiGC.TDTP 8DST.TDT'P 0o728 5BH.N.TDTP u7o408 ~BH~,TDTPA.." " T~AT~TDTP 2'131 TCA,N.TDTP 11448,629 TCAF,TDTP :DTP 3819,8)7 TSC~..'~ .... 'P TCFD,T:' ' '2564,156 TSCF.TDTP IMFD,TDTP 3~8.~45 BACK,TDTP ~0~.3~8 F~C.TDTP GRCH.TDTP -999.2B0 0 7792 ~99 1722.542 113,877 5372. ! 75 1203. 209 42. 893 SIBH.TDTP TPH!.TDTP TCND.TOTP INND-TDTP TEN$.TDTP $IBH.TDTP TPHI.TDTP TCND.TDTP INND.TDTP TENS.TDTP 134 I27 24."267 14562. 324 2083.473 1175,000 155.449 24,439 1086~,688 2023.205 1150.000 ,IS Tame Verification Listing ichlumberqer AlasKa Computing CeDter 2-~AR-INg5 15:17 PAGE: 13 DFPT. o3q!.000 SIG~.TDTP 1~.821 SIGC.TDTP SDS!.TDTP 0.500 S~HN.TDTP 86.477 SBHF.TDTP TPAT.TQTp 2.224 TCAN.TDTP 16796.~52 TCAF.TDTP TCFD.TDTP 4576.~51 TSC~.TDTP 34~7.53~ TSCF.TDTP INFD.TDTP 349.70~ BACK.TDTP 190.77~ FBAC.TOTP G~CM.TDTP 67.563 0.385 $IBH.TDTP ,62.020 TPH!.TDTP 7553.~54 TCND.TDTP 1559.27~ iMND.TDTP 40.~56 TENS.TDTP 162.251 25.828 13324.076 2204.697 ~160.000 ** EMD OF DAT~ **** FILE TRAILER **** FILF NA~E : EDIT .004 SERVICE : FLIC VFRSIO~ : O01CO1 DATE : 95/03/ 2 MAX REC SIZE : L.~ST FII,E : **** FILE HEADER **** FILF NAME : EDIT S~RVICE : FLIC VERSION : ~X REC SIZE : 1024 FILE TYPE : LO LAST FILE FIL~ HEADER FILF NUMBER: 5 EDITED CORVE$ Depth shifted and ClipPed c:urves for each pass in separate P~S$ NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE :SUMMARY LDWG TOO[,, CODE START DEPTH STOP DEPTH ............. ...... .. .... . ..... .... TDTP 9519,0 9391.0 $ CURVE SHIWT DATA - PASS TO PASS(~iEASURED DEPTH) BASELIME CURVE FOR SHIFTS LDWG CUR'VE CODE: GRCH PASS MU~BER~ 1 ----------~QUIVALE~T U~$gIFT~D DEPTH---------- BASELINE DEPTH GRCH SIG~ .IS Tame verlf~..cat~on ;cblumberqer Alaska Com[~utlnn Center ~-~AR-~.995 15:17 R8~88.0 88BSq.5 9504.0 9504.0 9490.0 9490.5 9475,5 9475.0 9468,5 9470.0 9456,0 9457.0 453,5 9454.5 . 436,5 943~.~ 9433,5 9435.0 9414.5 9416.0 9396,5 939~.5 9]86.5 9370,0 9171,5 !00,0 101.5 101.5 PEMARK$: TDTP ~ORA× PASS 2. BORAX PASS ~ GRCH SHIFTED TO BASE PASS I GRCH. ~RAX P~SS 2 SIG~ SHIFT~D TO BAS~ PASS 1 SIG~, ~ND ALL TD~rP CURV~S CARRIED NITN THE SIGH SHIFTS, LIS FDRMAT OATA PAGE~ 14 DATA FORMAT SPECIFICATtUN RECORD ** SET TYPE - 64gB ** TYPE REPR CODE VAbU~ 1 66 0 2 66 0 3 73 84 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT !1 66 12 1~ 68 13 66 0 14 65 FT 15 66 68 i6 66 0 66 IS Tape Verification bistino chlumberqer Alaska Computinq Center 2-~A~-1995 15:!.7 PAGE: ** SET TYPE - CHAN .......NA~ :'':''3~';'::~''~'':':'~R I ~l . P ID ORDEP # LOG I~m~m~m~m~m~~~~mm~ D~PT VT 50095~ O0 $IGM TDTP CU 500951 O0 SIGC TDTP CU 500951 $IS~ TDTP CU 500951 O0 SDSI TQTP C!I 500951 O0 6BH~ TDTP CU 500951 00 SBHF TDTP CU 500951 O0 TPH~ TDTP PU-S 50095~ O0 T~AT TDTP 500951 O0 TCA~ TDTP CPS 500951 Ou TCAF TDTP CPS 500951 00 TCND TDTP CPS 500951 O0 TCFD TDTP CPS 500951 O0 TSCN TDTP CPS 500951 O0 T$CF TDTP CPS 500951 O0 INND TDTP CPS 500951 O0 INFD TDTP CPS 500951 O0 BAC~ TDTP CPS 500951 O0 FBAC TDTP CPS 500951 00 T~NS TDTP LB 500951 G~C~ TDTP GAPI 500951 O0 , TYPE CLASS 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 00 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 000 O0 mmmmmmmm--#m OD N 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 S 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 0 5 1 1 4 68 0000000000 ! I 4 68 0000000000 1 I 4 68 0000000000 I 1 4 68 0000000000 1 1 4 68 0000000000 1 i 4 68 0000000000 i 1 4 68 0000000000 I 1 4 68 0000000000 1 1 4 6~ 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 1 4 68 0000000000 1 ! 4 68 0000000000 1 1 4 68 0000000000 1 1 4 6~ 0000000000 I 1 4 68 0000000000 1 1. 4 68 0000000000 i 1 4 68 0000000000 i 1 4 68 0000000000 1 1 4 68 0000000000 15 ** D~TA ** DEPT, 9512,000 8IG~.TDTP ' . D~ SDfi].TDTP 0 690 8BHN T...'tP I~AT.TDTP 2.11.! TCAN,TDTP CFD.TDTP 5155.119 TSCN,TDTP INFD.TDTP ]7!.205 BACK,TDYP G~C~,TDTP -999.~50 DE?T. 9500,000 8IGM,TDTP SDS!,TDTP 0,669 $:BHN.TDTP TPAT,TDTP 2 146 TCAb~.r TP . · IO ~ .... .. TCFD TDTP 40~3 5.0 TSCN'TDTP IMFD.TDTP 386.078 BACK.,TDTP G~CM.TDTP -999. 250 DEPT. 9391.000 SIGM.TOTP SDSI'TDTP 0,626 SBHN,TDTP TRAT.TDTP 2'123 TCAN.TDTP TCFD,TDTP 4637.000 TSC~,TDTP IMFD.T, . :.,DTP 337.18~,. BACK -~D.I,P G~CH,TDTP 143.375 20,274 SIGC.TDTP 0.514 80.1.21 SBHF.TDTP 65 133 t. 77~5. ~.40 TCAF,TDTP 8423!869 37.48.287 TSC .TDTP 1775 293 330.803 FBAC.TDTP !16.164 20 340 84 1,21, 13254 000 2837.OOO 216.176 19.tb8 81.805 15932,000 3363 500 204~996 SIBN ,TDTP HI ,TDTP TCND,TDTP INND.TDTP TEN$oTDTP 8IGC.:DTP 0,327 8iBH.TDTP 8BHF. DTP 70.098 TPHI.TDTP TCAF.TDTP 6175,O00 TCND.TDTP TSCF,TDTP 132~,750 INND,TDTP FBAC.TDTP 56,78! TENS,TDTP SIGC.TDTP 0 349 SBHF.TDTP 66 246 TCAF.TDTP 7509 000 TSCF,TDTP t585 500 FBAC.TDTP 45,579 S!BH,TDTP TPHI'TDTP TCND ' TOTP IN~D.TDTP TENS.TDTP 143.435 24 349 14618 740 2083 .143 1160 000 152,656 24,t90 11;685.000 20!5,557 11.55.563 148,203 23'901 13181.:125 :2116.625 1,151.422 ** END OF DATA ** IS Tape Verification l.istIno chlumber~er Alaska Comput~no Center **** FILE TRAILER FILE NAME : EDIT .005 SERVICE : FLIC VERS!~N : OOI. CO1 DAT~ : 05103/ MAX REC SIZE : !074 LAST FILE : 2-MAR-1995 15117 PAGE: 16 **** FILE HEADER **** FILE NAME : Ei)IT .006 SERVICE : FbIC VERSION : O01CO1 DAT~ : q5/0]/ 2 ~AX REC SIZE : 1024 FILE TYPE : LU FILW ~EADER FILE NUMBER: 6 AVERAGED CURVES Compensated Neutron: Aritnmetic average of edited Passes for all curves, Pulsed Neutron: Unaveraged edited Pass ! Gamma Rag and backlround counts; arithmetic average of edited static basel!ne passes for all other curves. DEPTH INCREMENT 0.5000 PASSES TNCLHDED IN AVERAG~ LDWG TOOL CODE PASS NltMBERS ....... ..... .. .......... RE~ARK~: T~IS ARITH~ETIC AVERAGE FILE CONTA. IN~ THE AVERAGE OF THE THREE BASE PASSES, A~D THE PASS I CURVES FOR GRCH, TENS, BACK, AND EBAC. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64gg ** TYPE REPR CODE VALUE 2 66 0 3 73 ~4 4 66 1 i~ Ta~e Verl~i~catlon List~n.~ lU~berger ~la~ka Computin~ Center 2-MAR-!995 15:17 PAGE: !.7 m#m~mmmmmmmmmm~mmmmm~m~mmmmmmMmmmm b 73 7 65 8 68 0.5 9 65 1! 66 12 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 ** SE~ ORDE~ DEPT FT 500951 SIG~ PN~V CU SIGC PNAV CU S!B~ PNAV CU 6DS! PNAV CU SBHN PNAV CU SBHF PNAV CU TPHI PNA¥ PU-S TRAT PNAV TCAN PNA¥ CPS TCAF PNAV CPS TCND PNAV CPS TCFD PNAV CPS TSC~ PNAV CPS T$CF PNAV CP6 INND PNAV CPS I~FD PNAV CPS BACK TDTP CPS FBAC TDTP CPS TENS TDTP LB G~CH TDTP GAPI TYP~ - CHAN ~, ~ LOG TYPE CLASS ~O[) NtI~B SA.P EnE~ CODE (HEX) O0 300 000 6 ! i 4 68 0000000000 500951 O0 000 O0 0 6 ! 1 4 68 0000000000 500951 O0 OOO O0 0 6 1, 1 4 68 0000000000 500951 O0 000 O0 0 6 1 ! 4 68 0000000000 500951 O0 000 O0 0 6 1 1 4 68 0000000000 500951 O0 000 O0 0 6 1 1 4 68 0000000000 500951 O0 000 O0 0 6 1 ~ 4 68 0000000000 500951 O0 000 00 0 6 I 1 4 68 0000000000 500951 O0 000 O0 0 6 ! 1 4 68 0000000000 500951 O0 000 O0 0 6 1 ! 4 68 0000000000 500951 O0 000 O0 0 6 1 1 4 68 0000000000 500951 O0 000 O0 0 6 1 1 4 68 0000000000 500951 O0 000 00 0 6 ! I 4 68 0000000000 500951 O0 000 O0 0 6 1 1 4 ' 68 0000000000 500951 O0 000 O0 0 6 1 1 4 68 0000000000 500951 O0 000 0() 0 6 1 I 4 68 0000000000 500951 O0 000 O0 0 6 ! 1 4 68 0000000000 500951 O0 000 O0 0 6 t I 4 68 0000000000 500951 O0 000 O0 0 6 1 I 4 68 0000000000 500951 O0 000 O0 0 6 1 1 4 68 0000000000 500951 O0 000 O0 0 6 1 i 4 68 0000000000 * * D A T A * * DEPT 9512.000 SDST'PNAV:. 0.:475 TPAT.PNAV 1.625 TCFD.PNAV 7434.809 !NFD.PNAV 369.71~ G]~CH.TDTP m999.~50 $ IC~'~, PNAV 1B.716 $IGC.PNAV 1 66I $~3HN,PNAV 49.877 SBHF.PNAV 42:959 T "PNAV 11208.014 TCA~V. PNAV ~5906.867 'CA~ · SCN.PNAV 5397.936 TSCF,PNAV 2334.57~ BACK.TDTP 109,463 ~'B C TC~P 26.622 $IMM.PNAV TPHI.PNAV TCND.PNAV INND.PNAV TENS.TDTP 68 335 24:297 23352.645 2152.559 1195'000 ,I$ Tape Verificat~.on [~iSt~DO ichlumberger AlaSKa ComputinO Center ~-~AR-1995 !5:17 PAGE: DFPT. 9500.00o $1G~!.PNAV SDSI.PNAV 0.457 ~BHN.PNAV TRAT.PNAV 1.86~ TC~.PNAV TCFD.PNaV 77~9.7~2 TOCi~.PN~V INFD.PNAV 3~b.1~8 SACK.TDTD G~CM.TDTP -999.~50 DEPT. 939!.00U SIG~.P~AV SDS~.PNAV 0.487 SBMN.PNAV TRAT.PNAV 1.846 TCAN.PNAV TCFD.PNAV 6392.307 TSCN.PNAV INFD.PNAV 370.757 BACK.TDTP G~C~.TDTP 45.965 END OF DATA i~.356 SIGC.PNAV q0.943 SBHF.PNAV 31879.~68 TCAF.PNAV 6717.959 TSCF.PNAV 4~.0u3 FBAC.'~DTP 18.4~8 SIGC.PNAV bL.568 SBHF.PNAV 25656.402 TCAF.PNAV 5257.486 TSCF.PNAV 58.~4 FBAC.TDTP 2.363 SIBH.PNAV 33.066 TPHI.PNAV 12222.469 TCND.PNAV 2575.088 INND,PNAV 10.890 TENS.TDTP 47:.t4~ TPHI.PNAV 9931.05] TCND.PNAV 2034'989 INND.PNAV 16.683 TENS.TDTP 46.086 29.560 25802.449 2143.683 1190.000 88.586 31.857 22006.355 ~387.916 1095.000 **** FILE TRAILER FTLF NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DAT~ : 95/03/ 2 MAX REC SIZE : 1024 FIL~ TYPE : L~ST FILE : **** FILE HEADER FILE NAME : EDIT .007 SERVICE : FLiC V~RSION :OO!COl DATE : 95/03/ 2 FIL~ TYPE : LO LASTFILE : FILE HEADER FILE NUMBER RAW Ct. IRYES Curves add DEPTH INCREMENT: F!LF SUMMARY VENDOR TOOL CODE $ log header data for each 1 0,50 O0 START D~PTH 9530,5 pass in separate STOP DEPTH files: raw background pass in last IS Tame Verlflcation Listing chlumbe.roer AlasKa Computino Center 2-MAR-1995 15:17 19 LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TI~E LOGCER ON TI) DRILLER (FT): TD LOGGER(ET): TOP LO~ INTERYAb (ET): BOTTOM LOG INTERVAL I,OGGTNG SPEED (FPHR): DEP'rN CONTROL !!&ED (YES/NO): 17-JAN-95 38.2 1016 9518.0 9518.0 9390.0 9512.0 ~800.0 17-jAN-g5 TOOL STRING (~OP VENDOR TOOL COOE TOOL TYPE TDTP TDT~ TDTP TDTP $ Pf!LSE NEUTRON TOOL ~U~BER CGRS-A-S62 CPSC-A-867 TNC-P-!4! TND-P-75 TNG-P-236 9643.0 BOREHOLE AND CASING DATA OPEN HOLE B!'r SIZE DRILLERS CASING DEPT~{ (FT): LOGGERS CASING DEPTH (FT): BO~EHOLE CONDITIONS FLUID TYPE: FLUID OENSITY SURFACE TEMPERATURE (DEGF): BOTTO~ MOLE TEMPERATURE (DEGF): FLUID SALINITY FL!~ID LEYEL (FT): FLUID RATE AT WELL}lEAD WATER CUTE (PCT): GAS/OIL RATIO: CMO~E NEUTRON TOOL TOOL TYPE (EPITNERM~b O~ THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE CO!)~!T RATf] NORi~A[,IZATIt]N TOP NORMALIZING WINDOW BASE NORmALIZiNG WIND[~W (FT): ~L!JELtNE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS)~ FAR COUNT RATE HIGH SCALE NEAR COOMT RATE LOW SCALE (CPS): NEA~ COUNT RATE NIG~ SCALE (CPS): CRUDE -!2.0 1.94.0 NEITHER SANDSTONE 2,65 0 !3000 0 32000 TOOL STANDOFF (IN): IS Tape Yer~ficatlon I~istinq CblUmberger AlasKa Computinq Center 2-~AR-1995 15:!7 PAGE~ 2O Rt~ARKS: TIED IN Tt~ S~S BHC DATED 5-DEC-91. THE PURPOSE OF T}~IS hOG ~AS TO DETE~MI~!E IF GAS WAS PRESENT !~ 943~-9450' LR LOBE, TU OBTAIN BASE POROSITY, A~D TO DETERMINE FRaCTU~Ei hEIGHT WIT}{ BORAX. PUMPED ~10 BBLS OF CRUOM AT 3.5 BP~ PRIOR TO LOGGING DA$~L!NE PA$SF$. PU~PED JO0 BSL$ OF BORAXAND FOLLOWED ~ITH 60 BBbS OF CRUDE BEFORE LOGGING BORAX PASSES. bOGGED B~PA~ PASSES ,WILE ~U~PING AT .5 bPM. HAS IS PRESINT FRO~ 9438' TO 9450' bORAX IS !NDICAT~]D FRO~ 9485' TO 9504''ME ~ ~0 FORMATION A MO~¢ I~}DYCAT!ON OF FORMATION ~ORAX IS PRESENT FRO~ 945~' YO Q477', $ LIS FORMAT OATA ** DATA FORMAT SPECIFICATIOM RECORD ** ** SET TYPE - 64~B ** TYPE REPR CODE YAbUE 2 66 0 3 73 260 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT It 66 3 1~ 68 1,3 66 0 14, 65 FT t5 66 68 16 66 1 0 66 I ** SET ~'YPE - CHAN ** ID ORDER # LOG TYPE CbASS ~OD NUMB SAMP EbE~ CODE (HEX) DMPT FT 500951 O0 000 O0 0 7 I I 4 68 0000000000 $IG~ P$1 Ct] 500951 O0 000 o0 0 7 1 i 4 68 0000000000 STDT PS! 500951 O0 000 O0 0 7 1 1 4 68 0000000000 TD~{I PS! PU 500951 O0 000 O0 0 7 1 I 4 68 0000000000 ISHU PSI ~ 500951 O0 000 00 0 7 I 1 4 68 0000000000 SFF~ PSl, CU 500951 O0 000 O0 0 7 1 I 4 68 0000000000 IS Tame Verification t, istlnq chlumberoer AlasKa Computimo Center 2-~AR-1995 15:17 21 '''NAMF ......~oER.~-';''~-'I';~'-'~''''~;~NI MER A .... AP~'';;~'~i~''~MB NUmB .......... SIZE R~'''PR .... PROCESS'''''''' ID ORDEP ~ bOG TYPE Ct, ASS MOD NUmB SAMP ELEM CODE (HEX) SFND PS1 CU 500951 00 000 oo o 7 1 1 4 68 SBHF PS1. CU 500951 O0 000 O0 0 7 1 1 4 68 SBHN PS1 C~! 500951 0o 000 00 0 7 I 1 4 68 FTDT P81 CPS 5(,0951 00 000 00 0 7 I 1 4 68 NTDT PS1 CPS 500951 O0 000 00 0 7 1 1 4 68 AFFD PS1 CPS 500951 O0 000 00 0 7 1 1 4 68 A~FD PSI CPS 500951 00 000 00 0 7 1 1 4 6~ AFND PSi CPS 500951 00 000 O0 0 7 1 I 4 68 ABND PSt CPS 500951 00 000 ~0 0 7 1 1 4 ~8 SIGC PS~ CIl 500951 00 000 O0 0 7 1 1 4 68 $IBH PSi CU 500951 00 000 00 0 7 1 I 4 68 ~0~ PSI 500951 00 000 O0 0 7 1 1 4 68 TPAT PS1 500951 O0 000 00 0 7 1 1 4 68 SDSI PSI CU 500951 O0 000 00 0 7 1 1 4 68 B~C~ PSi CPS 500951 O0 000 00 0 7 1 I 4 68 FBAC PS! CPS 500951 00 000 00 0 7 i 1 4 68 TCAN PSI. CPS 500951 00 000 O0 0 7 1 I 4 68 TCAF PSI CPS 500951 O0 000 O0 0 7 1 t 4 68 TCND PS{ CPS 500951 00 000 00 0 7 1 1 4 68 TCF'D PSi CPS 500951 00 000 00 0 7 1 1 4 68 TSCN PSi CPS 500951 O0 000 O0 0 7 1 I 4 68 TSCF PS1 CPS 500951 O0 000 O0 0 7 I 1 4 68 INND PS1 CPS 500951 ~0 000 O0 0 7 1 I 4 ~8 INFD PSI CPS 500951 00 000 O0 0 7 1 1 4 68 LC0i PS1 500951 00 000 00 0 7 1 I 4 68 RN1 PSi CPS 500951 00 000 00 0 7 1 1 4 68 RN2 P$~ CPS 500951 0o 000 00 o 7 1 1 4 68 RN3 PS! CPS 500951 00 000 O0 0 7 1 1 4 68 RN4 PS1 CPS 500951 00 000 00 0 7 1 1 4 68 RN5 PSI CPS 500951 0o 000 00 0 7 1 1 4 68 RN6 PSi CP6 500951 O0 000 00 0 7 1 t 4 68 RN7 PS! CPS 500951 00 000 o0 0 7 I I 4 68 RN8 PS1 CPS 500951 O0 000 00 0 7 I 1 4 68 RN9 PS1 CPM 500951 OO 000 O0 0 7 I I 4 68 RNI0 PSi CPS 500951. 00 000 O0 0 7 1 1 4 68 RNlt PS! CPS 500951, O0 000 oo 0 7 I i 4 68 ~Ml~ PS1 CPS 500951 O0 000 O0 0 7 1 I 4 68 RN13 P$1 CPS 500951 00 000 00 0 7 1 I 4 68 RNi4 PSI CPS 500951 00 000 O0 0 7 1 1 4 68 RS15 PS1 CPS 500951 00 000 00 0 7 1 I 4 68 RN16 PS! CPS 500951 00 000 O0 0 7 1 1 4 68 ~F1 PS1 CPS 500951. O0 000 O0 0 7 1 I 4 68 RF2 PS! CPS 500951 00 000 00 0 7 I 1 4 68 RF3 PS1 CPS 500951 00 000 00 0 7 1 i 4 68 Rw4 PS1 CPS 500951 00 000 O0 0 7 I i 4 68 RF5 PS1 CPS 500951 00 000 O0 0 7 I 1 4 68 RF6 PSI CPS 500951 00 000 00 0 7 1 I ~ 68 RF7 PS1 CPS 500951 00 000 00 0 7 1 1 4 68 RF8 PS! CP6 500951 00 000 00 0 7 ! ! 4 68 RF9 PS1 CPS 500951 00 000 O0 0 7 ! i 4 68 RF10 PS1 CPS 500951 O0 000 O0 0 7 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O0000000OO 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Tame verificatl, on Listino chtumherger AlasKa Computinq Center 22 RF12 PSl CPS RFI~ PS1 CPS RFi~ PS~ CPS ~F!5 PS1 CPS R~I~ PSI CPS TENS PSI bB m*mmmmmmmmmmmmmmmmm~mmmmmmmmm SERVICE APl AFl AP1 API F [!RDE~ ~ bOG TYPE CLASS ~OO N [ ........................... 00951 O0 000O0 0 500951 O0 000 O0 0 7 5009~ nO 000 O0 0 7 ~00951 O0 000 O0 0 7 500951 O0 OOU O0 0 7 500951 O0 000 O0 0 7 ILE NUMB NLj~B SIZE REPR PR C UMB 8A~P ELE~ CODE fHE 1 1 4 68 o0o00_ 1 I 4 68 00o000 1 I 4 68 000000 1 1 4 68 000000 1. 1 4 68 000000 1 1 4 68 000000 oo ooo oo o 1 4 .o2o..oo.o- DFpT. g530.500 ISHU.PS! 37.906 SBHN.PS1 72.718 ABFD.PS1 1,148 SIBM.PS! 90.354 BACK.PSI 15.359 TCND.PS! -174.0gl INND,PSI. -0.5~2 RNa.PSI 77.515 RN6.,PSI 1699.078 RNIO,PS1 1921.301 RNI4,PS1 21.29.635 RF~,PS1 23.851 RF6.PS1 462.964 RFI~,PS! b34.261 RF1 ,PS1 91b.669 GR,PS! 53,750 DKPT. 9500,000 ISHU,PS1 39.500 SBMM.Ps1 39.333 ABF'D.PS1 13!.439 SIS~.:PS! 41.541 ~AC~,PS1 _ 41'566 ~CND,PS1 29336,930 INND.PS1 2225.4!4 RNa.PS1 29.807 RN6.P$I 1796.56.6 RMIO.PS1 2002'870 RNi.~,PS1 32~4.908 PF~..PSI ~.4.471 RF6,PS1 563.039 RF10,PSI 683.383 RFI4.PS1 1212.037 G~,PS! SIGM.PS1 23.938 STDT.PS1 66.000 TPHI.PS1 SFFO.PS! 25.282 SFND.PS1 28.839 SBMF.PS1 FTDT.P$1 0.000 NTDT.PSI 0 000 AFFD.PS{ AFND.PS1 43.~33 ABND.PS1 3~803 SIGC.PS1 ~MOF.PS1 -0.047 TROT.PS1 0.000 SDSI.PS1 FBAC.PS1 10.652 TCAN.PS! 0.000 TCAF.PS1 TCFD.PS1 '-115.145 TSCN.PS1 0 000 TS[F,PS1 !NFO.PS1 -0.362 LCOI,PS1 0~000 R 1.P$I RN3.-PS1 1143.521 RN4'PS1 1523~ 152 RNS,PS1 RN7.PSI 1087,966 RNS.PS1 916.669 RNg..PS1 Rail.PS1 2717.599 RN12.PS1 2782,414 RN13,PS1 ~IS.PSi 1,!52.78t RN16.PsI 458.334 RFI~PS1 RF3.PS1 287.:038 RF4,PS1 416 668 RF5.PSI RF7*PS1 365,742 RF~.PSI 314~816 RF9.PSI R.F~.I:.,PSI 893.52l RF12.PSI 1018.521 RF13.PS1 ~:FI..5*PS1 532.409 RFI6.PSI 171.297 TE~S,PS1 $IG~.PS1 SFFD.PS1 FTOT.PS! AFND.PSI M~OF.PSt FBAC.PS! TCFD.PSi iNFD.PSI RN3.P$1 RN7,PSi RNll,PSi RN15-PS1 RF3.PS1 RF7-PS1 PFll.PS1 RFI5.PSI 16.0bO 18.073 13,319 506.335 1.026 11'571 9068,740 402.070 988 541. 1293 699 3107 458 1878 228 40~.~I0 !010.031 734.05g STDT'PS1 66.000 TPH!.PS! SFND.PS1 ]0,248 SBHF.PS1 NTDT.PSI 9.049 AFFD,PS1 a~.~,PSl 477,221 SIGC.PS! TRA .PSi 1,932 TCAN.PS1 39911.672 TCAF,P51 TSC~.PS1 8765 439 TSCF,PS1 [.,CO1.PSi 2i617 RN!.PSi RN4.PSI 1328 .083 RNS.P$1 RFB,PS1 330 46 RF9,P$1 RF12,PS1 11.73,355 RFI3*PS1 RF16-PSI 270,774 TENS.PSI 0000 0000 0000 0000 0000 0000 o..o.o£.. 0.000 60 600 17~704 1.344 1.982 0.000 0.000 819.446 1,513!893 1884 264 2662.043 277.778 416,668 638.890 995 O0 29.097 29.053 0.318 15251'479 3349.544 825.2~7 1530.090 1856'738 3756,456 309'456 391,.118 623,211 1246.421 1190'000 IS Tame Verif~.cat!.on Listino chlumberger Alaska Computlnq Center ~-~AR-1995 15:1.7 PAGE: 23 DEPT. 9351.500 $IG~q. PS1 ISHU,P$1 47.500 SFFD.PS1 SBHM,PS1 51,977 FTDT.PS1 ABFD,PS1 114.062 AFND,PSI SIB~,PS1 79.896 H~OP".PS1 BACh.PS1 57,192 FBAC.PS1 TCND,PS! 18150.246 TCFD.PS1 IMND,P$1 2391.877 INFO.PS1 RN~oPS1 49.932 RN3,PS1 RN6,PS1 14K0,004 RN7.PS1 RMIO,PS1 lb36.671 ~Mll.PS1 RNI4,DS1 1010,00] ~F2.PS1 1.4.266 RF3,PS1 RF~'PS1 440.001 RF7.PS1 RFIO,9S1 536 ~68 .6~1 PS1 RFI4,PS1 430.001 GP,PSI. 33.2~9 30.32~ STDT.PS1 3~.~06 SFND.PSI 7.~27 NTDT,PS1 448.863 ABNO,PS1 1.!06 TRAT,PS1 16.899 TEAm.PS% 5440.0b0 TSCN.PS1 424.234 LCO1,PSI I080.003 RN4,P&! 773.335 RNS.PS1 2263.339 ~N12.PS1 410.001 RN16.PS1 310.00! RF4,PS1 ~70.001 RFS,PS1 i531334 mF16,PS1 66.0U0 TPHI.PS1 32,433 SBHF.PS1 19.70] AFFD,PS1 443.194 SIGC,PS1 I 569 SD$I,PS1 28327:203 TCAF.PS1 2761.164 TSCF.P$1 2,651 RNI,P$1 1446.670 RN5,P$1 916.669 RN9,PS1 1993.338 ~N13.PS1 223,334 RF~,PS1 403.334 RFL,PS1 340,001 RFg,PSi 710,002 RF1]oPS1 60,000 TENS,PS! 36,1~2 53,583 106,172 0,783 0,549 10256,635 1041,422 896,669 1473,337 1676,67! 162~ 337 3~3~334 526,668 550,001 1090,000 ** ENO OF DATA ** **** FILM TRAILER **** FILE NAME : EDIT .007 S~RVICE : FLIC VERSION : O0~CO1 D~'rE : 05103/ 2 ~AX REC SIZE : !024 FILM TYPE : LO L~ST FILE : **** FILE HEADER **** FILE NA~E : EDIT ,008 SERVICE : FLIC VERSIO~ : 001. C01 DATE MAX REC SIZE : FIL~ TYPE : bO L~ST FII,E FILE HEADER FILE NUMBER 8 R~AW CURVES Curves and log header data for PASS NL.}~BER: 2 DEPTH INCREMENT: 0,5000 FTL~ SUMMARY VENDOR TOOL CODE START DEPTH each mass in separate STOP DEPTH illes; raw Oackoround pass in Tape Verification .chlumberqer AlasKa Computind Center 2-~AP.-~ 99b !5:!7 PAGE: 24 TOT? $ bOG HEADER DATA 9524.5 DATE LOGGED: SOFTWAPE VERSION: q'I~E LOGGER ON BOTTO~: TD DPIbLER TD TOP LOG INTERVAL Bf]TTDM LOG INTERYAL LOGGING SPEED (FPHR)~ DEPTH CO~!TRUL !!SED (YES/NO): 9353,5 17-JA~-95 38,2 ~047 9518.0 951B,0 9390,0 951~,0 !,800.0 17-JAN-95 TOOL STRING (TOP T(] BOTTOM) VENDOR TO~L CODE T~OL TYPE TDTP TDTP TDTP TDTP TDTP $ .. I) NEUTRON PULSED NEUTRON PULSED NEUTRON PULSED NEUTRON PULSED NEUTRON ~O~EMOLE AMD CAS'lNG DATA OPEN HOLE BIT SIZE (IN)= DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): BDREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURF.ACE TEMPERATURE (DEGF): BOTTO~ HOLE TEMPERATURE (DEGF): FLUID SALINITY FLUID LEVEL (FT): FLUID RATE AT ~ELLHEAD fBPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE NEUTRON TOOL TOO!, TYPE (EPITHERMA6 OR THERMAL): MATRIX: RATRI× DENSITY: HOLE CORRECTION (IN): NEITHER SANDSTONE 2,65 ~LUELINE COUNT RATE SCAbFS SET BY FIELD ENGILiEER FAa COI.)N~ RATE LOW SCALE (CPS): 0 FAR COUNT ~ATE HIGH SCALE (CPS): 13000 HEAR COUNT RATE .b~J~ SCALE (CPS): 0 TOOL NIIMBER CGRS-A-862 CPSC-A-867 TNC-P-141 THO-P-75 TNG-P-236 9643,0 CRUDE -12.0 t94.0 BLUELINM COUNT RATE N~IRMALIZATiOI~ IN OIL ZONE TOP NORMALIZING WINDOW BASE NORmALiZING ~INDOW I$ rape VerJ. f..!cation Listlnq chlumberger Alaska Computinq Center 2-MAR-~995 15:17 NEAR COUNT RATF HIGH SCA;.E (CPS): TOOL STAMDOFF (IN): R~ARKS: 32000 TIP. i!) !$ TO SNS BHC DATED 5-DEC-91, THE PURPOSE OF THIS bOG ~AM TO DETEP~INE IF GAS WAS P~ESENT I~.~ 94BB-9450' L~ LUBE, TO OBTAIN BASE POROSITY, AND TO OETER~qINE FNACTURE HEIGHT WITH ~ORAX, PU~qPED 210 B~LS OF CRUDE AT 3,5 ~P~ PRIOR TO [~OGG!NG BASELINE PASSFS, PUMPED ]00 BBLS OF BORAXAND FOLLOWED wITH 60 BBLS OF CRUDE BEFORE L~GG!NG BORAX PASSES, bOGGED..- BORAX PASSES W~!I,g PU?~PlNG AT ,5 BPS, MAS IS PRESINT FRO~q 9438' TO 9450' SOME FORMATION BORAX IS INDICATED FROM 9485' TO 9904' A MORE ROBUST INDICATION flF F{)~ATiON BORAX IS PRES.{NT FRO~ 94~4' TD 9477', LIS FORMAT DATA PAGE: 7,5 ** DATA FORMAT SPECI~!CATI~]N ~ECORD ** ** SET TYPE - 64EB ** TYPE REP~ CODE ~A~UE t 66 0 2 66 0 3 7] 26O 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1! 66 3 !.2 68 1~ 66 0 ~4 65 FT 15 66 68 16 66 0 66 ** SST TYPE - CMAN ** .......................,,.......,.,..,....,,,-,,........................--.-.......-... NAME SERV UM!T SERVIC ....... APl P PI bE NU~ N:U~ SIZE REPR PR[JCgS$ ID ORDE~ # bOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DMPT FT 500951 O0 000 O0 0 8 I I 4 68 0000000000 S.!G~ PS2 CU 500951 O0 000 O0 0 8 ! I 4 68 0000000000 STDT PS2 500951 O0 000 O0 0 8 I I 4 68 0000000000 IS Tame Verification Listimo chlumberger AlasKa ComputinO Center 2-~-'iAR- 1995 15:17 PAGe: 26 Ti) ORDER ~ LOG TYP~ CLASS MOD NUmB SAMP ELFM CODE (HEX) mmmm mmm mmmmmMm mm Immmmmmmm mMmm mmmmmm~mmmm mmmmm /mmm m ~m Mm m oo o 0 _ 0 ISHU P$2 V 500951 O0 000 O0 0 g 1 I 4 6~ SFFD PS~ CU 500951 O0 00o O0 0 8 1 I 4 68 SFND PS2 CU 500951 O0 000 O0 o 8 1 I 4 68 SB~r PS2 CU 500951 O0 000 O0 0 8 1 1 4 68 SBHN PS~ CU 500951 O0 000 O0 0 B I i 4 68 YTDT P$~ CPS 500951 O0 O00 O0 0 8 1 1 4 68 NTDT PS2 CPS 500951 O0 000 O0 0 8 1 1 4 68 AFFD PS~ CPS 500951 O0 000 O0 0 8 1 1 4 68 ABFD PS2 CPS 500951 00 000 O0 0 ~ 1 1 4 68 AFND PS2 CPS 500951 O0 000 O0 0 8 1 l 4 68 ABND PS2 CPS 500951 O0 000 O0 o 8 1 1 4 68 SIGC PS2 CU 500951 O0 o00 O0 0 8 1 ! 4 68 SIBH PS2 CU 500951 O0 000 O0 0 8 1 1 4 68 M~OF PS~ 500951 00 000 00 0 8 I ! 4 68 TRAT P$~ 500951 O0 000 O0 0 8 1 1 4 68 SDSI PS~ CU 500951 O0 000 O0 0 8 1 1 4 68 BAC~ PS2 CPS 500951 O0 000 O0 0 8 I 1 4 68 FBAC PS2 CPS 500951 O0 000 O0 0 a ! I 4 68 TCAN PS2 CPS 500951 O0 000 O0 0 8 1 I 4 68 TCAF P$2 CPS 500951 O0 000 O0 0 8 1 1 4 68 TCND PS2 CPS 500951 O0 000 O0 0 8 1 I 4 68 TCFD PS2 CPS 500951 O0 000 oO 0 8 1 1 4 68 TSCN P$2 CPS 500951. O0 000 O0 0 ~ ! 1 4 68 T$CF P$2 CP~ 500951 00 0o0 OO 0 8 1 1 4 68 INND P$2 CPS 500951 O0 000 O0 0 8 1 1 4 68 INFD PS2 CPS 500951 O0 o00 O0 0 8 1 I 4 68 ~C0! P$2 500951 O0 000 O0 0 8 1 i 4 68 RN1 PS~ CPS 500951 O0 000 O0 0 8 1 I 4 68 RN2 PS2 CPS 500951 O0 000 O0 0 ~ 1 I 4 68 RN3 P$2 CPS 500951 O0 000 O0 0 8 i I 4 68 RN4 952 CPS 500951 O0 000 O0 0 8 1 ! 4 68 RN5 PS2 CPS 500951 O0 000 O0 0 8 1 I 4 68 RN6 PS2 CPS 500951 O0 000 O0 0 B I ! 4 68 RN7 P$2 CPS 500951 O0 000 O0 0 8 1 1 4 6~ RN8 PS2 CPS 500951 O0 000 O0 0 8 1 I 4 68 RN9 PS2 CPS 500951 O0 000 O0 0 ~ ! 1 4 68 RNIO PS2 CP~ 500951 O0 000 O0 0 8 I I 4 68 RNll P82 CPS 500951 O0 000 O0 0 8 1 ! 4 68 RNt~ PS2 CPS 500951 O0 000 O0 0 8 1 I 4 68 RNI3 PS2 CPS 500951 OO 000 O0 0 8 1. I 4 68 ~N14 952 CPS 500951 O0 000 O0 0 8 ! 1 4 68 RN15 PS2 CPS 500951 O0 000 O0 0 8 i I 4 60 RN!6 PS~ CPS 500951 O0 000 O0 0 8 i I 4 68 RFI PS~ CPS 500951 O0 000 O0 0 ~ 1 1 4 68 ~2 P$2 CPS 5009:51 O0 000 O0 0 8 t I 4 68 RF3 PS~ CPS 500951 O0 000 O0 0 8 I I 4 68 RF4 P82 CPS 50n95t O0 000 oo 0 8 1 I 4 68 RF5 P$2 CPS 500951 O0 000 O0 0 8 I i 4 68 RF6 PS2 CPS 500951 O0 000 O0 0 ~ ! I 4 68 R~7 P$2 CPS ~00951 O0 000 o0 0 8 I 1 4 68 0000000o0o 0000000o00 0000000oo0 000000o000 00o0o00000 0000000000 0000000o00 0000000000 0oo0000o00 000000000o 0000000000 000o000o00 0000000000 00o0000000 0000o00000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 o000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 000000000o 0000000000 0000000o00 000000000o 000000000o 000o000000 0000000000 IS Tare Verification LtstlnQ cblumberger AlasKa Comuutin¢! Center 2-MAR-1995 15:17 PAGE: 27 RF9 PS2 CPS 500951 O0 000 RFIO PS2 CPS 500951 O0 000 RPll P$2 CPS 500951 O0 000 RFI~ PS~ CPS 500951 O0 OOO RPI~ PS~ CPS 500951, O0 000 RF14 P$2 CPS 500951 O0 000 RFI5 PS~ CPS 500951 O0 000 RFI6 P$2 CPS 500951 O0 000 T~N$ P$2 LB 500951 O0 000 GR PS2 GAPI 500951 O0 000 mmmmmmmmmmmmmmmm#mmmmmmm#mmmmmm CLASS MOD NUmB SA~P ELEM CODE (HEX) ''~. ............. 0 8 ~ ........... 1 ~ ..... ;'8 ................ 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 @ I 1 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 ~ 1 1 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 8 1 I 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 O0 0 8 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm D~PT, 0524,500 $IG~ PS2 ISNU,PS2 ~ 35.56,3 SPFD:PS2 SBHN.PS2 51.977 FTDT.PS2 ABFD,PS2 I~4.062 AFND.P$2 SIB~ PS2 79.896 ~MOF,PS2 BACK:PS~ 57.192 FLOC,PS2 TCND.PS2 18150,246 TCFD.PS2 INND.PS2 ~]91.877 IaFD.PS2 RN~,P$~ 196.163 RN3.PS2 ~N6,PS2 1698.466 RN7,PS2 RNIO,PS2 1,873.851 RNII,PS2 RN14,.P$2 2173.852 RN15.PS2 RF~,PS2 47,555 RF3.PS2 RF6.PS~ 498,463 RF7*PS2 RFi~,PS2 576,925 RFI, I,P$2 RFI~,PS~ 86,3.079 RFI5-PS2 G~,P$~ 95.698 ~[~T, 9500,000 SIGM.P$2 _.U:. P$2 41,031 SFFD.P82 S.,...t~.Bu~.p$2 39,393 FTDT,PS22 ABFD,PS2 115.883 AFND.PS SIBH.PS~ 4!.,719 MMOF:.PS2 BA. CK,P82 93,879 FBAC,PS2 TCND,PS~ ~5858,395 TCFD,PS~ INND,PS2 2197.357 INFD,PS2 ~N2,PS2 89,165 RN31PS2 ~N6:,PS2 175'6,004 RM7,P~2 RNiO*P~2 1956,005 R~I.I,PS2 RN!4,PS2 ~460,006 ~F~,~S~ ~6'750 R~.PS2 , '~F PS2 RF6,.PS~ 4~4 00! R 7, RFIO;PS~ 59~'00i RFIi,PS2 RFI4,PS2 964,002 RF15,PS2 G~,P82 95 6 8 30 32~ STDT. .PS2 66 000 TPHI.PS 31:106 SFND*PS2 32:43.3 SBHF,PS 7,127 NTDT.PS2 4!9.703 AFFD.PS2 448.8~3 ~BNI).PS2 ...43! 194 SIGC,P$2 I.~06 TRAT.PS2 I 569 SDSI,P$2 16.899 TCAN.PS2 28327 ~03 TCAF.PS~ 5440.080 TSCN.PS2 2761 164 TSCF,PS2 424,~34 LcOI.,PS2 21651 RNI,P$2 II~7.695 RN4.PS2 1509.23S RN5,P$2 11,76,926 RNSoPS2 835,~87 Rag P$2 2663.0a3 RN12,PS2 ;2796 30 RN13:P$~ 1361,542 RN16,P$2 821::~4! RFI.P$2 ~90.770 RF4,PS2 401.539 RF5.P$2 632.309 RF16,PS2 276.924 17 343 ST[. If, PS2 66.000 TPHI,P82 19.941 SFND,PS2 22.783 SB~F.P$2 11,687 NTDI' ,PS2 34,512 AFFD,P$2 430,6!5 ABND,P$2 466,018 SIGC,PS2 1.207 TRAT,PS2 1,865 SDS!.PS2 23.449 TCAN,PS2 33613,64! TCAF*.PS2 7792,491 TSCN,PS2 6884,730 TSCF.PS2 390,325 LCO1,PS2 2,585 RN!,PS~ 1076.003 RN4,PS2 !4t~.004 RN5.PS2 1216.003 RNS'PS2 892,002 RN9'PS~ 29~,0. 007 ~N12,P:S2 3200,008 RNI3,.PS~ 1312. 003 RN16,PS2 524,00~ RFI.PS~ 256.001 RF4,PS2 356,001 RFS'PS2 360.001 RFS,PS2 316,001 RFg,Ps~ 940.002 RF12.PS2 !024,003 RFt3.PS2 . , ~ { ~ ~ ' 596.001 RFI6,PS2 228 00! I ..... NS,PS~ 58 106,172 0,783 0.549 10256.635 ~041.422 853,848 1633 850 1869 235 ~635 391 272 308 438 463 600 Ol 1.040,000 28,493 33,928 101,006 2,585 :so6 162 004 1892,005 3!32'008 256°001 agS'O0& 1i2 003 1150,000 ,IS Tape Verification l~istin~ ;CblUmber~er AlasKa Comput~.nn Center 2-~A~-1995 15:!7 PAGE~ 28 DEPT, 9353.500 ISH{J,PS2 37,00o SEED.PS2 SBHN,P$2 68.580 FTDT,PS2 A~F~,PS~ 87,61] aFND,PS2 SIB~,PS~ 127,205 ~OF.PS2 BACW,PS~ 17().2~5 EMAC,PS2 TCND,P$2 13688.531 TCFD.PS2 IMND.PS2 ~931 351 INFD.PS2 ~2,PS~ 1~2[942 RNh,PS2 ~N6,PS2 ~25!.4]~ RM7,PS2 RM10,PS~ 14~7.146 RN~.I.PS2 RMI4.PS~ 698,573 ~N!5,PS2 ~F~,PS~ ~7,833 RFh.PS2 ~FS,PS~ 308,572 RF7.PS2 RFIO.PS2 347.~44 RFll,PS2 RF14,P$~ 214.2~6 RF]5,P$2 Gm,PS2 29.72~ STDT.PS2 31.834 ~FMO,PS2 4.415 ~TDT,PS2 49~.274 ABED,PS2 1.~74 TRAT,PS2 20,468 TCAN.PS2 3621.950 TSCN,PS2 369.78~ LC01,PS2 1020.O03 R~4,PS2 612.~59 RNS.P$2 1795.719 ~N12,PS2 398.572 RN16.PS2 26~.429 RF4.PS2 162 85~ RFS.PS2 471~430 RF12.PS2 ~28,572 RF~6,PS2 66.000 TPM!.PS2 3fi.~06 SBHF.PS2 12.408 AFFD.PS2 370.512 SIGC.PS2 1.463 SD$].PS2 ~4603,785 TCAF,P$2 1528,843 TSCF,PS2 2,426 RNJ,P82 1354,289 RN5.P$2 852,859 RNg,PS~ 1465.718 RN13.P8~ 360,001 RF1.P$2 304.286 RF5.P$~ 304,286 RF9.PS2 420.001 RF13.PS~ 102,857 TENS,PS2 32.965 58,439 71,265 2,111 0,763 5087,491 630,285 844,288 1178,574 1410.003 1118.574 248.572 312.858 411,430 381,430 1155,000 ** ENO OF DATA ** **** FILM TRAILER **** FILE NA~E : EDIT ,008 SERVICE : FLIC VERSION : 001C0! DATE : 95/03/ 2 MAX REC SlZ~ : !024 FIL~ TYPE : bO hAST FILE : **** FILE !~iEADER **** FILE NAME : EDIT ,009 SERVICE : FLIC VERSION : 001C01 DATE : 95/0]/ 2 MAX REC SIZ~ : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RaW CURVES Curves and log header data PASS NUMBER: 3 DMPTM INCREMENT: 0,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH for each pass in separate STOP DEPTH flles~ raw background pass in !astfi Tame Verlflcatlom Listin~ lumberger AlasKa Comput~n~ Center 2-MAR-lEg5 15:17 29 TDTP' ............. ' 95~7~ .... bOG HEADER DATA DATE LOGGED: SOFTWARE TIME LOGGED ON BOTTG~: TD DRILLER TD LOGGER(FT): TOP LOG INTEPVAL (FT): BOTTOM LnG INTERVAL LOGGING SPEED DEPTH Co~TRO~, I~$~D (YES/NO): TOOI~ ST~ING (TOP TO BOTTOM) VENDO~ TOOL CODE TOO[, TYPE TDTP TDTP TDTP TDTP TDTP PULSED NEUTRON PUbSED NEUTRON BOREHOLE AND CASING DATA OPEN MOLE BIT SIZE (IN): DRILLERS CASING DEPTH LOGGERS CASING DEPTH (FT); BOREHObE CONDITIONS FLUID TYPE; FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): bEVEL (FT)~- D · FLUID RATE ~T ~ATER CUTS (PET): GAS/GIb RATIO: C~OKE NEUTRON TOOL TOOL TYPE (EPITHE~MAL OR THERMAL): MATRIX: ~ATRIX DENSITY: HOLE CORRECTIO~ (IN): mmmmmmmmmm 9351,5 17-JAN-95 38.2 1054 9518.0 9518.0 9390.0 9512.0 1800.0 NO 17-JAN-95 TOOL NUMBER CGRS-A-86~ CPSC-A-867 TND-P-75 TNG-P-2]6 9643,0 CRUDE -12.0 194.0 NEITHER SANDSTONE 2.65 BLUEbINE COUNT RATE NORMALIZATION IN OiL ZONE TOP NORM.~DIZING W!NDO~ (FT): BASE NORMALIZING NINDUW (MT): BL!JELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT ~ATE LOW SCALE (CPS): 0 aTE dI(,~ $CALZ (CPS): 13000 FAR COUNT R~ "' ' . ..... IS Tame Verification Listinn chlumberger Alaska Computino Center 2-~AR-~.995 15:17 NEAR COUNT RATR LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF # RFMARKS: 32000 TIED IN TO SWS BHC DATED 5-DEC-q1. THE PURPOSE (OF T~IS LOG ~AS TO DETERMINE IF GAS WAS PRESENT IN 9438-9450' bR I, OBE, TO OBTAIN BASE POROSITY, AND TO DETERMINE FRACTUPE HEIGHT WITH BORAX PU~PED 210 B~LS OF"CRIiDE Al' 3,5 BPS PRIOR T6 LOGGING BASELINE PASSE~. PUMPED 100 BBLS OF BORAXAND FOLLOWED ~ITH 60 BBLS OF C~UDE BEFORE LOGGING BORA× PASSES, LOGGED BO~AX PASSES WM!LE PUMPING AT ,5 HAS IS PRESINT FROM 9438' %O g450' SOME BORAX .IS INDICATED FROM 9485' TO g~04', A MORE ROBUST INDICATION OF FORMATION BORAX IS PRESENT FROM 9~54' TO 9477', S LIS FORMAT DATA PAGE: 0 DATA FORMAT SPECIFICATION RECO~D ** ~* SET TYPE - ~4EB ** TYPE REPP CODE ~ALUE ! 66 0 2 66 0 3 73 260 5 66 6 73 7 65 8 68 0,5 9 65 il 66 12 68 13 66 0 i4 65 FT 15 66 6~ 16 66 0 66 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API APl API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EbE~ CODE (HEX) DEPT FT 50095~ O0 000 O0 0 9 I ! 4 68 0000000000 SIG~ PS3 CU 500951 O0 000 O0 0 9 ! I 4 68 0000000000 I$ Tare verification Listino chlumberger Alaska Compt]tino Center 2-~AR-1995 15:17 31¸ ORDER .~ b~G TYPE CbASS MOD MUMB SAt-~,P EbEM CUDE (HEX) STDT PS~ 500951 00 o00 00 0 g 1 1 4 68 TPHI PS~ PU 500951 O0 000 00 0 9 1 1 4 ~8 ISHI! PS3 V ~00951 O0 000 O0 0 9 1 1 4 68 SFF~ PS3 CIJ ~0095i 00 000 00 0 g 1 1 4 68 SFN~ PS3 CU 500951 O0 O00 O0 0 9 1 1 4 b8 S~HF PS3 CU 500951 O0 000 O0 0 9 I i 4 68 S~HM PS] CU 500951 00 000 O0 O 9 ! 1 4 68 FTDT PS3 CPS 500951 O0 000 00 0 g 1 1 4 68 NTDT P$3 CPS 500951 O0 000 O0 0 g 1 I 4 68 AFFD P$3 CPS 500951 O0 000 O0 0 9 1 I 4 69 ABFO P$3 CPS 500951 O0 000 O0 0 9 1 1 4 68 AFND P$3 CPS 500951 O0 000 O0 0 9 I I 4 68 ABND PS3 CPS 500951 O0 000 O0 0 g 1 1 4 68 S~GC PS~ CU 500951 O0 000 O0 0 q 1 1 4 68 8IB~ PS3 CU 500951 00 000 00 0 g ! 1 4 68 M~OF PS3 500951 00 000 00 0 9 I 1 4 68 T~AT PS3 500951 O0 000 O0 0 9 1 1 4 68 SDS! PS3 CU 500951 O0 000 O0 0 9 1 i 4 68 BACK PS3 CPS 500951 OO 000 O0 0 9 1 ! 4 68 FBAC PS3 CPS 500951 O0 000 O0 0 9 1 t 4 68 TCAN P53 CPS 500951 O0 000 O0 0 9 I 1 4 68 TCAF P53 CP6 500951 O0 000 O0 0 9 i I 4 68 TCND P$3 CPS 500951 O0 000 O0 0 g 1 1 4 68 TCFD P$3 CP6 500951 O0 000 O0 0 9 1 1 4 68 TSC~ PS3 CPS 500951 O0 000 O0 0 q 1 1 4 68 TSCF P$3 CPS 500951 O0 000 O0 0 9 1 ! 4 68 !NND PS3 CPS 500951 O0 000 O0 0 9 1 ! 4 68 INFD P$3 CPS 500951 O0 000 O0 0 9 1 I 4 6~ bCO! P$3 500951 O0 000 O0 0 9 I I 4 68 RN1 P83 CPS 500951 O0 000 O0 0 9 1 1 4 68 RN2 PS3 CPS 500951, O0 000 O0 0 9 1 1 4 68 RN3 PS3 CPS 500951 O0 000 O0 0 9 1 ! 4 68 RM4 PS3 CPS 500951 O0 000 O0 0 9 1 I, 4 68 RN5 P$3 CPS 500951 O0 000 O0 0 9 1 I 4 68 RN6 PS3 CPS 500951: O0 000 O0 0 9 1 1 4 68 ~7 PS3 CPS 50095! O0 000 O0 0 g ! 1 4 68 RN8 PS3 CPS 500951 O0 000 O0 0 9 ! ! 4 68 RN9 PS3 CPS 500951 O0 000 O0 0 9 1 1 4 68 RN10 PS3 CPS 500951 00 000 00 0 9 I t 4 68 RNI1 PS3 CPS 500951 O0 000 00 0 9 t I 4 68 RNI~ PS3 CPS 500951 O0 000 O0 0 9 1 1 4 68 RN13 P$3 CPS 500951, O0 000 O0 0 9 1 I 4 68 RM!4 PS3 CPS 500951 O0 000 O0 0 9 1 1 4 68 RN!5 PS3 CPS 500951 O0 000 O0 0 9 I ! 4 68 RN16 PS3 CPS 500951 O0 000 O0 0 9 1 1 4 68 RF! P$3 CPS 500951 O0 000 O0 0 9 1. I 4 68 RF2 P$3 CPS 500951 00 000 O0 0 g 1 1 4 68 RF3 PS3 CPS 500951, O0 000 O0 0 9 1 ! 4 68 RF4 PS3 CPS 500951 O0 000 00 0 9 1 ! 4 68 RF5 PS3 CPS 500951 O0 000 O0 0 9 I 1 4 68 RF6 PS3 CPS 500951 O0 000 O0 0 9 ! 1 4 68 0000000000 0000000000 0000000000 0000000000 OOOO0O0OOO 0000000000 OOOO0000OO 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0o0o00o000 000000000o 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000o00 0000000000 0000000000 00000o0000 0000000000 0000000000 0000000000 0000000000 0000000000 00000000o0 0000000000 0000000000 0000000000 000000000o 0000000000 O000000oo0 0000000000 wade Verification Listinn chlumberger AlasKa Computing Center 2-?4A.R-1.995 15:17 PAGE: 32 ORDEN # RE7 P53 CPS 500951 RF8 P53 CPS 50095i RF9 P$3 CPS 500951 RE10 PS3 CPS 500951 RFI] PS3 CPS 500951 RFI~ PS3 CPS 500951 RF13 PS3 CPS 50095! RFld PS] CPS 500951 RF15 PS3 CPS 50095! RF!6 PS3 CPS 500951 'r~N8 PS3 LB 500951 GP PS3 GAPI 500951 mmmmmmmmmmmmmmmmmmmmmmmmmm LOG TYPE CLASS MOD NUmB SA~P ELEM CODE (HEX) O0 000 O0 0 9 1 1 4 68 0000000000 O0 000 O0 0 g 1 1 4 68 0000000000 O0 000 O0 0 9 1 1 4 6~ 0000000000 00 000 00 O g 1 I 4 68 0000000000 O0 000 O0 0 g 1 1 4 6B 0000000000 O0 000 O0 0 O 1 I 4 68 0000000000 00 000 00 0 g 1 1 4 68 0000000000 O0 000 O0 0 0 1 1 4 6~ 0000000000 O0 000 O0 0 9 1 1 4 68 0000000000 O0 000 O0 0 g i 1 4 68 0000000000 O0 000 O0 0 9 I I 4 68 0000000000 O0 000 O0 0 9 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm DEPT. ISHU.PS3 ABED PS3 SIB~:PS3 BACK,PS3 TCND.P$3 INND.P$3 ~N6.P$3 RN10..PS3 RN14.P$3 RE6.P$3 RE10 PS3 RFI4. PS3 GR.PS3 DFPT ABFD,PS3 BACK,PS3 TCNDiPS3 INN~'P$3 RNa*PS3 ~6,Pg3 ~N10,PS3 ~14,P$3 ~F2 PS3 ~F~ PS3 RFI0 PS3 ~14 PS3 g527.000 30.063 68.580 87.61,] 127.205 120.215 13688.531 1,931.35i 208,052 1693.850 1864,6~0 2146,159 59,443 470,770 613.848 890,771 171,000 9500.000 34.031 39-320 11.9.209 4!.500 129,199 25442.!60 1982,1~5 120.373 ~772,004 ~956.005 2152.0o5 3i.208 512.001 652.0O2 920.002 SIGH.PS3 29.723 STDT.PS3 66.000 TP~.I.PS] SFFO.PS3 31.834 SEND.PS3 36 886 SBHF.P$3 FTDT*PS3 4.4!5 MTDT.PS3 12~408 AFFD.PS3 AFND.PS3 492.274 ABeD.PS3 370,512 SIGC.PS3 M~OF.PS3 1.274 TRAT.P$3 ! 463 SDSI.P$3 FaAC.PS] 20 468 TCA~ PS3 146031785 TCAF.PS3 TCFO.PS3 3621~950 TSCN.~PS3 1528.843 TSCF,P$3 !NED.PS3 369.7~2 LC01.PS3 2.426 RN1. PS3 RN3,P$3 11061.541 RN4,PS3 1523.081 RNS:P'$3 RM7.P$3 1186o157 RNS'PS3 867.694 RN9,P$3 RN!I-PS3 2570.775 RNI2,P$3 2663,083 RN13.P$3 RNI5.PS3 I384.619 RN16,PS3 890771 RFI'P$3 RF3,PS3 295'385 RF4,Ps3 396~924 RF5,PS3 RF7.PS3 369.232 RFS.P$3 295'385 RFg.P$3 RF!I,P$3 863.079 RFI2,PS3 950 772 RFI3 PS.3 RE15 PS3 5~1,540 RE16 e : . .Po3 309 232 TEN$iP$3 $IG~.PS3 i8.464 ,.I[.T.P$3 66 000 TPHI.P$3 $~FD,P$3 20.698 S~NL P$3 23~886 SBHF.P$3 FTDT.PS3 i1.'690 ~ ~'~ . · tTDI',P83 34 4~6 AFFD.P$3 AFND.PS3 448.893 ABNU.PS3 466.376 $IGC.P$3 MHOF.PS3 1.177 TRAf. P$3 !,.824 SDSI.PS3 FSAC*PS3 33.0U6 TCAr.PS3q 31495'832 TCAF.P$3 TCFD,PS3 7730.205 T$CN.P~3 6552~350 TSCF.PS3 I~Fi)iPS3 376.824 bC01.PS3 21552 ~NI..PS3 RN3*PS3 1072.003 RN4,P$3 1464 eN'5*PS3 RNg.PS3 '004 RF3.P$3 248.00! RF4,.PS3 376:.~0! RF5,PS3 RF7'P$3 344,001 RF8..PS3 288.001 RF9,PS3 O' 'o ~Fil PS3 900.0 2 RF12 P$3 10 03 RFI3 PS3 RF15.P$3 504'001 RF1.6.PS3 2. ,*:~0112 TEN$..PS3 32.965 58.439 71.265 2.111 0'763 5087.491 630.285 81.6,925 !643~081 1740,004 2658..468 26~,078 433,847 618 463 960 28.436 34.!20 105,009 2'618 852,002 1636.004 18.4.8'005 2896.007 256.00~ 440'001 568,001 1084,003 1125'000 .I$ Tame verification bfstXnq .ChlUmherger AlasKa Com~utinQ Center !71.000 D~P? 9351,500 SI~?t. VS3 ISHU:PS3 36,031 SEED,PS3 SBHN,PS3 59,015 FTDT.PS3 ABED,PS3 109,220 AFND,PS3 6IBH.PS] 101,077 M~DF,PS3 BACK,PS3 127,658 F~AC.P$3 ICND.D$3 17480.551 TCFO.PS3 INN~,DS] 2112,54b INFDoPS3 ~N~.P$3 120.]73 R~JL,PS~ ~N6 PS] 1524.004 RN7.PS3 RNIO:PS3 1576.004 ~MII.PS3 RM14.PS] 956.002 ~N15.PS3 RFC*PS3 35,666 RFL,PS3 RFT,PS3 440,001 RF7,PS3 RFIO PS3 4~6,001 RElY,PS3 ~F14:PS~ 316.001 RF15.PS3 G~,PS3 60.~5 ** END OF DATA ** ~-~AR-1995 15:!.7 51,819 STDT.PS3 66,000 32,753 SFNDoPS3 34,525 5.734 NTDT,PS3 17,164 545o9~8 ABND,PS3 448,606 1.!~6 TRAT.PS] 1,645 3B.]~O TCAN.PS3 ~1~09,906 4795,450 TSCN.PS3 2259,465 3~.84] LCO1.PS3 2,840 1~,003 RN4,PS3 1476,004 844,002 RNB.PS3 880,002 2220.005 ~N!2.PS3 1904,005 520'00~ RN16,PS3 484,001 288.001 RF4.PS3 396,001 ~52.001 RES,PS3 300,001 6~0..002 RF!2.PS3 588 001 196.000 RF16.PS3 128]000 TPHI.PS] SBHF.P$] AFFD,P$] SIGC,PS3 SD$I.P$3 /CAF,PS3 TSCF.PS] RN~..PS3 RNg,Ps3 RN13.PS3 RFI.PS] RES.PS3 RFg,PS3 RElY.PS3 TENS.PS] PAGE: 33 4],237 50,678 102.804 0.934 0,726 6875,557 795,65b 840,002 1516,004 1692,004 ~492,004 268.00! 392,001 512,001 504.001 11~0.000 **** FILE TRAIbEP **** FILE NAME : EDIT ,009 SERVICE : FLIC VERSION : OO1CO1 DATE : 95/03/ 2 ~AX REC SIZE : ~024 FILE TYPE : LO bAST FILE : **** FILE HEADER **** FILE NAMM : EDIT ,010 SERVICE : FLIC VERSION : O01, COI D~TE : 95/0.3/ ~AX REC SIZE : 1024 FILE TYPE : LO b~ST FILE : F!bE HEADER FILE NUMBER RA~ CURVES Curves add log DEPTH INCREMENT: FILE ~SU~MARY 10 header data 4 0,5o00 ~or each pass in separate files,' raw bacK,round pass in 3N0% qIo N1 NOI£¥MIq¥~MO~ M~V~ £N1]03 0'~61 O'gt ×~HO~ §6-NVP-LI 9Fg-d-DN~ L98-V-OWdD ON O*OOBI 0'~6 0'06E6 0'8~6 0'8I~6 S6-NVD-L'[ :(NI) NOIJ~OMM~OO MqOH :A£i~N30 :(~¥~3H~ ~0 rI~3H~idM) 3dX~ qO0~ ~OO& NO~[IMN :Cid) q3A3q. OifiQA :3di~ Olflqd :(£M) H£dMQ DNig~3 98~qqI~O :(NI) 3Zi9 tI~ 3qOH N~dO V~¥Q 9Ni~¥D ON~ 3qOH3~O~ NOa£flMN O3~qBd $ 3dA& "IO0,L MOOD qo0~ ~OON3A (~[)iZO~ 0£ dO&) 9NIaZS qOoZ S'6~E6 mmmmmmmmmm H&d3O :(ON/~A) Oagl'~ qoaiNOO :(£j) q~Aa3~NI DOq dOA :(~/) 83qqlaO fl& :wO~J,O~ NO ~3DDOq :NOISHMA ¥£V0 ~3U~3H 90q 0'~[~6 ........... IS Tape Verlfication bistlnq chlumherqer AlasKa Compute, hq Center 2-~AR-J. 995 15:17 FAR COUNT RATE HIGH SCALE (CPS): NEAR COUntY RATE NEAR COUNT RATE TOOL STANDOFF (I~): RF~!~R~S: 30o0 TIED IN TO SdS BHC DATED 5-DEC-Q1, THE PURPOSE OF THIS LOG wA6 TO DETEPMINM IF GAS WAS PRESENT IN 94]8-9450' LR LOBE. T~ OBTAIN BASE POROSITY, A~!D TO DETERMINE FRACTUPE HEIGHT W!TM BORAX, PUMPED 210 B~LS OF CRUDE AT 3.5 BPS PRIOR TO LOGGING BASELINE PASSES. PUMPED 100 BBL$ OF BORAXAND FOLLOWED WITH 60 BBb$ OF CRUDE 8EFORE LOGGING BORAX PASSES. LOGGED BORAX PASSES WNILE PU~PING AT ,5 BPS. HAS IS PRES!MT FROM 94]8' TO 9450' SO~E F'OR~ATION BORAX IS INDICATEO FROM 9485' TO 9~04' A MORE ROBUST INOICATIUN OF FORmATIOn] ~ORAX IS PRESENT FROM 9454' TO 9477'. $ LIS FORMAT DATA PAGE~ 35 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** '''''''''''''''~;~TYPE 1, 66 0 2 66 0 3 73 260 4 66 5 66 7 65 S 68 0,5 9 65 FT 11 66 !2 68 13 66 0 14 65 ~T 15 66 68 16 66 0 66 1 IS Tape verification Listin~ chlumberger AlasKa Computinq Center 2-MAR-1995 15:17 PAGE: 36 STDT PS4 500951 O0 000 O0 0 10 1 1 4 TPHI PS4 Pt! 500951 O0 000 O0 0 10 1 1 4 ISHU PS4 V 500951 O0 000 O0 0 10 I i 4 SFFD PS4 CU 500951 O0 000 O0 0 10 1 1 4 SFND PS4 Cl.) 500951 O0 000 O0 0 10 I 1 4 SBHF PS4 CU 500951 O0 000 O0 0 !0 1 ! 4 SRHN PS4 CU 500951 O0 000 O0 0 10 1 1 4 FTDT PS4 CPS 500951 O0 000 O0 0 10 1 1 4 NTDT PS4 CPS 500951 O0 000 O0 0 10 1 ! 4 AFFD PS4 CPS 500951 O0 000 O0 0 10 1 I 4 ABFD PS4 CPS 500951 O0 000 O0 0 10 I I 4 AFND PS4 CPS 500951 O0 000 O0 0 10 1 1 4 ABND PS4 CPS 500951 O0 000 O0 0 10 1 1 4 $I(;C PS4 CU 500951 O0 000 O0 0 10 1 I 4 S!BH PS4 CU 500951 O0 000 O0 0 10 1. 1 .4 M~OF PS4 500951 O0 000 O0 0 I0 I 1 4 TRAT PS4 500951 O0 000 O0 0 I0 1 1 4 SDSI PS4 CU 500951, O0 000 O0 0 1.0 I I 4 B~Cg PS4 CPS 500951 O0 000 O0 0 10 1 ! 4 FBAC P$4 CPS 500951 O0 000 00 0 !0 1, 1 4 TCAN PS4 CPS 500951. O0 000 O0 0 10 1 1 4 TCAF PS4 CPS 500951, O0 000 O0 0 10 1 1 4 TCND PS4 CPS 500951 O0 000 O0 0 !0 1 1 4 TCFD PS4 CPS 500951 O0 000 O0 0 I0 1 I 4 TSCN PS4 CPS 500951 O0 000 O0 0 10 i ! 4 TSCF PS4 CPS 500951 O0 000 O0 0 10 1 1 4 INND P$4 CPS 500951 O0 000 O0 0 10 1 1 4 INFD PS4 CPS 500951 O0 000 O0 0 10 I 1 4 LCOI PS4 500951 O0 000 O0 0 10 ! 1, 4 BNi PS4 CPS 500951 O0 000 O0 0 10 1 ! 4 RN2 PS4 CPS 500951 O0 000 O0 0 10 1 1 4 RN3 P$4 CPS 500951 O0 000 O0 0 1.0 1 I 4 ~N4 P$4 CPS 500951 O0 000 O0 0 10 i 1 4 RN5 P$4 CPS 500951 O0 000 O0 0 !0 I I 4 RN6 PS4 CPS 500951 O0 000 O0 0 10 1 1 4 RN7 PS4 CPS 500951 O0 000 O0 0 10 I 1 4 RN8 PS4 CPM 500951 O0 000 O0 0 10 1 I 4 RN9 P$4 CPS 500951 O0 000 O0 0 10 ! 1 4 RNIO P84 CP6 500951 O0 000 O0 0 10 I I 4 BNIJ. PS4 CPS 500951 O0 000 O0 0 10 ! 1 4 RNI2 PS4 CPS 500951 O0 000 O0 0 10 1 1 4 RN13 P54 CPS 500951 O0 000 O0 0 !0 1 1 4 RN!4 PS4 CPS 500951 O0 000 O0 0 !0 I 1 4 RN15 PS4 CPS 500951 00 000 O0 0 10- ! I 4 RN1.6 PS4 CPS 500951 O0 000 O0 0 10 I 1 4 afl PS4 CPS 500951 O0 000 O0 0 !0 1 i 4 RF2 PS4 CPS 500951 O0 000 O0 0 10 ! 1 4 RP3 PS4 CPS 500951 O0 000 O0 0 10 ! I 4 68 68 68 68 68 68 68 68 68 68. 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 6.8 68 68 68 00000o0000 000o000000 o0000o0000 0o00000000 0000000000 0000000000 o00000000o 000000000o 0000000000 0000000000 O0OOO00O0O o000000000 0000000000 0000000000 000o000000 o000000o00 0000000000 0000000000 0000000000 0000000000 0000000000 00000000o0 0000000000 0000000000 0000000000 0000000o00 0000000000 0000000000 0000000000 0OO0OO0OO0 0000000000 0000000000 0000000000 000000:0000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ,IS Tare Verif!catlon Listino 2-~AR-1995 15:17 ;cblumberoer Alaska Computin~ Center 37 R D fORDER # LOG TYPE CbA$S ~OD NU~B SA~P ELEM CODE (HEX) I '~;~'';~.. .... ~;~ .................... 500951 00 000 ~. .... ~. ................................. 10 I I 4 68 0000000000' ..... ' .... RF5 PS4 CPS 500951 O0 000 O0 O 10 1 I 4 68 0000000000 RE6 P$4 CP6 500951 O0 000 00 0 i0 1 1 4 RF7 PS4 CPS 500951 00 000 O0 0 !0 I 1 4 RF8 PS4 CPS 500951 O0 000 00 O 10 1 I 4 RF9 PS4 CPS 500951 00 000 00 0 10 1 I 4 RFIO P$4 CPS 500951 00 000 O0 0 10 I 1 4 RFll P$4 CPS 500951 O0 000 O0 0 10 1 1 4 RFI~ PS4 CPS 500951 O0 000 00 0 10 1 I 4 RF13 PS4 CPM 500951 O0 000 O0 0 10 1 1 4 RF14 PS4 CPS 500951 O0 000 00 0 10 1 I 4 RFI5 PS4 CPS 500951 00 000 00 0 10 1 1 4 R~16 P$4 CPS 500951 O0 000 O0 0 10 1 1 4 TENS P$4 LB 500951 O0 000 O0 0 10 1 t 4 G~ PS4 G~P! 500951 O0 000 O0 0 10 I I 4 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 9532.000 $IG~,PS4 19.976 STDT,PS4 ISHU'PS4 53,656 SFFD:,PS4 21.141 SFND.PS4 SBHN,PS4 54,6~0 FTDT'PS4 9,227 NTDT.PS4 ABFD.ps4 !02,905 AFND,P$4 .483.998 ABND.PS4 SIB~.PS4 81.487 ~OF.PS4 1,!80 TRAT.PS~ BACK.PS4 266.404 FBAC.PS4 81.602 TCAN*P$4 TCND*PS4 19822,51,6 'PCFO,PS4 6349.680 TSCN,PS4 INND.P$4 2!01.394 INFD.PS4 360.205 LCOI,PS4 RN~.:P.S4 352.202 RN3,P~4 946.156 RN4,PS4 RN6,PS4 11.40,003 RN7,P$4 1024.618 RNS.P$4 RNIO PS4 1186.157 RN],I.PS4 172! 543 R'N12,PS4 RNI4:PS4 1..~69.235 RNIS.P$4 t546:158 RNI6,PS4 ~F2.P$4 98.082 RF3-PS4 235.385 RF4,PS4 RF6 P$4 364.616 RF7.,PS4 313,847 RFS..PS4 R~I.O:P$4 420,001 RFI1,P$4 609,232 RF12,P$4 RF14~Ps4 8~6.156 RF15.P$4 618.4~3 RF!b.P$4 GR.PS4 58,375 DEPT 9500.000 $I:GM.PS4 20,5'~6 STDT,PS4 ISHU".P$4 57,094 o~ FD....~ ,., 4 2!,167 SFND,PS4 .... . 'T PS4 5.604 NTDT.PS4 8BHN.P84 87 408 ABFD.. 84 64 798 AFN{'),PS4 249.i45 ABND.PS:~ STBH.PS4 I55,449 ~OF- PS4 1.14t, TRAT,PS4 BACK,PS4 201,348 FS~C.PS4 42.~93 TCAN,PS4 TCND,PS4 10863.688 TCFD, PS4 3819,837 TSCN,PS4 INN~,PS4 ~023,205 iNFO,PS4 348,445 LCOI,.PS4 ~N2.PS4 190.800 RN3'PS4 837.965 RN4,PS4 PN6.PS4 777.780 ~RN7.PS4 61! !13 RNS,PS4 ..... o4 856 484 :Ra:l 1,PS4 11'75:920 RN12.PS4 RNI4.PS4 ~.120,373 Rt~! 5,P.S4 875.002 RNI6,PS4 RF2.PS4 31.297 RF3,.PS4 227,794 F:Fg,PS4 66,000 23.488 23.781 412103 ! 628 23007 008 4601 764 2 320 1149 234 881 54! 1892 313 1329 234 281 539 313,8~7 696,925 456,924 66 000 22 201 12 525 257 200 1 51! 11448 629 2564 !56 2 !31 888 814 817 1!89 8t8 745.372 ~14.900 TPH!.P$4 SBHF,PS4 AFFD.PS4 SIGC'P$4 SD$!.,PS4 TCAF*PS4 TSCF.P$4 RN1.P$4 RN5.PS4 RN9.P$4 RN13.P64 RFI,P$.4 RFS'P$4 RF9.P64 RFI. 3'PS4 TENS.PS4 TPHI,PS4 $B~F.PS4 AFFD P$4 s cl s.4 SDSI,PS4 TCAF,PS4 TSCF,PS4 RNI.P$4 RNS.PS4 RN9.PS4 RN13.PS4 RF1.P84 RF5,PS4 950 !,128 0'575 9917'795 ~983.7~5 816,925 1112.3,11 '!241 542 2007 697 249 231 286 155 452.309 835.387 925.000 24.439 66.917 57,607 0.289 0'728 5372,175 1~03 09 73 ~50 837 965 967 595 !240.744 24~ 986 ~IS Tame verification bistin~ ;chl!]mberqer Alaska Computing CeDter PFC.PS4 236.390 RFT,PS6 RF!O.P$4 335.244 PFll,PS4 RF14.PS4 4~5,502 RF!5,PS4 GR,PS4 58.375 DEPT, 9349,500 SIGH.PS4 ISMU.PS4 67.063 SFFD,PS4 SBHN.PS4 61,511 FTDT,PS4 ABFD.DS4 106,012 AFND,PS4 S!BH.PS4 97,718 MMOF.PS4 BACK,PS4 222.198 FBAC,PS4 TCND.P$4 1478be826 TCFD.PS4 INND,PS4 1988.9~3 INFD,PS4 ~N~.PS4 2~4.568 RN3.PS4 R~6,PS4 ~.375.672 RN7.PS4 RNIO.PS4 14~7.81! RNll,PS4 RN14.PS4 ~066,847 RN!5.PS4 RF~,PS4 40,232 RF3,PS4 PF6,PS4 417.1~3 RF7.PS4 RFIO,P$4 497,3~7 RFI~,PS4 RFI4,PS4 393,049 RF15,PS4 G~,PS4 ~6,375 END OF DATA 2-~AR-!995 15:!7 227.794 RFS.PS4 44..6.992 RF~2,PS4 322.350 Rf'lS,PS4 26 580 STDT.PS4 291656 SFND.PS4 5.936 MTDT.PSg 595.403 ABND,PS4 1.0~6 TRAT.PS4 42.893 TCAN.PSq 47U6.241 TSCN,PS4 ]87,~0~ LCO1.PS4 1006.687 RN4,PS4 842.248 RNS,PS4 2001.342 RN!2oPS4 705.a84 RN16,PS4 ~72.728 RF4,PS4 192.514 RF16,PS4 305 158 ~Fg.PS4 472i781 RF13.P~4 180 516 TENS,PS4 66,000 TPHI.PS4 36.217 SBhF.P64 15.602 AFFD,PS4 358.787 $IGC.PS4 1.332 SDSI.PS4 18428.031 TCAF,P$4 195B.006 TSCF.PS4 2,!52 RNI,P$4 1247,329 RN5,PS4 862,302 RNg.PS4 1852.946 RN13.PS4 709.895 RFI.PS4 368,985 RFS.PS4 316.~46 RF9.PS4 573,531 RF13.PS4 140.375 TENS,PS4 PAGE: 361,032 532,953 1150.000 24 175 46:479 83,515 3.076 7122,286 909.654 842.248 1259.36t 1508.025 1451,875 300,~03 389.038 473,263 569.520 1160.000 38 **** FILE TRAILER **** FIb~ ~AME : EDIT ,010 SERVICE : FblC VERSION : OOlCOl D~T~ : 05103/ 2 ~AX REC SIZE : 1,024 FIL~ TYPE : !,,0 LAST FILE : **** FILE HEADER **** FILE NAME : EDIT ,0!! SERVICE : Fb!C V~RSION : O0!COI DATE : 95/03/ 2 MAX REC 5IZE : 1024 FILM TYPE : LO bAST FILE FILE HEADER FILE NUMBER II RaW CURVES Curves and log header PASS NUMBER: 5 data for each pass in separate files; raw background pass in last fi 2NOZ qIO NI 0'~6'[ O'gI= 0'E~96 ~WfiN qOO& ON 0'008I 0'06E6 0'8I~6 0'8I~6 :(£3) ~OONiai DNiZiqV~aON :($~) ~OONI~ DNIZI~V~aON dO~ qO0~ :Oi£~M qIO/9~'D :CtOa) ~lflD :(Ndd) A%iNiq~s 9NDI£IilNOD ~qOHMaO~ :CSA) H&d~.O DNISVD :(NI) 3ZI~ ¥iVQ DNigVD ON~ 3qOHM~O~ NO~Iti~N o~sqfld NO~£flSN O~Sqild Md~ qO0~ ~OOO qUO& aO~aZ^ :~ON/W3A) 03~ii qO~INOD :(£A) qVA~3iNI :CIA] ~¥~i ~Q~3H DOq ~'~I6 000~'0 6E :3DVd ul~s'lq uolTeDttI~el ~Oe£ SI :IS Ta~e Ver!,fication Listin~ chlumberger AlasKa Computino Center ~-~AR-19g5 15:!7 PAGE~ 4O nLI!ELINE COU~T RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SC~L~ (CPS): 13000 NEAR COUNT RATE [,,OW SCALE (CPS): NEAR COUNT RATE NIGH SCALf~ (CPS): 32000 TOOL STANDOF'F (,IN): TIED IN TO SWS OMC DATED 5-DEC-91, THE PURPOSE OF T}{!S LOG ~AS TO DETERMINE IF GAS WAS PRESENT I~ g438-9450' LR LOBE, TO OBTAIN BASE POROSITY, AND TO D£TSRMINE FRACTURE HEIGHT WITH ~ORAX. PUMPED 210 B~L$ OF CRUDE AT 3,5 BP~ PRIOR TO LOGGING BASELINE PASSE&. PUMPED 1o0 BOLS OF BORAXAND FOLLOWED wITH 60 BOLS OF CRUDE BEFORE LUGGING BORAX PASSES, bOGGED BORAX PASSES WHILE PU~iPING AT 5 OPM. HAS IS PRESINT FRO~ 943~' TO 9450'. ~']~E FORMATION BORAX IS INDICATED FROM 9485' TO q504'. A MORE ROBUST INDICATIO~ OF FORMATION BORAX IS PR~SE~T FROM 9454' TO 9477', LIS FORMAT DATA DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB *$ TYPE RgPR CODE VALUE 1 66 0 2 66 0 3 73 260 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT 11. 66 3 12 68 13 66 0 14 65 FT 15 6b 6B I6 66 ~. 0 66 ! IS Tame Verl. flcatlon Listing ,chlumberger AlasKa Computtn~,d Center 2-MAR-!995 I5:17 PAGE: 41 ** SET TYPE - CHAN ** NAMF SERV UNIT SERVI MB gB I R ., PR C ID ORDER # bOG TYPE CLASS MOD Nij~,b '~;;' .......... FT ' .................................. 500951 O0 000 O0 0 11 SANP ELFa CODE (HEX) 1 4 _ 00 ~IGM PS5 CU g00951 O0 000 00 0 STDT P$5 500951 O0 000 O0 0 11 TPH! PS5 pi! 500951 O0 000 O0 0 11 1 ISH[! PS5 V 500951 O0 000 O0 o ll 1 SFFD PS5 CI.! 500951 00 000 06 0 11 1 SFND PS5 CU 500951 o0 000 00 SBHF P35 CU 500951 O0 OOO O0 0 11 SBHN PS5 CU 500951 O0 000 O0 0 11 1 FTDT PS5 CPS 500951 o0 000 00 0 11 NTDT PS5 CPS 500951 O0 000 00 0 11 1 AFFD PS5 CPS 500951 O0 000 O0 0 11 1 ABFD P$5 CPS 500951 00 000 00 0 11 1 AFND PS5 CPS 500951 O0 000 00 0 11 1 ARND P$5 CPS 500951 O0 000 O0 0 11 1 8IGC P$5 CU 500951 O0 000 O0 0 11 1 SIB~ P$5 Cl.) 500951 O0 000 O0 0 11 1 ~OF PS5 500951 O0 000 O0 0 !1 1 TRAT PS5 500951 O0 000 O0 0 1! SDSI PS5 CIJ 500951 00 000 00 0 BACK PS5 CPS 500951 O0 000 O0 0 11 FBAC PS5 CPS 500951 O0 000 O0 0 11 TCAN PS5 CPS 500951 00 000 00 0 !1 1 TCAF PS5 CPS 500951 00 000 00 0 11 1 TCND PS5 CPS 500951 00 000 00 O TCFD PS5 CPS 500951 O0 000 O0 0 TSC~ P$5 CPS 500951 O0 000 O0 0 1I 1 TSCF PS5 CPS 500951 00 000 00 0 1! 1 INND P$5 CPS 500951 00 000 00 O 11 INFD PS5 CPS 500951 0o 000 00 0 !1 1 LCO1 PS5 500951 O0 000 O0 0 11 RN1 PS5 CPS 500951 O0 000 O0 0 11 1 RN2 PS5 CPS 500951 00 000 00 0 1! 1 RN3 PS5 CPS 500951 00 000 00 0 1! I RN4 PS5 CPS 500951 O0 000 O0 0 11 1 RN5 P$5 CPS 500951 O0 000 O0 0 RN6 PS5 CPS 500951 O0 000 00 0 11 1 RN7 PS5 CPS 500951 00 000 00 0 11 RN8 P$5 CPS 500951 O0 000 00 0 !I 1 RN9 P$5 CPS 500951 00 000 O0 0 11 RN!O PS5 CPS 500951 O0 000 O0 0 11 1 RNll P$5 CP~ 500951 O0 000 O0 0 I1 1 RNI~ PS5 CPS 500951 O0 000 O0 0 1! 1 RNI3 PS5 CPS 500951 O0 000 O0 0 11 l RNI4 PS5 CPS 500951 O0 000 O0 0 tl ! RN15 PS5 CPS 500951 O0 000 O0 0 I1 RNI6 PS5 CPS 500951 00 000 00 0 11 RFI PS5 CPS 500951 O0 000 00 0 11 1 RF2 PS5 CPS 500951 O0 000 O0 0 I! ! RF3 PS5 CPS 500951 00 000 O0 0 1! 1 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 ~8 0000000000 1 4 6~ 0000000000 1 4 60 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 b8 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 ! 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 i 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 ! 4 68 0000000000 1 4 60 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 ~8 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 i 4 68 0000000000 I 4 68 0000000000 I 4 60 0000000000 I 4 6~ 0000000000 1 4 6~ 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 IS Tape Verlflcat~.on Listino 2-MA~-199515:17 ~chlumberger Alaska COmputlno Center PAGE: 42 NAME SERV UNiT SIER APl PI AP! FILE N ~ N ,D S EPR OCE !O ORDER # LOg TYPE CLASS ~OD .NUMB 8AMP EbEM Ct]DE (HEX) RF4 P CPS 500951 00 000 O0 0 11 1 1 8 0 0 0 RF5 P$5 CPS 500951 O0 000 00 0 11 1 1 4 68 0000000000 RF6 P$5 CP6 500951 00 000 00 0 11 1 1 4 68 0000000000 RF7 P$5 CPS 500951 O0 000 O0 0 11 i I 4 68 0000000000 RF8 PS5 CPS 500951 O0 000 O0 0 11 1 1 4 68 0000000000 RF9 PS5 CPS 500951 O0 000 O0 0 11 1 1 4 68 0000000000 RPIO PS5 CPS 500951 O0 000 O0 0 11 1 I 4 68 0000000000 RFI] PS5 CPS 500951 O0 000 O0 0 11 1 1 4 68 0000000000 RF12 P$5 CPS 500951 00 000 00 0 11 1 I 4 ~8 0000000000 RFi3 PS5 CPS 500951 00 000 00 0 11 1 I 4 68 0000000000 RF14 PS5 CPS 500951 00 000 O0 0 11 1 1 4 68 0000000000 afl5 PS5 CPS 500951 00 000 00 0 11 I I 4 68 0000000000 RF16 PS5 CPS 500951 O0 000 O0 0 11 1 1 4 68 0000000000 TFNS PS5 LB 500951 O0 000 O0 0 11 1 1 4 68 0000000000 GR PS5 GAP! 500951 O0 000 O0 0 11 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmmmmm! mmmmmmmmmmm#mmmmmmNmmmmmmmmm#mmmmmmmmmmmm DFPT 9525500 SIG~.PS5 ~6580 STDT.P$S IS~,:PSS 55:o~1 SFFD.PS5 ~ 9~656 SFND,PSS SBHN,P$5 61.51.1 FTDT,PS5 5936 NTDT.RS5 ABFD PS5 106o012 AFN~ PS5 5951403 ABNi).PS5 s ":pss M O ,:PSS 066 n T.VSS BACK.PS5 2~.198 FB~C.P85 4. 1893 TCAN.P85 TeND.PS5 1478b.826 TCFO.P85 4706.2~1 x, n. PS5 19,8.9, ,ro.pss 7.,oa t, co!.Pss RNa.PS5 313.041 RNi,PS5 1013.891 RN4,P$5 RN6.P$5 1.134.262 RN7.P$5 949.076 RNS.P$5 R"lO.P85 1162.040 RNII.P$5 1791.671 RN!2.P85 RN!4,PS5 !944.449 RN!5,P$5 1560.t89 RN16,?S5 ~F~,P$5 !11,800 RF3,P$5 259.260 RF4.PS5 RF6.PS5 365.742 RF7.P85 ]75,001 RFS,PS5 RFIO.PS5 425,927 RFll,PS5 606.4~3 RF12*PS5 RF14.P$5 856.484 RF15.PS5 768,520 RF16.PS5 GR,PS5 286.000 DEPT, 9500.000 SlGM,P$5 20.246 $TDT,PS5 ISHU.P85 55.094 8FFD,P$5 20.712 SF~D.P$5 SBHN,P$5 84.427 FTDT*PS5 5.926 NTDT.P$5 ABFD,PS5 64'248 AFND,PS5 260,801 ABND.PS5 $!B~.P$5 152.541 M~OF.PS5 BACK,PS5 2!7.170 FOAC.PS5 5,'2677'425 TRAT.PS5 TCAN,PS5 TCND.PS5 11472,225 TCFD'P$5 4026,720 T$CN,PS5 INND.PS5 ~015.521 INFD,P$5 389,117 LCO!.PS5 ~N2'P$5 220 571 . , ' ,.,3.' .,i5 . 6.8 9 R P:85 R'N6,P85 859.601 RN7.PS5 653,297 RNa. PS5 RtIlO.PS5 919.773 RNll,P$5 1255.017 RNI2,PS5 RN!4.P85 1186.249 RN!5..P$5 906.879 RN!6*PS5 · . . . R4,PS5 ~F~,PS5 67065 RF3 PS5 206.304 F 66.000 36.217 15 602 358 7B7 132 18428 0331. 1958 006 2 ! 52 1166669 875 002 ! 944449 1185 188 328704 273 !49 745 ]72 481, 483 66.000 2!.868 131374 267.023 1'505 12981,467 2779.534 2.I37 971.349 893,985 328,~83 1790 33 o:i74 TPHI.P$5 SBMF'PS5 AFFD.PS5 SIGC.P$5 SDSI.P$5 TCAF.P$5 T$CF,P$5 RN! P$5 RN5 PS5 RNg PS5 .RN!3 PS5 RFI..P$5 RF5*PS5 RFg,P$5 RF!3.PS5 TENS.PS5 SBHF~PS5 AFFD.P$5 SIGC,PS5 SD$I,P$5 TCAF*PS5 TSCF.PS5 RNI.PS5 RNS'.P$5 RNg. PS5 RN13.PS5 RFI,PS5 RF5*PS5 24. 175 46:479 83.515 3.076 712286 90 654 847.2~4 110!.854 1212.96b 207i!079 25 001 33 334 40~,408 865.743 930.000 23,915 70,625 61.665 0.318 0.672 6073,:504 1300'432 829'515 872'495 1070.203 1345,275 236.390 232~092 ~'DNI )Iq2 : NIDi~O t[0° Oq : 3dl& ~ql~ t[0/~6 : MiVO [OOiO0 : NOI~8~A OO0'0SII 0tL'f0S 098'IL~I ~66'~I8 OL~'ggL9 ~68°0 L08'~O~ 000'09I[ ISI'L£~ S~d*~NaI O00'O§I S~d*EI3M 6f8'gI9 Sgd'f~a ~IL'S~E ~d*[JM SPI'L£L ~d*itN~ ~98*EgL~ fSd'6~a I£~'I98 ~d*~Na 8~L*SS[I SSd*tN~ Sgd*~¥D,t 9~g'l~L/I ~Sd'Ig~ £6I'I §gd*J~g 8~8'S~ ~gd*X~d~ 000*99 SSd*~NM$ ~60'~Fg ~d 6~ 9~'60[ ~Sd'~IA~ 6gS'gL9 ~Sd*~Ja [oo'o~g fSd'gI~a 9[L'~PL 19a'qN~V qSd'ZQ£N [gO'9 t[0'09 S~d'I[Ma [Lf'88P ~d*Lda LSg'~6~ Sgd*9~a gSd*I[~ t98'~8~I SSd'OtN8 ~d*LN~ EO0*O~[ ~d*MNd g~d'EN~ S88'S~ S~d'O~NI L£8'g86t ~d'QNNI §Sd*~O~ gSL'OO g~d*ONS~ 6~6'9b §Sd*&O~ ~g£'9S Sgd'NH~9 ~Sd*OS~S 881'~9 ~gd*tiH~I ~Sd'~I9 OOt*6~f~ '£d3q 000'98g ggd*aD g~d'L~a ~99'~8a Sgd*gAd ,IS Tame vertftcatlo~ Listing iChlumberger AlasKa Computing Center PAGE~ 44 **** REEL TRAI!,E~ SFRVICE N~a~ : EOIT D~T~ ~ 95103/ 2 OPI~IN : ~LIC R~EL NAmE : 05056 CONTINUATION ~ pREVIOUS REEL COMMENT : aRCO ALASK~ INC,, DS 4-40, PRUDHOE ~AY, APl 50-0~9-2~224-00 * ALASKA COMPUTING CENTER * . ............................ . ....... SCHLUMBERGER ....... . ............................ , COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 4 - 40 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292222400 REFERENCE NO : 98049 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/02/ 3 ORIGIN : FLIC REEL NAME : 98049 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, D.S. 4-40, PRUDHOE BAY, 50-029-22224-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/02/ 3 ORIGIN : FLIC TAPE NAME : 98049 CONTINUATION # : 1 PREVIOUS TAPE : COf4~ENT : ARCO ALASKA INC, D.S. 4-40, PRUDHOE BAY, 50-029-22224-00 TAPE HEADER Prudhoe Bay CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4 - 40 API NUMBER: 500292222400 OPERATOR: ARCO Alaska, Inc. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 3-FEB-98 JOB NUMBER: 98049 LOGGING ENGINEER: J Maj cher OPERATOR WITNESS: K Neupert SURFACE LOCATION SECTION: 34 TOWNSHIP: 1 iN RANGE: 15E FNL: 1269 FSL : FEL: 307 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: 60. O0 DERRICK FLOOR: 59. O0 GROUND LEVEL: 27. O0 WELL CASING RECORD 1 ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 7. 675 9030.0 29.70 5.500 9643.0 17.00 3.500 8696.0 9.30 2.875 9391.0 6.40 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 05-DEC-91 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9499.5 9495.0 9488.0 9485.0 9481.5 9477.5 9471.0 9465.5 9463.5 9460.0 9458.0 9456.5 9453.0 9448.5 9448.0 9441.0 9437.5 9433.5 9429.0 9426.0 9425.5 9424 5 9424 0 9419 0 9416 5 9415 0 9410 5 9407 5 9405 0 9399.0 9395.5 9395.0 9392.0 9391.0 9387.5 9386.5 9379.0 9374.5 9368.0 9362.0 9356.0 9342.0 9338.0 9334.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH TDTP 88885.5 88886.5 9498.0 9493.0 9486.0 9484.0 9479.0 9479.0 9474.0 9474.0 9468.5 9468.5 9464.0 9464.0 9462.0 9462.0 9460.0 9460.0 9457.0 9457.0 9455.5 9455.5 9451.0 9450.5 9447.5 9447.5 9440.5 9435.5 9430.5 9428.0 9426.0 9424.0 9418.5 9414.0 9407.0 9403.5 9398.0 9394.5 9391.0 9386.0 9378.0 9373.0 9366.0 9361.0 9354.5 9337.5 9334.5 9440.5 9435.5 9430.5 9428.0 9426.0 9424.0 9418.5 9416.0 9414.0 9410.5 9407.0 9403.5 9398.0 9394.5 9391.0 9386.0 9378.0 9373.0 93 66.0 9361.0 9354.5 9341.0 9337.5 9334.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 9330 0 9323 0 9322 5 9314 5 9311 5 9298 0 9289 5 9286.5 9275 5 9275 0 9271 0 9261 5 9257 0 9253 0 9246.5 9236.0 9232.0 9227.5 9223.5 9218.0 9212.5 9208.0 9206.5 9202.0 9198.0 9186.0 9182.5 9179.5 9175.0 9169.0 9162.0 9154.5 9152.0 9151.5 9148.0 9144.5 9137.0 9133.5 9122.5 9118.0 9109.5 9107.5 9107.0 9103.0 9098.0 9095.0 9092.0 100.0 $ REMARKS: 9329.0 9322.5 9314.5 9310.5 9297.5 9291.0 9287.0 9275.0 9270.0 92 61.0 9256.5 9252.5 9246.5 9232.0 9227.5 9223.5 9217.0 9213.0 9208.0 9206.0 9202.5 9198.0 9187.0 9182.0 9179.5 9174.5 9169.0 9162.0 9154.0 9152.0 9329.0 9322.5 9314.5 9310.5 9298.0 9291.0 9287.0 9275.0 9270.0 9261.0 9256.5 9252.5 9246.5 9235.5 9232.0 9227.5 9223.5 9217.0 9213.0 9208.0 9206.0 9202.5 9198 0 9187 0 9182 0 9179 5 9174 5 9169 5 9162.0 9154.5 9152.0 9148.0 9144.0 9144.0 9137.0 9137.0 9133.5 9133.5 9122.0 9122.0 9117.5 9117.5 9109.0 9109.0 9108.0 9108.0 9102.5 9102.5 9098.0 9098.0 9093.0 9093.0 9092.0 9092.0 100.0 100.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE TDTP DATA AQUIRED ON ARCO ALSKA'S DS 4-40 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE BCS GA~A RAY, ALSO SIGMA PASS #1 AND THE BCS G~ RAY, CARRYING ALL TDTP CURVES WITH THE SIGMA SHIFTS. PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI]MBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9480.5 9090.0 TDTP 9505.5 9090.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP .............. REMARKS: THIS FILE CONTAINS CASED HOLE TDTP 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: TYPE REPR CODE VALUE 3 73 92 4 66 1 $ 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 ** 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 1094428 O0 000 O0 0 1 1 1 4 68 SIGM TDTP CU 1094428 O0 000 O0 0 1 1 1 4 68 TPHI TDTP PU-S 1094428 O0 000 O0 0 1 1 1 4 68 SBHF TDTP CU 1094428 O0 000 O0 0 1 1 1 4 68 SBHN TDTP CU 1094428 O0 000 O0 0 1 1 1 4 68 SIGC TDTP CU 1094428 O0 000 O0 0 1 1 1 4 68 SIBH TDTP CU 1094428 O0 000 O0 0 1 1 1 4 68 TRAT TDTP 1094428 O0 000 O0 0 1 1 1 4 68 SDSI TDTP CU 1094428 O0 000 O0 0 1 1 1 4 68 BACK TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 FBAC TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 TCAN TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 TCAF TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 TCND TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 TCFD TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 TSCN TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 TSCF TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 INND TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 INFD TDTP CPS 1094428 O0 000 O0 0 1 1 1 4 68 GRCH TDTP GAPI 1094428 O0 000 O0 0 1 1 1 4 68 TENS TDTP LB 1094428 O0 000 O0 0 1 1 1 4 68 CCL TDTP V 1094428 O0 000 O0 0 1 1 1 4 68 GR BCS GAPI 1094428 O0 000 O0 0 1 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: DEPT. 9520. 000 SIGM. TDTP -999. 250 TPHI. TDTP SBHN. TDTP - 999.250 SIGC. TDTP - 999.250 SIBH. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP TSCF. TDTP -999. 250 INND. TDTP -999. 250 INFD. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 GR. BCS DEPT. 9080. 000 SIGM. TDTP -999. 250 TPHI. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP SDSI. TDTP -999. 250 BACK. TDTP -999. 250 FBAC. TDTP TCAF. TDTP -999.250 TCND. TDTP -999.250 TCFD. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 GR. BCS -999. 250 SBHF. TDTP -999. 250 TRAT. TDTP -999. 250 TCAN. TDTP -999. 250 TSCN. TDTP -999. 250 GRCH. TDTP 88. 004 -999. 250 SBHF. TDTP -999. 250 TRAT. TDTP -999. 250 TCAN. TDTP -999. 250 TSCN. TDTP -999. 250 GRCH. TDTP 28. 949 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SU~fiV~ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9483.0 9088.5 TDTP 9507.0 9089.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 9505.0 9502.0 9499.5 9494.5 9493.0 9488.5 9485.0 9481.0 9476.0 9470.5 9467.0 9465.5 9461.0 9458.0 9456.5 9454.5 9450.0 9446.5 9443.0 9440.5 9438.5 9436.0 9433.5 9428.5 9426.0 9424 0 9422 5 9421 5 9419 5 9414 0 9411 0 9410.5 9405.5 9404.5 9402.0 9398.5 9398.0 9396.0 9392.0 9389.5 9387.5 9384.5 9381.0 9380.0 9378.0 9377.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH TDTP 88888.0 88888 0 9470.5 9465.5 9464.0 9457.5 9455.5 9453.5 9447.5 9440.5 9436.0 9428.0 9426.0 9421.0 9414.0 9410.5 9407.0 9403.5 9398.0 9395.0 9389.0 9383.5 9381.0 9378.0 9505 0 9502 0 9498 0 9493 0 9491 0 9486 0 9484 0 9478.5 9473.0 9468.5 9461.0 9455.0 9449.0 9442.0 9437.0 9434.0 9430.5 9428.0 9426.0 9424.0 9422.5 9419.0 9410.5 9404.5 9397.5 9391.0 9386.5 9379.5 9375.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 9372 9371 9371 9368 9367 5 9361 5 9357.0 9353.5 9353.0 9345.0 9341.0 9338.0 9337.5 9336.0 9331.5 9330.0 9327.0 9323.0 9321.0 9315.0 9314.5 9311.0 9309.5 9304.0 9300.0 9294.5 9289.0 9288.0 9282.5 9278.0 9275.5 9275.0 9273.5 9269.0 9261.5 9260.5 9251.0 9246.0 9242.5 9216.5 9209.5 9208.0 9205.5 9202.0 9201.5 9200.5 9197.5 9194.5 9190.0 9186.5 9181.5 9176.5 9174.5 9169.0 9161.5 5 9371.5 5 9370.0 0 0 9366.5 9361.0 9355.5 9352.0 9344.0 9337.5 9334.5 9331.0 9329.0 9327.0 9316.5 9309.5 9287.0 9275.0 9273.0 9270.0 9261.0 9251.5 9246.5 9242.5 9216.0 9210.0 9208.0 9205.0 9202.5 9200.5 9198.0 9189.5 9182.0 9174.5 9169.0 9370.0 9367.0 9352.5 9341.0 9337.5 9329.0 9323.0 9320.5 9314.5 9308.5 9303.5 9300.0 9295.0 9289.5 9282.0 9278.5 9275.0 9260.5 9205.5 9202.5 9195.0 9188.0 9181.5 9176.0 9170.0 9162.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 9158.5 9154.5 9149.0 9146.5 9144.0 9138.5 9132.5 9128.5 9122.0 9120.5 9120.0 9117.5 9115.5 9113.0 9112.0 9110.0 9109.5 9107 5 9107 0 9102 0 9098 0 9095 0 9094 5 100 0 $ 9158.5 9154.5 9149.0 9147.0 9144.5 9132.0 9129.0 9122.0 9119.5 9117.5 9115.0 9111.5 9109.0 9108.0 9102.5 9098.5 9093.0 98.5 9138.5 9120.0 9117.5 9112.5 9109.0 9107.5 9098.0 9094.0 99.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO SIGMA PASS #2 AND SIGMA 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 10 TYPE REPR CODE VALUE .............................. 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 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM TDTP CU 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI TDTP PU-S 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 SBHF TDTP CU 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 SBHN TDTP CU 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 SIGC TDTP CU 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 SIBH TDTP CU 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT TDTP 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 SDSI TDTP CU 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 BACK TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TCAN TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TCAF TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TCND TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TCFD TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TSCN TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TSCF TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 INND TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 INFD TDTP CPS 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH TDTP GAPI 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 TENS TDTP LB 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 CCL TDTP V 1094428 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9507. 000 SIGM. TDTP 15. 580 TPHI. TDTP 24. 407 SBHF. TDTP SBHN. TDTP 43. 725 SIGC. TDTP 2.172 SIBH. TDTP 51. 021 TRAT. TDTP SDSI. TDTP O. 419 BACK. TDTP 294. 779 FBAC. TDTP 88. 767 TCAN. TDTP TCAF. TDTP 15882. 514 TCND. TDTP 22807. 742 TCFD. TDTP 7163. 305 TSCN. TDTP TSCF. TDTP 2561 . 379 INND. TDTP 1532. 837 INFD. TDTP 277. 764 GRCH. TDTP TENS. TDTP 1340. 000 CCL. TDTP O. 000 DEPT. 9088. 500 SIGM. TDTP -999.250 TPHI. TDTP -999. 250 SBHF. TDTP SBHN. TDTP -999. 250 SIGC. TDTP -999. 250 SIBH. TDTP -999. 250 TRAT. TDTP SDSI. TDTP -999.250 BACK. TDTP -999.250 FBAC. TDTP -999.250 TCAN. TDTP TCAF. TDTP -999. 250 TCND. TDTP -999. 250 TCFD. TDTP -999. 250 TSCN. TDTP TSCF. TDTP -999.250 INND. TDTP -999.250 INFD. TDTP -999.250 GRCH. TDTP TENS. TDTP -999. 250 CCL. TDTP -999. 250 36.717 1.772 37755.258 6088.805 -999.250 -999.250 -999.250 -999.250 -999.250 23.719 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 11 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SU~94ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9487.0 9094.5 TDTP 9506.0 9094.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GRCH TDTP 88888.0 88892.0 88887.0 9502.5 9501.5 9500.0 9498.0 9495.5 9493.5 9493.0 9491.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 12 9485.5 9481.0 9476.5 9476.0 9473.5 9472.0 9470.5 9468.5 9465.0 9464.5 9460.5 9458.5 9456.5 9452.5 9450.5 9444.0 9441.5 9438.5 9435.5 9434.0 9431.0 9428.5 9426.0 9425.5 9423.5 9422.5 9421.5 9420.0 9419.5 9416.5 9414.0 9411 0 9410 5 9407 5 9406 0 9405 5 9399 0 9398 5 9392 0 9387 5 9383 5 9377 0 9376 0 9372.5 9370.0 93 68.5 9367.0 93 61.5 9359.0 9357.0 9353.5 9352.5 9342.0 9338.0 9336.0 9480.0 9476.0 9474.0 9470.5 9464.0 9460.5 9455.5 9451.0 9440.5 9435.5 9432.5 9428.0 9426.0 9421.0 9419.0 9414.0 9410.5 9407.5 9403.5 9398.0 9390.5 9378.0 9371.5 9366.5 9361.0 9355.5 9352.0 9341.0 9337.5 9334.5 9484.0 9478.5 9473.0 9466.0 9464.0 9458.5 9455.5 9449.0 9443.0 9436.5 9431.0 9428.0 9426.0 9424.0 9422.5 9419.0 9416.0 9410.0 9404.5 9398.0 9386.0 9381.0 9374.5 9370.0 9367.0 9361.0 9358.0 9352.5 9337.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 13 9334.5 9332.0 9331.0 9323.0 9322.5 9321.0 9314.5 9311.5 9308.5 9300.5 9293.0 9292 0 9288 0 9285 5 9282 5 9276 0 9274 5 9272 0 9269.5 9265.5 9260.5 9255.0 9254.0 9253.0 9251.0 9246.0 9235.5 9233.0 9230.5 9229.5 9222.5 9217.0 9208.0 9207.5 9206.0 9204.0 9201 5 9195 5 9193 0 9188 0 9186 0 9183 0 9179 5 9168 5 9162.0 9161.5 9158.5 9155.0 9152.0 9149.0 9146.5 9144.0 9142.0 9134.5 9132.5 9331.0 9319.5 9310.5 9292.5 9285.5 9275.5 9273.0 9255.0 9253.0 9251.5 9230.0 9208.0 9204.5 9193.0 9182.0 9162.0 9158.5 9154.5 9152.0 9147.0 9142.0 9135.5 9132.0 9334.5 9330.5 9323.0 9320.5 9314.5 9307.0 9301.0 9294.5 9289.5 9282.0 9275.0 9271.5 9267.5 9264.5 9260.5 9253.0 9246.5 9235.5 9233.0 9230.0 9222.5 9216.0 9208.0 9205.5 9202.5 9195.5 9190.0 9186.5 9179.5 9169.5 9162.0 9149.5 9144.0 9132.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 14 9126.0 9120.5 9120 0 9117 5 9114 5 9113 0 9109 5 9107 5 9106 5 9103 5 9102 5 9098.0 100.0 9125.5 9119.5 9117.5 9115.0 9108.0 9102.5 9098.5 100.5 9119.5 9117.5 9112.5 9109.0 9107.5 9105.0 9102.5 100.0 REMARKS: THIS FILE CONTAINS CASED HOLE TDTP PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO SIGMA PASS #3 AND SIGMA 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 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 15 ** 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 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 SIGM TDTP CU 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI TDTP PU-S 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 SBHF TDTP CU 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 SBHN TDTP CU 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 SIGC TDTP CU 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 SIBH TDTP CU 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT TDTP 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 SDSI TDTP CU 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 BACK TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TCAN TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TCAF TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TCND TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TCFD TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TSCN TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TSCF TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 INND TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 INFD TDTP CPS 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH TDTP GAPI 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 TENS TDTP LB 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 CCL TDTP V 1094428 O0 000 O0 0 3 1 1 4 68 0000000000 * * DA TA * * DEPT. 9506. 000 SIGM. TDTP 15. 577 TPHI. TDTP 25. 901 SBHF. TDTP SBHN. TDTP 43 . 402 SIGC. TDTP 1 . 839 SIBH. TDTP 50. 611 TRAT. TDTP SDSI. TDTP O. 422 BACK. TDTP 309. 549 FBAC. TDTP 95.102 TCAN. TDTP TCAF. TDTP 15961. 969 TCND. TDTP 23012. 727 TCFD. TDTP 7256.315 TSCN. TDTP TSCF. TDTP 2633.208 INND. TDTP 1455.237 INFD. TDTP 276. 790 GRCH. TDTP TENS. TDTP 1325. 000 CCL. TDTP O. 000 DEPT. 9094. 000 SIGM. TDTP 12. 183 TPHI. TDTP 13. 971 SBHF. TDTP SBHN. TDTP 47. 909 SIGC. TDTP O. 380 SIBH. TDTP 57. 625 TRAT. TDTP SDSI. TDTP O. 204 BACK. TDTP 267. 757 FBAC. TDTP 61. 956 TCAN. TDTP TCAF. TDTP 33903. 492 TCND. TDTP 27160. 992 TCFD. TDTP 12076. 885 TSCN. TDTP TSCF. TDTP 5681.524 INND. TDTP 1892.110 INFD.TDTP 419.522 GRCH. TDTP TENS. TDTP 1250. 000 CCL. TDTP O. 000 37.768 1.824 39048.563 6441.747 -999.250 34. 162 1. 437 60429. 086 10126. 666 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 4 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 INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, TDTP $ REMARKS: THIS FILE CONTAINS THE ARITH~ETIC AVERAGE OF 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 5 66 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 17 TYPE REPR CODE VALUE 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PNAV CU 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PNAV PU-S 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 SBHF PNAV CU 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 SBHN PNAV CU 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 SIGC PNAV CU 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 SIBH PNAV CU 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PNAV 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 SDSI PNAV CU 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 BACK TDTP CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC TDTP CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 TCANPNAV CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 TCAF PNAV CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 TCND PNAV CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 TCFD PNAV CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 TSCN PNAV CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 TSCF PNAV CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 INND PNAV CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 INFD PNAV CPS 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH TDTP GAPI 1094428 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9505.500 SIGM. PNAV 15.330 TPHI.PNAV 23.509 SBHF. PNAV 33.308 SBHN. PNAV 41.580 SIGC. PNAV 2.178 SIBH. PNAV 46.064 TRAT. PNAV 1.743 SDSI.PNAV 0.400 BACK. TDTP 84.650 FBAC. TDTP 23.147 TCAN. PNAV 42097.438 TCAF. PNAV 18050.652 TCND.PNAV 23893.641 TCFD.PNAV 7744.463 TSCN. PNAV 6525.534 TSCF. PNAV 2789.284 INND.PNAV 1597.642 INFD.PNAV 303.086 GRCM. TDTP -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 18 DEPT. 9090.000 SIGM. PNAV -999.250 TPHI.PNAV -999.250 SBHF. PNAV -999.250 SBHN. PNAV -999.250 SIGC. PNAV -999.250 SIBH. PNAV -999.250 TRAT. PNAV -999.250 SDSI.PNAV -999.250 BACK. TDTP 131.497 FBAC. TDTP 27.629 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 17.359 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SU~iARY VENDOR TOOL CODE START DEPTH TDTP 9534.5 $ 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) : STOP DEPTH 9087.5 08-NOV-97 CP 44.2 1653 08-NOV-97 9515.0 9514.0 9090.0 9515.0 1500.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 19 DEPTH CONTROL USED (YES/NO) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~FIA RAY GR GARDA RAY $ NO TOOL NUMBER CGRS 863 TDT P 396 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9643.0 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) : Crude Oil 35.0 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): 200 FAR COUNT RATE HIGH SCALE (CPS): 12200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS BHC Sonic 05-DEC-1991. Ave Outputs computed from the 3 passes. GOC 9250 UNDERRUN: 9340-48 THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 20 ** 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 5 1 1 4 68 0000000000 DEPT FT 1094428 SIGM PS1 CU 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 SBHF PS1 CU 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 SBHN PS1 CU 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 SIGC PS1 CU 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 SIBH PS1 CU 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 SDSI PS1 CU 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 BACK PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TCANPS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TCAF PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TCND PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TCFD PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TSCN PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TSCF PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 INND PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 INFD PS1 CPS 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1094428 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 21 ** DATA ** DEPT. 9520.000 SIGM. PSl 14.038 TPHI.PS1 SBHN. PS1 44.336 SIGC. PS1 3.374 SIBH. PS1 SDSI.PS1 0.302 BACK. PSi 104.564 FBAC. PS1 TCAF. PS1 19930.273 TCND. PS1 23286.078 TCFD. PS1 TSCF. PS1 2854.928 II?ND. PSI 1746.502 INFD. PS1 GR.PS1 36.719 CCL.PS1 0.000 DEPT. 9087.500 SIGM. PS1 16.587 TPHI.PS1 SBHN. PS1 48.861 SIGC. PS1 1.012 SIBH. PS1 SDSI.PS1 0.389 BACK. PSI 132.514 FBAC. PS1 TCAF. PS1 17432.281 TCND.PS1 21764.770 TCFD. PS1 TSCF. PS1 2920.235 INND.PS1 1772.832 INFD. PS1 GR.PS1 36.563 CCL.PS1 0.000 13.844 SBHF. PS1 50.266 TRAT. PS1 25.906 TCAN. PS1 7867.384 TSCN. PS1 307.570 TENS.PSi 18.459 SBHF. PS1 61.678 TRAT. PS1 26.349 TCAN. PS1 8238.021 TSCN. PS1 386.820 TENS.PSi 31.241 1.401 37494.961 5370.996 785.000 36.083 1.487 34762.242 5823.331 755.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE . FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 6 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 S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH TDTP 9532.5 9090.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 22 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): 08-NOV-97 CP 44.2 1653 08-NOV-97 9515.0 9514.0 9090.0 9515.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~mlA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS 863 TDT P 396 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9643.0 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) : Crude Oil 35.0 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): 200 FAR COUNT RATE HIGH SCALE (CPS): 12200 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS BHC Sonic 05-DEC-1991. Ave Outputs computed from the 3 passes. LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 23 GOC 9250 UNDERRUN: 9340-48 THIS FILE CONATINS THE RAW DATA FOR PASS #2. $ 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 NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 SBHF PS2 CU 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 SBHN PS2 CU 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 SIGC PS2 CU 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 SIBH PS2 CU 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 SDSI PS2 CU 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 BACK PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 TCAN PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 TCAF PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 TCND PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 TCFD PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 TSCN PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 24 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) TSCF PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 INND PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 INFD PS2 CPS 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1094428 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9520.000 SIGM. PS2 14.796 TPHI.PS2 20.774 SBHF. PS2 SBHN. PS2 43.413 SIGC. PS2 2.875 SIBH. PS2 49.814 TRAT. PS2 SDSI.PS2 0.447 BACK. PS2 313.223 FBAC.PS2 95.692 TCAN. PS2 TCAF. PS2 16693.770 TCND.PS2 22560.266 TCFD.PS2 7207.708 TSCN. PS2 TSCF. PS2 2607.112 INND.PS2 1468.813 INFD. PS2 269.333 TENS.PS2 GR.PS2 238.375 CCL.PS2 0.000 DEPT. 9090.000 SIGM. PS2 12.176 TPHI.PS2 15.095 SBHF. PS2 SBHN. PS2 50.716 SIGC. PS2 0.509 SIBH. PS2 63.739 TRAT. PS2 SDSI.PS2 0.206 BACK. PS2 266.898 FBAC. PS2 60.800 TCAN. PS2 TCAF. PS2 31820.805 TCND.PS2 26010.910 TCFD.PS2 11200.633 TSCN. PS2 TSCF. PS2 5155.717 INND.PS2 1792.746 INFD. PS2 399.978 TENS.PS2 GR.PS2 23.719 CCL.PS2 0.000 38.166 1.663 37132.664 5799.112 1285.000 42.037 1.471 58242.758 9436.691 1285.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 25 FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: O . 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH TDTP 9528.0 $ 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): STOP DEPTH 9091.5 08-NOV-97 CP 44.2 1653 08-NOV-97 9515.0 9514.0 9090.0 9515.0 1500.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY TDTP THERMAL DECAY $ TOOL NUMBER CGRS 863 TDT P 396 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 9643.0 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) : Crude Oil 35.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 26 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 200 FAR COUNT RATE HIGH SCALE (CPS) : 12200 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS) : 30000 TOOL STANDOFF (IN): REMARKS: Correlation Log: SWS BHC Sonic 05-DEC-1991. Ave Outputs computed from the 3 passes. GOC 9250 UNDERRUN: 9340-48 THIS FILE CONATINS THE RAW DATA FOR 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 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 1094428 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1094428 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1094428 O0 000 O0 0 7 1 1 4 68 0000000000 SBHF PS3 CU 1094428 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 27 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) SBHNPS3 CU 1094428 O0 000 O0 0 7 1 1 4 68 SIGC PS3 CU 1094428 O0 000 O0 0 7 1 1 4 68 SIBH PS3 CU 1094428 O0 000 O0 0 7 1 1 4 68 TRAT PS3 1094428 O0 000 O0 0 7 1 1 4 68 SDSI PS3 CU 1094428 O0 000 O0 0 7 1 1 4 68 BACK PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 FBAC PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 TCANPS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 TCAF PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 TCND PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 TCFD PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 TSCN PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 TSCF PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 INND PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 INFD PS3 CPS 1094428 O0 000 O0 0 7 1 1 4 68 TENS PS3 LB 1094428 O0 000 O0 0 7 1 1 4 68 GR PS3 GAPI 1094428 O0 000 O0 0 7 1 1 4 68 CCL PS3 V 1094428 O0 000 O0 0 7 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 9520.000 SIGM. PS3 13.978 TPHI.PS3 24.568 SBHF. PS3 SBHN. PS3 43.820 SIGC.PS3 2.353 SIBH. PS3 51.617 TRAT. PS3 SDSI.PS3 0.413 BACK. PS3 340.500 FBAC. PS3 105.698 TCAN. PS3 TCAF. PS3 21350.949 TCND. PS3 23609.063 TCFD. PS3 7393.120 TSCN. PS3 TSCF. PS3 2660.703 INND. PS3 1453.846 INFD.PS3 315.457 TENS.PS3 GR.PS3 150.625 CCL.PS3 0.000 DEPT. 9091.500 SIGM. PS3 12.643 TPHI.PS3 14.399 SBHF. PS3 SBHN. PS3 48.029 SIGC.PS3 0.416 SIBH. PS3 58.133 TRAT. PS3 SDSI.PS3 0.215 BACK. PS3 272.372 FBAC. PS3 63.148 TCAN. PS3 TCAF. PS3 31902.285 TCND.PS3 26215.965 TCFD.PS3 11445.602 TSCN. PS3 TSCF. PS3 5337.277 INND. PS3 1866.321 INFD.PS3 423.867 TENS.PS3 GR.PS3 38.000 CCL.PS3 0.000 30.379 1.832 51836.617 6459.753 1250.000 31.866 1.442 57021.922 9539.813 1255.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/02/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-FEB-1998 11:12 PAGE: 28 **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 98/02/ 3 ORIGIN : FLIC TAPE NAME : 98049 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA INC, D.S. 4-40, PRUDHOE BAY, 50-029-22224-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/02/ 3 ORIGIN : FLIC REEL NAME : 98049 CONTINUATION # PREVIOUS REEL : COGENT : ARCO ALASKA INC, D.S. 4-40, PRUDHOE BAY, 50-029-22224-00 RECEIVED JAN 10 1992 Alaska Oil & Gas Cons. CommissJor~ Anchorage 0 E: 0 'i: '[ 6 6 'i: - D ;:i~ (J -- 9 ~ :3D~d 0 t:: 0 "i: :; O 6 l: - ;:) g (:t.- q '~ LgL'O 9gl"L6£g OSO'g L~O°g 90I'~gI 6gL'O ~E'9~8~ 889'~ 6~0'9g~ O05'Z6 £gt'O ~9~'~ 00~'06 9~L:O 898 0Sg'666' 0SE'666' 666- 0Sg°666~ 0S['666 0§g:'666 ~ 39~'d 129¥d b:!$ Tepe ',;erif.fcat..Jon o'::?, hea..,..~er C~at.,~ f~or each rt~n anq tool. st~in(l in separate fi. les~ '....ool strin;g ~1 fo run presented f:jrst {[:,ri~arv Oeoth contrni strinq used to OeDt. h shf[t the Sadler fo!l.o¥:,ed ~'~v files for other s:a.i.n oass strinqs per ?: l 'T,-, l) T 'r ~...: 0 5- P!!.'C- 9 ! 5c;(,::-~ A 50 S[,S-~.:~''~, 2004 o 0 i 8. () 0"8S Ot ) ~ d Ifil IIiI IIIIi Ii~II I I I I I III oo;;;;;;;; ;; ; "~ .... '~' ': '[ t i6-D~JC-I, got Ir;:3 2 84, 5, <:! 0 9 H T ~. ?~. D "'[ E; 3,905 155.56:1 565. 200 -32.188 0,786 290.200 293,200 256.84.4 4.162 !.55.561 549.600 -73,25",) 0..7~4 57,~6i 0 !. 06O 55.03.,~ 32.920 155.665 585.6 (.) 0 ,,,82.3 ! 3 0.78O 11.~51 14.356 24.6!2 ! !,2. 156.(:29 -109.5~3 0.789 1!4.',2.,50 J. 22. 044, 14C'.R5~ 71. R 0(..: ! 54.1 C'6 5 % 3.20 t) -gg.250 0.8 r:, 0 27.()33 3 2.4 b 3 28.855 ab. 3 ,'.:: -~ 1.52.446 o P. D T E PAGE: 12 -20.000 0,7~6 386.000 89,607 3,411 4'052 - ~:188 364,000 76,~51 706,~99 17'373 16,377 6.55i -73,250 0,784 385,200 20.209 790,816 e4.380 69.608 5,734 -82,313 0.780 352,400 24,204 724,658 8.753 8,194 22.192 -109,563 0.789 34.662 765.369 36.992 30.804 2.519 -9g.250 0.800 0gg'666 0Sg'666' OSg 666' OS~ 666' OS~ 666' OSE 666- 00~ LO[: 00~'6~ t9§'99 000°0S6t 000'0S6[ 596'I~8 L~g't, 8 008'90[ 9[8'0 000'08[ O~ [ # 0 ' ~ i 0 6 Og~L '~2 Sct"~lU~:her.qer A.]aske Cor~p,.~t:.i~¢~ CenteT ,1, C)'9! !0:30 15 9t O00',~SEf/ ~89'9LI LgL'~61: t9L'O 88~'~[6I 08L'8I O00'g[L~ 6EB'gLt 0~8'~0~ 900 0 L~L'© 000'09~ L~6'eL~ O~9'L~C °0 [60 ~[ 969 ~i 000 019~0£~ S~L'O ~8L'9~9 ~8'L~ ~[~'09E E9t'O 808'9 9L~'6~Et L[O°u 8~0'0 966'LL 6EL'9 6[u'O '[o9'~ 868'L~ 9L8'6~ 000'0~£~ 90~'~ 08~'~L 0~9'0- 90g't6E O00'g~ L~tiLL OL§ O- E6L°O CLC'O~ 060"0~ C~6"L9I 60g'g 9[O'PO~ 800'0- 9LL"O O00°~EE~ ~19"691 L86'iOg £00"0 99L"0 gL["6Oi~g 8 t : MgVd q N O' 80 d 089!66~z LI::O g ~90 8I~9 609'~g I.~L'L 'i;L8 ' f, 9'[ OL[ "g gqO ' t:q L:b L ~t. 0... L '~Lt 6~:, 0 E ~ v [ L 0 9 0 ~ 0 [: 0 ~ "[ 6 6 '[.-- D';~' {] - 9 i444.700 SS~i'v'. LDT 2.7 g 3 C A L !.~. b 0 T ,! 34.4: () ~ g R. !.,,~ D T 6.9 k 0 TENS, C~L 76(). 541 O 0 6 b I '.!" i!. L D T 8 i 2 S S ~i' V, L, D T 841~ C f~ L ,!, L D T 9 7 !. G ~':;:, b !)T ~ ~ 7 '? ~ R .~. C ~:' L, 028 2.J74 -0.!27 I7.2'2,9 1,379. 376 6.980 79. 535 760.54! ,3.22O 1738.666 4365.0OO 2 . 2 '72 -0.!20 16.fl20 !,329.29! 6. 080 64 ' 7 ]0 76?.07.2...8 3.166 1926,851 4385.000 PAGE: 19 1~ 0,605 2.459 76,136 4,122 t61,648 4:365'000 40.0.4,2 40,921 527,275 0.832 -0.546 147.352 80,430 4.044 1.71,474 4:t85,000 39,052 38,233 [;33.435 0.833 for each t,ass, tool strinq, i. n Oq ' 6 0 * [. 0 6 o~ 0 g'; 0 T '[ 6 6 j; -' J :ii ,::I- 9 T [. 0 t 0 o # gLL°O L[9'gE L06°~,~I 008'98E ~LL'O O00'O~- ~O~6E 6L6 ~ L60'E6- L06'~I 0~E'666- O000OO0000 8 ~ 9 0 13D~'d 0 E: 0 '[ 'i, 6,3 [ - 3:4 {i- 9 000'0~6I 000'0~6[ 8~8'06 009'90£ 6~0'~I ~8'6SL 008'69[ 06L'O 6LO!SE LLO 9~L 86S 8~ 009'L8£ £9~ L6- 8O6.L~ g6S 6L~'8 ~g'889 009~£ ~LL:O O~g 68' 88~'6 ESS'L9 9LE"E~ 000'£9' 618'8 ~ES'LI 8gE'~69 6~L'89 009'£9£ i. 't,' t~ ' 8- 06L ' 0 [59S ' ~;0 O09'9DS SSL'O EOS'L6- L6L ~ DI, L 0 oS~'68- 008'9~ 66~ "0 t, g e "6 g 0 ° 8~ uOL' S 0 t:' 6 ~.~" ~' i:06 "(}SL 9 :Lgt{i'i) .t.'. : · IIt II ,, II lli I II llIlI I II ii, I I iii I III i il I I I I II Il I Iii ii }ii i I ii! ill .. Ii (X'.',]E) '"4CI,LJ;J i,,.,]:]ri',.q (]',:i':,;' ~ i..~.~r't,.,, ;~('}~,.i .., f:g %'r ;! O ~do.~. i, .'")L)'] -f,f, N S iq 2) 0 d d. . dd[q8 M'ZiS ~ ~:,~ ~ ' '" ',., ..,, ,.: ,..,, ~l ;4 ! t :".~. >'1 ' 1 .I 3 I .-.* w_ _ [dY [d~' Icl~- '4..., ,._,~i :r'. e..,,_, d ., :3DVd PAGe: 27 t I a 68 CO00000000 ! I 4 68 0000000oo0 ~ I 4 68 0000000000 ~. ~ 4 68 0000000000 1 ! 4 6~ OOOO000000 1 !. 4 6~ 0000000000 ! ! 4 68 0oo000000o * * i: ,a (l'h * * 2569. 314 RCFT, C?,JR !.22.539 !64.450 HTE'N. C l::,i P 12!,755 TE~iS, L[)R c~C ~T. Cx' t? 4426.33~ RCFT.CNP G F'. C"',' R 22.813 CAI,I .C~ ~'.~ T ~' ',:, C..,,~ ~t !62.456 !{TE['~. C/,.~ ~ P !..~ Z. [.,D'~ 134.23] l'Ft'~$, L9¢ ~?'E~', I,~,)~ 768.2.17 'P.','.i h. C~ip 1 . 999 T¢iPR. ",Ir, F' ("'. "..'-r,'. (? ',~ ~ 482.2,4" ~.~, RCFT. C:,;R, r: ~.~. C "~; ;-:~ 26.72 8 C a. 1., .l. C ~' P ~'r~lr. .~"~r:' 160. ...... 1 ;~2 HTU'N.. ,C;~g_ ,' 1. ~'?;, ~ 134. iton ' 35,692 830,092 6.462 125.912 3430.000 33.292 858.340 7,326 795.264 4830.000 25.010 1,601,20! 6,808 698.976 4700.000 25.1~9 1.727,360 6 773 768:247 4625.000 20.634 2186.755 6.946 658.477 4350,000 49.993 33,059 2.P97 3896.9!3 26.54,8 1.58.343 !24.475 670.225 4!85.!19 54.524 156.295 122.2~? 663,004 3,932 1509 282 154.254 161.253 760o4B4 3. 946 548. 507 t. 45.2()1 !54.253 292.11t 76'1 . 379 T !(~ P H. CNR CALl .CNR TENS. [,,DR RCFT.CNU TE~$.LDP T~PH,CNR RCPT.CN~ TENS,UDR PAGE; 28 22.939 670,225 4395,000 21.601 1801.795 7.913 663,00 4 42,95,000 50,359 350'730 7,015 760"484 4.445,000 48.372 350,730 6,980 767 .~79 44,1.5.000 ¢¢~,
